Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout222-019C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\I1OGWE08\2024-05-19_22605_CRU_CD4-597_InjectionProfile_Updated_Transmittal.docx
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AOGCC ***This update is to include the final report as well as the Emeraude folder***
Attn: Natural Resources Technician
333 W. 7th Ave., Suite 100
Anchorage, Ak. 99501-3539
Delivered By: CPAI Sharefile
______________________________ _____________________________________
Date received Signature
______________________________ ______________________________________
PLEASE RETURN COPY VIA EMAIL TO:
DIANE.WILLIAMS@READCASEDHOLE.COM
READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503
PHONE: (907)245-8951
E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM
222-019
T38874
Gavin Gluyas
Digitally signed by Gavin
Gluyas
Date: 2024.06.05 08:53:36
-08'00'
C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\I1OGWE08\2024-05-18_22605_CRU_CD4-597_CoilFlag_Transmittal.docx
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22605 CRU CD4-597 50-103-20839-00 Coil Flag 18-May-24
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AOGCC
Attn: Natural Resources Technician
333 W. 7th Ave., Suite 100
Anchorage, Ak. 99501-3539
Delivered By: CPAI Sharefile
______________________________ ______________________________________
Date received Signature
PLEASE RETURN COPY VIA EMAIL TO:
DIANE.WILLIAMS@READCASEDHOLE.COM
READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503
PHONE: (907)245-8951
E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM
222-019
T38847
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.05.28 10:14:54
-08'00'
C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\I1OGWE08\2024-05-19_22605_CRU_CD4-597_InjectionProfile_Transmittal.docx
DELIVERABLE DISCRIPTION
Ticket # Field Well # API # Log Description Log Date
22605 CRU CD4-597 50-103-20839-00 Injection Profile 19-May-24
DELIVERED TO
Company & Address
DIGITAL FILE
# of Copies
LOG PRINTS
# of Prints
CD’s
# of Copies
1
AOGCC
Attn: Natural Resources Technician
333 W. 7th Ave., Suite 100
Anchorage, Ak. 99501-3539
Delivered By: CPAI Sharefile
______________________________ ______________________________________
Date received Signature
PLEASE RETURN COPY VIA EMAIL TO:
DIANE.WILLIAMS@READCASEDHOLE.COM
READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503
PHONE: (907)245-8951
E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM
222-019
T38846
Gavin Gluyas
Digitally signed by Gavin
Gluyas
Date: 2024.05.24 11:27:12
-08'00'
PTD: 222-019
T38519
2/21/2024Kayla Junke
Kayla
Junke
Digitally signed
by Kayla Junke
Date: 2024.02.21
09:50:55 -09'00'
PTD: 222-019
T38519
2/21/2024Kayla Junke
Kayla
Junke
Digitally signed by
Kayla Junke
Date: 2024.02.21
09:48:56 -09'00'
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Wednesday, December 6, 2023
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Bob Noble
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
CD4-597
COLVILLE RIV UNIT CD4-597
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 12/06/2023
CD4-597
50-103-20839-00-00
222-019-0
W
SPT
4031
2220190 1500
223 223 221 221
467 566 455 535
INITAL P
Bob Noble
10/29/2023
30 MinPretestInitial15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:COLVILLE RIV UNIT CD4-597
Inspection Date:
Tubing
OA
Packer Depth
1275 2500 2450 2440IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitRCN231030162107
BBL Pumped:2.7 BBL Returned:2.7
Wednesday, December 6, 2023 Page 1 of 1
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1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________
2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number:
Exploratory Development
3. Address: Stratigraphic Service
6. API Number:
7. If perforating:8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?CD4-597
Will planned perforations require a spacing exception? Yes No
9. Property Designation (Lease Number): 10. Field: Current Pools:
Kuparuk River Field
Colville Delta - Narwhal
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD):
18350 4360 4360 1550 None None
Casing Collapse
Structural
Conductor
Surface 2260
Intermediate 3090
Intermediate 5410, 8530
Liner 7500
Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft):
12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations: OIL WINJ WDSPL Suspended
16. Verbal Approval: Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name:Baskoro Tejo
Contact Email:baskoro.tejo@cop.com
Contact Phone: 907-265-6462
Authorized Title: Completions Engineer
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other:
Post Initial Injection MIT Req'd? Yes No
Spacing Exception Required? Yes No Subsequent Form Required:
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
4306
4-1/2" 183506062
4-1/2"
4360
7"
20"
13-3/8"
120
2716
Perforation Depth MD (ft):
9-5/8"8324
7240. 11220
MD
5750
5020
120
2385
3447
120
2716
405912476
8324
Length Size
Proposed Pools:
TVD Burst
PRESENT WELL CONDITION SUMMARY
18350
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL380077, ADL384211, ADL380082,
ADL388903, ADL391587
222-019
P.O. Box 100360 Anchorage, Alaska, 99510-0360 50-103-20839-00-00
ConocoPhillips
8430
Tubing Grade: Tubing MD (ft):
LTP @ 12288' MD / 4031' TVD, Production
Packer @12195' MD/4020' TVD
Perforation Depth TVD (ft): Tubing Size:
L-80 10603
31-May-23
HAL TNT Prod Packer, Baker SLZXP
Packer/Hanger, No SSSV
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
AOGCC USE ONLY
Perforate
Reppair Well
Exploratory Stratigraphic Development Service
BOP Test Mechanical Integrity Test Location Clearance
No
No
Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
Feb 16, 2023
By Meredith Guhl at 7:44 am, Feb 17, 2023
323-101
DSR-2/22/23SFD 4/19/2023
Undefined Oil SFD 4/19/2023
18,340 4,355 SFD
10-404
X
CDW 04/19/2023
VTL 4/20/2023JLC 4/21/2023
04/21/2023
Brett W. Huber,
Sr.
Digitally signed by Brett W. Huber,
Sr.
Date: 2023.04.21 10:32:25 -08'00'
RBDMS JSB 042523
Section 1 - Affidavit 10 AAC 25.283 (a)(1)
Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators
within one-half mile radius of the current or proposed wellbore trajectory have been provided
notice of operations in compliance with 20 AAC 25.283(a)(1).
Section 2 – Plat 20 AAC 25.283 (2)(A)
Plat 1: Wells within 1/2 mile
Table 1: Wells within 1/2 miles (2)(C)
Well Name API Well Type Status Field Name Fluid Type Well in Frac Port 1/2 mi Buffer Open Interval in Frac Port 1/2 mi Buffer
CD4-499 501032081000 PROD ACTIVE QANNIK OIL
CD4-595 501032077800 PROD ACTIVE NARWHAL OIL YES YES
CD4-595PH 501032077870 EXPEND PA NARWHAL <Null> YES N/A
CD4-594 501032080700 INJ ACTIVE NARWHAL SW
CD4-594PH1 501032080770 EXPEND PA NARWHAL <Null>
CD4-318 501032051900 PROD PA NANUQ KUPARUK OIL
CD4-318A 501032051901 PROD ACTIVE NANUQ KUPARUK OIL
CD4-318PB1 501032051970 EXPEND PA NANUQ KUPARUK <Null>
CD4-320 501032053100 PROD ACTIVE NANUQ KUPARUK OIL
CD4-320PB1 501032053170 EXPEND PA NANUQ KUPARUK <Null>
CD4-319 501032051600 INJ ACTIVE NANUQ KUPARUK MWAG
CD4-321 501032053600 INJ ACTIVE NANUQ KUPARUK MWAG
CD4-302 501032054500 INJ ACTIVE NANUQ KUPARUK MWAG
CD4-306 501032055000 INJ ACTIVE NANUQ KUPARUK MWAG
CD4-322 501032055100 INJ ACTIVE NANUQ KUPARUK MWAG
CD4-304 501032055500 PROD ACTIVE NANUQ KUPARUK OIL
CD4-304PB1 501032055570 EXPEND PA NANUQ KUPARUK <Null>
CD4-301 501032055700 PROD PA NANUQ KUPARUK <Null>
CD4-301A 501032055701 PROD PA NANUQ KUPARUK <Null>
CD4-301B 501032055702 PROD ACTIVE NANUQ KUPARUK OIL
CD4-208 501032051700 INJ PA NANUQ MWAG
CD4-208PB1 501032051770 EXPEND PA NANUQ <Null>
CD4-209 501032053200 INJ ACTIVE NANUQ MWAG
NANUQ 3 501032036500 EXPLOR PA NANUQ <Null>
CD4-292 501032066900 PROD ACTIVE NANUQ OIL
CD4-291 501032067200 INJ ACTIVE NANUQ MWAG
CD4-291PB1 501032067270 EXPEND PA NANUQ <Null>
CD4-290 501032067400 PROD ACTIVE NANUQ OIL
CD4-289 501032069700 INJ ACTIVE NANUQ PW YES YES
CD4-210 501032053300 PROD PA NANUQ OIL
CD4-214 501032053700 INJ ACTIVE NANUQ MWAG
CD4-214L1 501032053760 INJ ACTIVE NANUQ MWAG
CD4-211 501032053800 PROD ACTIVE NANUQ OIL
CD4-211L1 501032053860 PROD ACTIVE NANUQ OIL
CD4-211L1-01 501032053861 PROD ACTIVE NANUQ OIL
CD4-215 501032053900 PROD ACTIVE NANUQ OIL
CD4-298 501032062300 PROD ACTIVE NANUQ OIL
CD4-298PB1 501032062370 EXPEND PA NANUQ <Null>
CD4-215L1 501032053960 PROD ACTIVE NANUQ OIL
CD4-213 501032054000 INJ PA NANUQ <Null>
NANUQ 5 501032041400 EXPLOR PA ALPINE <Null>
CD4-208A 501032051701 PROD ACTIVE ALPINE OIL
CD4-208AL1 501032051760 PROD ACTIVE ALPINE OIL
CD4-208APB1 501032051771 EXPEND PA ALPINE <Null>
CD4-12 501032041401 INJ ACTIVE ALPINE MWAG
CD4-12PB1 501032041470 EXPEND PA ALPINE <Null>
CD4-96 501032067300 PROD PA ALPINE OIL
CD4-96A 501032067301 PROD ACTIVE ALPINE OIL
CD4-96APB1 501032067370 EXPEND PA ALPINE <Null>
CD4-93 501032069000 PROD PA ALPINE <Null>
CD4-93A 501032069001 PROD ACTIVE ALPINE OIL
CD4-26 501032060000 INJ ACTIVE ALPINE MWAG
CD4-24 501032060200 INJ ACTIVE ALPINE MWAG
CD4-24PB1 501032060270 EXPEND PA ALPINE <Null>
CD4-24PB2 501032060271 EXPEND PA ALPINE <Null>
CD4-25 501032060800 PROD ACTIVE ALPINE OIL
CD4-25L1 501032060860 PROD ACTIVE ALPINE OIL
CD4-25PB1 501032060870 EXPEND PA ALPINE <Null>
CD4-210A 501032053301 PROD PA ALPINE <Null>
CD4-210B 501032053302 PROD ACTIVE ALPINE OIL
CD4-210APB1 501032053370 EXPEND PA ALPINE <Null>
CD4-17 501032053400 INJ ACTIVE ALPINE MWAG
CD4-16 501032053500 PROD ACTIVE ALPINE OIL
CD4-23 501032062100 PROD ACTIVE ALPINE OIL
CD4-23PB1 501032062170 EXPEND PA ALPINE <Null>
CD4-23PB2 501032062171 EXPEND PA ALPINE <Null>
CD4-213A 501032054001 INJ PA ALPINE <Null>
CD4-213B 501032054002 INJ ACTIVE ALPINE MWAG
CD4-213BPB1 501032054070 EXPEND PA ALPINE <Null>
CD4-213BPB2 501032054071 EXPEND PA ALPINE <Null>
CD2-77 501032062900 PROD ACTIVE ALPINE OIL
CD4-07 501032055300 PROD ACTIVE ALPINE OIL
CD4-03 501032064100 INJ ACTIVE ALPINE MWAG
CD4-05 501032055800 PROD ACTIVE ALPINE OIL
CD4-27 501032064400 INJ ACTIVE ALPINE MWAG
CD4-27PB1 501032064470 EXPEND PA ALPINE <Null>
CD4-27PB2 501032064471 EXPEND PA ALPINE <Null>
CD4-27PB3 501032064472 EXPEND PA ALPINE <Null>
Wells within 1/2 mile buffer of well track
* Data from SDE layer:
AK_WELL_BOTTOM_TD_ATDB_DD83
SECTION 3 – FRESHWATER AQUIFERS 20 AAC 25.283(a)(3)
There are no freshwater aquifers or underground sources of drinking water within a one-half
mile radius of the current or proposed wellbore trajectory.
See Conclusion number 3 of the Area Injection Order AIO 018.000- Colville River Field, Alpine
Oil Pool: Enhanced Recovery Project, which states “No underground sources of drinking water
(“USDWs”) exist beneath the permafrost in the Colville River Unit area.”
SECTION 4 – PLAN FOR BASELINE WATER SAMPLING FOR
WATER WELLS 20 AAC 25.283(a)(4)
There are no water wells located within one-half mile of the current or proposed wellbore
trajectory and fracturing interval. A water well sampling plan is not applicable.
SECTION 5 – DETAILED CEMENTING AND CASING INFORMATION
20 AAC 25.283(a)(5)
All casing is cemented and tested in accordance with 20 AAC 25.030.
See Wellbore schematic for casing details.
SECTION 6 – ASSESSMENT OF EACH CASING AND CEMENTING
OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE
WELL 20 AAC 25.283(a)(6)
Casing & Cement Assessments:
13 & 3/8” casing cement pump report on 08/05/2022 shows that the job was pumped as
designed, indicating competent cementing operations. The cement job was pumped with
11ppg DeepCRETE cement lead, followed by 15.8 ppg class G cement displaced with 8.33
ppg water. Full returns were seen throughout the job. The plug bumped at 869 psi and the
floats were checked and they held.
9 & 5/8” casing cement pump report on 08/19/2022 shows that the job was pumped as
designed, indicating competent cementing operations. The cement job was pumped with 15.8
ppg class G cement, displaced with 8.33 ppg water. The plug bumped at 939 psi and the floats
were checked and they held.
The 7” casing cement report on 08/31/2022 shows that the job was pumped as designed,
indicating competent cementing operations. The cement job was pumped with 13.0 ppg Class
G cement lead and 15.8 ppg class G cement tail. Full returns were seen throughout the job.
The plug bumped at 1062 psi and the floats were checked and they held.
Summary
All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone
penetrated by the well is isolated.
Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has
determined that this well can be successfully fractured within its design limits.
SECTION 7 – PRESSURE TEST INFORMATION AND PLANS TO PRESSURE-TEST
CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7)
On 08/07/2022 the 13-3/8” casing was pressure tested to 3,000 psi for 30 minutes
On 08/22/2022 the 9-5/8” casing was pressure tested to 3,000 psi for 30 minutes.
On 09/03/2022 the 7” casing was pressure tested to 3,500 psi for 30 minutes.
On 09/16/2022 the 4-1/2” tubing was pressure tested to 3,500 psi for 30 minutes.
On 09/16/2022 the 7” casing by 9-5/8” by 4.5 tubing annulus was pressure tested to 3,850
psi for 30 minutes.
AOGCC Required Pressures [all in psi]
Maximum Predicted Treating Pressure (MPTP) 6,125
Annulus pressure during frac 3,850
Annulus PRV setpoint during frac 3,600
7-5/8" Annulus pressure test 3,850
4-1/2" Tubing pressure Test 3,500
Electronic PRV 7,125
Highest pump trip 6,625
Max IA allowed is 3500 psi.
3,850 Error. CDW 04/19/2023
3,600
SECTION 8 – PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE,
WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8)
Table 2: Wellbore pressure ratings
Size Weight, ppf Grade API Burst, psi API Collapse, psi
13 & 3/8” 68 L-80 5,050 2,260
9 & 5/8” 40 L-80 5,750 3,090
7” 26 L-80 7,240 5,410
7” 29 TN-110S 11,220 8,530
4.5” 12.6 L-80 8,430 7,500
Stimulation Surface Rig-Up
Alpine 10K Frac Tree
SECTION 9 – DATA FOR FRACTURING ZONE AND CONFINING
ZONES 20 AAC 25.283(a)(9)
CPAI has formed the opinion, based on seismic, well, and other subsurface information
currently available that the fracturing zone consists of Cretaceous Brookian “Narwhal” Topset
Sands. The Narwhal interval is approximately 225’ TVD thick at the heel of the lateral,
thickening to >700’ TVD at the toe. The Narwhal reservoir is a very fine-grained quartz and
lithic rich sand, interbedded with mudstone and siltstone, with a coarsening upward log profile.
Top Narwhal was intersected at 12577’ MD, -4014.5’ TVDSS. The estimated fracture gradient
for the Narwhal reservoir is 10.9 ppg.
The overlying confining zone consists of greater than 1500’ TVD of Seabee Formation
(dominantly mudstones beginning at top of C-30, 2789’ MD, -2372’ TVDSS) and approximately
200’ TVD of Albian K3 (dominantly siltstones). The estimated fracture gradient for the Seabee
is 16-17 ppg and for the Albian K3 14.2 ppg.
The underlying confining zone consists of approximately 250’ TVD of Albian mudstones and
siltstones, based on nearby well control (CD4-595PH) and was not penetrated in the CD4-597
wellbore. The estimated fracture gradient for this interval is 16-17 ppg.
SECTION 10 – LOCATION, ORIENTATION AND A REPORT ON
MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT
CONFINING ZONE 20 AAC 25.283(a)(10)
The plat shows the location and orientation of each well that transects the confining zone.
ConocoPhillips has formed the opinion, based on following assessments for each well and
seismic, well, and other subsurface information currently available that none of these wells will
interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the
proposed wellbore trajectory.
Casing & Cement assessments for all wells that transect the confining zone:
CD4-595 PH: CD4-595 PH was plugged and abandoned per state regulations on 1/10/2019
CD4-595: The 7” intermediate 2 liner was cemented on 1/28/2019. The primary cement job
was pumped with 74.5 bbls of 13.5 ppg Class G cement lead and 21.5 bbls 15.8 ppg class G
cement tail. The plugs bumped and floats held during the job, with no losses to formation. A
Slim Cement Mapping Tool (SCMT) log was run on May 16th, 2019 and the top of good cement
is at 13,353 ftMD.
STATUSCasing SizeTop of Oil Pool (MD)Top of Oil Pool (TVDSS)Top of Cement (MD)Top of Cement (TVDSS)Top of Cement Determined ByReservoir Status Zonal IsolationCement Operations SummaryMechanical IntegrityPA 9 5/8" 16,275' 4,034' 14,677' 3,836' Tag PA as per AOGCC regulations4 P&A plugs with TOC @ 14,677'. 7" casing covering abandoned holePlug 1: 304 sx 15.8 ppg class G cement Plug 2: 306 sx 15.8 ppg class G cement Plug 3: 307 sx 15.8 ppg class G cement Plug 4: 328 sx 15.8 ppg class G cement1/27/19, 7" & 9 5/8" casing pressure tested to 2,000 psiACTIVE7" 16,275' 4,034' 13,353' 3,674' log ProducingTOC at 13,353' MD and Packer at 10,528' MD13.5 ppg class G cement lead and 15.8 ppg class G cement tail4/30/2019 9-5/8" intrm1 casing and 7" intrm2 liner test to 3,600 psi for 30 minutes
SECTION 11 – LOCATION OF, ORIENTATION OF AND GEOLOGICAL
DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE
CONFINING ZONES 20 AAC 25.283(a)(11)
CPAI has formed the opinion, based on seismic, well, and other subsurface information
currently available that two faults or fracture systems transect the confining zone within one
half mile radius of the wellbore trajectory for CD4-597. The first faut intersected the CD4-597
well path at 6745’ MD and the second fault intersected at 17148’ MD. Both faults were
interpreted from seismic data prior to drilling. The first fault was encountered far above the
reservoir interval in the overlying Seabee Formation. The fault was interpreted to be a single
plane with 60-90’ of throw. The second fault was encountered as predicted with an estimated
throw of 10-15’ within the Narwhal reservoir. Within one half mile radius of the wellbore
trajectory for CD4-597, the first fault was also encountered in the CD4-595 at 6630’ MD and
CD4-594 at 6297’ MD, and the second fault was encountered in CD4-595 at 16350’ MD.
Fracture gradients within the top seal intervals would not be exceeded during fracture
stimulation and would therefore confine injected fluids to the pool. CPAI has formed the
opinion, based on seismic, well and other subsurface information currently available that the
apparent faults will not interfere with containment.
We do not expect any of our hydraulic fractures to intersect the faults seen in this wellbore.
If there are indications that a fracture has intersected a fault during fracturing operations,
ConocoPhillips will go to flush and terminate the stage immediately.
Well Name
Fault
Depth MD
(ft)
Fault Depth
TVDSS (ft)
Fault Vertical
Displacement
(ft)
Fluid
Losses
(bbls/hr)
CD4-597 6475 -3162 60-90 0
CD4-597 17148 -4239 10-15 0
CD4-595 6630 -2815 60-90 0
CD4-595 16350 -4174 10-15 0
CD4-594 6297 -2888 60-90 0
SECTION 12 – PROPOSED HYDRAULIC FRACTURING PROGRAM
20 AAC 25.283(a)(12)
CD4-597 was completed in 2022 as a horizontal producer in the Narwhal formation. The well
was completed with a 4.5” tubing upper completion and a 4.5” liner with a ball actuated sliding
sleeve lower completion. The first stage sleeve has already been shifted open for pressure
monitoring in November 2022. The first stage will be stimulated without dropping another ball.
The 2nd stage will then be pumped and a third ball drop (progressively getting larger) after each
remaining stage, these balls will provide isolation from the previous stage and allow fracturing
from the toe of the well towards the heel.
Proposed Procedure:
Halliburton Pumping Services:
1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition
to identify any preexisting conditions.
2. Ensure all Pre-frac Well work has been completed and confirm the tubing and annulus
are filled with a freeze protect fluid to 2,000’ TVD.
3. Pressure test the rig installed frac tree to 10,000 psi.
4. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC.
5. MIRU 25 clean insulated Frac tanks, with a berm surrounding the tanks that can hold
a single tank volume plus 10%. Load tanks with 100º F seawater (approx. 2,200
barrels are required for each stage with breakdown, maximum pad and pumping
down the next ball. (450 bbls usable volume per tank).
6. MIRU HES Frac Equipment.
7. PT Surface lines to 10,000 psi using a Pressure test fluid.
8. Test IA Pop off system to ensure lines are clear and all components are functioning
properly.
9. Bring up pumps and increase annulus pressure from 2,500 psi to 3,850 psi as the
tubing pressures up.
10. Pump the 300 bbl breakdown stage (30# Hybor G) according to the attached excel
HES pump schedule. Bring pumps up to maximum rate of 25 BPM as quickly as
possible, pressure permitting. Ensure sufficient volume is pumped to load the well
with Frac fluid, prior to shut down.
11. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates.
12. Pump the 7 stage Frac job by following attached HES schedule @ ~25 bpm with a
maximum expected treating pressure of 6,125 psi.
13. RDMO HES Equipment. Freeze Protect the tubing and wellhead if not able to
complete following the flush.
14. Well is ready for Post Frac well prep/production tree installation and flowback
(Slickline and possibly CTU).
2,500 psi to 3,850
Max IA allowed is 3500 psi based on 3850 psi IA test. CDW 04/19/2023
SECTION 13 – POST-FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY
PLAN 20 AAC 25.283(a)(13)
Flowback will be initiated through a de-sander unit until the fluids clean up at which time it will be turned over to
production for initial clean up production before conversion to injection
WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED CDDirectional SurveyCD4-597 50-103-20839-00-00 222-019 CRU MWD/LWD/DD VISION SERVICES FINAL FIELD 11-Sep-22 1#REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF!Transmittal Receipt________________________________ X____________________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.VTuong@slb.comSLB Auditor -A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point.# Schlumberger-PrivateBy Meredith Guhl at 12:51 pm, Dec 16, 2022222-019T37373Meredith GuhlDigitally signed by Meredith Guhl Date: 2022.12.16 12:51:37 -09'00'
TTT RR AA NN SS MM II TT TT AA LL
FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl
ConocoPhillips Alaska, Inc. AOGCC
P.O. Box 100360 333 W. 7
th Ave., Suite 100
Anchorage AK 99510-0360 Anchorage, Alaska 99501
RE:: CD4-5977
Permit: 222-019
DATE: 12-14-2022
Transmitted:
North Slope, Colville River Unit, Alaska
Via SFTP upload
Schlumberger log data
Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com
CC: CD4-597 e-transmittal well folder
Receipt: Date:
Alaska/IT-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512
By Meredith Guhl at 11:54 am, Dec 15, 2022
222-019
T37373
Meredith Guhl Digitally signed by Meredith Guhl
Date: 2022.12.15 11:55:40 -09'00'
1a. Well Status:Oil SPLUG Other Abandoned Suspended
1b. Well Class:
20AAC 25.105 20AAC 25.110 Development Exploratory
GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test
2. Operator Name:6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry:
Aband.:
3. Address: 7. Date Spudded: 15. API Number:
4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number:
Surface:
9. Ref Elevations: KB: 17. Field / Pool(s):
GL: 18.8 BF:
Total Depth: 513' FSL, ' 4990' FEL S33 T11N R5E UM 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:
GR, RES, PWD, DIR, AZI, DEN, NEU, CALIPER, POROSITY, SONIC
23.
BOTTOM
20" H-40 120 10 yrds
13 3/8" L-80 2,387'
9 5/8" L-80 3,450
7" L-80 4,058
4 1/2" L-80 4,355
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-MSCF:
Test Period
Casing Press:Calculated Gas-MSCF:Oil Gravity - API (corr):
Press. 24-Hour Rate
8,171' 12,476' 3,428' 8 3/4"
Liner 12,288'-18,340' MD to 3,720'-4,355' TVD
2,406' - 2,741' MD 52.5 bbls of Class G
4.5" 12,287' MD/4,031' TVD
167' FSL, 2654 ' FEL, S29 T11N R5E UM
18,340'
CASING, LINER AND CEMENTING RECORD
1,268' MD/1,248'TVD
SETTING DEPTH TVD
40'
5949897
5944920
94
Sr Res EngSr Pet GeoSr Pet Eng
Narwhal/ Undefined Oil Pool
Lead: 87 bbls of 13ppg Class G
Tail: 22 bbls of 15.8ppg Class G 26
N/A
Oil-Bbl:Water-Bbl:
Gas-Oil Ratio:Choke Size:Water-Bbl:
24
Flow Tubing
INJECTOR
Date of Test: Oil-Bbl:
Per 20 AAC 25.283 (i)(2) attach electronic information
12.6 3,720'
PACKER SET (MD/TVD)
TUBING RECORD
6 1/8"12,288'
PRODUCTION TEST
HOLE SIZE
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size
and Number; Date Perfd):
Lead: 447 bbls of 11ppg G Blend
Tail: 73 bbls of 15.8ppg Class G
CEMENTING RECORD
12,298'
SIZE
40 40'
AMOUNT
PULLED
40' 2,716'
DEPTH SET (MD)
57.9
388625
TOP
SETTING DEPTH MD
40'
BOTTOM
18,350'MD/4,355'TVD
N/A
GRADE
N/A
68
120'
LONS 97-007
CASING
CRU/CD4-597
ADL380077, ADL384211, ADL380082,
ADL388903
2412' FSL, 12' FEL, S24 T11N R4E UM
WT. PER
FT.
378233
Top of Productive Interval:
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,
TOP
385740
8/1/2022
16"
42"
P.O. Box 100360, Anchorage, AK 99510-0360
5957540
9/8/2022
40'
50-103-20839-00-00
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
ConocoPhillips Alaska, Inc.
WAG
Gas
9/17/2022 222-019
8,324' 40' 12 1/4"
141 bbls of 15.8ppg Class G
WINJ
SPLUGOther Abandoned Suspended
Stratigraphic Test
No
No
Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment
By James Brooks at 3:35 pm, Oct 17, 2022
Completed
9/17/2022
JSB
RBDMS JSB 102522
Colville River/Narwhal Undef Oil
mudlogs
SFD 11/8/2022 DSR-11/3/22 GVTL 10/3/2023
Conventional Core(s): Yes No Sidewall Cores:
N/A
30.
MD TVD
Surface Surface
1268 1246
2421 2200
2789 2430
3525 2750
C10 5335 3014
10978 3839
Top of Productive Interval 12577 4072
(Narwhal ):
Formation at total depth 18350 4355
(TD): Narwhal
31. List of Attachments:
Cement Report, Directional Survey, Well Schematic, Operations Summary
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Haibin Guo
Contact Email:haibin.guo@conocophillips.com
Authorized Contact Phone:907-265-1487
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:
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).
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.
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram
with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical
reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted.
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, 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).
Signature w/Date:
Haibin Guo
Drilling Engineer
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.
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.
29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS
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, 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.
K3
C30
INSTRUCTIONS
Authorized Name:
Authorized Title:
C40
C20
If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form,
if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071.
Yes No
Well tested? Yes No
28. CORE DATA
If yes, list intervals and formations tested, briefly summarizing test results. Attach
separate pages to this form, if needed, and submit detailed test information,
including reports, per 20 AAC 25.071.
NAME
Permafrost - Top
Permafrost - Base
No
NoSidewall Cores: Yes No
Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment
Digitally signed by Haibin Guo
DN: OU=CPAI, O=Drilling and Wells, CN=Haibin Guo, E=Haibin.guo@conocophillips.com
Reason: I am the author of this document
Location: your signing location here
Date: 2022.10.17 11:55:49-08'00'Foxit PDF Editor Version: 11.2.1Haibin Guo
CD4-597
Horizontal Narwhal Sand Injector
Wellbore Schematic Final
Conductor Installed:
20" set @ 120' MD / TVD
Production Liner:
4-1/2" 12.6# L-80 HYD563
Tubing:
4-½” 12.6# L-80 HYD563
To 12,323' MD
12-1/4" Intermediate 1 Hole
6-1/8" Production Hole
16" Surface Hole
Narwhal Left of Lefty Sand Top:
12,975' MD / 4,129' TVD
Intermediate 2:
7" 26#, L80, TXPM and 7" 29# TN110SS TS-Blue
at 12,476' MD / 4,059' TVD RKB
7" x 9 5/8" Liner hanger at 8,170 MD
FMC Big Bore Well Head
SLB Single DHG
K-3 Sand Top:
10,975' MD / 3,839' TVD
Narwhal Central Sand Top:
12,577' MD / 4,073' TVD
4-½” Davis
Lynch dual valve
float shoe/collar
3.75" SLB DB Nipple
3.813" X CMD
3.813" HAL X Nipple
8-3/4” Intermediate 2 Hole
Production TD:
18,350' MD / 4,360' TVD
4-1/2” x 7" ZXP Liner Top Packer 12,288' MD
4-1/2” x 7" Baker Flex Lock Liner hanger
DrilPlex WBM
10.5ppg
LSND WBM
11ppg
LSND WBM
9.2 ppg
VersaPro OBM
9.0 ppg
Diesel
6.8ppg
~1500' TVD
GLMGLM
GLM
Brine
9.5ppg
Frac sleeves
Baker FracPoint 5.6"OD
Narwhal Lefty Sand
13,041' MD/ 4138' TVD
Baker Premier Production Packer
SLB KBG 4-5 GLM with SOV
SLB KBG 4-5 GLM with Dummy Valve
Last Update: 9/30/2022
Doyon 142 RKB = 57.9' MSL
Surface Casing:
13-3/8" 68# L-80 HYD563
2,716’ MD / 2,385' TVD RKB
55 deg Inc
Int1 TOC @ 6,580' MD / 3,197' TVD RKB
250' TVD above casing shoe
Intermediate 1:
9 5/8" 40#, L80, TXPM
Set at 8,324' MD / 3,447' TVD RKB
82 deg Inc
Int 2 TOC
At 9,475' MD / 3,619' TVD RKB
1500'MD above K3 top
Casing Strings
Casing Description
CONDUCTOR
OD (in)
20
ID (in)
19.12
Top (ftKB)
38.8
Set Depth (ft…
120.0
Set Depth …
120.0
Wt/Len (lb/ft)
94.00
Grade Top Connection
Casing Description
SURFACE
OD (in)
13 3/8
ID (in)
12.42
Top (ftKB)
38.8
Set Depth (ft…
2,716.4
Set Depth …
2,386.9
Wt/Len (lb/ft)
68.00
Grade
L-80
Top Connection
Hyd563
Casing Description
INTERMEDIATE
OD (in)
9 5/8
ID (in)
8.84
Top (ftKB)
36.0
Set Depth (ft…
8,324.0
Set Depth …
3,450.3
Wt/Len (lb/ft)
40.00
Grade
L80
Top Connection
TXP
Casing Description
LINER
OD (in)
7
ID (in)
6.28
Top (ftKB)
8,170.5
Set Depth (ft…
12,476.0
Set Depth …
4,058.3
Wt/Len (lb/ft)
26.00
Grade
L-80
Top Connection
7
Liner Details: excludes liner, pup, joints, casing, sub , shoe , float...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°)Item Des Com Make Model
Nominal ID
(in)
8,192.1 3,431.1 81.66 Nipple - RS Baker RS Nipple and Hyd 563 Pup Baker RS 6.220
Casing Description
LINER
OD (in)
4 1/2
ID (in)
3.96
Top (ftKB)
12,287.9
Set Depth (ft…
18,340.0
Set Depth …
4,355.1
Wt/Len (lb/ft)
12.60
Grade
L-80
Top Connection
Hyd 563
Liner Details: excludes liner, pup, joints, casing, sub , shoe , float...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°)Item Des Com Make Model
Nominal ID
(in)
12,330.0 4,037.2 81.63 Crossover Crossover Bushing 4-1/2" Hyd563 pin x
5" VTHT Box
Baker 3.980
12,341.1 4,038.8 81.62 Crossover Crossover Bushing 5" VTHT Box x 4-
1/2" Hyd563 pin
Baker 3.890
13,018.5 4,134.6 81.74 Swell Packer Baker 5.6" OD Oil Swell Packer, 4-1/2",
12.6#, L80, H563 (#14)
Baker 3.980
13,567.8 4,209.7 83.47 Swell Packer Baker 5.6" OD Oil Swell Packer, 4-1/2",
12.6#, L80, H563 (#13)
Baker 3.980
13,842.3 4,232.8 85.73 FRAC Sleeve/Port Baker frac sleeve #11, Hyd563
3.438" OD Ball
3.386
14,017.0 4,245.9 85.88 Swell Packer Baker 5.6" OD Oil Swell Packer, 4-1/2",
12.6#, L80, H563 (#12)
Baker 3.980
14,250.5 4,255.7 89.50 FRAC Sleeve/Port Baker frac sleeve #10, Hyd563
3.375" OD Ball
3.327
14,426.6 4,257.1 89.65 Swell Packer Baker 5.6" OD Oil Swell Packer, 4-1/2",
12.6#, L80, H563 (#11)
Baker 3.980
14,659.2 4,258.4 89.83 FRAC Sleeve/Port Baker frac sleeve #9, Hyd563
3.313" OD Ball
3.256
14,833.3 4,259.0 89.73 Swell Packer Baker 5.6" OD Oil Swell Packer, 4-1/2",
12.6#, L80, H563 (#10)
Baker 3.980
15,067.3 4,260.6 89.61 FRAC Sleeve/Port Baker frac sleeve #8, Hyd563
3.250" OD Ball
3.195
15,240.8 4,261.5 89.67 Swell Packer Baker 5.6" OD Oil Swell Packer, 4-1/2",
12.6#, L80, H563 (#9)
Baker 3.980
15,465.2 4,263.7 89.31 Swell Packer Baker 5.6" OD Oil Swell Packer, 4-1/2",
12.6#, L80, H563 (#8)
Baker 3.980
15,616.4 4,267.3 88.15 FRAC Sleeve/Port Baker frac sleeve #7, Hyd563
3.188" OD Ball
3.119
15,792.3 4,271.3 89.48 Swell Packer Baker 5.6" OD Oil Swell Packer, 4-1/2",
12.6#, L80, H563 (#7)
Baker 3.980
16,027.8 4,273.2 89.72 FRAC Sleeve/Port Baker frac sleeve #6, Hyd563
3.125" OD Ball
3.074
16,200.3 4,274.2 89.52 Swell Packer Baker 5.6" OD Oil Swell Packer, 4-1/2",
12.6#, L80, H563 (#6)
Baker 3.980
16,433.4 4,276.2 89.43 FRAC Sleeve/Port Baker frac sleeve #5, Hyd563
3.063" OD Ball
3.003
16,607.9 4,277.3 89.68 Swell Packer Baker 5.6" OD Oil Swell Packer, 4-1/2",
12.6#, L80, H563 (#5)
Baker 3.980
16,800.5 4,278.3 89.36 FRAC Sleeve/Port Baker frac sleeve #4, Hyd563
3.000" OD Ball
2.958
17,056.6 4,288.8 85.48 Swell Packer Baker 5.6" OD Oil Swell Packer, 4-1/2",
12.6#, L80, H563 (#4)
Baker 3.980
17,239.3 4,306.3 83.39 Swell Packer Baker 5.6" OD Oil Swell Packer, 4-1/2",
12.6#, L80, H563 (#3)
Baker 3.980
17,470.7 4,336.0 82.75 FRAC Sleeve/Port Baker frac sleeve #3, Hyd563
2.945" OD Ball
2.909
17,645.3 4,352.4 87.03 Swell Packer Baker 5.6" OD Oil Swell Packer, 4-1/2",
12.6#, L80, H563 (#2)
Baker 3.980
17,838.1 4,357.5 89.70 FRAC Sleeve/Port Baker frac sleeve #2, Hyd563
2.895" OD Ball
2.855
18,011.1 4,358.2 90.18 Swell Packer Baker 5.6" OD Oil Swell Packer, 4-1/2",
12.6#, L80, H563 (#1)
Baker 3.980
18,243.2 4,356.1 90.62 FRAC Sleeve/Port Baker frac sleeve #1, Hyd563
2.845" OD Ball
2.804
Tubing Strings: string max indicates LONGEST segment of string
Top (ftKB)
33.6
Set Depth …
4,032.5
String Ma…
4 1/2
Tubing Description
Tubing – Completion
Upper
Set Depth (ftKB)
12,297.8
Wt (lb/ft)
12.60
Grade
L-80
Top Connection
Hyd563
ID (in)
3.96
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°)Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
33.633.60.00 HANGER 11.000 FMC 4-1/2" Tubing Hanger Hydril
HYD 563 Min ID 3.92"
FMC TC-EMS3.958
1,287.4 1,264.221.34 Nipple - DB,
XN, DS, D
4.500 NIPPLE,LANDING,4 1/2","X",3.813",
H563
HESSN#
4548838
-3
3.813
3,282.12,671.267.78 INJ 4.500 4-1/2" x 1" Camco KBM4-5 GLM w/
DCK-2 SOV, 12.6# H563 BEK Latch
Camco SN#
23288-
10
3.958
11,996.9 3,988.6 81.59 FRAC
Sleeve/Port
5.500 Sliding Sleeve,4 1/2","X",3.813" GX,
H563 (NEXO-2 CMD)
BakerPN#
H12610
307
3.813
HORIZONTAL, CD4-597, 10/17/2022 9:29:45 AM
Vertical schematic (actual)
LINER; 12,287.9-18,340.0
Shoe; 18,337.9-18,340.0
Collar - Float; 18,295.7-18,297.8
FRAC Sleeve/Port; 18,243.2-
18,245.5
Swell Packer; 18,011.1-18,031.1
FRAC Sleeve/Port; 17,838.1-
17,840.5
Swell Packer; 17,645.3-17,665.3
FRAC Sleeve/Port; 17,470.7-
17,473.1
Swell Packer; 17,239.3-17,259.3
Swell Packer; 17,056.6-17,076.6
FRAC Sleeve/Port; 16,800.5-
16,802.8
Swell Packer; 16,607.9-16,627.9
FRAC Sleeve/Port; 16,433.4-
16,435.8
Swell Packer; 16,200.3-16,220.3
FRAC Sleeve/Port; 16,027.8-
16,030.1
Swell Packer; 15,792.3-15,812.3
FRAC Sleeve/Port; 15,616.4-
15,618.8
Swell Packer; 15,465.2-15,485.2
Swell Packer; 15,240.8-15,260.8
FRAC Sleeve/Port; 15,067.3-
15,069.7
Swell Packer; 14,833.3-14,853.3
FRAC Sleeve/Port; 14,659.2-
14,661.5
Swell Packer; 14,426.6-14,446.6
FRAC Sleeve/Port; 14,250.5-
14,252.9
Swell Packer; 14,017.0-14,037.0
FRAC Sleeve/Port; 13,842.3-
13,844.6
Swell Packer; 13,567.8-13,587.8
Swell Packer; 13,018.5-13,038.5
LINER; 8,170.5-12,476.0
Shoe - Float; 12,472.4-12,476.0
Collar - Landing ; 12,345.9-
12,349.3
Crossover; 12,341.0-12,342.8
Hanger; 12,331.7-12,341.0
Crossover; 12,330.0-12,331.7
Coupling; 12,318.7-12,320.2
Packer (Liner Top); 12,287.9-
12,318.7
Mule Shoe; 12,290.1
Mechanical Locator; 12,288.2
VALVE; 12,265.9
Nipple ; 12,215.7
Packer (Tubing); 12,195.1
Gauge / Pump Sensor; 12,131.9
INJ; 12,064.8
FRAC Sleeve/Port; 11,996.9
INTERMEDIATE; 36.0-8,324.0
Shoe - Float; 8,320.1-8,324.0
Collar - Float; 8,237.6-8,240.5
Nipple - RS; 8,192.1-8,199.0
Hanger; 8,170.5-8,192.1
INJ; 3,282.1
SURFACE; 38.8-2,716.4
Shoe - Float; 2,712.1-2,716.4
Collar - Float; 2,623.1-2,626.4
Nipple - DB, XN, DS, D; 1,287.4
CONDUCTOR; 38.8-120.0
Casing Hanger; 38.8-40.1
Casing Hanger; 36.0-37.4
HANGER; 33.6
WNS INJ
KB-Grd (ft)
39.10
RR Date Other Elev…
CD4-597
...
TD
Act Btm (ftKB)
18,350.0
Well Attributes
Field Name
NARWHAL
Wellbore API/UWI
501032083900
Wellbore Status
INJ
Max Angle & MD
Incl (°)MD (ftKB)
WELLNAME WELLBORE
Annotation End DateH2S (ppm)DateComment
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°)Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
12,064.8 3,998.5 81.56 INJ 4.500 4-1/2" x 1" Camco KBM4-5 GLM w/
DV, 12.6# H563 BK Latch
Camco SN#
23288-
11
3.865
12,131.9 4,008.4 81.58 Gauge / Pump
Sensor
4.500 SLB Metris Evolve DHG + Mandrel,
4-1/2" 12.6# L-80, H563
SLB SN#
43844-1
3.920
12,215.8 4,020.6 81.63 Nipple 4.500 TUBING,4 1/2",12.6#,L80, H563 Tenaris
Hydril
Hyd563 3.813
12,288.2 4,031.1 81.65 Mechanical
Locator
4.920 Mechanical locator (Collar 5.5" OD
( NOGO spaced out 2')
Baker Mechani
cal
Shear
Locator
3.860
12,290.1 4,031.4 81.64Mule Shoe 4.500 Mule Shoe - 4 1/2" Hyd 563 Box Baker Mule
shoe
3.958
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN ID (in)
33.633.60.00 BPV
12,265.9 4,027.9 81.65 VALVE
HORIZONTAL, CD4-597, 10/17/2022 9:29:51 AM
Vertical schematic (actual)
LINER; 12,287.9-18,340.0
Shoe; 18,337.9-18,340.0
Collar - Float; 18,295.7-18,297.8
FRAC Sleeve/Port; 18,243.2-
18,245.5
Swell Packer; 18,011.1-18,031.1
FRAC Sleeve/Port; 17,838.1-
17,840.5
Swell Packer; 17,645.3-17,665.3
FRAC Sleeve/Port; 17,470.7-
17,473.1
Swell Packer; 17,239.3-17,259.3
Swell Packer; 17,056.6-17,076.6
FRAC Sleeve/Port; 16,800.5-
16,802.8
Swell Packer; 16,607.9-16,627.9
FRAC Sleeve/Port; 16,433.4-
16,435.8
Swell Packer; 16,200.3-16,220.3
FRAC Sleeve/Port; 16,027.8-
16,030.1
Swell Packer; 15,792.3-15,812.3
FRAC Sleeve/Port; 15,616.4-
15,618.8
Swell Packer; 15,465.2-15,485.2
Swell Packer; 15,240.8-15,260.8
FRAC Sleeve/Port; 15,067.3-
15,069.7
Swell Packer; 14,833.3-14,853.3
FRAC Sleeve/Port; 14,659.2-
14,661.5
Swell Packer; 14,426.6-14,446.6
FRAC Sleeve/Port; 14,250.5-
14,252.9
Swell Packer; 14,017.0-14,037.0
FRAC Sleeve/Port; 13,842.3-
13,844.6
Swell Packer; 13,567.8-13,587.8
Swell Packer; 13,018.5-13,038.5
LINER; 8,170.5-12,476.0
Shoe - Float; 12,472.4-12,476.0
Collar - Landing ; 12,345.9-
12,349.3
Crossover; 12,341.0-12,342.8
Hanger; 12,331.7-12,341.0
Crossover; 12,330.0-12,331.7
Coupling; 12,318.7-12,320.2
Packer (Liner Top); 12,287.9-
12,318.7
Mule Shoe; 12,290.1
Mechanical Locator; 12,288.2
VALVE; 12,265.9
Nipple ; 12,215.7
Packer (Tubing); 12,195.1
Gauge / Pump Sensor; 12,131.9
INJ; 12,064.8
FRAC Sleeve/Port; 11,996.9
INTERMEDIATE; 36.0-8,324.0
Shoe - Float; 8,320.1-8,324.0
Collar - Float; 8,237.6-8,240.5
Nipple - RS; 8,192.1-8,199.0
Hanger; 8,170.5-8,192.1
INJ; 3,282.1
SURFACE; 38.8-2,716.4
Shoe - Float; 2,712.1-2,716.4
Collar - Float; 2,623.1-2,626.4
Nipple - DB, XN, DS, D; 1,287.4
CONDUCTOR; 38.8-120.0
Casing Hanger; 38.8-40.1
Casing Hanger; 36.0-37.4
HANGER; 33.6
WNS INJ CD4-597
...
WELLNAME WELLBORE
Page 1/51
CD4-597
Report Printed: 9/26/2022
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)
5/3/2022
00:00
5/3/2022
06:00
6.00 MIRU, MOVE DMOB P RIG DOWN SUB AND BOP DECK
INTERCONNECTS TO PREP FOR
SKIDDING RIG
FLOOR,DISASSEMBLE MUD PUMP #2
FOR INSPECTION,CONT. TO CLEAN
INSIDE AND OUTSIDE
OF CELLAR,STARTED TO BREAK
INTERCONNECTS BETWEEN PITS-
SUB AND PUMP-PITS,BLEW
DOWN TEST PUMP AND FREEZE
PROTECTED,STARTED CHECKING
TIRE PRESSURES FOR RIG
MOVE,
0.0 0.0
5/3/2022
06:00
5/3/2022
12:00
6.00 MIRU, MOVE DMOB P CLEAN AND ORGANIZE IN CELLAR
AND BOP DECK, CIRCULATE DEEP
CLEAN THROUGH PITS
AND ALL MUD LINES, PULL SEATS,
DISCHARGE SREENS AND INSPECT
SUCTION MANIFOLDS ON
BOTH MUD PUMP, PREP TOP DRIVE
FOR SERVICING, CHANGE OUT
ENCODER ON DRAWWORKS,
PREP ST-100 FOR 5 7/8'' DRILL PIPE,
CONT. CHECKING RIG TIRES FOR
RIG MOVE, GATHER
TOOLS FOR REMOVING STAIRS AND
LANDING FOR RIG MOVE
0.0 0.0
5/3/2022
12:00
5/3/2022
18:00
6.00 MIRU, MOVE DMOB P REMOVE GAS WATCH SYSTEM
FROM FLOW LINE FOR INSPECTION,
CLEAN IN PUMP ROOM,
RIG DOWN PUMP TO PITS
INNERCONNECTS, RIG DOWN
TOTCO ANNULUS SENSOR CABLES,
CONT CHECKING RIG TIRES FOR
RIG MOVE, PRESSURE WASH ON
RIG FLOOR, PREP ALL STUDS
FOR BOPES, OTECO AND GREY
LOCK CONNECTIONS, REMOVE
CUTTINGS BOX, EMPTY ALL
FLUID FROM MUD PITS TO VAC
TRUCK
0.0 0.0
5/3/2022
18:00
5/4/2022
00:00
6.00 MIRU, MOVE DMOB P REMOVE POP OFF LINES @ PUMP-
PITS INTERCONNECT, STAGE SPILL
KITS AT EACH MODULE
FOR RIG MOVE,LOCATE AND
CHARGE RADIOS FOR RIG
MOVE,SHIP OUT REST OF FLUID
FROM
PITS, CLEAR SUCTION LINES AND
PULL PLUGS ON MIX,CLEANOUT,AND
CHARGE
PUMPS,WORKING ON PM'S, CONT.
HOUSEKEEPING AROUND RIG,MOVE
ROUGHNECK HEATER
FURTHER AWAY FROM MPD
SKID,CLEAN ROCKWASHER
PITS,FUCTION AND GREASE POP
OFFS,DERRICKHAND WENT UP AND
SECURED THE DERRICK FOR RIG
MOVE
0.0 0.0
5/4/2022
00:00
5/4/2022
06:00
6.00 MIRU, MOVE DMOB P RAN MOVING HYDRAULIC'S AND
FUNCTION TEST STOMPERS, CONT.
TO PLUMB IN ROUGHNECK
HEATEWR BY MPD SKID, WENT
AROUND RIG CLEARED RIG VAC
LINES GREASED CHOKE MANIFOLD
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 2/51
CD4-597
Report Printed: 9/26/2022
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)
5/4/2022
06:00
5/4/2022
12:00
6.00 MIRU, MOVE DMOB P EMPTY OUT REMAINING FLUID
FROM TRIP TANK, CUT AND SLIP
DRILL LINE (60 FT.), HOUSE
KEEPING ON RIG FLOOR,
INVENTORY PARTS AND EQUIPMENT
AROUND RIG, PREP SUB
STOMPERS FOR RAISING
0.0 0.0
5/4/2022
12:00
5/4/2022
18:00
6.00 MIRU, MOVE DMOB P REMOVE BEAVER SLIDE FOR RIG
MOVE AND PLACE IN PIPE SHED,
OFF LOAD REMAINING
FLUID IN MUD PITS AND ROCK
WASHER, MP2'S AROUND RIG,
GREASE RIG FLOOR SKIDDING
RAILS FOR MOVE, BLOW DOWN AND
DISCONNECT STEAM, AIR, VAC, AIR,
AND ELECTRICAL
GOING TO ROCK WASHER, MODIFY
STEAM HEATER STAND IN COLD
START ROOM, SECURE SUB
RACKS AND AIR SLIP CART ON RIG
FLOOR FOR MOVE, SECURE TOOLS
AND EQUIPMENT IN PIPE
SHED FOR MOVE, CLEAN UP OUT
SIDE THE RIG OF ALL LOOSE
DEBRIS, MOVE AIR HEATERS
FROM AROUND SUB IN PREP FOR
SPOTTING CRANE
0.0 0.0
5/4/2022
18:00
5/4/2022
21:00
3.00 MIRU, MOVE DMOB P PLUMB ROUGHNECK HEATER BACK
AT MPD PANEL,PREP PIPE SHED
STAIRS FOR REMOVAL
FOR RIG MOVE,FINISH BLOWING
DOWN PRESSURE WASHER AND
WATER LINES IN PUMP
MODULE,PUT HEATERS ON ICE
COVERING POWER LINES TO BE
MOVED FOR RIG MOVE,
CD4-597 2 04-May-2022
2
0.0 0.0
5/4/2022
21:00
5/5/2022
00:00
3.00 MIRU, MOVE DMOB P CLEAN AND SUCK OUT CELLAR BOX,
BLOW DOWN WATER ARCOSS RIG,
PREP PINS AND
KEEPERS ON PIPE SHED LANDING
FOR REMOVAL, HOUSE KEEPING
AROUND RIG, DISCONNECT
WATER LINES AROUND RIG
0.0 0.0
5/5/2022
00:00
5/5/2022
12:00
12.00 MIRU, MOVE DMOB P ORGINIZING IN MUD PITS, CONT.
HOUSE KEEPING AROUND RIG ,
INVENTORY TOOLS AND
EQUIPMENT, REPAIR LIGHTS, MAKE
LIST OF LIGHT THAT ELECTRICIAN
WILL REPAIR,
MOVE CHOKE AWAY FROM WELL TO
MOVE SUB OUT. GREASE ALL PINS
INSURE ALL HAVE SAFETY PINS
0.0 0.0
5/5/2022
12:00
5/6/2022
00:00
12.00 MIRU, MOVE DMOB P CONT. ORGANIZING IN MUD PITS,
CONT. HOUSEKEEPING AROUND
RIG, INVENTORY
LIGHTS AROUND RIG THAT NEED
REPAIR, PLACE PRODUCTION TREE
BEHIND WELL
(CD4-597),PREP CD4 FOR LAYING
RIG MATS,REPAIR BOILER
BLOWDOWN LINE. RUN ALL
COLD STARTS, ELECTRICIAN
UNPLUGS ALL MODS, BLOW DOWN
STEAM SYSTEM, PUT
POWER MOD, PUMP MOD, AND
PIPESHED ON SUSPENSION
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 3/51
CD4-597
Report Printed: 9/26/2022
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)
5/6/2022
00:00
5/6/2022
06:00
6.00 MIRU, MOVE DMOB P CONT. PREP CD4-597 RIG MATS.
PREP STAGE UP SPOT ON CD1 FOR
PIPE SHED. LAY
TRANSITION MATS ON PIPE SHED
COMPLEX, PUMP COMPLEX, AND
MOTOR COMPLEX. GET
RIG PAINT INVENTORY.
0.0 0.0
5/6/2022
06:00
5/6/2022
09:00
3.00 MIRU, MOVE DMOB P CONT. PREP CD4-597 RIG MATS.
PREP STAGE UP SPOT ON CD1 FOR
PIPE SHED. LAY
TRANSITION MATS ON PIPE SHED
COMPLEX, PUMP COMPLEX, AND
MOTOR COMPLEX. GET
RIG PAINT INVENTORY
0.0 0.0
5/6/2022
09:00
5/6/2022
09:45
0.75 MIRU, MOVE MOB P MOVE AND STAGE ROCKWASHER 0.0 0.0
5/6/2022
09:45
5/6/2022
11:00
1.25 MIRU, MOVE MOB P MOVE AND STAGE PIPESHED 0.0 0.0
5/6/2022
11:00
5/6/2022
11:45
0.75 MIRU, MOVE MOB P MOVE AND STAGE MOTOR MOD 0.0 0.0
5/6/2022
11:45
5/6/2022
12:00
0.25 MIRU, MOVE MOB P MOVE AND STAGE PUMP MOD 0.0 0.0
5/6/2022
12:00
5/6/2022
12:15
0.25 MIRU, MOVE MOB P CONT. TO MOVE AND STAGE PUMP
MOD
0.0 0.0
5/6/2022
12:15
5/6/2022
12:45
0.50 MIRU, MOVE MOB P MOVE AND STAGE PITS 0.0 0.0
5/6/2022
12:45
5/6/2022
14:30
1.75 MIRU, MOVE DMOB P SKID RIG FLOOR 0.0 0.0
5/6/2022
14:30
5/6/2022
15:15
0.75 MIRU, MOVE DMOB P RAISE AND SECURE STOMPERS 0.0 0.0
5/6/2022
15:15
5/6/2022
16:15
1.00 MIRU, MOVE DMOB P INSTALL TONGUE ON SUB. MOVE
PIPESHED AND MOTOR MOD FROM
CD1 TO CD4 @ 15:30
0.0 0.0
5/6/2022
16:15
5/6/2022
17:30
1.25 MIRU, MOVE DMOB P PICK AIR HEATER OFF PITS ROOF.
PIPESHED AND MOTOR MOD ARRIVE
@ CD4 @ 16:30
0.0 0.0
5/6/2022
17:30
5/6/2022
18:00
0.50 MIRU, MOVE DMOB P RAISE AND PIN CELLAR DOOR 0.0 0.0
5/6/2022
18:00
5/6/2022
19:00
1.00 MIRU, MOVE MOB P STAGE UP PUMP AND PITS MODS @
EDGE OF CD-1
0.0 0.0
5/6/2022
19:00
5/6/2022
20:30
1.50 MIRU, MOVE MOB P MOVE PUMP & PITS MODS T/ CD-4
AND STAGE.
0.0 0.0
5/6/2022
20:30
5/7/2022
00:00
3.50 MIRU, MOVE MOB P MOVE SUB OFF CD-1 WD-03 AND
STAGE @ EDGE OF PAD. MOVE RIG
MATS, PULL
HERCULITE AND WAIT FOR ALPINE
RUNWAY TO OPEN.
0.0 0.0
5/7/2022
00:00
5/7/2022
02:30
2.50 MIRU, MOVE MOB P MOVE SUB AND ROCKWASHER F/
CD-1 T/ CD-4
110.0 110.0
5/7/2022
02:30
5/7/2022
03:30
1.00 MIRU, MOVE RURD P STAGE SUB AND LAY RIG MATS F/
SUB.
0.0 0.0
5/7/2022
03:30
5/7/2022
06:00
2.50 MIRU, MOVE RURD P SPOT SUB AND SET STOMPERS 0.0 0.0
5/7/2022
06:00
5/7/2022
07:00
1.00 MIRU, MOVE RURD P SKID RIG FLOOR, REMOVE TONGUE
ON SUB
0.0 0.0
5/7/2022
07:00
5/7/2022
08:00
1.00 MIRU, MOVE RURD P SPOT PITS 0.0 0.0
5/7/2022
08:00
5/7/2022
09:00
1.00 MIRU, MOVE RURD P SPOT PUMP MOD 0.0 0.0
5/7/2022
09:00
5/7/2022
10:00
1.00 MIRU, MOVE RURD P SPOT MOTOR MOD 0.0 0.0
5/7/2022
10:00
5/7/2022
11:00
1.00 MIRU, MOVE RURD P SPOT ROCKWASHER 0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 4/51
CD4-597
Report Printed: 9/26/2022
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)
5/7/2022
11:00
5/7/2022
12:00
1.00 MIRU, MOVE RURD P SPOT PIPESHED 0.0 0.0
5/7/2022
12:00
5/7/2022
18:00
6.00 MIRU, MOVE RURD P M/U ALL INTERCONNECTS,
CHOKE/KILL HOSES ON THE SUB.
CHECK LANDINGS AROUND
THE RIG, ELECTRICIAN PLUG ALL
MODS IN, GET STEAM, WATER, AIR
GOING AROUND RIG.
WORK ON PRE-ACCEPTANCE
CHECK LIST
0.0 0.0
5/7/2022
18:00
5/8/2022
00:00
6.00 MIRU, MOVE RURD P CONT. WORKING ON RIG
ACCEPTANCE CHKLIST. CONNECT
CHRG PUMP
SUCTION/DISCHARGE LINES,
CONNECT MPD LINES IN BOP DECK.
CHK/KILL LINES, LWR
MEZZ. PLATFORM. CLEAN PIN
POCKETS ON PIPE SHED STAIR PAD
EYES. RIG UP SKATE
RIG ACCEPTED FOR MAINTANCE AT
2400HRS
0.0 0.0
8/1/2022
00:00
8/1/2022
01:00
1.00 SURFAC, DRILL SFTY P CONT. TAKING ON MUD TO PITS,
PJSM ON PICKING UP BHA AND
HANDLING PROCEDURES
0.0 0.0
8/1/2022
01:00
8/1/2022
03:15
2.25 SURFAC, DRILL BHAH P P/U AND M/U PARTIAL DIRECTIONAL
BHA AS PER WELL PLAN TIH 100'
0.0 0.0
8/1/2022
03:15
8/1/2022
03:30
0.25 SURFAC, DRILL DRLG P WASH DOWN F/ 100' TO 114'MD @
630 GPM 517 PSI 55% FLOW 20 RPM
1K TQ
CLEAN OUT CONDUCTOR F/ 114' TO
131' @ 630 GPM 633 PSI 55 % 20 RPM
1-3K WOB 1-3 TQ ADT.33
0.0 131.0
8/1/2022
03:30
8/1/2022
03:45
0.25 SURFAC, DRILL TRIP P POOH F/ 131' MDS TO 43' @ 480 GPM
P/U WT 53K
131.0 41.0
8/1/2022
03:45
8/1/2022
04:00
0.25 SURFAC, DRILL TRIP P RACK STAND BACK OF HWDP L/D XO 41.0 41.0
8/1/2022
04:00
8/1/2022
06:00
2.00 SURFAC, DRILL BHAH P P/U SURFACE BHA AS PER SLB AND
SCIENTIFIC GYRO REPS F/ 43' TO
131'
41.0 131.0
8/1/2022
06:00
8/1/2022
06:45
0.75 SURFAC, DRILL SRVY P SHOOT GYRO SURVEY @
CONDUCTOR
131.0 131.0
8/1/2022
06:45
8/1/2022
12:00
5.25 SURFAC, DRILL DDRL P DRILL 16” SURFACE HOLE TAKING
GYRO SURVEYS. F/ 128‘ MD - T/ 464‘
MD 464‘ TVD, WOB =
2-10K, GPM = 625, PSI ON = 855, PSI
OFF = 805, RPM = 40, TQ ON = 5, TQ
OFF = 3, FLOW OUT
= 63%, ECD = 11.62 PPG, P/U WT =
76K, S/O WT = 73K, AST=1.48, ART
= .72, ADT =2.20 ,
TOTAL BIT HRS =2.20, TOTAL JARS =
0
131.0 464.0
8/1/2022
12:00
8/1/2022
18:00
6.00 SURFAC, DRILL DDRL P DRILL 16” SURFACE HOLE TAKING
GYRO SURVEYS. F/ 464‘ MD - T/ 834‘
MD 828‘ TVD, WOB =
10-12K, GPM = 625, PSI ON = 1067,
PSI OFF = 980, RPM = 40, TQ ON = 6-
8, TQ OFF = 3, FLOW
OUT = 65%, ECD = 11.39 PPG, P/U WT
= 86K, S/O WT = 84K, ROT= 85 DROP
SOAP STICKS AND
SAPP EACH CONNECTION
464.0 834.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 5/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/1/2022
18:00
8/2/2022
00:00
6.00 SURFAC, DRILL DDRL P DRILL 16” SURFACE HOLE F/ 834‘ MD
- T/ 1,225‘ MD 1,220‘ TVD, WOB = 7-
13K, GPM = 650, PSI
ON = 1,139, PSI OFF = 1,028, RPM =
40, TQ ON = 4-8K, FLOW OUT = 57%,
ECD = 11.3 PPG, P/U
WT = 98K, S/O WT = 98K, RT WT =
95K, AST= 2.59, ART = , ADT = 3.37,
TOTAL BIT HRS = 8.16,
TOTAL JARS = 3.95
INCREASE IN WOOD CUTTINGS @
595' MD
GRAVEL TO CLAY @ 615'
834.0 1,225.0
8/2/2022
00:00
8/2/2022
06:00
6.00 SURFAC, DRILL DDRL P DRILL 16” SURFACE HOLE F/ 1225'
MD - T/ 1774' MD ‘ TVD, WOB = 7-13K,
GPM = 725, PSI ON = 1,1459, PSI OFF
= 1,258, RPM = 40, TQ ON = 4-8K,
FLOW OUT = 57%, ECD = 11.3 PPG,
P/U WT = 98K, S/O WT = 98K, RT WT =
95K, AST= 2.59, ART = , ADT = 3.37,
TOTAL BIT HRS = 8.16, TOTAL JARS =
3.95
INCREASE IN WOOD CUTTINGS @
595' MD GRAVEL TO CLAY @ 615'
MWD SURVEY START AT 1290'
1,225.0 1,774.0
8/2/2022
06:00
8/2/2022
12:00
6.00 SURFAC, DRILL DDRL P DRILL 16” SURFACE HOLE F/ 1774‘
MD - T/ 2137‘ MD 2010‘ TVD, WOB =
20-25K, GPM = 825,
PSI ON = 1830, PSI OFF = 1650, RPM
= 55, TQ ON = 6-10K, FLOW OUT =
65%, ECD = 11.32 PPG,
P/U WT = 125K, S/O WT = 109K, RT
WT = 114K, AST= 1.87, ART = 6.30,
ADT = 8.17, TOTAL BIT
HRS = 19.76, TOTAL JARS = 15.55
1,774.0 2,137.0
8/2/2022
12:00
8/2/2022
18:00
6.00 SURFAC, DRILL DDRL P DRILL 16” SURFACE HOLE F/ 2137‘
MD - T/ 2415‘ MD 2196‘ TVD, WOB =
25K, GPM = 900 PSI
ON = 2113, PSI OFF = 1965, RPM = 55,
TQ ON = 7K, FLOW OUT = 66%, ECD
= 11.06 PPG, P/U
WT = 123K, S/O WT = 112K, RT WT =
113K, PUMP BIT BALLING SWEEPS
EVERY 2 STANDS.
2,137.0 2,415.0
8/2/2022
18:00
8/2/2022
18:30
0.50 SURFAC, DRILL CIRC P HOLE UNLOADED, GET PITS AND
ROCK CLEANED AND READY TO GO
AGAIN
2,415.0 2,415.0
8/2/2022
18:30
8/3/2022
00:00
5.50 SURFAC, DRILL DDRL P DRILL 16” SURFACE HOLE F/ 2,415‘
MD - T/ 2,624‘ MD 2,330‘ TVD, WOB =
23-25K, GPM = 900,
PSI ON = 2,147, PSI OFF = 2,100, RPM
= 40, TQ ON = 7-9K, FLOW OUT =
68%, ECD = 11.24 PPG,
P/U WT = 127K, S/O WT = 111K, RT
WT = 118K, AST= 1.47, ART = 7.18,
ADT = 8.65, TOTAL BIT
HRS = 28.41, TOTAL JARS = 24.20
2,415.0 2,624.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 6/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/3/2022
00:00
8/3/2022
01:00
1.00 SURFAC, DRILL DDRL P DRILL 16” SURFACE HOLE F/ 2624‘
MD - T/ 2,646‘ MD 2,330‘ TVD, WOB =
23-25K, GPM = 900, PSI ON = 2,147,
PSI OFF = 2,100, RPM = 40, TQ ON = 7
-9K, FLOW OUT = 68%, ECD = 11.24
PPG, P/U WT = 127K, S/O WT = 111K,
RT WT = 118K,
2,624.0 2,646.0
8/3/2022
01:00
8/3/2022
02:00
1.00 SURFAC, DRILL CIRC T CIRCULATED HOLE CLEAN WHILE
WAITING ON CPAI GEOLIST FOR
FINAL MD AND TVD. PC SOFT WARE
FOR GEOLOGIST NOT WORKING
PROPERLY. FIXED PC AND
CONFIRMED DEPTHS DD AND CPAI
REP.
2,646.0 2,646.0
8/3/2022
02:00
8/3/2022
03:00
1.00 SURFAC, DRILL DDRL P DRILL 16” SURFACE HOLE F/ 2,648‘
MD - T/ 2721‘ MD 2,330‘ TVD, WOB =
23-25K, GPM = 900, PSI ON = 2,147,
PSI OFF = 2,100, RPM = 40, TQ ON = 7
-9K, FLOW OUT = 68%, ECD = 11.24
PPG, P/U WT = 127K, S/O WT = 111K,
RT WT = 118K, AST= 1.47, ART = 8.27,
ADT = 9.5, TOTAL BIT HRS = 29.39,
TOTAL JARS = 25.18
2,646.0 2,721.0
8/3/2022
03:00
8/3/2022
03:15
0.25 SURFAC, DRILL SRVY P OBTAIN FINAL SURVEY AND TORQUE
AND DRAG VALVES
2,721.0 2,721.0
8/3/2022
03:15
8/3/2022
05:00
1.75 SURFAC, CASING CIRC P CIRCULUTE 1 B/U RACK STAND
BACK CIRCULATE ANOTHER B/U
RACK STAAND BACK
2,721.0 2,258.0
8/3/2022
05:00
8/3/2022
05:15
0.25 SURFAC, CASING OWFF P FLOW CHECK WELL WELL STATIC 2,258.0 2,258.0
8/3/2022
05:15
8/3/2022
12:00
6.75 SURFAC, CASING BKRM P BROOH F/ 2258' MD TO 1675'' MD @
900 GPM
1507 PSI RPM 40 TQ ECD'S F/O 67 %
P/U WT 95k
2,258.0 1,675.0
8/3/2022
12:00
8/3/2022
16:00
4.00 SURFAC, CASING BKRM P BROOH F/ 1675‘ MD - T/ 1307‘ MD, W/
GPM = 900, PSI = 1556, RPM = 40, TQ
= 3K. F/O = 67%,
ECD = 11.07PPG, P/U WT = 95K.
ORIENTATE HIGH SIDE.
1,675.0 1,307.0
8/3/2022
16:00
8/3/2022
16:45
0.75 SURFAC, CASING OWFF P OWFF ATTEMPT TO PULL ON
ELEVATORS 30K OVER PULL
OBSERVED @ 1286' MD. KELLY
UP PUMP OUT OF HOLE
1,307.0 1,307.0
8/3/2022
16:45
8/3/2022
22:30
5.75 SURFAC, CASING TRIP P BROOH F/ 1307' MD T/ 743' MD @ 500
GPM, 660PSI, 60% F/O, P/U 90K
1,307.0 743.0
8/3/2022
22:30
8/3/2022
23:00
0.50 SURFAC, CASING TRIP P POOH ON ELEVATORS F/ 743' MD T/
188' MD
743.0 188.0
8/3/2022
23:00
8/4/2022
00:00
1.00 SURFAC, CASING OTHR P B/D TOP DRIVE, HOLD PJSM F/ L/D
BHA
188.0 188.0
8/4/2022
00:00
8/4/2022
03:00
3.00 SURFAC, CASING BHAH P L/D SURFACE BHA PER SDI AND SLB
REP'S
188.0 0.0
8/4/2022
03:00
8/4/2022
05:00
2.00 SURFAC, CASING PUTB P CLEAN AND CLEAR RIG FLOOR R/U
CASING EQUIPMENT
0.0 0.0
8/4/2022
05:00
8/4/2022
06:00
1.00 SURFAC, CASING PUTB P P/U AND DUMMY RUN HANGER AND
LANDING JT.
0.0 0.0
8/4/2022
06:00
8/4/2022
07:00
1.00 SURFAC, CASING PUTB P PERFORM DUMMY RUN W/ 13 3/8"
HANGER AND LANDING JT
0.0 0.0
8/4/2022
07:00
8/4/2022
08:00
1.00 SURFAC, CASING PULD P CONT. R/U CSG RUNNING
EQUIPMENT
0.0 0.0
8/4/2022
08:00
8/4/2022
08:15
0.25 SURFAC, CASING SFTY P HOLD PJSM FOR RUNNING 13 3/8"
CSG
0.0 0.0
8/4/2022
08:15
8/4/2022
09:00
0.75 SURFAC, CASING PUTB P M/U 13 3/8" 68# L-80 HYD 563 SHOE
TRACK F/ SURFACE T/ 179' MD. M/U
TQ= 25K FT/LBS
0.0 179.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 7/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/4/2022
09:00
8/4/2022
09:30
0.50 SURFAC, CASING OWFF P TEST FLOATS 179.0 179.0
8/4/2022
09:30
8/4/2022
12:00
2.50 SURFAC, CASING PUTB P CONT. TO RUN 13 3/8" 68# L-80 HYD
563 F/ 179' T/ 863' MD. S/O WT= 75K.
M/U TQ= 25K
FT/LBS. FILLING ON THE FLY VIA
VOLANT, TOPPING OFF EVERY 10
JTS. MONITORING
DISPLACEMENT VIA PIT #5.
179.0 863.0
8/4/2022
12:00
8/4/2022
15:00
3.00 SURFAC, CASING PUTB P CONT. TO RUN 13 3/8" 68# L-80 HYD
563 F/ 863' T/ 1413' MD. S/O WT=
110K. M/U TQ= 25K
FT/LBS. FILLING ON THE FLY VIA
VOLANT, TOPPING OFF EVERY 10
JTS. MONITORING
DISPLACEMENT VIA PIT #5.
863.0 1,413.0
8/4/2022
15:00
8/4/2022
16:00
1.00 SURFAC, CASING CIRC P CIRCULATE STRING VOLUME
STAGING UP TO 8 BPM ICP 136 PSI
FCP 137 PSI, P/U
WT=119K. S/O WT=112, 2165
STROKES TOTAL
1,413.0 1,413.0
8/4/2022
16:00
8/4/2022
21:00
5.00 SURFAC, CASING PUTB P CONT. TO RUN 13 3/8" 68# L-80 HYD
563 F/ 1413 T/ 2664' MD. S/O WT=
151K. M/U TQ= 25K
FT/LBS. FILLING ON THE FLY VIA
VOLANT, TOPPING OFF EVERY 10
JTS. MONITORING
DISPLACEMENT VIA PIT #5.
1,413.0 2,664.0
8/4/2022
21:00
8/4/2022
22:00
1.00 SURFAC, CASING CIRC P CIRC B/U AND RECIP. F/ 2,664' MD T/
2,664' MD, STAGING RATE UP TO 8
BPM, 182 PSI, 48%
F/O. TOTAL STKS PUMPED= 1,960
(231 BBLS)
2,664.0 2,664.0
8/4/2022
22:00
8/4/2022
22:45
0.75 SURFAC, CASING PUTB P M/U 10' PUP, HANGER AND LANDING
JT F/ 2,664' MD T/ 2,677' MD
2,664.0 2,677.0
8/4/2022
22:45
8/4/2022
23:00
0.25 SURFAC, CASING WASH P WASH DOWN LANDING JT F/ 2,677'
MD T/ 2,716' MD @ 3 BPM, 96 PSI,
31% F/O, S/O WT= 160K
2,677.0 2,716.0
8/4/2022
23:00
8/4/2022
23:30
0.50 SURFAC, CASING CIRC P CIRC AND RECIP F/ 2,716' MD T/
2,710' MD STAGING PUMPS TO 8
BPM, 200 PSI, 45% F/O.
TOTAL STKS PUMPED= 2,221 (262
BBLS)
2,716.0 2,710.0
8/4/2022
23:30
8/5/2022
00:00
0.50 SURFAC, CEMENT OTHR P B/D TOP DRIVE, M/U CEMENT HOSE
TO VOLANT
2,710.0 2,710.0
8/5/2022
00:00
8/5/2022
01:45
1.75 SURFAC, CEMENT CIRC P CIRC AND RECIP F/ 2716' TO 2710'
MD WITH CEMENT HOSE STAGING
RATE UP TO 8 BPM
338 PSI 42% F/O TOTAL STROKES
5286 624 BBLS
2,716.0 2,716.0
8/5/2022
01:45
8/5/2022
02:45
1.00 SURFAC, CEMENT PRTS P PRESS TEST CEMENT LINES 500PSI
LOW 3500PSI HIGH GOOD TEST,
WHILE MOVING REMAIN MUD IN
PITS TO TRUCKS FOR CEMENNT
JOB
2,716.0 2,716.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 8/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/5/2022
02:45
8/5/2022
07:30
4.75 SURFAC, CEMENT CMNT P CEMENTERS PUMP 99.5 BBLS 10.7#
MUD PUSH II, DROP BOTTOM PLUG.
PUMP 447 BBLS
11# LEAD CEMENT FOLLOWED BY 73
BBLS 15.8# TAIL CEMENT, DROP TOP
PLUG. PUMP 10
BBLS FRESH WATER. SWAP OVER
TO RIG PUMP AND CHASE PLUG @ 7
BPM, 515 PSI, 54%
F/O. @ 3100 STKS AWAY SLOW
PUMPS T/ 3 BPM, 386 PSI, 45% F/O.
BUMP PLUG @ 3232
STKS. HOLD 890 PSI FOR 5 MIN,
BLEED OFF AND CHECK FLOATS
(GOOD). CIP @ 07:30, 201
BBLS CEMENT TO SURFACE
2,716.0 2,716.0
8/5/2022
07:30
8/5/2022
12:00
4.50 SURFAC, WHDBOP CLEN P CLEAN CEMENT VALVES, CLEAN
RISER AND DRIP PAN, CLEAN
SURFACE LINES IN MUD
PITS, AND OFF LOAD AND CLEAN
ROCKWASHER, PULL LANDING
JOINT, START TO RIG
DOWN/ LAY DOWN CASING
EQUIPMENT.
0.0 0.0
8/5/2022
12:00
8/5/2022
18:00
6.00 SURFAC, WHDBOP RURD P FINISH RIG DOWN/ LAY DOWN
CASING EQUIPMENT. NIPPLE DOWN
RISERS AND L/D
MOUSEHOLE, OPENED AND PINNED
CELLAR DOOR T/ GET WELL HEAD
INTO CELLAR T/ RIG
UP AND ORIENTATE , SIMOPS CONT.
T/ CLEAN SURFACE LINES,
EQUIPMENT AND
ROCKWASHER, PUT CHOKE FLANGE
BACK ON STACK AND ORIENTATE 90
CORRECTLY FOR
KILL LINE, REMOVED 4" VALVES
FROM CONDUCTER AND CAPPED,
GET SPACER SPOOL TO
THE CELLAR AND MAKE UP TO WELL
HEAD
0.0 0.0
8/5/2022
18:00
8/6/2022
00:00
6.00 SURFAC, WHDBOP NUND P NIPPLE UP BOP STACK, CHOKE, KILL
AND MPD EQUIPMENT PER BEYOND
REPS
SIMOPS- CONT. CLEANING OUT
ROCK WASHER AND MUD PITS
0.0 0.0
8/6/2022
00:00
8/6/2022
02:00
2.00 SURFAC, WHDBOP NUND P NIPPLE UP BOP STACK, CHOKE, KILL
AND MPD EQUIPMENT PER BEYOND
REPS SIMOPS- CONT. CLEANING
OUT ROCK WASHER AND MUD PITS
0.0 0.0
8/6/2022
02:00
8/6/2022
03:00
1.00 SURFAC, WHDBOP MPSP P M/U TESTY PLUG AND INSTALL PER
FMC REP
0.0 0.0
8/6/2022
03:00
8/6/2022
04:00
1.00 SURFAC, WHDBOP PRTS P FLOOD STACK, TEST MPD RCD
HEAD AND ORBIT VALVE T/ 250 1200
PSI
0.0 0.0
8/6/2022
04:00
8/6/2022
05:00
1.00 SURFAC, WHDBOP BOPE P CONT. R/U TO TESTING EQUIP FOR
BOPE TEST, PRESSURE UP KUMMY
UNIT
0.0 0.0
8/6/2022
05:00
8/6/2022
06:00
1.00 SURFAC, WHDBOP BOPE P PERFORM SHELL TEST ON STACK
AND CHOKE MANIFOLD, CKOKE AND
KILL LINES
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 9/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/6/2022
06:00
8/6/2022
12:00
6.00 SURFAC, WHDBOP BOPE T PERFORM SHELL TEST ON BOPE
PRIOR TO CHARTED TEST,
DISCOVERED LEAKS AT
CHOKE HOSE OTECO CLAMP SO
REMOVED CLAMP AND REPLACED
GASKET, ATTEMPTED
TO PERFORM SHELL TEST AGAIN
AND DISCOVERED LEAK WHERE
THE ANNULAR MAKES
UP TO UPPER RAMS, THEREFORE
WE HAD TO REMOVE STACK YOKE
TO SWEENEY
WRENCH STUDS TIGHT.
0.0 0.0
8/6/2022
12:00
8/6/2022
15:00
3.00 SURFAC, WHDBOP BOPE T UPON TRYING TO TEST AFTER
ADDRESSING LEAKS IT WAS
DETERMINED THAT THE
ANNULAR, YOKE , AND MPD
ROTATING HEAD NEEDED TO BE
REMOVED TO CHANGE OUT
API RING BELOW ANNULAR, C/O API
RING AND RE-INSTALLED ANNULAR,
ROTATING HEAD,
AND TRIP NIPPLE,
0.0 0.0
8/6/2022
15:00
8/6/2022
16:30
1.50 SURFAC, WHDBOP BOPE T TROUBLESHOOT MPD RCD CLAMP 0.0 0.0
8/6/2022
16:30
8/6/2022
18:00
1.50 SURFAC, WHDBOP BOPE T CONT. TO ADDRESS LEAKS ON
STACK AND CHOKE LINE
0.0 0.0
8/6/2022
18:00
8/6/2022
18:30
0.50 SURFAC, WHDBOP BOPE T W/ 5 7/8" TEST JT TEST ANNULAR,
CV # 1, 12, 13, 14, RIG FLOOR KILL
LINE T/ 250 LOW, 5,000
HIGH FOR 5/5
0.0 0.0
8/6/2022
18:30
8/7/2022
00:00
5.50 SURFAC, WHDBOP BOPE T ADDRESS LEAKS ON CHOKE LINE,
AND BOP STACK. OPEN UPPER RAM
DOORS AND
INSPECT 3 1/2" X 6" RAM SEALS,
OBSERVE MINOR DAMAGE ON BOTH
RAMS, C/O SEALS
FOR NEW ONES.
0.0 0.0
8/7/2022
00:00
8/7/2022
00:30
0.50 SURFAC, WHDBOP BOPE T PERFORM SHELL TEST ON BOP
STACK, CHOKE LINES, CHOKE
MANIFOILD TO 5000 PSI GOOD TEST.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 10/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/7/2022
00:30
8/7/2022
05:00
4.50 SURFAC, DRILLOUT BOPE P TEST BOPE ALL TESTS T/ 250 LOW
5,000 HIGH FOR 5 CHARTED MIN. W/
EXCEPTION OF
MANUAL OPERATED & SUPER
CHOKE TESTED T/ 250 LOW & 2,000
PSI FOR 5 CHARTED MIN,
W/ 5 7/8" TEST JT TEST ANNULAR, 3
1/2" X 6" UPR, 3 1/2" X 6" LPR, TEST
CHOKE VALVES
1-15, MANUAL OPERATED & SUPER
CHOKE, CHOKE & KILL MANUALS &
HCR'S, 4" VALVE ON
KILL LINE, 5 7/8" FOSV X2, 5 7/8"
DART VALVE, UPPER & LOWER IBOP;
BLIND/ SHEAR RAMS;
PERFORM KOOMEY DRAWDOWN,
ACC = 3,025 PSI. MANIF. = 1,500 PSI.
ACC = 1,800 PSI
AFTER ALL FUNCTIONS ON
BOTTLES, 8 SEC FOR 200 PSI. BUILD
W/ 2 ELEC. PUMPS, 59 SEC
T/ BUILD FULL SYS. PRESSURE W/ 2
ELEC. & 2 AIR PUMPS, CLOSING
TIMES ANNULAR = 10
SEC. UPR = 7 SEC. BLIND / SHEARS
= 7 SEC. LPR = 7 SEC. CHOKE HCR =
2 SEC. KILL HCR = 2
SEC; TEST PVT GAIN/LOSS AND
FLOW OUT ALARMS, TEST LEL AND
H2S ALARMS;
WITNESSED BY AOGCC REP AUSTIN
MCLEOD
0.0 0.0
8/7/2022
05:00
8/7/2022
09:00
4.00 SURFAC, DRILLOUT RURD P R/D TESTING EQUIPMENT, PULL
TEST PLUG, SET WEAR RING.
WEAR RING ID= 12 3/8", LENGTH=
42", SIMOPS BLOWN TESTING
EQUIPMENT/ CLEAN/CLEAR
FLOOR TO PREP TO PICKUP BHA
0.0 0.0
8/7/2022
09:00
8/7/2022
09:30
0.50 SURFAC, DRILLOUT SFTY P PJSM ON P/U BHA/TRIP IN THE
HOLE.
0.0 0.0
8/7/2022
09:30
8/7/2022
12:00
2.50 SURFAC, DRILLOUT BHAH P P/U BHA/ LOAD SOURCE PER SLB
REP
0.0 429.0
8/7/2022
12:00
8/7/2022
14:30
2.50 SURFAC, DRILLOUT BHAH P CONT. P/U BHA/ LOAD SOURCE PER
SLB REP
429.0 429.0
8/7/2022
14:30
8/7/2022
16:00
1.50 SURFAC, DRILLOUT TRIP P RIH FROM SURFACE TO 429 MD' T/
2407 MD', SO= 107K
429.0 2,407.0
8/7/2022
16:00
8/7/2022
17:00
1.00 SURFAC, DRILLOUT CIRC P STAGE UP T/ 900 GPM AND WASH F/
2407' MD' T/ 2497 MD' , PSI= 1490,
FO= 65%
2,407.0 2,497.0
8/7/2022
17:00
8/7/2022
18:00
1.00 SURFAC, DRILLOUT RURD P R/U TO TEST CASING, PURGE AIR
FROM ALL LINES
2,497.0 2,497.0
8/7/2022
18:00
8/7/2022
18:45
0.75 SURFAC, DRILLOUT PRTS P @ 2,497' MD TEST CASING TO 3,000
PSI FOR 30 MIN. 5 BBLS TO
PRESSURE UP, 5 BBLS
BLED OFF
2,497.0 2,497.0
8/7/2022
18:45
8/7/2022
19:30
0.75 SURFAC, DRILLOUT RURD P R/D TESTING EQUIPMENT 2,497.0 2,497.0
8/7/2022
19:30
8/7/2022
20:00
0.50 SURFAC, DRILLOUT WASH P WASH DOWN F/ 2,497' MD T/ 2,621.72'
MD @ 600 GPM, 740 PSI, 56% F/O, 40
RPM, 4-8K TQ,
P/U WT= 125K, S/O WT= 106K, ROT
WT= 114K. TAG PLUG @ 2,621.72' MD
2,497.0 2,622.0
8/7/2022
20:00
8/7/2022
21:00
1.00 SURFAC, DRILLOUT DRLG P DRILL PLUGS AND FLOAT COLLAR F/
2,621.72' MD T/ 2,623.7' MD @ 600
GPM, 741 PSI, 57%
F/O, 40 RPM, 5-9K TQ
2,622.0 2,622.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown
Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program
Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________
ConocoPhillips Alaska, Inc. Development Exploratory
Stratigraphic Service 6. API Number:
7. Property Designation (Lease Number): 8. Well Name and Number:
9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s):
11. Present Well Condition Summary:
Total Depth measured 18,350 feet feet
true vertical 4,360 feet feet
Effective Depth measured 18,350 feet 12,288 / 12,195 feet
true vertical 4,360 feet 4,031 / 4,020 feet
Perforation depth Measured depth N/A feet
True Vertical depth N/A feet
Tubing (size, grade, measured and true vertical depth) 4.5" 12.6# L80 12,323' MD 4,036' TVD
SLZXP LTP 12,288' MD 4,031' TVD
Packers and SSSV (type, measured and true vertical depth) HAL TNT 12,195' MD 4,020' TVD
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
13.
Prior to well operation:
Subsequent to operation:
15. Well Class after work:
Daily Report of Well Operations Exploratory Development Service Stratigraphic
Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL
Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG
Sundry Number or N/A if C.O. Exempt:
Contact Name:
Contact Email:
Authorized Title: Contact Phone:
3090
5410, 8530
5020
5750
7240, 11220
Burst Collapse
2260
120
2385
3447
4059
4-1/2"
8324
12476
18,340 4355
7"
measuredPlugs
Junk measured
1.633MMlbs 20/40 Wan-Li Ceramic proppant, 51,748 lbs of 100 Mesh, 758 bbls of seawater, and 250 treating pressure/2450 BHG pressure.
Length
120
2716
Size
Conductor
Surface
Intermediate
20"
13-3/8"
9-5/8"
Intermediate
Liner
8324
4306
6062
Casing
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
222-019
50-103-20839-00-00
Job logs attached
5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work:
ADL380077, ADL384211, ADL380082, ADL388903, ADL391587
Colville Delta - Narwhal Undefined Oil
P.O. Box 100360 Anchorage, AK 99510-03603. Address:
CD4-597
measured
true vertical
Packer
Representative Daily Average Production or Injection Data
Casing Pressure Tubing Pressure
0 5000
0 0
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
0
Gas-Mcf
MD
120
2716
15,616' - 18,236' MD
0
Structural
TVD
323-101
Sr Pet Eng:
7500
Sr Pet Geo: Sr Res Eng:
Authorized Name and Digital
Signature with Date:
WINJ WAG
0
Water-BblOil-Bbl
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
0
369
8430
907-265-6462
Baskoro Tejo
baskoro.tejo@cop.com
Completions Engineer
Development Service
GINJ SUSP SPLUG
Gas
G
Form 10-404 Revised 10/2021 Submit Within 30 days of Operations
Baskoro Tejo July 31, 2023
g
BaBaBaBaaBsksssoro Tejo
By Grace Christianson at 9:49 am, Aug 01, 2023
Prepared By:
Keegan Lambe
Daniel Faur
Nannook Crew
Intervals 1-7
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
otherwise. The application, therefore, by the user of this report or any part thereof, is solely at the users
own risk.
CD4-597
Conoco Phillips
Harrison Bay County, AK
Post Job Report
Stimulation Treatment
API: 50-103-20839
Prepared for: Baskoro Tejo
July 23, 2023
A-Sand Formation
30# 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
Appendix
Well Summary
Chemical Summary
Planned Design
Water Straps 7-21
Water Straps 7-22
Water Straps 7-23
Water Analysis 7-21
Water Analysis 7-22
Water Analysis 7-23
Real-Time QC
Event Log 7-21
Event Log 7-22
Event Log 7-23
Prejob Break Test Day 1
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
38 - 41
42 - 55
56 - 60
8 - 18
19
20 - 33
34 - 37
61 - 68
69 - 72
73
74
75
76 - 77
78
79
4
5
6 - 7
80
81
82
83
84
85
86
87
88
89
90
91
92
93
94
95
Conoco Phillips - CD4-597 TOC 2
527,953 gallons of 30# Delta
99,774 gallons of 30# Linear
0 gallons of Seawater
6,100 gallons of Freeze Protect
956,200 pounds of Wanli 20/40 Ceramic
35,000 pounds of 100M
514,015 gallons of 30# Delta
108,344 gallons of 30# Linear
2,956 gallons of Seawater
872,804 pounds of Wanli 20/40 Ceramic
36,000 pounds of 100M
Thank you,
Keegan Lambe
Senior Technical Professional
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 July 21, 2023 a stimulation treatment was performed in the A-Sand formation on the CD4-597 well in Harrison Bay
County, AK. The CD4-597 was a 7 stage Horizontal Sleeve Design. The proposed treatment consisted of:
The actual treatment fully completed 6 of 7 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:
Breaker schedules where adjusted from planned designs based on lab testing performed in the field and in Deadhorse. Planned
pumping schedules were adjusted from initial designs by customer.
Interval 4 was cut short from design due to all pumps starting to cavitate during the 3ppg proppant stage. Rate could not be
regained and the decision was made to flush the well and clean out pumps. After cleaning out pumps Interval 5 was pumped
without any complications.
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.
In interval 7, all remaining 100M was placed into the hopper from the castle leaving 0 behind in the castle. Estimating
approximatly 38000lbs of 20/40 was left in the castle. This was proppant that was leftover from the stage cut short and design
adjustments.
Conoco Phillips - CD4-597 Executive Summary 3
Conoco Phillips A-SandCD4-59750-103-20839*Exceeds 80% of burst pressure*Description OD (in) ID (in) Wt (#) GradeFUF (gal/ft)MD Top (ft)MD Btm (ft) Volume (gal)Tubular Burst Pressure (psi)Tubing4.5 3.958 12.6 L-80 0.6392 0 11,417 7,298 8,430Tubing4.5 3.958 12.6 L-80 0.6392 11,417 18,340 4,425 8,430Total18,34011,723ft1.05ft105.8ftft1.05ft105.8ftTop MD (ft)Btm MD (ft)Average TVD (ft)Interval #Formation DescriptorAverage Interval Temperature (F)Ball Drop Time (HH:MM)Ball Hit Time (HH:MM)JSV Drop (bbl)JSV Slow Down (bbl)JSV Hit (bbl)Early (bbl)Surface Seat Pressure (psi)Surface Peak Pressure (psi)Surface Differential (psi)BH Seat Pressure (psi)BH Peak Pressure (psi)BH Differential (psi)Rate at Shift (bpm)Toe18,234 18,236 4,3561Narwhal105.7NA NA NA NA NA NA NA NA NA NA NA NA NA17,838 17,840 4,3572Narwhal105.84:48:00 PM 5:00:00 PM 2,944 3,165 3,20213.51,304 4,162 2,858 2,710 5,627 2,917 10.217,470 17,472 4,3363Narwhal105.56:26:00 PM 6:39:00 PM 5,224 5,440 5,4818.91,258 3,969 2,711 2,659 5,363 2,704 10.116,800 16,802 4,2784Narwhal104.91:25:00 PM 1:43:00 PM 30 236 2814.7808 3,552 2,744 2,244 5,323 3,079 10.216,433 16,435 4,2765Narwhal104.96:00:00 PM 6:19:00 PM 2,493 2,693 2,7367.11,428 4,395 2,967 2,340 5,342 3,002 10.616,027 16,029 4,2736Narwhal104.99:48:00 AM 10:08:00 AM 0 194 2377.21,905 4,854 2,949 2,317 5,117 2,800 10.3Heel15,616 15,618 4,2677Narwhal104.811:15:00 AM 11:27:00 AM 1,778 1,966 2,0141.72,635 4,982 2,347 2,972 5,767 2,795 10.3237.79,98211,167 265.910,73910,50410,244Displacement to Top Sleeve/Perf (gal)(BBLS)11,655 277.511,402 271.5255.7250.1243.9Interval #1Max Pressure (psi)9,000Isolation TypeSwell PackerTreatment TubularsCustomerFormationLeaseAPIDateTemperature DataTemp. Gradient (°F/100 ft)BHST (°F)Directional Data4,3062,23718,340Directional Data2,2377/21/2023KOPTemperature DataSleeve/Perf Depth Sleeves723456Temp. Gradient (°F/100 ft)BHST (°F)TVD at Bottom PerfMD at Bottom Perf4,35718,236KOPAvg. TVDTotal MDConoco Phillips - CD4-597 Wellbore Information 4
CUSTOMERConoco Phillips APIBFD (lb/gal)8.54LAT 70.29217042LEASECD4-597SALES ORDEBHST (°F)106LONG-150.98903FORMATIONA-SandDATE Max Pressure (psi)9000*Exceeds 80% of burst pressure*Prop Slurry Design Clean Actual Clean Actual Clean Calculated Slurry Design Prop Calculated Prop BC-140X2 Losurf-300D MO-67 WG-36 OPTIFLO-HTE BE-6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total TotalCrosslinker Surfactant BufferInterval Number Description Description Description(ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (ppt) (ppt) (ppt)1-1 Shut-In Shut-In-1-2 Seawater Prime Up Pressure Test 5.0 1,000 588 14 140.151-3 Shut-In Shut-In-1-4 30# Linear DFIT 10.0 1,680 1,736 41 41 1.00 30.00 1.00 0.151-5 Shut-In Shut-In-1.001-6 30# Linear Step Rate Test 15.0 4,200 2,359 56 56 1.00 30.00 0.151-7 30# Delta Establish Stable Fluid 15.0 8,000 4,926 117 117 0.50 1.00 0.15 30.00 1.00 0.151-8 30# Delta Minifrac 25.0 12,600 13,175 314 314 0.50 1.00 0.15 30.00 1.00 0.151-9 30# Linear Flush 25.0 12,495 12,557 299 299 1.00 30.00 1.00 0.151-10 Shut-In Shut-In-1-11 30# Delta Establish Stable Fluid 25.0 8,000 6,859 163 163 0.50 1.00 0.15 30.00 1.00 0.151-12 30# Delta Pad 25.0 15,000 14,965 356 356 0.50 1.00 0.15 30.00 1.00 0.151-13 30# Delta Proppant Laden Fluid 100M 0.50 25.0 10,000 9,515 227 231 5,000 4,141 0.50 1.00 0.15 30.00 1.00 0.151-14 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 14,000 13,979 333 349 14,000 15,077 0.50 1.00 0.15 30.00 1.00 0.151-15 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 14,000 13,950 332 364 28,000 29,848 0.50 1.00 0.15 30.00 1.00 0.151-16 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 8,000 7,971 190 217 24,000 25,597 0.50 1.00 0.15 30.00 1.00 0.151-17 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 5,000 4,968 118 141 20,000 21,264 0.50 1.00 0.15 30.00 1.00 0.151-18 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 4,000 3,956 94 115 20,000 19,827 0.50 1.00 0.15 30.00 1.00 0.151-19 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 4,000 4,934 117 143 24,000 24,352 0.50 1.00 0.15 30.00 1.00 0.151-20 30# Delta Spacer and Ball Drop 25.0 1,200 1,480 35 35 0.50 1.00 0.15 30.00 1.00 0.152-1 30# Linear Displace Ball to Seat 25.0 11,402 11,641 277 277 1.00 30.00 1.00 0.152-2 30# Delta Establish Stable Fluid 15.0 8,400 5,272 126 126 0.50 1.00 0.15 30.00 1.00 0.152-3 30# Delta Pad 25.0 12,894 12,871 306 306 0.50 1.00 0.15 30.00 1.00 0.152-4 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 0.25 25.0 10,000 9,956 237 239 2,500 1,870 0.50 1.00 0.15 30.00 1.00 0.152-5 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 14,000 13,974 333 347 14,000 13,798 0.50 1.00 0.15 30.00 1.00 0.152-6 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 14,000 13,974 333 363 28,000 28,328 0.50 1.00 0.15 30.00 1.00 0.152-7 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 8,000 7,946 189 215 24,000 24,424 0.50 1.00 0.15 30.00 1.00 0.152-8 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 5,000 4,965 118 139 20,000 19,809 0.50 1.00 0.15 30.00 1.00 0.152-9 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 4,000 3,968 94 115 20,000 18,870 0.50 1.00 0.15 30.00 1.00 0.152-10 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 4,000 4,452 106 128 24,000 20,517 0.50 1.00 0.15 30.00 2.00 0.152-11 30# Delta Spacer and Ball Drop 25.0 1,200 1,030 25 25 0.50 1.00 0.15 30.00 1.00 0.153-1 30# Linear Displace Ball to Seat 25.0 11,167 11,411 272 272 1.00 30.00 1.00 0.153-2 30# Delta Establish Stable Fluid 15.0 8,400 5,189 124 124 0.50 1.00 0.15 30.00 1.00 0.153-3 30# Delta Pad 25.0 10,800 10,786 257 257 0.50 1.00 0.15 30.00 1.00 0.153-4 30# Delta Proppant Laden Fluid 100M 0.50 25.0 10,000 9,414 224 228 5,000 3,349 0.50 1.00 0.15 30.00 1.00 0.153-5 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 8,000 7,965 190 197 8,000 6,947 0.50 1.00 0.15 30.00 1.00 0.153-6 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 8,000 7,961 190 205 16,000 14,288 0.50 1.00 0.15 30.00 1.00 0.153-7 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 10,000 9,977 238 266 30,000 26,902 0.50 1.00 0.15 30.00 1.00 0.153-8 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 6,000 5,970 142 166 24,000 22,573 0.50 1.00 0.15 30.00 2.00 0.153-9 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 5,000 4,960 118 145 25,000 25,432 0.50 1.00 0.15 30.00 2.00 0.153-10 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 4,500 5,890 140 171 27,000 29,126 0.50 1.00 0.15 30.00 2.00 0.153-11 30# Linear Flush 25.0 11,587 11,613 277 277 1.00 30.00 1.00 0.153-12 Shut-In Shut-In-4-1 Shut-In Shut-In-4-2 Seawater Prime Up Pressure Test 5.0 1,000 1,234 29 290.154-3 Shut-In Shut-In-4-4 30# Linear Spacer and Ball Drop 15.0 1,200 1,291 31 31 1.00 30.00 1.50 0.154-5 30# Linear Displacement 15.0 10,739 10,813 257 257 1.00 30.00 1.50 0.154-6 30# Linear DFIT 10.0 1,680 1,691 40 40 1.00 30.00 1.50 0.154-7 Shut-In Shut-In-4-8 30# Delta Establish Stable Fluid 25.0 8,000 8,936 213 213 0.50 1.00 0.15 30.00 1.50 0.154-9 30# Delta Minifrac 25.0 8,820 8,808 210 210 0.50 1.00 0.15 30.00 1.50 0.154-10 30# Linear Flush 25.0 10,739 10,821 258 258 1.00 30.00 1.50 0.154-11 Shut-In Shut-In-4-12 30# Delta Establish Stable Fluid 15.0 8,000 6,290 150 150 0.50 1.00 0.15 30.00 1.50 0.154-13 30# Delta Pad 25.0 10,800 9,930 236 236 0.50 1.00 0.15 30.00 1.50 0.154-14 30# Delta Proppant Laden Fluid 100M 0.50 25.0 10,000 9,332 222 227 5,000 4,710 0.50 1.00 0.15 30.00 1.50 0.154-15 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 5,000 4,971 118 123 5,000 4,536 0.50 1.00 0.15 30.00 1.50 0.154-16 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 5,000 4,973 118 129 10,000 9,615 0.50 1.00 0.15 30.00 1.50 0.154-17 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 8,000 13,680 326 359 24,000 31,132 0.50 1.00 0.15 30.00 1.50 0.154-18 30# Linear Flush 25.0 10,739 10,895 259 259 1.00 30.00 2.00 0.1550-103-208390908735894Liquid Additives Dry AdditivesInterval 1Narwhal@ 18234 - 18236.36 ft 105.7 °FInterval 2Narwhal@ 17838 - 17840.36 ft 105.8 °FInterval 3Narwhal@ 17470 - 17472.36 ft 105.5 °FInterval 4Narwhal@ 16800 - 16802.36 ft 104.9 °FConoco Phillips - CD4-597 Actual Design 5
CUSTOMERConoco Phillips APIBFD (lb/gal)8.54LAT 70.29217042LEASECD4-597SALES ORDEBHST (°F)106LONG-150.98903FORMATIONA-SandDATE Max Pressure (psi)9000*Exceeds 80% of burst pressure*Prop Slurry Design Clean Actual Clean Actual Clean Calculated Slurry Design Prop Calculated Prop BC-140X2 Losurf-300D MO-67 WG-36 OPTIFLO-HTE BE-6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total TotalCrosslinker Surfactant BufferInterval Number Description Description Description(ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (ppt) (ppt) (ppt)50-103-208390908735894Liquid Additives Dry Additives5-1 Shut-In Shut-In-5-2 Seawater Prime Up Pressure Test 5.0 1,000 674 16 160.155-3 Shut-In Shut-In-5-4 30# Linear Spacer and Ball Drop 15.0 1,200 - 1.00 30.00 1.50 0.155-5 30# Delta Establish Stable Fluid 25.0 8,000 12,457 297 297 0.50 1.00 0.15 30.00 1.50 0.155-6 30# Delta Pad 25.0 10,739 10,726 255 255 0.50 1.00 0.15 30.00 1.50 0.155-7 30# Delta Proppant Laden Fluid 100M 0.50 25.0 10,000 10,952 261 267 5,000 5,520 0.50 1.00 0.15 30.00 1.50 0.155-8 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 5,000 4,969 118 123 5,000 4,710 0.50 1.00 0.15 30.00 1.50 0.155-9 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 5,000 4,960 118 129 10,000 10,200 0.50 1.00 0.15 30.00 1.50 0.155-10 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 6,500 6,467 154 176 19,500 20,656 0.50 1.00 0.15 30.00 1.50 0.155-11 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 6,000 5,943 142 168 24,000 25,000 0.50 1.00 0.15 30.00 1.50 0.155-12 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 5,500 5,452 130 160 27,500 28,198 0.50 1.00 0.15 30.00 2.00 0.155-13 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 5,000 4,949 118 150 30,000 30,617 0.50 1.00 0.15 30.00 2.00 0.155-14 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 2,000 3,869 92 111 14,000 17,856 0.50 1.00 0.15 30.00 2.00 0.155-15 30# Linear Flush 25.0 10,504 10,856 258 258 1.00 30.00 1.50 0.155-16 Shut-In Shut-In-6-1 Shut-In Shut-In-6-2 Seawater Prime Up Pressure Test 5.0 1,000 460 11 110.156-3 Shut-In Shut-In-6-4 30# Linear Spacer and Ball Drop 15.0 1,200 585 14 14 1.00 30.00 1.50 0.156-5 30# Delta Establish Stable Fluid 15.0 8,000 4,211 100 100 0.50 1.00 0.15 30.00 1.50 0.156-6 30# Delta Pad 15.0 9,450 9,605 229 229 0.50 1.00 0.15 30.00 1.50 0.156-7 30# Delta Proppant Laden Fluid 100M 0.50 25.0 10,000 15,339 365 374 5,000 8,394 0.50 1.00 0.15 30.00 1.50 0.156-8 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 5,000 4,960 118 123 5,000 4,763 0.50 1.00 0.15 30.00 1.50 0.156-9 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 5,000 4,975 118 129 10,000 9,580 0.50 1.00 0.15 30.00 1.50 0.156-10 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 6,500 6,466 154 174 19,500 19,078 0.50 1.00 0.15 30.00 1.50 0.156-11 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 6,000 5,956 142 168 24,000 24,363 0.50 1.00 0.15 30.00 2.00 0.156-12 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 5,500 5,956 142 171 27,500 27,529 0.50 1.00 0.15 30.00 2.00 0.156-13 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 5,000 5,956 142 174 30,000 30,054 0.50 1.00 0.15 30.00 2.00 0.156-14 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 4,100 4,501 107 128 28,700 19,261 0.50 1.00 0.15 30.00 2.00 0.156-15 30# Delta Spacer and Ball Drop 25.0 1,200 1,403 33 33 0.50 1.00 0.15 30.00 1.50 0.157-1 30# Delta Pad 25.0 9,700 11,520 274 274 0.50 1.00 0.15 30.00 2.00 0.157-2 30# Delta Proppant Laden Fluid 100M 0.50 25.0 10,000 6,206 148 150 5,000 1,870 0.50 1.00 0.15 30.00 1.50 0.157-3 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 5,000 4,985 119 124 5,000 4,676 0.50 1.00 0.15 30.00 1.50 0.157-4 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 5,000 4,963 118 128 10,000 9,005 0.50 1.00 0.15 30.00 1.50 0.157-5 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 6,500 6,472 154 173 19,500 17,709 0.50 1.00 0.15 30.00 1.50 0.157-6 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 6,000 5,953 142 166 24,000 22,916 0.50 1.00 0.15 30.00 1.50 0.157-7 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 5,500 5,461 130 159 27,500 27,587 0.50 1.00 0.15 30.00 2.00 0.157-8 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 5,000 5,461 130 162 30,000 30,299 0.50 1.00 0.15 30.00 2.00 0.157-9 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 4,100 4,067 97 127 28,700 28,211 0.50 1.00 0.15 30.00 2.00 0.157-10 30# Delta Proppant Laden Fluid Wanli 20/40 Ceramic 8.00 25.0 2,100 4,737 113 141 16,800 26,404 0.50 1.00 0.15 30.00 2.00 0.157-11 30# Linear Flush 25.0 9,982 10,075 240 240 1.00 30.00 2.00 0.157-12 Shut-In Shut-In-623,016 625,315 14,888 15,846 897,700 900,788Design Total (gal)Actual Total (gal)Design Total (lbs)Calculated Total (lbs)Ticket Total (lbs)BC-140X2 Losurf-300D MO-67 WG-36 OPTIFLO-HTE BE-6527,953 514,015 956,200 872,804 872,804(gal) (gal) (gal) (lbs) (lbs) (lbs)99,774 108,344 35,000 27,984 36,000 Initial Design Material Volume 264.0 627.7 79.2 18,831.8 841.8 94.2-2,956 - - - Actual Design Material Volume 257.0 622.4 77.1 18,670.8 847.6 93.8-6,100 - - - Physical Material Volume Pumped 250 625 80 18140 840 94.34-- - - - - Physical Material Volume Deviance -3% 0% 4% -3% -1% 1%-- -** IFS numbers for proppant are taken from software calculations based on multiple variablesMicroMotion Volume Pumped 253 608 76 18,877 831 --- -** Proppant is billed from Weight Ticket volumesMicroMotion Volume Deviance -2% -2% -2% 1% -2% - -- --Fluid Type30# Delta30# LinearSeawaterFreeze Protect-Proppant TypeWanli 20/40 Ceramic100M-----Interval 6Narwhal@ 16027 - 16029.36 ft 104.9 °FInterval 7Narwhal@ 15616 - 15618.36 ft 104.8 °FInterval 5Narwhal@ 16433 - 16435.36 ft 104.9 °FConoco Phillips - CD4-597 Actual Design 6
7/21/23 12:58
7/21/23 17:00
242 min
NA bpm
NA psi
NA psi
NA bbl
25.2 bpm
3,521 psi
3,564 psi
24.0 bpm
2,933 psi
2,988 psi
3,300 psi
1,727 hhp
167 psi
308 psi
743 psi
6.37 ppg
5
5
23 cP
83.8 F
8.7
Minifrac
16.560 bpm
2046 psi
2862 psi
25.17 bpm
3367 psi
3598 psi
135,965 lbs
4,141 lbs
140,106 lbs
140,106 lbs
100,678 gal 2,397 bbls
16,652 gal 396 bbls
588 gal 14 bbls
Wanli 20/40 Ceramic Pumped:
Proppant Summary
Total Proppant Pumped* :
Fluid Summary (by fluid description)
Average Visc:
Average Temp:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Max Rate:
Max Surface Pressure:
Max BH Pressure:
Interval Summary
CD4-597 - Narwhal - Interval 1
Interval Summary
Start Date/Time:
End Date/Time:
Average Missile Pressure:
Open Well Pressure:
Initial OA Pressure:
Average Surface Pressure:
Average Rate:
Max OA Pressure:
Minifrac Max Surface Pressure:
100M Pumped:
Proppant in Formation:
30# Delta Volume:
30# Linear Volume:
Seawater Volume:
Minifrac Max DH Pressure:
Dart/Ball Early :
Average pH:
Minifrac Average Rate:
Diagnostic method
Pump Time:
Initial BH Pressure (Breakdown):
Average BH Pressure:
Pumps Ending Stage:
Max Proppant Concentration:
Minifrac Average Pressure:
Minifrac Average DH Pressure:
Minifrac Max Rate:
Pumps Starting Stage:
Average Missile HHP:
Conoco Phillips - CD4-597 Interval Summary 7
14,965 gal 356 bbls
59,273 gal 1,411 bbls
1,480 gal 35 bbls
12,557 gal 299 bbls
2,359 gal 56 bbls
11,785 gal 281 bbls
13,175 gal 314 bbls
1,736 gal 41 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Wellhead opened at 12:58 7-21. DFIT was pumped from 12:59 to 13:04 for a total of 41bbl.
Max rate was 10.57bpm and average was 8.47bpm. Gel viscosity varried during the start of
the stage. After making adjustments held gel loading constant the remainder of the stage.
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.
DFIT Volume:
Proppant Laden Fluid Volume:
Spacer and Ball Drop Volume:
Interval Status:
Zach Thomas
Abdon Gamez
Kyle Metzgar
Chad Burkett
Keegan Lambe
Minifrac Volume:
Fluid Summary (by stage description)
Flush Volume:
Step Rate Test Volume:
Establish Stable Fluid Volume:
Pad Volume:
Conoco Phillips - CD4-597 Interval Summary 8
7/21/23 17:00
7/21/23 18:39
99 min
10.2 bpm
4,162 psi
5,627 psi
13 bbl
25.2 bpm
3,486 psi
3,460 psi
23.3 bpm
2,706 psi
2,751 psi
3,107 psi
1,542 hhp
NA psi
743 psi
750 psi
6.26 ppg
5
5
23 cP
85.9 F
8.7
127,616 lbs
0 lbs
127,616 lbs
127,616 lbs
78,408 gal 1,867 bbls
11,641 gal 277 bbls
11,641 gal 277 bbls
12,871 gal 306 bbls
59,235 gal 1,410 bbls
1,030 gal 25 bbls
5,272 gal 126 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Status:
Proppant was left in hopper prior to starting stage. Pumped 20/40 instead of 100M at 0.25ppg.
Started wet proppant in 5.00ppg proppant. 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
Zach Thomas
Abdon Gamez
Kyle Metzgar
Wanli 20/40 Ceramic Pumped:
100M Pumped:
Total Proppant Pumped* :
30# Delta Volume:
30# Linear Volume:
Pad Volume:
Proppant Laden Fluid Volume:
Spacer and Ball Drop Volume:
Establish Stable Fluid Volume:
Average Visc:
Average Temp:
Average pH:
Max Proppant Concentration:
Pumps Starting Stage:
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:
CD4-597 - Narwhal - Interval 2
Average BH Pressure:
Average Missile HHP:
Open Well Pressure:
Initial OA Pressure:
Max OA Pressure:
Pumps Ending Stage:
Proppant Summary
Proppant in Formation:
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Displace Ball to Seat Volume:
Conoco Phillips - CD4-597 Interval Summary 9
7/21/23 18:39
7/21/23 20:06
87 min
10.1 bpm
3,969 psi
5,363 psi
9 bbl
25.2 bpm
3,081 psi
3,301 psi
23.7 bpm
2,620 psi
2,666 psi
3,107 psi
1,521 hhp
NA psi
755 psi
779 psi
6.49 ppg
5
5
23 cP
85.8 F
8.7
2419 psi
0.558 psi/ft
2346 psi
2319 psi
2300 psi
125,268 lbs
3,349 lbs
128,617 lbs
128,617 lbs
68,112 gal 1,622 bbls
23,024 gal 548 bbls
11,411 gal 272 bbls
10,786 gal 257 bbls
52,137 gal 1,241 bbls
11,613 gal 277 bbls
5,189 gal 124 bbls
Completed
Fluid Summary (by stage description)
Displace Ball to Seat Volume:
Pad Volume:
ISDP:
Final Fracture Gradient:
30# Delta Volume:
Interval Status:
CD4-597 - Narwhal - 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):
Initial Surface Pressure (Breakdown):
Start Date/Time:
Establish Stable Fluid Volume:
Max OA Pressure:
Wanli 20/40 Ceramic Pumped:
Average Missile HHP:
Average Temp:
Average Missile Pressure:
Average Surface Pressure:
Average BH Pressure:
Pumps Starting Stage:
Pumps Ending Stage:
Average pH:
Final 5 min:
30# Linear Volume:
100M Pumped:
Max Proppant Concentration:
Open Well Pressure:
Interval Summary
Proppant Laden Fluid Volume:
Initial OA Pressure:
Flush Volume:
Proppant Summary
Total Proppant Pumped* :
Proppant in Formation:
Fluid Summary (by fluid description)
Average Visc:
Final 10 min:
Final 15 min:
Conoco Phillips - CD4-597 Interval Summary 10
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
7/22/23 13:22
7/22/23 17:08
226 min
10.2 bpm
3,552 psi
5,323 psi
5 bbl
24.8 bpm
3,232 psi
3,286 psi
18.2 bpm
2,154 psi
2,167 psi
2,806 psi
960 hhp
206 psi
481 psi
713 psi
3.59 ppg
4
3
24 cP
86 F
8.5
Minifrac
16.240 bpm
1811 psi
2610 psi
24.78 bpm
3125 psi
3025 psi
2402 psi
0.561 psi/ft
2334 psi
2316 psi
2302 psi
45,283 lbs
4,710 lbs
49,993 lbs
49,993 lbs
Proppant Summary
Wanli 20/40 Ceramic Pumped:
Total Proppant Pumped* :
Average Surface Pressure:
Pumps Starting Stage:
Diagnostic method
Final Fracture Gradient:
Final 5 min:
100M Pumped:
Minifrac Max DH Pressure:
ISDP:
Max OA Pressure:
Max Proppant Concentration:
Average Visc:
Minifrac Average Rate:
Minifrac Average DH Pressure:
Average Rate:
Average Missile Pressure:
Average BH Pressure:
Average Missile HHP:
Pumps Ending Stage:
Minifrac Max Surface Pressure:
Final 10 min:
Final 15 min:
Max Surface Pressure:
Initial BH Pressure (Breakdown):
Pump Time:
Open Well Pressure:
Initial OA Pressure:
Max BH Pressure:
Minifrac Average Pressure:
Initial Surface Pressure (Breakdown):
Keegan Lambe
Zach Thomas
Abdon Gamez
End Date/Time:
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
CD4-597 - Narwhal - Interval 4
Interval Summary
Start Date/Time:
Dart/Ball Early :
Max Rate:
Average Temp:
Average pH:
Minifrac Max Rate:
Initial Rate (Breakdown):
Proppant in Formation:
Conoco Phillips - CD4-597 Interval Summary 11
66,920 gal 1,593 bbls
35,511 gal 846 bbls
1,234 gal 29 bbls
9,930 gal 236 bbls
32,956 gal 785 bbls
10,813 gal 257 bbls
1,291 gal 31 bbls
21,716 gal 517 bbls
15,226 gal 363 bbls
8,808 gal 210 bbls
1,691 gal 40 bbls
Cut Short
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Kyle Metzgar
Chad Burkett
Keegan Lambe
Zach Thomas
Fluid Summary (by fluid description)
Seawater Volume:
Fluid Summary (by stage description)
Flush Volume:
Interval Status:
Adjusted designs from origonal pump schedule. DFIT and Minifrac were pumped in this
interval. During 3ppg all pumps started to cavitate. Running wet proppant. Cut proppant to
clear fluid and attempted to get rate back. Switched to linear to flush well while attempting to
get rate back. Stage was called and the well was completely flushed. No tracer was dropped in Abdon Gamez
Pad Volume:
Minifrac Volume:
DFIT 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.
30# Delta Volume:
Establish Stable Fluid Volume:
Proppant Laden Fluid Volume:
Displacement Volume:
Spacer and Ball Drop Volume:
30# Linear Volume:
Conoco Phillips - CD4-597 Interval Summary 12
7/22/23 18:00
7/22/23 19:41
101 min
10.6 bpm
4,395 psi
5,342 psi
7 bbl
25.6 bpm
3,016 psi
3,223 psi
22.7 bpm
2,455 psi
2,437 psi
2,958 psi
1,366 hhp
490 psi
659 psi
722 psi
7.61 ppg
5
5
24 cP
89.1 F
8.7
2486 psi
0.581 psi/ft
2443 psi
2428 psi
2409 psi
137,237 lbs
5,520 lbs
142,757 lbs
142,757 lbs
70,744 gal 1,684 bbls
10,856 gal 258 bbls
674 gal 16 bbls
10,726 gal 255 bbls
47,561 gal 1,132 bbls
10,856 gal 258 bbls
12,457 gal 297 bbls
Completed
Interval Summary
Final 10 min:
Final 15 min:
Proppant Summary
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Wanli 20/40 Ceramic Pumped:
Pad Volume:
30# Linear Volume:
100M Pumped:
CD4-597 - Narwhal - Interval 5
Average BH Pressure:
Initial OA Pressure:
Max Proppant Concentration:
Start Date/Time:
Average Rate:
Proppant in Formation:
Seawater Volume:
Final 5 min:
Flush Volume:
Dart/Ball Early :
Average Missile HHP:
Open Well Pressure:
Average Visc:
Max Surface Pressure:
Pumps Starting Stage:
Pumps Ending Stage:
Final Fracture Gradient:
ISDP:
Interval Status:
Establish Stable Fluid Volume:
30# Delta Volume:
Pump Time:
Average Missile Pressure:
Max OA Pressure:
Initial BH Pressure (Breakdown):
Average pH:
Initial Surface Pressure (Breakdown):
Max Rate:
Total Proppant Pumped* :
Initial Rate (Breakdown):
End Date/Time:
Max BH Pressure:
Average Surface Pressure:
Average Temp:
Proppant Laden Fluid Volume:
Conoco Phillips - CD4-597 Interval Summary 13
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Keegan Lambe
Zach Thomas
Abdon Gamez
*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
Ball was dropped from hydraulic master. Establishing crosslink took significantly longer than
anticipated. Interval pumped to design.
Conoco Phillips - CD4-597 Interval Summary 14
7/23/23 9:48
7/23/23 11:27
99 min
10.3 bpm
4,854 psi
5,117 psi
7 bbl
24.9 bpm
4,859 psi
5,130 psi
20.7 bpm
2,571 psi
2,598 psi
3,042 psi
1,306 hhp
0 psi
436 psi
733 psi
7.55 ppg
5
5
24 cP
85.2 F
8.6
134,628 lbs
8,394 lbs
143,022 lbs
143,022 lbs
69,328 gal 1,651 bbls
585 gal 14 bbls
0 gal 0 bbls
9,605 gal 229 bbls
54,109 gal 1,288 bbls
1,988 gal 47 bbls
4,211 gal 100 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Zach Thomas
Abdon Gamez
*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
CD4-597 - Narwhal - Interval 6
Interval Summary
Average pH:
Proppant Summary
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Proppant Laden Fluid Volume:
Pumps Starting Stage:
Max Rate:
Average Missile Pressure:
Average Rate:
Open Well Pressure:
Interval Status:
Ball was dropped from the Hydraulic Master. Held 100M stage long to fully clean hopper out of
100M. Pumped the wet proppant in 1-3ppg. Rocks were noticed on top of blender screens in
4ppg. 7ppg cut was earlier than anticipated. Interval pumped to design
Keegan Lambe
Establish Stable Fluid Volume:
Max OA Pressure:
Proppant in Formation:
Wanli 20/40 Ceramic Pumped:
Average BH Pressure:
Freeze Protect Volume:
End Date/Time:
Max Surface Pressure:
Max BH Pressure:
Average Visc:
Average Temp:
Total Proppant Pumped* :
Start Date/Time:
Spacer and Ball Drop Volume:
100M Pumped:
Pumps Ending Stage:
Initial OA Pressure:
Pump Time:
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Dart/Ball Early :
30# Delta Volume:
30# Linear Volume:
Max Proppant Concentration:
Pad Volume:
Average Surface Pressure:
Initial Rate (Breakdown):
Average Missile HHP:
Conoco Phillips - CD4-597 Interval Summary 15
7/23/23 11:27
7/23/23 12:38
71 min
10.3 bpm
4,982 psi
5,767 psi
2 bbl
25.5 bpm
3,472 psi
3,150 psi
23.0 bpm
2,499 psi
2,524 psi
2,953 psi
1,406 hhp
NA psi
723 psi
753 psi
8.68 ppg
5
5
23 cP
86.8 F
8.7
2534 psi
0.594 psi/ft
2505 psi
2453 psi
2424 psi
166,807 lbs
1,870 lbs
168,677 lbs
168,677 lbs
59,825 gal 1,424 bbls
10,075 gal 240 bbls
11,520 gal 274 bbls
48,305 gal 1,150 bbls
10,075 gal 240 bbls
Completed
CD4-597 - Narwhal - Interval 7
End Date/Time:
Dart/Ball Early :
ISDP:
Average pH:
Initial OA Pressure:
Pumps Starting Stage:
Max Proppant Concentration:
Average Temp:
Average Missile HHP:
Average BH Pressure:
Average Surface Pressure:
Interval Summary
Final Fracture Gradient:
Interval Status:
Fluid Summary (by fluid description)
Final 5 min:
Proppant Summary
Max Rate:
Initial BH Pressure (Breakdown):
Start Date/Time:
Open Well Pressure:
Pumps Ending Stage:
Final 10 min:
Pad Volume:
Proppant Laden Fluid Volume:
Max OA Pressure:
30# Delta Volume:
Max Surface Pressure:
Max BH Pressure:
Average Rate:
Average Missile Pressure:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Average Visc:
Wanli 20/40 Ceramic Pumped:
100M Pumped:
Final 15 min:
30# Linear Volume:
Flush Volume:
Total Proppant Pumped* :
Proppant in Formation:
Fluid Summary (by stage description)
Pump Time:
Conoco Phillips - CD4-597 Interval Summary 16
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:Chad Burkett
100M ran out early from castle. Ran wet proppant until castle was empty. Switched at end of
5ppg to the dry proppant. Pumps cavitated in 8ppg. Interval pumped to design.
Kyle Metzgar
Keegan Lambe
Zach Thomas
Abdon Gamez
*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 - CD4-597 Interval Summary 17
CustomerFormationLeaseAPIDateWell SummaryWanli 20/40 Ceramic 100MTotal ProppantSurface Pressure Rate Visc Temp pH Surface Pressure Rate bbl gal bbl gal bbl gal bbl lbs lbs lbs12988 24.0 23 83.8 8.7 3521 25.2 2,397 16,652 396 588 14 117,918 2,808 135,965 4,141 140,106 22751 23.3 23 86 8.7 3486 25.2 1,867 11,641 277 90,049 2,144 127,616 127,616 32666 23.7 23 86 8.7 3081 25.2 1,622 23,024 548 91,136 2,170 125,268 3,349 128,617 42167 18.2 24 86 8.5 3232 24.8 1,593 35,511 846 1,234 29 103,665 2,468 45,283 4,710 49,993 52437 22.7 24 89 8.7 3016 25.6 1,684 10,856 258 674 16 82,274 1,959 137,237 5,520 142,757 62598 20.7 24 85 8.6 4859 24.9 1,651 585 14 460 11 70,373 1,676 134,628 8,394 143,022 72524 23.0 23 87 8.7 3472 25.5 1,424 10,075 240 69,900 1,664 166,807 1,870 168,677 Minimum1424 585 14 460 11 69900 1664 45283 1870 49993 Average1748 15478 369 739 18 89331 2127 124686 4664 128684 Maximum2397 35511 846 1234 29 117918 2808 166807 8394 168677 Wanli 20/40 Ceramic 100M Total ProppantPressure Rate Visc Temp pH Pressure Rate bbl gal bbl gal bbl gal bbl lbs lbs TotalPlanned12,570 99,774 2,376 0 0 633,827 15,091 867,700 30,000 991,200Recorded1511 13.0 14 50 5.05 4859 25.6 12,238 108,344 2,580 2,956 70 625,315 14,888 872,804 27,984 900,788Weight Tickets872,804 36,000 908,804** Proppant is billed from Weight Ticket volumes** IFS numbers for proppant are taken from software calculations based on Total FluidFluids ProppantsFluids ProppantsTotal FluidAverage MaxSeawater30# Delta 30# Linear30# Delta 30# LinearIntervalAverage MaxSeawaterJuly 21, 202350-103-20839CD4-597A-SandConoco Phillips Conoco Phillips - CD4-597 Fluid System-Proppant Summary 18
Hydraulic Fracturing Fluid Product Component Information Disclosure
2023-07-21
Alaska
Harrison Bay
50-103-20839
CONOCOPHILLIPS
l River Unit CD4-597
-150.9890
70.2921
NAD83
none
Oil
4358
625315
Hydraulic Fracturing Fluid Composition:
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)**
Ingredient Mass
lbs Comments Company First Name Last Name Email Phone
SEAWATER (SG
8.52) Halliburton Base Fluid Water 7732-18-5 100.00%85.05225%5327684 Density = 8.52 Halliburton
BC-140 X2 Halliburton Initiator Listed Below Listed Below 0
BE-6(TM)
Bactericide Halliburton Microbiocide Listed Below Listed Below 0
LoSurf-300D Halliburton Non-ionic Surfactant Listed Below Listed Below 0
LVT-200
Baker
Hughes Additive Listed Below Listed Below 0 NA
MO-67 Halliburton pH Control Listed Below Listed Below 0
OPTIFLO-HTE Halliburton Breaker Listed Below Listed Below 0 NA
SP BREAKER Halliburton Breaker Listed Below Listed Below 0
WG-36 GELLING
AGENT Halliburton Gelling Agent Listed Below Listed Below 0
Ceramic
Proppant - Wanli Wanli Proppant Listed Below Listed Below 0 NA
Sand-Common
White-100 Mesh,
SSA-2 Halliburton Proppant Listed Below Listed Below 0
GPT 3000-3014 ResMetrics Tracer Listed Below Listed Below 0 NA
OPT 2000-2050 ResMetrics Tracer Listed Below Listed Below 0 NA
WPT 1000-1050 ResMetrics Tracer Listed Below Listed Below 0 NA
Ingredients
Listed
Above Listed Above 1,2,4 Trimethylbenzene 95-63-6 1.00%0.00076%48
2,7-Naphthalenedisulfonic acid, 3-
hydroxy-4-[(4-sulfor-1-
naphthalenyl) azo] -, trisodium
salt 915-67-3 0.10%0.00004%3
2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00%0.00150%94
C.I. Pigment Red 5 6410-41-9 1.00%0.00013%9
Confidential Proprietary 0.10%0.00000%1 ResMetrics Product Stewardship
info@resmetr
ics.com 8325921900
Confidential Proprietary 100.00%0.00240%151 ResMetrics Product Stewardship
info@resmetr
ics.com 8325921900
Corundum 1302-74-5 65.00%9.05686%567323
Crystalline silica, quartz 14808-60-7 100.00%0.57873%36252
Cured acrylic resin Proprietary 1.00%0.00013%9
Denise Tuck,
Halliburton, 3000
N. Sam Houston
Pkwy E.,
Houston, TX
77032, 281-871-
6226 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Distillates (petroleum),
hydrotreated light 64742-47-8 100.00%0.00000%0
Ethanol 64-17-5 60.00%0.04550%2850
Ethylene glycol 107-21-1 30.00%0.01216%762
Glycol Ether Proprietary 0.85%0.00001%1 ResMetrics Product Stewardship
info@resmetr
ics.com 8325921900
Guar gum 9000-30-0 100.00%0.28959%18140
Heavy aromatic petroleum
naphtha 64742-94-5 30.00%0.02275%1425
Hemicellulase 9025-56-3 5.00%0.00067%42
Monoethanolamine borate 26038-87-9 100.00%0.04055%2540
Mullite 1302-93-8 45.00%6.27013%392762
Naphthalene 91-20-3 5.00%0.00379%238
Oxyalkylated nonyl phenolic resin Proprietary 30.00%0.02275%1425 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Oxyalkylated phenolic resin Proprietary 10.00%0.00758%475 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Poly(oxy-1,2-ethanediyl), alpha-(4-
nonylphenyl)-omega-hydroxy-,
branched 127087-87-0 5.00%0.00379%238
Polyamine Proprietary 30.00%0.00402%252 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Propylene Glycol 57-55-6 0.20%0.00000%1
Sodium chloride 7647-14-5 5.00%4.25275%266393
Sodium hydroxide 1310-73-2 30.00%0.00406%255
Sodium persulfate 7775-27-1 100.00%0.00000%0
Sodium sulfate 7757-82-6 0.10%0.00000%0
Walnut hulls NA 100.00%0.01341%840 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Water 7732-18-5 100.00%0.02570%1610
* Total Water Volume sources may include fresh water, produced water, and/or recycled water _
** Information is based on the maximum potential for concentration and thus the total may be over 100%
Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided.Version web 1.3
All component information listed was obtained from the suppliers Material Safety Data Sheets (MSDS). As such, the Operator is not responsible for inaccurate and/or incomplete information. Any questions regarding the content of the MSDS should be directed to the supplier who
provided it. The Occupational Safety and Health Administrations (OSHA) regulations govern the criteria for the disclosure of this information. Please note that Federal Law protects "proprietary", "trade secret", and "confidential business information" and the criteria for how this
information is reported on an MSDS is subject to 29 CFR 1910.1200(i) and Appendix D.
Production Type:
True Vertical Depth (TVD):
Total Water Volume (gal)*:
MSDS and Non-MSDS Ingredients are listed below the green line
Well Name and Number:
Longitude:
Latitude:
Long/Lat Projection:
Indian/Federal:
Fracture Date
State:
County:
API Number:
Operator Name:
Page 1/1Procedure CloseoutCD4-597Primary Job TypeSUPPORT OTHER OPERATIONSStart Date7/14/2023End Date Final Job StatusIN PROGRESSTotal Time Log Hours (hr)189.20SummaryNetwork/Order Number Project Desc Estimator10450750Start Date ZX Code Time Log Hrs (hr)Cum Time Log (days) Last 24hr Sum7/14/2023 ZX02 Fracturing 12.50 0.52 SPOT TANK FARM7/15/2023 ZX02 Fracturing 12.00 1.02 CONTINUE SPOTTING TANK FARM7/16/2023 ZX02 Fracturing 12.00 1.52 PT DISCHERGE/ LOADING MANIFOLD7/17/2023 ZX02 Fracturing 17.99 2.27 CREW SWAP/ LOAING/HEATING WATER7/18/2023 ZX02 Fracturing 23.98 3.27 LOADING/HEATING WATERFRAC SHACK-> ON LOCATION7/19/2023 ZX02 Fracturing 23.99 4.27 COMPLETE LOADING/HEATING WATERSPOT CASTLES, LOAD CHEMSFRAC SHACK SPOT INLOAD PROPPANT, 1 CASTLE FULL, 2 CASTLES INOPRABLEFINISH SPOTTING EQUIPMENT7/20/2023 ZX02 Fracturing 23.98 5.27 HAL-> REPAIR CASTLES, COMPLETE RIG IN TO WELL, SPOT BALL DROP PUMP, NIPPLE UP GOAT HEADLYNDEN-> CONTINUE PROPPANT LOADING, PRELOADING @MT6, INSTALL RESTRAINTAES-> CRANE WORK TYING ON THE DART LAUNCH TREE AND ROTARY, COMPLETE IRON TIE IN TO LAUNCH PUMPAES-> COMPLETED SCAFFOLD RIG IN AROUND LAUNCH ROTARYGREAT NORTH-> SPOT EQUIPMENT NIPPLE UP LAUNCH TREE AND ROTARY, RIG UP ACCUMULATOR TO LAUNCH TREEFRAC SHACK-> COMPLETED EQUIPMENT TIE IN7/21/2023 ZX02 Fracturing 20.64 6.13 WELL OPENED AT 12:59, OPENING PRESSURE 105, PERFORMED DFIT, STEP RATE TEST AND MINIFRAC, AFTER 30 MIN. SHUTDOWN PUMPED 3 FRAC INTERVALS, INTERVAL ONE, TOTAL PROPPANT 4,141 LB. 100 MESH, 135,965 LB. 20/40, 2,807 BBL CLEAN VOLUMEINTERVAL TWO, TOTAL PROPPANT 127,616 LB. 20/40, 2,144 BBL CLEAN VOLUMEINTERVAL THREE TOTAL PROPPANT 3,349 LB 100 MESH, 125,268 LB 20/40, 2,170 BBL CLEAN VOLUME7/22/2023 ZX02 Fracturing 23.97 7.13 DROPPED BALL 3.003 MEASURED PUMP DFIT, STEP RATE MINIFRAC, COMPLETED INTERVAL 4 INTERVAL 4 BALL DISPLACEMENT 285.7 JSV ACTUAL 281 JSV GOOD SEAT INDICATION, PUMPED 4710LB 100 MESH, 45283 20/40,RUNNING WET PROPPANT MIX, DURING THE 3LB STAGE PUMPS STARTED CAVITATING, CUT PROPPANT TO CLEAR PUMPS, NO RATE RETURN, CALLED FLUSH, CALLED THE STAGE. TOTAL CLEAN VOLUME 2,493 BBLCOMPLETED INTERVAL 5, DROPPED BALL 3.065 MEASURED DISPLACEMENT 2737 JSV, ACTUAL 2730 GOOD BALL SEAT JSV SIGNIFICANT TIME FOR CROSSLINK ESTABLISHMENT; PUMPED 5510 LB 100 MESH, 137,237 LB 20/40 TOTAL CLEAN VOLUME 1942 BBL7/23/2023 ZX02 Fracturing 18.15 7.88 COMPLETED STAGES 6 AND 7 STAGE 6, DROPPED AND SEATED MEASURED 3.126 BALL, DISPLACEMENT VOLUME 244 BBL ACTUAL 237 BBL DIFFERENTIAL PSI 2949, PUMPED 8,394 LB 100 MESH, 143,022 LB 20/40 CLEAN VOLUME 1,671 BBL, MAX PROPPANT PPG 7.55 AVG RATE 20.7 BPMSTAGE 7 DROPPED AND SEATED MEASURED 3.1905 DISPLACEMENT VOLUME 237.6 BBL ACTUAL 235 BBL,TRIPPED PUMPS ON BREAK OVER, DIFFERENTIAL PSI 2800, PUMPED 1,870 LB 100 MESH, 166,807 20/40 TOTAL CLEAN 1,664 BBL MAX PROPPANT PPG 8.68, AVG RATE 23 BPM
Page 11/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/7/2022
21:00
8/7/2022
22:00
1.00 SURFAC, DRILLOUT DRLG P DRILL CEMENT F/ 2,623.7' MD T/
2,711.5' MD @ 600 GPM, 728 PSI, 57%
F/O, 60 RPM, 3-10K
TQ, 4-6 WOB
2,622.0 2,711.0
8/7/2022
22:00
8/8/2022
00:00
2.00 SURFAC, DRILLOUT DRLG P DRILL SHOE F/ 2,711.5' MD T/ 2,716'
MD @ 500 GPM, 513 PSI, 50% F/O, 80
RPM, 3-10K TQ, 1-5
WOB
2,711.0 2,716.0
8/8/2022
00:00
8/8/2022
00:30
0.50 SURFAC, DRILLOUT COCF P DRILL RAT HOLE F/ 2,716' MD T/
2,721' MD @ 500 GPM, 500 PSI, 58%
F/O, 60 RPM, 3-10K TQ, 1-5
WOB
2,716.0 2,721.0
8/8/2022
00:30
8/8/2022
00:45
0.25 SURFAC, DRILLOUT COCF P WORKED THROUGH SHOE 3 TIMES
@ 500 GPM, 500 PSI, 58% F/O, 40
RPM, 6-7K TQ.
OBSERVED NO TORQUE OR
OVERPULL
2,721.0 2,721.0
8/8/2022
00:45
8/8/2022
01:15
0.50 SURFAC, DRILLOUT DDRL P DRILL NEW HOLE F/ 2,721' MD T/
2,741' MD @ 600 GPM, 700 PSI, 58%
F/O, 80 RPM, 3-10K TQ, 10
WOB
2,721.0 2,741.0
8/8/2022
01:15
8/8/2022
02:00
0.75 SURFAC, DRILLOUT CIRC P ROT AND RECIP, CIRC B/U F/ 2,741'
MD T/ 2,685' MD @ 600 GPM, 700 PSI,
55% F/O, 40 RPM, 6K
TQ. TOTAL STKS= 3,374 (398 BBLS)
2,741.0 2,685.0
8/8/2022
02:00
8/8/2022
02:30
0.50 SURFAC, DRILLOUT FIT P @ 2,685' MD R/U FOR LOT/FIT 2,685.0 2,685.0
8/8/2022
02:30
8/8/2022
03:30
1.00 SURFAC, DRILLOUT FIT T PERFORM LOT/FIT W/ 10.3 PPG
DRILLPLEX, PRESSURED UP T/ 524
PSI, ISOLATED WELL, AFTER 10
MIN PRESSURE BLED DOWN TO 220
PSI. PUMPED 2.6 BBLS, BLED 1 BBL
BACK TO PITS
LOT EQUAL OF 12.4 PPG
2,685.0 2,685.0
8/8/2022
03:30
8/8/2022
04:30
1.00 SURFAC, DRILLOUT FIT T PERFORM LOT/FIT W/ 10.3 PPG
DRILLPLEX, PRESSURED UP T/ 568
PSI, ISOLATED WELL, AFTER 10
MIN PRESSURE BLED DOWN TO200
PSI. PUMPED 2.7 BBLS, BLED 1 BBL
BACK TO PITS
LOT EQUAL OF 12.4 PPG
2,685.0 2,685.0
8/8/2022
04:30
8/8/2022
05:30
1.00 SURFAC, DRILLOUT CIRC T PUMPS UP WELL DATA TO MWD,
PJSM DISPLACE WELL WITH 11PPG
LSND MUD.
2,685.0 2,685.0
8/8/2022
05:30
8/8/2022
06:30
1.00 SURFAC, DRILLOUT CIRC T DISPLACE WELL F/ 10.3 PPG
DRILLPLEX T/ 11.0 PPG LSND. ROT
AND RECIP F/ 2,713' MD T/
2,685' MD @ 400 GPM, 244 PSI, 47%
F/O, 20 RPM, 6K TQ, ROT P/U WT=
115K, ROT S/O WT=
120K
TOTAL STKS PUMPED= 3487 (412
BBLS TO DISPLACE)
2,685.0 2,685.0
8/8/2022
06:30
8/8/2022
08:30
2.00 SURFAC, DRILLOUT CIRC T ROT / RECIP, F/ 2,710' MD T/ 2,685'
MD, 20 RPM, 3-4K TQ, 400 GPM, 300
PSI, 48% FO, PU=115
2,685.0 2,685.0
8/8/2022
08:30
8/8/2022
10:00
1.50 SURFAC, DRILLOUT OWFF T OBTAIN SPR'S OWFF STATIC
SPR’S @ 2,685’ MD, MW = 11.0 PPG
TIME: 08:30
#1 MP – 30SPM – 83 PSI, 40SPM – 113
PSI
#2 MP – 30SPM – 84 PSI, 40SPM – 114
PSI
2,685.0 2,685.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 12/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/8/2022
10:00
8/8/2022
10:30
0.50 SURFAC, DRILLOUT RURD T R/D AND BLOW DOWN TESTING
EQUIP
2,685.0 2,685.0
8/8/2022
10:30
8/8/2022
12:00
1.50 SURFAC, DRILLOUT STRP T POOH ON ELEVATORS F/ 2685' TO
524' MD P/U 50K
2,685.0 524.0
8/8/2022
12:00
8/8/2022
12:30
0.50 SURFAC, DRILLOUT OWFF T OWFF @ 524' PRIOR TO L/D BHA
(STATIC)
524.0 524.0
8/8/2022
12:30
8/8/2022
13:00
0.50 SURFAC, DRILLOUT TRIP T RACK BACK 1 STD DP AND HWDP IN
DERRICK F/ 524' T/ 154'
524.0 154.0
8/8/2022
13:00
8/8/2022
16:00
3.00 SURFAC, DRILLOUT BHAH T L/D BHA PER SLB REP 154.0 0.0
8/8/2022
16:00
8/8/2022
17:00
1.00 SURFAC, DRILLOUT CLEN T CLEAN / CLEAR RIG FLOOR OF ALL
BHA TOOLS AND EQUIPMENT
0.0 0.0
8/8/2022
17:00
8/8/2022
18:45
1.75 SURFAC, DRILLOUT WASH T M/U STACK WASHER, WASH STACK
@ 900 GPM
0.0 0.0
8/8/2022
18:45
8/8/2022
19:45
1.00 SURFAC, DRILLOUT PULD T PULL WEAR RING AND SET TEST
PLUG PER FMC REP
0.0 0.0
8/8/2022
19:45
8/8/2022
20:30
0.75 SURFAC, DRILLOUT RURD T R/U T/ TEST BOP 0.0 0.0
8/8/2022
20:30
8/8/2022
21:00
0.50 SURFAC, DRILLOUT BOPE T W/ 3 1/2" TEST JT, TEST ANNULAR
AND UPPER PIPE RAMS (3 1/2" X 6"
VBR'S
TESAT ANNULAR 250 PSI AND 2500
PSI
TEST RAMS 250 PSI AND 3500 PSI
0.0 0.0
8/8/2022
21:00
8/8/2022
21:30
0.50 SURFAC, DRILLOUT PULD T R/D TESTING EQUIPMENT 0.0 0.0
8/8/2022
21:30
8/8/2022
22:30
1.00 SURFAC, DRILLOUT PULD T PULL TEST PLUG, SET WEAR RING 0.0 0.0
8/8/2022
22:30
8/9/2022
00:00
1.50 SURFAC, DRILLOUT CLEN T CLEAN AND CLEAR RIG FLOOR, R/U
TO RUN 3 1/2" TBG
0.0 0.0
8/9/2022
00:00
8/9/2022
00:30
0.50 SURFAC, DRILLOUT RURD T CONT. TO CLEAN RIG FLOOR AND
CLEAR RIG FLOOR R/U TUBING
TONGS TO RUN 3.5" TUBING
0.0 0.0
8/9/2022
00:30
8/9/2022
03:30
3.00 SURFAC, DRILLOUT PUTB T HOLD PJSM P/U AND RUN 3.5" 9+.3#
L-80 HYD 563 TUBING AND X/O FROM
SURFACE TO 521' MAKE UP
CONNECTIONS TO 2900 FT/LBS S/O
WT 50K
0.0 521.0
8/9/2022
03:30
8/9/2022
05:00
1.50 SURFAC, DRILLOUT TRIP T TIH OUT OF DERRICK W 5 7/8" DRILL
PIPE F/ 521' TO 2687'
521.0 2,687.0
8/9/2022
05:00
8/9/2022
05:30
0.50 SURFAC, DRILLOUT WASH T WASH DOWN F/ 2,687' MD T/ 2,741'
MD @ 4 BPM, 103 PSI, 33% F/O, 10
RPM, 2K TQ.
TAG BOTTOM @ 2,741.89' MD W/ 3K
WOB
2,687.0 2,741.0
8/9/2022
05:30
8/9/2022
12:00
6.50 SURFAC, DRILLOUT CIRC T ROT AND RECIP F/ 2,734' MD T/ 2,687'
MD @ 4 BPM, 84 PSI, 33% F/O, 10
RPM, 2K TQ. WHILE
WAITING ON CEMENT LABS, SIMOPS
- TESTING MPD EQUIPMENT
OFFLINE (CHARTED),
CLEANING AND ORGANIZINING BOP
DECK
2,741.0 2,741.0
8/9/2022
12:00
8/9/2022
14:30
2.50 SURFAC, DRILLOUT CIRC T CONT. T/ ROT AND RECIP F/ 2,734'
MD T/ 2,687' MD @ 4 BPM, 72 PSI,
31% F/O, 10 RPM, 2K
TQ. WHILE WAITING ON CEMENT
LABS, SIMOPS-FINISH TESTING MPD
EQUIPMENT OFFLINE
(CHARTED), RIG UP PUP JTS,TIW'S,
AND CROSSOVERS FOR CEMENT
SWIVEL
2,741.0 2,734.0
8/9/2022
14:30
8/9/2022
15:00
0.50 SURFAC, DRILLOUT TRIP T POOH T/ 2,683, RACK BACK STD, P/U
5 7/8" SINGLE (31.57)
2,734.0 2,683.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 13/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/9/2022
15:00
8/9/2022
16:00
1.00 SURFAC, DRILLOUT CIRC T ROT AND RECIP F/ 2,712 MD' T/ 2,682
MD' @ 4BPM, 78 PSI, 32% F/O, 10
RPM, 2KTQ
2,712.0 2,712.0
8/9/2022
16:00
8/9/2022
17:00
1.00 SURFAC, DRILLOUT PULD T BLOW DOWN TOP DRIVE AND RIG
UP CEMENT SWIVEL, RIH F/ 2,712'
MD T/ 2,741' MD, S/O
WT= 99K. BREAK CIRCULATION
THROUGH CEMENT LINE @ 4 BPM,
108 PSI, 31% F/O, 10 RPM,
2K TQ
2,712.0 2,741.0
8/9/2022
17:00
8/9/2022
18:15
1.25 SURFAC, DRILLOUT CMNT T HOLD PJSM, CEMENTERS PUMP 25.7
BBLS 12.5 PPG MUDPUSH II,
FOLLOWED BY 52.5 BBLS
15.6 PPG TAIL CEMENT, FOLLOWED
BY 4.5 BBLS 12.5 MUDPUSH II. SWAP
OVER TO RIG
PUMP AND CHASE W/ 11.0 PPG LSND
@ 6 BPM, 68 PSI, 31% F/O, 20 RPM,
2.4K TQ. @ 318
STKS AWAY SLOW PUMPS TO 3 BPM,
26 PSI, 30% F/O, 20 RPM, 2.4K TQ.
PUMPS OFF @ 361
STKS AWAY
2,741.0 2,741.0
8/9/2022
18:15
8/9/2022
19:15
1.00 SURFAC, DRILLOUT RURD T L/D CEMENT SWIVEL, PUP, SINGLE
AND POOH ON ELEVATORS
RACKING BACK STDS F/
2,741' MD T/ 2,214' MD PULLING @ 20
FT/MIN, P/U WT= 87K
2,741.0 2,214.0
8/9/2022
19:15
8/9/2022
20:00
0.75 SURFAC, DRILLOUT CIRC T @ 2,214' MD CIRC X2 B/U AND
ROTATE @ 700 GPM, 327 PSI, 59%
F/O, 10 RPM, 1K TQ.
TOTAL STKS PUMPED= 5,254 (621
BBLS). PUMPED DOWN WIPER BALL
2,214.0 2,214.0
8/9/2022
20:00
8/9/2022
22:30
2.50 SURFAC, DRILLOUT SQEZ T PERFORM CEMENT SQUEEZE. SHUT
IN UPPER PIPE RAMS, PRESSURE
UP TO 200 PSI,
AFTER 2 HOURS OBSERVE BLEED
OFF TO 116 PSI. BLEED OFF ALL
PRESSURE AND LEAVE
WELL SHUT IN.
PUMPED 11 STKS (1.3 BBLS), BLED 1
BBL BACK TO MUD PITS.
2,214.0 2,214.0
8/9/2022
22:30
8/10/2022
00:00
1.50 SURFAC, DRILLOUT CLEN T PERFORM GENERAL
HOUSEKEEPING AROUND THE RIG,
WORK ON MP2'S. CLEAN CEMENT
VALVES ON MUD MANIFOLD, FLUSH
OUT 1502 PIECES.
2,214.0 2,214.0
8/10/2022
00:00
8/10/2022
06:00
6.00 SURFAC, DRILLOUT WOC T WAITING CEMENT TO SET TO 100
PSI COMPRESSIVE STRENGTH.
PERFORM GENERAL
HOUSEKEEPING AROUND THE RIG,
WORK ON MP2'S. CLEAN CEMENT
VALVES ON MUD MANIFOLD, FLUSH
OUT 1502 PIECES.
2,214.0 2,214.0
8/10/2022
06:00
8/10/2022
09:30
3.50 SURFAC, DRILLOUT WOC T WAITING ON CEMENT TO SET TO 100
PSI COMPRESSIVE STRENGTH.
TEST MPD CHOKES. CONT TO
WORK RIG PM'S, PREP FOR POOH.
STAGE PITS FOR INTERMEDIATE 1
HOLE SECTION.
2,214.0 2,214.0
8/10/2022
09:30
8/10/2022
10:30
1.00 SURFAC, DRILLOUT CIRC T CIRC B/U WHILE R/B STAND F/ 2,214'
MD T/ 2,116' MD W/ 700 GPM, 361 PSI,
61% F/O, P/U WT - 85K. TOTAL STKS
PUMPED - 4,363.
2,214.0 2,214.0
8/10/2022
10:30
8/10/2022
11:00
0.50 SURFAC, DRILLOUT OWFF T B/D TD. OWFF F/ 15 MIN (STATIC) 2,214.0 2,214.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 14/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/10/2022
11:00
8/10/2022
12:00
1.00 SURFAC, DRILLOUT TRIP T POOH ON ELEVATORS F/ 2,114' MD T/
521' MD.
2,214.0 521.0
8/10/2022
12:00
8/10/2022
13:00
1.00 SURFAC, DRILLOUT RURD T R/U CSG TONGS AND FLOOR
SAFETY VALVE.
521.0 521.0
8/10/2022
13:00
8/10/2022
14:30
1.50 SURFAC, DRILLOUT TRIP T L/D 3½ CEMENT STRING F/ 521' MD. 521.0 0.0
8/10/2022
14:30
8/10/2022
16:00
1.50 SURFAC, DRILLOUT RURD T R/D DOYON CSG RUNNING TOOLS.
SIMOPS - P/U INTERMEDIATE BHA
VIA BEAVERSLIDE
0.0 0.0
8/10/2022
16:00
8/10/2022
19:00
3.00 SURFAC, DRILLOUT BHAH T PJSM, MAKEUP BHA #2 TO 442' MD 0.0 442.0
8/10/2022
19:00
8/10/2022
20:45
1.75 SURFAC, DRILLOUT TRIP T RIH F/ 442' MD T/ 2,232' MD.
MONITOR DISPLACEMENT ON TT.
P/U WT - 118K, S/O WT - 108K.
442.0 2,232.0
8/10/2022
20:45
8/10/2022
22:00
1.25 SURFAC, DRILLOUT WASH T WASH DOWN FROM 2,232' MD W/ 84
GPM, 74 PSI 28% F/O T/ TOP OF
CEMENT @ 2,390' MD SETTING DN 7-
10K.
2,232.0 2,390.0
8/10/2022
22:00
8/10/2022
22:30
0.50 SURFAC, DRILLOUT REAM T WASH AND REAM DOWN F/ TOP OF
CEMENT AT 2,390' MD T/ 2,417' MD W/
606 GPM, 710 PSI, 58% F/O, 60 RPM,
5K TQ. ROT WT - 108K
2,390.0 2,417.0
8/10/2022
22:30
8/10/2022
23:15
0.75 SURFAC, DRILLOUT CIRC T ROTATE AND RECIPROCATE F/ 2,417'
MD T/ 2,354' MD W/ 606 GPM, 730 PSI,
58% F/O, 20 RPM, 5K TQ. TOTAL
STKS PUMPED - 5767
2,417.0 2,417.0
8/10/2022
23:15
8/11/2022
00:00
0.75 SURFAC, DRILLOUT PRTS T R/U AND TEST CSG TO 1125 PSI. 26
STKS TO PRESSURE UP (3 BBLS). 2
BBLS BLED BACK.
2,417.0 2,417.0
8/11/2022
00:00
8/11/2022
00:45
0.75 SURFAC, DRILLOUT PRTS T R/D AND B/D TESTING LINES 2,417.0 2,417.0
8/11/2022
00:45
8/11/2022
05:15
4.50 SURFAC, DRILLOUT DRLG T DRILL CEMENT F/ 2,417' MD T/ 2,718'
MD W/ 600 GPM, 705 PSI, 60 RPM,
5.5K TQ, 58% F/O, UP WT - 118K, S/O
WT - 108K, ROT WT - 117K
2,417.0 2,718.0
8/11/2022
05:15
8/11/2022
06:00
0.75 SURFAC, DRILLOUT CIRC T ROTATE AND RECIPROCATE F/ 2,718'
MD T/ 2,672' MD W/ 600 GPM, 719 PSI,
40 RPM, 5-7K TQ, 58% F/O, UP WT -
118K, S/O WT - 108K, ROT WT - 117.
TOTAL STKS PUMPED - 4054
2,718.0 2,718.0
8/11/2022
06:00
8/11/2022
07:30
1.50 SURFAC, DRILLOUT FIT T R/U AND FIT TO 13.1 EMW W/ 280
PSI. 5 STKS TO PRESSURE UP
AND .7 BBLS BLED BACK. R/D LINES.
2,718.0 2,718.0
8/11/2022
07:30
8/11/2022
08:30
1.00 SURFAC, DRILLOUT DRLG T DRILL CEMENT F/ 2,718' MD T/ 2,741
W/ 600 GPM, 733 PSI, 55% F/O, 10K
TQ, 7K WOB, UP WT - 118K, S/O WT -
114K, ROT WT - 113K
2,718.0 2,741.0
8/11/2022
08:30
8/11/2022
10:00
1.50 SURFAC, DRILLOUT CIRC T ROTATE AND RECIPROCATE F/ 2,741'
MD T/ 2,609' MD W/ 600 GPM, 732 PSI,
55% F/O, 20 RPM, 6K TQ, TOTAL
STKS PUMPED - 11,486
2,741.0 2,609.0
8/11/2022
10:00
8/11/2022
11:30
1.50 SURFAC, DRILLOUT LOT T R/U AND PERFORM LOT. 630 PSI
ACHIEVED (15.9 EMW) W/ 1.3 BBLS
PUMPED (11 STKS). A 20 MIN BLEED
DN OBSERVED PSI FALL TO 85 PSI.
BLEED REMAINING PSI OFF AND
GAIN .6 BBLS IN TRIP TANK. R/D AND
B/D TEST EQUIPMENT.
2,609.0 2,609.0
8/11/2022
11:30
8/11/2022
12:00
0.50 SURFAC, DRILLOUT CLEN T CLEAN AND PREP PITS FOR 300
BBLS DISPLACEMENT.
2,609.0 2,609.0
8/11/2022
12:00
8/11/2022
12:30
0.50 SURFAC, DRILLOUT CLEN T CONT CLEAN AND PREP PITS FOR
300 BBLS DISPLACEMENT.
2,609.0 2,609.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 15/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/11/2022
12:30
8/11/2022
13:30
1.00 SURFAC, DRILLOUT DISP T DISPLACE OUT 300 BBLS OF
CEMENT CONTAMINATED MUD T/
10.9 PPG LSND @ 370 GPM, 311 PSI,
45% F/O. TOTAL STKS PUMPED -
2623
2,609.0 2,609.0
8/11/2022
13:30
8/11/2022
18:00
4.50 INTRM1, DRILL DDRL P DRILL 12¼ INTERMEDIATE HOLE
SECTION #1 FROM 2,741' MD T/
3,137' MD – 2,587' TVD, 10K WOB
1000 GPM, 1720 PSI, 130 RPM, 6K TQ,
63% F/O, 11.70 ppg ECD,126K UP WT,
112K DN WT, 117K ROT WT. ADT =
3.36, TOTAL BIT HRS = 3.36 TOTAL
JAR HRS = 29.12
2,741.0 3,137.0
8/11/2022
18:00
8/12/2022
00:00
6.00 INTRM1, DRILL DDRL P DRILL 12¼ INTERMEDIATE HOLE
SECTION #1 FROM 3,137' MD T/
3,735' MD – 2,800' TVD, 10K WOB
1000 GPM, 1800 PSI, 130 RPM, 8K TQ,
63% F/O, 11.75 ppg ECD, 128 UP WT,
110K DN WT, 115K ROT WT. ADT =
4.52, TOTAL BIT HRS = 7.88 TOTAL
JAR HRS = 33.64
3,137.0 3,735.0
8/12/2022
00:00
8/12/2022
06:00
6.00 INTRM1, DRILL DDRL P DRILL 12¼ INTERMEDIATE HOLE
SECTION #1 FROM 3,735' MD T/
4,200' MD – 2,857' TVD, 12K WOB
1000 GPM, 1935 PSI, 130 RPM, 8K TQ,
63% F/O, 11.79 ppg ECD, 128 UP WT,
106K DN WT, 114K ROT WT. ADT
=4.83 , TOTAL BIT HRS = 12.71 TOTAL
JAR HRS = 38.47
3,735.0 4,200.0
8/12/2022
06:00
8/12/2022
12:00
6.00 INTRM1, DRILL DDRL P DRILL 12¼ INTERMEDIATE HOLE
SECTION #1 FROM 4,200' MD T/
4,486' MD – 2,895' TVD, 8K WOB 1000
GPM, 2057 PSI, 130 RPM, 8K TQ, 64%
F/O, 11.87 ppg ECD, 132 UP WT, 105K
DN WT, 115K ROT WT. ADT = 4.21 ,
TOTAL BIT HRS = 16.92 TOTAL JAR
HRS = 42.68
4,200.0 4,886.0
8/12/2022
12:00
8/12/2022
18:00
6.00 INTRM1, DRILL DDRL P DRILL 12¼ INTERMEDIATE HOLE
SECTION #1 FROM 4,486' MD T/
4,707' MD – 2,924' TVD, 7K WOB 1000
GPM, 2122 PSI, 130 RPM, 8K TQ, 65%
F/O, 11.91 ppg ECD, 136 UP WT, 106K
DN WT, 107K ROT WT. ADT = 5.37,
TOTAL BIT HRS = 22.29 TOTAL JAR
HRS = 48.05
4,886.0 4,707.0
8/12/2022
18:00
8/13/2022
00:00
6.00 INTRM1, DRILL DDRL P DRILL 12¼ INTERMEDIATE HOLE
SECTION #1 FROM 4,707' MD T/
5,144' MD – 2,990' TVD, 12K WOB
1000 GPM, 2100 PSI, 130 RPM, 10K
TQ, 64% F/O, 11.85 ppg ECD, 140 UP
WT, 106K DN WT, 117K ROT WT. ADT
= 5.22 , TOTAL BIT HRS = 27.51
TOTAL JAR HRS = 53.27
4,707.0 5,144.0
8/13/2022
00:00
8/13/2022
05:30
5.50 INTRM1, DRILL DDRL P DRILL 12¼ INTERMEDIATE HOLE
SECTION #1 FROM 5,144' MD T/
5,616' MD – 3,055' TVD, 10-12K WOB
1000 GPM, 2248 PSI, 130 RPM, 10K
TQ, 64% F/O, 11.85 ppg ECD, 140 UP
WT, 106K DN WT, 117K ROT WT. ADT
- 4.39, BIT HRS - 31.9, JAR HOURS -
57.66
5,144.0 5,616.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 16/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/13/2022
05:30
8/13/2022
12:00
6.50 INTRM1, DRILL BKRM P OBTAIN SPR'S. BROOH F/ 5,616' MD
T/ 4,675' MD @ 300 - 450' HR W/ 1000
GPM, 2200 PSI, 64% F/O, 120 RPM, 7K
TQ, ECD - 11.65, UP WT WHILE AT
FULL RATE - 110K. PUMP BIT
BALLING SWEEPS EVERY OTHER
STAND
5,616.0 4,675.0
8/13/2022
12:00
8/13/2022
18:00
6.00 INTRM1, DRILL BKRM P CONT TO BROOH F/ 4,675' MD T/
3458' MD. @ 400 - 450' HR W/ 1000
GPM, 2000 PSI, 64% F/O, 120 RPM, 7K
TQ, ECD - 11.65, UP WT WHILE AT
FULL RATE - 110K. PUMP BIT
BALLING SWEEPS EVERY OTHER
STAND
3,900' MD - CAT2 VOLUME - 85%
SMALL, LIGHT CLAY CUTTINGS
LOAD, INCREASE QUANITIY OF 4-8"
SIZE CHUNKS
3,670' MD CAT2 VOLUME - 85%
SMALL, LIGHT CLAY CUTTINGS
LOAD, OCCASIONAL OF 4-8" SIZE
CHUNKS
4,675.0 3,458.0
8/13/2022
18:00
8/13/2022
21:30
3.50 INTRM1, DRILL BKRM P CONT TO BROOH F/ 3,458' MD T/
2,698' MD. @ 300 - 500' HR W/ 1000
GPM, 1985 PSI, 64% F/O, 120 RPM, 7K
TQ, ECD - 11.65, UP WT WHILE AT
FULL RATE - 110K. PUMP BIT
BALLING SWEEPS EVERY OTHER
STAND OWFF WHILE AT THE SHOE
(STATIC)
SIMOPS - SERVICE THE TOP DRIVE
AT THE SHOE.
2,862' MD CAT2 VOLUME - 85%
SMALL, LIGHT CLAY CUTTINGS
LOAD, INCREASE IN SIZE RATIO
3,458.0 2,698.0
8/13/2022
21:30
8/14/2022
00:00
2.50 INTRM1, DRILL BKRM P CONT TO BROOH F/ 2,698' MD T/
1,945' MD. @ 600' HR W/ 1000 GPM,
1776 PSI, 64% F/O, 80 RPM, 4K TQ,
ECD - 11.33, UP WT WHILE AT FULL
RATE - 101K. CONTINUE TO PUMP
BIT BALLING SWEEPS EVERY
OTHER STAND
2,450' MD, CAT3 VOLUME - 60%
SMALL, 20% LARGE, LIGHT CLAY
CUTTINGS LOAD, LARGE INCREASE
OF MATERIAL ON SWEEP RETURNS.
1,760' MD, CAT3 VOLUME - 40%
SMALL, 40% LARGE, LIGHT CLAY
CUTTINGS LOAD, LARGE INCREASE
OF MATERIAL ON SWEEP RETURNS.
2,698.0 1,945.0
8/14/2022
00:00
8/14/2022
04:00
4.00 INTRM1, DRILL BKRM P CONT TO BROOH F/ 1,945' MD T/
1,228' MD. @ 600' HR W/ 1000
GPM,1615 PSI, 64% F/O, 80 RPM, 4K
TQ, ECD - 11.09 UP WT WHILE AT
FULL RATE - 90K. CONTINUE TO
PUMP BIT BALLING SWEEPS EVERY
OTHER STAND
1,530' MD CAT2 VOLUME - 50%
SMALL, 30% LARGE, DECREASING
CLAY CUTTINGS LOAD
1,220' MD CAT2 VOLUME - 90%
SMALL, MINIMAL CLAY CUTTINGS
LOAD
1,945.0 1,228.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 17/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/14/2022
04:00
8/14/2022
07:30
3.50 INTRM1, DRILL TRIP P RIH ON ELEVATORS F/ 1,228' MD T/
5,503' MD. MONITOR DISP VIA TT.
FILL PIPE EVERY 20 STANDS.
INCOUNTER OBSTRUCTION @ 5,504'
MD. SETTING DOWN 15K.
UNSUCCESSFUL ON PASSING BY
OBSTRUCTION.
1,228.0 5,503.0
8/14/2022
07:30
8/14/2022
09:00
1.50 INTRM1, DRILL REAM P P/U TO 5,472' MD, KELLY UP AND
SUCCESSFULLY REAM THROUGH
OBSTRUCTION @ 5,503' MD DOWN T/
5,516' MD W/ 700 GPM, 1282 PSI, 59%
F/O, 80 RPM, 7K TQ, 140K UP WT, S/O
WT - 104K, 117K ROT WT,
5,503.0 5,616.0
8/14/2022
09:00
8/14/2022
12:00
3.00 INTRM1, DRILL DDRL P DRILL 12¼ INTERMEDIATE HOLE
SECTION #1 FROM 5,616' MD T/
5,870' MD – 3,091' TVD, 7K WOB 1000
GPM, 2218 PSI, 150 RPM, 9K TQ, 64%
F/O, 11.74 ppg ECD, 140 UP WT, 110K
DN WT, 123K ROT WT. ADT - 2.46, BIT
HRS - 34.36, JAR HOURS - 60.12.
SIMOPS - DUMP/DILUTE 300 BBLS @
5,653' MD. CONT WITH BIT BALLING
SWEEPS. ADD CUP OF SAPP AT
CONNECTIONS
5,616.0 5,870.0
8/14/2022
12:00
8/14/2022
18:00
6.00 INTRM1, DRILL DDRL P DRILL 12¼ INTERMEDIATE HOLE
SECTION #1 FROM 5,870' MD T/
6,389' MD – 3,182' TVD, 9K WOB 1000
GPM, 2320 PSI, 150 RPM, 9K TQ, 63%
F/O, 11.91 ppg ECD, 143 UP WT, 113K
DN WT, 124K ROT WT. ADT - 5.54, BIT
HRS - 39.9, JAR HOURS - 65.66.
SIMOPS - CONT WITH BIT BALLING
SWEEPS. ADD CUP OF SAPP AT
CONNECTIONS
5,870.0 6,389.0
8/14/2022
18:00
8/15/2022
00:00
6.00 INTRM1, DRILL DDRL P DRILL 12¼ INTERMEDIATE HOLE
SECTION #1 FROM 6,389' MD T/
6,745' MD – 3,228' TVD, 10K WOB
1000 GPM, 2413 PSI, 150 RPM, 9K TQ,
63% F/O, 11.91 ppg ECD, 143 UP WT,
113K DN WT, 124K ROT WT. ADT -
4.2, BIT HRS - 44.1, JAR HOURS -
69.86. SIMOPS - CONT WITH BIT
BALLING SWEEPS, ADD CUP OF
SAPP AT CONNECTIONS
DUMP AND DILUTE 300 BBLS @
6,744' MD
6,389.0 6,745.0
8/15/2022
00:00
8/15/2022
06:00
6.00 INTRM1, DRILL DDRL P DRILL 12¼ INTERMEDIATE HOLE
SECTION #1 FROM 6,745' MD T/
7,215' MD – 3,288' TVD, 9K WOB 1000
GPM, 2425 PSI, 150 RPM, 9K TQ, 63%
F/O, 12.05 ppg ECD, 143 UP WT, 113K
DN WT, 124K ROT WT. .ADT - 5.05,
BIT HRS - 49.15, JAR HOURS - 74.91
SIMOPS - CONT WITH BIT BALLING
SWEEPS, ADD CUP OF SAPP AT
CONNECTIONS
6,745.0 7,215.0
8/15/2022
06:00
8/15/2022
12:00
6.00 INTRM1, DRILL DDRL P DRILL 12¼ INTERMEDIATE HOLE
SECTION #1 FROM 7,215' MD T/
7,551' MD – 3,337' TVD, 4K WOB 1000
GPM, 2448 PSI, 150 RPM, 10K TQ,
63% F/O, 11.93 ppg ECD, 153 UP WT,
113K DN WT, 130K ROT WT. ADT -
5.04, BIT HRS - 54.19, JAR HOURS -
79.95. SIMOPS - CONT WITH BIT
BALLING SWEEPS, ADD CUP OF
SAPP AT CONNECTIONS
7,215.0 7,551.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 18/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/15/2022
12:00
8/15/2022
18:00
6.00 INTRM1, DRILL DDRL P DRILL 12¼ INTERMEDIATE HOLE
SECTION #1 FROM 7,551' MD T/
7,950' MD – 3,395' TVD, 10K WOB
1000 GPM, 2558 PSI, 150 RPM, 10K
TQ, 63% F/O, 12.1 ppg ECD, 158 UP
WT, 129K DN WT, 129K ROT WT. ADT
- 5.34, BIT HRS - 59.53, JAR HOURS -
85.29. SIMOPS - CONT WITH BIT
BALLING SWEEPS, ADD CUP OF
SAPP AT CONNECTIONS
DUMP AND DILUTE 300 BBLS @
7,880' MD
7,551.0 7,950.0
8/15/2022
18:00
8/15/2022
23:30
5.50 INTRM1, DRILL DDRL P DRILL 12¼ INTERMEDIATE HOLE
SECTION #1 FROM 7,950 MD T/ 8,329'
MD – 3,450' TVD, 10K WOB 1000 GPM,
2617 PSI, 140 RPM, 10K TQ, 63% F/O,
12.14 ppg ECD, 161 UP WT, 115K DN
WT, 129K ROT WT. ADT - 4.53 BIT
HRS - 64.06, JAR HOURS - 89.82.
SIMOPS - CONT WITH BIT BALLING
SWEEPS, ADD CUP OF SAPP AT
CONNECTIONS
7,950.0 8,329.0
8/15/2022
23:30
8/16/2022
00:00
0.50 INTRM1, CASING CIRC P OBTAIN FINAL SPR'S AND SURVEY @
8,329' MD. PREP MUD PITS /
ROCKWASHER FOR 600 BBL DUMP
AND DILUTE.
8,329.0 8,329.0
8/16/2022
00:00
8/16/2022
06:00
6.00 INTRM1, CASING BKRM P BROOH F/ 8,329' MD T/ 7,123 @ W/
1000 GPM, 2348 PSI, 63% F/O, 150
RPM, 8K TQ, ECD - 12.11, 118K UP WT
AT RATE. SIMOPS - DUMP AND
DILUTE 600 BBLS OF 11.0 PPG LSND.
7,870' MD - CAT3 VOLUME - 95%
SMALL, MODERATE CLAY CUTTINGS
LOAD
7,250' MD - CAT3 VOLUME - 90%
SMALL, 5% LARGE, MODERATE
CLAY CUTTINGS LOAD, APPERANCE
OF LARGER CHUNKS
8,329.0 7,123.0
8/16/2022
06:00
8/16/2022
12:00
6.00 INTRM1, CASING BKRM P BROOH F/ 7,123' MD T/ 5,828' MD W/
1000 GPM, 2,153 PSI, 63% F/O, 150
RPM, 10K TQ, ECD - 11.59, 111K UP
WT AT RATE. SIMOPS. CONT TO
PUMP BIT BALLING SWEEPS EVERY
OTHER STAND
6,880,' MD CAT3 VOLUME - 90%
SMALL, MODERATE CLAY CUTTINGS
LOAD
MADD PASS AT 6,980' MD T/ 6,800' @
150 FT/HR
7,123.0 5,828.0
8/16/2022
12:00
8/16/2022
18:00
6.00 INTRM1, CASING BKRM P BROOH F/ 5,828' MD T/ 4,380' MD W/
1000 GPM, 2020 PSI, 63% F/O, 120
RPM, 8K TQ, ECD - 11.56, 111K UP WT
AT RATE. SIMOPS. CONT TO PUMP
BIT BALLING SWEEPS EVERY
OTHER STAND
5,435,' MD CAT3 VOLUME - 85%
SMALL, MODERATE CLAY CUTTINGS
LOAD OCCASIONAL 4-6" CHUNKS
MADD PASS AT 5,896' MD T/ 5,566'
MD @ 150 FT/HR.
5,828.0 4,380.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 19/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/16/2022
18:00
8/17/2022
00:00
6.00 INTRM1, CASING BKRM P BROOH F/ 4,380' MD T/ 2,982' MD W/
1000 GPM, 1843 PSI, 63% F/O, 80
RPM, 7K TQ, ECD - 11.33, 113K UP WT
AT RATE. SIMOPS. CONT TO PUMP
BIT BALLING SWEEPS EVERY
OTHER STAND
3,770' MD CAT3 VOLUME - 85%
SMALL, MODERATER CLAY
CUTTINGS LOAD, INCREASED
PRESENCE OF 4"-6" CHUNKS
3,220' MD CAT3 VOLUME - 90%
SMALL, MODERATER CLAY
CUTTINGS LOAD, SLIGHT
INCREASED IN LARGER CHUNKS
MADD PASS AT 3,530' MD T/ 3,200'
MD @ 150 FT/HR.
4,380.0 2,982.0
8/17/2022
00:00
8/17/2022
06:00
6.00 INTRM1, CASING BKRM P BROOH F/ 2,982' MD T/ 446 MD W/
1000 GPM, 1665 PSI, 63% F/O, 75
RPM, 2K TQ, ECD - 11.32, 73K UP WT
AT RATE. SIMOPS. CONT TO PUMP
BIT BALLING SWEEPS EVERY
OTHER STAND
2,980' MD CAT2 VOLUME - 90%
SMALL, LIGHT CLAY CUTTINGS
LOAD, DECREASE IN LARGER
MATERIAL
2,982.0 1,190.0
8/17/2022
06:00
8/17/2022
12:00
6.00 INTRM1, CASING BHAH P B/D TD, OWFF, PJSM, L/D BHA #2 AS
PER SLMB DD/MWD F/ 446' MD.
MONITOR DISP VIA TT. CLEAR AND
CLEAN RIG FLOOR.
1,190.0 0.0
8/17/2022
12:00
8/17/2022
13:00
1.00 INTRM1, CASING WWWH P M/U STACK FLUSHING TOOL. FLUSH
STACK @ 900 GPM, 155 PSI, 60% F/O.
PASSING THROUGH STACK 4X.
0.0 0.0
8/17/2022
13:00
8/17/2022
14:00
1.00 INTRM1, CASING RURD P PULL WEAR BUSHING AND INSTALL
TEST PLUG PER FMC REP.
0.0 0.0
8/17/2022
14:00
8/17/2022
17:00
3.00 INTRM1, CASING RURD P CLOSE BLIND/SHEAR RAMS. C/O
UPPER PIPE RAMS TO 9 5/8".
SIMOPS - R/D SQUEEZE JOB
CEMENT SWIVEL. PREP RIG FLOOR
FOR TESTING RAMS/ANNULAR
0.0 0.0
8/17/2022
17:00
8/17/2022
18:30
1.50 INTRM1, CASING BOPE P TEST 9 5/8" UPPER RAMS, ANNULAR,
& 4½ IF FOSV T/ 250 LOW, 3500 HIGH
F/ 5/5 CHARTED MIN.(GOOD) R/D &
B/D TEST EQUIPMENT.
0.0 0.0
8/17/2022
18:30
8/17/2022
21:30
3.00 INTRM1, CASING RURD P P/U & R/U 9 5/8" 40# L-80 CSG
RUNNING EQUIPMENT. SIMOPS -
M/U LANDING JT/PUP/9 5/8" HANGER
AND MAKE DUMMY RUN.
0.0 0.0
8/17/2022
21:30
8/17/2022
23:45
2.25 INTRM1, CASING PUTB P P/U AND M/U 9 5/8" SHOE TRACK T/
206' MD. BAKERLOK TO PIN END OF
JT #5. CHECK FLOATS (GOOD).
MONITOR DISP VIA PIT #5
0.0 206.0
8/17/2022
23:45
8/18/2022
00:00
0.25 INTRM1, CASING PUTB P RIH W/ 9 5/8" 40# L-80 TXP/H563 CSG
F/ 206' MD T/ 323' MD. MONITOR
DISP VIA PIT #5.
206.0 323.0
8/18/2022
00:00
8/18/2022
05:30
5.50 INTRM1, CASING PUTB P RIH W/ 9 5/8" 40# L-80 TXP/H563 CSG
F/ 323' MD T/ 2,710' MD. FILLING ON
THE FLY VIA VOLANT CRT. TOPPING
OFF EVERY 10 JTS. MONITOR DISP
VIA PIT #5. TORQUE TXP
CONNECTIONS TO 20,960 FT/LBS
323.0 2,710.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 20/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/18/2022
05:30
8/18/2022
06:45
1.25 INTRM1, CASING CIRC P AT 2,710' MD STAGE PUMPS UP F/ 2
BPM, 84 GPM, ICP - 121 PSI, 28% F/O
TO 8 BPM, 336 GPM, FCP - 206, 43%
F/O. TORQUE AND DRAG VALUES @
4 BPM - 146 PSI, 34% F/O - 20 RPM,
4K TQ, UP WT - 122K, S/O WT - 115K,
ROT WT - 118K
WITH OUT PUMPS - 20 RPM - 4K TQ,
UP WT - 127K, S/O WT - 118K, ROT
WT - 123K
2,710.0 2,710.0
8/18/2022
06:45
8/18/2022
13:15
6.50 INTRM1, CASING PUTB P RIH W/ 9 5/8" 40# L-80 TXP/H563 CSG
F/ 2,710' MD TO 5,375' MD. FILLING
ON THE FLY VIA VOLANT CRT.
TOPPING OFF EVERY 10 JTS.
MONITOR DISP VIA PIT #5. S/O WT -
124K. TORQUE TXP CONNECTIONS
TO 20,960 FT/LBS
OBSERVE DISPLACEMENT
INCORRECT AND 97 VIS RETURNS
ON MUD. DECISION MADE TO CIRC
2,710.0 2,710.0
8/18/2022
13:15
8/18/2022
15:45
2.50 INTRM1, CASING CIRC P RECIP PIPE F/ 5,370' MD T/ 5,390' MD
STAGING PUMPS UP F/ 94 GPM, 194
PSI, 28% F/O, T/ 300 GPM, 235 PSI,
40% F/O, UP WT - 153K, S/O WT -
120K. TOTAL STKS PUMPED - 6444.
2,710.0 5,390.0
8/18/2022
15:45
8/18/2022
19:00
3.25 INTRM1, CASING PUTB P RIH W/ 9 5/8" 40# L-80 TXP/H563 CSG
F/ 5,390' MD TO FINAL TXP XO JT AT
6,394' MD. FILLING ON THE FLY VIA
VOLANT CRT. TOPPING OFF EVERY
10 JTS. MONITOR DISP VIA PIT #5.
TORQUE TXP CONNECTIONS TO
20,960 FT/LBS
5,390.0 6,394.0
8/18/2022
19:00
8/19/2022
00:00
5.00 INTRM1, CASING PUTB P RIH W/ 9 5/8" 40# L-80 TXP/H563 CSG
F/ 6,394' MD TO 8,076' MD. FILLING
ON THE FLY VIA VOLANT CRT.
TOPPING OFF EVERY 10 JTS.
MONITOR DISP VIA PIT #5. TORQUE
HYDRILL 563 CONNECTIONS TO
13,000 FT/LBS
6,394.0 8,076.0
8/19/2022
00:00
8/19/2022
00:45
0.75 INTRM1, CASING PUTB P RIH W/ 9 5/8" 40# L-80 TXP/H563 CSG
F/ 8,076' MD TO 8,282' MD. FILLING
ON THE FLY VIA VOLANT CRT.
TOPPING OFF EVERY 10 JTS.
MONITOR DISP VIA PIT #5. TORQUE
HYDRILL 563 CONNECTIONS TO
13,000 FT/LBS
8,076.0 8,282.0
8/19/2022
00:45
8/19/2022
01:15
0.50 INTRM1, CASING PUTB P P/U LANDING JT. M/U HANGER. RIH
F/ 8,282' MD AND WASH DN @ 2 BPM,
118 PSI, 30% F/O. S/O WT - 123K.
LAND HANGER ON DEPTH @ 8,324'
MD.
8,282.0 8,324.0
8/19/2022
01:15
8/19/2022
03:30
2.25 INTRM1, CEMENT CIRC P RECIP PIPE F/ 8,324' MD TO 8,304'
MD CONDITION MUD AS PER SLMB
MUD ENGINEER, STAGING PUMPS
UP F/ 2 BPM, 84 GPM, ICP - 118, 30%
F/O TO 7 BPM, 300 GPM, FCP - 312,
40% F/O. UP WT - 200K, S/O WT -
130K
8,324.0 8,324.0
8/19/2022
03:30
8/19/2022
04:15
0.75 INTRM1, CEMENT RURD P B/D TD. INSTALL CEMENT HOSE AND
MANIFOLD TO VOLANT CRT.
8,324.0 8,324.0
8/19/2022
04:15
8/19/2022
06:00
1.75 INTRM1, CEMENT CIRC P CONT TO RECIP PIPE F/ 8,324' MD TO
8,304' MD CONDITION MUD AS PER
SLMB MUD ENGINEER, RAMP
PUMPS UP TO 7 BPM, 300 GPM, 470
PSI, 40% F/O. UP WT - 200K, S/O WT
- 130K
8,324.0 8,324.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 21/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/19/2022
06:00
8/19/2022
09:45
3.75 INTRM1, CEMENT CMNT P SWAP TO CEMENTERS. FLOOD
LINES W/ WATER AND PT TO 3500
PSI (GOOD). RECIP PIPE F/ 8,324'
MD T/ 8,304' MD. PUMP 63 BBLS 13.0
PPG MUD PUSH @ 4 BPM, 250 PSI,
30% F/O. DROP BTM PLUG. CHASE
PLUG WITH 141 BBLS OF 15.8 PPG
CEMENT@ 4.4 BPM, 34% F/O 200 PSI.
DROP TOP PLUG. CHASE PLUG W/
20 BBLS OF WATER @ 5.3 BPM, 140
PSI, 25% F/O. SWAP TO RIG PUMPS.
PUMP TREATED 11.0 LSND AT 6 BPM,
ICP - 250, FCP - 450, 38% F/O. UP WT
- 200K, S/O WT - 130K. AT 4700 STKS
OBSERVE HOOKLOAD DROP TO 88K
SET CSG ON HANGER. REDUCE
RATE TO 3 BPM, 380 PSI, 30% F/O.
BUMP PLUG AT 5097 STKS.
PRESSURE UP T/ 900 PSI. HOLD FOR
5 MIN. BLEED OFF CHECK FLOATS
(GOOD). CIP @ 9:45.
8,324.0 8,324.0
8/19/2022
09:45
8/19/2022
13:00
3.25 INTRM1, CEMENT RURD P B/O TOP PUP ON LANDING JT, L/D
LANDING JT, R/D CSG RUNNING
EQUIPMENT, CLEAR AND CLEAN RIG
FLOOR.
8,324.0 8,324.0
8/19/2022
13:00
8/19/2022
14:30
1.50 INTRM1, CEMENT WWSP P P/U AND SET 13 3/8" X 9 5/8"
PACKOFF AS PER FMC. TEST TO
5,000 PSI FOR 10 MIN. WITNESSED
BY CPAI REP.
8,324.0 8,324.0
8/19/2022
14:30
8/19/2022
17:00
2.50 INTRM1, CEMENT RURD P C/O SAVER SUB TO 4½ IF. SIMOPS -
CHANGE UPPER RAMS TO 3½ X 6
VBR'S.
8,324.0 8,324.0
8/19/2022
17:00
8/20/2022
00:00
7.00 INTRM1, CEMENT RURD P PROCESS 5" DP, 4" DP, AND
INTERMEDIATE 2 BHA IN PIPESHED.
SIMOPS - C/O CHARGE PUMP ON #1
MP. C/O MUD PUMP #2 LINERS TO
5½.. COMPLETE MP2 ON
ACCUMULATOR BACK UP BOTTLES.
8,324.0 8,324.0
8/20/2022
00:00
8/20/2022
02:00
2.00 INTRM1, WHDBOP BOPE P INSTALL TEST PLUG. FLOOD LINES
AND SHELL TEST BOPE T/ 3500 PSI.
(GOOD)TEST BOPE TO 250 LOW,
3500 HIGH F/ 5/5 CHARTED MIN W/ 4
AND 5" TEST JTS. SIMOPS - DRESS
#1 PUMP WITH 5½ SWABS/LINERS.
8,324.0 8,324.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 22/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/20/2022
02:00
8/20/2022
11:30
9.50 INTRM1, WHDBOP BOPE P TEST BOPE W/ 5" TEST JT, TEST
ANNULAR T/ 250 LOW, 2500 HIGH.
TEST UPPER & LOWER VBR'S,
CHOKE VALVES 1-14, MEZZ KILL,
MUD MANIFOLD KILL, HCR KILL. MAN
KILL, 2 EA 4½ IF FOSV AND 1 EA
DART, 2EA XT39 FOSV AND 1 EA
DART. UPPER IBOP - LOWER IBOP
(failed), BLIND/SHEAR RAMS TO 250
LOW, 3500 HIGH, W/ 4" TEST JT
TEST ANNULAR TO 250 LOW, 2500
HIGH, UPPER AND LOWER VBR'S,
MAN CHOKE, HCR CHOKE TO 250
LOW, 3500 HIGH, MANUAL AND HYD
CHOKES TESTED TO 250 LOW, 2000
HIGH, PERFORM ACC DRAWDOWN
TEST - ACC-3000 PSI, MANIF - 1500
psi, ACC - 1800 AFTER ALL
FUNCTIONS, 10 SEC TO BUILD 200
PSI, 52 SEC TO BUILD FULL SYSTEM
PSI W/ 2 AIR PUMPS AND 2
ELECTRICAL PUMPS, TEST PVT GAIN
-LOSS, FLOW OUT, & H2S AND LEL.
AOCGG REP GUY COOK WAIVED
WITNESS TO THE TEST AT 06:49 ON
8-19-22
8,324.0 8,324.0
8/20/2022
11:30
8/20/2022
13:00
1.50 INTRM1, WHDBOP RURD P PULL TEST PLUG C/O MASTER
BUSHINGS TO SPLIT MASTER
BUSHINGS. R/D & B/D TESTING
EQUIPMENT - (4 EA FOSV AND 2 EA
DART VALVES.)
8,324.0 8,324.0
8/20/2022
13:00
8/20/2022
18:00
5.00 INTRM1, WHDBOP LOT P ATTEMPT TO ANNULAR INJECT DN
13 3/8" X 9 5/8" ANNULAR W/ 11.0
PPG W/ RIG PUMPS. FAILED
(UNABLE TO ACHIEVE LOT)
OBSERVE 471 PSI(MAX) AT
SURFACE. SIMOPS - REMOVE
LOWER IBOP ON TDS-11.
8,324.0 8,324.0
8/20/2022
18:00
8/20/2022
20:30
2.50 INTRM1, WHDBOP RGRP T INSTALL NEW LOWER IBOP ON TDS-
11. RE-INSTALL TQ RINGS(X2). TQ
TO 185 FT/LBS. RE-TIE WIRE BOLTS.
TEST LOWER IBOP TO 250 LOW,
3500 HIGH F/ 5/5 CHARTED MIN
(GOOD).
8,324.0 8,324.0
8/20/2022
20:30
8/20/2022
21:30
1.00 INTRM1, WHDBOP RURD P R/D TEST EQUIPMENT. INSTALL 9” ID
SHORTY WEAR BUSHING AS PER
FMC. RILDS (X2).
8,324.0 8,324.0
8/20/2022
21:30
8/21/2022
00:00
2.50 INTRM1, DRILLOUT BHAH P P/U AND M/U INTERMEDIATE 2 BHA
AS PER SLMB DD T/ 161' MD.
MONITOR DISP VIA TT.
0.0 160.0
8/21/2022
00:00
8/21/2022
01:30
1.50 INTRM1, DRILLOUT BHAH P CONT TO P/U BHA F/ 161' MD T/ 620'
MD. MONITOR DISP VIA TT.
160.0 620.0
8/21/2022
01:30
8/21/2022
03:15
1.75 INTRM1, DRILLOUT PULD P RIH W/ INTERMEDIATE 2 BHA F/ 620'
MD T/ 2075' MD PICKING UP 4" XT39
DP 1X1. MONITOR DISP VIA TT.
620.0 2,075.0
8/21/2022
03:15
8/21/2022
03:45
0.50 INTRM1, DRILLOUT RGRP T BLACK OUT RIG. C-27 UNABLE TO
FIRE. CALL ELECTRICIAN TO
TROUBLESHOOT.
2,075.0 2,075.0
8/21/2022
03:45
8/21/2022
04:15
0.50 INTRM1, DRILLOUT SVRG P INSPECT AIR SLIP BACK SAVERS
AND SKATE.
2,075.0 2,075.0
8/21/2022
04:15
8/21/2022
04:45
0.50 INTRM1, DRILLOUT PULD P CONT TO RIH W/ INTERMEDIATE 2
BHA ON 4" XT39 DP 1X1 FROM
PIPESHED F/ 2,075' MD T/ 2,530' MD.
MONITOR DISP VIA TT. S/O WT - 74K
2,075.0 2,530.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 23/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/21/2022
04:45
8/21/2022
05:15
0.50 INTRM1, DRILLOUT DHEQ P SHALLOW HOLE TEST MWD @ 2,530'
MD AS PER DD W/ 500 GPM, 2111 PSI,
55% F/O.
2,530.0 2,530.0
8/21/2022
05:15
8/21/2022
07:15
2.00 INTRM1, DRILLOUT PULD P CONT TO RIH W/ INTERMEDIATE 2
BHA ON 4" XT39 DP 1X1 FROM
PIPESHED F/ 2,530' MD T/ 3,365' MD.
MONITOR DISP VIA TT. UP WT - 90K,
S/O WT - 98K.
2,530.0 3,365.0
8/21/2022
07:15
8/21/2022
11:00
3.75 INTRM1, DRILLOUT TRIP T OBSERVE INCORRECT RABBIT
BEING USED. STOP P/U PIPE AND
DROP 2.15 RABBIT INSTRING. POOH
ON ELEVATORS F/ 3,365' MD 620' MD
STANDING STANDS BACK IN THE
DERRICK. MONITOR DISP VIA TT.
FIND RABBIT IN FIRST JT OF HWDP.
3,365.0 620.0
8/21/2022
11:00
8/21/2022
13:15
2.25 INTRM1, DRILLOUT TRIP T RIH F/ 620' MD T/ 3,365' MD ON
ELEVATORS W/ 4" XT39 DP.
MONITOR DISP VIA TT. FILLING PIPE
EVERY 20 STDS.
620.0 3,365.0
8/21/2022
13:15
8/21/2022
15:30
2.25 INTRM1, DRILLOUT PULD P CONT TO RIH W/ INTERMEDIATE 2
BHA ON 4" XT39 DP 1X1 FROM
PIPESHED F/ 3,365' MD T/ 4,590' MD.
MONITOR DISP VIA TT. S/O WT - 94K
3,365.0 4,590.0
8/21/2022
15:30
8/21/2022
16:15
0.75 INTRM1, DRILLOUT CIRC P CIRC B/U W/ 445 GPM, 2082 PSI, 47%
F/O. TOTAL STKS PUMPED - 3784.
4,590.0 4,590.0
8/21/2022
16:15
8/21/2022
17:00
0.75 INTRM1, DRILLOUT PULD P CONT TO RIH W/ INTERMEDIATE 2
BHA ON 5"NC50 DP 1X1 FROM
PIPESHED F/ 4,590' MD T/ 4,719' MD.
MONITOR DISP VIA TT
4,590.0 4,719.0
8/21/2022
17:00
8/21/2022
22:30
5.50 INTRM1, DRILLOUT MPDA P PULL TRIP NIPPLE. INSTALL MPD
BEARING AND DRAIN NIPPLE.
COMMISION MPD CHOKES AND
TRAIN CREW.
4,719.0 4,719.0
8/21/2022
22:30
8/22/2022
00:00
1.50 INTRM1, DRILLOUT MPDA P CONT WITH TRAINING CREW ON
MPD OPS. PULL BEARING AND
DRAIN NIPPLE, INSTALL TRIP
NIPPLE.
4,719.0 4,719.0
8/22/2022
00:00
8/22/2022
01:30
1.50 INTRM1, DRILLOUT LOT P ATTEMPT TO ANNULAR INJECT DN
13 3/8" X 9 5/8" ANNULAR W/ 11.0
PPG W/ RIG PUMP. FAILED (UNABLE
TO ACHIEVE LOT) OBSERVE 533 PSI
(MAX) AT SURFACE @ 55 STKS
PUMPED(4.7 BBLS). BLED DN 10 PSI
IN 10 MIN. BLED BACK 1.4 BBLS TO
TT. R/D AND B/D SURFACE LINES.
4,719.0 4,719.0
8/22/2022
01:30
8/22/2022
07:00
5.50 INTRM1, DRILLOUT PULD P CONT TO RIH W/ INTERMEDIATE 2
BHA ON 5" NC50 DP 1X1 FROM
PIPESHED F/ 4,719' MD T/ 8,082' MD.
MONITOR DISP VIA TT. UP WT -
130K, S/O WT - 68K.
4,719.0 8,082.0
8/22/2022
07:00
8/22/2022
09:30
2.50 INTRM1, DRILLOUT SLPC P CUT AND SLIP 60' OF 1.375 DRILL
LINE. SIMOPS - CONDITION MUD W/
6 BPM, 250 GPM, 964 PSI, 36% F/O.
TOTAL STKS PUMPED - 8,769
8,082.0 8,082.0
8/22/2022
09:30
8/22/2022
11:00
1.50 INTRM1, DRILLOUT CIRC P ROT AND RECIP PIPE F/ 8,068' MD T/
8,082' MD W/ 448 GPM, 2,437 PSI,
51% F/O, 20 RPM, 8K TQ, UP WT -
130K, S/O WT - 68K. ROT WT - 103K.
TOTAL STKS PUMPED 16,282.
8,082.0 8,082.0
8/22/2022
11:00
8/22/2022
12:30
1.50 INTRM1, DRILLOUT PRTS P R/U AND TEST 9 5/8" CSG TO 3000
PSI FOR 30 CHARTED MIN (GOOD)
8,082.0 8,082.0
8/22/2022
12:30
8/22/2022
12:45
0.25 INTRM1, DRILLOUT PULD P CONT TO RIH W/ INTERMEDIATE 2
BHA ON 5" NC50 DP 1X1 FROM
PIPESHED F/ 8,082' MD T/ 8,184' MD.
8,082.0 8,184.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 24/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/22/2022
12:45
8/22/2022
13:15
0.50 INTRM1, DRILLOUT COCF P WASH DN F/ 8,184' MD TO TOP OF
PLUGS/CEMENT AT 8,235' MD W/ 400
GPM, 2,214PSI, 47% F/O. SET DN 8K,
S/O WT - 79K.
8,184.0 8,235.0
8/22/2022
13:15
8/22/2022
23:00
9.75 INTRM1, DRILLOUT DRLG P DRILL CEMENT PLUGS, FLOAT
COLLAR, CEMENT, SHOE, AND RAT
HOLE F/ 8,235' MD T/ 8329' MD W/ 500
GPM, 3360 PSI, 52% F/O, 30-60 RPM,
11TQ, 5-6 WOB.
8,235.0 8,329.0
8/22/2022
23:00
8/22/2022
23:15
0.25 INTRM1, DRILLOUT DDRL P DRILL AHEAD F/ 8,329' MD T/ 8,349'
MD W/ 500 GPM, 3270 PSI, 52% F/O,
60 RPM, 11.5TQ, 10 WOB.
8,329.0 8,349.0
8/22/2022
23:15
8/23/2022
00:00
0.75 INTRM1, DRILLOUT CIRC P ROT AND RECIP PIPE F/ 8,349' MD T/
8,183' MD W/ 500 GPM, 3164 PSI, 51%
F/O, 40 RPM, 10K TQ, UP WT - 98K,
S/O WT - 100K AT DRILLING RATE.
8,349.0 8,183.0
8/23/2022
00:00
8/23/2022
00:45
0.75 INTRM1, DRILLOUT CIRC P ROT AND RECIP PIPE F/ 8,349' MD T/
8,183' MD W/ 500 GPM, 3186 PSI, 51%
F/O, 40 RPM, 10K TQ, UP WT - 98K,
S/O WT - 100K AT DRILLING RATE.
TOTAL STKS PUMPED - 8618
8,183.0 8,349.0
8/23/2022
00:45
8/23/2022
01:30
0.75 INTRM1, DRILLOUT FIT P AT 8,279' MD FLOOD LINES, CLOSE
UPPER VBR'S AND PERFORM FIT W/
11.0 PPG LSND. ACHIEVE 840 PSI,
15.7 EMW, 2.1 BBLS PUMPED, 2 BBLS
BLED BACK.
8,349.0 8,279.0
8/23/2022
01:30
8/23/2022
02:30
1.00 INTRM2, DRILL MPDA P PULL TRIP NIPPLE, INSTALL MPD
BEARING AND DRAIN NIPPLE AS PER
BEYOND REP.
8,279.0 8,279.0
8/23/2022
02:30
8/23/2022
03:30
1.00 INTRM2, DRILL CIRC P WASH DN F/ 8,279' MD T/ 8,349' MD
W/ 500 GPM, 3300 PSI, 50% F/O, 40
RPM, 11K TQ, 99K S/O WT AT RATE.
SIMOPS - PJSM ON DISPLACING
WELL TO 9.2 PPG LSND
8,279.0 8,349.0
8/23/2022
03:30
8/23/2022
06:30
3.00 INTRM2, DRILL DISP P ROT AND RECIP PIPE F/ 8,349' MD T/
8,279' MD & DISPLACE 11.0 PPG
LSND W/ 9.2 PPG LSND @ 100 GPM,
ICP - 605 W/ MPD HOLDING 50 PSI
BACK PRESSURE, INCREASE RT TO
500 GPM, 1968 PSI, 60 RPM, 9K TQ,
55% F/O. UP WT - 122K, S/O WT -
77K, ROT WT - 104K. OBTAIN SPR'S.
8,349.0 8,349.0
8/23/2022
06:30
8/23/2022
12:00
5.50 INTRM2, DRILL DDRL P DRILL 8¾ INTERMEDIATE 2 HOLE
SECTION F/ 8,349' MD T/ 8,814' MD
3,521' TVD, WOB - 8-15K, GPM, 516,
1975 PSI, RPM, 140, 9K TQ, F/O % 54,
ECD - 11.32, UP WT - 128K, S/O WT -
72K, ROT WT - 99K. BIT HRS - 4.32
UNSUCCESSFUL HOLDING 410 PSI
ON CONNECTION - WELLBORE BLED
DN TO 50.
8,349.0 8,814.0
8/23/2022
12:00
8/23/2022
19:00
7.00 INTRM2, DRILL DDRL P DRILL 8¾ INTERMEDIATE 2 HOLE
SECTION F/ 8,814' MD T/ 9,124' MD,
3,566' TVD, WOB - 11K, GPM, 516,
2107 PSI, 140 PM, 12-14K TQ, F/O %
55, ECD - 11.39, UP WT - 148K, S/O
WT - 68K, ROT WT - 101K. BIT HRS -
7.92 HOLDING 400 - 410 PSI ON
CONNECTION VIA MPD
8,814.0 9,124.0
8/23/2022
19:00
8/23/2022
21:30
2.50 INTRM2, DRILL BKRM T OBSERVE POOR DRILLING
PERAMETERS, ie. (PACKOFFS, TQ
SWINGS). DECISION MADE TO
BROOH F/ 9,124' MD T/ 8,180' MD W/
509 GPM, 2037 PSI, 57% F/O, 120
RPM, 10K TQ, ECD - 11.18, 104K ROT
WT WHILE PULLING.
9,124.0 8,180.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 25/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/23/2022
21:30
8/23/2022
22:45
1.25 INTRM2, DRILL CIRC T ROT AND RECIP PIPE FROM 8,184'
MD T/ 8,085' MD. PUMP HI VIS
SWEEP S/S W/ 523 GPM, 2088 PSI,
54% F/O, 10.89 ECD, 60 RPM, 7 TQ.
UP WT 103K, S/O WT 97K WHILE AT
RATE. TOTAL STKS PUMPED - 9873.
OBSERVE 124K P/U WT, AND 54K S/O
WT. OBSERVE 10% CUTTINGS
INCREASE ON SWEEP RETURN.
8,180.0 8,085.0
8/23/2022
22:45
8/24/2022
00:00
1.25 INTRM2, DRILL CIRC T DROP 2.115 OD STEEL BALL AND
PUMP DN @ 250 GPM, 886 PSI, 36%
F/O. REDUCE RT AT 540 STKS T/ 125
GPM, 640 PSI, 30% F/O. BALL ON
SEAT AT 734 STKS. PRESSURE UP
TO 1953 PSI AND OBSERVE WELL
COMMANDER OPEN. CONT TO CIRC
@ 700 GPM, 2078 PSI, 60% F/O. ROT
AND RECIP PIPE F/ 8,180' MD T/
8,085' MD. SIMOPS - PUMP HI VIS
SWEEP S/S.
8,085.0 8,180.0
8/24/2022
00:00
8/24/2022
00:45
0.75 INTRM2, DRILL CIRC T CONT TO CIRC @ 700 GPM, 2078 PSI,
60% F/O. ROT AND RECIP PIPE F/
8,180' MD T/ 8,085' MD. SIMOPS -
PUMP HI VIS SWEEP S/S. TOTALS
STKS PUMPED - 12,909. OBSERVE
MINIMAL RETURNS ON SWEEP.
8,180.0 8,085.0
8/24/2022
00:45
8/24/2022
01:30
0.75 INTRM2, DRILL DHEQ T DROP 2.115 OD STEEL BALL AND
PUMP DN @ 250 GPM, 600 PSI, 40%
F/O. REDUCE RT AT 540 STKS T/ 135
GPM, 575 PSI, 34% F/O. BALL ON
SEAT AT 710 STKS. PRESSURE UP
TO 1929 PSI AND OBSERVE WELL
COMMANDER CLOSE. CONFIRM
CLOSED W/ MWD ACTIVATION AT 500
GPM.
8,085.0 8,180.0
8/24/2022
01:30
8/24/2022
02:30
1.00 INTRM2, DRILL TRIP T LINE UP MPD ON BACK SIDE VIA
PUMP #2 LINED UP TO RCD HEAD.
TIH F/ 8,180' MD T/ 9,025' MD. UP WT
- 124K, S/O WT - 85K. MONITOR DISP
VIA ACTIVE PITS.
8,180.0 9,025.0
8/24/2022
02:30
8/24/2022
03:30
1.00 INTRM2, DRILL CIRC T WASH DN AND CIRC B/U F/ 9,025' MD
T/ 9,124' MD W/ 500 GPM, 2046 PSI,
55% F/O, 76 RPM, 5K TQ, ECD - 10.8,
UP WT @ RATE - 103K, S/O WT AT
RATE - 102K. TOTAL STKS PUMPED -
6932
9,025.0 9,124.0
8/24/2022
03:30
8/24/2022
06:00
2.50 INTRM2, DRILL DDRL P DRILL 8¾ INTERMEDIATE 2 HOLE
SECTION F/ 9,124' MD T/ 9,335' MD
TVD 3,598' MD, WOB - 8K, GPM, 520,
2222 PSI, 120 PM, 9-11K TQ, F/O 55%,
ECD - 11.12, UP WT - 148K, S/O WT -
68K, ROT WT - 101K. BIT HRS - 9.69
HOLDING 400 - 410 PSI ON
CONNECTION VIA MPD PUMPING
NUT PLUG SWEEPS EVERY OTHER
STAND
9,124.0 9,335.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 26/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/24/2022
06:00
8/24/2022
10:00
4.00 INTRM2, DRILL DDRL P DRILL 8¾ INTERMEDIATE 2 HOLE
SECTION F/ 9,335' MD T/ 9,770' MD,
WOB - 9K, GPM, 515, 2140 PSI, 120
PM, 12-14K TQ, F/O % 55, ECD -
11.17, UP WT - 140K, S/O WT - 78K,
ROT WT - 104K. HOLDING 410 PSI ON
CONNECTION VIA MPD PUMPING
NUT PLUG SWEEPS EVERY OTHER
STAND. SIMOPS - LRS OPS - TEST
#1. LRS SPENT 2.5 HRS ATTEMPTING
TO FREEZE PROTECT THE OA. THEY
VARIED PERAMETERS AND FLOW
RATES TARGETING MAX PSI OF 530.
(PUMPED TOTAL OF 2.69 BBLS /
BLED BACK 2.34 bbls)
9,335.0 9,770.0
8/24/2022
10:00
8/24/2022
11:30
1.50 INTRM2, DRILL CIRC T OBSERVE 100% PACKOFF AT 9,770'
MD. REDUCE RATE TO 40-124 GPM,
RPM TO 80-20 AND PICK UP STRING
TO 9,690' MD. BLEED PSI TO 0.
RETUN RATE TO 42 GPM, 20 RPM
AND REGAIN RETURNS. CONT
SLACKING OFF T/ 9,770' MD
STAGING PUMPS UP TO RATE.
OBSERVE HOLE UNLOADING AT B/U.
9,770.0 9,770.0
8/24/2022
11:30
8/24/2022
12:00
0.50 INTRM2, DRILL DDRL P DRILL 8¾ INTERMEDIATE 2 HOLE
SECTION F/ 9,770' MD T/ 9,800' MD,
WOB - 9K, GPM, 515, 2140 PSI, 120
PM, 12-14K TQ, F/O % 55, ECD -
11.17, UP WT - 140K, S/O WT - 78K,
ROT WT - 104K. HOLDING 410 PSI ON
CONNECTION VIA MPD PUMPING
NUT PLUG SWEEPS EVERY OTHER
STAND
9,770.0 9,800.0
8/24/2022
12:00
8/24/2022
17:30
5.50 INTRM2, DRILL DDRL P DRILL 8¾ INTERMEDIATE 2 HOLE
SECTION F/ 9,800' MD T/ 10,205' MD,
WOB - 6K, GPM, 515, 2222 PSI, 120
PM, 10-15K TQ, F/O 55%, ECD -
11.36, UP WT - 154K, S/O WT - N/A,
ROT WT - 108K. HOLDING 410 PSI ON
CONNECTION VIA MPD PUMPING 10
bbl NUT PLUG SWEEPS EVERY
OTHER STAND. SIMOPS - LRS:
TEST #2 LRS 8 HRS ATTEMPTING TO
FREEZE PROTECT THE OA.. THEY
VARIED PERAMETERS AND FLOW
RATES TARGETING MAX PSI OF 530.
(PUMPED TOTAL OF 2.78 BBLS /
BLED BACK 1.28 BBLS)
9,800.0 10,205.0
8/24/2022
17:30
8/24/2022
19:15
1.75 INTRM2, DRILL CIRC T OBSERVE 100% PACKOFF AT 10,205'
MD. REDUCE RATE TO 42 GPM, RPM
TO 20-70 AND SLOWLY WORK UP
STRING TO 10,164' MD. BLEEDING
PSI TO 0 (3X) MAX PSI AT SURFACE -
830. REGAIN RETURNS. CONT TO
WORK STRING F/ 10,164' MD T/
10,250' MD STAGING PUMPS UP TO
512 GPM. TOTAL STKS PUMPED
8224. OBSERVE HOLE UNLOADING
AT B/U.
10,205.0 10,250.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 27/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/24/2022
19:15
8/25/2022
00:00
4.75 INTRM2, DRILL DDRL P DRILL 8¾ INTERMEDIATE 2 HOLE
SECTION F/ 10,205' MD T/ 10,445' MD,
WOB - 10K, GPM, 515, 2468 PSI, 140
PM, 13-17K TQ, F/O 55%, ECD -
11.45, UP WT - 146K, S/O WT - N/A,
ROT WT - 103K. BIT HRS - 20.91.
HOLDING 410 PSI ON CONNECTION
VIA MPD PUMPING 10 bbl NUT PLUG
SWEEPS EVERY STAND,AND
ADDING SAPP AT CONNECTIONS.
10,250.0 10,445.0
8/25/2022
00:00
8/25/2022
06:00
6.00 INTRM2, DRILL DDRL P DRILL 8¾ INTERMEDIATE 2 HOLE
SECTION F/ 10,445' MD T/ 10,825' MD,
WOB - 10K, GPM, 515, 2487 PSI, 120
PM, 13-17K TQ, 55% F/O, ECD - 11.44,
UP WT - 151K, S/O WT - N/A, ROT WT
- 101K. BIT HRS - 25.13. HOLDING 410
PSI ON CONNECTION VIA MPD
PUMPING 10 bbl NUT PLUG SWEEPS
EVERY STAND AND ADDING SAPP
AT CONNECTIONS.
10,445.0 10,825.0
8/25/2022
06:00
8/25/2022
12:00
6.00 INTRM2, DRILL DDRL P DRILL 8¾ INTERMEDIATE 2 HOLE
SECTION F/ 10,825' MD T/ 11,183' MD,
WOB - 12K, GPM, 519, 2433 PSI, 120
PM, 13-18K TQ, 55% F/O, ECD - 11.49,
UP WT - 151K, S/O WT - N/A, ROT WT
- 101K. BIT HRS - 29.37. HOLDING 410
PSI ON CONNECTION VIA MPD
PUMPING 10 bbl NUT PLUG SWEEPS
EVERY STAND AND ADDING SAPP
AT CONNECTIONS.
10,825.0 11,183.0
8/25/2022
12:00
8/25/2022
18:00
6.00 INTRM2, DRILL DDRL P DRILL 8¾ INTERMEDIATE 2 HOLE
SECTION F/ 11,183' MD T/ 11,570' MD,
WOB - 12K, GPM, 519, 2491 PSI, 120
PM, 13-18K TQ, 55% F/O, ECD - 11.49,
UP WT - 151K, S/O WT - N/A, ROT WT
- 101K. BIT HRS - 33.54 HOLDING 410
PSI ON CONNECTION VIA MPD
PUMPING 10 bbl NUT PLUG SWEEPS
EVERY STAND AND ADDING SAPP
AT CONNECTIONS.
11,183.0 11,570.0
8/25/2022
18:00
8/26/2022
00:00
6.00 INTRM2, DRILL DDRL P DRILL 8¾ INTERMEDIATE 2 HOLE
SECTION F/ 11,570' MD T/ 11,891' MD,
WOB - 8K, GPM, 520, 2536 PSI, 120
PM, 13-19K TQ, 55% F/O, ECD - 11.34,
UP WT - 177K, S/O WT - N/A, ROT WT
- 109K. BIT HRS 37.18 HOLDING 410
PSI ON CONNECTION VIA MPD
PUMPING 10 bbl NUT PLUG SWEEPS
EVERY STAND AND ADDING SAPP
AT CONNECTIONS.
11,570.0 11,891.0
8/26/2022
00:00
8/26/2022
06:00
6.00 INTRM2, DRILL DDRL P DRILL 8¾ INTERMEDIATE 2 HOLE
SECTION F/ 11891' MD T/ 12,241,' MD,
WOB - 6K, GPM- 520, 2343 PSI, 120
PM, 13-19K TQ, 55% F/O, ECD - 11.42
UP WT - 181K, S/O WT - N/A, ROT WT
- 109K. BIT HRS - 41.42 HOLDING 410
PSI ON CONNECTION VIA MPD
PUMPING 10 bbl NUT PLUG SWEEPS
EVERY STAND AND ADDING SAPP
AT CONNECTIONS.
11,891.0 12,241.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 28/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/26/2022
06:00
8/26/2022
10:00
4.00 INTRM2, DRILL DDRL P DRILL 8¾ INTERMEDIATE 2 HOLE
SECTION F/ 12,241' MD T/ 12,478,'
MD, WOB - 11K, GPM - 520, 2510 PSI,
120 PM, 13-19K TQ, 55% F/O, ECD -
11.38 UP WT - 185K, S/O WT - N/A,
ROT WT - 111K. BIT HRS - 44.02
HOLDING 410 PSI ON CONNECTION
VIA MPD PUMPING 10 bbl NUT PLUG
SWEEPS EVERY STAND AND
ADDING SAPP AT CONNECTIONS.
12,241.0 12,478.0
8/26/2022
10:00
8/26/2022
12:00
2.00 INTRM2, CASING CIRC P OBTAIN FINAL TQ & DRAG 185K UP
WT, NA S/O, 111K ROT WT. SHOOT
FINAL MWD SURVEY. CIRC
BOTTOMS UP AT DRILLING RATE 520
GPM, 2305 PSI, 120 RPM, 14K TQ,
WORK FULL STAND, RACK BACK
STAND AND CIRCULATE ANOTHER
BOTTOMS UP AT FULL RATE SAME
PERAMETERS TO 12,396' MD
12,478.0 12,396.0
8/26/2022
12:00
8/26/2022
18:00
6.00 INTRM2, CASING BKRM P BROOH @ 150-350 FT/HR F/ 12,396'
MD T/ 11,736' MD W/ 515 GPM, ICP -
2400, FCP - 2150 56% F/O, 10.98 ECD,
GAS UNITS - 39, 120 RPM, 13K TQ,
110K UP WT WHILE AT RATE. MADD
PASS F/ 11,974' MD T/ 11,721' MD @
150 FT/HR. MPD MAINTAINING 11.1
AT CONNECTIONS AND 11.0 WHILE
POOH. PUMPING 10 bbl NUT PLUG
SWEEPS EVERY OTHER STAND
12,396.0 11,736.0
8/26/2022
18:00
8/27/2022
00:00
6.00 INTRM2, CASING BKRM P BROOH @ 150-350 FT/HR F/ 11,736'
MD T/ 10,653' MD W/ 515 GPM, ICP -
2175, FCP - 2,208 56% F/O, 11.39
ECD, GAS UNITS - 62, 120 RPM, 13K
TQ, 107K UP WT WHILE AT RATE.
INCREASE MPD PSI TO 11.4 AT
CONNECTIONS AND 11.3 WHILE
POOH. MADD PASS F/ 11,074' MD T/
10,821' MD & 10,924' MD TO 10,721'
MD @ 150 FT/HR. PUMPING 10 bbl
NUT PLUG SWEEPS EVERY OTHER
STAND
11,736.0 10,653.0
8/27/2022
00:00
8/27/2022
06:00
6.00 INTRM2, CASING BKRM P BROOH @ 350-600 FT/HR F/ 10,653'
MD T/ 9,830' MD W/ 520 GPM, ICP -
2,208, FCP - 2178 56% F/O, 11.43
ECD, GAS UNITS - 41, 120 RPM, 11K
TQ, 107K UP WT WHILE AT RATE.
INCREASE MPD PSI TO 11.4 AT
CONNECTIONS AND 11.3 WHILE
POOH. MADD PASS F/ 10,674' MD TO
10,421' MD & 10,374' MD TO 10,121'
MD & 9,874' MD TO 9,830' MD @ 150
FT/HR.
10,653.0 9,830.0
8/27/2022
06:00
8/27/2022
12:00
6.00 INTRM2, CASING BKRM P BROOH @ 350-600 FT/HR F/ 9,830'
MD T/ 8,795' MD W/ 520 GPM, ICP -
2178, FCP - 2166 56% F/O, 11.18 ECD,
GAS UNITS - 44, 120 RPM, 11K TQ,
102K UP WT WHILE AT RATE.
INCREASE MPD PSI TO 11.4 AT
CONNECTIONS AND 11.3 WHILE
POOH. MADD PASS F/ 9,830' MD T/
9,521' MD & 8,984' MD TO 8,871' MD
@ 150 FT/HR. PUMPING 10 bbl NUT
PLUG SWEEPS EVERY OTHER
STAND
9,830.0 8,795.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 29/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/27/2022
12:00
8/27/2022
17:30
5.50 INTRM2, CASING BKRM P BROOH @ 150-350 FT/HR F/ 8,795'
MD T/ 8,182' MD W/ 520 GPM, ICP -
2166, FCP - 2058 56% F/O, 11.32 ECD,
GAS UNITS - 41, 120 RPM, 11K TQ,
107K UP WT WHILE AT RATE.
INCREASE MPD PSI TO 11.4 AT
CONNECTIONS AND 11.3 WHILE
POOH. PUMPING 10 bbl NUT PLUG
SWEEPS EVERY OTHER STAND
8,795.0 8,182.0
8/27/2022
17:30
8/27/2022
20:00
2.50 INTRM2, CASING CIRC P DROP 2.115 OD STEEL BALL AND
PUMP DN @ 126 GPM, 500 PSI, 24%
F/O. BALL ON SEAT AT 588 STKS.
PRESSURE UP TO 1966 PSI AND
OBSERVE WELL COMMANDER
OPEN. CONT TO CIRC @ 650 GPM,
2,009 PSI, 60% F/O. ROT AND RECIP
PIPE @ 60 RPM, 10K TQ F/ 8,182' MD
T/ 8,087' MD. TOTAL STKS PUMPED -
24,177.
8,182.0 8,087.0
8/27/2022
20:00
8/27/2022
22:00
2.00 INTRM2, CASING CIRC P DROP 2.115 OD STEEL BALL AND
PUMP DN @ 126 GPM, 602 PSI, 24%
F/O. BALL ON SEAT AT 602 STKS.
PRESSURE UP TO 1946 PSI AND
OBSERVE WELL COMMANDER
CLOSE. CONT TO CIRC @ 520 GPM,
2125 PSI, 53% F/O. ROT AND RECIP
PIPE@ 60 RPM, 10K TQ F/ 8,182' MD
T/ 8,087' MD. TOTAL STKS PUMPED -
13,151 SIMOPS - HOLD PJSM FOR
DISPLACING WELL TO 11.4 PPG
LSND
8,087.0 8,182.0
8/27/2022
22:00
8/28/2022
00:00
2.00 INTRM2, CASING DISP P DISPLACE WELLBORE FROM 9.2
PPG LSND TO 11.4 PPG LSND.
FOLLOWING MPD - MUD ENGINEER
PUMP SCHEDULE. ROT AND RECIP
PIPE F/ 8,182' MD T/ 8,,087' MD. ROT
W/ 60 RPM, 6K TQ, PUMP 30 BBLS OF
VIS SPACER, FOLLOWED BY 11.4
LSND @ 520 GPM, 2350 PSI, 61% F/O.
REDUCE RATE AS PER PLAN. FINAL
CIRC RATE OF 280 GPM, 1081 PSI,
42% F/O. ECD - 12.38 TOTAL STKS
PUMPED - 8146. OBSERVE 11.2 MW
RETURNS. OBTAIN SPR'S. SHUT
DOWN. MAKE CALLS.
8,182.0 8,087.0
8/28/2022
00:00
8/28/2022
01:00
1.00 INTRM2, CASING OWFF P STAND BACK STD #80. MONITOR
WELL VIA CLOSED CHOKES - 29 PSI.
BLED DN TO 20 PSI. OPEN UP AT
THE RCD HEAD AND MONITOR
(STATIC) SIMOPS - B/D TD
8,087.0 8,087.0
8/28/2022
01:00
8/28/2022
02:30
1.50 INTRM2, CASING COND T WEIGHT UP PIT #5 FROM 11.2 TO
11.4 PPG. INSUFFICIENT MUD
WEIGHT RETURNS TO SURFACE
DURING DISPLACEMENT.
8,087.0 8,087.0
8/28/2022
02:30
8/28/2022
04:15
1.75 INTRM2, CASING SMPD P STRIP OUT OF THE HOLE F/ 8,087'
MD T/ 7,322' MD. MONITOR DISP VIA
PIT 5. MPD KEEPING 70 PSI WHILE
PULLING AND 25 PSI WHILE IN THE
SLIPS. UP WT - 124K, S/O WT - 86K.
8,087.0 7,322.0
8/28/2022
04:15
8/28/2022
05:30
1.25 INTRM2, CASING OWFF T OBSERVE 40K OVERPULL AT 7,322'
MD AND INCORRECT HOLE FILL.
ATTEMPT TO WORK BY
OBSTRUCTION (UNSUCCESSFUL).
RIH F/ 7,322' MD TO 7,425' MD AND
OWFF. UP WT - 130K, S/O WT - 73K.
7,322.0 7,425.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 30/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/28/2022
05:30
8/28/2022
08:00
2.50 INTRM2, CASING SMPD P STRIP OUT OF THE HOLE F/ 7,425'
MD T/ 6,107' MD. MONITOR DISP VIA
PIT 5. MPD KEEPING 70 PSI WHILE
PULLING AND 25 PSI WHILE IN THE
SLIPS. UP WT - 124K, S/O WT - 86K.
7,425.0 6,107.0
8/28/2022
08:00
8/28/2022
09:30
1.50 INTRM2, CASING COND T OBSERVE DISCREPENCIES IN FLUID
DISPLACEMENT. STOP. OWFF.
DECISION MADE TO BUILD 227 BBLS
OF 11.4 LSND IN PITS.
6,107.0 6,107.0
8/28/2022
09:30
8/28/2022
10:30
1.00 INTRM2, CASING MPDA P REMOVE MPD BEARING AND DRAIN
NIPPLE. INSTALL TRIP NIPPLE.
6,107.0 6,107.0
8/28/2022
10:30
8/28/2022
14:00
3.50 INTRM2, CASING TRIP P POOH ON ELEVATORS F/ 6,107' MD
TO 4,601' MD. MONITOR DISP VIA TT.
UP WT - 97K, S/O WT - 80K.
6,107.0 4,601.0
8/28/2022
14:00
8/28/2022
14:45
0.75 INTRM2, CASING CIRC P PUMP SLUG. SIMOPS - C/O
HANDLING EQUIPMENT FROM 5" TO
4".
4,601.0 4,601.0
8/28/2022
14:45
8/28/2022
19:30
4.75 INTRM2, CASING TRIP P POOH ON ELEVATORS F/ 4,601' MD
TO TOP OF 4" HWDP @ 620' MD.
MONITOR DISP VIA TT. UP WT - 78K
4,601.0 620.0
8/28/2022
19:30
8/28/2022
23:00
3.50 INTRM2, CASING BHAH P OWFF. L/D INTERMEDIATE 2 BHA F/
620' MD AS PER SLMB DD. MONITOR
DISP VIA TT.
620.0 0.0
8/28/2022
23:00
8/29/2022
00:00
1.00 INTRM2, CASING BHAH P CLEAR AND CLEAN RIG FLOOR.
SIMOPS - P/U 5" TEST JT AND M/U
STACK FLUSHING TOOL.
0.0 0.0
8/29/2022
00:00
8/29/2022
00:30
0.50 INTRM2, CASING WWWH P FLUSH STACK W/ 640 GPM, 55 PSI,
54% F/O. WORK THROUGH 3X. B/D
TD. R/D STACK FLUSHING TOOL.
0.0 0.0
8/29/2022
00:30
8/29/2022
01:15
0.75 INTRM2, CASING RURD P MT STACK. PULL WEAR BUSHING.
INSTALL UPPER TEST PLUG VIA FMC
REP. CLOSE BLIND/SHEER RAMS.
LINE UP MPD INJECTION LINE TO
THE IA TO MONITOR WELL BORE.
MONITOR VIA PILL PIT 2
0.0 0.0
8/29/2022
01:15
8/29/2022
03:30
2.25 INTRM2, CASING BOPE P C/O UPPER VBR'S TO 4½" X 7".
CONTINUE TO MONITOR WELL BORE
VIA MPD LINE ON PILL PIT 2.
0.0 0.0
8/29/2022
03:30
8/29/2022
05:00
1.50 INTRM2, CASING RURD P P/U 5" TEST JT. FLOOD LINES AND
SHELL TEST BOPE (GOOD)
0.0
8/29/2022
05:00
8/29/2022
07:00
2.00 INTRM2, CASING BOPE P WITH THE 7" TEST JT TEST ANNUAR
TO 250 PSI LOW 2500 PSI HIGH.
TEST UPPER 4½" X 7" TO 250 PSI
LOW 3500 PSI HIGH F/ 5/5 CHARTED
MIN.(GOOD). WITH 5" TEST JT TEST
UPPER VBR'S TO 250 PSI LOW 3500
PSI HIGH F/ 5/5 CHARTED MIN
(GOOD)
0.0 0.0
8/29/2022
07:00
8/29/2022
07:30
0.50 INTRM2, CASING RURD P PULL TEST PLUG, INSTALL 9.125 ID
WEAR BUSHING PER FMC REP. B/D
TEST LINES.
0.0 0.0
8/29/2022
07:30
8/29/2022
09:30
2.00 INTRM2, CASING RURD P MOBILIZE 7" CSG EQUIPMENT TO
THE RIG FLOOR. R/U DOYON CSG
POWER TONGS, TQ TURN
EQUIPEMENT, ELEVATORS,
CORRECT XO FOR FOSV, AND FILL
UP LINE.
0.0 0.0
8/29/2022
09:30
8/29/2022
10:00
0.50 INTRM2, CASING SFTY P PJSM ON RUNNING 7" LINER W/ CPAI
RIG SUPERVISOR, DDI TP, DDI CSG
REP, AND RIG CREW.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 31/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/29/2022
10:00
8/29/2022
10:45
0.75 INTRM2, CASING PUTB P M/U AND BAKER LOC DAVIS LYNCH
7" TN-110SS TS BLUE SHOE TRAC TO
130' MD(TO PIN END OF JT 4). TQ
TURN TS BLUE CONNECTIONS TO
OPTIMUM TQ OF 11,600 FT/LBS.
CHECK FLOATS (GOOD)
0.0 130.0
8/29/2022
10:45
8/29/2022
14:00
3.25 INTRM2, CASING PULD P RIH W/ 7" TN-110SS TS BLUE X TXP
LINER. TQ TURN TS BLUE
CONNECTIONS TO OPTIMUM TQ OF
11,600 FT/LBS F/ 130' MD TO 978' MD.
MONITOR DISP VIA PIT 5.
130.0 978.0
8/29/2022
14:00
8/29/2022
14:15
0.25 INTRM2, CASING RURD P R/D DDI CSG TQ TURN RUNNING
EQUIPMENT.
978.0 978.0
8/29/2022
14:15
8/29/2022
15:00
0.75 INTRM2, CASING PUTB P RIH W/ 7" TXP F/ 978' MD T/ 1,185' MD.
TQ TXP CONNECTIONS TO 14,750
FT/LBS. MONITOR DISP VIA PIT 5.
978.0 1,185.0
8/29/2022
15:00
8/29/2022
15:45
0.75 INTRM2, CASING CIRC P FILL PIPE AND CIRCULATE CSG
VOLUMEW/ 65 GPM, 84 PSI, 27% F/O,
TOTAL STKS PUMPED - 502
1,185.0 1,185.0
8/29/2022
15:45
8/29/2022
23:30
7.75 INTRM2, CASING PUTB P RIH W/ 7" TXP F/ 1,185' MD T/ 4,237'
MD. TQ TXP CONNECTIONS TO
14,750 FT/LBS. MONITOR DISP VIA
PIT 5.
1,185.0 4,237.0
8/29/2022
23:30
8/30/2022
00:00
0.50 INTRM2, CASING PUTB P P/U & M/U SLZXP LINER HANGER
ASSEMBLY TO HYD563 X TXP XO.
ADD XAN PLEX D & RIH F/ 4,237' MD
T/ 4,316' MD. TQ HYD563
CONNECTIONS TO 9,400 FT/ LBS. UP
WT - 109K, S/O WT - 93K.
4,237.0 4,316.0
8/30/2022
00:00
8/30/2022
01:30
1.50 INTRM2, CASING CIRC P M/U 1ST STD OF 5" DP AND RIH F/
4,316' MD T/ 4,406' MD. CIRC LINER
VOLUME (165 BBLS) STAGE PUMPS
UP T/ 6 BPM. ICP @ 84 GPM - 333 W/
25% F/O. FCP @ 252 GPM 490 W/
39% F/O. OBTAIN T&D VALUES W/ 85
GPM 288 PSI, 27% F/O - UP WT -
101K, S/O WT - 93K, 20 RPM, 3.5K TQ
ROT WT - 97K. W/O PUMPS - UP WT -
110K, S/O WT - 98K, ROT WT - 102K,
20 RPM, 3.5K TQ. TOTAL STKS
PUMPED - 2441
4,316.0 4,406.0
8/30/2022
01:30
8/30/2022
09:30
8.00 INTRM2, CASING RUNL P RIH W/ 7" LINER ON 5" DP @ 20
FT/MIN F/ 4,406' MD T/ 8,120' MD.
FILL PIPE EVERY 10 STDS.
MONITOR DISP VIA PIT 5. DRIFT
STANDS OUT OF THE DERRICK WITH
2.75 OD RABBIT. UP WT - 125K, S/O
WT - 68K
4,406.0 8,120.0
8/30/2022
09:30
8/30/2022
10:00
0.50 INTRM2, CASING MPDA P PULL TRIP NIPPLE, INSTALL DRAIN
NIPPLE AND MPD BEARING.
8,120.0 8,120.0
8/30/2022
10:00
8/30/2022
10:45
0.75 INTRM2, CASING RUNL P RIH W/ 7" LINER ON 5" DP @ 20
FT/MIN F/ 8,120' MD T/ 8,273' MD.
FILL PIPE EVERY 10 STDS.
MONITOR DISP VIA PIT 5. DRIFT
STANDS OUT OF THE DERRICK WITH
2.75 OD RABBIT. UP WT - 125K, S/O
WT - 68K
8,120.0 8,273.0
8/30/2022
10:45
8/30/2022
12:00
1.25 INTRM2, CASING DISP P AT 8,273 DISPLACE WELL F/ 11.4 PPG
TO 9.2 PPG LSND AS PER BEYOND
PUMP SCHEDULE @ 21 GPM, 422
PSI, 14% F/O. TOTAL STKS PUMPED
- 598
8,273.0 8,273.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 32/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/30/2022
12:00
8/30/2022
18:30
6.50 INTRM2, CASING DISP P CONT T/ DISPLACE OVER TO 9.2
PPG AS PER BEYOND PUMP
SCHEDULE. AT 2700 STKS ROT AND
RECIP F/ 8,273' MD T/ 8,249' MD
SLOWLY STAGING PUMPS UP TO 5
BPM, 199 GPM, ICP - 645 @ 42 GPM,
FCP - 552 @ 199 GPM W/ 35% F/O.
ROT 20 RPM, 6K TQ, 102K UP WT -
96K S/O WT. TOTAL STKS PUMPED -
9422
8,273.0 8,273.0
8/30/2022
18:30
8/30/2022
19:00
0.50 INTRM2, CASING RUNL P OBTAIN T&D VALUES. WITH 84 BPM,
381 PSI, 23% F/O, 20 RPM, 6K TQ,
120K UP WT, 80K S/O WT, 103K ROT
WT. W/O PUMPS - 20 RPM, 7K TQ, UP
WT - 130K, 80K S/O, 103K ROT.
8,273.0 8,273.0
8/30/2022
19:00
8/31/2022
00:00
5.00 INTRM2, CASING RUNL P RIH W/ 7" LINER ON 5" DP @ 20
FT/MIN F/ 8,273' MD T/ 11,300' MD.
FILL PIPE EVERY 10 STDS.
MONITOR DISP VIA PIT 1. DRIFT
STANDS OUT OF THE DERRICK WITH
2.75 OD RABBIT. S/O WT - 75K
8,273.0 11,300.0
8/31/2022
00:00
8/31/2022
00:45
0.75 INTRM2, CASING RUNL P RIH W/ 7" LINER ON 5" DP @ 20
FT/MIN F/ 11,300' MD T/ 11869' MD.
FILL PIPE EVERY 10 STDS.
MONITOR DISP VIA PIT 1. DRIFT
STANDS OUT OF THE DERRICK WITH
2.75 OD RABBIT.
11,300.0 11,869.0
8/31/2022
00:45
8/31/2022
02:15
1.50 INTRM2, CASING RUNL P RIH W/ 7" LINER ON 5" HWDP @ 20
FT/MIN F/ 11,869' MD T/ 12,338' MD.
FILL PIPE EVERY 10 STDS.
MONITOR DISP VIA PIT 1. DRIFT
STANDS OUT OF THE DERRICK WITH
2.75 OD RABBIT. S/O WT - 82K
11,869.0 12,338.0
8/31/2022
02:15
8/31/2022
03:00
0.75 INTRM2, CASING RUNL P CIRC DN @ 2 BPM 587 PSI, 30% F/O,
F/ 12,388' MD T/12,432.87' MD. P/U
SINGLE AND WASH DN TO 12,478' MD
AT SAME RATE. P/U 19' PUP WASH
DN AT SAME RATE AND TAG BTM AT
12,478' MD W/ 12K. S/O WT = 93K.
12,338.0 12,478.0
8/31/2022
03:00
8/31/2022
11:00
8.00 INTRM2, CEMENT CIRC P CONDITION MUD FOR CEMENT JOB.
ROT & RECIP PIPE F/ 12,476' MD T/
12,454' MD STAGING PUMPS UP TO 6
BPM. ICP - 475 @ 85 GPM, 27% F/O.
20 RPM, 11K TQ. UP WT - 125K, S/O -
129K, ROT WT - 125K. FCP - 730 @
250 GPM, 40% F/O.
12,478.0 12,478.0
8/31/2022
11:00
8/31/2022
11:45
0.75 INTRM2, CEMENT RURD P RIG UP BAKER CEMENT SWIVEL AND
CEMENTERS. SPACE OUT AND
OBTAIN FINAL
WEIGHTS. ROT WT 134K 196K P/U
10K TQ.
12,478.0 12,478.0
8/31/2022
11:45
8/31/2022
12:00
0.25 INTRM2, CEMENT SFTY P PJSM WITH ALL HANDS ON CEMENT
JOB. PT SURFACE LINES T/ 4500 PSI,
CHARTED. PUMP
40 BBL OF MUD PUSH @ 5 BPM, 339
PSI, 36% F/O 20 RPM, 10K TQ
12,478.0 12,478.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 33/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/31/2022
12:00
8/31/2022
14:00
2.00 INTRM2, CEMENT CMNT P DROP BTM PLUG AND CHASE WITH
87.1 BBL OF 13PPG LEAD CEMENT @
5 BPM, 327 PSI,
34% 20RPM, 10K TQ. PUMP 22 BBL
OF 15.8 PPG TAIL CEMENT @ 4 BPM,
105 PSI, 33% F/O
11K TQ @ 20 RPM. DROP BTM PLUG
AND CHASE WITH 20 BBL OF H20 VIA
CEMENTERS.
CHASE WITH RIG PUMPS @ 5 BPM
270 PSI, 35% F/O CATCH PRESSURE
@ 65 STKS. FIRST
PLUG LANDED @ 1309 STKS. STAGE
UP T/ 6 BPM, 938 PSI, 34% F/O 20
RPM, 17K MAX TQ
SEEN. SLOW DOWN TO 3BPM 577
PSI, 32% F/O, 0 RPM, 2ND PLUG
LAND @ 3191 STKS.
PRESSURE UP 500 OVER T/ 1100 PSI.
HOLD F/ 5 MIN. BLEED OFF AND
CHECK FLOATS.
FLOATS HELD.
12,478.0 12,478.0
8/31/2022
14:00
8/31/2022
14:45
0.75 INTRM2, CEMENT THGR P SET ZXP LINER HANGER AND
PACKER AS PER BAKER REP. @
12,473' MD PRESS UP T/
2700 PSI, SET 3 MIN, PRESS TO 4000
PSI, PAKER SET @ 3500 PSI, SET
DOWN 80K. BLEED
OFF PRESSURE. P/U 140K AND
RELEASE F/ LINER HANGER.
12,478.0 12,478.0
8/31/2022
14:45
8/31/2022
15:00
0.25 INTRM2, CEMENT PRTS P PRESSURE TEST PACKER T/ 1500
PSI F/ 10 MIN.
12,478.0 12,478.0
8/31/2022
15:00
8/31/2022
15:15
0.25 INTRM2, CEMENT THGR P PRESSURE UP 500 PSI, AND P/U 8
FEET TO VERIFY LINER IS FREE,
PRESSURE BLED TO 0
PSI NEW DEPTH 8170' MD TOL
12,478.0 8,170.0
8/31/2022
15:15
8/31/2022
15:30
0.25 INTRM2, CEMENT CIRC P CIRCULATE @ 275 GPM, 450 PSI, 42
% F/O TO 778 STKS.
8,170.0 8,170.0
8/31/2022
15:30
8/31/2022
17:00
1.50 INTRM2, CEMENT RURD P RIG DWN BAKER CEMENT SWIVEL
AND LD PUP JT AND WORKING
SINGLE. F/ 8170' MD T/
8031' MD. P/U 140K
8,170.0 8,031.0
8/31/2022
17:00
8/31/2022
18:00
1.00 INTRM2, CEMENT CIRC P DROP 2 NERF BALLS AND
CIRCULATE @ 500 GPM, 810 PSI,
56% F/O. 5112 STKS PUMPED
8,031.0 8,031.0
8/31/2022
18:00
8/31/2022
18:30
0.50 INTRM2, CEMENT CIRC P B/D TD AND LINE UP PUMP ON
BACKSIDE TO FILL HOLE
8,031.0 8,031.0
8/31/2022
18:30
8/31/2022
19:15
0.75 INTRM2, CEMENT TRIP P POOH ON ELEVATOR F/ 8031' MD T/
7563' MD RACKING BACK 5" HWDP,
P/U 123K
8,031.0 7,563.0
8/31/2022
19:15
8/31/2022
20:15
1.00 INTRM2, CEMENT MPDA P PJSM REMOVE DRIP NIPPLE AND
MPD BEARING. INSTALL TRIP NIPPLE
7,563.0 7,563.0
8/31/2022
20:15
9/1/2022
00:00
3.75 INTRM2, CEMENT TRIP P CONT POOH ON ELEVATORS W/ 5"
DP. F/ 7,563' MD T/ 3,173' MD.
MONITORING HOLE FILL
VIA PIT#5. P/U WT= 97K
7,563.0 3,173.0
9/1/2022
00:00
9/1/2022
02:00
2.00 INTRM2, CEMENT TRIP P CONT POOH ON ELEVATORS W/ 5"
DP. F3,173' to 35' MD. MONITORING
HOLE FILL VIA PIT#5. P/U WT= 55K
3,173.0 35.0
9/1/2022
02:00
9/1/2022
02:30
0.50 INTRM2, CEMENT BHAH P L/D HANGER RUNNING TOOL AS PER
BAKER REP. ALL RUNNING TOOLS
ACCOUNTED FOR. DOG SUB
SHEARED HRDE WAS HYDRAULIC
RELEASED RS PACKER AQLL SEALS
ACCOUNTED FOR.
35.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 34/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/1/2022
02:30
9/1/2022
04:30
2.00 INTRM2, WHDBOP CLEN P CLEAN AND CLEAR RIG FLOOR, R/U
WASH TOOL WASH BOPE STACK
0.0 0.0
9/1/2022
04:30
9/1/2022
06:00
1.50 INTRM2, WHDBOP NUND P PJSM CHANGE OUT TOP RAMS TO 3-
1/2" X 6" VBR'S.
0.0 0.0
9/1/2022
06:00
9/1/2022
12:00
6.00 INTRM2, WHDBOP CLEN P PERFORM WEEKLY DERRICK
INSPECTION, CLEAN/ORGANIZE ON
RIG FLOOR, PREP FOR
BOP TEST, BRING UP BHA
COMPONENTS TO RIG FLOOR,
CLEAN SUCTION MANIFOLDS,
SUCTION SCREENS AND
DISCHARGE SCREENS ON BOTH
MUD PUMPS, C/O ALL CAMLOCK
GASKETS FROM WATER BASED TO
OBM ON TANK FARM SYSTEM,
EMPTY AND CLEAN IN
MUD PITS, FLUSH AND CLEAN TANK
FARM TANKS.
0.0 0.0
9/1/2022
12:00
9/1/2022
21:00
9.00 INTRM2, WHDBOP CLEN P CONT. TO PERFORM WEEKLY
DERRICK INSPECTION,
CLEAN/ORGANIZE ON RIG FLOOR,
PREP FOR BOP TEST, CLEAN
SUCTION MANIFOLDS, SUCTION
SCREENS AND DISCHARGE
SCREENS ON BOTH MUD PUMPS,
EMPTY AND CLEAN IN MUD PITS,
FLUSH AND CLEAN
TANK FARM TANKS. L/D 6 STANDS
OF 5" HWDP VIA MOUSEHOLE.
MOTORMAN WENT
THROUGH ACCUMULATOR BOTTLES
AND RECORDED PRESSURES
0.0 0.0
9/1/2022
21:00
9/1/2022
22:30
1.50 INTRM2, WHDBOP CLEN P CONT. TO CLEAN/ORGANIZE ON RIG
FLOOR, PREP FOR BOP TEST,
CLEAN SUCTION
MANIFOLDS, SUCTION SCREENS
AND DISCHARGE SCREENS ON
BOTH MUD PUMPS, EMPTY
AND CLEAN IN MUD PITS
0.0 0.0
9/1/2022
22:30
9/2/2022
00:00
1.50 INTRM2, WHDBOP SLPC P CUT AND SLIP 42' OF DRILL LINE 0.0 0.0
9/2/2022
00:00
9/2/2022
01:00
1.00 INTRM2, WHDBOP BOPE P FILL LINES AND STACK W/ WATER
PURGE AIR FROM LINES AND SHELL
TEST GOOD TEST.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 35/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/2/2022
01:00
9/2/2022
04:45
3.75 INTRM2, WHDBOP BOPE P TEST BOPE ALL TESTS T/ 250 LOW
3,500 HIGH FOR 5 CHARTED MIN. W/
EXCEPTION OF
MANUAL OPERATED & SUPER
CHOKE TESTED T/ 250 LOW & 2,000
PSI FOR 5 CHARTED MIN, W/
4" TEST JT TEST ANNULAR, 2 7/8" X 5
1/2" UPR, 2 7/8" X 5 1/2" LPR, W/ 4 1/2"
TEST JT TEST 2
7/8" X 5 1/2" UPR & 2 7/8" X 5 1/2"
LPR, TEST CHOKE VALVES 1-15,
MANUAL OPERATED & SUPER
CHOKE, CHOKE & KILL MANUALS &
HCR'S, 4" VALVE ON KILL LINE, 4"
FOSV, 4" DART VALVE,
UPPER & LOWER IBOP; BLIND/
SHEAR RAMS; PERFORM KOOMEY
DRAWDOWN, ACC = 1800 PSI.
MANIF. = 3000 PSI. ACC = 1800 PSI
AFTER ALL FUNCTIONS ON
BOTTLES, 7 SEC FOR 200 PSI.
BUILD W/ 2 ELEC. PUMPS, 57 SEC T/
BUILD FULL SYS. PRESSURE W/ 2
ELEC. & 2 AIR PUMPS,
CLOSING TIMES ANNULAR = 23 SEC.
UPR = 18 SEC. BLIND / SHEARS = 16
SEC. LPR = 16 SEC.
CHOKE HCR = 2 SEC. KILL HCR = 2
SEC; TEST PVT GAIN/LOSS AND
FLOW OUT ALARMS, TEST
LEL AND H2S ALARMS; AOGCC REP
KAM P. ST.JOHN WAIVED WITNESS
@ 06:30 HRS on 9/1/22
0.0 0.0
9/2/2022
04:45
9/2/2022
07:00
2.25 INTRM2, WHDBOP PULD P PULL TEST PLUG, SET WEAR RING,
R/D TESTING EQUIPMENT,
CALIBRATE BLOCKS
WEAR RING ID= 9 1/8", B/D TESTING
EQUPIMENT/ CHOKE,KILL, AND TOP
DRIVE
0.0 0.0
9/2/2022
07:00
9/2/2022
10:00
3.00 INTRM2, DRILLOUT RURD P MAKE UP SECTION PIPE TALLY, C/O
HANDLING EQUIPMENT FROM 5" TO
4", SLIPS,
ELEVATORS, ST-100 DIE BLOCKS,
P/U MASTER BUSHINGS FOR
SMALLER BHA, ETC
0.0 0.0
9/2/2022
10:00
9/2/2022
12:00
2.00 INTRM2, DRILLOUT BHAH P HOLD PJSM ON P/U BHA, P/U BHA/
LOAD SOURCE F/ 0' T/ 465.01' PER
SLB REP.
0.0 0.0
9/2/2022
12:00
9/2/2022
14:00
2.00 INTRM2, DRILLOUT BHAH P P/U BHA/ LOAD SOURCE F/ 0' T/
465.01' MD PER SLB REP. S/O WT 59K
MONITOR VIA TRIP
TANK
0.0 465.0
9/2/2022
14:00
9/2/2022
16:30
2.50 INTRM2, DRILLOUT TRIP P RIH W/ 4" DP F/ PIPE SHED,
DRIFTING EACH JOINT ON SKATE
WITH 2" DRIFT, F/ 465' MD TO
1503' MD, MONITOR DISPLACEMENT
VIA TRIP TANK
465.0 1,503.0
9/2/2022
16:30
9/2/2022
17:00
0.50 INTRM2, DRILLOUT DHEQ P @1503' MD, CHECK ALL SURFACE
LINES, PERFORM SHALLOW HOLE
TEST PER SLB REP.
@ 200 GPM, PSI=1030 , RPM= 30
1,503.0 1,503.0
9/2/2022
17:00
9/3/2022
00:00
7.00 INTRM2, DRILLOUT TRIP P RIH W/ 4" DP F/ PIPE SHED,
DRIFTING EACH JOINT ON SKATE
WITH 2" DRIFT, F/ 1,503' MD
TO 6,515' MD, MONITOR
DISPLACEMENT VIA TRIP TANK. P/U
WT= 89K, S/O WT= 75K
1,503.0 6,515.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 36/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/3/2022
00:00
9/3/2022
01:00
1.00 INTRM2, DRILLOUT TRIP P RIH W/ 4" DP OUT OF DERRICK F/
6,515' MD T/ 8,121' MD, MONITORING
DISPLACEMENT VIA TRIP
TANK. P/U WT= 97K, S/O WT= 77K
6,515.0 8,121.0
9/3/2022
01:00
9/3/2022
01:30
0.50 INTRM2, DRILLOUT TRIP P @ 8,121' MD KELLY UP AND CIRC @
225 GPM, 1,404 PSI, 35% F/O.
VERIFY SONICSCOPE
CONFIGURATION W/ SLB DD.
8,121.0 8,121.0
9/3/2022
01:30
9/3/2022
03:45
2.25 INTRM2, DRILLOUT DLOG P RIH W/ 4" DP OUT OF DERRICK F/
8,121' MD T/ 10,486' MD LOGGING
CEMENT. MONITORING
DISPLACEMENT VIA TRIP TANK.
RUNNING SPEED= 1,700'/HR. P/U
WT= XK, S/O WT= XK
8,121.0 10,486.0
9/3/2022
03:45
9/3/2022
04:30
0.75 INTRM2, DRILLOUT RURD P M/U 4"X5" X/O, NC50 FLOAT SUB. C/O
4" HANDLING EQUIPMENT T/ 5"
HANDLING EQUIPMENT
10,486.0 10,486.0
9/3/2022
04:30
9/3/2022
07:00
2.50 INTRM2, DRILLOUT DLOG P RIH W/ 5" DP OUT OF DERRICK F/
10,486' MD T/ 12,092' MD LOGGING
CEMENT.
MONITORING DISPLACEMENT VIA
TRIP TANK. RUNNING SPEED=
1,700'/HR. P/U WT= 84K, S/O
WT= 108K
10,486.0 12,092.0
9/3/2022
07:00
9/3/2022
07:30
0.50 INTRM2, DRILLOUT WASH P WASH DOWN F/ 12,092' MD T/ 12,233'
MD, 210 GPM, PSI= 1623, F/O %=38,
86K S/O, 124K P/U.
12,092.0 12,233.0
9/3/2022
07:30
9/3/2022
10:00
2.50 INTRM2, DRILLOUT CIRC P TOOK WT @ 12,233' MD (10K),
RACKED BACK STD 125, KELLY UP T/
STD 124 AND BEGAN
TO CIRCULATE AND CONDITION
MUD F/ CASING TEST,
ROTATE/RECIP. FULL STD WHILE
CIRC. @ 220 GPM, 40 RPM, PSI=1604,
36% F/O, 5K TQ, P/U= 103K, S/O=
107K.(6895 TOT.
STRKS)
12,233.0 12,138.0
9/3/2022
10:00
9/3/2022
11:30
1.50 INTRM2, DRILLOUT PRTS P BLOW DOWN TOP DRIVE, RIG UP F/
CASING TEST, PERFORM CASING
PRESSURE TEST @
6 SPM TO 3500 PSI (30 MIN.
CHARTED), 114 TOT. STRKS,
PUMPED 9.6 BLLS, BLED BACK
9.5BBLS.
12,138.0 12,138.0
9/3/2022
11:30
9/3/2022
12:00
0.50 INTRM2, DRILLOUT RURD P RIG DOWN AND BLOW DOWN
TESTING EQUPMENT.
12,138.0 12,138.0
9/3/2022
12:00
9/3/2022
13:00
1.00 INTRM2, DRILLOUT DRLG P WASH DOWN F/ 12,138' MD T/ TAG
TOP OF LANDING COLLAR PER DD
@ 12,345' MD, 220
GPM, PSI=1635 , 33% F/O, 40RPM, 5K
TQ, S/O 108K, P/U 111K
12,138.0 12,345.0
9/3/2022
13:00
9/3/2022
13:45
0.75 INTRM2, DRILLOUT DRLG P DRILL OUT LANDING COLLAR F/
12,345‘ MD - T/ 12,349.26‘ MD , WOB =
9, GPM = 220, PSI=
1650, RPM = 55, TQ = 9-10K, FLOW
OUT = 33%,
12,345.0 12,349.0
9/3/2022
13:45
9/3/2022
16:45
3.00 INTRM2, DRILLOUT DRLG P DRILL CEMENT F/ 12,349.26‘ MD - T/
12,390‘ MD , WOB= 9, GPM= 250, PSI=
1994, RPM= 120,
TQ= 9-10K, FLOW OUT = 32%,
12,349.0 12,390.0
9/3/2022
16:45
9/3/2022
17:00
0.25 INTRM2, DRILLOUT DRLG P DRILL OUT FLOAT COLLAR F/ 12,390.‘
MD - T/ 12,396‘ MD , WOB =8K , GPM
=250 , PSI=2029 ,
RPM =55 , TQ =9 K, FLOW OUT = 34%
12,390.0 12,396.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 37/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/3/2022
17:00
9/3/2022
18:30
1.50 INTRM2, DRILLOUT DRLG P DRILL OUT CEMENT F/ 12,396' MD T/
12,474' MD, WOB= 3K, 250 GPM, 2,050
PSI, 34% F/O, 9K
TQ,
12,396.0 12,474.0
9/3/2022
18:30
9/3/2022
19:30
1.00 INTRM2, DRILLOUT DRLG P DRILL OUT SHOE F/ 12,474' MD T/
12,479' MD @ 250 GPM, 2,099 PSI,
33% F/O, 100 RPM, 12K
TQ, WOB= 1-6K
12,474.0 12,479.0
9/3/2022
19:30
9/3/2022
19:45
0.25 INTRM2, DRILLOUT DRLG P REAM THROUGH SHOE X2 F/ 12,479'
MD T/ 12,470 @ 250 GPM, 2,099 PSI,
36% F/O, 100 RPM,
10K TQ.
12,479.0 12,470.0
9/3/2022
19:45
9/3/2022
21:30
1.75 INTRM2, DRILLOUT DRLG P ROT AND RECIP, CIRC B/U F/ 12,470'
MD T/ 12,373' MD @ 250 GPM, 2,130
PSI, 36% F/O, 100
RPM, 10K TQ, P/U ROT WT= 103K,
S/O ROT WT= 107K. TOTAL STKS
PUMPED= 6,870 (587
BBLS)
12,470.0 12,373.0
9/3/2022
21:30
9/3/2022
22:30
1.00 INTRM2, DRILLOUT MPDA P @ 12,470' MD FLOW CHECK (STATIC).
REMOVE TRIP NIPPLE, INSTALL MPD
BEARING PER
BEYOND REP. LINE UP MP#2 ON INJ.
LINE, BLEED MP#1 DAMPNER T/ 550
PSI.
12,373.0 12,470.0
9/3/2022
22:30
9/3/2022
22:45
0.25 INTRM2, DRILLOUT DDRL P WASH DOWN F/ 12,470' MD T/ 12,479'
MD @ 250 GPM, 2,130 PSI, 36% F/O,
100 RPM, 10K TQ
DRILL NEW HOLE F/ 12,479' MD T/
12,498' MD @ 250 GPM, 2,171 PSI,
39% F/O, 100 RPM, 11K
TQ, WOB= 7K, ADT = .18, TOTAL BIT
HRS = .18, TOTAL JAR HRS = 44.2
12,470.0 12,498.0
9/3/2022
22:45
9/3/2022
23:00
0.25 INTRM2, DRILLOUT RURD P REAM UP F/ 12,498' MD T/ 12,470' @
250 GPM, 2,099 PSI, 36% F/O, 100
RPM, 10K TQ.
L/D WORKING SINGLE
12,498.0 12,470.0
9/3/2022
23:00
9/4/2022
00:00
1.00 INTRM2, DRILLOUT CIRC P ROT AND RECIP, CIRC B/U F/ 12,470'
MD T/ 12,373' MD @ 250 GPM, 2,130
PSI, 39% F/O, 100
RPM, 10K TQ, P/U ROT WT= 103K,
S/O ROT WT= 107K.
12,470.0 12,373.0
9/4/2022
00:00
9/4/2022
00:30
0.50 INTRM2, DRILLOUT CIRC P CONT. ROT AND RECIP, CIRC B/U F/
12,470' MD T/ 12,373' MD @ 250 GPM,
2,130 PSI, 39% F/O, 100
RPM, 10K TQ, P/U ROT WT= 103K,
S/O ROT WT= 107K. TOTAL STKS
PUMPED= 7,086 (605 BBLS)
12,470.0 12,373.0
9/4/2022
00:30
9/4/2022
01:00
0.50 INTRM2, DRILLOUT RURD P R/U FOR LOT 12,470.0 12,373.0
9/4/2022
01:00
9/4/2022
02:00
1.00 INTRM2, DRILLOUT LOT P @ 12,470' MD, PERFORM XLOT PER
CPAI. WAITING ON DATA FROM
HOUSTON TO RECORD IN
IADC.
12,470.0 12,373.0
9/4/2022
02:00
9/4/2022
02:30
0.50 PROD1, DRILL RURD P R/D TESTING EQUIPMENT 12,373.0 12,373.0
9/4/2022
02:30
9/4/2022
03:00
0.50 PROD1, DRILL WASH P REAM F/ 12,470' MD T/ 12,498' MD X3
CHECKING OPEN HOLE INTEGRITY
@ 250 GPM, 2,102 PSI,
43% F/O, 120 RPM, 10K TQ
NO ISSUES
12,470.0 12,498.0
9/4/2022
03:00
9/4/2022
05:00
2.00 PROD1, DRILL CIRC P ROT AND RECIP F/ 12,470' MD T/
12,373' MD @ 250 GPM, 2,085 PSI,
39% F/O, 100 RPM, 10K TQ,
P/U ROT WT= 103K, S/O ROT WT=
107K.
12,470.0 12,373.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 38/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/4/2022
05:00
9/4/2022
07:00
2.00 PROD1, DRILL RURD P INCREASE PULSATION DAMPNER
PRESSURE T/ 950 PSI ON MP#1,
SERVICE TOP DRIVE,
PREP FOR DISPLACEMENT T/ OBM
IN MUD PITS AND ROCKWASHER,
OFFLOAD PIT #5 TO
UPRIGHTS, TRAP PRESSURE W/
MPD TO DISPLACE OBM THROUGH
BOTH MUD PUMPS
12,373.0 12,373.0
9/4/2022
07:00
9/4/2022
10:00
3.00 PROD1, DRILL RURD P DISPLACE WELL F/ 9.3 PPG LSND T/
9.0 PPG VERSAPRO OBM. @ 225
GPM, 2650 PSI, 34%
F/O, TOTAL STRKS PUMPED = 10,772
SIMOPS- PURGE ALL
CENTRIFUGALS WITH OBM
12,373.0 12,470.0
9/4/2022
10:00
9/4/2022
10:30
0.50 PROD1, DRILL CIRC P OBTAIN SPR'S 12,470.0 12,470.0
9/4/2022
10:30
9/4/2022
11:00
0.50 PROD1, DRILL WASH P REAM DOWN F/ 12,469' MD T/ TAG
BOTTOM @ 12,498' MD, 240 GPM, 120
RM, ROT. S/O 106K,
36% F/O, 2800 PSI.
12,470.0 12,498.0
9/4/2022
11:00
9/4/2022
12:00
1.00 PROD1, DRILL DDRL P DRILL 6 1/8” PRODUCTION HOLE F/
12,498‘ MD - T/ 12,565‘ MD 4071‘ TVD,
WOB = 5K, GPM =
240 PSI ON = 2929, PSI OFF = 2963,
RPM = 120, TQ ON = 7, TQ OFF = 6,
FLOW OUT = 41%,
12,498.0 12,565.0
9/4/2022
12:00
9/4/2022
18:00
6.00 PROD1, DRILL DDRL P DRILL 6 1/8” PRODUCTION HOLE F/
12,565‘ MD - T/ 12914‘ MD 4119‘ TVD,
WOB = 2, GPM =
230, PSI ON = 2739, PSI OFF = 2713,
RPM = 150, TQ ON = 8K, TQ OFF = 7,
FLOW OUT = 41%,
ECD = 11.02 PPG, P/U WT = 148K, S/O
WT = 65K, RT WT = 106K, MPD
CONNECTION BACK PSI
= 435
12,565.0 12,914.0
9/4/2022
18:00
9/5/2022
00:00
6.00 PROD1, DRILL DDRL P DRILL 6 ǩ” PRODUCTION HOLE F/
12,914‘ MD - T/ 13,368‘ MD 4,183‘ TVD,
WOB = 10K, GPM =
230, PSI ON = 2,599, PSI OFF = 2,563,
RPM = 150, TQ ON = 10K, TQ OFF =
8K, FLOW OUT =
44%, ECD = 11.0 PPG, P/U WT = 160K,
S/O WT = N/A, RT WT = 110K, ADT =
8.92, TOTAL BIT
HRS = 9.95, TOTAL JAR HRS = 53.97,
MPD CONNECTION BACK PSI = 435
12,914.0 13,368.0
9/5/2022
00:00
9/5/2022
06:00
6.00 PROD1, DRILL DDRL P DRILL 6 ǩ” PRODUCTION HOLE F/
13,368‘ MD TO 13806' MD 4,183‘ TVD,
WOB = 10K, GPM = 230, PSI ON =
2,599, PSI OFF = 2,563, RPM = 150,
TQ ON = 10K, TQ OFF = 8K, FLOW
OUT = 44%, ECD = 11.0 PPG, P/U WT
= 160K, S/O WT = N/A, RT WT = 110K,
ADT = 14.92, TOTAL BIT HRS = 15.95
TOTAL JAR HRS = 56.97, MPD
CONNECTION BACK PSI = 435
13,368.0 13,806.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 39/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/5/2022
06:00
9/5/2022
12:00
6.00 PROD1, DRILL DDRL P DRILL 6 ǩ” PRODUCTION HOLE F/
13,806‘ MD - T/ 14,181‘ MD 4255‘ TVD,
WOB = 5K, GPM =
230, PSI ON = 2633, PSI OFF = 2630,
RPM = 150, TQ ON = 8K, TQ OFF = 8K,
FLOW OUT = 35%,
ECD = 10.98 PPG, P/U WT = 165K, S/O
WT = 67K, RT WT = 114K, ADT = 9.41,
TOTAL BIT HRS =
19.36, TOTAL JAR HRS = 63.38, MPD
CONNECTION BACK PSI = 385
SPR’S @ 13,885’ MD, 4,236’ TVD MW
= 9.0 PPG TIME: 07:00
#1 MP – 1BPM – 469/371 PSI 2BPM –
716/224PSI
13,806.0 14,181.0
9/5/2022
12:00
9/5/2022
18:00
6.00 PROD1, DRILL DDRL P DRILL 6 ǩ” PRODUCTION HOLE F/
14,181‘ MD - T/ 14,641‘ MD 4,258‘ TVD,
WOB = 3K, GPM =
230, PSI ON = 2504, PSI OFF = 2490,
RPM = 150, TQ ON = 9, TQ OFF = 8,
FLOW OUT = 41%,
ECD = 10.91 PPG, P/U WT = 171K, S/O
WT = N/A, RT WT = 114K, MPD
CONNECTION BACK PSI
= 385
14,181.0 14,641.0
9/5/2022
18:00
9/6/2022
00:00
6.00 PROD1, DRILL DDRL P DRILL 6 ǩ” PRODUCTION HOLE F/
14,641‘ MD - T/ 15,114‘ MD 4,259‘ TVD,
WOB = 3K, GPM =
230, PSI ON = 2,570, PSI OFF = 2,564,
RPM = 150, TQ ON = 9K, TQ OFF =
10K, FLOW OUT =
40%, ECD = 10.94 PPG, P/U WT =
174K, S/O WT = N/A, RT WT = 116K,
ADT = 9.09, TOTAL BIT
HRS = 28.45, TOTAL JAR HRS = 72.47,
MPD CONNECTION BACK PSI = 385
SPR’S @ 14,734’ MD, 4,259’ TVD MW
= 9.0PPG TIME: 19:15
#1 MP – 2BPM – 880/178PSI 3BPM –
1,120/134PSI
LOSSES FOR TOUR= 173 BBLS
LOSSES DEPTHS 13979' AND 14737'
14,641.0 15,114.0
9/6/2022
00:00
9/6/2022
06:00
6.00 PROD1, DRILL DDRL P DRILL 6 ǩ” PRODUCTION HOLE F/
15,114‘ MD T/ 15586' 4,259‘ TVD,
WOB = 3K, GPM = 230, PSI ON =
2,570, PSI OFF = 2,564, RPM = 150,
TQ ON = 9K, TQ OFF = 10K, FLOW
OUT = 40%, ECD = 10.94 PPG, P/U WT
= 174K, S/O WT = N/A, RT WT = 116K,
ADT = 9.09, TOTAL BIT HRS = 28.45,
TOTAL JAR HRS = 72.47, MPD
CONNECTION BACK PSI = 385
15,114.0 15,586.0
9/6/2022
06:00
9/6/2022
10:30
4.50 PROD1, DRILL DDRL P DRILL 6 ǩ” PRODUCTION HOLE F/
15,586‘ MD - T/ 15,871‘ MD 4273‘ TVD,
WOB= 8K, GPM=
230, PSI ON= 2564, PSI OFF= 2552,
RPM= 150, TQ ON= 11K, TQ OFF=
10K, FLOW OUT= 35%,
ECD= 11.20 PPG, P/U WT=179K, S/O
WT= N/A, RT WT= 115K, ADT= 8.45,
TOTAL BIT HRS=
36.90, TOTAL JAR HRS= 80.92, MPD
CONNECTION BACK PSI= 380
15,586.0 15,871.0
9/6/2022
10:30
9/6/2022
11:00
0.50 PROD1, DRILL SVRG P 30 MINUTE RIG SERVICE 15,871.0 15,871.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 40/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/6/2022
11:00
9/6/2022
14:00
3.00 PROD1, DRILL DDRL T WASH OUT ON SUCTION POT ON # 1
MUD PUMP, SWAPPED PUMP # 2 F/
MPD T/ HOLE,
ROT./RECIP. F/ 15,871 T/15,776 @ 230
GPM, 130 RPM, 2516 PSI, 32% F/O,
119K P/U, 105 S/O,
WHILE REPAIRING PUMP #1.
SPR’S @ 15,584’ MD, 4,264’ TVD MW
= 9.1PPG TIME: 06:00
#1 MP – 12SPM – 330/310 PSI 24SPM
– 630/230PSI
TOUR LOSSES= 102 BBLS
15,871.0 15,871.0
9/6/2022
14:00
9/6/2022
18:00
4.00 PROD1, DRILL DDRL P DRILL 6 ǩ” PRODUCTION HOLE F/
15,871‘ MD - T/ 16,153‘ MD 4,274‘ TVD,
WOB= 8K, GPM=
230, PSI ON= 2717, PSI OFF= 2630,
RPM= 150, TQ ON= 12K, TQ OFF=
11K, FLOW OUT= 35%,
ECD= 11.31 PPG, P/U WT= 191K, S/O
WT= N/AK, RT WT= 115K, MPD
CONNECTION BACK PSI=
380
15,871.0 16,153.0
9/6/2022
18:00
9/7/2022
00:00
6.00 PROD1, DRILL DDRL P DRILL 6 ǩ” PRODUCTION HOLE F/
16,153‘ MD - T/ 16,626‘ MD 4,278‘ TVD,
WOB= 3K, GPM=
230, PSI ON= 2,580, PSI OFF= 2,582,
RPM= 150, TQ ON= 12K, TQ OFF=
11K, FLOW OUT= 33%,
ECD= 11.30 PPG, P/U WT= 190, S/O
WT= N/A, RT WT= 115K, ADT= 7.39,
TOTAL BIT HRS= 44.29,
TOTAL JAR HRS= 88.31, MPD
CONNECTION BACK PSI= 385
SPR’S @ 16,153’ MD, 4,274’ TVD MW
= 9.0PPG TIME: 18:00
#2 MP – 2BPM – 940/194PSI 3BPM –
1,180/153PSI
16,153.0 16,626.0
9/7/2022
00:00
9/7/2022
06:00
6.00 PROD1, DRILL DDRL P DRILL 6 ǩ” PRODUCTION HOLE F/
16,626‘ MD TO 17099' 4,278‘ TVD,
WOB= 3K, GPM= 230, PSI ON= 2,580,
PSI OFF= 2,582, RPM= 150, TQ ON=
12K, TQ OFF= 11K, FLOW OUT= 33%,
ECD= 11.30 PPG, P/U WT= 190, S/O
WT= N/A, RT WT= 115K, ADT= 7.39,
TOTAL BIT HRS= 44.29, TOTAL JAR
HRS= 88.31, MPD CONNECTION
BACK PSI= 385
60/80 BBLS/HRS LOSSES AT 15964'
MD
16,626.0 17,099.0
9/7/2022
06:00
9/7/2022
09:00
3.00 PROD1, DRILL DDRL P DRILL 6 ǩ” PRODUCTION HOLE F/
17,099‘ MD - T/ 17,221‘ MD 4,303‘ TVD,
WOB= 3K, GPM=
230, PSI ON= 2517, PSI OFF= 2626,
RPM= 150, TQ ON= 12K, TQ OFF=
11K, FLOW OUT= 32%,
ECD= 10.92 PPG, P/U WT= 187K, S/O
WT= N/A, RT WT= 114K, ADT= 6.37,
TOTAL BIT HRS=
50.66, TOTAL JAR HRS= , MPD
CONNECTION BACK PSI= 320
17,099.0 17,221.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 41/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/7/2022
09:00
9/7/2022
13:00
4.00 PROD1, DRILL CIRC T ROTATE/ RECIP. WHILE WAITING ON
MUD, F/ 17,221 T/ 17,168, @ 200 GPM,
80 RPM, 32%
F/O, 2205 PSI, P/U RWT= 119K, S/O
RWT= 114K.
SPR’S @ 17,190’ MD, 4295’ TVD MW =
9.0 PPG TIME: 08:00
#1 MP – 2BPM – 950/180 PSI 3BPM –
1200/140PSI
TOUR FLUID LOSS - 259 BBLS
17,221.0 17,221.0
9/7/2022
13:00
9/7/2022
18:00
5.00 PROD1, DRILL DDRL P DRILL 6 ǩ” PRODUCTION HOLE F/
17,221‘ MD - T/ 17,535‘ MD 4,342‘ TVD,
WOB= 5 K, GPM=
230, PSI ON= 2710, PSI OFF= 2700,
RPM= 125, TQ ON= 11K, TQ OFF=
11K, FLOW OUT= 37%,
ECD= 11.02 PPG, P/U WT= 193K, S/O
WT= N/A, RT WT= 122K, MPD
CONNECTION BACK PSI=
340
17,221.0 17,535.0
9/7/2022
18:00
9/8/2022
00:00
6.00 PROD1, DRILL DDRL P DRILL 6 ǩ” PRODUCTION HOLE F/
17,535‘ MD - T/ 17,935‘ MD 4,360‘ TVD,
WOB= 4K, GPM=
230, PSI ON= 2,504, PSI OFF= 2,442,
RPM= 125, TQ ON= 13K, TQ OFF=
13K, FLOW OUT= 31%,
ECD= 10.54 PPG, P/U WT= 200K, S/O
WT= N/A, RT WT= 125K, ADT= 8.93,
TOTAL BIT HRS=
59.59, TOTAL JAR HRS= 103.61, MPD
CONNECTION BACK PSI= 320
SPR’S @ 17,568’ MD, 4,348’ TVD MW
= 9.0PPG TIME: 18:30
#2 MP – 2BPM – 950/204PSI 3BPM –
1,175/167PSI
TOTAL MUD LOSS 24 HRS 913 BBLS
17,535.0 17,935.0
9/8/2022
00:00
9/8/2022
06:00
6.00 PROD1, DRILL DDRL P DRILL 6 ǩ” PRODUCTION HOLE F
17,935‘ MD TO 18350' TD 4,360‘ TVD,
WOB= 4K, GPM= 230, PSI ON= 2,504,
PSI OFF= 2,442, RPM= 125, TQ ON=
13K, TQ OFF= 13K, FLOW OUT= 31%,
ECD= 10.54 PPG, P/U WT= 200K, S/O
WT= N/A, RT WT= 125K, ADT= 8.93,
TOTAL BIT HRS= 59.59, TOTAL JAR
HRS= 103.61, MPD CONNECTION
BACK PSI= 320 LOSING MUD ON
EACH STAND DRILLING 100 BBLS
17,935.0 18,350.0
9/8/2022
06:00
9/8/2022
07:00
1.00 PROD1, CASING CIRC P OBTAIN SPR'S, SHOOT FINAL
SURVEY,
@ 18,350’ MD, 4354’ TVD MW =
9.0PPG TIME: 06:30
#1 MP – 2BPM – 720/230 PSI 3BPM –
1000/180 PSI
#2 MP – 2BPM – 760/200 PSI 3BPM –
1050/165PSI
17,935.0 18,350.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 42/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/8/2022
07:00
9/8/2022
12:00
5.00 PROD1, CASING CIRC P BROOH WHILE CIRCULATE F/ 18,350'
MD T/ 18,040' MD, 1 B/U PER STAND,
GPM= 230, PSI= 2549, TQ= 13-17K,
F/O 34%, ECD= 10.59 PPG, FINAL
P/U= 215K, S/O= N/A, RTW= 120K.
MPD CONECTION BACK
PSI= 320. PUMPING LCM SWEEPS
EACH STAND.
TOUR FLUID LOSS- 590 BBLS
17,935.0 18,350.0
9/8/2022
12:00
9/8/2022
18:00
6.00 PROD1, CASING BKRM P CONT. BROOH F/ 18,040‘ MD - T/
16,910‘ MD, W/ GPM = 230, PSI =
2492, RPM = 110, TQ =
10-12K. F/O = 34%, ECD = 10.41PPG,
P/U RT WT = 122K. MPD HOLDING
320 PSI IN SLIPS.
MONITORING HOLE FILL VIA PITS #2-
5
17,935.0 18,350.0
9/8/2022
18:00
9/9/2022
00:00
6.00 PROD1, CASING BKRM P CONT. BROOH F/ 16,910‘ MD - T/
15,250‘ MD, W/ GPM = 230, PSI =
2,409, RPM = 80, TQ =
10-12K. F/O = 37%, ECD = 10.40PPG,
P/U RT WT = 122K. MPD HOLDING
320 PSI IN SLIPS.
MONITORING HOLE FILL VIA PITS #2-
5
TOTALLY FLUID LOSS= 580 BBLS
RECIEVED 400 BBLS AT 20:00HRS
17,935.0 18,350.0
9/9/2022
00:00
9/9/2022
06:00
6.00 PROD1, CASING BKRM P CONT. BROOH F 17935 T/ 13389', W/
GPM = 230, PSI = 2,409, RPM = 80, TQ
= 10-12K. F/O = 37%, ECD =
10.40PPG, P/U RT WT = 122K. MPD
HOLDING 320 PSI IN SLIPS.
MONITORING HOLE FILL VIA PITS #2-
5
17,935.0 13,389.0
9/9/2022
06:00
9/9/2022
08:30
2.50 PROD1, CASING BKRM P CONT. BROOH F/ 13,389‘ MD - T/
12,740‘ MD, W/ GPM = 230, PSI =
2330, RPM = 80, TQ = 10K.
F/O = 33%, ECD = 10.25PPG, P/U RT
WT = 118K, MPD HOLDING 320 PSI IN
SLIPS,
MONITORING HOLE FILL VIA PITS #2-
5
13,389.0 12,470.0
9/9/2022
08:30
9/9/2022
10:00
1.50 PROD1, CASING BKRM P @ 12,740 SLOW PULLING SPEED T/
200 FPH TO PULL BHA THROUGH
SHOE,@ 230 GPM, 80
RPM, 30% F/O, 2282 PSI, 112K P/U RT
WT, 10.25 ECD, 8-9K TQ, T/ 12,470'
MD.(NO OVERPULL
SEEN @ SHOE).
12,470.0 12,374.0
9/9/2022
10:00
9/9/2022
12:00
2.00 PROD1, CASING CIRC P CIRC. B/U WHILE ROTATE/RECIP. F/
12,470' MD T/12,374' MD, @ 230 GPM,
2290 PSI, 80 RPM,
33% F/O, 8K TQ, ECD= 10.19, P/U RT
WT= 112K, S/O RT WT= 103K. (7,133
TOTAL STRKS.)
TOUR FLUID LOSS- 41 bbls
12,470.0 12,374.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 43/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/9/2022
12:00
9/9/2022
12:30
0.50 PROD1, CASING OWFF P PERFORM 1 DRAWDOWN WITH MPD,
HELD STATIC @ 10 PPG
10 ppg = 222 psi
10.21 ppg = 264 psi
DRAWDOWN
TIME POSITION PSI
VOLUME RETURNED MAN
TOTCO
0 OPEN 239
0 25.1 22.1
15 OPEN 222
1.98 BBL 23.4
12,374.0 12,374.0
9/9/2022
12:30
9/9/2022
13:15
0.75 PROD1, CASING CIRC P DROP ACTIVATION BALL FOR WELL
COMMANDER AS PER DD (1.75"),
PUMP DOWN @ 120
GPM, 900 PSI BALL ON SEAT @ 998
STKS, WELL COMMANDER OPEN @
2466 PSI W/ 320 PSI
ON MPD
12,374.0 12,374.0
9/9/2022
13:15
9/9/2022
17:30
4.25 PROD1, CASING CIRC P CIRCULATE 3X BOTTOMS UP
THROUGH WELL COMMANDER, ROT
& RECIP F/ 12,470‘ MD -
T/ 12,374‘ MD, W/ GPM = 320, PSI =
1826, FLOW OUT = 38%, RPM = 80,
TQ = 8K, P/U RT WT =
108K, S/O RT WT = 106K, TOTAL
PUMPED 21,338 STKS
12,470.0 12,374.0
9/9/2022
17:30
9/9/2022
18:15
0.75 PROD1, CASING CIRC P DROP 1.75" BALL TO CLOSE WELL
COMMANDER @ 120 GPM, 550 PSI,
38% F/O, @ 970 STKS
AWAY DROP RATE T/ 84 GPM, 465
PSI, 38% F/O. @ 1,008 STKS
OBSERVE PUMP PRESSURE
INCREASE T/ 2,708 PSI AND THEN
SHEAR OUT. WELL COMMANDER
CONFIRMED CLOSED
PER SLB DD
12,374.0 12,374.0
9/9/2022
18:15
9/9/2022
19:30
1.25 PROD1, CASING CIRC P ROT AND RECIP F/ 12,470' MD T/
12,374' MD, @ 230 GPM, 2,200 PSI, 80
RPM, 39% F/O, 8K TQ,
ECD= 10.06, P/U RT WT= 112K, S/O
RT WT= 103K. (4,856 TOTAL STRKS.)
PREP IN MUD PITS FOR
DISPLACEMENT
12,470.0 12,374.0
9/9/2022
19:30
9/9/2022
21:00
1.50 PROD1, CASING CIRC P PUMP 80 BBLS 9.5 PPG SPACER,
SPOT 500' OF THE SPACER F/ 12,470'
MD T/ 12,000' MD @
5 BPM, 1,993 PSI, 32% F/O, 80 RPM,
8K TQ, ROT WT= 123K
12,470.0 12,000.0
9/9/2022
21:00
9/10/2022
00:00
3.00 PROD1, CASING CIRC P DISPLACE 9.0 PPG VERSAPRO W/
10.0 PPG VERSACLEAN. ROT AND
RECIP F/ 12,000' MD T/
11,904' MD FOLLOWING MPD
PUMPING SCHEDULE. ICP= 2,101,
22% F/O, 80 RPM, 8K TQ, ROT
P/U WT= 109K, ROT S/O WT= 106K
12,000.0 11,904.0
9/10/2022
00:00
9/10/2022
03:00
3.00 PROD1, CASING CIRC P DISPLACE 9.0 PPG VERSAPRO W/
10.0 PPG VERSACLEAN. ROT AND
RECIP F/ 12,000' MD T/ 11,904' MD
FOLLOWING MPD PUMPING
SCHEDULE. ICP= 2,101, 22% F/O, 80
RPM, 8K TQ, ROT P/U WT= 109K, ROT
S/O WT= 106K
12,000.0 11,904.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 44/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/10/2022
03:00
9/10/2022
03:30
0.50 PROD1, CASING OWFF P OWFF WELL STATIC B/D TANK FARM
LINES, FLUSH MP #1 W/ 10 PPG LINE
PUMPS BACK UP.
12,000.0 11,904.0
9/10/2022
03:30
9/10/2022
06:30
3.00 PROD1, CASING STRP P SOOH W/ 5" DP F/ 12000'MD T/ 10461'
P/U 133K MONITORING HOLE FILL
VIA PITS #6 MPD HOLDING 130 PSI =
10.2 PPG
12,000.0 10,461.0
9/10/2022
06:30
9/10/2022
07:30
1.00 PROD1, CASING STRP P MONITOR WELL FOR FLOW PRIOR
TO PULLING MPD BEARING (STATIC),
PULL BEARING
PER MPD REP
12,000.0 10,461.0
9/10/2022
07:30
9/10/2022
10:00
2.50 PROD1, CASING STRP P FILL TRIP TANK W/ 10.0 PPG OBM
FOR TRIP, C/O HANDLING
EQUIPMENT AND RE-DRESS
SLIPS AND IRON ROUGHNECK FROM
5" TO 4",
12,000.0 10,461.0
9/10/2022
10:00
9/10/2022
11:00
1.00 PROD1, CASING TRIP P ATTEMPT TRIP OUT OF HOLE @
10,461' MD ON ELEVATORS, (SWAB
OBSERVED). DECISION
MADE TO PUMP OUT OF HOLE.
12,000.0 10,461.0
9/10/2022
11:00
9/10/2022
12:00
1.00 PROD1, CASING PMPO P PUMP OUT OF HOLE F/ 10,461' MD T/
9,927' MD, @ 110 GPM, P/U WT=
110K. MONITOR HOLE
FILL VIA PIT #6.
12,000.0 10,461.0
9/10/2022
12:00
9/10/2022
13:30
1.50 PROD1, CASING PMPO P CONT. TO PUMP OUT OF HOLE F/
9,927' MD T/9,643' MD, @ 110 GPM,
P/U WT= 110K.
MONITOR HOLE FILL VIA PIT #6,
ATTEMPT TO PULL ON ELEVATORS,
(STILL SWABBING),
DECISION MADE TO INSTALL 4"
BEARING FOR STRIPPING OUT
10,461.0 9,927.0
9/10/2022
13:30
9/10/2022
14:30
1.00 PROD1, CASING MPDA P PULL TRIP NIPPLE, INSTALL DRIP
NIPPLE, INSTALL MPD BEARING PER
MPD REP. BDTD
9,927.0 9,927.0
9/10/2022
14:30
9/10/2022
22:45
8.25 PROD1, CASING STRP P SOOH UTILIZING MPD TO MITIGATE
SWAB F/ 9,643‘ MD - T/ 558‘ MD
(STD#1), W/ 4” DP, RK BK
IN DRK, P/U WT = 75K, MPD HOLDING
90 PSI OUT OF SLIPS, 50 PSI IN
SLIPS. MONITOR HOLE
FILL VIA PIT #6
9,927.0 558.0
9/10/2022
22:45
9/10/2022
23:15
0.50 PROD1, CASING OWFF P FLOW CHECK (STATIC). CLEAN RIG
FLOOR
558.0 558.0
9/10/2022
23:15
9/11/2022
00:00
0.75 PROD1, CASING MPDA P REMOVE MPD BEARING, INSTALL
TRIP NIPPLE PER BEYOND REP
558.0 558.0
9/11/2022
00:00
9/11/2022
00:30
0.50 PROD1, CASING MPDA P REMOVE MPD BEARING, INSTALL
TRIP NIPPLE PER BEYOND REP
558.0 558.0
9/11/2022
00:30
9/11/2022
01:45
1.25 PROD1, CASING RURD P RCD CLAMP LEAKING, PUL RISER
AND FIXED LEAK
558.0 558.0
9/11/2022
01:45
9/11/2022
03:00
1.25 PROD1, CASING TRIP P CONT. POOH F/ 558' TO 282' P/U WT
60 MONITORING WELL VIA PIT #6
CHANGE OUT JARS WITH JOINT OF
HEAVY WEIGHT DRILL PIPE
558.0 282.0
9/11/2022
03:00
9/11/2022
05:30
2.50 PROD1, CASING BHAH P L/D PRODUCTION BHA FROM 282' TO
SURFACE
282.0 0.0
9/11/2022
05:30
9/11/2022
07:00
1.50 PROD1, CASING CLEN P CLEAN AND CLEAR BHA AND TOOLS
FROM RIG FLOOR
0.0 0.0
9/11/2022
07:00
9/11/2022
09:15
2.25 COMPZ1, CASING RURD P P/U CASING EQUIPMENT, P/U PUP
JTS, CENTRILIZERS, R/U TO RUN 4
1/2" LINER
0.0 0.0
9/11/2022
09:15
9/11/2022
09:30
0.25 COMPZ1, CASING SFTY P HOLD PJSM ON RUNNING 4.5" LINER 0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 45/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/11/2022
09:30
9/11/2022
09:45
0.25 COMPZ1, CASING RCST P P/U-RUN 4.5" 12.6# L-80 H563 SHOE 0.0 0.0
9/11/2022
09:45
9/11/2022
11:00
1.25 COMPZ1, CASING RCST P RIH W/ 4.5" 12.5# H563 LINER F/
SURFACE T/268' MD FILLED PIPE
AND CHECKED FLOATS
0.0 268.0
9/11/2022
11:00
9/11/2022
12:00
1.00 COMPZ1, CASING RCST P RIH W/ 4.5" 12.5# H563 LINER F/ 268'
MD , T/ 775' MD, FILLING PIPE VIA
FILL HOSE,
MONITORING DISPLACEMENT VIA
PIT 6. PU/SO =50K
268.0 775.0
9/11/2022
12:00
9/11/2022
18:00
6.00 COMPZ1, CASING RCST P RIH W/ 4.5" 12.5# L-80 HYD 563 LINER
F/ 775' MD , T/ 5140' MD, FILLING
PIPE ON THE FLY,
TOPPING OFF EVERY 10 JTS.
MONITORING DISPLACEMENT VIA
PIT 6. M/U TQ F/ HYD563=
3.8K, M/U TQ F/ HYD521= 4.7K
775.0 5,140.0
9/11/2022
18:00
9/11/2022
19:30
1.50 COMPZ1, CASING RCST P RIH W/ 4.5" 12.5# L-80 HYD 563 LINER
F/ 5,140' MD , T/ 5,993' MD, FILLING
PIPE ON THE FLY,
TOPPING OFF EVERY 10 JTS.
MONITORING DISPLACEMENT VIA
PIT 6. M/U TQ F/ HYD563=
3.8K, M/U TQ F/ HYD521= 4.7K. P/U
WT= 80K, S/O WT= 70K
5,140.0 5,993.0
9/11/2022
19:30
9/11/2022
22:00
2.50 COMPZ1, CASING PULD P M/U LINER HANGER AND ZXP
PACKER ASSEMBLY PER BAKER
HUGHES REP F/ 5,993' MD T/6067' MD
6,067' MD. P/U WT= 81K, S/O WT=
72K
5,993.0 6,067.0
9/11/2022
22:00
9/11/2022
22:30
0.50 COMPZ1, CASING RUNL P RIH W/ 4" DP F/ 6,067' MD T/ 6,175'
MD. ESTABLISH CIRCULATION @ 2
BPM, 270 PSI, 30% F/O.
OBTAIN T&D PARAMETERS PER
BAKER HUGHES REP.
2 BPM- 10 RPM= 2K TQ, 30 RPM= 2K
TQ, ROT WT= 77K, P/U WT= 82K, S/O
WT= 73K
PUMPS OFF- 10 RPM= 2K TQ, 30
RPM= 2K TQ, ROT WT= 77K, P/U WT=
83K, S/O WT= 73K
6,067.0 6,175.0
9/11/2022
22:30
9/12/2022
00:00
1.50 COMPZ1, CASING RUNL P RIH W/ 4" DP F/ 6,175' MD T/ 7,493'
MD, MONITORING DISPLACEMENT
VIA PIT #6. S/O WT=
73K. FILLING DP ON THE FLY,
TOPPING OFF EVERY 5 STDS
6,175.0 7,493.0
9/12/2022
00:00
9/12/2022
02:15
2.25 COMPZ1, CASING RUNL P CONT.RIH W/ 4" DP F/ 7,493' TO
9858' MD , MONITORING
DISPLACEMENT VIA PIT #6. S/O WT=
73K. FILLING DP ON THE FLY,
TOPPING OFF EVERY 5 STDS
7,493.0 9,858.0
9/12/2022
02:15
9/12/2022
03:00
0.75 COMPZ1, CASING RUNL P RIH W/ 4" HWDP F/ 9,858' MD T/
10,412' MD (6 STDS), MONITORING
DISPLACEMENT VIA PIT #6.
S/O WT= 77K. FILLING DP ON THE
FLY, TOPPING OFF EVERY 3 STDS
9,858.0 10,412.0
9/12/2022
03:00
9/12/2022
03:45
0.75 COMPZ1, CASING RURD P CHANGE OUT HANDLING
EQUIPMENT FOR 5" DP
10,412.0 10,412.0
9/12/2022
03:45
9/12/2022
07:30
3.75 COMPZ1, CASING RUNL P RIH W/ 5" DP F/ 10,412' MD T/ 12395'
MD, MONITORING DISPLACEMENT
VIA PIT #6. S/O WT= XK.
FILLING DP ON THE FLY, TOPPING
OFF EVERY 5 STDS.
10,412.0 12,395.0
9/12/2022
07:30
9/12/2022
08:15
0.75 COMPZ1, CASING OWFF P FLOW CHECK (STATIC). REMOVE
TRIP NIPPLE, INSTALL MPD BEARING
PER BEYOND REP.
12,395.0 12,395.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 46/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/12/2022
08:15
9/12/2022
09:00
0.75 COMPZ1, CASING RUNL P RIH W/ 5" DP F/ 12,395MD T/ 12,470'
MD, MONITORING DISPLACEMENT
VIA PIT #6. S/O WT=
86K.
12,395.0 12,470.0
9/12/2022
09:00
9/12/2022
16:30
7.50 COMPZ1, CASING CIRC P BEGIN DISPLACEMENT - PUMP 80
BBL 9.5PPG OBM SPACER, CHASED
BY 9.0PPG OBM @
50 GPM, 465 PSI. SLOWED PUMP
RATE TO 40 GPM, 491 PSI, (1,860
STKS) DUE TO LOSSES
12,470.0 12,470.0
9/12/2022
16:30
9/12/2022
17:00
0.50 COMPZ1, CASING THGR P OBTAIN T&D PARAMETERS W/
PUMPS OFF - 10 RPM, 6K TQ. 30
RPM, 6K TQ, ROT WT =
116K, P/U WT = 138K, S/O WT = 85K
12,470.0 12,470.0
9/12/2022
17:00
9/13/2022
00:00
7.00 COMPZ1, CASING RUNL P SIH W/ 5" DP - DRIFTING FROM
DERRICK W/ 2'' DRIFT, F/ 12,470' MD
T/ 16,380' MD, P/U WT=
162K, S/O WT = 70K, MONITOR
DISPLACEMENT VIA PIT 4, FILLING
EVERY 5 STDS. MPD
PRESSURE IN SLIPS = 220 PSI / OUT
OF SLIPS = 70 PSI
12,470.0 16,380.0
9/13/2022
00:00
9/13/2022
04:00
4.00 COMPZ1, CASING RUNL P SIH W/ 5" DP - DRIFTING FROM
DERRICK W/ 2'' DRIFT, F/ 16380' MD
T/ 18340' MD, P/U WT= 162K, S/O WT
= 70K, MONITOR DISPLACEMENT VIA
PIT 4, FILLING EVERY 5 STDS. MPD
PRESSURE IN SLIPS = 220 PSI / OUT
OF SLIPS = 70 PSI
HANGER IS ON DEPTH 12331'MD
16,380.0 18,340.0
9/13/2022
04:00
9/13/2022
06:30
2.50 COMPZ1, CASING CIRC P CIRCULATE B/U @ 3 BPM @ 864 PSI
9% FLOW OUT SLOW TO 2 BPM 664
SLOW TO 1 BPM 532PSI DUE TO
LOSES
18,340.0 18,340.0
9/13/2022
06:30
9/13/2022
09:30
3.00 COMPZ1, CASING CIRC P PUMP 15 BBLS HI-VIS SPACER, SHUT
DOWN/DROP 1" BALL, CHASE BALL
AT 3.5 BPM, BALL
DID NOT SEAT, @3281 STRKS SHUT
DOWN AND DROP BALL # 2 (1.5"). @
3737 TOTAL
STROKES FIRST BALL SEATS
18,340.0 18,340.0
9/13/2022
09:30
9/13/2022
10:00
0.50 COMPZ1, CASING THGR P PRESSURE UP TO 2000 PSI AND SET
DOWN TO 50K HOOKLOAD PER
BAKER REP.,
PRESSURE UP TO 2500 PSI/HOLD 5
MIN., PRESSURE UP TO 3000
PSI/HOLD 5 MIN., (PACKER
SET @ 2700 PSI), PRESSURED UP
TO SHEAR BALL SEAT (4941 PSI).
18,340.0 18,340.0
9/13/2022
10:00
9/13/2022
11:00
1.00 COMPZ1, CASING PRTS P P/U ROTATING DOG SUB AND SET
LINER TOP PACKER PER BAKER
REP / TOL 12,287' MD
12,287.0 12,287.0
9/13/2022
11:00
9/13/2022
12:00
1.00 COMPZ1, CASING PRTS P PRESSURE TEST TOP OF LINER TOP
PACKER TO 3500 PSI F/ 10 MIN.
(CHARTED '
12,287.0 12,287.0
9/13/2022
12:00
9/13/2022
14:45
2.75 COMPZ1, WELLPR CIRC P P/U TO PULL RUNNING TOOL OUT OF
SPACER PER BAKER REP F 12287'. T/
12,168' MD, KELLY UP T/
CIRCULATE B/U, 250 GPM, 1040 PSI
12,287.0 12,168.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 47/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/13/2022
14:45
9/13/2022
16:30
1.75 COMPZ1, WELLPR FRZP P R/U TO INJECT OA W/ LVT FOR LOT,
PRESSURE UP T/ 800 PSI @ 6SPM
(1ST PRESSURE STOP). PUMPED 42
STRKS (3.5 BBLS), SHUT-IN AND
MONTIORED PRESSURE. BLED
BACK 1.3 BBLS,
NOTIFIED TOWN OF RESULTS.
PROCEEDED WITH 2ND TEST.
PRESSURE UP T/ 880 PSI @ 58
STRKS, SAW PRESSURE
DROP/STABALIZE, THEN START TO
KLIMBING TO MAX PRESSURE OF
1015 PSI @ 175 STRKS THEN DROP
TO 920 PSI BY END OF 245 STRKS
(20.75 BBLS W/ 0 BLEED BACK).
INJECTED TOTAL OF 23 BBLS W/ RIG.
12,168.0 12,168.0
9/13/2022
16:30
9/13/2022
17:00
0.50 COMPZ1, WELLPR FRZP P SWAP OVER TO LITTLE RED TO
FREEZE PROTECT ANNULUS /
SIMOPS EMPTY PITS 1-4 IN
PREP FOR DISPLACEMENT
PUMPED WITH LRS, STAGE RATE UP
TO 2 BPM.
PUMPED 70 BBLS W/ MAX
PRESSURE OF 1082 PSI. SHUT
DOWN AND MONITOR W/ PRESSURE
STABALIZING AT 945 PSI. PUMPED
AN ADDITIONAL 5 BBLS W/ MAX
PRESSURE OF 1074 PSI. SHUT
DOWN, PRESSURE STABLIZED TO
960 PSI. BLEED OFF OA TO 300 PSI
BLEED BACK 8 BBLS. PUMP AN
ADDITIONAL 11 BBLS (@ 0.25 BPM)
W/ MAX PRESSURE OF 1130 PSI.
SHUT DOWN AND MONITOR FOR 20
MIN W/ PRESSURE SLOWLY BLEED
TO 1,000 PSI. BLEED BACK OA TO
400 PSI, BLEED BACK 7 BBLS.
INJECTED A TOTAL OF 71 BBLS WITH
LRS.
TOTAL FREEZE PROTECT W/ 102
BBLS OF DIESEL/LVT (W/ 8 BBLS
PREVIOUSLY PUMPED).
12,168.0 12,168.0
9/13/2022
17:00
9/13/2022
21:00
4.00 COMPZ1, WELLPR CIRC P DISPLACE WELL F/ 9.0 PPG OBM T/
9.5 BRINE, PUMP 20 BBLS LVT F/ PILL
PIT 1, SWAP ON
THE FLY T/ 100 BBLS 11.0 PPG
TRANSITION SPACER F/ PIT 5, SWAP
T/ 40 BBLS 9.5 PPG
CLEANING SPACER F/ PIT 6, SWAP T/
35 BBLS 9.5 PPG HI-VIS SPACER F/
PIT 7, CHASED BY
9.5 PPG BRINE, @ 210 GPM, 651 PSI,
33% F/O. TOTAL STKS PUMPED=
11,339 (968 BBLS
12,168.0 12,168.0
9/13/2022
21:00
9/13/2022
21:45
0.75 COMPZ1, WELLPR OWFF P OWFF (STATIC 12,168.0 12,168.0
9/13/2022
21:45
9/13/2022
22:45
1.00 COMPZ1, WELLPR MPDA P REMOVE MPD BEARING, INSTALL
TRIP NIPPLE PER BEYOND REP
12,168.0 12,168.0
9/13/2022
22:45
9/13/2022
23:30
0.75 COMPZ1, WELLPR CLEN P B/D TOP DRIVE, CLEAN AND CLEAR
RIG FLOOR
12,168.0 12,168.0
9/13/2022
23:30
9/14/2022
00:00
0.50 COMPZ1, WELLPR TRIP P POOH SIDEWAYS W/ 5" DP F/ 12,168'
MD T/ 11,937' MD L/D PIPE IN SHED.
MONITORING
HOLE FILL VIA TRIP TANK. P/U WT=
164K
12,168.0 11,937.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 48/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/14/2022
00:00
9/14/2022
06:00
6.00 COMPZ1, WELLPR TRIP P TOOH LAYING DOWN 5" DP F/ 11,937'
TO 9111' MD L/D PIPE IN SHED.
MONITORING HOLE FILL VIA TRIP
TANK. P/U WT= 145K
11,937.0 9,111.0
9/14/2022
06:00
9/14/2022
09:00
3.00 COMPZ1, WELLPR TRIP P CONT. POOH SIDEWAYS W/ 5" DP F/
9,111' MD T/4,342 ' MD L/D PIPE IN
SHED. MONITORING
HOLE FILL VIA TRIP TANK. P/U WT=
93K.
9,111.0 4,342.0
9/14/2022
09:00
9/14/2022
09:30
0.50 COMPZ1, WELLPR RURD P C/O HANDLING EQUIPMENT FROM 5"
T/ 4".
4,342.0 4,342.0
9/14/2022
09:30
9/14/2022
12:00
2.50 COMPZ1, WELLPR TRIP P CONT. POOH SIDEWAYS W/ 4" DP F/
4,342' MD T/ 3,209' MD L/D PIPE IN
SHED. MONITORING
HOLE FILL VIA TRIP TANK
4,342.0 3,209.0
9/14/2022
12:00
9/14/2022
15:00
3.00 COMPZ1, WELLPR TRIP P CONT. POOH SIDEWAYS W/ 4" DP F/
3,209' MD T/ SURFACE, L/D PIPE IN
SHED.
MONITORING HOLE FILL VIA TRIP
TANK
3,209.0 0.0
9/14/2022
15:00
9/14/2022
15:45
0.75 COMPZ1, WELLPR BHAH P L/D LINER RUNNING TOOL PER
BAKER REP
0.0 0.0
9/14/2022
15:45
9/14/2022
16:00
0.25 COMPZ1, WELLPR OWFF P OWFF (STATIC). 0.0 0.0
9/14/2022
16:00
9/14/2022
16:30
0.50 COMPZ1, WELLPR CLEN P CLEAN/CLEAR FLOOR, M/U UP
STACK WASHER T/ RUN STANDS
OUT OF DERRICK IN THE
HOLE
0.0 0.0
9/14/2022
16:30
9/14/2022
18:45
2.25 COMPZ1, WELLPR TRIP P RIH W/ 4" DP F/ DERRICK T/ 6,187'MD,
MONITORING DISPLACEMENT VIA
TRIP TANK
0.0 6,187.0
9/14/2022
18:45
9/15/2022
00:00
5.25 COMPZ1, WELLPR TRIP P POOH SIDEWAYS W/ 4" DP F/ 6,187'
MD T/ 600', L/D PIPE IN SHED.
MONITORING HOLE FILL
VIA TRIP TANK. P/U WT= 50K
6,187.0 600.0
9/15/2022
00:00
9/15/2022
01:00
1.00 COMPZ1, WELLPR TRIP P POOH SIDEWAYS W/ 4" DP F/ 600' MD
T/ SURFACE ', L/D PIPE IN SHED.
MONITORING HOLE FILL VIA TRIP
TANK. P/U WT= 50K
600.0 0.0
9/15/2022
01:00
9/15/2022
01:30
0.50 COMPZ1, RPCOMP WWWH P WASH BOP STACK AS PER FMC REP 0.0 0.0
9/15/2022
01:30
9/15/2022
02:00
0.50 COMPZ1, RPCOMP WWSP P PULL WEAR RING PER FMC REP 0.0 0.0
9/15/2022
02:00
9/15/2022
02:45
0.75 COMPZ1, RPCOMP WWWH P WASH WELL HEAD AS PER FMC REP
WHILE CLEANING RIG FLOOR
0.0 0.0
9/15/2022
02:45
9/15/2022
05:00
2.25 COMPZ1, RPCOMP RURD P PJSM R/U UPPER COMPLETION
HANDLING TOOLS AND SLB
COMMUNICATION CABLE, HANG
SHEAVE IN DERRICK PJSM TO RUN
UPPER COMPLETION W/ BAKER,
DOYON, SLB, ,CPAI
0.0 0.0
9/15/2022
05:00
9/15/2022
05:30
0.50 COMPZ1, RPCOMP PUTB P M/U MULE SHOE, PREMIER PACKER
F/ SURFACE T/ 153' MD, S/O WT= 45K
0.0 153.0
9/15/2022
05:30
9/15/2022
06:30
1.00 COMPZ1, RPCOMP PUTB P P/U DHG + MANDREL AND NOTICE IT
WAS INSTALLED UPSIDE DOWN.
ORIENT THE
MANDREL IN CORRECT POSITION
153.0 153.0
9/15/2022
06:30
9/15/2022
07:30
1.00 COMPZ1, RPCOMP PUTB P M/U MANDREL, GLM AND SLIDING
SLEEVE F/ 153' MD T/ 314' MD, S/O
WT= 46K
153.0 314.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 49/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/15/2022
07:30
9/15/2022
12:00
4.50 COMPZ1, RPCOMP PUTB P RIH W/ 4 1/2" 12.6# L-80 HYD 563 TBG
F/ 314' MD T/ 3,893' MD. MONITORING
DISPLACEMENT
VIA TRIP TANK. INSTALLING CANNON
CLAMP EACH CONNECTION. HYD
521 M/U TQ= 4.7K,
HYD 563 M/U TQ= 3.8K. S/O WT= 74K
314.0 3,893.0
9/15/2022
12:00
9/15/2022
18:00
6.00 COMPZ1, RPCOMP PUTB P RIH W/ 4 1/2" 12.6# L-80 HYD 563 TBG
F/ 3,893' MD T/ 8194' MD.
MONITORING
DISPLACEMENT VIA TRIP TANK.
INSTALLING CANNON CLAMP EACH
CONNECTION. HYD 521
M/U TQ= 4.7K, HYD 563 M/U TQ= 3.8K.
S/O WT= 70K SIMOPS BLEED OA
PRESSURE F/ 600 PSI
T/ 250 PSI = 3BBL
3,893.0 8,194.0
9/15/2022
18:00
9/15/2022
22:00
4.00 COMPZ1, RPCOMP PUTB P RIH W/ 4 1/2" 12.6# L-80 HYD 563 TBG
F/ 8194' MD T/ 12,300' MD.
MONITORING
DISPLACEMENT VIA TRIP TANK.
INSTALLING CANNON CLAMP EACH
CONNECTION. HYD 521
M/U TQ= 4.7K, HYD 563 M/U TQ= 3.8K.
P/U WT = 106K, S/O WT = 69K
8,194.0 12,300.0
9/15/2022
22:00
9/15/2022
23:00
1.00 COMPZ1, RPCOMP THGR P TAG NO-GO @ 12,300'. P/U TO
BREAK OVER, SLACK OFF AND SET
DOWN 10K CONFIRM
DEPTH, P/U 5' OF FREE TRAVEL, S/O
AND TAG, SET DOWN 15K TO SHEAR
LOCATOR PIN,
POOH T/12,180', P/U 106K, L/D JT
#301, 300, 299 AND STRAP IN SHED
TO FIGURE SPACE OUT
AS PER CO-MAN
12,300.0 12,300.0
9/15/2022
23:00
9/15/2022
23:30
0.50 COMPZ1, RPCOMP PUTB P RIH W/ SPACE OUT PUPS, F/12,180'
T/12,260', SOW=69K, "PUP LENGTHS"
9.73', 9.78', 9.76',
7.28' & JT #299
12,180.0 12,260.0
9/15/2022
23:30
9/16/2022
00:00
0.50 COMPZ1, RPCOMP THGR P M/U LINER HANGER & LANDING JT
AS PER FMC REP
12,260.0 12,260.0
9/16/2022
00:00
9/16/2022
01:00
1.00 COMPZ1, RPCOMP THGR P MAKE UP CONTROL LINE TO TBG
HANGER AS PER FMC REP. TEST TO
5000 PSI FOR 10 MIN COP REP
WITNESSED. RIH AND LAND OUT
HANGER @ 12298' RUN IN LOCK
DOWN PINS
FINAL CLAMP COUNT
306 CROSS COUPLINGS
2 MID JOINT
12,260.0 12,298.0
9/16/2022
01:00
9/16/2022
03:00
2.00 COMPZ1, RPCOMP PRTS P FILL STACK AND SURFACE LINES,
SHUT UPPER RAMS TEST TUBING
HANGER SEALS VIA KILL LINE 250
PSI 5 MIN 4000 PSI 10 MIN CHARTED
AS PER CO MAN, MONITOR OA
PRESSURE AT ALL TIMES
12,298.0 12,298.0
9/16/2022
03:00
9/16/2022
05:00
2.00 COMPZ1, RPCOMP PRTS P RIG UP HEAD PIN AND CEMENT
HOSE TO PT TUBING, FILL ALL
SURFACE LINES AND PT,
PRESSURE TEST TUBING TO
3500PSI, 30 MIN "CHARTED" BLEED
TUBING TO 3000PSI
12,298.0 12,298.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 50/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/16/2022
05:00
9/16/2022
05:45
0.75 COMPZ1, RPCOMP PRTS P FIOOD INJECTION LINE, PT
IA/TUBING HANGER, 3850PSI, 30
"CHARTED" BLEED OF OA
PRESSURE AS NEEDED, BLEED
TUBING BACK DOWN TO 3000PSI TO
ENSURE GOOD TEST
ON IA
12,298.0 12,298.0
9/16/2022
05:45
9/16/2022
06:00
0.25 COMPZ1, RPCOMP WWSP P BLEED TUBING PRESSURE TO 0PSI
TO SHEAR THE SOV, BOTH TUBING
AND IA @ 0 PSI
12,298.0 12,298.0
9/16/2022
06:00
9/16/2022
06:30
0.50 COMPZ1, RPCOMP CIRC P LINE UP TO REVERSE CIRC. PUMP
@ 1BPM, 78 PSI, 12% F/O. 69 STKS
PUMPED
12,298.0 12,298.0
9/16/2022
06:30
9/16/2022
07:00
0.50 COMPZ1, RPCOMP RURD P R/D DDI CSG EQUIPMENT. L/D CSG
TONGS, ELEVATORS DWN BEAVER
SLIDE. SIMOPS
MONITOR WELL FOR FLOW F/ 30
MIN.
12,298.0 12,298.0
9/16/2022
07:00
9/16/2022
07:45
0.75 COMPZ1, RPCOMP RURD P R/D AND L/D LANDING JT AS PER
FMC REP, B/D CEMENT HOSE.
12,298.0 12,298.0
9/16/2022
07:45
9/16/2022
08:30
0.75 COMPZ1, RPCOMP PRTS P INSTALL BPV AND TEST T/ 2500 PSI
F/ 10 MIN CHARTED. 66 STKS
PUMPED
12,298.0 12,298.0
9/16/2022
08:30
9/16/2022
10:30
2.00 COMPZ1, RPCOMP CLEN P REMOVE CONTROL LINE SPOOL
FROM RIG FLOOR. CLEAN AND
CLEAR RIG FLOOR.
SIMOPS SUCK STACK OUT VIA RIG
VAC. B/D MPD AND INJ LINES,
CHOKE/KILL. OFFLOAD
FLIUD IN PITS TO VAC TRUCKS
12,298.0 12,298.0
9/16/2022
10:30
9/16/2022
12:00
1.50 COMPZ1, WHDBOP NUND P NIPPLE DWN MPD RCD HEAD, AIR
VALVE AND 2" HOSES
12,298.0 12,298.0
9/16/2022
12:00
9/16/2022
14:45
2.75 COMPZ1, WHDBOP NUND P REMOVE CHOKE AND KILL LINE.
BREAK STACK, BOTH SPACER
SPOOLS AND RACK BACK.
STACK
12,298.0 12,298.0
9/16/2022
14:45
9/16/2022
15:15
0.50 COMPZ1, WHDBOP NUND P REMOVE BOTH SPACER SPOOLS 12,298.0 12,298.0
9/16/2022
15:15
9/16/2022
17:15
2.00 COMPZ1, WHDBOP WWSP P TERMINATE CONTROL LINE AS PER
SLMB REP. SIMOPS PREP TREE
ADAPTER FLANGE
12,298.0 12,298.0
9/16/2022
17:15
9/16/2022
18:00
0.75 COMPZ1, WHDBOP NUND P PREP CELLAR FOR TREE INSTALL AS
PER FMC REP
12,298.0 12,298.0
9/16/2022
18:00
9/16/2022
21:30
3.50 COMPZ1, WHDBOP NUND P INSTALL TREE AS PER FMC REP,
ORIENT AS PER PAD OPERATOR ,
TORQ ALL BOLTS TO
SPEC, SIM-OPS CON'T CLEANING
OBM IN MUD PITS, PREP FOR
TESTNG OF TREE
12,298.0 12,298.0
9/16/2022
21:30
9/16/2022
22:00
0.50 COMPZ1, WHDBOP PRTS P FMC REP TEST VOID ON TREE,
5OOO PSI, 10 MIN WITNESS BY COP
REP AND COP COMPLETION ENG.
12,298.0 12,298.0
9/16/2022
22:00
9/16/2022
23:30
1.50 COMPZ1, WHDBOP FRZP P RIG UP LINES AND MANIFOLD FOR
FREEZE PROTECT/ U-TUBE, FILL
TREE W/DIESEL
12,298.0 12,298.0
9/16/2022
23:30
9/17/2022
00:00
0.50 COMPZ1, WHDBOP RURD P FILL LINES W/ DIESEL TO GET
READY FOR PRESSURE TEST
12,298.0 12,298.0
9/17/2022
00:00
9/17/2022
03:00
3.00 COMPZ1, WHDBOP PRTS P TEST PRODUCTION TREE TO 250 PSI
LOWQ AND 5000 PSI HIGH 15 MIN ON
CHART
0.0 0.0
9/17/2022
03:00
9/17/2022
04:30
1.50 COMPZ1, WHDBOP WWSP P REMOVE DART AND BPV AS PER
FMC HAND REP.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
Page 51/51
CD4-597
Report Printed: 9/26/2022
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/17/2022
04:30
9/17/2022
06:00
1.50 COMPZ1, WHDBOP RURD P CLEANING OF MUD PITS, CELLAR
AND BOP DECK, WAITING ON LRS
FOR FREEZE PROTECT
0.0 0.0
9/17/2022
06:00
9/17/2022
08:00
2.00 COMPZ1, WHDBOP RURD P CONT. WAITING ON LRS, GATHER
CPAI X/O'S, AND PREP FOR SENDING
OUT.
0.0 0.0
9/17/2022
08:00
9/17/2022
09:45
1.75 COMPZ1, WHDBOP FRZP P RIG UP LRS, PT LINES AND PUMP
110 BBL OF DIESEL DOWN IA TAKING
RETURNS UP
TUBING 825 PSI, 2 BPM. FINAL SHUT
IN PRESS. 550 PSI, SHUT IN AND
EQUALIZE IA AND
TUBING (U-TUBE)
0.0 0.0
9/17/2022
09:45
9/17/2022
12:00
2.25 COMPZ1, WHDBOP OWFF P SHUT IN, EQUALIZE IA AND TUBING
(U-TUBE), SIMOPS CLEAN PITS WITH
DEEP CLEAN.
OFFLOAD FLUID IN PITS. CONT.
GATHERING CPAI X/O'S AND PREP
TO SEND OUT.
PRESSURE WASH DERRICK
WINDWALLS
0.0 0.0
9/17/2022
12:00
9/17/2022
14:30
2.50 COMPZ1, WHDBOP OWFF P CONT. ALLOWING WELL TO U-TUBE.
PRESSURE STABILIZED AT 200 PSI.
BLED PRESSURE
TO ZERO .5 BBL TO BLEED OFF
TANK. REMOVE TOP DRIVE LINK
ADAPTERS AND SEND TO
SHOP FOR REPAIR. REMOVE
HERCULITE FROM TANK FARM AREA
AND ROLL UP. CONT.
FLUSHING PITS WITH DEEP CLEAN.
SERVICE TOP DRIVE TRACTION
MOTORS. PRESSURE
WASH DERRICK WINDWALLS.
PERFORM MP2'S ON DRAWWORKS.
PRESSURE WASH
DERRICK WINDWALLS. PERFORM
MP2'S ON DRAWWORKS
0.0 0.0
9/17/2022
14:30
9/17/2022
16:00
1.50 COMPZ1, WHDBOP WWSP P B/D & R/D FREEZE PRO. EQUIPMENT.
INSTALL BPV AND TREE CAP W/
GAUGE AS PER FMC
REP.
0.0 0.0
9/17/2022
16:00
9/17/2022
18:00
2.00 DEMOB, MOVE DMOB P PRESSURE WASH DERRICK
WINDWALLS, CONT. CLEANING PITS
WITH DEEP CLEAN PILL.
INSTALL IA FLANGE, AND RIG DOWN
OA MANIFOLD. HOUSEKEEPING IN
CELLAR.
0.0 0.0
9/17/2022
18:00
9/18/2022
00:00
6.00 DEMOB, MOVE DMOB P CON'T W/ CLEANING OF WIND
WALLS AND DERRICK, CON'T
FLUSHING LINES AND
CLEANING PITS, ASSIST MAG-TECH
WITH RIGGING DOWN, PREP 5"
DERRICK FINGERS FOR
INSPECTION
RIG RELEASED @ 0000 HRS
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 9/18/2022
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$ 2&7# & #) $ 4#$$ 2)7#4 2 & #& 2$7#&2)47#$ 2 24 #& "& 2)$7#" 4# $"2 ")# %@A)%;% ( *
$ 2 &4#& &&#$$ $ $#4 2)77#$ $4247 #7 2$ )#72)4&#) 2 2") #) "& 2)74#& $#& $"27)# %@A)%;% ( *
$ 27 7# &&#)$ $ $# & 2)7 #) $42$ $# 2)"&#$2)$$#" 2 2)4# "& 2"4# 4# $"2 $&#)& %@A)%;% ( *
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$ 2&7#7 & # 4 $ $# 7 2) $# $42"$7#4 2") # 2)$#4 2 24 # "& 2" #4 $# $"2 4)#& %@A)%;% ( *
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$724 "#" & #&$ $ #7 2) "#" $42  2) #72)$ # 2 72 $4#7 "& 2& #$ $# $24&&# ) %@A)%;% ( *
$72$ #) & #74 $&#$ 2) "#& $42 &#$ 2 #2)$ # 2 72&"4#" "& 2 " #7 4#7 $2$&$#74 %@A)%;% ( *
$72))# & #7 $&# 2) #7 $427" #$ 2 ) #2)$7# 2 72 &# "& 2 &#" 4#" $2) #7 %@A)%;% ( *
$72"" #" & # $&#)$ 2) # $42 $ # 2 #"2)$ # 2 72777# "& 27")# 4#" $2"7 # " %@A)%;% ( *
$72"$#4 & #) $&# & 2) 7#) $42 #& 27)#"2)$&#" 2 72 &7#" "& 27&4# 4#7 $27)#$) %@A)%;% ( *
$72 )7#4 & # & $ #7 2) 7# $42&&4# 27 #2)$ #4 2 72 4#& "& 2 ) # $# $2 7#4 %@A)%;% ( *
$727)$#4 & #77 $ #$" 2) # $42 7$#) 2 )#"2)$ # 2 72)"#) "& 2  $#& $27 # 4 %@A)%;% ( *
$72 $ # & #& $ 4#7 2) #& $$24)# 2 $# 2)$ # 2 72"4#& "& 2&)#4 $#7 $2 )#& %@A)%;% ( *
$72&$4#4 & #"4 $ 4#$" 2) &# $$2$) #$ 2&$))4#7 2 72) # "& 2&7 # 4#& $2&" # 4 %@A)%;% ( *
$72 4"# & # & $ 4# 2)&4# $$2)47#" 2&7#72)))#& 2 72$ 7#4 "& 2 $#" $# $2 ) # %@A)%;% ( *
$72  &7# $ $ 4#7 2)&# $$2)& #$ 2 $$#"2)) #4 2 724 )# "& 2 #7 $#$ $ 24)4# %@A)%;% ( *
$ 24 )# &# $ $# 2) $# $$2" $#" 2 7#"2)"#4 2 7244 # "&&244"#" )#& $ 2$$)# 7 %@A)%;% ( *
$ 2$& #" &# $ )#&& 2"44# $$2 # $42444#42)"#4 2 2 ) #) "&&24 #7 $#4 $ 2)4# %@A)%;% ( *
$ 2)&$#4 &)# $ )# & 2"$$# $$2 " #& $424)#2) "#7 2 2&$#7 "&&24&7#7 )#) $ 2) #$ %@A)%;% ( *
$ 2" # &)# $ $ 4# 2")"# $$27)4# $424&7# 2)77#4 2 2  "&&2$) #& )#7 $ 2"& #$" %@A)%;% ( *
$ 27 # &)# " $ #$) 2"" # $$2 4$#$ $42$""#72)  2 27 7# "&&2$ #) $# $ 2  %@A)%;% ( *
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$ 27 #7 & # $ #$ 2" "#$ $$2&7"#) $42)"$#42) #) 2 2 $"#" "&&2)7 # "#$ $ 277 #$& %@A)%;% ( *
$ 2 #$ &J $&# ) 2" 7#" $$2 #) $42) #72) &# 2 2"$# "&&2"$ #) $#) $ 2 &#") %@A)%;% ( *
$ 2&&# & #&" $ #) 2" #7 $)24)#) $42") #2) # 2 2" 4# "&&2"7 # )#) $ 2& $# %@A)%;% ( *
$ 2 )#$ & # & $ #& 2" &#$ $)2$4"#) $42" # 2"44#) 2 2) 4# "&&2$#7 4# $ 2 #" %@A)%;% ( *
$&24"7# 4#4 $ #&7 2" &#$ $)2$&"# $42"4#$2"44#) 2 2$& #& "&&27"#& 4# $724"&#$& %@A)%;% ( *
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$&2" 4#4 4# $&#& 2" #4 $)2 4#4 $42 # 2) #$ 2 2 )4# "&&27)"#& 4#4 $72" #7 1D+,+
,
Page 1/1
CD4-597
Report Printed: 9/26/2022
Cement
Cement Details
Description
Conductor String Cement
Cementing Start Date
2/4/2022 22:00
Cementing End Date
2/4/2022 04:30
Wellbore Name
CD4-597
Comment
Cement Stages
Stage # 1
Description
Conductor String Cement
Objective Top Depth (ftKB)
39.1
Bottom Depth (ftKB)
120.0
Full Return?
No
Vol Cement …Top Plug?
No
Btm Plug?
No
Q Pump Init (bbl/m… Q Pump Final (bbl/… Q Pump Avg (bbl/…P Pump Final (psi) P Plug Bump (psi) Recip?
No
Stroke (ft) Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
Cement Fluids & Additives
Fluid
Fluid Type
Primary Cement
Fluid Description Estimated Top (ftKB)
39.1
Est Btm (ftKB)
120.0
Amount (sacks) Class Volume Pumped (bbl)
48.1
Yield (ft³/sack)
1.16
Mix H20 Ratio (gal/sack) Free Water (%) Density (lb/gal)
16.00
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Conductor String Cement
Page 1/1
CD4-597
Report Printed: 9/26/2022
Cement
Cement Details
Description
Surface String Cement
Cementing Start Date
8/5/2022 02:45
Cementing End Date
8/5/2022 07:30
Wellbore Name
CD4-597
Comment
CEMENTERS PUMP 99.5 BBLS 10.7# MUD PUSH II, DROP BOTTOM PLUG. PUMP 447 BBLS
11# LEAD CEMENT FOLLOWED BY 73 BBLS 15.8# TAIL CEMENT, DROP TOP PLUG. PUMP 10
BBLS FRESH WATER. SWAP OVER TO RIG PUMP AND CHASE PLUG @ 7 BPM, 515 PSI, 54%
F/O. @ 3100 STKS AWAY SLOW PUMPS T/ 3 BPM, 386 PSI, 45% F/O. BUMP PLUG @ 3232
STKS. HOLD 890 PSI FOR 5 MIN, BLEED OFF AND CHECK FLOATS (GOOD). CIP @ 07:30, 201
BBLS CEMENT TO SURFACE
Cement Stages
Stage # 1
Description
Surface String Cement
Objective Top Depth (ftKB)
39.1
Bottom Depth (ftKB)
2,716.4
Full Return?
Yes
Vol Cement …
201.0
Top Plug?
Yes
Btm Plug?
No
Q Pump Init (bbl/m…
341
Q Pump Final (bbl/…
386
Q Pump Avg (bbl/…
5
P Pump Final (psi)
386.0
P Plug Bump (psi)
890.0
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
R/U cementers and PJSM on cement job. SLB pump 5 bbls H2O and PT lines 3,500 psi. (good). Pump 100 bbls 10.7 ppg mud push II. Shut down and drop
bottom plug. Pump 447 bbls 11 ppg 1266 stks 1.91 yield lead cement, Followed by 73 bbl 15.8 ppg 330 stks 1.16 yield tail cement,pump 20 bbls freshwater,
shut down drop top plug, displace with rig pumps 331 bbls @ 5bpm 342 psi Full returns all job. bump plug 500psi over circ rate held for 5 min. bleed off check
floats floats held CIP 07:30 hrs (201 bbls cement to surface)
Cement Fluids & Additives
Fluid
Fluid Type
Lead Cement
Fluid Description Estimated Top (ftKB)
39.1
Est Btm (ftKB)
2,221.0
Amount (sacks)
1,314
Class
Blend
Volume Pumped (bbl)
447.0
Yield (ft³/sack)
1.91
Mix H20 Ratio (gal/sack)
6.67
Free Water (%) Density (lb/gal)
11.00
Plastic Viscosity (cP)
218.0
Thickening Time (hr)
6.00
CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Fluid
Fluid Type
Tail Cement
Fluid Description Estimated Top (ftKB)
2,221.0
Est Btm (ftKB)
2,716.4
Amount (sacks)
350
Class
G
Volume Pumped (bbl)
73.0
Yield (ft³/sack)
1.17
Mix H20 Ratio (gal/sack)
5.03
Free Water (%) Density (lb/gal)
15.80
Plastic Viscosity (cP)
151.0
Thickening Time (hr)
5.01
CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Surface String Cement
Page 1/1
CD4-597
Report Printed: 9/26/2022
Cement
Cement Details
Description
Cement Squeeze
Cementing Start Date
8/9/2022 17:00
Cementing End Date
8/9/2022 22:30
Wellbore Name
CD4-597
Comment
HOLD PJSM, CEMENTERS PUMP 25.7 BBLS 12.5 PPG MUDPUSH II, FOLLOWED BY 52.5 BBLS
15.6 PPG TAIL CEMENT, FOLLOWED BY 4.5 BBLS 12.5 MUDPUSH II. SWAP OVER TO RIG
PUMP AND CHASE W/ 11.0 PPG LSND @ 6 BPM, 68 PSI, 31% F/O, 20 RPM, 2.4K TQ. @ 318
STKS AWAY SLOW PUMPS TO 3 BPM, 26 PSI, 30% F/O, 20 RPM, 2.4K TQ. PUMPS OFF @ 361
STKS AWAY.
PERFORM CEMENT SQUEEZE. SHUT IN UPPER PIPE RAMS, PRESSURE UP TO 200 PSI,
AFTER 2 HOURS OBSERVE BLEED OFF TO 116 PSI. BLEED OFF ALL PRESSURE AND LEAVE
WELL SHUT IN.
PUMPED 11 STKS (1.3 BBLS), BLED 1 BBL BACK TO MUD PITS
Cement Stages
Stage # 1
Description
Squeeze – Formation
Squeeze
Objective Top Depth (ftKB)
2,406.0
Bottom Depth (ftKB)
2,741.0
Full Return?
No
Vol Cement …
0.0
Top Plug?
No
Btm Plug?
No
Q Pump Init (bbl/m…
231
Q Pump Final (bbl/…
231
Q Pump Avg (bbl/…P Pump Final (psi) P Plug Bump (psi) Recip?
No
Stroke (ft) Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB)
2,390.0
Tag Method
Drill Bit
Depth Plug Drilled Out To (ftKB)
2,741.0
Drill Out Diameter (in)
12 1/4
Comment
HOLD PJSM, CEMENTERS PUMP 25.7 BBLS 12.5 PPG MUDPUSH II, FOLLOWED BY 52.5 BBLS
15.6 PPG TAIL CEMENT, FOLLOWED BY 4.5 BBLS 12.5 MUDPUSH II. SWAP OVER TO RIG
PUMP AND CHASE W/ 11.0 PPG LSND @ 6 BPM, 68 PSI, 31% F/O, 20 RPM, 2.4K TQ. @ 318
STKS AWAY SLOW PUMPS TO 3 BPM, 26 PSI, 30% F/O, 20 RPM, 2.4K TQ. PUMPS OFF @ 361
STKS AWAY.
PERFORM CEMENT SQUEEZE. SHUT IN UPPER PIPE RAMS, PRESSURE UP TO 200 PSI,
AFTER 2 HOURS OBSERVE BLEED OFF TO 116 PSI. BLEED OFF ALL PRESSURE AND LEAVE
WELL SHUT IN.
PUMPED 11 STKS (1.3 BBLS), BLED 1 BBL BACK TO MUD PITS
Cement Fluids & Additives
Fluid
Fluid Type
Tail Cement
Fluid Description Estimated Top (ftKB)
2,406.0
Est Btm (ftKB)
2,741.0
Amount (sacks)
246
Class
G
Volume Pumped (bbl)
52.5
Yield (ft³/sack)
1.20
Mix H20 Ratio (gal/sack)
5.11
Free Water (%) Density (lb/gal)
15.60
Plastic Viscosity (cP)
57.0
Thickening Time (hr)
5.00
CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Cement Squeeze
Page 1/1
CD4-597
Report Printed: 9/26/2022
Cement
Cement Details
Description
Intermediate String 1 Cement
Cementing Start Date
8/19/2022 06:00
Cementing End Date
8/19/2022 09:45
Wellbore Name
CD4-597
Comment
HOLD PJSM, CEMENTERS PUMP 63 BBLS 13 PPG MUDPUSH II, DROP BTM PLUG. CHASE WITH 141 BBLS 15.8 PPG CEMENT. DROP TOP PLUG. KICK
OUT WITH 20 BBLS WATER. SWAP TO RIG PUMPS. DISPLACE W/ TREATED LSND 11.0 PPG. BUMP PLUG AT 5097 STKS. PRESSURE UP 500 PSI
OVER FCP(900PSI) HOLD FOR 5 MIN. BLEED OFF TO CHECK FLOATS (GOOD). CIP @ 09:45.
Cement Stages
Stage # 1
Description
Intermediate String 1
Cement
Objective Top Depth (ftKB)
6,610.0
Bottom Depth (ftKB)
8,324.0
Full Return?
Yes
Vol Cement …
0.0
Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
4
Q Pump Final (bbl/…
3
Q Pump Avg (bbl/…
6
P Pump Final (psi)
450.0
P Plug Bump (psi)
380.0
Recip?
Yes
Stroke (ft)
20.00
Rotated?
Yes
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
HOLD PJSM, CEMENTERS PUMP 63 BBLS 13 PPG MUDPUSH II, DROP BTM PLUG. CHASE WITH 141 BBLS 15.8 PPG CEMENT. DROP TOP PLUG. KICK
OUT WITH 20 BBLS WATER. SWAP TO RIG PUMPS. DISPLACE W/ TREATED LSND 11.0 PPG. BUMP PLUG AT 5097 STKS. PRESSURE UP 500 PSI
OVER FCP(900PSI) HOLD FOR 5 MIN. BLEED OFF TO CHECK FLOATS (GOOD). CIP @ 09:45.
Cement Fluids & Additives
Fluid
Fluid Type
Intermediate Cement
Fluid Description Estimated Top (ftKB)
6,610.0
Est Btm (ftKB)
8,324.0
Amount (sacks)
685
Class
G
Volume Pumped (bbl)
141.0
Yield (ft³/sack)
1.17
Mix H20 Ratio (gal/sack)
5.07
Free Water (%) Density (lb/gal)
15.80
Plastic Viscosity (cP)
104.0
Thickening Time (hr)
8.00
CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Intermediate String 1 Cement
Page 1/1
CD4-597
Report Printed: 9/26/2022
Cement
Cement Details
Description
Intermediate String 2 Cement
Cementing Start Date
8/31/2022 12:00
Cementing End Date
8/31/2022 14:00
Wellbore Name
CD4-597
Comment
PJSM WITH ALL HANDS ON CEMENT JOB. PT SURFACE LINES T/ 4500 PSI, CHARTED. PUMP
40 BBL OF MUD PUSH @ 5 BPM, 339 PSI, 36% F/O 20 RPM, 10K TQ.
DROP BTM PLUG AND CHASE WITH 87.1 BBL OF 13PPG LEAD CEMENT @ 5 BPM, 327 PSI,
34% 20RPM, 10K TQ. PUMP 22 BBL OF 15.8 PPG TAIL CEMENT @ 4 BPM, 105 PSI, 33% F/O
11K TQ @ 20 RPM. DROP BTM PLUG AND CHASE WITH 20 BBL OF H20 VIA CEMENTERS.
CHASE WITH RIG PUMPS @ 5 BPM 270 PSI, 35% F/O CATCH PRESSURE @ 65 STKS. FIRST
PLUG LANDED @ 1309 STKS. STAGE UP T/ 6 BPM, 938 PSI, 34% F/O 20 RPM, 17K MAX TQ
SEEN. SLOW DOWN TO 3BPM 577 PSI, 32% F/O, 0 RPM, 2ND PLUG LAND @ 3191 STKS.
PRESSURE UP 500 OVER T/ 1100 PSI. HOLD F/ 5 MIN. BLEED OFF AND CHECK FLOATS.
FLOATS HELD
Cement Stages
Stage # 1
Description
Intermediate String 2
Cement
Objective Top Depth (ftKB)
9,475.0
Bottom Depth (ftKB)
12,476.0
Full Return?
Yes
Vol Cement …
0.0
Top Plug?
No
Btm Plug?
No
Q Pump Init (bbl/m…
5
Q Pump Final (bbl/…
4
Q Pump Avg (bbl/…
5
P Pump Final (psi)
600.0
P Plug Bump (psi)
1,100.0
Recip?
No
Stroke (ft) Rotated?
Yes
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method
Pipe/String
Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
PJSM WITH ALL HANDS ON CEMENT JOB. PT SURFACE LINES T/ 4500 PSI, CHARTED. PUMP
40 BBL OF MUD PUSH @ 5 BPM, 339 PSI, 36% F/O 20 RPM, 10K TQ.
DROP BTM PLUG AND CHASE WITH 87.1 BBL OF 13PPG LEAD CEMENT @ 5 BPM, 327 PSI,
34% 20RPM, 10K TQ. PUMP 22 BBL OF 15.8 PPG TAIL CEMENT @ 4 BPM, 105 PSI, 33% F/O
11K TQ @ 20 RPM. DROP BTM PLUG AND CHASE WITH 20 BBL OF H20 VIA CEMENTERS.
CHASE WITH RIG PUMPS @ 5 BPM 270 PSI, 35% F/O CATCH PRESSURE @ 65 STKS. FIRST
PLUG LANDED @ 1309 STKS. STAGE UP T/ 6 BPM, 938 PSI, 34% F/O 20 RPM, 17K MAX TQ
SEEN. SLOW DOWN TO 3BPM 577 PSI, 32% F/O, 0 RPM, 2ND PLUG LAND @ 3191 STKS.
PRESSURE UP 500 OVER T/ 1100 PSI. HOLD F/ 5 MIN. BLEED OFF AND CHECK FLOATS.
FLOATS HELD
Cement Fluids & Additives
Fluid
Fluid Type
Lead Cement
Fluid Description Estimated Top (ftKB)
9,475.0
Est Btm (ftKB)
11,976.0
Amount (sacks)
257
Class
G
Volume Pumped (bbl)
87.0
Yield (ft³/sack)
1.89
Mix H20 Ratio (gal/sack)
10.30
Free Water (%) Density (lb/gal)
13.00
Plastic Viscosity (cP) Thickening Time (hr)
15.00
CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Fluid
Fluid Type
Tail Cement
Fluid Description Estimated Top (ftKB)
11,976.0
Est Btm (ftKB)
12,476.0
Amount (sacks)
106
Class
G
Volume Pumped (bbl)
22.0
Yield (ft³/sack)
1.17
Mix H20 Ratio (gal/sack)
5.08
Free Water (%) Density (lb/gal)
15.80
Plastic Viscosity (cP) Thickening Time (hr)
7.50
CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Intermediate String 2 Cement
TO: AOGCC
333 WEST 7T" SUITE 100
ANCH. AK. 99501
279-1433
OPERATOR: CPAI
SAMPLE TYPE: Dry Cuttings
SAMPL S SENT:
) CD4-597
�34 -3 5 - 18350
5 Boxes
SENT BY: M. McCRACKEN
SAMPLE TRANSMITTAL
3 y 50 - � (2) 3�;-0 ov��
,?;,-) - 0 19
DATE: September 29, 2022
AIR BILL: N/A
CPAL 2022092901
CHARGE CODE: N/A
NAME: CD4-597
NUMBER OF BOXES: 5 Box
UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND RETURN A SIGNED COPY
OF THIS FORM TO:
RECEIVE
CONOCOPHILLIPS, ALASKA
700 G ST
ATO-380
ANCHORAGE, AK. 99510
ATTN: MIKE McCRACKEN
Mike.mccracken@conocophillips.com
L i3OPP�'q(—etIZZ
RECEIVE®
AOGCC
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STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
SSu bm it t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner: Rig No.:142 DATE: 9/2/22
Rig Rep.: Rig Email:
Operator:
Operator Rep.: Op. Rep Email:
Well Name:PTD #2220190 Sundry #
Operation: Drilling: X Workover: Explor.:
Test: Initial: Weekly: Bi-Weekly: X Other:
Rams:250 / 3500 Annular:250 / 3500 Valves:250 / 3500 MASP:1449
MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 1P
Permit On Location P Hazard Sec.P Lower Kelly 1P
Standing Order Posted P Misc.NA Ball Type 4P
Test Fluid Water Inside BOP 2P
FSV Misc 0NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0NATrip Tank PP
Annular Preventer 1 13 5/8 5M P Pit Level Indicators PP
#1 Rams 1 3.5"x6"P Flow Indicator PP
#2 Rams 1 Blind/Shear P Meth Gas Detector PP
#3 Rams 1 3.5"x6"P H2S Gas Detector PP
#4 Rams 0NAMS Misc 0NA
#5 Rams 0NA
#6 Rams 0NAACCUMULATOR SYSTEM:
Choke Ln. Valves 1 3 1/8" 5M P Time/Pressure Test Result
HCR Valves 2 3 1/8" 5M P System Pressure (psi)3000 P
Kill Line Valves 3 3 1/8" 5M P Pressure After Closure (psi)1800 P
Check Valve 0NA200 psi Attained (sec)7 P
BOP Misc 0NAFull Pressure Attained (sec)57 P
Blind Switch Covers: All stations Yes
CHOKE MANIFOLD:Bottle Precharge:P
Quantity Test Result Nitgn. Bottles # & psi (Avg.): 6@2000 P
No. Valves 14 P ACC Misc 0NA
Manual Chokes 1P
Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result
CH Misc 0NA Annular Preventer 12 P
#1 Rams 6 P
Coiled Tubing Only:#2 Rams 6 P
Inside Reel valves 0NA #3 Rams 6 P
#4 Rams 0 NA
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:0 Test Time:4.0 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 8/31/22@ 6:40
Waived By
Test Start Date/Time:9/2/2022 1:00
(date) (time)Witness
Test Finish Date/Time:9/2/2022 5:00
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Kam StJohn
Doyon
Test Annular & rams #1 & #3 with both a 4" and 5" test jt, All tests 250psi-lo/3500psi-Hi 5min ea. On chart. Test 2ea 4" FOSV &
dart, Test 2ea. 5" FOSV & dart. Test all H2S, gas, flow & PVT alarms, both audible & visual, Rams functioned from both primary
and remote controls. Drawdown conducted w/ 2 air & 2 elec pumps, All tests good, no failures. Test waived by AOGCC Kam P
StJohn.
F. Carlo / A. Allen
CPAI
A. Dorr / M. Aurthur
CRU CD4-597
Test Pressure (psi):
rig142@doyondrilling.com
d142cm@conocophillips.com
Form 10-424 (Revised 08/2022) 2022-0902_BOP_Doyon142_CRU_CD4-597
9
9
9 9
9
9 9
9
9
9
9
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WŚŽŶĞ͗ϵϬϳͲϳϵϯͲϭϮϰϮ
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.
&ƌŽŵ͗ZŝŐϭϰϮфƌŝŐϭϰϮΛĚŽLJŽŶĚƌŝůůŝŶŐ͘ĐŽŵх
^ĞŶƚ͗dƵĞƐĚĂLJ͕ƵŐƵƐƚϯϬ͕ϮϬϮϮϱ͗ϭϲWD
dŽ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх͖KK'WƌƵĚŚŽĞĂLJфĚŽĂ͘ĂŽŐĐĐ͘ƉƌƵĚŚŽĞ͘ďĂLJΛĂůĂƐŬĂ͘ŐŽǀх͖
ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх
^ƵďũĞĐƚ͗ůĂƚĞƚĞƐƚƌĞƉŽƌƚ
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MATTHEW SAM
Rig 142 Toolpusher
Rig142@doyondrilling.com
Doyon Rig 142 907-670-6002
Cell, 907-322-3715
&$87,21 7KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ
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&58&'
37'
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
SSu bm itt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner: Rig No.:142 DATE: 8/20/22
Rig Rep.: Rig Email:
Operator:
Operator Rep.: Op. Rep Email:
Well Name:PTD #2220190 Sundry #
Operation: Drilling: X Workover: Explor.:
Test: Initial: Weekly: Bi-Weekly: X Other:
Rams:250/3500 Annular:250/2500 Valves:250/3500 MASP:1449
MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 1P
Permit On Location P Hazard Sec.P Lower Kelly 1FP
Standing Order Posted P Misc.NA Ball Type 4P
Test Fluid Water Inside BOP 2P
FSV Misc 0NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0NATrip Tank PP
Annular Preventer 1 13-5/8" 5M P Pit Level Indicators PP
#1 Rams 1 3.5" x 6"P Flow Indicator PP
#2 Rams 1 Blind/Shear P Meth Gas Detector PP
#3 Rams 1 3.5" x 6"P H2S Gas Detector PP
#4 Rams 0NAMS Misc 0NA
#5 Rams 0NA
#6 Rams 0NAACCUMULATOR SYSTEM:
Choke Ln. Valves 1 3-1/8" 5M P Time/Pressure Test Result
HCR Valves 2 3-1/8" 5M P System Pressure (psi)3000 P
Kill Line Valves 1 3-1/8" 5M P Pressure After Closure (psi)1800 P
Check Valve 0NA200 psi Attained (sec)10 P
BOP Misc 0NAFull Pressure Attained (sec)52 P
Blind Switch Covers: All stations Yes
CHOKE MANIFOLD:Bottle Precharge:P
Quantity Test Result Nitgn. Bottles # & psi (Avg.): #6@1990 P
No. Valves 14 P ACC Misc 0NA
Manual Chokes 1P
Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result
CH Misc 0NA Annular Preventer 28 P
#1 Rams 9 P
Coiled Tubing Only:#2 Rams 6 P
Inside Reel valves 0NA #3 Rams 7 P
#4 Rams 0 NA
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:1 Test Time:11.5 HCR Choke 2 P
Repair or replacement of equipment will be made within days. HCR Kill 2 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 8/19/22 06:49AM
Waived By
Test Start Date/Time:8/20/2022 2:00
(date) (time)Witness
Test Finish Date/Time:8/20/2022 13:30
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Guy Cook
Doyon
Test Annular to 2500psi w/ 4", 5" Test jt's. Test Rams #1 & #3 w/ both 4" & 5" Test jts, test 2ea 4"& 5" FOSV & 1ea 4"& 5" Dart.
All test 250psi-lo, 3500psi-Hi 5min ea on chart. Test all H2S, gas, pvt and flow alarms, both audible & visual. All rams functioned
from both the primary and remote controls. Drawdown conducted w/ 2ea Air, and 2ea Electric pumps. Failure= Lower IBOP,
changed out tested. Bottle Precharge - 1000 psi.
M.Sam / H. Huntington
CPAI
A. Dorr / B. Marmon
CRU CD4-597
Test Pressure (psi):
d142cm@conocophillips.com
rig142@doyondrilling.com
Form 10-424 (Revised 08/2022) 2022-0820_BOP_Doyon142_CRU_CD4-597
9
9
9
9
9 9 9 9
9
9
9 9
9
9
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FP
Failure= Lower IBOP,
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________COLVILLE RIV UNIT CD4-597
JBR 09/02/2022
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:4
Rig down 3 months. 5-7/8" joint. New Annular to 5k. Op went to 5k on all components. Annular/TPR flange FP-new ring for
pass. Choke hose flange FP-replace gasket for pass. TPR FP-re dress bodies for pass. TPR door seal FP-inspect/tighten for
pass. Annular 10 secs; Rams 7 secs; HCRs 2 secs. Poor test.
Test Results
TEST DATA
Rig Rep:Carlo/AllenOperator:ConocoPhillips Alaska, Inc.Operator Rep:Tucker/Arthur
Rig Owner/Rig No.:Doyon 142 PTD#:2220190 DATE:8/7/2022
Type Operation:DRILL Annular:
250/5000Type Test:INIT
Valves:
250/5000
Rams:
250/5000
Test Pressures:Inspection No:bopSAM220808200611
Inspector Austin McLeod
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 23
MASP:
1449
Sundry No:
CLOSURE TIME (sec)
Time/Pressure P/F
Location Gen.:P
Housekeeping:P
PTD On Location P
Standing Order Posted P
Well Sign P
Drl. Rig P
Hazard Sec.P
Misc NA
Upper Kelly 1 P
Lower Kelly 1 P
Ball Type 2 P
Inside BOP 1 P
FSV Misc 0 NA
14 PNo. Valves
1 PManual Chokes
1 PHydraulic Chokes
1 FPCH Misc
Stripper 0 NA
Annular Preventer 1 13-5/8"P
#1 Rams 1 3.5"x6"FP
#2 Rams 1 Blind/Shear P
#3 Rams 1 3.5"x6"P
#4 Rams 0 NA
#5 Rams 0 NA
#6 Rams 0 NA
Choke Ln. Valves 1 3-1/8"P
HCR Valves 2 3-1/8"P
Kill Line Valves 3 3-1/8"P
Check Valve 0 NA
BOP Misc 2 Door/Flange FP
System Pressure P3025
Pressure After Closure P1800
200 PSI Attained P8
Full Pressure Attained P59
Blind Switch Covers:PAll stations
Nitgn Btls# &psi (avg)P6@2000
ACC Misc NA0
P PTrip Tank
P PPit Level Indicators
P PFlow Indicator
P PMeth Gas Detector
P PH2S Gas Detector
NA NAMS Misc
Inside Reel Valves 0 NA
9
9
9
9 9 9 9
9
9
9
9
9
FP3.5"x6"
Door/Flange FP
FP
Rig down 3 months.Annular/TPR flange FP-new ring for
pass. Choke hose flange FP-TPR FP-re dress TPR door seal FP-
Annular 10 secs; Rams 7 secs; HCRs 2 secs.
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Chris Brillon
Engineering Manager
ConocoPhillips Alaska, Inc.
PO Box 100360
Anchorage, AK 99510-0360
Re: Colville River Field, Narwhal Undefined Pool, CRU CD4-597
ConocoPhillips Alaska, Inc.
Permit to Drill Number: 222-019
Surface Location: 2868’ FNL, 12’ FEL, Sec 24, T11N, R4E
Bottomhole Location: 4729’ FNL, 5023’ FEL, Sec 33, T11N, R5E
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 well logs
run must be submitted to the AOGCCwithin 90 days after completion, suspension or abandonment
of this well.
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,
Jeremy M. Price
Chair
DATED this ___ day of April, 2022.
Jeremy Price
Digitally signed by Jeremy
Price
Date: 2022.04.04 11:36:27
-08'00'
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dts 4/4/2022
JLC 4/4/2022
4/4/22
Jeremy Price Digitally signed by Jeremy Price
Date: 2022.04.04 11:36:47 -08'00'
CRU CD4-597 (PTD 222-019)
Conditions of Approval:
Approval is granted to run the LWD-Sonic on upcoming well with the following provisions:
1. CPAI will provide a written log evaluation/interpretation to the AOGCC along with the log as
soon as they become available. The evaluation is to include/highlight the intervals of competent
cement that CPAI is using to meet the objective requirements for annular isolation, reservoir
isolation, or confining zone isolation etc. Providing the log without an evaluation/interpretation
is not acceptable.
2. LWD sonic logs must show free pipe and Top of Cement, just as the e-line log does. CPAI must
start the log at a depth to ensure the free pipe above the TOC is captured as well as the TOC.
Starting the log below the actual TOC based on calculations predicting a different TOC will not
be acceptable.
3. CPAI will provide a cement job summary report and evaluation along with the cement log and
evaluation to the AOGCC when they become available
4. CPAI will provide the results of the FIT when available.
5. Depending on the cement job results indicated by the cement job report, the logs and the FIT,
remedial measures or additional logging may be required.
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
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Digitally signed by
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Date: 2022.01.25
13:00:50 -09'00'
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Page 1 of 7
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Application for Permit to Drill Document
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Requirements of 20 AAC 25.005 (f) ............................................................................................................. 2
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Requirements of 20 AAC 25.005(c)(2) ......................................................................................................... 2
Requirements of 20 AAC 25.050(b) ............................................................................................................. 2
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Requirements of 20 AAC 25.005(c)(3) ......................................................................................................... 3
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Page 2 of 7
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Attachment 1: Location Maps ..................................................................................................................... 7
Attachment 2: Directional Plan ................................................................................................................... 7
Attachment 3: Drilling Hazards Summary .................................................................................................... 7
Attachment 4: Cement Summary ................................................................................................................. 7
Attachment 5: Well Schematic .................................................................................................................... 7
Attachment 6: Wellhead Schematic ............................................................ Error! Bookmark not defined.
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Requirements of 20 AAC 25.005 (f)
Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC
25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix
to the name designated for the well by the operator and to the number assigned to the well by the commission.
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Requirements of 20 AAC 25.005(c)(2)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission
and identified in the application:
(2) a plat identifying the property and the property's owners and showing
(A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to
governmental section lines.
(B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained
by the National Geodetic Survey in the National Oceanic and Atmospheric Administration;
(C) the proposed depth of the well at the top of each objective formation and at total depth: and (D) other information required by 20 AAC
25.050(b);
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Requirements of 20 AAC 25.050(b)
If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must
(1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any
portion of the proposed well;
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Page 3 of 7
and
(2) for all wells within 200 feet of the proposed wellbore
(A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that
each named operator has been furnished a copy of the application by certified mail; or
(B) state that the applicant is the only affected owner.
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Requirements of 20 AAC 25.005(c)(3)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission
and identified in the application:
(3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037,
as applicable;
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Requirements of 20 AAC 25.005 (c)(4)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission
and identified in the application:
(4) information on drilling hazards, including
(A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on
a methane gradient;
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(B) data on potential gas zones;
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and
(C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a
propensity for differential sticking;
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Requirements of 20 AAC 25.005 (c)(5)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission
and identified in the application:
(5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f);
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Requirements of 20 AAC 25.005(c)(6)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission
and identified in the application:
(6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre-perforated
liner, or screen to be installed;
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Requirements of 20 AAC 25.005(c)(7)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission
and identified in the application:
(7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under
20 AAC 25.035(h)(2);
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Requirements of 20 AAC 25.005(c)(8)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission
and identified in the application:
(8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033;
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Density (ppg) 11.0
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Requirements of 20 AAC 25.005 (c)(9)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission
and identified in the application:
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Requirements of 20 AAC 25.005 (c)(10)
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Requirements of 20 AAC 25.005 (c)(11)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission
and identified in the application:
(11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed
conditions as required by 20 AAC 25.061(b);
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Requirements of 20 AAC 25.005 (c)(12)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission
and identified in the application:
(12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met;
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Requirements of 20 AAC 25.005 (c)(13)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission
and identified in the application:
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Intermediate II ¶±¶
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Density (ppg) 9.2
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API Fluid Loss (ml/30min) <10
pH 9.5-10.0
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Requirements of 20 AAC 25.005 (c)(14)
An application for a Permit to Drill mustc be accompanied by each of the following items, except for an item already on file with the commission
and identified in the application:
(14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to
request authorization under 20 AAC 25.080 for an annular disposal operation in the well.;
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Attachment 1: Location Maps
Attachment 2: Directional Plan
Attachment 3: Drilling Hazards Summary
Attachment 4: Cement Summary
Attachment 5: Well Schematic
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t >>͗^ d/KE͗ džĐĞƐƐďĞůŽǁWĞƌŵĂĨƌŽƐƚ͗ϭ͘ϱϱϬйϭϯͲϯͬϴΗ^hZ&х džĐĞƐƐŝŶWĞƌŵĂĨƌŽƐƚ͗ϯ͘ϱϮϱϬй>ĞĂĚĐĞŵĞŶƚLJŝĞůĚϭ͘ϵϮĨƚΔϯͬƐŬϭ͘ϭϲ ĨƚΔϯͬƐŬ ϭ͘ϵϮ ĨƚΔϯͬƐŬdĂŝůĐĞŵĞŶƚLJŝĞůĚϭ͘ϭϲĨƚΔϯͬƐŬϭϬϱ Ĩƚϭϵ͘ϲ ďďůƐϯϬϮ͘Ϭ ďďůƐϭϭϬ͘Ϭ ďďůƐϰϯϭ͘ϲďďůƐŽƌϮϰϮϯ͘ϭĨƚΔϯŽƌϭϮϲϮƐŬƐϬ͘ϭϴϲϮ >ͬ&dϬ͘Ϭϳϰϵ>ͬ&dϭϮ͘ϬďďůƐϱϲ͘Ϯ ďďůƐϬ͘ϭϰϵϳ>ͬ&dϲϴ͘ϮďďůƐŽƌϯϴϮ͘ϳĨƚΔϯŽƌϯϯϬƐŬƐϭϮϱϳ Ĩƚϯϵϳ͘ϳďďůƐϭϬϱ &dϮϲϱϲ&dϮϳϯϲ&dϱϬϬ&dϭϮϱϳ &dϮϮϯϲ&dϮϮϯϲĨƚϴϬ&dyϬ͘ϭϰϵϳ>ͬ&dсϭϮ͘Ϭ>^ϱϬϬ&dyϬ͘Ϭϳϰϵ>ͬ&dсϯϳ͘ϱ>^ϯϳ͘ϱ>^yϭ͘ϱϱϬйϱϲ͘Ϯ>^ϲϴ͘Ϯ >^ϭϬ͘ϬďďůƐϮϲϱϲ ĨƚϭϮďďůƐϮϳϯϲ Ĩƚϵϳϵ&dyϬ͘Ϭϳϰϵ>ͬ&dсϳϯ͘ϯ>^ϳϯ͘ϯ>^yϭ͘ϱϱϬйϭϭϬ͘Ϭ>^ϭϭϱϮ&dyϬ͘Ϭϳϰϵ>ͬ&dсϴϲ͘ϯ>^ϴϲ͘ϯ>^yϯ͘ϱϮϱϬйϯϬϮ͘Ϭ>^ϭϬϱ&dyϬ͘ϭϴϲϮ>ͬ&dсϭϵ͘ϲ>^ϰϯϭ͘ϲ>^Ϯϲϱϲ&dyϬ͘ϭϰϵϳ>ͬ&dсϯϵϳ͘ϳ>^ϯϵϳ͘ϳ>^ŝƐƉůĂĐĞŵĞŶƚс;ϮϳϯϲΖͲϴϬΖͿdžϬ͘ϭϰϵϳďďůͬĨƚсdŽƚĂůdĂŝůĞŵĞŶƚсϯϴϳ͘ϳdĂŝůĞŵĞŶƚLJŝĞůĚсKEhdKZс^ŚŽĞƚŽdŽƉŽĨdĂŝůс ;ϮϳϯϲΖͲϮϮϯϲΖͿdžϬ͘ϬϳϰϵďďůͬĨƚdžϭ͘ϱ;ϱϬйĞdžĐĞƐƐͿdŽƚĂů>ĞĂĚĞŵĞŶƚсϭϬϱΖdžϬ͘ϭϴϲϮďďůͬĨƚdžϭ͘Ϭ;ϬйĞdžĐĞƐƐͿĂƐĞŽĨWĞƌŵĂĨƌŽƐƚƚŽKEс ;ϭϮϱϳΖͲϭϬϱΖͿdžϬ͘ϬϳϰϵďďůͬĨƚdžϯ͘ϱ;ϮϱϬйĞdžĐĞƐƐͿWƌĞǀŝŽƵƐƐŚŽĞфϭϲΗK,ĂƐĞŽĨWĞƌŵĂĨƌŽƐƚфϭϲΗKEdŽdŽƉŽĨ&ůŽĂƚŽůůĂƌϭϲΗK,džϭϯ͘ϯϳϱΗ^'ͲĞůŽǁWĞƌŵĂĨƌŽƐƚϭϲΗK,džϭϯ͘ϯϳϱΗ^'^,K dZ<> D EdϮϬΗKEdžϭϯ͘ϯϳϱΗ^'/^W> D EddKd>sK>hD Ͳd/>DddKd>sK>hD Ͳ> DdďďůƐ
sK>hD ^ϭϲΗK,džϭϯ͘ϯϳϱΗ^'Ͳ/ŶWĞƌŵĂĨƌŽƐƚd/> D EdϮϱϬйK, y ^^/Ed ZE>^ĞƚĚĞƉƚŚĞƐƚdŽƉŽĨdĂŝůdKd>sK>hD ϱϬйK, y ^^WZ s/Kh^^,K dKWK&&>KdK>>Z^ d Wd,> E'd,K&d/>> E'd,K&> ^ K&W ZD&ZK^ddŽƉŽĨ&ϰͲϱϵϳϭϯͲϯͬϴΗ^hZ& ϭϭ͘ϬƉƉŐĞĞƉZ d >ĞĂĚ^ůƵƌƌLJϭϱ͘ϴƉƉŐůĂƐƐ'dĂŝů^ůƵƌƌLJ^ŚŽĞƚƌĂĐŬс ϴϬΖdžϬ͘ϭϰϵϳďďůͬĨƚdžϭ͘Ϭ;ϬйĞdžĐĞƐƐͿϭϯͲϯͬϴΗ^hZ& D Ed>h>d/KE^>ĞĂĚĞŵĞŶƚLJŝĞůĚсĞƐŝŐŶ͗ϱϬϬΖŽĨϭϱ͘ϴƉƉŐdĂŝůŵƚǁŝƚŚϭϭ͘ϬƉƉŐ>ĞĂĚŵƚƚŽƐƵƌĨĂĐĞǁŝƚŚϱϬйĞdžĐĞƐƐďĞůŽǁWĞƌŵĂĨƌŽƐƚΘϮϱϬйĞdžĐĞƐƐŝŶWĞƌŵĂĨƌŽƐƚW/d/ ^EEh>Z^ĞƐŝŐŶ͗ϱϬϬΖŽĨϭϱ͘ϴƉƉŐdĂŝůŵƚǁŝƚŚϭϭ͘ϬƉƉŐ>ĞĂĚŵƚƚŽƐƵƌĨĂĐĞǁŝƚŚϱϬйĞdžĐĞƐƐďĞůŽǁWĞƌŵĂĨƌŽƐƚΘϮϱϬйĞdžĐĞƐƐŝŶWĞƌŵĂĨƌŽƐƚƚŵŽĨ>ĞĂĚƚŽĂƐĞŽĨWĞƌŵĂĨƌŽƐƚс ;ϮϮϯϲΖͲϭϮϱϳΖͿdžϬ͘ϬϳϰϵďďůͬĨƚdžϭ͘ϱ;ϱϬйĞdžĐĞƐƐͿ Wd,^ϮϬΗKEdžϭϯ͘ϯϳϱΗсϭϲΗK,džϭϯ͘ϯϳϱΗсEŽŵŝŶĂůϭϯ͘ϯϳϱΗϲϴηсϱϲ͘ϮďďůƐ
t >>͗^ d/KE͗ džĐĞƐƐƉůĂŶŶĞĚ͗ ϭ͘ϰϰϬйĞŵĞŶƚLJŝĞůĚ ϭ͘ϭϲĨƚΔϯͬƐŬϭ͘ϭϲ ĨƚΔϯͬƐŬϵ͘ϭ ďďůƐфϵϱͬϴΗ/Ed/ϭϯϮ͘ϴ ďďůƐϮϳϯϲ Ĩƚϭϰϭ͘ϵďďůƐŽƌϳϵϲ͘ϵĨƚΔϯŽƌϲϴϳƐŬƐфϭϮϭͬϰΗK,ϲϯϬ͘ϲďďůƐϬ͘Ϭϱϵϳ >ͬ&dϬ͘Ϭϱϱϴ>ͬ&dϬ͘ϬϬϬϬ>ͬ&dϬ͘Ϭϳϱϴ >ͬ&dϮϳϯϲ &dϴϯϭϲ &dϴϰϯϲ &dϭϳϬϭ &dϱϱϳϬ Ĩƚϲϳϯϱ &dϱϲϱϵ Ĩƚϲϳϯϱ ĨƚϭϮϬ &dy Ϭ͘Ϭϳϱϴ >ͬ&dс ϵ͘ϭ >^ϭϳϬϭ &dy Ϭ͘Ϭϱϱϴ >ͬ&dс ϵϰ͘ϵ >^ϵϰ͘ϵ >^y ϭ͘ϰ ϰϬй ϭϯϮ͘ϴ >^ϭϰϭ͘ϵ >^ϴϯϭϲ Ĩƚϴϯϭϲ &dy Ϭ͘Ϭϳϱϴ >ͬ&dс ϲϯϬ͘ϲ >^ϴϰϯϲ ĨƚϲϯϬ͘ϲ>^dKd>sK>hD ϭϯϮ͘ϴďďůƐ^ƵƌĨĂĐĞdŽdŽƉŽĨ&ůŽĂƚŽůůĂƌdKd>sK>hD ĞƐƚdK/^W> D Edϵ͘ϭďďůƐϭϮ͘ϮϱΗK,džϵ͘ϲϮϱΗ^'ďďůƐ ĞƐƚdK&tWZ s/Kh^^,K с^ d Wd,с D Ed&>KdK>>ZсϰϬйK, y ^^ĞƐŝƌĞĚdK;ϮϱϬΖdsĂďŽǀĞƐŚŽĞĐĂůĐƵůĂƚĞĚͿс&ůŽĂƚĐŽůůĂƌ^ĞƚĚĞƉƚŚ&/>>K& D Edс^,K dZ<sK>hD ^ĞƐƚdKDWϲϬďďůƐϱďďůƐdŽƚĂůĞŵĞŶƚsŽůƵŵĞсϭϯͲϯͬϴΗ^'džϵͲϱͬϴΗ^'сŝƐƉůĂĐĞŵĞŶƚс ϴϯϭϲΖdžϬ͘ϬϳϱϴďďůͬĨƚс
ϲϯϬ͘ϲ
EŽŵŝŶĂůϵϱͬϴΗϰϬη^'с Wd,^EEh>Z^ϭϮͲϭͬϰΗK,džϵͲϱͬϴΗ^'с/Ed ZE>EŽŵŝŶĂůϱϳͬϴΗϮϲ͘ϯηWсϰͲϱϵϳϵͲϱͬϴΗ/Ed/ϵͲϱͬϴΗ/ŶƚĞƌŵĞĚŝĂƚĞ/ĞŵĞŶƚĂůĐƵůĂƚŝŽŶƐϭϯϯͬϴΗ^hZ&хĞƐŝŐŶ͗ůĂƐƐ'ϭϱ͘ϴƉƉŐĞŵĞŶƚƚŽϮϱϬΖdsĂďŽǀĞƐŚŽĞƐĞƚĚĞƉƚŚ͘ĞŵĞŶƚLJŝĞůĚс WůĂŶŶĞĚdKс ϲϳϯϱΖDĞƐŝŐŶ͗ůĂƐƐ'ϭϱ͘ϴƉƉŐĞŵĞŶƚƚŽϮϱϬΖdsĂďŽǀĞƐŚŽĞƐĞƚĚĞƉƚŚ͘^ŚŽĞdƌĂĐŬ ϭϮϬΖdžϬ͘ϬϳϱϴďďůͬĨƚdžϭ͘Ϭ;ϬйĞdžĐĞƐƐͿW/d/ ^WƌĞǀŝŽƵƐƐŚŽĞϭϮͲϭͬϰΗdžϵͲϱͬϴΗŶŶƵůƵƐс ;ϴϰϯϲΖͲϲϳϯϱΖͿdžϬ͘ϬϱϱϴďďůͬĨƚdžϭ͘ϰ;ϰϬйĞdžĐĞƐƐͿ
t >>͗^ d/KE͗ džĐĞƐƐƉůĂŶŶĞĚ͗ϭ͘ϯϯϬйфϰΗW>ĞĂĚĞŵĞŶƚLJŝĞůĚϭ͘ϵϲĨƚΔϯͬƐŬdĂŝůĞŵĞŶƚLJŝĞůĚϭ͘ϭϲĨƚΔϯͬƐŬϭ͘ϭϲĨƚΔϯͬƐŬϭ͘ϵϲĨƚΔϯͬƐŬϬĨƚϴϱ͘ϲ ďďůƐϴϱ͘ϲďďůƐŽƌϰϴϬ͘ϴĨƚΔϯŽƌϮϰϱƐŬƐϰ͘ϲ ďďůƐϵϱͬϴΗ/Ed/хϭϳ͘ϰ ďďůƐϬ͘ϬϲϬϯ>ͬ&dϮϮďďůƐŽƌϭϮϯ͘ϱĨƚΔϯŽƌϭϬϲƐŬƐϬ͘ϬϮϴϮ >ͬ&dϮϰϲ͘ϬďďůƐϬ͘ϬϮϲϴ>ͬ&dфϳΗ/Ed//Ϭ͘ϬϭϬϴ>ͬ&dϬ͘Ϭϯϴϯ>ͬ&dϴϰϯϲĨƚфϴϯͬϰΗK,ϴϰϯϲ&dϴϮϴϲ&dϭϮϯϲϵ&dϳϴϰϴĨƚϭϮϰϴϵ&dϴϬϯϱĨƚϱϬϬ&dϮϰϲϬ&dϵϱϮϵ&dϵϱϮϵĨƚϮϰϲϬ&dyϬ͘ϬϮϲϴ>ͬ&dсϲϱ͘ϵ>^ϲϱ͘ϵ>^yϭ͘ϯϯϬйϴϱ͘ϲ>^фϴϯͬϰΗK,ϴϱ͘ϲ >^ϭϮϯϲϵ ĨƚϭϮϰϴϵĨƚϭϮϬ&dyϬ͘Ϭϯϴϯ>ͬ&dсϰ͘ϲ>^ϱϬϬ&dyϬ͘ϬϮϲϴ>ͬ&dсϭϯ͘ϰ>^ϭϯ͘ϰ>^yϭ͘ϯϯϬйϭϳ͘ϰ>^ϮϮ͘Ϭ>^ϭϬϳ͘ϲ >^ϴϮϴϲ &dy Ϭ͘ϬϭϬϴ >ͬ&dс ϴϵ͘ϴ >^ϰϬϴϯ&dyϬ͘Ϭϯϴϯ>ͬ&dсϭϱϲ͘Ϯ>^Ϯϰϲ͘Ϭ>^ŝƐƉůĂĐĞŵĞŶƚс;ϭϮϯϲϵΖͲϴϮϴϲΖͿdžϬ͘ϬϯϴϯďďůͬĨƚнϴϮϴϲΖdžϬ͘ϬϭϬϴďďůͬĨƚсϭϱ͘ϴƉƉŐůĂƐƐ'dĂŝů^ůƵƌƌLJ^ŚŽĞƚƌĂĐŬс ϭϮϬΖdžϬ͘ϬϯϴϯďďůͬĨƚdžϭ͘Ϭ;ϬйĞdžĐĞƐƐͿ^ŚŽĞƚŽdŽƉŽĨdĂŝůс ϱϬϬΖdžϬ͘ϬϮϲϴďďůͬĨƚdžϭ͘ϯ;ϯϬйĞdžĐĞƐƐͿdŽƚĂůdĂŝůĞŵĞŶƚсĨƚϴϮϴϲdŽƉŽĨϳΗ>ŝŶĞƌ,ĂŶŐĞƌWƌĞǀŝŽƵƐƐŚŽĞĞƐƚdK&tWZ s/Kh^^,K сϴ͘ϳϱΗK,džϳΗ^'> D Ed^,K dZ<d/> D EdsK>hD ^ĞƐŝƌĞĚdK;ϮϱϬΖdsĂďŽǀĞƐŚŽĞĐĂůĐƵůĂƚĞĚͿс> E'd,K&> с^ d Wd,с> E'd,K&d/>сdKd>> sK>hD &>KdK>>ZсdKWϳΗ>/E ZсϰϬďďůƐĞƐƚdKdKd> D EdsK>hD ϴ͘ϳϱΗK,džϳΗ^'/^W> D EddŽdŽƉŽĨdŽƉ>ŝŶĞƌ,ĂŶŐĞƌ>ŝŶĞƌ,ĂŶŐĞƌdŽdŽƉŽĨ&ůŽĂƚŽůůĂƌdKd>sK>hD dKd>d/>sK>hD ϭϳ͘ϰďďůƐϴϱ͘ϲďďůƐEŽŵŝŶĂůϳΗϮϲη^'с Wd,^ϵͲϱͬϴΗ^'džϳΗ^'с/Ed ZE>dŽƉŽĨϵͲϱͬϴΗ>ŝŶĞƌ,ĂŶŐĞƌϯϬйK, džĐĞƐƐ ϰ͘ϲďďůƐ^ĞƚĚĞƉƚŚďďůƐϰϳϯ͘ϯ &ůŽĂƚĐŽůůĂƌϱďďůƐĞƐƚdKDWEEh>Z^ϵͲϱͬϴΗ^'džϰΗWсϴͲϯͬϰΗK,džϳΗ^'сEŽŵŝŶĂůϰΗϭϰηWсϰͲϱϵϳϳΗ/Ed//ϳΗ/ŶƚĞƌŵĞĚŝĂƚĞ//ĞŵĞŶƚĂůĐƵůĂƚŝŽŶƐϭϯϯͬϴΗ^hZ&хdĂŝůĞŵĞŶƚLJŝĞůĚс>ĞĂĚĞŵĞŶƚLJŝĞůĚсĞƐŝŐŶ͗ϭϯƉƉŐĞdžƚĞŶĚĞĚůĞĂĚǁŝƚŚϱϬϬΖϭϱ͘ϴƉƉŐĐůĂƐƐ'ƚĂŝůƚŽϭϱϬϬΖDĂďŽǀĞ<ϯŵĂƌŬĞƌ͘W/d/ ^dŽƚĂů>ĞĂĚĞŵĞŶƚсĞƐŝŐŶ͗ϭϯƉƉŐĞdžƚĞŶĚĞĚůĞĂĚǁŝƚŚϱϬϬΖϭϱ͘ϴƉƉŐĐůĂƐƐ'ƚĂŝůƚŽϭϱϬϬΖDĂďŽǀĞ<ϯŵĂƌŬĞƌ͘ϭϯƉƉŐ džƚĞŶĚĞĚ>ĞĂĚ^ůƵƌƌLJϴͲϯͬϰΗdžϳΗŶŶƵůƵƐс ;ϭϮϰϴϵΖͲϵϱϮϵΖͲϱϬϬΖͿdžϬ͘ϬϮϲϴďďůͬĨƚdžϭ͘ϯ;ϯϬйĞdžĐĞƐƐͿ
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ϲͲϭͬϴΗWƌŽĚƵĐƚŝŽŶ,ŽůĞ
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CAUTION: This email originated from outside the State of Alaska mail system. Do not
click links or open attachments unless you recognize the sender and know the content
is safe.
From:Guo, Haibin
To:Loepp, Victoria T (OGC)
Cc:Strumness, Laura A;Macdonald, Justin D
Subject:RE: [EXTERNAL]CRU CD4-597(PTD 222-019) C10 Halo
Date:Tuesday, March 29, 2022 3:54:23 PM
Attachments:CD4-597_PTD_Follow-Up_Questions.pdf
Hi Victoria,
Attached is the offset wells logs and interpretation for CD4-597.
Qannik reservoir is not present on CD4-597
CD4-597 C10 doesn’t have Halo sand
If you have any questions on the logs/interpretation, please feel free to let Laura, Geologist as
attached, or me know.
Thanks,
Haibin Guo
ERD Drilling Engineer
ConocoPhillips Alaska
Office: 907.265.1487
Cell: 907.227.6048
From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>
Sent: Wednesday, March 23, 2022 9:55 AM
To: Guo, Haibin <Haibin.Guo@conocophillips.com>
Subject: [EXTERNAL]CRU CD4-597(PTD 222-019) C10 Halo
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.
Haibin,
Please provide an assessment of the C10(Halo) and the Qannik at/near this proposed location: log,
thickness, pay, cutoffs, producibility and any other relevant information.
Victoria
Victoria Loepp
Senior Petroleum Engineer
State of Alaska
Oil & Gas Conservation Commission
333 W. 7th Ave
Anchorage, AK 99501
Work: (907)793-1247
Victoria.Loepp@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 Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov
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WELL PERMIT CHECKLISTCompanyConocoPhillips Alaska, Inc.Well Name:COLVILLE RIV UNIT CD4-597Initial Class/TypeSER / PENDGeoArea890Unit50360On/Off ShoreOnProgramSERField & PoolWell bore segAnnular DisposalPTD#:2220190COLVILLE RIVER, NARWHL UND OIL - 120176NA1Permit fee attachedYes2Lease number appropriateYes3Unique well name and numberNoNarwhal Pool is Undefined.4Well located in a defined poolYes5Well located proper distance from drilling unit boundaryYes6Well located proper distance from other wellsYes7Sufficient acreage available in drilling unitYes8If deviated, is wellbore plat includedYes9Operator only affected partyYes10Operator has appropriate bond in forceYes11Permit can be issued without conservation orderYes12Permit can be issued without administrative approvalYes13Can permit be approved before 15-day waitYesERIO 6 applies to Narwhal sands, WINJ is approved WAG injection is not.14Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForYes15All wells within 1/4 mile area of review identified (For service well only)YesWell will be pre-produced for 30-60 days to clean it up before injection.16Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes18Conductor string providedYes19Surface casing protects all known USDWsYes310% excess planned20CMT vol adequate to circulate on conductor & surf csgNo21CMT vol adequate to tie-in long string to surf csgNoProductive interval will be completed with uncemented production liner with perf joints22CMT will cover all known productive horizonsYes23Casing designs adequate for C, T, B & permafrostYesRig has steel tanks; all waste to approved disposal wells24Adequate tankage or reserve pitNA25If a re-drill, has a 10-403 for abandonment been approvedYesAnti-collision analysis complete; no major risk failures26Adequate wellbore separation proposedYesDiverter waiver granted per 20 AAC 25.035(h)(2)27If diverter required, does it meet regulationsYesMax formation pressure is 1850 psi(8.6 ppg EMW); will drill w/ 10 ppg EMW28Drilling fluid program schematic & equip list adequateYesSince MPSP is <3000 psig only one fixed and one variable ram required29BOPEs, do they meet regulationYesMPSP is 1449 psig; will test BOPs to 3500 psig30BOPE press rating appropriate; test to (put psig in comments)Yes31Choke manifold complies w/API RP-53 (May 84)Yes32Work will occur without operation shutdownNo33Is presence of H2S gas probableYesno wells within the AOR34Mechanical condition of wells within AOR verified (For service well only)YesNone expected based on numerous wells drilled from CD4-Pad.35Permit can be issued w/o hydrogen sulfide measuresYes36Data presented on potential overpressure zonesNA37Seismic analysis of shallow gas zonesNA38Seabed condition survey (if off-shore)NA39Contact name/phone for weekly progress reports [exploratory only]ApprDLBDate2/28/2022ApprVTLDate3/1/2022ApprDLBDate2/28/2022AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate-03JLC 4/4/2022
