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HomeMy WebLinkAbout222-142 T R A N S M I T T A LL
FROM:Kelsey Anderson TO: Meredith Guhl
ConocoPhillips Alaska, Inc. AOGCC
700 G Street 333 W.7
th Ave., Suite 100
Anchorage AK 99501 Anchorage, Alaska
RE:: KRU 3S-704
Permit: 222-142
DATE: 05/20/2025
Transmitted:
North Slope
KRU 3S-704
Via SFTP
____ 3S-704 GeoSphere Data
Size 106 MB, 4 files
Transmittall instructions: please promptly sign, scan, and e-mail to AKGGREDTSupport@ConocoPhillips.onmicrosoft.COM
CC: 3S-704 - e-transmittal well folder
Receipt: Date:
Alaska/IT-Data Services |ConocoPhillips Alaska |
222-142
T40436
5/21/2025Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2025.05.21 08:47:42 -08'00'
T R A N S M I T T A LL
FROM:Kelsey Anderson TO: Meredith Guhl
ConocoPhillips Alaska, Inc. AOGCC
700 G Street 333 W.7
th Ave., Suite 100
Anchorage AK 99501 Anchorage, Alaska
RE:: KRU 3S-704
Permit: 222-142
DATE: 05/02/2025
Transmitted:
North Slope
KRU 3S-704
Via SFTP
____ 3S-704 Geochem Data
Size 1.09 MB, 6 files
Transmittall instructions: please promptly sign, scan, and e-mail to AKGGREDTSupport@ConocoPhillips.onmicrosoft.COM
CC: 3S-704 - e-transmittal well folder
Receipt: Date:
Alaska/IT-Data Services |ConocoPhillips Alaska |
224-142
T40352
Gavin Gluyas
Digitally signed by Gavin
Gluyas
Date: 2025.05.02 09:45:46
-08'00'
T R A N S M I T T A LL
FROM:Kelsey Anderson TO: Meredith Guhl
ConocoPhillips Alaska, Inc. AOGCC
700 G Street 333 W.7
th Ave., Suite 100
Anchorage AK 99501 Anchorage, Alaska
RE:: 3S-704
Permit: 222-142
DATE: 04/14/2025
Transmitted:
North Slope
3S-704
Via SFTP
____ Mudlog LAS Data
Size 10.9 MB, 3 files
Transmittall instructions: please promptly sign, scan, and e-mail to AKGGREDTSupport@ConocoPhillips.onmicrosoft.COM
CC: 3S-704 - e-transmittal well folder
Receipt: Date:
Alaska/IT-Data Services |ConocoPhillips Alaska |
222-142
T38149
Gavin Gluyas
Digitally signed by Gavin
Gluyas
Date: 2025.04.14 11:46:49
-08'00'
From:Heusser, Heather A (DNR)
To:Guhl, Meredith D (OGC)
Cc:Morgan, Kirk A (DNR)
Subject:RE: ConocoPhillips KRU 3S-704, Extended Confidentiality?
Date:Wednesday, April 16, 2025 3:22:56 PM
Hi Meredith,
We have not received a request for extended well confidentiality on KRU 3S-704.
Heather
From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Sent: Tuesday, April 8, 2025 10:56 AM
To: Heusser, Heather A (DNR) <heather.heusser@alaska.gov>
Cc: Morgan, Kirk A (DNR) <kirk.morgan@alaska.gov>
Subject: ConocoPhillips KRU 3S-704, Extended Confidentiality?
Hello Heather,
Has ConocoPhillips Alaska requested extended confidentiality for KRU 3S-704, API 50-103-20848-
00-00, due for release after April 8, 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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222-142
T39271
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.07.24 09:57:25 -08'00'
TT RR AA NN SS MM II TT TT AA LL
CONFIDENTIAL DATA
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: 3S-704
Permit: 222-142
DATE: 04/23/2024
Transmitted:
Kuparuk River Unit, North Slope, Alaska
3S-704
Via hard drive drop
Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com
CC: 3S-704 - e-transmittal well folder
Receipt: Date:
Alaska/IT-GGRE & Data/ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512
222-172
T38416
Meredith Guhl Digitally signed by Meredith Guhl
Date: 2024.04.23 14:31:33 -08'00'
222-142
TT RR AA NN SS MM II TT TT AA LL
CONFIDENTIAL DATA
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: 3S-704
Permit: 222-142
DATE: 11/28/2023
Transmitted:
Kuparuk River Unit, North Slope, Alaska
3S-704
Via SFTP
ML – 16.8 MB 9 files, 0 folders
Logs – 8.80 GB 98 files, 33 folders
Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com
CC: 3S-704 - e-transmittal well folder
Receipt: Date:
Alaska/IT-Data Services/ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512
PTD: 222-142
T38149
11/29/2023
Kayla
Junke
Digitally signed
by Kayla Junke
Date: 2023.11.29
10:21:31 -09'00'
CAUTION: This email originated from outside the State of Alaska mail system. Do not
click links or open attachments unless you recognize the sender and know the content
is safe.
From:Morrow, Dustin W
To:Wallace, Chris D (OGC)
Cc:Loepp, Victoria T (OGC); McLellan, Bryan J (OGC)
Subject:RE: [EXTERNAL]KRU 3S-704 (PTD 2221420) Sundry 10-404 Fracfocus and Chemical Disclosure Requirements
Date:Monday, April 17, 2023 9:41:34 AM
Good morning Mr. Wallace,
I was able to track down one of our team members that puts in all the fracfocus reports and he
confirmed that the reports were completed late last week.
Please let me know if you are seeing the reports or if you would like me to send them to you in
another way.
Thank you,
Dustin W. Morrow
Staff Completions Engineer
ConocoPhillips Alaska
Cell: 832-493-9141
Office: 907-263-4752
From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Sent: Thursday, April 6, 2023 10:16 AM
To: Morrow, Dustin W <Dustin.W.Morrow@conocophillips.com>
Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; McLellan, Bryan J (OGC)
<bryan.mclellan@alaska.gov>
Subject: [EXTERNAL]KRU 3S-704 (PTD 2221420) Sundry 10-404 Fracfocus and Chemical Disclosure
Requirements
CAUTION:This email originated from outside of the organization. Do not click links or open
attachments unless you recognize the sender and know the content is safe.
Dustin,
We are reviewing the KRU 3S-704 10-404 report for the recent fracture stimulation and require
additional information.
1. The 10-404 report doesn’t seem to have a chemical disclosure showing the frac chemical CAS
numbers. The chemical disclosure generated for fracfocus is often submitted to AOGCC to
meet this regulation requirement. You can email this to me and I will attach to the 10-404.
2. It is a requirement to post the frac information and chemical disclosure on the fracfocus.org
website prior to submission of the 10-407 to AOGCC. Please complete this process so that I
can progress our review.
As per 20 AAC 25.300, CPAI is required to provide this requested information within 30 days.
Thanks and Regards,
Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue,
Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov
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 Chris Wallace at
907-793-1250 or chris.wallace@alaska.gov.
Hydraulic Fracturing Fluid Product Component Information Disclosure
Hydraulic Fracturing Fluid Composition:
Job Start Date:3/19/2023
Job End Date:3/29/2023
State:Alaska
County:Harrison Bay
API Number:50-103-20848-00-00
Operator Name:ConocoPhillips Company/Burlington
Resources
Well Name and Number:3S-704
Latitude:70.39458000
Longitude:-150.19215500
Datum:NAD27
Federal Well:NO
Indian Well:NO
True Vertical Depth:4,262
Total Base Water Volume (gal):1,565,958
Total Base Non Water Volume:78,298
Trade Name Supplier Purpose Ingredients
Chemical
Abstract
Service
Number
(CAS #)
Maximum
Ingredient
Concentration
in Additive
(% by mass)**
Maximum
Ingredient
Concentration
in HF Fluid
(% by mass)**
Comments
SEAWATER (SG
8.52)
Halliburton Base Fluid
Water 7732-18-5 100.00000 71.95248 Density = 8.52
Ingredients Listed Above Listed Above
Water 7732-18-5 100.00000 0.12507
CAT-3
ACTIVATOR
Halliburton Activator
Listed Below
LVT-200 Baker Hughes Additive
Listed Below
MO-67 Halliburton pH Control
Listed Below
BE-6(TM)
Bactericide
Halliburton Microbiocide
Listed Below
WG-36 GELLING
AGENT
Halliburton Gelling Agent
Listed Below
LoSurf-300D Halliburton Non-ionic
Surfactant
Listed Below
OPTIFLO-II
DELAYED
RELEASE
BREAKER
Halliburton Breaker
Listed Below
Sand-Common
White-100 Mesh,
SSA-2
Halliburton Proppant
Listed Below
Ceramic
Proppant - Wanli
Wanli Proppant
Listed Below
Potassium
Formate Brine
MI Swaco Completion/Stim
ulation
Listed Below
BC-140 X2 Halliburton Initiator
Listed Below
Corundum 1302-74-5 65.00000 17.64486
Mullite 1302-93-8 45.00000 12.21567
Sodium chloride 7647-14-5 5.00000 3.59801
Crystalline silica, quartz 14808-60-7 100.00000 0.35684
Guar gum 9000-30-0 100.00000 0.21224
Potassium Formate 590-29-4 100.00000 0.10694
Ethanol 64-17-5 60.00000 0.03947
Monoethanolamine
borate
26038-87-9 100.00000 0.03616
EDTA/Copper chelate Proprietary 30.00000 0.02261
Oxyalkylated nonyl
phenolic resin
Proprietary 30.00000 0.01973
Heavy aromatic
petroleum naphtha
64742-94-5 30.00000 0.01973
Sodium hydroxide 1310-73-2 30.00000 0.01165
Ethylene glycol 107-21-1 30.00000 0.01085
Ammonium persulfate 7727-54-0 100.00000 0.00904
Oxyalkylated phenolic
resin
Proprietary 10.00000 0.00658
Ammonium chloride 12125-02-9 5.00000 0.00377
Items above are Trade Names with the exception of Base Water . Items below are the individual ingredients.
* Total Water Volume sources may include various types of water including fresh water, produced water, and recycled water
** Information is based on the maximum potential for concentration and thus the total may be over 100%
*** If you are calculating a percentage of total ingredients do not add the water volume below the green line to the water volume above the green line
Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided.
Ingredient information for chemicals subject to 29 CFR 1910.1200(i) and Appendix D are obtained from suppliers Material Safety Data Sheets (MSDS)
Poly(oxy-1,2-ethanediyl),
alpha-(4-nonylphenyl)-
omega-hydroxy-,
branched
127087-87-0 5.00000 0.00329
Naphthalene 91-20-3 5.00000 0.00329
Oxylated phenolic resin Proprietary 30.00000 0.00271
2-Bromo-2-nitro-1,3-
propanediol
52-51-7 100.00000 0.00127
Ammonia 7664-41-7 1.00000 0.00075
1,2,4 Trimethylbenzene 95-63-6 1.00000 0.00066
C.I. pigment Orange 5 3468-63-1 1.00000 0.00009
2,7-
Naphthalenedisulfonic
acid, 3-hydroxy-4-[(4-
sulfor-1-naphthalenyl)
azo] -, trisodium salt
915-67-3 0.10000 0.00004
Distillates (petroleum),
hydrotreated light
64742-47-8 100.00000
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: 93' FSL, 80' FEL S13 T12N R7E 9. Ref Elevations: KB: 17. Field / Pool(s):
GL: 24.9 BF:
Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation:
4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number:
Surface: x- y- Zone- 4
TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD:
Total Depth: x- y- Zone- 4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 N/A (ft MSL)
22. Logs Obtained:
23.
BOTTOM
20" L-80 115'10 yards
10.75" L-80 2572'
7.625" L-80 4131'
4 1/2" P-110 4261'
24. Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr):
Press. 24-Hour Rate
Sr Pet Geo
13.5" Lead:569bbl of 10.7ppg Class G
Tail: 52bbl of 15.8ppg Class G
SETTING DEPTH TVD
40'
40'
3293'
115'
7316'
Sr Pet Eng
228bbls of 15.3ppg Class G16370'
63bbls of 15.3ppg Class G
4109'
9.875"
6.5"
7147'4.5 6965'MD/4083'TVD
7140'MD/4109'TVD
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
7140'
PACKER SET (MD/TVD)
TUBING RECORD
SIZE DEPTH SET (MD)
Sr Res Eng
Oil-Bbl: Water-Bbl:
Water-Bbl:
PRODUCTION TEST
N/A
Date of Test: Oil-Bbl:
Flow Tubing
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and
Number; Date perf'd or liner run):
Liner: 7140'MD/4109' TVD - 16370'MD/4261' TVD
Gas-Oil Ratio:Choke Size:
suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud
log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing
collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary.
N/A
40'
40'
Per 20 AAC 25.283 (i)(2) attach electronic information
29.7 40'
94
45.5
42"
12.6
CASING
40'
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date perf'd or liner run):
WT. PER
FT.GRADE
5981987
TOP HOLE SIZE AMOUNT
PULLEDTOP
SETTING DEPTH MD
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,
BOTTOM
472364
473504
CEMENTING RECORD
5991242
1861'MD/1766'TVDN/A
GR, RES, DEN, GWD, DIR, AZI, PWD, SONIC, CALIPER, NEU, USIT, CBL
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
ConocoPhillips Alaska, Inc.
WAG
Gas
3/8/2023 222-142
50-103-20848-00-00
KRU 3S-704
2/8/2023
16372'MD/4261'TVD
N/A
61.5
P.O.Box 100360, Anchorage, AK 99510-0360
476383
2807' FSL, 877' FEL S18 T12N R8E
1401' FSL, 3762' FEL S30 T12N R8E
3/1/2023
5993942
Kuparuk River Field/ Exploratory Oil Pool
ADL380107, ADL025544, ADL392374
LONS 01-013
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
By James Brooks at 9:53 am, Apr 06, 2023
Completed
3/8/2023
JSB
RBDMS JSB 041123
AOGCC
DSR=10/25/23 G
, Mudlog
SFD 3/25/2025VTL 3/25/2025
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
Surface Surface
1861 1761
Top West Sak 2211 2023
3002 2460
3498 2670
C-50 5253 3408
7026 4082
16372 4261
31. List of Attachments:
Directional Survey, Well Schematic, Cement Operations, Operations Summary
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Matt Smith
Digital Signature with Date:
Contact Phone:907-263-4324
General:
Item 1a:
Item 1b:
Item 4b:
Item 9:
Item 15:
Item 19:
Item 20:
Item 22:
Item 23:
Item 24:
Item 27:
Item 28:
Item 30:
Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment; or 90 days after log acquisition, whichever occurs first.
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Base West Sak
Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic
diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from
a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071.
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core
analysis, paleontological report, production or well test results, per 20 AAC 25.070.
Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
TPI (Top of Producing Interval).
Authorized Name and
INSTRUCTIONS
Contact Email: matt.smith@conocophillips.com
Authorized Title: Drilling Engineer
Campanian/Seabee
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.
Formation Name at TD:
Nanushuk
Yes No
Well tested? Yes No
28. CORE DATA
If Yes, list intervals and formations tested, briefly summarizing test results for
each. Attach separate pages if needed and submit detailed test info including
reports and Excel or ASCII tables per 20 AAC 25.071.
NAME
Permafrost - Top
Permafrost - Base
29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS
Top of Productive Interval:
Coyote/Nanushuk
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
Digitally signed by Matt Smith
DN: CN=Matt Smith, E=matt.smith2@
conocophillips.com
Reason: I am the author of this document
Location:
Date: 2023.04.05 13:02:53-08'00'
Foxit PDF Editor Version: 12.0.1
3S-704 Wellbore Schematic
Horizontal Coyote Producer
Surface Casing: 10-¾" 45.5#, L-80, Hydril 563 @
3,292’ MD / 2,571' TVD, 61° Inc
Conductor: 20" driven to +/-94' GL / 130' RKB
Production Liner: 4-½" 12.6#, TN-110S, Hydril 563
@ 16,370' MD / 4,261' TVD, 90° Inc
Tubing: 4-½”12.6#, L-80, Hydril 5639-и" Intermediate Hole
6-1/2" Production Hole
KL
A
-
S
H
I
E
L
D
W
B
M
13-½" Surface Hole
Intermediate Casing:
7-з" 29.7#, L80, Hydril 563 +
800' 39#, TN110S, Hyd563
Heavy Heel set @
7,316' MD / 4,131' TVD, 83° Inc
Updated: 03/16/23
by R. Ciolkosz
AUS Frac sleeves
LS
N
D
Sp
u
d
M
u
d
3.813", X Nipple
FlexLock/ZXP, Liner Hanger @ 7,139' MD / 4,108' TVD
4-½” x 7-з " TNT Packer
Est. TOC @ 6,000’ MD / 3,750’ TVD
HES OPSIS Gauge Mandrel
Gas Lift Mandrel, 4-½” x 1”
Gas Lift Mandrel, 4-½” x 1”
Alpha Sleeves
Top Coyote @ 7,023’ MD / 4,092’ TVD
3.813", X Nipple
Planned TOC @ liner top
Page 1/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/5/2023
03:00
2/5/2023
12:00
9.00 MIRU, MOVE MOB P Prep rig for move from 3S-701 to 3S-
704
Warm up rig moving systems
Blow down steam and water lines. start
to prep pad for rig move
Move rockwasher , move MPD unit
away from sub base , prep pipe shed
and pits/motors to pull away from sub
base
0.0 0.0
2/5/2023
12:00
2/6/2023
00:00
12.00 MIRU, MOVE MOB P Pull pipe shed away from sub base ,
clear excess snow away from around
sub base , move pits and motors back
away from sub base , clear excess snow
around 3S-704 , lay rig mats in front of
sub base , skid rig floor back into move
position
Pull sub base off of 3S-701 , spot
equipment in 3S-704 cellar , crab sub
base to spot postion , ready sub to spot
over 3S-704
Working under cold/foul weather
requirements
0.0 0.0
2/6/2023
00:00
2/6/2023
03:30
3.50 MIRU, MOVE MOB P Spot , level and shim sub base over 3S-
704 , lower stompers and set
pressures , lower cellar windwalls
Lay out rig mats for pipe shed
Working under cold/foul weather
requirements
0.0 0.0
2/6/2023
03:30
2/6/2023
06:30
3.00 MIRU, MOVE MOB P Skid rig floor into drilling position , spot
pits and motors to sub base , lay out rig
mats for pipe shed , spot MPD choke
manifold house
Hook up steam and fuel to sub
Working under cold/foul weather
requirements
0.0 0.0
2/6/2023
06:30
2/6/2023
12:00
5.50 MIRU, MOVE MOB P Lay out herculite and plywood for
rockwasher and spot same , hook up
service lines from pits to sub base ,
remove rig mats and herculite from 3S-
701 cellar
Work on rig acceptance checklist
0.0 0.0
2/6/2023
12:00
2/6/2023
20:00
8.00 MIRU, MOVE MOB P Spot pipe shed , spot pipe shed heater ,
berm around rig , work on rig
acceptance checklist , rig up service
lines to rig floor , work on getting heat to
cellar and rig floor and chinking wind
walls
Do walk around rig for rig acceptance
checklist to insure its complete
Rig accepted at 20:00 HRS
0.0 0.0
2/6/2023
20:00
2/6/2023
22:00
2.00 MIRU, MOVE MOB P Change out saver sub to 4 1/2" IF ,
move BHA to short side of pipe shed ,
verify lines and valves are ready to bring
on mud , prep cellar for N/U diverter
adaptor and riser , continue working on
getting steam to cellar and rig floor
changing out compromised fittings as
needed , bring on spud mud to pits ,
spot MWD shack , spot pre tour meeting
room
0.0 0.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 2/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/6/2023
22:00
2/7/2023
00:00
2.00 MIRU, MOVE MOB P Obtain RKB's , prep conductor for
diverter adaptor , make up diverter
adaptor to conductor
0.0 0.0
2/7/2023
00:00
2/7/2023
06:00
6.00 MIRU, MOVE NUND P Install diverter adaptor on conductor test
seals to 200 PSI for 10 min , install 4"
valves on conductor , install 2" 1502
valves on diverter adaptor , install flow
line , nipple up surface riser , have to
modify 2" bleeder nipple on riser
Load 5" DP and 5" HWDP in pipe shed
and continue working on steam to cellar
and rig floor , work on water transfer
pumps in motor room , bring on spud
mud , stock warm up shacks with drum
products
0.0 0.0
2/7/2023
06:00
2/7/2023
10:00
4.00 MIRU, MOVE NUND P Continue to modify 2" bleeder nipple on
surface riser , nipple up surface riser ,
hook up hole fill line , install flow line ,
hook up drain lines , turnbuckles
Install 2" drain lines on diverter adaptor
Load 5" HWDP into pipe shed , strap
and tally all 5"
Work on getting steam to cellar and
water transfer pumps in motor room
Prep pits for surface , dress shakers
0.0 0.0
2/7/2023
10:00
2/7/2023
12:00
2.00 MIRU, MOVE RURD P Install mouse hole , prep mud pumps for
drilling , mobilize BHA components to rig
floor , put 5" DP Elev on top drive
Cont working on steam lines around rig
0.0 0.0
2/7/2023
12:00
2/7/2023
20:00
8.00 MIRU, MOVE RURD P Cont to ready shed for picking up BHA
and BHA components for picking up ,
prep pipe shed for picking up 5" DP
Pick up stand back 28 STDS 5" DP -
drifted 2.87" off skate
Pick up stand back 6 STDS 5" HWDP -
drifted 2.57" off skate
Cont working on steam lines around rig
0.0 0.0
2/7/2023
20:00
2/7/2023
21:30
1.50 MIRU, MOVE RURD P Finish pre spud checklist - blow air from
top drive to mud pumps , check cellar
pump function (frozen up) spot super
sucker by cellar , check flow paddle ,
verify ground wires hooked up , verify
saftey equipment in place and functional
0.0 0.0
2/7/2023
21:30
2/7/2023
22:15
0.75 MIRU, MOVE SFTY P Pre spud meeting with all hands
PJSM M/U BHA #1 and clean out
conductor
0.0 0.0
2/7/2023
22:15
2/7/2023
23:30
1.25 SURFAC, DRILL BHAH P M/U BHA # 1 T/42'
Kelly up on a stand of HWDP slack off
and tag up at 63'
0.0 63.0
2/7/2023
23:30
2/7/2023
23:45
0.25 SURFAC, DRILL CIRC P Fill mud line and riser up with 8.8 PPG
spud mud check for leaks
Pressure test mud line to 4000 PSI
63.0 63.0
2/7/2023
23:45
2/8/2023
00:00
0.25 SURFAC, DRILL REAM P Clean out conductor F/63' T/117'
400 GPM 290 PSI
30 RPM 1.5K TQ
63.0 117.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 3/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/8/2023
00:00
2/8/2023
00:45
0.75 SURFAC, DRILL DDRL P Drill 13-1/2" directional surface hole
F/117' to 200'.
Spud well @ 00:00 hrs 2-8-23
400 GPM
400 PSI
30 RPM
2K TQ
3-8K WOB
75K P/U
75K S/O
75K ROT
ADT = .68
Bit HRS = .68
117.0 200.0
2/8/2023
00:45
2/8/2023
01:30
0.75 SURFAC, DRILL PMPO P Pump out F/200' T/38'
2 BPM 100 PSI
Blow down top drive
200.0 38.0
2/8/2023
01:30
2/8/2023
04:00
2.50 SURFAC, DRILL BHAH P Make up BHA #2 as per SLBG DD F/38'
T/188'
38.0 188.0
2/8/2023
04:00
2/8/2023
04:15
0.25 SURFAC, DRILL REAM P Break circulation , test MWD and GWD
tools
400 GPM 630 PSI
Precautionary wash and ream F/188'
T/200'
400 GPM 30 RPM
188.0 200.0
2/8/2023
04:15
2/8/2023
06:00
1.75 SURFAC, DRILL DDRL P Drill 13-1/2" directional surface hole
F/200' T/369'
450 GPM
910 PSI
50 RPM
2K TQ
5K WOB
85K P/U
85K S/O
85K ROT
ADT = 2.27
Bit HRS = 2.95
Jar HRS = 2.27
200.0 369.0
2/8/2023
06:00
2/8/2023
12:00
6.00 SURFAC, DRILL DDRL P Drill 13-1/2" directional surface hole
F/369' T/832'
450 GPM
950 PSI
50 RPM
6K TQ
6K WOB
105K UP
99K DN
102K ROT
ADT = 2.93
Bit HRS = 5.88
Jar HRS = 5.20
369.0 832.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 4/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/8/2023
12:00
2/8/2023
17:00
5.00 SURFAC, DRILL DDRL P Drill 13-1/2" directional surface hole
F/832' T/1,280'
450 GPM
1080 PSI
50 RPM
6K TQ
6-18K WOB
112K UP
112K DN
116K ROT
ECD = 10.48
ADT = 2.81
AST = 1.85
ART = .96
Bit HRS = 8.69
Jar HRS = 8.01
832.0 1,280.0
2/8/2023
17:00
2/8/2023
17:30
0.50 SURFAC, DRILL SVRG P Service rig while repair rod wash pump
on # 2 MP
1,280.0 1,280.0
2/8/2023
17:30
2/9/2023
00:00
6.50 SURFAC, DRILL DDRL P Drill 13-1/2" directional surface hole
F/1,280' T/1,880'
450 GPM
1020 PSI
50 RPM
6K TQ
6-18K WOB
119K UP
116K DN
119K ROT
ECD = 10.51
ADT = 3.95
AST = 2.89
ART = 1.06
Bit HRS = 12.64
Jar HRS = 11.96
1,280.0 1,880.0
2/9/2023
00:00
2/9/2023
12:00
12.00 SURFAC, DRILL DDRL P Drill 13-1/2" directional surface hole
F/1,880' T/3,031'
675 GPM
2230 PSI
80 RPM
8K TQ
10-20K WOB
130K UP
113K DN
116K ROT
ECD = 11.26
ADT = 7.02
AST = 4.04
ART = 2.98
Bit HRS = 19.66
Jar HRS = 18.98
1,880.0 3,031.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 5/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/9/2023
12:00
2/9/2023
12:15
0.25 SURFAC, DRILL DDRL P Drill 13-1/2" directional surface hole
F/3,031'' T/3,100'
675 GPM
2280 PSI
80 RPM
8K TQ
10-20K WOB
130K UP
113K DN
116K ROT
ECD = 11.26
3,031.0 3,100.0
2/9/2023
12:15
2/9/2023
12:45
0.50 SURFAC, DRILL CIRC T Hole unload and flow line and possum
belly packed off , shut down pumps
clean out flow line and possum belly ,
stage pumps and rotory up to 675 GPM
and 80 RPM
675 GPM 2110 PSI
80 RPM 7K TQ
3,100.0 3,100.0
2/9/2023
12:45
2/9/2023
13:00
0.25 SURFAC, DRILL SVRG P Service rig - drawworks and top drive ,
while inspecting #2 MP suction valve
and seat
3,100.0 3,100.0
2/9/2023
13:00
2/9/2023
15:45
2.75 SURFAC, DRILL DDRL P Drill 13-1/2" directional surface hole
F/3,100' T/3,303'
675 GPM
2220 PSI
80 RPM
8K TQ
10-20K WOB
130K UP
120K DN
126K ROT
ECD = 11.22
ADT = 1.78
AST = .6
ART = 1.18
Bit HRS = 21.44
Jar HRS = 20.76
3,100.0 3,303.0
2/9/2023
15:45
2/9/2023
17:15
1.50 SURFAC, TRIPCAS CIRC P CBU @ 675 GPM 2230 PSI , pump 40
BBL N/P sweep , L/D single and stand
on estand back T/3,190'
3,303.0 3,190.0
2/9/2023
17:15
2/9/2023
17:45
0.50 SURFAC, TRIPCAS OWFF P Blow down top drive , flow check - static 3,190.0 3,190.0
2/9/2023
17:45
2/9/2023
23:45
6.00 SURFAC, TRIPCAS BKRM P BROOH F/3,190' T/1,870'
Pull slow circulating 1x B/U F/2,157'
T/1,870'
675 GPM 2040 PSI
80 RPM 6K TQ
118K ROT
Hole unload at 2,745'
Orientate motor hi side
3,190.0 1,870.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 6/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/9/2023
23:45
2/10/2023
00:00
0.25 SURFAC, TRIPCAS PMPO P POOH with pumps F/1,870' T/1,776'
675 GPM 1720 PSI
130K UP
Attempt to pull on elevators @ 1,870' ,
pull 25K over twice to 155K and
swabbing @ 1,850'
130K UP
1,870.0 1,776.0
2/10/2023
00:00
2/10/2023
04:30
4.50 SURFAC, TRIPCAS PMPO P POOH with pumps F/1,776' T/738'
675 GPM 1700 PSI , 550 GPM 1150
PSI
100K UP
At 1,540' hole unload , slow pumps
down , clean possum belly and stage
pumps back up to 675 GPM
At 1,260' hole unload , slow pumps
down , clean possum belly and stage
up to 550 GPM
1,776.0 738.0
2/10/2023
04:30
2/10/2023
04:45
0.25 SURFAC, TRIPCAS OWFF P Flow check - static 738.0 738.0
2/10/2023
04:45
2/10/2023
06:30
1.75 SURFAC, TRIPCAS PMPO P Pumping out of hole F/738' T/179'
600 GPM 1300 PSI
106K UP
738.0 179.0
2/10/2023
06:30
2/10/2023
07:15
0.75 SURFAC, TRIPCAS OWFF P Flow check - static 179.0 179.0
2/10/2023
07:15
2/10/2023
10:30
3.25 SURFAC, TRIPCAS BHAH P Lay down BHA #2 as per SLBG DD 179.0 0.0
2/10/2023
10:30
2/10/2023
11:45
1.25 SURFAC, TRIPCAS CLEN P Clean and clear rig floor of BHA
equipment , remove excess mud and ice
from rig floor
SimOps - clean mud pump suction
pods , clean out possum belly and flow
line in pits
0.0 0.0
2/10/2023
11:45
2/10/2023
14:30
2.75 SURFAC, CASING RURD P R/U to run 10 3/4" CSG , Volant CRT ,
side door elevator's , spider slips , make
up floor valve to cross over.
SimOps - move BHA from pipe shed ,
mix spud mud in pits , finish prep pump
room for CMT job
0.0 0.0
2/10/2023
14:30
2/10/2023
16:45
2.25 SURFAC, CASING PUTB P Run 10 3/4" CSG as per detail T/168' ,
started to take weight , washed DN
T/209' at 2.5 BPM 80 PSI , check floats
holding
Baker lok shoe track
Make up TQ 16.2K double bump each
connection
0.0 209.0
2/10/2023
16:45
2/10/2023
18:00
1.25 SURFAC, CASING PUTB P Precauionary wash DN F/209' T/411'
2 BPM 80 PSI
75K DN
Make up TQ 16.2K double bump each
connection
209.0 411.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 7/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/10/2023
18:00
2/10/2023
19:45
1.75 SURFAC, CASING PUTB P RIH with 10 3/4" CSG as per detail
F/411' T/899'
100K UP
80K DN
Hole fill off last 5 JTS from JT#15-20
Take WT at 899' set DN 20K
Make up TQ 16.2K double bump each
connection
411.0 899.0
2/10/2023
19:45
2/10/2023
20:30
0.75 SURFAC, CASING PUTB P Circulate CSG DN F/899' T/1021'
2.5 BPM 110 PSI
Make up TQ 16.2K double bump each
connection
899.0 1,021.0
2/10/2023
20:30
2/10/2023
21:30
1.00 SURFAC, CASING PUTB P RIH with 10 3/4" CSG as per detail
F/1,021' T/1,278'
120K UP
95K DN
Tag up at 1,278' set DN 30K to 65K on
the hook
Make up TQ 16.2K double bump each
connection
1,021.0 1,278.0
2/10/2023
21:30
2/10/2023
22:00
0.50 SURFAC, CASING PUTB P Attempt to wash DN at 1,278' @ 2 BPM
140 PSI , stage pumps up to 4 BPM 180
PSI
Set DN to 55K on hook = 40K DN with
no increase in pump pressure
1,278.0 1,278.0
2/10/2023
22:00
2/11/2023
00:00
2.00 SURFAC, CASING REAM T Wash and ream 10 3/4" CSG down
F/1,278' T/1,291'
4 BPM 180-200 PSI , 10 RPM 10-12K
free TQ - rotate in the hole T/1,291'
setting down 5-22K and TQ to 12-15.5K
105K Rot WT , 95K DN while slacking
off with 12K TQ
Pick up make sure can still move up @
1,273' and 1,284' was clean pick up with
no increase in pump PSI or TQ
After picking up at 1,284' pump PSI and
TQ started increasing and flow out
started bouncing around like hole was
cleaning up after getting mud vis up to
300 plus
Cont wash/ream T/1,291'
Went to pick up at 1,291' to make sure
clean pick up , picked up 10' to 1,281'
and pump PSI increase T/310 PSI and
TQ stall out at 16K and returns dropped
off. Slack off regain returns and TQ drop
off
Noticed lots of sand at the shakers on
the first B/U after getting mud vis up ,
sand at shakers diminish and get more
small pea size gravel
Pull up slowly to last clean spot at 1,275'
at 4 BPM 200-260 PSI , 10 RPM 10 -
15K TQ , get to 1,275' and pump PSI,
TQ and return flow back steady
1,278.0 1,275.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 8/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/11/2023
00:00
2/11/2023
00:45
0.75 SURFAC, CASING REAM T Wash and ream CSG F/1,275' T/1,291'
4 BPM 190 PSI , 10 RPM 10-12K TQ
100K Rot Wt
Once back down to 1,291' , pump PSI
up to 250 PSI and TQ F/10 - 12K T/13-
14K
Shakers clean up some , small pea size
gravel
Setting DN 5-20K
Make up TQ 16.2K double bump each
connection
1,275.0 1,291.0
2/11/2023
00:45
2/11/2023
05:45
5.00 SURFAC, CASING REAM T Wash and ream 10 3/4" CSG DN
F/1,291' T/1,350'
4 BPM 190 - 200 PSI with mud pump
#2 , 10 - 15 RPM 8-13K TQ
105K Rot Wt , setting down to 30K
At 1,299' try just washing DN with no
sucess at 2 - 4 BPM
95K DN - set DN to 70K on hook = 25K
DN
MP #1 - 4 BPM 160 PSI , 4.5 BPM 150
PSI
Shakers cleaned up
Make up TQ 16.2K double bump each
connection
1,291.0 1,350.0
2/11/2023
05:45
2/11/2023
09:45
4.00 SURFAC, CASING WASH P RIH with 10 3/4" CSG F/1,350' T/1,956'
Precautionary washing down @ 2 BPM
150 PSI
100K DN
Work thru tight spots at 1,400' , 1,432' ,
1,477'
Make up TQ 16.2K double bump each
connection
1,350.0 1,956.0
2/11/2023
09:45
2/11/2023
10:45
1.00 SURFAC, CASING CIRC P Circ cond mud staging pumps up to 6.5
BPM 230 PSI
145K UP
105K DN
No losses while circulating
1,956.0 1,956.0
2/11/2023
10:45
2/11/2023
20:30
9.75 SURFAC, CASING WASH P RIH with 10 3/4" CSG F/1,956' T/3,251'
Precautionary washing DN at 2 BPM
230 PSI
175K UP
120K DN
Make up TQ 16.2K double bump each
connection
1,956.0 3,251.0
2/11/2023
20:30
2/11/2023
20:45
0.25 SURFAC, CASING OTHR P Pick up StreamFlo hanger and landing
JT , install 2 shear pins in running tool ,
make up hanger to string , pull spider
slips out of rotary table
3,251.0 3,251.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 9/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/11/2023
20:45
2/11/2023
21:30
0.75 SURFAC, CASING WASH P Wash DN F/3,251' T/3,292' at 2 BPM
230 PSI
Land out on landing ring @ 3,292 shoe
depth
120K DN
Go to pick up to work casing and pull 15
- 20K over after .34' of free travel at
175K up and .97' up from fully landed ,
attempt to pull string over with tugger
and try again still pull over to 190K ,
decide to leave CSG landed out and try
picking up again after circ some at 6
BPM
3,251.0 3,251.0
2/11/2023
21:30
2/12/2023
00:00
2.50 SURFAC, CEMENT CIRC P Circulate and condition mud for CMT job
stage pumps up to 6 BPM
2 BPM 230 PSI
6 BPM 300 PSI ICP
6 BPM 170 PSI FCP
Stage trucks for CMT job , prep shed to
load DP , prep pits, rockwasher and
cellar for CMT job , blow air thru cement
line to cementing unit , blow ait thru
black water line to cellar from mud
pumps
At 23:00 HRS try to work pipe up ,
pulled to 200K on the hook = 25K over
last known up weight.
3,251.0 3,251.0
2/12/2023
00:00
2/12/2023
01:15
1.25 SURFAC, CEMENT CIRC P Circulate and condition mud for CMT job
stage @ 6 BPM
MD WT 9.8 PPG in/out , Vis 91 in 91 out
YP at 24
6 BPM 170 PSI FCP
Stage trucks for CMT job , prep mud
pits, rockwasher and cellar for CMT job
3,251.0 3,251.0
2/12/2023
01:15
2/12/2023
01:30
0.25 SURFAC, CEMENT RURD P Blow down top drive , rig up CMT hose
and chart recorder
3,251.0 3,251.0
2/12/2023
01:30
2/12/2023
02:00
0.50 SURFAC, CEMENT CIRC P Break circ thru cement hose stage up to
6 BPM
6 BPM 330 PSI
3,251.0 3,251.0
2/12/2023
02:00
2/12/2023
02:30
0.50 SURFAC, CEMENT SFTY P PJSM with all hands on performing CMT
job
Circulate at 6 BPM during PJSM
3,251.0 3,251.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 10/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/12/2023
02:30
2/12/2023
09:00
6.50 SURFAC, CEMENT CMNT P HES flood lines in CMT unit , break circ
with 5 BBLS H2O , check pump trips ,
test lines to 3500 PSI
Perform surface cement job as per HES.
Pump 62.4 BBLS 10.2 PPG tuned prime
spacer with Pol-E-Flake and 4# red dye
@ 3.7 BPM
Drop bottom wiper plug and follow with
568 PPG Arctic Cem Lead Cement
W/2.5 LBS/SK bridgemaker, pump at
average 3.1 BPM.
Leave hanger landed during CMT job.
Follow with 52.2 BBLS 15.8 PPG tail
cement with 5 LBS/SK bridgemaker at
1.4 BPM average
Drop top wiper plug and chase with 20
BBLS H2O @ 4.7 BPM fresh water from
HES cement unit.
Displace 285 BBLS 9.8 PPG Spud mud
with rig pumps ICP at 4 BPM 483 PSI,
at 278 BBLS pumped reduce rate to 3
BPM 850 PSI FCP.
Bump plug at 2830 STKS and build
pressure to 1340 PSI and held for 5
minutes. Bleed pressure off and check
floats, floats holding.
Note: At 05:56 HRS lost returns 450
BBLS into lead , pumped 118 BBLS
more lead CMT , lost 52.2 BBLS tail
CMT , 20 BBLS H20 , 285 BBLS mud
for a total of 475.2 BBLS lost durning
cement job. At 6:15 AM 3S-701 OA =
200 PSI , at 11:30 OA = 198 PSI
CIP @ 08:56 hrs.
3,251.0 3,251.0
2/12/2023
09:00
2/12/2023
13:00
4.00 SURFAC, CEMENT RURD P Rig down CMT equipment , volant and
hoses , L/D landing JT , L/D casing
running equipment from floor
3,251.0 0.0
2/12/2023
13:00
2/12/2023
18:00
5.00 SURFAC, CEMENT BHAH T Prep pipe shed and bring bit and bit sub
to rig floor
Make up 9 7/8" bit and bit sub , RIH
T/1,911' singling in from pipe shed
98K DN
0.0 1,911.0
2/12/2023
18:00
2/12/2023
23:15
5.25 SURFAC, CEMENT CIRC T Circ cond mud and warm up 13 1/2" x
10 3/4" annulus
Circ at 800 GPM 910 PSI , 600 GPM
790 PSI
Flow line temp at start = 56°
Flow line temp at end = 76°
1,911.0 1,911.0
2/12/2023
23:15
2/13/2023
00:00
0.75 SURFAC, CEMENT TRIP T Blow down top drive
POOH F/1,911' T/962'
95K UP
95K DN
1,911.0 962.0
2/13/2023
00:00
2/13/2023
01:00
1.00 SURFAC, CEMENT TRIP T POOH F/962' to surface 962.0 0.0
2/13/2023
01:00
2/13/2023
02:30
1.50 SURFAC, CEMENT RURD T Clean rig floor , spot Eline unit , mobilize
SLBG eline tools and equipment to floor
and pipe shed
0.0 0.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 11/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/13/2023
02:30
2/13/2023
04:00
1.50 SURFAC, CEMENT ELNE T Make up USIT and CBL logging tools
T/54'
Test USRS at surface
0.0 0.0
2/13/2023
04:00
2/13/2023
08:15
4.25 SURFAC, CEMENT ELNE T RIH W/USIT and CBL on eline F/54'
T/2,635'
RIH to 500' , POOH to change flex point
for better data imaging
0.0 0.0
2/13/2023
08:15
2/13/2023
09:00
0.75 SURFAC, CEMENT ELNE T Rig down Eline tools , clear floor 0.0 0.0
2/13/2023
09:00
2/13/2023
17:15
8.25 SURFAC, CEMENT WAIT T Service rig while waiting on path forward
Slip-n-cut 75' drilling line , grease top
drive , drawworks , work on steam
system , service pits and rockwasher
drag chains , clean pits 1-2 and 6 ,
grease choke manifold and low TQ
valves on mud and CMT manifolds ,
prep top job pipe and fittings , grease
wash pipe and IBOP's , house keeping
0.0 0.0
2/13/2023
17:15
2/13/2023
23:00
5.75 SURFAC, CEMENT CIRC T RIH with 9 7/8" bit T/1,911'
Circ at 750 GPM 850 PSI to keep
annulus warm
Flow line temp at start = 58°
Flow line temp at end = 72°
Work on steam system , C/O DS tugger
cable , prep tools for top job ,
houskeeping , start on BWM
0.0 1,911.0
2/13/2023
23:00
2/14/2023
00:00
1.00 SURFAC, CEMENT TRIP T Blow down top drive and mud line
POOH F/1,911' T/938'
90K UP
1,911.0 938.0
2/14/2023
00:00
2/14/2023
01:00
1.00 SURFAC, CEMENT TRIP T POOH F/938' to surface , L/D 9 7/8" bit
SimOps - work on BWM
938.0 0.0
2/14/2023
01:00
2/14/2023
06:00
5.00 SURFAC, CEMENT NUND P PJSM - Blow down hole fill and bleeder
line , drain surface riser , remove flow
line and hoses , L/D mouse hole
N/D surface riser and StreamFlo diverter
adaptor
SimOps - Work on BWM , prep pits for
CMT pills for trucks
0.0 0.0
2/14/2023
06:00
2/14/2023
09:00
3.00 SURFAC, CEMENT RURD T Clean cellar area , prep for top job
SimOps - make up 10 JTS 3/4" steel
pipe in pipe shed for top job
0.0 0.0
2/14/2023
09:00
2/14/2023
12:00
3.00 SURFAC, CEMENT TRIP T Make up 3/4" top job pipe RIH T/121' ,
attempt to work past end of conductor at
117' , rig up to wash down with water
from cement unit
0.0 121.0
2/14/2023
12:00
2/14/2023
15:45
3.75 SURFAC, CEMENT TRIP T POOH with 3/4" top job string , plugged
off string while trying to work down , RIH
to 121' attempt to wash thru with H2O -
unsuccessful , Rig up CMT unit to
string , at 116' attempt to circ thru string
plugged off PSI up to 590 , pull out of
hole flush joints with water confirn it was
the string that was plugged removed
blockage in muleshoe , wash down to
121' with no issues
0.0 121.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 12/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/14/2023
15:45
2/15/2023
00:00
8.25 SURFAC, CEMENT WASH T Wash down top job pipe at 1/2 - 3/4
BPM while rotating pipe with pipe
wrench's 3 - 10 RPM
F/121' T/285' , work pipe down as able
to adjusting RPM's and letting PSI
stabilize as needed
At 63 BBLS water pumped started
adding SAPP at 2 sacks per 10 BBLS to
aid in washing clay's trying to keep from
pressuring up pump PSI
1/2 BPM 72 PSI
3/4 BPM 150 PSI @ 121' , 275 PSI @
240' , 300 PSI @ 285'
AOGCC Adam Earl witness
121.0 285.0
2/15/2023
00:00
2/15/2023
01:45
1.75 SURFAC, CEMENT WASH T Wash down top job pipe at 3/4 BPM
while rotating pipe with pipe wrench's 8 -
20 RPM
F/285' T/316' , work pipe down as able
to adjusting RPM's and letting PSI
stabilize as needed
At 290 BBLS water pumped stop adding
SAPP
300 PSI @ 285' , 380 PSI at 303'
AOGCC Adam Earl witness
285.0 316.0
2/15/2023
01:45
2/15/2023
02:30
0.75 SURFAC, CEMENT WASH T At 316' TQ got high on pipe and felt like
it was metal on metal grinding , pick up
was tight.
Picked up 3' to 313' , slack off while
pumping 3/4 - 1 BPM 320/530 PSI and
rotating pipe with pipe wrench's.
316.0 315.0
2/15/2023
02:30
2/15/2023
06:30
4.00 SURFAC, CEMENT CIRC T After several unsuccessful attempts to
go deeper than 315' , confer with town
about pumping cement
SimOps - shut down pumping with
cement unit , blow line down , and install
a 2" valve on hose for R/D of cement
job , break circ again at 1/4 BPM after
valve in line , PSI up to 230 before
getting returns and dropping down to
110 PSI
315.0 315.0
2/15/2023
06:30
2/15/2023
09:45
3.25 SURFAC, CEMENT CMNT T Pump 35 BBLS 10.7 PPG lead CMT at
28.9 BBLS had CMT to cellar at .75
BPM 350 PSI , POOH F/315' T/119' ,
pump 32.5 BBLS 10.7 PPG cement at .5
BPM 172 PSI CMT returns to cellar ,
POOH to hanger RIH T/119' @ 180° on
hanger flutes pump 30 BBLS 10.7 PPG
CMT at .87 BPM 196 PSI CMT returns
to cellar , POOH
Total CMT pump = 100 BBLS with 68.6
BBLS to surface
AOGCC Adam Earl witness
315.0 0.0
2/15/2023
09:45
2/15/2023
12:00
2.25 SURFAC, CEMENT RURD T Blow down and rig down lines from
cement job , clean cellar area , clean rig
floor in prep to install well head
0.0 0.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 13/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/15/2023
12:00
2/15/2023
12:45
0.75 SURFAC, WHDBOP NUND P Prep StreamFlo hanger neck and tools
for N/U well head
SimOps - clean cement valves , pill pits
1 and 2
0.0 0.0
2/15/2023
12:45
2/15/2023
17:30
4.75 SURFAC, WHDBOP NUND P Confirm well head orientation with
production operator for nipple up to
surface hanger , N/U well head test
seals to 5000 PSI F/10 min , obtain
RKB's (33.25' RKB to top of well head ,
35.56' to lower load shoulder , 34.29' to
upper load shoulder) , N/U BOP's and
MPD equipment
SimOps - mobilize StreamFlo equipment
to rig floor W/R , test plug and
setting/retriving tools , mobilize BHA to
floor , measure trip nipple length
0.0 0.0
2/15/2023
17:30
2/15/2023
20:30
3.00 SURFAC, WHDBOP OTHR P Perform between well maintenance ,
clean door sealing areas and tighten up
bolts , remove upper 3 1/2" x 6" rams to
replace sealing elements
0.0 0.0
2/15/2023
20:30
2/16/2023
00:00
3.50 SURFAC, WHDBOP NUND P Continue N/U BOP's and MPD
equipment , flow box , bleeder, hole fill ,
and mud bucket lines
MPD Orbit valve , 4" MPD lines , 2"
MPD mainifold , lower casing valve OA
sensor , stack drain , upper casing valve
mainfold and IA sensor
SimOps , modifiy trip nipple , put new
rubber elements in 3 1/2" x 6" rams
0.0 0.0
2/16/2023
00:00
2/16/2023
03:00
3.00 SURFAC, WHDBOP NUND P Finish hooking up MPD equipment ,
hook up choke/kill lines , finish putting 2"
1502 equipment on annulus valves ,
install mouse hole , secure cellar area
Finish BWM , open upper ram door's
and install upper 3 1/2" x 6" VBR
0.0 0.0
2/16/2023
03:00
2/16/2023
04:15
1.25 SURFAC, WHDBOP RURD P Pick up 5" test JT add a pup JT to top
for RKB , install test plug , lay down test
JT
0.0 0.0
2/16/2023
04:15
2/16/2023
06:15
2.00 SURFAC, WHDBOP MPDA P Fill stack with water , install MPD test
cap , test RCD head and 2" manifold to
250/1250 PSI F5 min each , pull RCD
test cap
0.0 0.0
2/16/2023
06:15
2/16/2023
09:00
2.75 SURFAC, WHDBOP RURD P Install MPD trip nipple and drip pan ,
R/U to test BOP , install 5" test JT
0.0 0.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 14/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/16/2023
09:00
2/16/2023
13:15
4.25 SURFAC, WHDBOP BOPE P Make up FOSV to dart valve , make up
test sub to top drive , fill stack and lines
with water , purge air from system ,
perform shell test
All test with 5" test joint to 250 PSI low
4,000 PSI for 5 minutes each test
charted. Test annular preventer with 5"
test joint to 250 psi low and 2,500 psi
high for 5 minutes each.
Test 4" Demco kill , choke valves 1 to
14 , 3.5" x 6" VBR top and bottom
rams , blind rams , auto/manual IBOP ,
HCR kill/choke valve , manual kill/choke
valve , Dart valve , FOSV. Test remote
and hydraulic chokes to 1,500 psi and
observed pressure drop when opening.
Accumulator drawdown:
ISP = 2900 PSI
PSI after functioning = 1475 PSI
200 psi rec = 31 seconds
Full system recovery = 151 seconds
4 bottles back up average = 2200 PSI
Bottle pre-charge average = 1000 PSI
Closing times: Annular = 25 seconds,
UPR = 7 seconds, Blind rams = 14
seconds, LPR = 7 seconds, Choke HCR
= 1 seconds, Kill HCR = 1 seconds
Test all gas alarms, PVT gain/loss, Flow
paddle
Witness waived by AOGCC Rep Kam
StJohn 2-15-23 @ 12:46 HRS
0.0 0.0
2/16/2023
13:15
2/16/2023
15:15
2.00 SURFAC, WHDBOP RURD P Rig down BOP testing equipment , pull
test plug and set W/R as per StreamFlo
rep. L/D test JT
W/R ID = 10"
Blow down lines
Note: When trying to set W/R the dogs
on running tool would not disengage
from W/R pulled to floor noticed spring
latch held out past latch ramp on R/T
engage latch ramp try setting W/R
again , pull W/R to floor and change out
running tool , set W/R as per StreamFlo
0.0 0.0
2/16/2023
15:15
2/16/2023
19:00
3.75 SURFAC, DRILLOUT BHAH P PJSM , M/U 9 7/8" BHA , make up bit
and Exceed tool gauge the stabs on the
Exceed showed top stab was 9 5/8" OD
not 9 3/4" OD , break off bit , L/D
primary Exceed and pick up back up
Exceed
Cont make up BHA T/793'
0.0 793.0
2/16/2023
19:00
2/16/2023
20:45
1.75 SURFAC, DRILLOUT TRIP P RIH with 5" DP F/793' T/2,969' 793.0 2,969.0
2/16/2023
20:45
2/16/2023
21:45
1.00 SURFAC, DRILLOUT DHEQ P Shallow test MWD tools
460 GPM 850 PSI
500 GPM 1070 PSI
2,969.0 2,969.0
2/16/2023
21:45
2/16/2023
23:00
1.25 SURFAC, DRILLOUT PRTS P Blow down top drive , R/U for CSG test
Pressure test 10 3/4” CSG T/3000 PSI
for 30 MIN W/9.8 PPG mud , charted
Pump total 45 STKS , 4.5 BBLS
PSI loss over 30 Min = 10 PSI , casing
held 99.7%
Total bled back = 4.5 BBLS
R/D and B/D lines and test equipment
2,969.0 2,969.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 15/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/16/2023
23:00
2/17/2023
00:00
1.00 SURFAC, DRILLOUT WASH P RIH F/2,969' T/3,066'
Wash DN F/3,066' T/3,193'
400 GPM 700 PSI
140K UP
107K DN
Tag up with 10K DN at 3,193'
2,969.0 3,193.0
2/17/2023
00:00
2/17/2023
03:45
3.75 SURFAC, DRILLOUT REAM P Wash/Ream cement F/3,193' T/3,203'
Drill out shoe track F/3,203' T/3,292'
Drill up plugs and float collar @ 400
GPM 720 PSI , 40-50 RPM 7-8K TQ , 5
-20K WOB
Drill up shoe @ 400 GPM 730 PSI , 80-
100 RPM 7-9K TQ , 1-5K WOB
Drill last 1-1 1/2' of shoe at 2 FPH
Clean out rat hole F/3,292' T/3,303'
3,193.0 3,303.0
2/17/2023
03:45
2/17/2023
04:00
0.25 SURFAC, DRILLOUT DDRL P Drill 20' new hole F/3,302' T/3,323'
500 GPM
1000 PSI
80 RPM
5-9K TQ on 5-7K off
3-5K WOB
P/U - 140K
S/O - 108K
ROT- 125K
ADT= .18
Bit HRS= .18
Jar HRS = 20.94
3,303.0 3,323.0
2/17/2023
04:00
2/17/2023
05:00
1.00 SURFAC, DRILLOUT CIRC P Circ condition mud for FIT
480 GPM 975 PSI
80 RPM 9K
140K UP
Work thru the shoe 3 times with no
issues with rotary and once with no
rotary
3,323.0 3,255.0
2/17/2023
05:00
2/17/2023
05:30
0.50 SURFAC, DRILLOUT OWFF P Flow check - blow down top drive 3,255.0 3,255.0
2/17/2023
05:30
2/17/2023
06:30
1.00 SURFAC, DRILLOUT FIT P Rig up for FIT
Perform FIT to 1004 PSI
LOT observed at 588 PSI 14.0 PPG
EMW with 9.6 PPG mud
Pump 2.8 BBLS , bleed back 1.3 BBLS
10 3/4" shoe at 3,292' MD 2,569' TVD
Flow check , rig down test equipment ,
blow down lines
3,255.0 3,255.0
2/17/2023
06:30
2/17/2023
07:30
1.00 SURFAC, DRILLOUT DHEQ P Pump up survey to retrive LOT test data
600 GPM 1350 PSI
3,255.0 3,255.0
2/17/2023
07:30
2/17/2023
08:30
1.00 INTRM1, DRILL DISP P Displace T/9.0 PPG LSND mud
Pump 50 BBLS 9.5 PPG Hi-Vis spacer ,
Followed by 9.0 PPG LSND mud
400/650 GPM 600/900 PSI
20 RPM 8K TQ
126K UP
120K DN
122K ROT
3,255.0 3,323.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 16/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/17/2023
08:30
2/17/2023
12:00
3.50 INTRM1, DRILL DDRL P Drill 9 7/8" hole F/3,323' T/3,632'
700 GPM
1200 PSI
150 RPM
7K TQ on 3K off
5K WOB
10.17 ECD
P/U - 130K
S/O - 122K
ROT- 128K
47 Units Max Gas
AVG = 88.2 FPH W/connections
ADT= 2.75
Bit HRS= 2.95
Jar HRS = 23.51
3,323.0 3,632.0
2/17/2023
12:00
2/18/2023
00:00
12.00 INTRM1, DRILL DDRL P Drill 9 7/8" hole F/3,632' T/4,766'
700 GPM
1430 PSI
150 RPM
7K TQ on 4K off
5-9K WOB
10.88 ECD
P/U - 148K
S/O - 130K
ROT- 133K
144 Units Max Gas
AVG = 94.5 FPH W/connections
ADT= 8.24
Bit HRS= 11.19
Jar HRS = 31.95
Pump Hi vis sweep at 3,800' see 20%
increase in cuttings at shakers
Pump Hi vis sweep at 4,390' see 25%
increase in cuttings at shakers
Pump Hi vis sweep at 4,766' see 25%
increase in cuttings at shakers, come
back 20 BBLS early
3,632.0 4,766.0
2/18/2023
00:00
2/18/2023
11:00
11.00 INTRM1, DRILL DDRL P Drill 9 7/8" hole F/4,766' T/5,810'
700 GPM
1745 PSI
150 RPM
7K TQ on 4.5K off
7-8K WOB
11.49 ECD
P/U - 165K
S/O - 130K
ROT- 141K
100 Units Max Gas
AVG = 95 FPH W/connections
ADT= 8.28
Bit HRS= 19.47
Jar HRS = 40.23
Pump Hi vis sweep at 5,306' see 25%
increase in cuttings at shakers - come
back 40 BBLS early
Pump Hi vis sweep at 5,716' see 10%
increase in cuttings at shakers
4,766.0 5,810.0
2/18/2023
11:00
2/18/2023
11:30
0.50 INTRM1, DRILL SVRG P Service rig
Simops change swab and liner on MP
#2
Circ at 300 GPM 580 PSI 60 RPM 5K
TQ
5,810.0 5,810.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 17/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/18/2023
11:30
2/18/2023
12:00
0.50 INTRM1, DRILL DHEQ P Circ at 700 GPM 1700 PSI 60 RPM 5K
TQ
Send down links to change steering
mode on the Xceed to manual
5,810.0 5,810.0
2/18/2023
12:00
2/19/2023
00:00
12.00 INTRM1, DRILL DDRL P Drill 9 7/8" hole F/5,810' T/6,685'
700 GPM
1970 PSI
150 RPM
8K TQ on 5K off
7-10K WOB
11.04 ECD
P/U - 160K
S/O - 143K
ROT- 146K
118 Units Max Gas
AVG = 73 FPH W/connections
ADT= 8.83
Bit HRS= 28.30
Jar HRS = 49.06
Pump Hi vis sweep at 6,211' see 10%
increase in cuttings at shakers - come
back 10 BBLS early
5,810.0 6,685.0
2/19/2023
00:00
2/19/2023
07:00
7.00 INTRM1, DRILL DDRL P Drill 9 7/8" hole F/6,685' T/7,326'
700 GPM
2000 PSI
170 RPM
10K TQ on 6K off
10K WOB
11.42 ECD
P/U - 166K
S/O - 140K
ROT- 151K
789 Units Max Gas
AVG = 91.5 FPH W/connections
ADT= 5.58
Bit HRS= 33.88
Jar HRS = 54.64
Pump Hi vis sweep at 6,947' see very
little increase in cuttings at shakers -
back 80 BBLS early
6,685.0 7,326.0
2/19/2023
07:00
2/19/2023
09:45
2.75 INTRM1, TRIPCAS CIRC P CBU x 3 while standing one stand back
per B/U , weight up to 9.6 PPG with 10.1
PPG spike fluid
700 GPM 1880 PSI
145 RPM 6K TQ
155K UP
140K DN
147K ROT
7,326.0 7,134.0
2/19/2023
09:45
2/19/2023
10:15
0.50 INTRM1, TRIPCAS OWFF P Flow check - slight drop 7,134.0 7,134.0
2/19/2023
10:15
2/19/2023
23:00
12.75 INTRM1, TRIPCAS BKRM P BROOH F/7,134' T/3,249'
While L/D 5" DP in the mousehole
700 GPM 1400 PSI
130 RPM 4-5K TQ
118K ROT WT
7,134.0 3,249.0
2/19/2023
23:00
2/20/2023
00:00
1.00 INTRM1, TRIPCAS CIRC P Flow check - CBU X2 , pump 40 BBLS
Hi Vis nut plug sweep
700 GPM 1320 PSI
70 RPM 4K TQ
120K ROT
3,249.0 3,249.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 18/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/20/2023
00:00
2/20/2023
00:15
0.25 INTRM1, TRIPCAS CIRC P Circulate to clean up casing
700 GPM 1320 PSI
70 RPM 4K TQ
120K ROT
3,249.0 3,249.0
2/20/2023
00:15
2/20/2023
04:00
3.75 INTRM1, TRIPCAS BKRM P BROOH F/3,249' T/1,895'
700 GPM 1300 PSI
70 RPM 3K TQ
122K UP
119K DN
Lay down 5" DP in the mouse hole
Pump Hi vis sweep at 2,019' , 25%
increase in cuttings
3,249.0 1,895.0
2/20/2023
04:00
2/20/2023
07:00
3.00 INTRM1, TRIPCAS TRIP P Flow check , Blow down top drive ,
POOH F/1,895' T/794'
Laying down DP to pipe shed
1,895.0 794.0
2/20/2023
07:00
2/20/2023
07:15
0.25 INTRM1, TRIPCAS OWFF P Flow check - static 794.0 794.0
2/20/2023
07:15
2/20/2023
09:00
1.75 INTRM1, TRIPCAS TRIP P POOH F/794' T/152'
L/D 5" HWDP to pipe shed
794.0 152.0
2/20/2023
09:00
2/20/2023
09:15
0.25 INTRM1, TRIPCAS OWFF P Flow check - static
PJSM L/D BHA and down load nukes
152.0 152.0
2/20/2023
09:15
2/20/2023
11:00
1.75 INTRM1, TRIPCAS BHAH P L/D BHA as per SLBG DD 152.0 0.0
2/20/2023
11:00
2/20/2023
12:30
1.50 INTRM1, TRIPCAS BHAH P Clean and clear rig floor
SimOps - C/O SLBG stand pipe
pressure gauge
0.0 0.0
2/20/2023
12:30
2/20/2023
14:30
2.00 INTRM1, WHDBOP WWWH P M/U stack washing tool to StreamFlo
stack washer and wear ring puller
Flush stack , pull wear ring , function
BOP rams and annular
0.0 0.0
2/20/2023
14:30
2/20/2023
16:30
2.00 INTRM1, WHDBOP RURD P Change out top rams to 7 5/8" solid
body , Make up 5" and 7 5/8" test joints
for space out , set test plug as per
Stream Flo
0.0 0.0
2/20/2023
16:30
2/20/2023
17:15
0.75 INTRM1, WHDBOP RURD P Rig up to test BOP make up FOSV to
dart valve , make up test sub to top
drive , fill stack and lines with water ,
purge air from system , perform shell
test
0.0 0.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 19/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/20/2023
17:15
2/20/2023
22:00
4.75 INTRM1, WHDBOP BOPE P All test with 7 5/8" and 5" test joints to
250 PSI low 4,000 PSI for 5 minutes
each test charted. Test annular
preventer with 5" test joint to 250 psi low
and 2,500 psi high for 5 minutes each.
Test 4" Demco kill , choke valves 1 to
14 , 7 5/8" top rams , 3.5" x 6" VBR
bottom rams , auto/manual IBOP , HCR
kill/choke valve , manual kill/choke
valve , Dart valve , FOSV.
Accumulator drawdown:
ISP = 2900 PSI
PSI after functioning = 1450 PSI
200 psi rec = 32 seconds
Full system recovery = 148 seconds
4 bottles back up average = 2250 PSI
Bottle pre-charge average = 1000 PSI
Closing times: Annular = 14 seconds,
UPR = 7 seconds, Blind rams = 7
seconds, LPR = 7 seconds, Choke HCR
= 1 seconds, Kill HCR = 1 seconds
PVT gain/loss, Flow paddle
Witness by AOGCC Rep Guy Cook
Trouble shoot gas sensor's
0.0 0.0
2/20/2023
22:00
2/20/2023
23:45
1.75 INTRM1, WHDBOP BOPE T Trouble shoot choke line , find out line
was froze up , thaw out line
Cont to trouble shoot gas sensor's
0.0 0.0
2/20/2023
23:45
2/21/2023
00:00
0.25 INTRM1, WHDBOP BOPE P Test blind rams to 250/4000 PSI for 5
min each
Witness by AOGCC Rep Guy Cook
Cont to trouble shoot gas sensor's
0.0 0.0
2/21/2023
00:00
2/21/2023
00:30
0.50 INTRM1, WHDBOP BOPE P Cont to test blind rams to 250/4000 PSI
for 5 min each
Witness by AOGCC Rep Guy Cook
Blow down choke and kill line
Cont to trouble shoot gas sensor's
0.0 0.0
2/21/2023
00:30
2/21/2023
02:00
1.50 INTRM1, WHDBOP BOPE T Thaw out choke line out side on top of
pits
Cont to trouble shoot gas sensor's
0.0 0.0
2/21/2023
02:00
2/21/2023
02:30
0.50 INTRM1, WHDBOP BOPE P Perform Draw down test with remote
and hydraulic chokes to 2,000 psi and
observed pressure drop when opening.
Witness by AOGCC Rep Guy Cook
0.0 0.0
2/21/2023
02:30
2/21/2023
05:00
2.50 INTRM1, WHDBOP RURD P Blow down lines , R/D testing
equipment , pull test plug
Cont to trouble shoot gas sensor's
0.0 0.0
2/21/2023
05:00
2/21/2023
08:00
3.00 INTRM1, CASING RURD P Rig up to run 7 5/8" casing , make up
Volant tool to top drive , 350 T spider
slips , 150T side door elevators , floor
valve to 29.7# and 39# crossovers
SimOps cont trouble shoot gas sensor
0.0 0.0
2/21/2023
08:00
2/21/2023
09:00
1.00 INTRM1, CASING SVRG P Service rig 0.0 0.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 20/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/21/2023
09:00
2/21/2023
18:00
9.00 INTRM1, CASING RGRP T Troubleshoot gas alarm systems ,
change out main board in dog house 3
times , rebuild H2S sensor head at bell
nipple and replace same , change out
ground wire traced out all wires for good
conductivity. Recalibrate system. Still
have failure at bell nipple H2S sensor
SimOps- change out valves and seats
#1 MP , clean suction chambers and
screens both mud pumps , thaw out
mud line , bleeder line and hole fill line ,
load production BHA in pipe shed , pick
up cross over's and subs to rig floor
Received variance to RIH with 7 5/8"
casing from AOGCC Rep Jim Regg at
17:00 HRS as long as personal wear a
personal H2S detector and a hand help
with personal monitoring in the cellar
area
0.0 0.0
2/21/2023
18:00
2/21/2023
19:00
1.00 INTRM1, CASING PUTB P PJSM on running casing
Pick up shoe track T/168'
Pump thru at 3.5 BPM to ensure clear ,
pick up , check floats - floats holding
Baker loc to pin end of JT# 4
29.7# MUT - 10,300 FT/LBS
39# MUT = 19,300 FT/LBS
Double bump each connection
0.0 168.0
2/21/2023
19:00
2/21/2023
22:00
3.00 INTRM1, CASING PUTB P RIH with 39# 7 5/8" casing F/168' T/923'
39# MUT = 19,300 FT/LBS
Double bump each connection
168.0 923.0
2/21/2023
22:00
2/21/2023
22:30
0.50 INTRM1, CASING RURD P Change out volant tool cup and floor
valve x/over
923.0 923.0
2/21/2023
22:30
2/22/2023
00:00
1.50 INTRM1, CASING PUTB P RIH F/923' T/1,500' as per detail with 7
5/8" 29.7# casing
105K DN
29.7# MUT - 10,300 FT/LBS
Double bump each connection
923.0 1,500.0
2/22/2023
00:00
2/22/2023
03:30
3.50 INTRM1, CASING PUTB P RIH F/1,500' T/3,272' as per detail with
7 5/8" 29.7# casing
125K UP
120K DN
29.7# MUT - 10,300 FT/LBS
Double bump each connection
1,500.0 3,272.0
2/22/2023
03:30
2/22/2023
04:30
1.00 INTRM1, CASING CIRC P CBU staging pumps up to 6 BPM
6 BPM 230 PSI
125K UP
120K DN
3,272.0 3,272.0
2/22/2023
04:30
2/22/2023
10:30
6.00 INTRM1, CASING PUTB P RIH F/3,272' T/5,252' as per detail with
7 5/8" 29.7# casing
138K DN
29.7# MUT - 10,300 FT/LBS
Double bump each connection
3,272.0 5,252.0
2/22/2023
10:30
2/22/2023
13:00
2.50 INTRM1, CASING CIRC P CBU staging pumps up to 6 BPM
4 BPM 280 PSI
6 BPM 350 PSI
150K UP
133K DN
5,252.0 5,252.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 21/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/22/2023
13:00
2/22/2023
20:00
7.00 INTRM1, CASING PUTB P RIH F/5,252 T/7,196' as per detail with 7
5/8" 29.7# casing
143K DN
29.7# MUT - 10,300 FT/LBS
Double bump each connection
16:00 HRS gas alarms fixed and tested
5,252.0 7,196.0
2/22/2023
20:00
2/22/2023
20:45
0.75 INTRM1, CASING WASH P Wash DN F/7,196' T/7,280'
2 BPM 380 PSI
XXXK UP
143K DN
7,196.0 7,280.0
2/22/2023
20:45
2/22/2023
21:15
0.50 INTRM1, CASING WASH P Pick up StreamFlo mandrel hanger ,
install 2 shear pins
Wash DN F/7,280' T/7,316'
2 BPM 370 PSI
175K UP
140K DN
7,280.0 7,316.0
2/22/2023
21:15
2/23/2023
00:00
2.75 INTRM1, CEMENT CIRC P Circ cond mud for CMT job
Stage pumps up to 7 BPM
2 BPM 340 PSI
3 BPM 370 PSI
4 BPM 390 PSI
5 BPM 380 PSI
6 BPM 400 PSI
7 BPM 450 PSI
168K UP
138K DN
Stage trucks for CMT job , blow air thru
CMT line to cellar load 4" DP in pipe
shed
7,316.0 7,316.0
2/23/2023
00:00
2/23/2023
01:15
1.25 INTRM1, CEMENT CIRC P Circ cond mud for CMT job
Stage pumps up to 8 BPM
7 BPM 450 PSI
8 BPM 490 PSI
No losses during circulation
Blow air thru CMT lines
MD WT 9.6 PPG , VIS 56/59 , YP @ 24
167K UP
131K DN
7,316.0 7,316.0
2/23/2023
01:15
2/23/2023
01:30
0.25 INTRM1, CEMENT RURD P Shut down pumps , B/D top drive , R/U
cement hose , valves and chart recorder
7,316.0 7,316.0
2/23/2023
01:30
2/23/2023
02:45
1.25 INTRM1, CEMENT CIRC P Break circ stage up to 8 BPM 700 PSI
thru CMT hose from rig pumps
PJSM on cement job while circulating
and working pipe
7,316.0 7,316.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 22/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/23/2023
02:45
2/23/2023
05:00
2.25 INTRM1, CEMENT CMNT P Cement 7-5/8" casing as per program.
Halliburton flood lines , test trips and
test lines to 4000 PSI
Dropped 1st bottom plug, pumped 59
BBLS tuned prime spacer 12.5 PPG
with BMII A 5 LBS/BBL @ 2.8 BPM
while reciprocating, PUW 177K, SOW
143K.
Dropped 2nd bottom wiper plug and
followed with 41 BBLS 15.3 PPG Lead
Cement with BMII @ 4.5 LBS/Sack,
pumped at average 2.5 - 3 BPM.
Followed with BBLS 21.5 PPG Lead
Cement without BMII , pumped at
average 2.5 - 3 BPM. Dropped top plug.
HES displaced with 10 BBLS H2O.
Displaced 319.5 BBLS with 9.6 PPG
mud using rig pump at 8 BPM , ICP 278
PSI, FCP 1010 PSI Observed burst disk
at 670 PSI 198.5 BBLS into
displacement (2.5 BBLS early) slowing
to 3 BPM last 20 BBLS 700 ICP , PSI up
F/800 PSI T/1300 PSI hold 5 min ,
Bleed pressure off and floats held.
Note: Shoe @ 7316.22', Float collar @
7228.82' , No Losses circulating and
cementing
Note: Casing was reciprocated and
landed when plugs dropped, spacer and
lead cement cleared shoe then resumed
reciprocating , Laned out 314 BBLS into
displacement 165K UP 115K DN prior to
landing - block weight 60K.
CIP @ 4:57 HRS
7,316.0 7,316.0
2/23/2023
05:00
2/23/2023
05:15
0.25 INTRM1, CEMENT OWFF P OWFF 7,316.0 7,316.0
2/23/2023
05:15
2/23/2023
06:00
0.75 INTRM1, CEMENT RURD P Break out landing JT , R/D and L/D
CRT , clear floor , B/D lines
0.0 0.0
2/23/2023
06:00
2/23/2023
07:00
1.00 INTRM1, CEMENT WWSP P Drain stack , set and test pack off to
5000 PSI F/5 min , L/D landing JT
0.0 0.0
2/23/2023
07:00
2/23/2023
09:15
2.25 INTRM1, CEMENT RURD P L/D 2 stands 5" DP , clean cement
valves on rig floor and cellar
C/O handling equipment , floor valves ,
and lift subs to 4"
SimOps - load 4" DP in pipe shed ,
clean under drip pan
0.0 0.0
2/23/2023
09:15
2/23/2023
13:15
4.00 INTRM1, WHDBOP RURD P C/O upper pipe rams to 3 1/2" x 6"
VBR , C/O saver sub to XT39
Cont load 4" DP in pipe shed and clean
pits
0.0 0.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 23/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/23/2023
13:15
2/23/2023
15:30
2.25 INTRM1, WHDBOP RURD P Set test plug as per StreamFlo Rep
Rig up to test BOP make up FOSV to
dart valve , make up test sub to top
drive , fill stack and lines with water ,
purge air from system , perform shell
test
SimOps - B/D mud line , L/D SLBG lift
subs , load 4" DP in shed , clean pits
0.0 0.0
2/23/2023
15:30
2/23/2023
15:30
0.00 INTRM1, WHDBOP FRZP P Freeze protect 10 3/4" x 7 5/8" annulus
during BOP test
Pump 7.75 BBLS diesel PSI up to 866
PSI to break over and start injecting
.5 BPM 824 intinal injection rate and PSI
1 BPM 750 PSI at 15 BBLS pumped
1.5 BPM 890 PSI at 20 BBLS pumped
1.75 BPM 915 PSI at 35 BBLS pumped
2 BPM 1043 PSI at 50 BBLS pumped
2 BPM 1055 PSI at 86 BBLS pumped
Intial shut in PSI = 670
0.0 0.0
2/23/2023
15:30
2/23/2023
22:00
6.50 INTRM1, WHDBOP BOPE P All test with 4" and 4 1/2" test joints to
250 PSI low 4,000 PSI for 5 minutes
each test charted. Test annular
preventer with 4" test joint to 250 psi low
and 2,500 psi high for 5 minutes each.
Test 4" Demco kill , choke valves 1 to
14 , 3.5" x 6" VBR top and bottom
rams , blind rams , auto/manual IBOP ,
HCR kill/choke valve , manual kill/choke
valve , Dart valve , FOSV. Test remote
and hydraulic chokes to 2,000 psi and
observed pressure drop when opening.
Accumulator drawdown:
ISP = 3000 PSI
PSI after functioning = 1400 PSI
200 psi rec = 28 seconds
Full system recovery = 187 seconds
4 bottles back up average = 2400 PSI
Bottle pre-charge average = 11 @ 1000
PSI
Closing times: Annular = 19 seconds,
UPR = 7 seconds, Blind rams = 15
seconds, LPR = 7 seconds, Choke HCR
= 1 seconds, Kill HCR = 1 seconds
Test all gas alarms, PVT gain/loss, Flow
paddle
Witness waived by AOGCC Rep Guy
Cook on 2-22-23 @ 16:27 HRS
0.0 0.0
2/23/2023
22:00
2/23/2023
23:30
1.50 INTRM1, WHDBOP RURD P R/D testing equipment , B/D lines , pull
test plug set W/R
W/R ID = 7.69"
0.0 0.0
2/23/2023
23:30
2/24/2023
00:00
0.50 INTRM1, DRILLOUT RURD P Bring up BHA components to rig floor ,
load 4" DP in shed
0.0 0.0
2/24/2023
00:00
2/24/2023
04:30
4.50 INTRM1, DRILLOUT RURD P Bring up BHA components to rig floor ,
program BHA , load BHA in shed ,
load , strap and tally 4" DP in shed for
single in with BHA
0.0 0.0
2/24/2023
04:30
2/24/2023
07:45
3.25 INTRM1, DRILLOUT RURD P PJSM - P/U stand back 12 stands of 4"
DP in derrick (drift to 2.563"). SIMOPS:
Pipe management in pipe shed.
0.0 0.0
2/24/2023
07:45
2/24/2023
12:00
4.25 INTRM1, DRILLOUT BHAH P PJSM. M/U 6-1/2" RSS BHA #4 to 207'
as per SLB DD & MWD. U/D WT 70K.
0.0 207.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 24/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/24/2023
12:00
2/24/2023
13:00
1.00 INTRM1, DRILLOUT BHAH P Continue M/U 6-1/2" RSS BHA #4 to
487' as per SLB DD & MWD. U/D WT
70K.
207.0 487.0
2/24/2023
13:00
2/24/2023
13:30
0.50 INTRM1, DRILLOUT SVRG P Rig service, top drive, ST-80, pipe skate
and draworks.
487.0 487.0
2/24/2023
13:30
2/24/2023
14:00
0.50 INTRM1, DRILLOUT SVRG P Safety critical scheduled PM on top
drive (work order). SIMOPS: Finish drill
pipe tally.
487.0 487.0
2/24/2023
14:00
2/24/2023
18:00
4.00 INTRM1, DRILLOUT PULD P RIH F/489' T/3,500' Single in the hole
with 4" DP from pipe shed. Filling pipe
every 20 STDS.
S/O 93K
487.0 3,500.0
2/24/2023
18:00
2/24/2023
19:30
1.50 INTRM1, DRILLOUT CIRC P Shallow test MWD tools good test ,
down link to turn on SonicScope for
memory logging.
250 GPM
1720 PSI
50 RPM
2K TQ
ROT 100K
3,500.0 3,500.0
2/24/2023
19:30
2/25/2023
00:00
4.50 INTRM1, DRILLOUT PULD P RIH F/3,510' T/6,775', Single in the hole
with 4" DP from pipe shed Logging
(memory) with Sonicscope @ 1800
FPH. Filling pipe every 20 STDS.
S/O 100K
3,510.0 6,775.0
2/25/2023
00:00
2/25/2023
01:30
1.50 INTRM1, DRILLOUT PULD P RIH F/6,775' T/7,003', Single in the hole
with 4" DP from pipe shed Logging
(memory) with SonicScope @ 1800
FPH. Filling pipe every 20 STDS.
S/O 95K
6,775.0 7,003.0
2/25/2023
01:30
2/25/2023
02:15
0.75 INTRM1, DRILLOUT CIRC P Circulate and condition mud for casing
test.
275 GPM
2440 PSI
S/O 95K
7,003.0 7,003.0
2/25/2023
02:15
2/25/2023
03:15
1.00 INTRM1, DRILLOUT PRTS P Pressure test 7-5/8" casing to 4,000 psi
with 9.5 ppg mud for 30 minutes - good
test. Record on chart. Pumped 5.1 bbls
and bled back 5.5 bbls.
7,003.0 7,003.0
2/25/2023
03:15
2/25/2023
03:45
0.50 INTRM1, DRILLOUT RURD P R/D test equipment, B/D lines
associated with test. Ready rig floor to
wash down with 4" DP stands from
derrick.
7,003.0 7,003.0
2/25/2023
03:45
2/25/2023
04:30
0.75 INTRM1, DRILLOUT REAM P Wash and ream down pumping 230 gpm
with 40 rpm. Tag at 7,224'.
7,003.0 7,224.0
2/25/2023
04:30
2/25/2023
09:30
5.00 INTRM1, DRILLOUT DRLG P Drill cement, wiper plugs and float
equipment from 7,224' to 7,316' at shoe.
Cleaned out rat hole to 7,326 '. Worked
through shoe and float collar 3 times.
230 GPM
1920 PSI
60 RPM
7K TQ
2-5K WOB
ROT 116K
7,224.0 7,326.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 25/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/25/2023
09:30
2/25/2023
10:00
0.50 INTRM1, DRILLOUT DDRL P Drill 20' new formation from 7,326' to
7,346'.
275 GPM
2440 PSI
60 RPM
8K TQ
10K WOB
10.87 ECD
7,326.0 7,346.0
2/25/2023
10:00
2/25/2023
10:30
0.50 INTRM1, DRILLOUT CIRC P Circulate and condition mud to 9.5 ppg
in/out for LOT/FIT test. Pull bit inside
casing and B/D top drive.
275 GPM
2320 PSI
60 RPM
8K TQ
7,346.0 7,316.0
2/25/2023
10:30
2/25/2023
10:45
0.25 INTRM1, DRILLOUT OWFF P OWFF - static. 7,316.0 7,316.0
2/25/2023
10:45
2/25/2023
11:30
0.75 INTRM1, DRILLOUT LOT P Rig up for FIT/ LOT testing equipment,
circulate through lines to purge air, close
UPR rams Perform FIT/LOT test as per
procedure. Used #2 mud pump pumping
9.5 ppg mud at 0.5 bbl increments to
test pressure of 1,018 PSI, 14.2 ppg
EMW. Observed leak off and pumped
0.2 bbls additional. 1.5 bbls pumped,
Initial SIP: 1,074 psi, Final SIP: 715 psi,
355 psi loss over 10 minutes. Bled off
and record 1.7 bbls bled back.
7,316.0 7,316.0
2/25/2023
11:30
2/25/2023
11:45
0.25 INTRM1, DRILLOUT RURD P Rig down test equipment and blow down
lines.
7,316.0 7,316.0
2/25/2023
11:45
2/25/2023
12:15
0.50 PROD1, DRILL OWFF P OWFF - observed a slight drop. Top off
riser and contiue to monitor - static.
7,316.0 7,316.0
2/25/2023
12:15
2/25/2023
12:30
0.25 PROD1, DRILL SFTY P PJSM on displacing to 9.5 ppg Kla-
Shield mud.
7,316.0 7,316.0
2/25/2023
12:30
2/25/2023
18:00
5.50 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole
from 7,346' to 7,668'.
Note: Pumped 50 bbls hi-vis weighted
spacer followed by 9.5 ppg Kla-Shield
mud on the fly while drilling to displace
9.5 ppg LSND mud.
262 GPM
2090 PSI
120 RPM
7K TQ
5K WOB
11.0 ECD
P/U - 113K
S/O - 95K
ROT- 112K
345 Units Max Gas
ADT= 4.01
Bit HRS= 4.15
7,316.0 7,668.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 26/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/25/2023
18:00
2/26/2023
00:00
6.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole
from 7,668' to 8,226' MD / 4,174' TVD .
265 GPM
2090 PSI
150 RPM
7K/5K TQ On/Off
5K WOB
11.0 ECD
P/U - 113K
S/O - 95K
ROT- 112K
675 Units Max Gas
ADT= 4.37
Bit HRS= 8.69
7,668.0 8,226.0
2/26/2023
00:00
2/26/2023
06:00
6.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole
from 8,226' to 8,894' MD / 4,182' TVD .
270 GPM
2200 PSI
150 RPM
8K/5K TQ On/Off
5K WOB
11.28 ECD
P/U - 135K
S/O - 96K
ROT- 112K
1002 Units Max Gas
ADT= 4.64
Bit HRS= 13.33
8,226.0 8,894.0
2/26/2023
06:00
2/26/2023
12:00
6.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole
from 8,894' to 9,555' MD / 4,193' TVD .
270 GPM
2310 PSI
150 RPM
7.6K/5.7K TQ On/Off
7K WOB
11.42 ECD
P/U - 137K
S/O - 96K
ROT- 116K
1064 Units Max Gas
ADT= 4.59
Bit HRS= 17.92
8,894.0 9,555.0
2/26/2023
12:00
2/26/2023
18:00
6.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole
from 9,555' to 10,241' MD / 4,201' TVD .
270 GPM
2430 PSI
150 RPM
7K/5.5K TQ On/Off
7K WOB
11.69 ECD
P/U - 136K
S/O - 94K
ROT- 112K
385 Units Max Gas
ADT= 4.61
Bit HRS= 22.44
9,555.0 10,241.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 27/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/26/2023
18:00
2/27/2023
00:00
6.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole
from 10,241' to 10,895' MD / 4,209'
TVD .
270 GPM
2470 PSI
150 RPM
8K/6K TQ On/Off
7K WOB
11.93 ECD
P/U - 138K
S/O - 92K
ROT- 112K
393 Units Max Gas
ADT= 4.53
Bit HRS= 26.97
10,241.0 10,895.0
2/27/2023
00:00
2/27/2023
06:00
6.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole
from 10,895' to 11,537' MD / 4,216'
TVD .
270 GPM
2430 PSI
150 RPM
8K/6K TQ On/Off
11K WOB
11.85 ECD
P/U - 138K
S/O - 92K
ROT- 115K
1079 Units Max Gas
ADT= 4.51
Bit HRS= 31.48
10,895.0 11,537.0
2/27/2023
06:00
2/27/2023
12:00
6.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole
from 11,537' to 12,199' MD / 4,219'
TVD .
270 GPM
2500 PSI
150 RPM
8K/6K TQ On/Off
5K WOB
11.97 ECD
P/U - 137K
S/O - 93K
ROT- 113K
1260 Units Max Gas
ADT= 4.54
Bit HRS= 36.02
11,537.0 12,199.0
2/27/2023
12:00
2/27/2023
18:00
6.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole
from 12,199' to 12,872' MD / 4,226'
TVD .
270 GPM
2670 PSI
150 RPM
8K/6.5K TQ On/Off
7K WOB
12.17 ECD
P/U - 145K
S/O - 98K
ROT- 119K
917 Units Max Gas
ADT= 4.52
Bit HRS= 40.54
12,199.0 12,872.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 28/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/27/2023
18:00
2/28/2023
00:00
6.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole
from 12,872' to 13,550' MD / 4,235'
TVD .
270 GPM
2770 PSI
150 RPM
8K/6.5K TQ On/Off
7K WOB
12.30 ECD
P/U - 153K
S/O - 102K
ROT- 125K
582 Units Max Gas
ADT= 4.58
Bit HRS= 45.12
12,872.0 13,550.0
2/28/2023
00:00
2/28/2023
06:00
6.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole
from 13,550' to 14,237' MD / 4,242'
TVD.
270 GPM
3270 PSI
150 RPM
9.5K/7.5K TQ On/Off
5-9K WOB
12.62 ECD
P/U - 166K
S/O - 105K
ROT- 134K
1654 Units Max Gas
ADT= 4.69
Bit HRS= 49.81
13,550.0 14,237.0
2/28/2023
06:00
2/28/2023
12:00
6.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole
from 14,237' to 14,888' MD / 4,237'
TVD.
270 GPM
3370 PSI
150 RPM
9.5K/7.5K TQ On/Off
4-9K WOB
12.80 ECD
P/U - 170K
S/O - 107K
ROT- 128K
1203 Units Max Gas
ADT= 4.50
Bit HRS= 54.31
14,237.0 14,888.0
2/28/2023
12:00
2/28/2023
18:00
6.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole
from 14,888' to 15,507' MD / 4,257'
TVD.
270 GPM
3410 PSI
150 RPM
9.5K/7.5K TQ On/Off
4-9K WOB
12.95 ECD
P/U - 172K
S/O - 107K
ROT- 143K
389 Units Max Gas
ADT= 4.63
Bit HRS= 58.94
14,888.0 15,507.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 29/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/28/2023
18:00
3/1/2023
00:00
6.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole
from 15,507' to 15,974' MD / 4,260'
TVD.
270 GPM
3600 PSI
150 RPM
10K/7.5K TQ On/Off
4-9K WOB
12.87 ECD
P/U - 177K
S/O - 110K
ROT- 144K
214 Units Max Gas
ADT= 4.68
Bit HRS= 63.62
15,507.0 15,974.0
3/1/2023
00:00
3/1/2023
05:00
5.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole
from 15,974' to TD @ 16,372' MD /
4,261' TVD.
270 GPM
3670 PSI
150 RPM
10K/8.5K TQ On/Off
4-9K WOB
12.87 ECD
P/U - 177K
S/O - 98K
ROT- 138K
1023 Units Max Gas
ADT= 4.14
Bit HRS= 67.76
15,974.0 16,372.0
3/1/2023
05:00
3/1/2023
05:15
0.25 PROD1, TRIPCAS CIRC P Obtain final TD survey, T&D numbers
and SPR's.
16,372.0 16,372.0
3/1/2023
05:15
3/1/2023
09:00
3.75 PROD1, TRIPCAS BKRM P BROOH F/16,372 T/16,194" circulating
1 bottoms up for first 2 stands laying
down pipe in mousehole to pipe shed.
270 GPM
3600 PSI
120 RPM
9K TQ
ROT 131K
16,372.0 16,194.0
3/1/2023
09:00
3/1/2023
09:15
0.25 PROD1, TRIPCAS OWFF P OWFF - static. 16,194.0 16,194.0
3/1/2023
09:15
3/1/2023
12:00
2.75 PROD1, TRIPCAS BKRM P BROOH at 1,000 fph F/16,194'
T/15,182' laying down 4 stands 4" DP
from mousehole to pipe shed and
racking back 4" HWDP.
270 GPM
3150 PSI
120 RPM
9K TQ
ROT 133K
16,194.0 15,182.0
3/1/2023
12:00
3/2/2023
00:00
12.00 PROD1, TRIPCAS BKRM P BROOH at 1,000 fph F/15,182'
T/10,301' racking back 4" HWDP (total
41 stands) and laying down 4" DP from
mousehole to pipe shed.
270 GPM
2280 PSI
120 RPM
6K TQ
ROT 105K
15,182.0 10,301.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 30/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/2/2023
00:00
3/2/2023
07:00
7.00 PROD1, TRIPCAS BKRM P BROOH at 1,000 fph F/10,301' T/7,570'
laying down excess 4" DP from
mousehole to pipe shed.
260 GPM
1950 PSI
10.5 ECD
P/U 135K
S/O 105K
10,301.0 7,570.0
3/2/2023
07:00
3/2/2023
08:15
1.25 PROD1, TRIPCAS TRIP P Pump into shoe F/7,570 T/7,288',
observed 15K overpull with BHA stab,
s/o and worked back up with normal
drag.
260 GPM
1950 PSI
P/U 135K
S/O 100K
10.5 ECD
7,570.0 7,288.0
3/2/2023
08:15
3/2/2023
10:45
2.50 PROD1, TRIPCAS CIRC P Circulate 2 x bottoms ups - no unloading
events observed while Sonic logging
F/7,286' T/7,098'.
Dropped 2.30" hollow drift with 100' tail
wire.
7,288.0 7,098.0
3/2/2023
10:45
3/2/2023
11:15
0.50 PROD1, TRIPCAS OWFF P OWFF - dropped 12" in 30 minutes. 7,098.0 7,098.0
3/2/2023
11:15
3/2/2023
12:00
0.75 PROD1, TRIPCAS TRIP P POOH F/7,098 T/7,007' on elevators as
per schedule.
7,098.0 7,007.0
3/2/2023
12:00
3/2/2023
18:45
6.75 PROD1, TRIPCAS TRIP P POOH F/7,007 T/581' on elevators as
per schedule to last stand 4" DP.
P/U 80K
7,007.0 581.0
3/2/2023
18:45
3/2/2023
19:00
0.25 PROD1, TRIPCAS OWFF P OWFF - static. 581.0 581.0
3/2/2023
19:00
3/2/2023
19:15
0.25 PROD1, TRIPCAS BOPE P Function test BOP rams, annular HCR
choke & kill.
Closing times: Annular = 16 sec, UPR
VBR's & LWR VBR's = 7 sec each, HCR
Choke & Kill 1 sec each.
581.0 581.0
3/2/2023
19:15
3/3/2023
00:00
4.75 PROD1, TRIPCAS BHAH P L/D 6-1/2" production BHA as per SLB
DD. Bit Grade: 0-0-In.
Note: Closed Blinds - 14 sec closing
time.
581.0 0.0
3/3/2023
00:00
3/3/2023
01:00
1.00 PROD1, TRIPCAS CLEN P Clean and clear excess BHA tools /
equipment F/ rig floor.
0.0 0.0
3/3/2023
01:00
3/3/2023
03:30
2.50 COMPZN, CASING RURD P R/U to run 4-1/2" lower completion liner. 0.0 0.0
3/3/2023
03:30
3/3/2023
04:00
0.50 COMPZN, CASING SVRG P Service rig while changing out power
tongs.
0.0 0.0
3/3/2023
04:00
3/3/2023
12:00
8.00 COMPZN, CASING PUTB P PJSM - RIH with 4 1/2" lower completion
liner as per detail T/5,043'.
Note: Top filling each jt on the fly with
mud. Checked floats with mud - ok.
S/O 96K
P/U 96K
0.0 5,043.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 31/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/3/2023
12:00
3/3/2023
16:30
4.50 COMPZN, CASING PUTB P PJSM - RIH with 4 1/2" lower
completion liner as per detail F/5,043'
T/9,193'.
Note: Top filling each jt on the fly with
mud.
S/O 96K
P/U 96K
5,043.0 9,193.0
3/3/2023
16:30
3/3/2023
17:00
0.50 COMPZN, CASING PUTB P Make up Baker liner hanger assy w/ZXP
packer w/10' tieback, Install RS packoff
seal nipple as per Baker rep, crossover
to 4" drill pipe and run 1 stand 4" drill
pipe. Take T&D numbers at 9,333'.
P/U 120K
S/O 95K
ROT 110K
20 RPM
5K TQ
9,193.0 9,333.0
3/3/2023
17:00
3/4/2023
00:00
7.00 COMPZN, CASING RUNL P RIH with 4-1/2" lower completion liner
on 4" drill pipe & HWDP F/9,333'
T/12,850' .
Note:Top filling each stand with 9.5 ppg
mud. Drifting HWDP to 2.11".
S/O 100K
9,333.0 12,850.0
3/4/2023
00:00
3/4/2023
07:00
7.00 COMPZN, CASING RUNL P RIH with 4-1/2" lower completion liner
on 4" drill pipe & HWDP F/12,850'
T/16,212' .
Note:Top filling each stand with 9.5 ppg
mud. Drifting HWDP to 2.11".
S/O 110K
12,850.0 16,212.0
3/4/2023
07:00
3/4/2023
08:00
1.00 COMPZN, CASING WASH P Taking weight, wash down F/16,212'
T/16,344'.
42 GPM
610 PSI
P/U 176K
S/O 115K
16,212.0 16,344.0
3/4/2023
08:00
3/4/2023
08:30
0.50 COMPZN, CASING RURD P B/D top drive. P/U Baker cement head
as per Baker rep.
16,344.0 16,344.0
3/4/2023
08:30
3/4/2023
08:45
0.25 COMPZN, CASING RUNL P RIH F/16,344' T/16,372' - tag bottom.
Space out liner hanger assy with shoe
at 16,370' as per Baker rep.
P/U 168K
S/O 112K
16,344.0 16,370.0
3/4/2023
08:45
3/4/2023
09:15
0.50 COMPZN, CEMENT RURD P R/U surface lines to cement head. 16,370.0 16,370.0
3/4/2023
09:15
3/4/2023
12:00
2.75 COMPZN, CEMENT CIRC P Circulate and condition mud staging
pump rate in 0.5 bpm increments to 4.3
bpm.
180 GPM
1,360 PSI
9.5 ppg MW
16,370.0 16,370.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 32/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/4/2023
12:00
3/4/2023
13:45
1.75 COMPZN, CEMENT PACK P Drop 1.5" liner setting ball and pump
down at 3 bpm at 1,010 psi for 150 bbls,
decreased to 2 bpm at 750 psi,
pressured up to 2,400 psi to set liner
hanger. S/O to 75K and confirmed set.
Pressured up to 3,480 psi and sheared
out ball seat. Bled off pressure, P/U 3
times to 175K and running tool was not
released. Mechanically released by
applying 2 rounds left hand rotation at
5K TQ, worked string and confirmed
running tool released. TOL at 7,139'.
P/U 155K
S/O 140K
16,370.0 16,370.0
3/4/2023
13:45
3/4/2023
15:45
2.00 COMPZN, CEMENT CIRC P Circulate staging rate up to 5.5 bpm w/
1,800 psi. PJSM for cement job.
16,370.0 16,370.0
3/4/2023
15:45
3/4/2023
18:45
3.00 COMPZN, CEMENT CMNT P Line up to Halliburton cement unit. Flood
lines with water. Test T/4,000 psi - good
test. Pumped 50 bbls 10.5 ppg spacer
@ 3.5 bpm, 650 psi, Mix and pump 228
bbls 15.3 ppg cement at 3-5 bpm, 700-
1,100 psi. Launch dart, pumped with rig
pump 12 bbls water, 125 bbls 9.5 ppg
Kla-Shield mud at 5 bpm, 2,150 psi
(slowed to 3 bpm and observed dart
latch at 3,139 psi (552 stks)), 20 bbls
10.5 ppg spacer, displace with 9.5 ppg
new treated mud at 4 bpm, 1,795 psi,
slowing to 2 bpm, 1,200 psi, bumping
plug at 1,928 stks (194 bbls), increased
to 500 psi over, 1,700 psi. held 5
minutes. Bled off pressure and floats
held. CIP @ 18:37 hrs on 3-4-2023.
16,370.0 16,370.0
3/4/2023
18:45
3/4/2023
19:15
0.50 COMPZN, CEMENT PACK P P/U and confirmed free travel, tool
released and rotating dog sub above
TOL at 7,139'. Set ZXP Liner Top
Packer per Baker Rep. Good indication
observed packer set when S/O while
rotating 40 rpm with dog sub, S/O to
75K weight applied 3 times. TOL @
7,139', Shoe @ 16,370'.
P/U 160K
S/O 110K
ROT 135K
16,370.0 7,139.0
3/4/2023
19:15
3/4/2023
20:30
1.25 COMPZN, CEMENT CIRC P Circulate 2 bottoms ups at 7,138'.
Pumped 5" wiper ball on second
circulation.
Note: 25 bbls cement inter phase to
surface - 11.4 ppg max weight, diverted
112 bbls total to rockwasher.
294-378 GPM
1700-2100 PSI
10 RPM
3K TQ
7,139.0 7,138.0
3/4/2023
20:30
3/4/2023
21:30
1.00 COMPZN, CEMENT RURD P L/D Baker cement head to pipe shed.
SIMOPS: Mix dry job.
7,138.0 7,138.0
3/4/2023
21:30
3/4/2023
21:45
0.25 COMPZN, CEMENT CIRC P Pump 30 bbls dry job at 5 bpm w/670
psi.
7,138.0 7,138.0
3/4/2023
21:45
3/5/2023
00:00
2.25 COMPZN, WELLPR PULD P POOH F/7,138' T/6,100' racking back 1
std DP and 5 std's HWDP, L/D excess
HWDP.
7,138.0 6,100.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 33/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/5/2023
00:00
3/5/2023
03:00
3.00 COMPZN, WELLPR PULD P POOH F/6,100' T/3,117' L/D excess
HWDP.
P/U 98K
6,100.0 3,117.0
3/5/2023
03:00
3/5/2023
04:45
1.75 COMPZN, WELLPR TRIP P POOH F/3,117' T/48' racking 4" DP in
derrick..
3,117.0 48.0
3/5/2023
04:45
3/5/2023
05:30
0.75 COMPZN, WELLPR BHAH P L/D Baker running tools.
Note: Tools had a cement skin on them.
48.0 0.0
3/5/2023
05:30
3/5/2023
06:30
1.00 COMPZN, WELLPR CLEN P Clear excess tools from floor and clean
same. Mobilize equipment and tools for
scraper BHA.
0.0 0.0
3/5/2023
06:30
3/5/2023
07:15
0.75 COMPZN, WELLPR CIRC P M/U stack washer and flush BOP with
black water, function upper and lower
rams and annular. Drain stack and fill
with 9.5 ppg Kla-Shield.
0.0 0.0
3/5/2023
07:15
3/5/2023
08:45
1.50 COMPZN, WELLPR BHAH P PJSM. M/U scraper BHA assy and
installed solid float. Check torque on all
connections as per Baker rep.
0.0 96.0
3/5/2023
08:45
3/5/2023
12:00
3.25 COMPZN, WELLPR TRIP P RIH F/96' T/4,620' on 4 stds 4" HWDP
and 4" DP.
S/O 98K
96.0 4,620.0
3/5/2023
12:00
3/5/2023
14:00
2.00 COMPZN, WELLPR TRIP P RIH F/4,620' T/6,600' on 4" DP.
P/U 130K
S/O 110K
4,620.0 6,600.0
3/5/2023
14:00
3/5/2023
17:30
3.50 COMPZN, WELLPR CIRC P Wash down F/6,600' T/7,157' (EOT).
Tag TOL at 7139' w/5K with nogo stab
as per Baker Rep. P/U to 7,137' staging
up rate to 715 gpm. Reciprocate
scraper F/7,137' T/6,950' while
circulating 2 bottoms ups.
210-330 GPM
580-1080 PSI
715 GPM
3650 PSI
6,600.0 7,157.0
3/5/2023
17:30
3/5/2023
19:30
2.00 COMPZN, WELLPR PRTS P B/D top drive. R/U and test casing / liner
top packer / liner to 3,500 psi f/30
minutes with 9.5 ppg mud. Pumped 5.1
bbls, bled back 5.5 bbls.Charted test -
good test.
7,011.0 7,011.0
3/5/2023
19:30
3/5/2023
20:15
0.75 COMPZN, WELLPR TRIP P RIH F/7,011 T/7,137'. SIMOPS: PJSM
on displacing to seawater,
7,011.0 7,137.0
3/5/2023
20:15
3/5/2023
21:00
0.75 COMPZN, WELLPR DISP P Pump 40 bbls Hi-Vis spacer and
displace 9.5 ppg Kla-Shield to 8.9 ppg
CI seawater + additives.
7,137.0 7,137.0
3/5/2023
21:00
3/5/2023
21:30
0.50 COMPZN, WELLPR OWFF P OWFF - static. 7,137.0 7,137.0
3/5/2023
21:30
3/5/2023
22:15
0.75 COMPZN, WELLPR PULD P L/D 1 stand 4" DP from derrick.
SIMOPS: Fill trip tank and prepare to lay
down pipe.
7,137.0 7,137.0
3/5/2023
22:15
3/6/2023
00:00
1.75 COMPZN, WELLPR PULD P POOH L/D 4" drill pipe F/7,137' T/5,400'
to pipe shed.
P/U 127K
7,137.0 5,400.0
3/6/2023
00:00
3/6/2023
04:45
4.75 COMPZN, WELLPR PULD P POOH L/D 4" drill pipe F/5,400' T/96' to
pipe shed.
P/U 127K
5,400.0 96.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 34/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/6/2023
04:45
3/6/2023
05:45
1.00 COMPZN, WELLPR BHAH P L/D scraper BHA as per Baker rep.
Removed float from float sub. Note:
Cleaned magnets (~2 LBS very fine
metal filings) and nothing recovered
from junk baskets. Scraper blade
profiles were packed with cement.
96.0 0.0
3/6/2023
05:45
3/6/2023
07:15
1.50 COMPZN, WELLPR WWWH P M/U StreamFlo wear bushing puller and
pull wear bushing as per StreamFlo rep.
M/U stack washer tool and flush BOP
and wellhead profile at 10 bpm, 40
RPM, 4 passes. L/D same to pipe shed.
B/D top drive.
0.0 0.0
3/6/2023
07:15
3/6/2023
10:30
3.25 COMPZN, RPCOMP RURD P Clean and clear rig floor excess
equipment. P/U Halliburton TEC wire
and spooler, Doyon casing tools and
ready all tools and equipment to run 4-
1/2" upper completion.
0.0 0.0
3/6/2023
10:30
3/6/2023
12:00
1.50 COMPZN, RPCOMP PUTB P PJSM. RIH T/256' w/4.5" 12.6# / L-80 /
HYD563 upper completion as per detail.
TQ to 3,800 ft/lbs. M/U ratchet mule
shoe locator assy, arsenal glass disk
sub (5,500 psi shear), landing nipple
assy,TNT production packer assy,gauge
mandrel assy and connect TEC wire as
per HES rep. Top filling every joint with
8.9 ppg seawater.
0.0 256.0
3/6/2023
12:00
3/6/2023
19:00
7.00 COMPZN, RPCOMP PUTB P RIH with 4 1/2" l-80/HYD 563 upper
completion as per detail F/256' T/3,493'
to jt # 80. Top filling every joint with 8.9
ppg seawater. Cable clamps ran on
every collar. Checking DHG every 50
joints.
S/O 85K
256.0 3,493.0
3/6/2023
19:00
3/6/2023
20:00
1.00 COMPZN, RPCOMP SVRG P Service rig. SIMOPS: work on skate
sensors.
3,493.0 3,493.0
3/6/2023
20:00
3/7/2023
00:00
4.00 COMPZN, RPCOMP PUTB P RIH with 4 1/2" l-80/HYD 563 upper
completion as per detail F/3,493'
T/5,837' to jt # 137. Top filling every joint
with 8.9 ppg seawater. Cable clamps
ran on every collar. Checking DHG
every 50 joints.
S/O 93K
3,493.0 5,837.0
3/7/2023
00:00
3/7/2023
02:00
2.00 COMPZN, RPCOMP PUTB P RIH with 4 1/2" l-80/HYD 563 upper
completion as per detail F/5,837'
T/7,067'. Top filling every joint with 8.9
ppg seawater. Cable clamps ran on
every collar. Checking DHG every 50
joints.
S/O 96K
5,837.0 7,067.0
3/7/2023
02:00
3/7/2023
03:45
1.75 COMPZN, RPCOMP THGR P Space out upper completion. Obtain P/U
121K, S/O 96K. RIH tag TOL with
locator and shear pins with 12K,
continue S/O to no-go confirmed w/10K.
Mark space out length and L/D joints
#170 to #168. Install 3.87' pup joint, P/U
joint #168 and RIH. P/U StreamFlo
tubing hanger w/ pup joint, M/U landing
joint with StreamFlo running tool as per
StreamFlo rep. Note: Spaced out for
locator to be 1.53' above TOL.
7,067.0 7,093.0
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 35/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/7/2023
03:45
3/7/2023
05:15
1.50 COMPZN, RPCOMP THGR P Feed through DHG wire through tubing
hanger as per HES and StreamFlo reps.
Test TEC wire swedgelocs through test
port to 5,000 pi f/10 minutes - good test.
SIMOPS: R/D tubing running
equipment, clean and clear rig floor
excess tools and equipment.
7,093.0 7,093.0
3/7/2023
05:15
3/7/2023
05:45
0.50 COMPZN, RPCOMP THGR P RIH and land out tubing hanger as per
StreamFlo rep. Locked in hanger and
pull test to confirmed locked.Test hanger
seals to 5,000 psi f/15 minutes - good
test.
S/O 95K
7,093.0 7,139.0
3/7/2023
05:45
3/7/2023
06:45
1.00 COMPZN, RPCOMP PRTS P Continue cleaning and clearing rig floor.
R/U squeeze manifold for testing and
prepare test equipment f/testing IA and
tubing.
7,139.0 7,139.0
3/7/2023
06:45
3/7/2023
09:00
2.25 COMPZN, RPCOMP PRTS P PJSM. Test surface lines to 4,550 psi.
Pressure up down tubing and set HES
TNT packer with 4,550 psi, held
F/15/min. Charted test with annulus
open. Bled down tubing to 2,650 psi.
Pressure test IA T/3,850 psi F/30
minutes, Charted test - good. Bled IA
and tubing to zero psi. Pressured up IA
to 3,000 psi and sheared SOV.
7,139.0 7,139.0
3/7/2023
09:00
3/7/2023
09:30
0.50 COMPZN, RPCOMP OWFF P OWFF - static. 7,139.0 7,139.0
3/7/2023
09:30
3/7/2023
10:00
0.50 COMPZN, RPCOMP RURD P R/D test equipment and lines from
testing IA and tubing.
7,139.0 7,139.0
3/7/2023
10:00
3/7/2023
11:00
1.00 COMPZN, WHDBOP RURD P L/D landing joint. Install HP-BPV as per
StreamFlo rep. Test HP-BPV direction of
flow through IA F/10 minutes. Charted
test - good.
7,139.0 7,139.0
3/7/2023
11:00
3/7/2023
12:00
1.00 COMPZN, WHDBOP MPDA P B/D all lines. N/D Beyond MPD
equipment and preparing to pull trip
nipple.
7,139.0 7,139.0
3/7/2023
12:00
3/7/2023
15:00
3.00 COMPZN, WHDBOP MPDA P PJSM. N/D Beyond MPD equipment,
RCD head, orbit valve, adapter, test
plug, flow box, flow line and pull trip
nipple.
7,139.0 7,139.0
3/7/2023
15:00
3/7/2023
19:45
4.75 COMPZN, WHDBOP NUND P Remove rams from BOP. Remove
koomey lines. Rack back BOP on
stump.
7,139.0 7,139.0
3/7/2023
19:45
3/7/2023
22:30
2.75 COMPZN, WHDBOP WWWH P N/D StreamFlo wellhead adapter. N/U
StreamFlo tree adapter and test to
5,000 psi f/10 minutes - good test,
witnessed by CPAI. Halliburton tied in
TEC wire for DHG through adapter and
installed gauge.
7,139.0 7,139.0
3/7/2023
22:30
3/8/2023
00:00
1.50 COMPZN, WHDBOP WWWH P M/U 10K Frac tree to adapter and wing
valves. Install gauges and flanges on IA.
7,139.0 7,139.0
3/8/2023
00:00
3/8/2023
01:15
1.25 COMPZN, WHDBOP NUND P Cont NU 10K frac tree, MU wing valves,
fill tree with diesel, RU to test tree
7,139.0 7,139.0
3/8/2023
01:15
3/8/2023
02:30
1.25 COMPZN, WHDBOP PRTS P Test frac tree to 250/5,000 psi for 15
min, good, With IA open, bleed off psi
and confirm 0 psi, RD test equip and
prep to pull test dart/HP-BPV
3/8/2023
02:30
3/8/2023
03:00
0.50 COMPZN, WHDBOP NUND P Pull tree test dart and HP-BPV per
StreamFlo rep
3/8/2023
03:00
3/8/2023
04:00
1.00 COMPZN, WHDBOP FRZP P RU to freeze protect well with LRS,
pressure test lines to 2000 psi, good.
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 36/36
3S-704
Report Printed: 4/3/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/8/2023
04:00
3/8/2023
07:30
3.50 COMPZN, WHDBOP FRZP P Pump 91 bbls diesel taking returns to
rockwasher, 1.25 bpm at 510 psi. U-tube
well to balance for 30 min, shut in well
and RD lines
3/8/2023
07:30
3/8/2023
08:15
0.75 COMPZN, WHDBOP MPSP P Set "H" BPV per StreamFlo rep
3/8/2023
08:15
3/8/2023
09:00
0.75 DEMOB, MOVE DMOB P Install gauges on tree/annulus valves,
close all valves, secure well.
Final Pressures: O/A=0 psi, I/A=0 psi,
Tbg=0 psi
Release rig at 0900 Hrs
Rig: DOYON 19
RIG RELEASE DATE 3/8/2023
Page 1/1
3S-704
Report Printed: 4/3/2023
Cement
Cement Details
Description
Surface String Cement
Cementing Start Date
2/12/2023 03:30
Cementing End Date
2/12/2023 09:00
Wellbore Name
3S-704
Comment
Pumped 62.4 BBLS 10.2 spacer with Pol-E-Flake and red dye added first 20 BBLS , had full returns up to 450 BBLS in to lead CMT , then lost returns pumped
118 more BBLS lead for a total of 568 BBLS 10.7 PPG Artic grade cement with 2.5 LBS/SK Bridgemaker , pumped 52.2 BBLS 15.8 PPG tail CMT with 5 LBS/SK
Bridgemaker, 20 BBLS H2O , chase with 285 BBLS mud , no returns , total lost 475.2 BBLS , bump plugs @ 2830 STKS , floats hold
Cement Stages
Stage # 1
Description
Surface String Cement
Objective
Cement 10 3/4" CSG to
surface
Top Depth (ftKB)
1,062.0
Bottom Depth (ftKB)
3,292.7
Full Return?
No
Vol Cement …
0.0
Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
4
Q Pump Final (bbl/…
1
Q Pump Avg (bbl/…P Pump Final (psi)
850.0
P Plug Bump (psi)
850.0
Recip?
No
Stroke (ft) Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB)
3,193.0
Tag Method
Drill Bit
Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
9 7/8
Comment
Pumped 62.4 BBLS 10.2 spacer with Pol-E-Flake and red dye added first 20 BBLS , had full returns up to 450 BBLS in to lead CMT , then lost returns pumped
118 more BBLS lead for a total of 568 BBLS 10.7 PPG Artic grade cement with 2.5 LBS/SK Bridgemaker , pumped 52.2 BBLS 15.8 PPG tail CMT with 5 LBS/SK
Bridgemaker, 20 BBLS H2O , chase with 285 BBLS mud , no returns , total lost 475.2 BBLS , bump plugs @ 2830 STKS , floats hold
Cement Fluids & Additives
Fluid
Fluid Type
Lead Cement
Fluid Description Estimated Top (ftKB)
1,062.0
Est Btm (ftKB)
2,792.0
Amount (sacks)
1,093
Class
G
Volume Pumped (bbl)
568.7
Yield (ft³/sack)
2.92
Mix H20 Ratio (gal/sack)
14.93
Free Water (%) Density (lb/gal)
10.70
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Fluid
Fluid Type
Tail Cement
Fluid Description Estimated Top (ftKB)
2,792.0
Est Btm (ftKB)
3,292.7
Amount (sacks)
251
Class
G
Volume Pumped (bbl)
52.2
Yield (ft³/sack)
1.16
Mix H20 Ratio (gal/sack)
5.08
Free Water (%) Density (lb/gal)
15.80
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Surface String Cement
Page 1/1
3S-704
Report Printed: 4/3/2023
Cement
Cement Details
Description
Intermediate String 1 Cement
Cementing Start Date
2/23/2023 02:45
Cementing End Date
2/23/2023 05:00
Wellbore Name
3S-704
Comment
Drop bottom plug , pump 59 BBLS 12.5 PPG spacer , drop bottom plug , pump 62.5 BBLS 15.3 lead CMT Bridgemaker II LCM in the first 41 BBLS , drop top
plug , pump 10 BBLS H2O , chase with 319.5 BBLS 9.6 PPG mud . plugs bump at 319.5 BBLS 3170 STKS , PSI up 500 over T/1300 F/5 min , bleed off check
floats
Cement Stages
Stage # 1
Description
Intermediate String 1
Cement
Objective Top Depth (ftKB)
6,249.0
Bottom Depth (ftKB)
7,316.2
Full Return?
Yes
Vol Cement …
0.0
Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
3
Q Pump Final (bbl/…
2
Q Pump Avg (bbl/…
3
P Pump Final (psi)
420.0
P Plug Bump (psi)
800.0
Recip?
Yes
Stroke (ft) Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
Drop bottom plug , pump 59 BBLS 12.5 PPG spacer , drop bottom plug , pump 62.5 BBLS 15.3 lead CMT Bridgemaker II LCM in the first 41 BBLS , drop top
plug , pump 10 BBLS H2O , chase with 319.5 BBLS 9.6 PPG mud . plugs bump at 319.5 BBLS 3170 STKS , PSI up 500 over T/1300 F/5 min , bleed off check
floats
Cement Fluids & Additives
Fluid
Fluid Type
Lead Cement
Fluid Description Estimated Top (ftKB)
6,249.0
Est Btm (ftKB)
7,316.2
Amount (sacks)
293
Class
G
Volume Pumped (bbl)
62.5
Yield (ft³/sack)
1.24
Mix H20 Ratio (gal/sack)
5.58
Free Water (%) Density (lb/gal)
15.30
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Intermediate String 1 Cement
Page 1/1
3S-704
Report Printed: 4/3/2023
Cement
Cement Details
Description
Production String 1 Cement
Cementing Start Date
3/4/2023 15:45
Cementing End Date
3/4/2023 18:45
Wellbore Name
3S-704
Comment
Pumped 50 bbls 10.5 ppg spacer, followed by 228 bbls 15.3 ppg lead cement, released dart, rig pumped 10 bbls water, 125 bbls 9.5 ppg mud, 20 bbls 10.5 ppg
space, 38 bbls 9.5 ppg mud bumping plug to 1,757 psi. Total displacement = 193 bbls. Floats held. Good returns during job.
Cement Stages
Stage # 1
Description
Production String 1
Cement
Objective Top Depth (ftKB)
7,139.0
Bottom Depth (ftKB)
16,370.0
Full Return?
Yes
Vol Cement …
25.0
Top Plug?
Yes
Btm Plug?
No
Q Pump Init (bbl/m…
4
Q Pump Final (bbl/…
2
Q Pump Avg (bbl/…
4
P Pump Final (psi)
1,168.0
P Plug Bump (psi)
1,757.0
Recip?
No
Stroke (ft) Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
Observed dart latch in wiper plug with 3,139 psi, dart pass Alpha sleeves, 1st - 1,421 psi and 2nd - 1,437 psi, bumped plug at 193 bbls with 1,168 psi, increased
to 1,757 psi. float held. Good returns during job.
Cement Fluids & Additives
Fluid
Fluid Type
Lead Cement
Fluid Description Estimated Top (ftKB)
7,139.0
Est Btm (ftKB)
16,370.0
Amount (sacks)
1,100
Class Volume Pumped (bbl)
228.0
Yield (ft³/sack)
1.24
Mix H20 Ratio (gal/sack)
5.56
Free Water (%) Density (lb/gal)
15.30
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Production String 1 Cement
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CDW 04/17/2023
AOGCC
RBDMS JSB 040623
50-103-20848-00-00 SFD
VTL 3/25/25 DSR-4/6/23
4 SFD
SFD 3/25/2025
Prepared By:
Keegan Lambe
James Campbell
Nannook Crew
Intervals 1-17
Notice: Although the information contained in this report is based on sound engineering practices, the
copyright owner(s) does (do) not accept any responsibility whatsoever, in negligence or otherwise, for any
loss or damage arising from the possession or use of the report whether in terms of correctness or
own risk.
3S-704
Conoco Phillips
Harrison Bay County, AK
Post Job Report
Stimulation Treatment
API: 50-103-20848
Prepared for: Dustin Morrow
March 29, 2023
Coyote Formation
25# Delta Frac
Table of Contents
Section Page(s)
Executive Summary
Wellbore Information
Actual Design
Interval Summary
Fluid System-Proppant Summary
Interval 1 Plots
Interval 2 Plots
Interval 3 Plots
Interval 4 Plots
Interval 5 Plots
Interval 6 Plots
Interval 7 Plots
Interval 8 Plots
Interval 9 Plots
Interval 10 Plots
Interval 11 Plots
Interval 12 Plots
Interval 13 Plots
Interval 14 Plots
Interval 15 Plots
Interval 16 Plots
Interval 17 Plots
Appendix
Well Summary
Chemical Summary
Planned Design
Water Straps 3-19
Water Straps 3-21
Water Straps 3-22
Water Straps 3-23
Water Straps 3-24
Water Straps 3-25
Water Straps 3-27
Water Straps 3-28
Water Straps 3-29
Water Analysis 3-18
Water Analysis 3-20
Water Analysis 3-22
Water Analysis 3-23
Water Analysis 3-24
Water Analysis 3-25
Water Analysis 3-26
Water Analysis 3-28
Water Analysis 3-29
Real-Time QC
Prejob Break Test Day 1
Event Log 3-19
Event Log 3-21
Event Log 3-22
Event Log 3-23
Event Log 3-24
Event Log 3-25
Event Log 3-27
Event Log 3-28
Event Log 3-29
Fann 15 Min Test Interval 1
Fann 15 Min Test Interval 2
Fann 15 Min Test Interval 3
Fann 15 Min Test Interval 4
Fann 15 Min Test Interval 5
Fann 15 Min Test Interval 6
Fann 15 Min Test Interval 7
Fann 15 Min Test Interval 8
Fann 15 Min Test Interval 9
Fann 15 Min Test Interval 10
Fann 15 Min Test Interval 11
Fann 15 Min Test Interval 12
Fann 15 Min Test Interval 13
Fann 15 Min Test Interval 14
Fann 15 Min Test Interval 15
Fann 15 Min Test Interval 16
Fann 15 Min Test Interval 17
53 - 56
57 - 64
65 - 68
10 - 28
29
30 - 44
45 - 52
3
4
5 - 9
69 - 76
77 - 80
81 - 91
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96 - 102
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Conoco Phillips - 3S-704 TOC 2
1,281,126 gallons of 25# Delta Frac
285,780 gallons of 25# Linear
3,360 gallons of Seawater
15,540 gallons of Freeze Protect
5,032,272 pounds of Wanli 16/20 Ceramic
69,972 pounds of 100M
1,287,026 gallons of 25# Delta Frac
274,922 gallons of 25# Linear
4,010 gallons of Seawater
0 gallons of Freeze Protect
13,398 gallons of Potasium Formate
5,033,600 pounds of Wanli 16/20 Ceramic
66,000 pounds of 100M
Thank you,
Keegan Lambe Alexander Bentz
Senior Technical Professional Technical Professional
Halliburton Energy Services Halliburton Energy Services
Halliburton maintains a continuous quality improvement process and appreciates any comments or suggestions that you may
have. Halliburton again thanks you for the opportunity to perform service work on this well. We hope to be your solutions
provider for future projects.
Engineering Executive Summary
On March 19, 2023 a stimulation treatment was performed in the Coyote formation on the 3S-704 well in Harrison Bay
County, AK. The 3S-704 was a 17 stage Horizontal Sleeve Design. The proposed treatment consisted of:
The actual treatment fully completed 16 of 17 stages. 0 stages were skipped, 0 stage screened out and 1 stages were cut short
of design. The actual treatment consisted of:
A more detailed description of the actual treatment can be found in the attached reports. The following comments were provided
to summarize events and changes to the proposed treatment:
Interval 17 was cut short due to castles emptying before expected on the final day of pumping.
MO-67 was run as a 50-50 dilution to maintain ability to make adjustments to the fluid system.
Halliburton is strongly committed to quality control on location. Before and after each job all chemicals, proppants, and fluid
volumes are measured to assure the highest level of quality control. Tank fluid analysis, crosslink time, and break tests are
performed before each job in order to optimize the performance of the treatment fluids.
Interval 11 was unable to be stimulated through the sleeve. Eline perforated and interval 11 was pumped through the
perforations.
Conoco Phillips - 3S-704 Executive Summary 3
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Coyote
@ 16155 - 16157.78 ft 104.7 °F
Interval 2
Coyote
@ 15548.6 - 15551.38 ft 104.7 °F
Interval 3
Coyote
@ 15048.7 - 15051.48 ft 104.6 °F
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Interval 6
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@ 13009.7 - 13012.48 ft 104.4 °F
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Interval 8
Coyote
@ 12506.2 - 12508.98 ft 104.3 °F
Interval 9
Coyote
@ 11991.3 - 11994.08 ft 104.3 °F
Interval 10
Coyote
@ 11479.8 - 11482.58 ft 104.3 °F
Co
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Interval 11
Coyote
@ 10973.9 - 10976.68 ft 104.2 °F
Interval 12
Coyote
@ 10462.2 - 10464.98 ft 104.1 °F
Interval 13
Coyote
@ 9952.3 - 9955.08 ft 104.1 °F
Interval 14
Coyote
@ 9445.1 - 9447.88 ft 104 °F
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Interval 15
Coyote
@ 8928.8 - 8931.58 ft 103.9 °F
-
Fl
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25
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--
Interval 17
Coyote
@ 7897.5 - 7900.28 ft 103.7 °F
Interval 16
Coyote
@ 8413.4 - 8416.18 ft 103.9 °F
Co
n
o
c
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P
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9
3/19/23 18:05
3/19/23 22:20
255 min
NA bpm
NA psi
NA psi
NA bbl
22.4 bpm
2,882 psi
4,130 psi
20.9 bpm
2,523 psi
2,268 psi
3,730 psi
1,289 hhp
382 psi
415 psi
10.05 ppg
22 cP
86.2 F
8.8
2784 psi
0.653 psi/ft
2687 psi
2687 psi
2694 psi
295,965 lbs
5,817 lbs
301,782 lbs
301,782 lbs
90,863 gal 2,163 bbls
43,567 gal 1,037 bbls
4,010 gal 95 bbls
3,780 gal 90 bbls
40 gal 1 bbls
20,988 gal 500 bbls
9,057 gal 216 bbls
54,796 gal 1,305 bbls
11,525 gal 274 bbls
22,445 gal 534 bbls
4,510 gal 107 bbls
8,530 gal 203 bbls
6,549 gal 156 bbls
Wanli 16/20 Ceramic Pumped:
Proppant Summary
Proppant Laden Fluid Volume:
Displacement Volume:
Total Proppant Pumped* :
Average Visc:
Average Temp:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Max Rate:
Max Surface Pressure:
Max BH Pressure:
Interval Summary
3S-704 - Coyote - Interval 1
Interval Summary
Start Date/Time:
End Date/Time:
Average Missile Pressure:
Initial OA Pressure:
Average Surface Pressure:
Average Rate:
Max OA Pressure:
Minifrac Volume:
Average Missile HHP:
Initial BH Pressure (Breakdown):
Average BH Pressure:
Max Proppant Concentration:
Step Rate Test Volume:
Establish Stable Fluid Volume:
Pad Volume:
Conditioning Pad Volume:
ISDP:
Final Fracture Gradient:
Final 10 min:
Load Well Volume:
100M Pumped:
Final 15 min:
Proppant in Formation:
25# Delta Frac Volume:
25# Linear Volume:
Seawater Volume:
Final 5 min:
Dart/Ball Early :
Average pH:
Pump Time:
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Flush Volume:
Potasium Formate Volume:
Conoco Phillips - 3S-704 Interval Summary 10
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Wellhead opened at 952psi. Sheared the Arsenal Sleeve at 5588PSI on surface. Alpha sleeve
shifted at 6260psi. After pumping the intial step down and 100M scour, the acid stages were
determined to not be needed for interval 01. Shut down from 19:41 to 20:21 for pressure analysis.
Resumed pumping interval 01 at 20:21. Interval pumped to design.
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Interval Status:
Nate Brzezinski
David Martinez
Chad Burkett
Keegan Lambe
Conoco Phillips - 3S-704 Interval Summary 11
3/21/23 10:32
3/21/23 12:46
134 min
12.2 bpm
3,627 psi
5,169 psi
23 bbl
22.9 bpm
3,067 psi
4,340 psi
21.6 bpm
2,802 psi
2,594 psi
3,938 psi
1,481 hhp
214 psi
373 psi
10.40 ppg
23 cP
87.4 F
8.8
304,994 lbs
2,860 lbs
307,854 lbs
307,854 lbs
81,382 gal 1,938 bbls
9,328 gal 222 bbls
1,470 gal 35 bbls
9,328 gal 222 bbls
18,899 gal 450 bbls
57,336 gal 1,365 bbls
875 gal 21 bbls
4,272 gal 102 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Status:
Wellhead opened at 713psi. Dart was launched ahead of bringing on frac equipment. Interval
pumped to design.
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Chad Burkett
Keegan Lambe
Craig Karpinski
Michael Johnson
Kyle Metzgar
Wanli 16/20 Ceramic Pumped:
100M Pumped:
Total Proppant Pumped* :
25# Delta Frac Volume:
25# Linear Volume:
Pad Volume:
Proppant Laden Fluid Volume:
Spacer and Dart Drop Volume:
Average Visc:
Average Temp:
Average pH:
Interval Summary
Start Date/Time:
End Date/Time:
Pump Time:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Max Rate:
Max Surface Pressure:
Max BH Pressure:
Average Rate:
Average Missile Pressure:
Average Surface Pressure:
3S-704 - Coyote - Interval 2
Average BH Pressure:
Average Missile HHP:
Initial OA Pressure:
Max OA Pressure:
Max Proppant Concentration:
Proppant Summary
Proppant in Formation:
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Potasium Formate Volume:
Displace Dart to Seat Volume:
Establish Stable Fluid Volume:
Conoco Phillips - 3S-704 Interval Summary 12
3/21/23 12:46
3/21/23 15:36
170 min
12.1 bpm
3,699 psi
5,149 psi
24 bbl
23.9 bpm
2,643 psi
4,004 psi
22.0 bpm
2,535 psi
2,310 psi
3,665 psi
1,364 hhp
374 psi
417 psi
10.40 ppg
22 cP
92.9 F
8.7
2705 psi
0.636 psi/ft
2590 psi
2568 psi
2559 psi
296,403 lbs
2,933 lbs
299,336 lbs
299,336 lbs
80,999 gal 1,929 bbls
32,119 gal 765 bbls
22,579 gal 538 bbls
17,785 gal 423 bbls
57,505 gal 1,369 bbls
9,540 gal 227 bbls
5,709 gal 136 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Keegan Lambe
Craig Karpinski
Michael Johnson
Interval Status:
Initial dart seat was not observed. Backup dart was programed and launched ahead of the frac
pumps coming online. Backup Dart landed. Pad Volume was adjusted to 425bbl. Interval pumped
to design.
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Kyle Metzgar
Chad Burkett
Max Proppant Concentration:
Fluid Summary (by stage description)
Displace Dart to Seat Volume:
Pad Volume:
ISDP:
Final Fracture Gradient:
25# Delta Frac Volume:
100M Pumped:
Establish Stable Fluid Volume:
3S-704 - Coyote - Interval 3
End Date/Time:
Max BH Pressure:
Average Rate:
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Max Rate:
Max Surface Pressure:
Pump Time:
Initial Rate (Breakdown):
Max OA Pressure:
Initial Surface Pressure (Breakdown):
Start Date/Time:
Proppant Summary
Total Proppant Pumped* :
Proppant in Formation:
Fluid Summary (by fluid description)
Average Visc:
Wanli 16/20 Ceramic Pumped:
Average Missile HHP:
Average Temp:
Average Missile Pressure:
Average Surface Pressure:
Average BH Pressure:
Average pH:
Final 5 min:
25# Linear Volume:
Interval Summary
Proppant Laden Fluid Volume:
Initial OA Pressure:
Flush Volume:
Final 10 min:
Final 15 min:
Conoco Phillips - 3S-704 Interval Summary 13
3/22/23 11:25
3/22/23 13:36
131 min
12.5 bpm
3,348 psi
5,165 psi
20 bbl
22.9 bpm
2,554 psi
3,943 psi
21.2 bpm
2,356 psi
2,110 psi
3,587 psi
1,221 hhp
180 psi
269 psi
10.22 ppg
22 cP
79.8 F
8.6
295,671 lbs
3,676 lbs
299,347 lbs
299,347 lbs
76,096 gal 1,812 bbls
10,345 gal 246 bbls
1,260 gal 30 bbls
8,704 gal 207 bbls
17,801 gal 424 bbls
54,115 gal 1,288 bbls
1,641 gal 39 bbls
4,180 gal 100 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:Chad Burkett
Keegan Lambe
Craig Karpinski
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Interval Status:
Wellhead opened at 530psi. Dart was pumped ahead of the frac equipment coming online. Interval
pumped to design.
Michael Johnson
Displace Dart to Seat Volume:
Pad Volume:
Proppant Summary
Wanli 16/20 Ceramic Pumped:
Total Proppant Pumped* :
Average Surface Pressure:
100M Pumped:
Max OA Pressure:
Max Proppant Concentration:
Average Visc:
Initial Surface Pressure (Breakdown):
End Date/Time:
Average Rate:
Average Missile Pressure:
Average BH Pressure:
Average Missile HHP:
Max Surface Pressure:
Initial BH Pressure (Breakdown):
Pump Time:
Initial OA Pressure:
3S-704 - Coyote - Interval 4
Interval Summary
Start Date/Time:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Establish Stable Fluid Volume:
Dart/Ball Early :
Max Rate:
Average Temp:
Average pH:
25# Delta Frac Volume:
Potasium Formate Volume:
Initial Rate (Breakdown):
Max BH Pressure:
25# Linear Volume:
Proppant in Formation:
Proppant Laden Fluid Volume:
Spacer and Dart Drop Volume:
Conoco Phillips - 3S-704 Interval Summary 14
3/22/23 13:36
3/22/23 15:22
106 min
11.9 bpm
4,506 psi
6,265 psi
24 bbl
23.0 bpm
2,389 psi
3,793 psi
21.9 bpm
2,175 psi
1,935 psi
3,450 psi
1,166 hhp
241 psi
302 psi
10.09 ppg
21 cP
81.1 F
8.7
2601 psi
0.613 psi/ft
2585 psi
2583 psi
2572 psi
281,846 lbs
2,801 lbs
284,647 lbs
284,647 lbs
74,588 gal 1,776 bbls
18,463 gal 440 bbls
8,608 gal 205 bbls
17,837 gal 425 bbls
52,725 gal 1,255 bbls
9,855 gal 235 bbls
4,026 gal 96 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Summary
Final 10 min:
Final 15 min:
Proppant Summary
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Wanli 16/20 Ceramic Pumped:
Pad Volume:
25# Linear Volume:
100M Pumped:
3S-704 - Coyote - Interval 5
Average BH Pressure:
Initial OA Pressure:
Max Proppant Concentration:
Start Date/Time:
Average Rate:
Proppant in Formation:
Final 5 min:
Keegan Lambe
Flush Volume:
Craig Karpinski
Michael Johnson
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Chad Burkett
Pump Time:
Average Missile Pressure:
Max OA Pressure:
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Average Missile HHP:
Average Visc:
Max Surface Pressure:
Final Fracture Gradient:
ISDP:
Interval Status:
Dart dropped and pumped during main frac. Dart seat observed. Interval pumped to design.
Establish Stable Fluid Volume:
25# Delta Frac Volume:
Initial Surface Pressure (Breakdown):
Max Rate:
End Date/Time:
Max BH Pressure:
Average Surface Pressure:
Total Proppant Pumped* :
Initial Rate (Breakdown):
Average Temp:
Average pH:
Proppant Laden Fluid Volume:
Displace Dart to Seat Volume:
Conoco Phillips - 3S-704 Interval Summary 15
3/23/23 13:25
3/23/23 15:28
123 min
12.3 bpm
3,575 psi
4,898 psi
20 bbl
22.7 bpm
2,450 psi
3,793 psi
21.6 bpm
2,247 psi
2,020 psi
3,462 psi
1,187 hhp
139 psi
243 psi
10.43 ppg
21 cP
78.1 F
8.7
301,204 lbs
2,981 lbs
304,185 lbs
304,185 lbs
72,383 gal 1,723 bbls
9,806 gal 233 bbls
1,050 gal 25 bbls
8,348 gal 199 bbls
17,810 gal 424 bbls
51,339 gal 1,222 bbls
1,458 gal 35 bbls
3,234 gal 77 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Status:
Wellhead opened at 422psi on surface. Dart was dropped ahead of the frac equipment being
brought online. Dart seat observed. 100M ran out early from castle. Interval pumped to design.
Keegan Lambe
Craig Karpinski
Michael Johnson
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Greg Clayton
3S-704 - Coyote - Interval 6
Interval Summary
Average pH:
Proppant Summary
Fluid Summary (by fluid description)
Potasium Formate Volume:
Fluid Summary (by stage description)
Proppant Laden Fluid Volume:
Max Rate:
Average Missile Pressure:
Average Rate:
Establish Stable Fluid Volume:
Max OA Pressure:
Proppant in Formation:
Displace Dart to Seat Volume:
Wanli 16/20 Ceramic Pumped:
Average BH Pressure:
End Date/Time:
Max Surface Pressure:
Max BH Pressure:
Total Proppant Pumped* :
Average Surface Pressure:
Average Missile HHP:
Pump Time:
Initial Rate (Breakdown):
Average Visc:
Average Temp:
Initial OA Pressure:
Start Date/Time:
Spacer and Dart Drop Volume:
100M Pumped:
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Dart/Ball Early :
25# Delta Frac Volume:
25# Linear Volume:
Max Proppant Concentration:
Pad Volume:
Conoco Phillips - 3S-704 Interval Summary 16
3/23/23 15:28
3/23/23 17:18
110 min
12.3 bpm
3,222 psi
4,996 psi
21 bbl
22.2 bpm
2,248 psi
3,541 psi
21.4 bpm
2,095 psi
1,866 psi
3,315 psi
1,099 hhp
229 psi
284 psi
9.92 ppg
21 cP
76.2 F
8.7
2605 psi
0.616 psi/ft
2568 psi
2563 psi
2558 psi
295,606 lbs
4,712 lbs
300,318 lbs
300,318 lbs
76,055 gal 1,811 bbls
16,947 gal 404 bbls
7,734 gal 184 bbls
16,740 gal 399 bbls
53,235 gal 1,268 bbls
9,213 gal 219 bbls
6,080 gal 145 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Proppant Laden Fluid Volume:
Greg Clayton
Initial OA Pressure:
Max Proppant Concentration:
Final 5 min:
Proppant Summary
100M Pumped:
3S-704 - Coyote - Interval 7
End Date/Time:
Dart/Ball Early :
ISDP:
Average pH:
Interval Summary
Final Fracture Gradient:
Average Missile HHP:
Average BH Pressure:
Average Surface Pressure:
Max Rate:
Initial BH Pressure (Breakdown):
Start Date/Time:
Establish Stable Fluid Volume:
Flush Volume:
Total Proppant Pumped* :
Proppant in Formation:
Max Surface Pressure:
Max BH Pressure:
Average Rate:
Average Missile Pressure:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Max OA Pressure:
Wanli 16/20 Ceramic Pumped:
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Average Temp:
Interval Status:
Dart seat observed. Adjusted Pad to 400bbl per customer request. Interval pumped to design. Keegan Lambe
Craig Karpinski
Michael Johnson
25# Linear Volume:
25# Delta Frac Volume:
Pad Volume:
Displace Dart to Seat Volume:
Average Visc:
Final 10 min:
Final 15 min:
Pump Time:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Conoco Phillips - 3S-704 Interval Summary 17
3/24/23 12:03
3/24/23 15:35
212 min
12.3 bpm
2,980 psi
4,735 psi
7 bbl
22.1 bpm
2,190 psi
3,598 psi
20.7 bpm
2,022 psi
1,773 psi
3,276 psi
1,028 hhp
148 psi
255 psi
10.49 ppg
21 cP
72.5 F
8.7
295,841 lbs
3,612 lbs
299,453 lbs
299,453 lbs
81,184 gal 1,933 bbls
18,725 gal 446 bbls
1,386 gal 33 bbls
8,171 gal 195 bbls
16,808 gal 400 bbls
50,749 gal 1,208 bbls
1,582 gal 38 bbls
8,972 gal 214 bbls
7,332 gal 175 bbls
6,295 gal 150 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Fluid Summary (by stage description)
Average Temp:
Total Proppant Pumped* :
Average BH Pressure:
Potasium Formate Volume:
25# Delta Frac Volume:
3S-704 - Coyote - Interval 8
Interval Summary
Proppant Summary
Wanli 16/20 Ceramic Pumped:
100M Pumped:
Fluid Summary (by fluid description)
Wellhead opened at 558psi. Dart launched ahead of frac. Once dart was landed, minifrac was
pumped. Shut down after minifrac for pressure analysis. After the observation period, crosslink
was re-established. Interval pumped to design.
Keegan Lambe
Craig Karpinski
Michael Johnson
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Greg Clayton
Minifrac Volume:
Flush Volume:
Proppant in Formation:
Displace Dart to Seat Volume:
Establish Stable Fluid Volume:
Max BH Pressure:
Dart/Ball Early :
Max Rate:
Initial Surface Pressure (Breakdown):
Start Date/Time:
Average Rate:
Max Proppant Concentration:
Initial OA Pressure:
Average Missile Pressure:
Interval Status:
Average pH:
End Date/Time:
Pump Time:
Average Missile HHP:
Initial BH Pressure (Breakdown):
Average Surface Pressure:
Initial Rate (Breakdown):
Max Surface Pressure:
Max OA Pressure:
25# Linear Volume:
Average Visc:
Spacer and Dart Drop Volume:
Pad Volume:
Proppant Laden Fluid Volume:
Conoco Phillips - 3S-704 Interval Summary 18
3/24/23 15:35
3/24/23 17:19
104 min
12.4 bpm
3,402 psi
4,945 psi
13 bbl
22.4 bpm
2,024 psi
3,520 psi
21.4 bpm
1,977 psi
1,718 psi
3,247 psi
1,036 hhp
238 psi
256 psi
10.26 ppg
21 cP
68.9 F
8.7
2676 psi
0.635 psi/ft
2590 psi
2582 psi
2568 psi
296,938 lbs
2,608 lbs
299,546 lbs
299,546 lbs
70,698 gal 1,683 bbls
16,388 gal 390 bbls
7,844 gal 187 bbls
16,787 gal 400 bbls
51,155 gal 1,218 bbls
8,544 gal 203 bbls
2,756 gal 66 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Summary
ISDP:
Proppant Summary
Wanli 16/20 Ceramic Pumped:
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Average pH:
Proppant Laden Fluid Volume:
Displace Dart to Seat Volume:
25# Delta Frac Volume:
25# Linear Volume:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Keegan Lambe
Craig Karpinski
Greg Clayton
Establish Stable Fluid Volume:
Michael Johnson
3S-704 - Coyote - Interval 9
Flush Volume:
Pad Volume:
Interval Status:
Dart seat observed. Interval pumped to design.
Max Rate:
Start Date/Time:
End Date/Time:
Pump Time:
Average BH Pressure:
Average Temp:
Max Proppant Concentration:
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Max OA Pressure:
Average Surface Pressure:
Final 5 min:
Average Missile HHP:
Initial OA Pressure:
Max Surface Pressure:
Max BH Pressure:
Initial Rate (Breakdown):
Final 10 min:
Total Proppant Pumped* :
Average Visc:
Proppant in Formation:
Dart/Ball Early :
Average Rate:
Average Missile Pressure:
Final Fracture Gradient:
100M Pumped:
Final 15 min:
Conoco Phillips - 3S-704 Interval Summary 19
3/25/23 9:26
3/25/23 11:36
130 min
12.3 bpm
3,306 psi
4,836 psi
9 bbl
20.7 bpm
2,116 psi
3,554 psi
19.4 bpm
2,010 psi
1,761 psi
3,286 psi
955 hhp
196 psi
300 psi
10.13 ppg
20 cP
75.8 F
8.8
292,427 lbs
3,679 lbs
296,106 lbs
296,106 lbs
72,308 gal 1,722 bbls
8,971 gal 214 bbls
1,050 gal 25 bbls
7,574 gal 180 bbls
15,722 gal 374 bbls
53,256 gal 1,268 bbls
1,397 gal 33 bbls
3,330 gal 79 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Summary
Pump Time:
Initial Surface Pressure (Breakdown):
Max Rate:
Total Proppant Pumped* :
Proppant in Formation:
Fluid Summary (by fluid description)
25# Linear Volume:
Average Missile HHP:
Initial OA Pressure:
Max OA Pressure:
Max Proppant Concentration:
Initial BH Pressure (Breakdown):
Dart/Ball Early :
25# Delta Frac Volume:
Wanli 16/20 Ceramic Pumped:
Fluid Summary (by stage description)
Pad Volume:
Spacer and Dart Drop Volume:
Establish Stable Fluid Volume:
Keegan Lambe
Craig Karpinski
Michael Johnson
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Greg Clayton
End Date/Time:
Max Surface Pressure:
Max BH Pressure:
Average Visc:
Proppant Summary
Average Temp:
Average pH:
Average BH Pressure:
Initial Rate (Breakdown):
3S-704 - Coyote - Interval 10
Start Date/Time:
Interval Status:
Wellhead opened at 469psi on surface. Dart was dropped ahead of frac equipment bringing rate.
Displace Dart to Seat Volume:
Proppant Laden Fluid Volume:
Average Rate:
Average Missile Pressure:
Potasium Formate Volume:
Average Surface Pressure:
100M Pumped:
Conoco Phillips - 3S-704 Interval Summary 20
3/25/23 11:36
3/25/23 11:24
NA min
12.3 bpm
7,558 psi
9,632 psi
14 bbl
22.4 bpm
2,529 psi
3,838 psi
20.3 bpm
2,107 psi
1,897 psi
3,382 psi
1,047 hhp
207 psi
350 psi
8.39 ppg
21 cP
84.1 F
8.7
298,058 lbs
3,491 lbs
301,549 lbs
301,549 lbs
79,854 gal 1,901 bbls
32,781 gal 781 bbls
1,134 gal 27 bbls
16,239 gal 387 bbls
17,781 gal 423 bbls
58,180 gal 1,385 bbls
1,363 gal 32 bbls
16,542 gal 394 bbls
2,530 gal 60 bbls
Completed
Interval Summary
Proppant Summary
Fluid Summary (by fluid description)
Total Proppant Pumped* :
Proppant in Formation:
Pump Time:
Initial BH Pressure (Breakdown):
Dart/Ball Early :
25# Delta Frac Volume:
25# Linear Volume:
Max BH Pressure:
Average Rate:
Average BH Pressure:
Initial OA Pressure:
100M Pumped:
Interval Status:
Average Temp:
Wanli 16/20 Ceramic Pumped:
Average pH:
Fluid Summary (by stage description)
Step Rate Test Volume:
Displace Dart to Seat Volume:
Average Missile HHP:
3S-704 - Coyote - Interval 11
Establish Stable Fluid Volume:
Pad Volume:
Proppant Laden Fluid Volume:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Average Visc:
Spacer and Dart Drop Volume:
Average Surface Pressure:
Potasium Formate Volume:
Average Missile Pressure:
Max Surface Pressure:
Max Proppant Concentration:
Max OA Pressure:
Max Rate:
End Date/Time:
Start Date/Time:
Conoco Phillips - 3S-704 Interval Summary 21
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval 11 dart seated on 3/25 and immediately pressured out. Cycled pressure on dart in an
attempt to shift sleeve. On 3/25 the sleeve could not be shifted. Rigged off the well to allow for
Eline to run in hole. Eline perforated the well on 3/26. Performed a Step rate/Injection test ahead of
pumping frac. Reopened wellhead to 653psi. Reopened the well at 08:36 on 3/27. Backup dart
was dropped at 394bbl JSV on 3/27. No Backup dart land observed. Extended pad to 425bbl.
Adjusted higher proppant concentrations per customer request depending on pressure response.
Held 8ppg long until treatment proppant.
Keegan Lambe
Craig Karpinski
Michael Johnson
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Greg Clayton
Conoco Phillips - 3S-704 Interval Summary 22
3/25/23 11:24
3/25/23 13:16
112 min
12.2 bpm
3,480 psi
5,066 psi
13 bbl
22.3 bpm
2,055 psi
3,327 psi
19.8 bpm
1,721 psi
1,500 psi
3,028 psi
835 hhp
326 psi
362 psi
10.29 ppg
21 cP
78.6 F
8.7
2635 psi
0.627 psi/ft
2605 psi
2603 psi
2590 psi
296,608 lbs
3,768 lbs
300,376 lbs
300,376 lbs
71,817 gal 1,710 bbls
14,282 gal 340 bbls
6,731 gal 160 bbls
15,738 gal 375 bbls
53,443 gal 1,272 bbls
7,551 gal 180 bbls
2,636 gal 63 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Dart seat observed. Interval pumped to design. Keegan Lambe
Craig Karpinski
Michael Johnson
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Greg Clayton
3S-704 - Coyote - Interval 12
Interval Summary
Average pH:
Max Rate:
Initial OA Pressure:
Pump Time:
Start Date/Time:
Average Rate:
Average Missile Pressure:
Final Fracture Gradient:
Initial Rate (Breakdown):
Average BH Pressure:
Dart/Ball Early :
Max BH Pressure:
Max OA Pressure:
Max Proppant Concentration:
Average Visc:
End Date/Time:
Initial BH Pressure (Breakdown):
Average Missile HHP:
Initial Surface Pressure (Breakdown):
Interval Status:
Flush Volume:
Final 10 min:
Wanli 16/20 Ceramic Pumped:
25# Linear Volume:
Establish Stable Fluid Volume:
Proppant Laden Fluid Volume:
100M Pumped:
Max Surface Pressure:
Final 15 min:
Average Temp:
Average Surface Pressure:
Proppant Summary
Fluid Summary (by fluid description)
25# Delta Frac Volume:
Fluid Summary (by stage description)
Final 5 min:
Total Proppant Pumped* :
ISDP:
Displace Dart to Seat Volume:
Proppant in Formation:
Pad Volume:
Conoco Phillips - 3S-704 Interval Summary 23
3/28/23 8:35
3/28/23 10:37
122 min
12.2 bpm
3,192 psi
4,781 psi
8 bbl
21.9 bpm
2,239 psi
3,472 psi
19.1 bpm
1,810 psi
1,609 psi
3,074 psi
849 hhp
243 psi
314 psi
10.49 ppg
21 cP
83.3 F
8.8
295,554 lbs
3,360 lbs
298,914 lbs
298,914 lbs
73,711 gal 1,755 bbls
6,455 gal 154 bbls
1,008 gal 24 bbls
6,455 gal 154 bbls
15,699 gal 374 bbls
53,758 gal 1,280 bbls
1,360 gal 32 bbls
2,894 gal 69 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:Greg Clayton
Fluid Summary (by stage description)
Wellhead open pressure was 436psi. Dart was dropped ahead of frac injection. Keegan Lambe
Craig Karpinski
Michael Johnson
3S-704 - Coyote - Interval 13
Initial OA Pressure:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Max Surface Pressure:
Max Proppant Concentration:
Average Rate:
Average Missile Pressure:
Max BH Pressure:
Average BH Pressure:
Interval Summary
End Date/Time:
Proppant Summary
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Pump Time:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Max Rate:
Average Surface Pressure:
Start Date/Time:
Wanli 16/20 Ceramic Pumped:
Interval Status:
Max OA Pressure:
Average Visc:
Average pH:
25# Delta Frac Volume:
Average Missile HHP:
Proppant in Formation:
Proppant Laden Fluid Volume:
Average Temp:
Establish Stable Fluid Volume:
Total Proppant Pumped* :
Pad Volume:
Spacer and Dart Drop Volume:
Potasium Formate Volume:
25# Linear Volume:
100M Pumped:
Displace Dart to Seat Volume:
Fluid Summary (by fluid description)
Conoco Phillips - 3S-704 Interval Summary 24
3/28/23 10:45
3/28/23 12:34
109 min
12.5 bpm
4,545 psi
5,148 psi
10 bbl
21.0 bpm
1,707 psi
3,006 psi
20.2 bpm
1,573 psi
1,383 psi
2,897 psi
779 hhp
343 psi
380 psi
10.36 ppg
21 cP
72.2 F
8.7
2618 psi
0.625 psi/ft
2540 psi
2571 psi
2562 psi
298,308 lbs
2,941 lbs
301,249 lbs
301,249 lbs
77,724 gal 1,851 bbls
6,979 gal 166 bbls
5,777 gal 138 bbls
15,603 gal 372 bbls
53,398 gal 1,271 bbls
6,979 gal 166 bbls
2,946 gal 70 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Alexander Bentz
Craig Karpinski
Michael Johnson
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Greg Clayton
25# Delta Frac Volume:
Displace Dart to Seat Volume:
Proppant in Formation:
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Flush Volume:
Total Proppant Pumped* :
25# Linear Volume:
Proppant Laden Fluid Volume:
3S-704 - Coyote - Interval 14
Interval Summary
Final 10 min:
Average Visc:
Start Date/Time:
Initial OA Pressure:
Average Rate:
Average Missile Pressure:
Average Missile HHP:
Dart/Ball Early :
Max Surface Pressure:
ISDP:
Final Fracture Gradient:
Final 5 min:
Wanli 16/20 Ceramic Pumped:
Final 15 min:
Proppant Summary
Establish Stable Fluid Volume:
Initial BH Pressure (Breakdown):
100M Pumped:
Dart seat observed. Interval pumped to design.
Max Rate:
Max BH Pressure:
End Date/Time:
Pump Time:
Average pH:
Interval Status:
Average Surface Pressure:
Average BH Pressure:
Average Temp:
Pad Volume:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Max OA Pressure:
Max Proppant Concentration:
Conoco Phillips - 3S-704 Interval Summary 25
3/29/23 8:26
3/29/23 10:28
122 min
12.2 bpm
3,141 psi
4,903 psi
8 bbl
21.0 bpm
1,948 psi
3,243 psi
19.9 bpm
1,648 psi
1,412 psi
2,878 psi
804 hhp
207 psi
339 psi
10.29 ppg
21 cP
82.7 F
8.7
294,919 lbs
4,549 lbs
299,468 lbs
299,468 lbs
73,633 gal 1,753 bbls
5,777 gal 138 bbls
1,260 gal 30 bbls
5,777 gal 138 bbls
15,674 gal 373 bbls
53,170 gal 1,266 bbls
1,662 gal 40 bbls
3,127 gal 74 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Alexander Bentz
Craig Karpinski
Michael Johnson
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Greg Clayton
Interval Status:
Wellhead open pressure was 401 psi. Dart was dropped ahead of frac injection.
Potasium Formate Volume:
Establish Stable Fluid Volume:
3S-704 - Coyote - Interval 15
Interval Summary
Average Missile Pressure:
End Date/Time:
Max BH Pressure:
Max Rate:
Average Visc:
Average pH:
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Average BH Pressure:
Max Surface Pressure:
Initial OA Pressure:
Max OA Pressure:
Max Proppant Concentration:
Pump Time:
Initial Rate (Breakdown):
Start Date/Time:
Proppant Summary
Total Proppant Pumped* :
Proppant in Formation:
Average Surface Pressure:
100M Pumped:
Average Temp:
Average Rate:
Average Missile HHP:
Wanli 16/20 Ceramic Pumped:
Dart/Ball Early :
Displace Dart to Seat Volume:
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
25# Delta Frac Volume:
Pad Volume:
25# Linear Volume:
Proppant Laden Fluid Volume:
Spacer and Dart Drop Volume:
Conoco Phillips - 3S-704 Interval Summary 26
3/29/23 10:28
3/29/23 12:18
110 min
12.4 bpm
3,154 psi
4,778 psi
14 bbl
21.1 bpm
1,730 psi
2,956 psi
20.3 bpm
1,688 psi
1,325 psi
2,827 psi
840 hhp
314 psi
378 psi
10.20 ppg
20 cP
82.7 F
8.7
2642 psi
0.632 psi/ft
2538 psi
2509 psi
2486 psi
290,971 lbs
4,790 lbs
295,761 lbs
295,761 lbs
73,345 gal 1,746 bbls
11,337 gal 270 bbls
5,006 gal 119 bbls
15,687 gal 374 bbls
54,946 gal 1,308 bbls
6,331 gal 151 bbls
2,712 gal 65 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Alexander Bentz
Craig Karpinski
Michael Johnson
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Greg Clayton
Dart seat observed. Interval pumped to design. Shut down post frac to load sand prior to starting
Interval 17.
Flush Volume:
Proppant Laden Fluid Volume:
Interval Status:
3S-704 - Coyote - Interval 16
Pad Volume:
Max Surface Pressure:
Average Missile Pressure:
Interval Summary
Initial OA Pressure:
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Final Fracture Gradient:
Final 5 min:
Proppant Summary
Total Proppant Pumped* :
ISDP:
Final 10 min:
Average pH:
Max Rate:
25# Delta Frac Volume:
25# Linear Volume:
Wanli 16/20 Ceramic Pumped:
Average Temp:
Max BH Pressure:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Pump Time:
Average Surface Pressure:
Start Date/Time:
Average BH Pressure:
Average Rate:
End Date/Time:
Average Missile HHP:
Displace Dart to Seat Volume:
Final 15 min:
Max OA Pressure:
Max Proppant Concentration:
Average Visc:
Proppant in Formation:
Fluid Summary (by stage description)
Fluid Summary (by fluid description)
100M Pumped:
Establish Stable Fluid Volume:
Conoco Phillips - 3S-704 Interval Summary 27
3/29/23 14:46
3/29/23 16:27
101 min
12.4 bpm
3,097 psi
4,542 psi
74 bbl
21.1 bpm
2,744 psi
3,283 psi
19.7 bpm
1,829 psi
1,610 psi
3,031 psi
883 hhp
200 psi
316 psi
8.32 ppg
21 cP
84.4 F
8.7
2828 psi
0.679 psi/ft
2800 psi
2788 psi
2766 psi
185,514 lbs
5,191 lbs
190,705 lbs
190,705 lbs
60,386 gal 1,438 bbls
12,652 gal 301 bbls
5,430 gal 129 bbls
15,731 gal 375 bbls
41,843 gal 996 bbls
1,252 gal 30 bbls
5,970 gal 142 bbls
2,812 gal 67 bbls
Cut Short
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Start Date/Time:
End Date/Time:
Dart dropped ahead of frac injection. Shut down during pad to isolate leak on ePRV line. Sand
Castle emptied early on 8.00 PPG.
Alexander Bentz
Craig Karpinski
Michael Johnson
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Greg Clayton
3S-704 - Coyote - Interval 17
Interval Summary
Average pH:
ISDP:
Final Fracture Gradient:
Proppant Summary
Pump Time:
100M Pumped:
Average Visc:
Average Temp:
Max OA Pressure:
Average Surface Pressure:
Max Rate:
Initial OA Pressure:
Average Missile HHP:
Max BH Pressure:
Initial Surface Pressure (Breakdown):
Average Missile Pressure:
Max Surface Pressure:
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Final 5 min:
Average Rate:
Initial Rate (Breakdown):
Wanli 16/20 Ceramic Pumped:
Final 10 min:
Final 15 min:
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Establish Stable Fluid Volume:
Average BH Pressure:
25# Linear Volume:
Max Proppant Concentration:
Proppant Laden Fluid Volume:
Displacement Volume:
Total Proppant Pumped* :
Flush Volume:
Pad Volume:
Proppant in Formation:
25# Delta Frac Volume:
Displace Dart to Seat Volume:
Interval Status:
Conoco Phillips - 3S-704 Interval Summary 28
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29
222-I�fZ
TO: AOGCC
333 WEST 7T" SUITE 100
ANCH. AK. 99501
279-1433
OPERATOR: CPAI
SAMPLE TYPE: Dry Cuttings
SAMPLES SENT:
3S-704
6600-16372
2 Boxes
SENT BY: M. McCRACKEN
SAMPLE TRANSMITTAL
MAR 116 202'j
AGCC
DATE: March 16, 2023
AIR BILL: NIA
CPAI: 2023031601
CHARGE CODE: NIA
NAME: 3S-704
NUMBER OF BOXES: 2 Boxes
1 (6 H 2-
UPON RECEIPT OF THESE SAMPLES PLEASE NOTE ANY DISCREPANCIES AND RETURN A SIGNED COPY
OF THIS FORM TO:
CONOCOPHILLIPS, ALASKA
700 G ST
ATO-380
ANCHORAGE, AK. 99510
ATTN: MIKE McCRACKEN
Mike.mccracken@conocophillips.com
RECEIVED:
RBDMS JSB 032023
1
Regg, James B (OGC)
From:Rig 19 <rig19@doyondrilling.com>
Sent:Wednesday, March 1, 2023 9:24 AM
To:DOA AOGCC Prudhoe Bay; Ben Wedin; D19 Company Man; Drilling Engineer; Regg, James B (OGC);
Brooks, Phoebe L (OGC); Rig 19; Rig Adviser
Subject:Emailing: Doyon 19 BOP Test 2-23-23 3S 704.xlsx Witness for H2S/LEL sensor repair
Attachments:Doyon 19 BOP Test 2-23-23 3S 704.xlsx
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.
Rig 19 Tool pusher
Grant Neuharth
Rig: 907 670‐6098
Cell‐907 232‐9864
Your message is ready to be sent with the following file or link attachments:
Doyon 19 BOP Test 2‐23‐23 3S 704.xlsx
Note: To protect against computer viruses, e‐mail programs may prevent sending or receiving certain types of file
attachments. Check your e‐mail security settings to determine how attachments are handled.
KRU 3S-704PTD 2221420
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.:19 DATE:2/23/23
Rig Rep.:Rig Email:
Operator:
Operator Rep.:Op. Rep Email:
Well Name:PTD #2221420 Sundry #
Operation:Drilling:Workover:Explor.:X
Test:Initial:Weekly:Bi-Weekly:X Other:
Rams:250/4000 Annular:250/2500 Valves:250/4000 MASP:1555
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 13-5/8"P Pit Level Indicators P P
#1 Rams 1 3.5X6''P Flow Indicator P P
#2 Rams 1 Blinds P Meth Gas Detector P P
#3 Rams 1 3.5" X 6"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 1 3.125 P Time/Pressure Test Result
HCR Valves 2 3.125 P System Pressure (psi)3000 P
Kill Line Valves 1 3.125 P Pressure After Closure (psi)1400 P
Check Valve 0 NA 200 psi Attained (sec)28 P
BOP Misc 1 4" Kill line Demco P Full Pressure Attained (sec)187 P
Blind Switch Covers:All stations Yes
CHOKE MANIFOLD:Bottle Precharge:11 @ 1000 P
Quantity Test Result Nitgn. Bottles # & psi (Avg.):4 @ 2400 P
No. Valves 14 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 19 P
#1 Rams 7 P
Coiled Tubing Only:#2 Rams 15 P
Inside Reel valves 0 NA #3 Rams 7 P
#4 Rams NA
Test Results #5 Rams NA
#6 Rams NA
Number of Failures:0 Test Time:6.5 HCR Choke 1 P
Repair or replacement of equipment will be made within days. HCR Kill 1 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 2/22/23 10:17
Waived By
Test Start Date/Time:2/23/2023 15:30
(date)(time)Witness
Test Finish Date/Time:2/23/2023 22:00
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Guy Cook
Doyon
Tested Annular with 4" test joint 250/2500psi, 4'' and 4.5'' test joint UPR, LPR. 250/4000psi low/high 5 min each. Tested all other
componets 250/4000psi low/high 5 min each. Tested hydraulic choke & manual choke at 2000 psi. Bottle Precharge= 1000 psi.
Tested Upper and Lower Kelly Valves at 250/4000 psi low/high 5 min each. / 14 day BOPE test interval is granted for drilling 3S-
704 with Doyon 19. CPAI is to take advantage of opportunities to test BOPE to avoid extensions.
Jim Regg
Supervisor, Inspections
G.Neuharth, S.Tower
Conoco Phillips
A.Lundale, D. Pickworth
KRU 3S-704
Test Pressure (psi):
rig19@doyondrilling.com
d19cm@conocophillips.com
Form 10-424 (Revised 08/2022)2023-0223_BOP_Doyon19_KRU_3S-704
copy of approval authorizing 14-day BOPE test interval dated 2/20/2023 is in well file -- jbr
J. Regg; 6/13/2023
1
Regg, James B (OGC)
From:Brooks, Phoebe L (OGC)
Sent:Wednesday, February 22, 2023 3:25 PM
To:Rig 19
Cc:Regg, James B (OGC)
Subject:RE: Doyon Rig 19 bop test 2/16/2023
Attachments:Doyon 19 02-16-23 Revised.xlsx
Attached is a revised report for KRU 3S‐704. The Operation was changed to Exploratory per PTD #2221420. Please
update your copy.
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.
From: Rig 19 <rig19@doyondrilling.com>
Sent: Thursday, February 16, 2023 9:03 PM
To: DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Ben Wedin <bwedin@doyondrilling.com>; D19
Company Man <d19cm@conocophillips.com>; Drilling Engineer <Doyon19.OperationsEngineer@conocophillips.com>;
Regg, James B (OGC) <jim.regg@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Rig 19
<rig19@doyondrilling.com>; Rig Adviser <wscrigadvisor@conocophillips.com>
Subject: Doyon Rig 19 bop test 2/16/2023
Shane Michael
Rig 19 Tourpusher
907 670‐6098
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.
KRU 3S-704PTD 2221420
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.:19 DATE:2/16/23
Rig Rep.:Rig Email:
Operator:
Operator Rep.:Op. Rep Email:
Well Name:PTD #2221420 Sundry #
Operation:Drilling:Workover:Explor.:X
Test:Initial:X Weekly:Bi-Weekly:Other:
Rams:250/4000 Annular:250/2500 Valves:250/4000 MASP:1555
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 13-5/8"P Pit Level Indicators P P
#1 Rams 1 3.5" X 6"P Flow Indicator P P
#2 Rams 1 Blinds P Meth Gas Detector P P
#3 Rams 1 3.5" X 6"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 1 3.125 P Time/Pressure Test Result
HCR Valves 2 3.125 P System Pressure (psi)2900 P
Kill Line Valves 1 3.125 P Pressure After Closure (psi)1475 P
Check Valve 0 NA 200 psi Attained (sec)31 P
BOP Misc 1 4" Kill line Demco P Full Pressure Attained (sec)151 P
Blind Switch Covers:All stations Yes
CHOKE MANIFOLD:Bottle Precharge:P
Quantity Test Result Nitgn. Bottles # & psi (Avg.):4 @ 2200 P
No. Valves 14 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 25 P
#1 Rams 7 P
Coiled Tubing Only:#2 Rams 14 P
Inside Reel valves 0 NA #3 Rams 7 P
#4 Rams 0 NA
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:0 Test Time:4.3 HCR Choke 1 P
Repair or replacement of equipment will be made within days. HCR Kill 1 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 2/13/23 22:45
Waived By
Test Start Date/Time:2/16/2023 9:00
(date)(time)Witness
Test Finish Date/Time:2/16/2023 13:15
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Kam StJohn
Doyon
Tested Annular with 5" test joint 250/2500psi, 3.5" x 6" UPR, LPR. 250/4000psi low/high 5 min each. Tested all other componets
250/4000psi low/high 5 min each. Tested hydraulic choke & manual choke at 1500 psi. Bottle Precharge=1000 psi. Tested Upper
and Lower Kelly Valves at 250/4000 psi low/high 5 min each.
O Williams, S.Michael
Conoco Phillips
A.Lundale, D. Pickworth
KRU 3S-704
Test Pressure (psi):
rig19@doyondrilling.com
d19cm@conocophillips.com
Form 10-424 (Revised 08/2022)2023-0216_BOP_Doyon19_KRU_3S-704
J. Regg; 6/12/2023
Doyon rig 19 BOPE Test
CPA well 3S-704 2/16/2023
Waived Witness by AOGCC rep, Kam St. John
All test 250/4000psi 5 charted min. each unless noted
5” test Joint
1. Annular preventer -250/2500psi
Top Pipe Rams 3.5” X 6” VBR’s 250/4000psi
2. Top pipe rams, 4” demco, Choke valves 1,12,13,14, 5” Dart Valve
3. HCR kill, Choke valves 9,11, 5” FOSV
4. Choke valves 5,8,10, IBOP,
5. Choke valves 4,6,7 Man. IBOP
6. Choke valve #2
7. HCR choke
8. Man. Choke, Man. Kill
Lower Pipe Rams 3.5” X 6” VBR’s
9. Lower pipe rams
Blind Rams
10. Blind rams, Choke valves 3,4,6
Super Choke and Man. Choke perform tests to 1500psi
11 A: Manual Choke
11B: Super Choke
1
Regg, James B (OGC)
From:Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>
Sent:Wednesday, February 22, 2023 5:40 PM
To:Regg, James B (OGC)
Cc:Loepp, Victoria T (OGC)
Subject:H2S Gas Detector on Doyon 19 (3S-704 (PTD 222-142))
Jim,
The failed H2S detector on Doyon 19 is working as of late this afternoon. The Company Rep has let the inspectors know.
I bring it up because we discussed it this morning and potential options if it could not be fixed.
Thank you!
Greg
Greg Hobbs, P.E.
Regulatory Engineer | Wells Team
ConocoPhillips Alaska Inc.
Office: 907 263 4749
Cell: 907 231 0515
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attachments unless you recognize the sender and know the content is safe.
1
Regg, James B (OGC)
From:Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>
Sent:Tuesday, February 21, 2023 5:08 PM
To:Regg, James B (OGC)
Cc:Loepp, Victoria T (OGC); DOA AOGCC Prudhoe Bay
Subject:H2S Gas Detector on Doyon 19 (3S-704 (PTD 222-142))
Jim,
I did mean Doyon 19. Sorry, I was filing data on 7es. Title corrected above.
The rig is now running down what is suspected to be a ground issue on the detector.
We will proceed as noted below and highlighted.
Thank you,
Greg
From:Regg, James B (OGC) <jim.regg@alaska.gov>
Sent:Tuesday, February 21, 2023 5:02 PM
To:Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>
Cc:Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; DOA AOGCC Prudhoe Bay
<doa.aogcc.prudhoe.bay@alaska.gov>
Subject:[EXTERNAL]RE: H2S Gas Detector on 7es (3S 704 (PTD 222 142))
CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you
recognize the sender and know the content is safe.
Did you mean Doyon 19? OK to proceed as noted below if detector does not test.
Jim Regg
Supervisor, Inspections
AOGCC
333 W. 7
th Ave, Suite 100
Anchorage, AK 99501
907 793 1236
From:Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>
Sent:Tuesday, February 21, 2023 4:55 PM
To:Regg, James B (OGC) <jim.regg@alaska.gov>
Cc:Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>
Subject:H2S Gas Detector on 7es (3S 704 (PTD 222 142))
OK to proceed as noted below if detector does not test.
2
Jim,
The BOP test went ok yesterday on Rig 7es with the exception of the H2S detector.
We have spent 12 hours troubleshooting the detector with the head being re built, a new head being installed, the cable
being checked, and now new boards are being installed. The testing of this final effort will be soon.
We are asking for permission to run and cement our Intermediate onelLiner.
Should the detector not test, the cellar will be manned with a sniffer. All hands wear H2S detectors also.
The work will continue on the Detector until it is functioning prior to drilling out the production interval.
Thank you,
Greg
Greg Hobbs, P.E.
Regulatory Engineer | Wells Team
ConocoPhillips Alaska Inc.
Office: 907 263 4749
Cell: 907 231 0515
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.
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________KUPARUK RIV UNIT 3S-704
JBR 04/04/2023
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:2
7 5/8" and 5" test joints used for testing. There was an issue with the gas detection system that disabled the H2S detector on
the bell nipple from working. After hours of troubleshooting it was determined it was the detection system and not the detector
or communication cable that was the issue. The rig will contact when the issue is resolved and the rig will not go to work until
the gas detection system is working properly.
Test Results
TEST DATA
Rig Rep:G. Newharth/S. MichaelOperator:ConocoPhillips Alaska, Inc.Operator Rep:A. Lundale/D. Pickworth
Rig Owner/Rig No.:Doyon 19 PTD#:2221420 DATE:2/21/2023
Type Operation:EXPL Annular:
250/2500Type Test:WKLY
Valves:
250/4000
Rams:
250/4000
Test Pressures:Inspection No:bopGDC230220082359
Inspector Guy Cook
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 12
MASP:
1555
Sundry No:
Control System Response Time (sec)
Time P/F
Housekeeping:P
PTD On Location P
Standing Order Posted P
Well Sign P
Hazard Sec.P
Test Fluid W
Misc NA
Upper Kelly 1 P
Lower Kelly 1 P
Ball Type 1 P
Inside BOP 1 P
FSV Misc 0 NA
14 PNo. Valves
1 PManual Chokes
1 PHydraulic Chokes
0 NACH Misc
Stripper 0 NA
Annular Preventer 1 13 5/8" 5000 P
#1 Rams 1 7 5/8" Solids P
#2 Rams 1 Blinds P
#3 Rams 1 3.5"x6" VBR P
#4 Rams 0 NA
#5 Rams 0 NA
#6 Rams 0 NA
Choke Ln. Valves 1 3 1/8" 5000 P
HCR Valves 2 3 1/8" 5000 P
Kill Line Valves 1 3 1/8" 5000 P
Check Valve 0 NA
BOP Misc 1 4" Kill Demco P
System Pressure P2900
Pressure After Closure P1450
200 PSI Attained P32
Full Pressure Attained P148
Blind Switch Covers:PAll Stations
Bottle precharge P
Nitgn Btls# &psi (avg)P4@2250
ACC Misc NA0
P PTrip Tank
P PPit Level Indicators
P PFlow Indicator
P PMeth Gas Detector
F FH2S Gas Detector
NA NAMS Misc
Inside Reel Valves 0 NA
Annular Preventer P14
#1 Rams P7
#2 Rams P7
#3 Rams P7
#4 Rams NA0
#5 Rams NA0
#6 Rams NA0
HCR Choke P1
HCR Kill P1
9
99
9
9999
9 9
9
RSHUDWRUQRWLILHG$2*&&WKDWUHSDLUVWRJDV
GHWHFWLRQFRPSOHWHG $2*&&IROORZXSLQVSHFWLRQ
MEU
issue with the gas detection system that disabled the H2S detector on
the bell nipple from working.
rig will contact when the issue is resolved
1
Regg, James B (OGC)
From:Regg, James B (OGC)
Sent:Monday, February 20, 2023 5:05 PM
To:Hobbs, Greg S
Cc:Loepp, Victoria T (OGC)
Subject:RE: 3S-704 (PTD 222-142) Between Well Maintenance report and 7 day BOP test interval variance
request
14 day BOPE test interval is granted for drilling 3S 704 with Doyon 19. CPAI is to take advantage of opportunities to test
BOPE to avoid extensions.
Jim Regg
Supervisor, Inspections
AOGCC
333 W. 7
th Ave, Suite 100
Anchorage, AK 99501
907 793 1236
From:Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>
Sent:Monday, February 20, 2023 7:57 AM
To:Regg, James B (OGC) <jim.regg@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>
Subject:RE: 3S 704 (PTD 222 142) Between Well Maintenance report and 7 day BOP test interval variance request
Good Morning Jim and Victoria,
Apologies for the disturbance on Presidents Day. We are coming out of the hole on the Intermediate one section of this
well and are planning on testing prior to the casing run to meet the 7 day BOP testing interval for the well as the casing
run could take us beyond the 7 day interval. We are then running casing and testing prior to drilling the production
section, now planned at three days later.
If the variance below is not approved, is a test at the start of our production section within a currently planned 9 day
interval approved?
This would eliminate a test at a 5 day interval, followed by a three day interval.
Thank you for the consideration,
Greg
From:Hobbs, Greg S
Sent:Thursday, February 16, 2023 2:28 PM
To:Regg, James B (CED) <jim.regg@alaska.gov>; Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>
Subject:3S 704 (PTD 222 142) Between Well Maintenance report and 7 day BOP test interval variance request
Jim and Victoria,
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attachments unless you recognize the sender and know the content is safe.
2
Attached, please find a between well maintenance report for Doyon 19 on the 3S 704 well.
An upper VBR front packer and top seals were replaced. This inspection follows a 60% first time BOP test pass rate of the
rig, and a 98.6% combined BOPE testing reliability in service to date.
I am requesting a variance to 20 AAC 25.035 e 10 B, the 7 day test interval of the BOP equipment on an exploration well,
to a 14 day test interval for 3S 704.
This was approved on CD4 594 (PTD 219 115), an infrastructure led exploratory well that was the second penetration
into an interval from a gravel pad with gravel access, analogous to the 3S Pad in Kuparuk.
The 3S 704 well will be the third penetration appraising the Coyote interval, preceded by a coil tubing Drilling
penetration and completion from 3S 24B (PTD 221 078), and a rotary penetration and completion from 3S 701A (PTD
222 134).
In addition, as a shallow interval penetrated prior to current appraisal by existing wells on the 3S pad, the pressure
characteristics of the interval are well understood.
Your consideration of this variance request is appreciated.
Greg
Greg Hobbs, P.E.
Regulatory Engineer | Wells Team
ConocoPhillips Alaska Inc.
Office: 907 263 4749
Cell: 907 231 0515
between well maintenance report
I am requesting a variance to 20 AAC 25.035 e 10 B,the 7 day test interval of the BOP equipment on an exploration well,
to a 14 day test interval for 3S 704.
3S 704 well will be the third penetration appraising the Coyote interval,
Dept.: CPA Drilling and Wells
Form Name: BWM Inspection Report
Appendix No.: D
Issue Date
TBD
Revision No.
0
Revision Date
16-Apr-2014
Prepared By
M. Kneale
Approved By
Level No.
Uncontrolled When Printed Page 1 of 12
Rig Name: Doyon 19 Report Date: 2/16/23
Equipment Involved: Annular, Single Gate x3, Choke Manifold, Manual Stack Valves,
HCR’s and Safety Valves
Share Point Address:
Manufacturer- Hydril Model #: 13 5/8” 5M Serial #: Hydril / 5M-BOP-Stack
Date/Time – Start: 02/15/23 @ 1730 Date/Time – End: 02/16/23 03:15
Total Days / Hours: 0 Days / 6 Hrs
Equipment Inspection Summary
Inspection Summary:
Annular & Element:
Inspected exterior of unit & hoses.
Element is clean and in good condition with no breaks or abnormalities. No oil leaks from worn/bad internal O-ring
seals.
Single Gate & Upper Pipe Rams:
Inspected exterior doors, hinges, operators, hoses, door seal, ram cavity and wear plate.
3 ½” x 6” VBR bodies, top seals & packers C/O seals and packers. No visible abnormalities or damage.
Single Gate & Middle Pipe Rams:
Inspected exterior doors, hinges, operators, hoses, door seal, ram cavity and wear plate.
Blind ram bodies, packers in good condition. No visible abnormalities or damage.
Single Gate & Lower Pipe Rams:
Inspected exterior doors, hinges, operators, hoses, door seal, ram cavity and wear plate.
3 ½” x 6” VBR bodies, top seals & packers in good condition. No visible abnormalities or damage.
Kill / Choke HCR, Manual Valves & Hoses, Choke Manifold:
Inspected exterior of valves, hydraulic hoses, fluid hoses and connections
All equipment in good condition, no visible leaks, loose bolts, connections, or issues.
5” 4.5 IF FOSV & Dart:
Inspected exterior of valves and functioned tested. No visible abnormalities or damage.
All equipment in good condition. Functions freely
Actions Taken:
Opened all ram doors and inspected upper and lower 3 ½” x 6” VBRs, and blind rams. C/O Upper VBR front packer and top
seals. Inspected all ram cavities, seals & rubbers. Inspected wear plates, as well as all sealing areas. Photographed all ram block
faces. All sealing rubbers and packers in good condition, no metal shavings, no oil leaks. Ram cavities were clear..
Visually inspected choke & kill HCR and manual valves, hoses and connections. Inspected choke manifold. Inspected FOSV
and Dart.
Dept.: CPA Drilling and Wells
Form Name: BWM Inspection Report
Appendix No.: D
Issue Date
TBD
Revision No.
0
Revision Date
16-Apr-2014
Prepared By
M. Kneale
Approved By
Level No.
Uncontrolled When Printed Page 2 of 12
List each Action Taken and inspection:
Item : 13-5/8” Annular Corresponding Root Cause: Inspection
Model and Sn#: 13 5/8" Hydril 5M GX Annular SN:
159125
Required Completion Date:BW’s
Completed by:Shane Michael Date Completed:02/16/23
Contractor Work Order #:
Required Action: None at this time
Item : Single Gate – UPR Corresponding Root Cause: Inspection
Model and Sn# 13 5/8" Hydril MPL 5M
SN: F837
Required Completion Date: BW’s
Completed by: Shane Michael Date Completed: 02/16/23
Contractor Work Order #:
Required Action: None at this time.
Item : Single Gate – MPR Corresponding Root Cause:Inspection
Model and SN 13 5/8" Hydril MPL 5M
SN: 165
Required Completion Date:BW’s
Completed by: Shane Michael Date Completed: 02/15/23
Contractor Work Order #:
Required Action: None at this time.
Dept.: CPA Drilling and Wells
Form Name: BWM Inspection Report
Appendix No.: D
Issue Date
TBD
Revision No.
0
Revision Date
16-Apr-2014
Prepared By
M. Kneale
Approved By
Level No.
Uncontrolled When Printed Page 3 of 12
Item : Single Gate - LPR
Corresponding Root Cause:Inspection
Model and SN 13 5/8" Hydril MPL 5M
SN: DM70636
Required Completion Date:BW’s
Completed by: Shane Michael Date Completed: 02/15/23
Contractor Work Order #:
Required Action:None at this time
Item : Annular Element Corresponding Root Cause:Inspection
Model and Sn# Required Completion Date: BW’s
Completed by: Shane Michael Date Completed: 02/16/22
Contractor Work Order #:
Required Action: None at this time.
Item : (UPR) 3 ½” x 6” VBR Corresponding Root Cause:Inspection
Model and Sn# Body: M7283-1
Top seal:
Face seal:
Body: M7283-2
Top seal:
Face seal:
Required Completion Date:
BW’s
Completed by: Shane Michael Date Completed: 02/16/22
Contractor Work Order #:
Required Action: Removed and replaced VBR top and front packer seals.
Item : Blind Rams Corresponding Root Cause: Inspection
Model and Sn# Body: N3926-1
Face Seal:
Body: N6926-2
Face Seal:
Required Completion Date:
BW’s
Completed by: Shane Michael Date Completed: 02/15/23
Contractor Work Order #:
Required Action: None at this time.
Dept.: CPA Drilling and Wells
Form Name: BWM Inspection Report
Appendix No.: D
Issue Date
TBD
Revision No.
0
Revision Date
16-Apr-2014
Prepared By
M. Kneale
Approved By
Level No.
Uncontrolled When Printed Page 4 of 12
Item : (LPR) 3 ½” x 6” VBR Corresponding Root Cause:Inspection
Model and SN Body: N6450-1
Top seal:
Face seal:
Body: N6820-1
Top seal:
Face seal:
Required Completion Date:
BW’s
Completed by: Shane Michael Date Completed:02/15/23
Contractor Work Order #:
Required Action: None at this time.
Dept.: CPA Drilling and Wells
Form Name: BWM Inspection Report
Appendix No.: D
Issue Date
TBD
Revision No.
0
Revision Date
16-Apr-2014
Prepared By
M. Kneale
Approved By
Level No.
Uncontrolled When Printed Page 5 of 12
Timeline Worksheet
Remediation Timeline From To Hours Date
Function & Inspect Annular 0300 0315 0.25 02/16/222
Open Upper Ram Doors, Clean & Inspect Pipe Rams, Close
Ram Doors
01:15 0230 1.75 02/16/22
Open Middle Ram Doors, Clean & Inspect Pipe Rams, Close
Ram Doors
1730 19:30 3.0 02/15/23
Open Lower Ram Doors, Clean & Inspect Pipe Rams, Close
Ram Doors
1930 2030 1. 02/15/23
List Personnel Conducting Investigation: Position
Team Member 1 Shane Michael Tourpusher
Team Member 2 Brandon Willard Driller
Team Member 3 Darren Young Floorhand
Team Member 4 Chris Edmunds Driller
Team Member 5 Larry Bennett Floorhand
Tool Pusher : Orville Williams, Shane Michael
CPA Company Rep: Andrew Lundale, Dusty Pickworth
Drilling Superintendent: Charles Broach
Prepared by: Shane Michael
Dept.: CPA Drilling and Wells
Form Name: BWM Inspection Report
Appendix No.: D
Issue Date
TBD
Revision No.
0
Revision Date
16-Apr-2014
Prepared By
M. Kneale
Approved By
Level No.
Uncontrolled When Printed Page 6 of 12
Annular
Upper Pipe Ram: 3 1/2” x 6” Variables
BOP-BLO-226 SN: M7283-2 (DS)
Dept.: CPA Drilling and Wells
Form Name: BWM Inspection Report
Appendix No.: D
Issue Date
TBD
Revision No.
0
Revision Date
16-Apr-2014
Prepared By
M. Kneale
Approved By
Level No.
Uncontrolled When Printed Page 7 of 12
Upper Pipe Ram: 3 1/2” x 6” Variables
BOP-BLO-225 SN: M7283-1 (ODS)
Dept.: CPA Drilling and Wells
Form Name: BWM Inspection Report
Appendix No.: D
Issue Date
TBD
Revision No.
0
Revision Date
16-Apr-2014
Prepared By
M. Kneale
Approved By
Level No.
Uncontrolled When Printed Page 8 of 12
Middle Pipe Ram: Blinds
BOP-BLO-328 SN: N6926-2 (DS)
Dept.: CPA Drilling and Wells
Form Name: BWM Inspection Report
Appendix No.: D
Issue Date
TBD
Revision No.
0
Revision Date
16-Apr-2014
Prepared By
M. Kneale
Approved By
Level No.
Uncontrolled When Printed Page 9 of 12
Middle Pipe Ram: Blinds
BOP-BLO-327 SN: N6926-1 (ODS)
Dept.: CPA Drilling and Wells
Form Name: BWM Inspection Report
Appendix No.: D
Issue Date
TBD
Revision No.
0
Revision Date
16-Apr-2014
Prepared By
M. Kneale
Approved By
Level No.
Uncontrolled When Printed Page 10 of 12
Dept.: CPA Drilling and Wells
Form Name: BWM Inspection Report
Appendix No.: D
Issue Date
TBD
Revision No.
0
Revision Date
16-Apr-2014
Prepared By
M. Kneale
Approved By
Level No.
Uncontrolled When Printed Page 11 of 12
Lower Pipe Ram: 3 1/2” x 6” Variables
BOP-BLO-319 SN: N6450-1 (DS)
Lower Pipe Ram: 3 1/2” x 6” Variables
BOP-BLO-319 SN: N6450-2 (DS)
Dept.: CPA Drilling and Wells
Form Name: BWM Inspection Report
Appendix No.: D
Issue Date
TBD
Revision No.
0
Revision Date
16-Apr-2014
Prepared By
M. Kneale
Approved By
Level No.
Uncontrolled When Printed Page 12 of 12
2023-0214_Surface_Csg_TopJob_KRU_3S-704_ae
Page 1 of 4
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg DATE: 2-17-2023
P. I. Supervisor
FROM: Adam Earl SUBJECT: Surface Casing Top Job
Petroleum Inspector KRU 3S-704
ConocoPhillips Alaska Inc.
PTD 2221420
2-14-2023: I traveled out to Doyon Rig 19 at KRU 3S-704 to witness a surface casing
cement top job. The cement stinger was ¾-inch Pac pipe with a 5/8-inch I.D. A 45-
degree mule shoe was run on-bottom to help rotate the top job string off anything on the
way down. The well’s 20-inch conductor was set at 120 feet MD RKB; the 10 ¾-inch
surface casing was set at 3293 feet MD RKB. There are 6 flute holes in the surface
casing hanger that were all options to run in with the stinger and the crews tried every
one of them with the same result – each run getting to just below the conductor base at
approximately 121 feet MD RKB.
CPAI was instructed by AOGCC to wash down as deep as possible before pumping the
cement top job. Doyon rig crew rotated the pipe manually while pumping water at 0.5 to
0.75 barrels per minute and reached the point of refusal at 315 feet MD RKB (297 feet
from ground level) after 20+ hours. A total of 415 bbls of water was used to wash down,
flushing the annulus almost 22 hours straight prior to the cement job. The 10.7ppg
cement was pumped, taking 28.5 barrels to get first sight of green cement back to
surface.
Attachments: Photos
9
9
9
9
9
James B. Regg Digitally signed by James B.
Regg
Date: 2023.06.08 13:49:26 -08'00'
2023-0214_Surface_Csg_TopJob_KRU_3S-704_aePage 2 of 4 Surface Casing Cement Top Job – KRU 3S-704 (PTD 2221420)Photos by AOGCC Inspector A. Earl2/14/2023¾-inch Pac string rig up for wash/cementingSurface casing fluted hanger
2023-0214_Surface_Csg_TopJob_KRU_3S-704_ae Page 3 of 4 ¾-inch Pac string run through surface casing hanger flute to wash down and cement conductor-surface casing annulus Pulling ¾-inch Pac string
2023-0214_Surface_Csg_TopJob_KRU_3S-704_aePage 4 of 4 Wash water returns while pumping cementTop Job cement returns to surface
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From:Rixse, Melvin G (OGC)
To:AOGCC Records (CED sponsored)
Subject:20230713 2122 APPROVAL for Surface Casing Top Job_ 3S-704
Date:Tuesday, February 14, 2023 9:29:06 AM
Attachments:image001.png
From: Rixse, Melvin G (OGC)
Sent: Monday, February 13, 2023 9:22 PM
To: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>
Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>
Subject: RE: 3S-704 surface cement Log
Greg,
CPAI is approved to perform a surface casing top job with 1” cementing string. AOGCC to witness that the cementing string is run as deep as possible and cement returns are seen at surface.
Mel Rixse
Senior Petroleum Engineer (PE)
Alaska Oil and Gas Conservation Commission
907-793-1231 Office
907-297-8474 Cell
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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov).
cc. AOGCC Inspectors, Jim Regg, Victoria Loepp
From: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>
Sent: Monday, February 13, 2023 8:25 PM
To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Subject: 3S-704 surface cement Log
Mel,
As discussed, here is the log of the surface cement job for the subject well.
A full report will be available tomorrow.
The rig is preparing for a top job. Do we have your approval?
Thank you,
Greg
Get Outlook for iOS
From: Tim Bales <TBales@slb.com>
Sent: Monday, February 13, 2023 8:09 PM
To: Smith, Matt <Matt.Smith2@conocophillips.com>; Doyon 19 Operations Engineer <Doyon19.OperationsEngineer@conocophillips.com>; AKA-CT-PSD@SLB.COM <aka-ct-psd@slb.com>; Robert Montgomery <RMontgomery@slb.com>
Cc: McCracken, Shane M <Shane.M.McCracken@conocophillips.com>; Doyon 19, Co-Man <d19cm@conocophillips.com>; Coates, David <Coates.Coates@conocophillips.com>; Vanderhorst, Mark J <Mark.J.Vanderhorst@conocophillips.com>; WSC
Rig Advisor <wscrigadvisor@conocophillips.com>; Surveillance Technician, WSC <WSC.SurveillanceTechnician@conocophillips.com>; Doherty, Dale R <Dale.R.Doherty@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Lee,
David L <David.L.Lee@conocophillips.com>
Subject: [EXTERNAL]RE: [Ext] Fwd: Overnight Plan / Logistics
Matt,
After our domain had a quick review and plotting the data on Techlog, looks like USIT is really struggling to identify the light weight 10.7ppg cement.
However, after closely inspecting VDL, Min, Max, Avg Acoustic Impedance and CBL measurements, we can say that we have cement/solid traces at least all the way through 1060ft. See screen shot of the log below for more clarification.
Call if you have any questions, our full report should be finalized tomorrow mid-morning.
Thanks,
Tim Bales
Alaska Sales
slb - Reservoir Performance
Office: 907-273-1706
Cell: 907-793-0188
www.slb.com
From: Smith, Matt <Matt.Smith2@conocophillips.com>
Sent: Monday, February 13, 2023 5:01 PM
To: Tim Bales <TBales@slb.com>; Doyon 19 Operations Engineer <Doyon19.OperationsEngineer@conocophillips.com>
Subject: [Ext] Fwd: Overnight Plan / Logistics
Tim, Please see distribution list below for sending the processed log tonight. As you'll see, operations are hinging on receiving your log and subsequent discussion with AOGCC. Please expedite as fast as possible. Thank you, Matt Smith 432-269-6432Tim,
Please see distribution list below for sending the processed log tonight. As you'll see, operations are hinging on receiving your log and subsequent discussion with AOGCC. Please expedite as fast as possible.
Thank you,
Matt Smith
432-269-6432
From: Doyon 19 Operations Engineer <Doyon19.OperationsEngineer@conocophillips.com>
Sent: Monday, February 13, 2023 4:29 PM
To: Doyon 19, Co-Man <d19cm@conocophillips.com>; Coates, David <Coates.Coates@conocophillips.com>; Smith, Matt <Matt.Smith2@conocophillips.com>; McCracken, Shane M <Shane.M.McCracken@conocophillips.com>; WSC Rig Advisor
<wscrigadvisor@conocophillips.com>; Surveillance Technician, WSC <WSC.SurveillanceTechnician@conocophillips.com>; Doherty, Dale R <Dale.R.Doherty@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Brillon, Chris L
<Chris.L.Brillon@conocophillips.com>; Lee, David L <David.L.Lee@conocophillips.com>; Vanderhorst, Mark J <Mark.J.Vanderhorst@conocophillips.com>
Subject: Overnight Plan / Logistics
Gents,
Logistics for this evening:
Andy – Begin loading 200 bbl top job cement and inform cementers of upcoming job. Inform AOGCC slope rep of intent to perform top job.
Matt – Inform SLB EWL to make sure final log is sent to all on this email (hopefully overnight tonight)
Andy/Dusty – As soon as log is received, mobilize cementers to location. Prepare rig for top job.
WSC Surv Tech – Once log received, call Greg Hobbs’ cell (907-231-0515). Send the final log to Melvin.rixse@alaska.gov
Greg – Let Melvin know that the log is available and we intend to proceed with top job with his concurrence. Ask that he reply all that we are OK to proceed.
Andy/Dusty – Proceed with pumping top job once AOGCC approval received (expected that slope rep will want to witness)
Please add any clarifications required.
Thanks,
Doyon 19 Operations Drilling Engineer
Ryan Ciolkosz / Keith Herring / Shane McCracken
907.301.9571
D19opseng@conocophillips.com
SLB-Private
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Chris Brillon
Wells Engineering Manager
ConocoPhillips Alaska, Inc
P.O. Box 100360
Anchorage, Alaska 99510-0360
Re: Kuparuk River Field, Undefined Oil Pool, 3S-704
ConocoPhillips Alaska, Inc
Permit to Drill Number: 222-142
Surface Location: 2474’ FNL, 876’ FEL NWSE S18 T12N R8E
Bottomhole Location: 1905’ FSL, 1032’ FWL, NWSW S30 T12N R8E
Dear Mr. Brillon:
Enclosed is the approved application for the permit to drill the above referenced well.
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well
logs run must be submitted to the AOGCC within 90 days after completion, suspension, or
abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first.
This permit to drill does not exempt you from obtaining additional permits or an approval required
by law from other governmental agencies and does not authorize conducting drilling operations
until all other required permits and approvals have been issued. In addition, the AOGCC reserves
the right to withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska
Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply
with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code,
or an AOGCC order, or the terms and conditions of this permit may result in the revocation or
suspension of the permit.
Sincerely,
Jessie L. Chmielowski
Commissioner
DATED this ___ day of December 2022. 16
Jessie L. Chmielowski
Digitally signed by Jessie L.
Chmielowski
Date: 2022.12.16 14:12:43 -09'00'
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By Anne Prysunka at 11:19 am, Oct 20, 2022
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BOP test to 4000 psig;
Annular preventer to 2500 psig
Diverter variance granted per 20 AAC 25.035(h)(2)
Intermediate II cement evaluation may use SonicScope under the attached Conditions of Approval
Surface casing LOT and annular LOT to the AOGCC as soon as available.
SFD 12/16/2022
X
VTL 12/16/2022GCW12/16/22
Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski
Date: 2022.12.16 14:12:56 -09'00'
KRU 3S-704
Conditions of Approval:
Approval is granted to run the LWD-Sonic on upcoming well with the following provisions:
1. CPAI will provide a written log evaluation/interpretation to the AOGCC along with the log as
soon as they become available. The evaluation is to include/highlight the intervals of competent
cement that CPAI is using to meet the objective requirements for annular isolation, reservoir
isolation, or confining zone isolation etc. Providing the log without an evaluation/interpretation
is not acceptable.
2. LWD sonic logs must show free pipe and Top of Cement, just as the e-line log does. CPAI must
start the log at a depth to ensure the free pipe above the TOC is captured as well as the TOC.
Starting the log below the actual TOC based on calculations predicting a different TOC will not
be acceptable.
3. CPAI will provide a cement job summary report and evaluation along with the cement log and
evaluation to the AOGCC when they become available
4. CPAI will provide the results of the FIT when available.
5. Depending on the cement job results indicated by the cement job report, the logs and the FIT,
remedial measures or additional logging may be required.
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Recommend approving requested variance of diverter requirement
based on examination of well records from Palm 1, Moraine 1,
3S-03, 3S-18, 3S-23, and 3S-613. SFD 12/16/2022
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