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Originated: Delivered to:31-Jul-25Alaska Oil & Gas Conservation Commiss31Jul25-NRATTN: Meredith Guhl333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539Anchorage, AK 99518(907) 273-1700 main (907)273-4760 faxWELL NAME API #SERVICE ORDER #FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTIONDATA TYPE DATE LOGGED3S-703 50-029237-61-00-00 223-056 Kuparuk River WL TTiX-HSD FINAL FIELD 8-Jul-253T-731 50-103209-05-00-00 224-156 Kuparuk River WL TTiX FSI & SCMT FINAL FIELD 12-Jul-253T-603 50-103208-87-00-00 224-074 Kuparuk River WL Caliper & Perforation FINAL FIELD 14-Jul-253S-606 50-103208-70-00-00 223-111 Kuparuk River WL TTiX- IPROF FINAL FIELD 21-Jul-25Transmittal Receipt________________________________X__________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.Nraasch@slb.comSLB Auditor - TRANSMITTAL DATETRANSMITTAL #A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media.# Schlumberger-Private225-035T40727T40728T40729T407303S-60650-103208-70-00-00223-111Kuparuk RiverWLTTiX- IPROFFINAL FIELD21-Jul-25Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.08.01 08:56:13 -08'00'
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Monday, October 14, 2024
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Sully Sullivan
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
3S-606
KUPARUK RIV UNIT 3S-606
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 10/14/2024
3S-606
50-103-20870-00-00
223-111-0
W
SPT
5022
2231110 1500
25 25 25 25
308 355 343 338
INITAL P
Sully Sullivan
8/4/2024
Initial MIT-IA, great test no issues
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:KUPARUK RIV UNIT 3S-606
Inspection Date:
Tubing
OA
Packer Depth
1110 1910 1875 1870IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitSTS240805101146
BBL Pumped:0.7 BBL Returned:0.9
Monday, October 14, 2024 Page 1 of 1
9
9
9
9
9 9
999
9
9James B. Regg Digitally signed by James B. Regg
Date: 2024.10.14 15:29:16 -08'00'
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________KUPARUK RIV UNIT 3S-606
JBR 04/05/2024
MISC. INSPECTIONS:
FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK:
ACCUMULATOR SYSTEM:MUD SYSTEM:
P/F P/F
P/FP/FP/F
Visual Alarm
QuantityQuantity
Time/Pressure
SizeQuantity
Number of Failures:0
Tested with 4 1/2" and 4" test joints, Tested all gas alarms and PVT's. Precharge Bottles = 15@1000psi and 1@950psi. GOOD
TEST!
Test Results
TEST DATA
Rig Rep:F. Carlo / K. HaugOperator:ConocoPhillips Alaska, Inc.Operator Rep:M. Tucker / B/ Marmon
Rig Owner/Rig No.:Doyon 142 PTD#:2231110 DATE:2/12/2024
Type Operation:DRILL Annular:
250/4000Type Test:OTH
Valves:
250/4000
Rams:
250/4000
Test Pressures:Inspection No:bopBDB240214074136
Inspector Brian Bixby
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 4.3
MASP:
1788
Sundry No:
Control System Response Time (sec)
Time P/F
Housekeeping:P
PTD On Location P
Standing Order Posted P
Well Sign P
Hazard Sec.P
Test Fluid W
Misc NA
Upper Kelly 1 P
Lower Kelly 1 P
Ball Type 2 P
Inside BOP 1 P
FSV Misc 0 NA
14 PNo. Valves
1 PManual Chokes
1 PHydraulic Chokes
0 NACH Misc
Stripper 0 NA
Annular Preventer 1 13 5/8"P
#1 Rams 1 3 1/2" x 6"P
#2 Rams 1 Blind/Shear P
#3 Rams 1 3 1/2" x 6"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 0 NA
System Pressure P3000
Pressure After Closure P1800
200 PSI Attained P21
Full Pressure Attained P111
Blind Switch Covers:PYES
Bottle precharge P
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
0 NAMS Misc
Inside Reel Valves 0 NA
Annular Preventer P18
#1 Rams P7
#2 Rams P7
#3 Rams P7
#4 Rams NA0
#5 Rams NA0
#6 Rams NA0
HCR Choke P1
HCR Kill P1
BOPE - Doyon 142
KRU 3S-606 (PTD 2231110)
AOGCC Insp #bopBDB240214074136
2/12/2024
Test Bope 4” & 4-1/2” Test Joints 250/4000psi on All
Components / Hyd & Manual Chokes 2000psi
1.4-1/2” TJ, Annular, CMV’s #’s 1, 12, 13, 14, Rig floor kill
line valve, 4” Dart valve, Upper IBOP 250/4000 5&5
2.4-1/2” TJ, 3-1/2”X6” UPR’s, CMV’s #’s 9, 11, Mezz Kill line
valve, 4” TIW #1, Lower IBOP 250/4000 5&5
3.CMV’s #’s 8, 10, HCR Kill, 4” TIW #2, 250/4000 5&5
4.CMV’s #’s 6, 7, Manual Kill 250/4000 5&5
5.HYD Choke, Pressure up to 2000psi hold for 1 minute,
bleed pressure through the choke and catch it before it
reaches zero, the sooner the better
6.Manual Choke, Pressure up to 2000psi hold for 1
minute, bleed pressure through the choke and catch it
before it reaches zero, the sooner the better
7. CMV’s #’s 2, 5 250/4000 5&5
8.4-1/2” TJ 3-1/2” X 6” LPR’s 250/4000
Perform Koomey Draw Down
Remove 4-1/2” Test Joint
9. CMV’s #’s 3, 4, Blind rams 250/4000 5&5
Install 4” Test Joint
10.4” TJ, Annular, HCR Choke 250/4000 5&5
11.4” TJ, 3-1/2” UPR’s, Manual Choke 250/4000 5&5
12.4” TJ, 3-1/2” X 6” Lower VBR’s, 250/4000 5&5
BOPE - Doyon 142
KRU 3S-606 (PTD 2231110)
AOGCC Insp #bopBDB240214074136
2/12/2024
1
Regg, James B (OGC)
From:Brooks, Phoebe L (OGC)
Sent:Tuesday, February 20, 2024 2:11 PM
To:Rig 142
Cc:Regg, James B (OGC)
Subject:RE: Doyon 142 BOPE Test Report 3S-606
Attachments:Doyon 142 02-01-24.xlsx
Kelly,
I made a minor revision, including only one test type – IniƟal (as this is the first report for KRU 3S‐606). Please update
your copy.
Thank you,
Phoebe
Phoebe Brooks
Research Analyst
Alaska Oil and Gas ConservaƟon Commission
Phone: 907‐793‐1242
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas
Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential
and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you
are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the
mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov.
From: Rig 142 <rig142@doyondrilling.com>
Sent: Friday, February 2, 2024 6:09 PM
To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>;
Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>
Cc: Doyon 142 Company Man <d142cm@conocophillips.com>
Subject: Doyon 142 BOPE Test Report 3S‐606
Kelly Haug
Rig 142 Tourpusher
Rig142@doyondrilling.com
Doyon Rig 142 Office 907-670-6002
Cell, 907-355-5834
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open
attachments unless you recognize the sender and know the content is safe.
KRU 3S-606PTD 2231110
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner:Rig No.:142 DATE:2/1/24
Rig Rep.:Rig Email:
Operator:
Operator Rep.:Op. Rep Email:
Well Name:PTD #2231110 Sundry #
Operation:Drilling:X Workover:Explor.:
Test:Initial:X Weekly:Bi-Weekly:Other:
Rams:250/5000 Annular:250/3500 Valves:250/5000 MASP:1788
MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 1 P
Permit On Location P Hazard Sec.P Lower Kelly 1 P
Standing Order Posted P Misc.NA Ball Type 2 P
Test Fluid Water Inside BOP 1 P
FSV Misc 0 NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0 NA Trip Tank P P
Annular Preventer 1 13-5/8" 5M P Pit Level Indicators P P
#1 Rams 1 7-5/8" SB P Flow Indicator P P
#2 Rams 1 Blind/ Shear P Meth Gas Detector P P
#3 Rams 1 3-1/2" x 6" VBR P H2S Gas Detector P P
#4 Rams 0 NA MS Misc 0 NA
#5 Rams 0 NA
#6 Rams 0 NA ACCUMULATOR SYSTEM:
Choke Ln. Valves 1 3-1/8" 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)1500 P
Check Valve 0 NA 200 psi Attained (sec)9 P
BOP Misc 0 NA Full Pressure Attained (sec)116 P
Blind Switch Covers:All stations Yes
CHOKE MANIFOLD:Bottle Precharge:1000 P
Quantity Test Result Nitgn. Bottles # & psi (Avg.):2008 P
No. Valves 14 P ACC Misc 0 NA
Manual Chokes 1 P
Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result
CH Misc 0 NA Annular Preventer 18 P
#1 Rams 8 P
Coiled Tubing Only:#2 Rams 8 P
Inside Reel valves 0 NA #3 Rams 7 P
#4 Rams 0 NA
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:0 Test Time:7.0 HCR Choke 2 P
Repair or replacement of equipment will be made within 0 days. HCR Kill 2 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 1-30-24 / 01:13
Waived By
Test Start Date/Time:2/1/2024 14:00
(date)(time)Witness
Test Finish Date/Time:2/1/2024 21:00
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Sully Sullivan
Doyon
F.Carlo/ Kelly Haug
Conoco
Mike Tucker / Mickey Aurthur
KRU 3S-606
Test Pressure (psi):
rig142@doyondrilling.com
d142cm@conocophillips.com
Test Annular w/ 7-5/8" and 5" test jts 250/3500psi, Test upper 7-5/8" SBR's 250/5000 w/7-5/8" test joint & lower 3-1/2" x 6"VBR
250/5000psi w/ 5" test jt. Test 2ea-5"FOSV/ 1ea-5" Dart 250/5000psi Test manual & hydraulic choke to 2,000 psi, Choke valves
#'s 1-14, Choke & Kill Manuals & HCR, 2x 4"Demco valve on Kill, Upper & Lower IBOP,250/5000psi, test all H2S, LEL & PVT and
flow alarms/both audible and visual. All rams functioned from both primary and remote controls. Drawdown conducted w/ 2 air,
and 2ea electrical air pumps. Rig on a 21 day BOP test cycle.
Form 10-424 (Revised 08/2022)2024-0201_BOP_Doyon142_KRU_3S-606
J. Regg; 4/5/2024
CAUTION: This email originated from outside the State of Alaska mail system. Do not
click links or open attachments unless you recognize the sender and know the content
is safe.
From:Rig 142
To:Brooks, Phoebe L (OGC)
Cc:DOA AOGCC Prudhoe Bay; Regg, James B (OGC)
Subject:adjusted 3s-606 BOPE test report
Date:Thursday, March 28, 2024 6:37:31 PM
Attachments:image003.png
10-424 3-2-24.xlsx
Some people who received this message don't often get email from rig142@doyondrilling.com. Learn why this isimportant
Adjust to reflect the # of nitrogen bottles on the koomey system, Thank you
Kelly Haug
Rig 142 Tourpusher
Rig142@doyondrilling.com
Doyon Rig 142 Office 907-670-6002
Cell, 907-355-5834
Kuparuk River Unit 3S-606
PTD 2231110
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner:Rig No.:142 DATE:3/2/24
Rig Rep.:Rig Email:
Operator:
Operator Rep.:Op. Rep Email:
Well Name:PTD #2231110 Sundry #
Operation:Drilling:x Workover:Explor.:
Test:Initial:Weekly:Bi-Weekly:Other:X
Rams:250/4000 Annular:250/3500 Valves:250/4000 MASP:1788
MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping p Well Sign P Upper Kelly 1 P
Permit On Location p Hazard Sec.P Lower Kelly 1 P
Standing Order Posted p Misc.NA Ball Type 2 P
Test Fluid Water Inside BOP 1 P
FSV Misc 0 NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0 P Trip Tank P P
Annular Preventer 1 13-5/8 5M P Pit Level Indicators P P
#1 Rams 1 3-1/2" x 6" VBR P Flow Indicator P P
#2 Rams 1 Blind / Shear P Meth Gas Detector P P
#3 Rams 1 3-1/2" x 6 VBR P H2S Gas Detector P P
#4 Rams 0 NA MS Misc 0 NA
#5 Rams 0 NA
#6 Rams 0 NA ACCUMULATOR SYSTEM:
Choke Ln. Valves 1 3-1/8" 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)1850 P
Check Valve 0 NA 200 psi Attained (sec)18 P
BOP Misc 0 NA Full Pressure Attained (sec)102 P
Blind Switch Covers:All stations Yes
CHOKE MANIFOLD:Bottle Precharge:1000 P
Quantity Test Result Nitgn. Bottles # & psi (Avg.):6 @ avg 2000 P
No. Valves 14 P ACC Misc 0 NA
Manual Chokes 1 P
Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result
CH Misc 0 NA Annular Preventer 18 P
#1 Rams 7 P
Coiled Tubing Only:#2 Rams 7 P
Inside Reel valves 0 NA #3 Rams 7 P
#4 Rams 0 NA
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:0 Test Time:7.0 HCR Choke 1 P
Repair or replacement of equipment will be made within 0 days. HCR Kill 1 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 3-2-24 22:00
Waived By
Test Start Date/Time:3/2/2024 15:00
(date)(time)Witness
Test Finish Date/Time:3/2/2024 22:00
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Brian Bixby
Doyon
Test Annular w/ 4-1/2" test jt 250/3500psi, Test upper 3-1/2" x 6" VBR's 250/4000 w/ 4" test joint & lower 3-1/2" x 6" VBR's
250/4000psi w/4-1/2" test jt. Test 2ea-4" FOSV/ 1ea-4" Dart 250/4000psi Test manual & hydraulic choke to 2,000 psi, Choke
valves #'s 1-14, Choke & Kill Manuals & HCR's, 2x 4"Demco valve on Kill, Upper & Lower IBOP, 250/4000psi, Test all H2S, LEL
& PVT flow alarms/both audible and visual. All rams functioned from both primary and remote controls. Drawdown conducted w/
2 air, and 2ea electrical pumps. Rig on a 21 day BOP test cycle.
F.Carlo/ Brian Limberg
ConocoPhillips Alaska Inc.
Mickey Arthur/ Adam Dorr
KRU 3S-606
Test Pressure (psi):
rig142@doyondrilling.com
d142cm@conocophillips
Form 10-424 (Revised 08/2022)2024-0302_BOP_Doyon142_KRU_3S-606
J. Regg; 4/3/2024Test charts attached
BOPE Test - Doyon 142
KRU 3S-606 (PTD 2231110)
3/2/2024
BOPE Test - Doyon 142
KRU 3S-606 (PTD 2231110)
3/2/2024
DOYON RIG 142 ACCUMULATOR DRAW DOWN WORKSHEET
WELL: 3S-606 DATE: 3-2-24
ACCUMULATOR PSI 3000 psi
MANIFOLD PSI 1550 psi
FUNCTION RAMS/ANNULAR/ HCR'S, DON'T FUNCTION BLINDS! FUNCTION ONE RAM
TWICE LET PRSSURE STABILIZE AND RECORD BACK UP NITROGEN BOTTLE'S
ACCUMULATOR PSI 1850 psi
NITROGEN BOTTLE'S PSI
BOTTLE # 1 2000
BOTTLE # 2 2000
BOTTLE # 3 2000
BOTTLE # 4 2000
BOTTLE # 5 2000
BOTTLE # 6 2000
AVG FOR 6 BOTTLE'S =2000
TURN ON ELEC. PUMP, SEC FOR 200 PSI =18 sec
TURN ON AIR PUMP'S
TIME FOR FULL CHARAGE =102 sec
Annular 16 sec
UPR 7 sec
Blind/ Shear 7 sec
LPR 7 sec
KILL HCR 1 sec
Choke HCR 1 sec
BOPE Test - Doyon 142
KRU 3S-606 (PTD 2231110)
3/2/2024
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown
Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program
Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops 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 20119 feet feet
true vertical 5181 feet feet
Effective Depth measured 20118 feet 7151 / 7466 feet
true vertical 5181 feet 5022 / 5148 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 7289' MD 5085' TVD
Baker SLZXP 7466' MD 5148' TVD
Packers and SSSV (type, measured and true vertical depth)HAL TNT 7151' MD 5022' TVD
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
13a.
Prior to well operation:
Subsequent to operation:
13b. Pools active after work: Torok Oil Pool
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:
Authorized Name and
Digital Signature with Date:Manabu Nozaki 6/21/2024 Contact Name:Manabu Nozaki
Contact Email:Manabu.Nozaki@ConocoPhillips.com
Authorized Title:Completions Engineer Contact Phone:907-265-6519
2558
Burst Collapse
2470
measured
TVD
Intermediate
Liner
6615
851
12833
Casing
Structural
4730
5148
4-1/2"
6615
7466
20118 5181
Plugs
Junk measured
4.3 MMlbs 16/20 Wan-Li LWC proppant, 105,000 lbs of 100 Mesh, and 2530 psi treating pressure/4800 psi BHG pressure.
Length
235
2922
235Conductor
Surface
Intermediate
20"
10-3/4"
Job logs attached
5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work:
ADL380107 / ADL380106 / ADL025528 / ADL393883
Kuparuk Field / Torok Oil Pool
KRU 3S-606
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
223-111
50-103-20870-00-00
P.O. Box 100360 Anchorage, AK 99510-03603. Address:
9-5/8"
11590
7-5/8"
4790
7850
6890
10860
TBD
N/A
measured
true vertical
Packer
Representative Daily Average Production or Injection Data
Casing Pressure Tubing PressureGas-Mcf
MD
7751' - 19829' MD
Size
235
52102922
324-150
Sr Pet Eng:
9210
Sr Pet Geo: Sr Res Eng:
WINJ WAG
Water-BblOil-Bbl
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
p
k
ft
t
Fra
O
s O
223
6. A
G
L
PG
,
Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
By Grace Christianson at 3:53 pm, Jun 21, 2024
Prepared By:
William Martin
Dan Faur
Nannook Crew
Intervals 1-9
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.
3S-606
Conoco Phillips
Harrison Bay County, AK
Post Job Report
Stimulation Treatment
API: 50-103-20870
Prepared for: Manabu Nozaki
April 1, 2024
Torok Formation
32# Hybor G
Table of Contents
Section Page(s)
Executive Summary
Actual Design
Wellbore Information
Interval Summary
Fluid System Proppant Summary
Interval 1 Plots
Interval 2 Plots
Interval 3 Plots
Interval 4 Plots
Interval 5 Plots
Interval 6 Plots
Interval 7 Plots
Interval 8 Plots
Interval 9 Plots
Appendix
Well Summary
Chemical Summary
Planned Design
Water Straps 3 31
Water Straps 4 1
Water Analysis 3 31
Water Analysis 4 1
Real Time QC
Event Log 3 30
Event Log 3 31
Event Log 4 1
Prejob Break Test
Fann 15 Min Test Interval 1
Fann 15 Min Test Interval 2
Fann 15 Min Test Interval 3
Fann 15 Min Test Interval 4
Fann 15 Min Test Interval 5
Fann 15 Min Test Interval 6
Fann 15 Min Test Interval 7
Fann 15 Min Test Interval 8
Fann 15 Min Test Interval 9
Sand Sieve Analysis
90
91
92
85
86
87
88
89
80
81
82
83
84
75
76
77
78
79
60 63
64 67
68
69
70
74
3
4 5
6
37 40
41 44
45 51
7 15
16
17 29
30 36
52 55
56 59
71 73
Conoco Phillips 3S 606 TOC 2
645,750 gallons of 32# Hybor G
38,749 gallons of 32# Linear
1,680 gallons of Seawater
4,940 gallons of Freeze Protect
1,800,000 pounds of Wanli 16/20 Ceramic
36,000 pounds of 100M
670,108 gallons of 32# Hybor G
41,706 gallons of 32# Linear
2,697 gallons of Seawater
7,980 gallons of Freeze Protect
1,851,920 pounds of Wanli 16/20 Ceramic
39,000 pounds of 100M
Thank you,
William Martin
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 March 31, 2024 a stimulation treatment was performed in the Torok formation on the 3S-606 well in Harrison Bay County,
AK. The 3S-606 was a 24 stage Horizontal Sleeve Design. The proposed treatment consisted of:
The actual treatment fully completed 9 of 24 stages. 0 stages were skipped, 0 stage screened out and 0 stages were cut short 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:
3S-606 was seperated into two different stimulations, intervals 1 through 9 will be initially stimulated followed by a flow period
before frac'ing the remaining stages, 10 through 24.
There were no changes made to the design in intervals 1 through 9. A DFIT was pumped after opening the Alpha Sleeve and a
Minifrac was pumped after opening the sleeve for interval 2.
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.
There were no changes to the fluid design in intervals 1 through 9. Full strength MO was used at a set point of 0.65 to maintain
the designed pH.
Conoco Phillips 3S 606 Executive Summary 3
Interval 1Torok@ 19829.46 - 19833.32 ft 139.3 °FInterval 2Torok@ 19299.01 - 19302.87 ft 139.3 °FInterval 3Torok@ 18777.47 - 18781.33 ft 139.2 °FInterval 4Torok@ 18255.02 - 18258.88 ft 139.2 °F
Interval 6Torok@ 17213.04 - 17216.9 ft 139.1 °FInterval 7Torok@ 16692.72 - 16696.58 ft 139 °FInterval 8Torok@ 16170.9 - 16174.76 ft 139.1 °FInterval 9Torok@ 15652.12 - 15655.98 ft 139.1 °FInterval 5Torok@ 17733.53 - 17737.39 ft 139.2 °F
Conoco PhillipsTorok3S6065010320870*Exceeds80% of burst pressure*Description OD (in) ID (in) Wt (#) GradeFUF(gal/ft)MD Top (ft) MD Btm (ft) Volume (gal)Tubular BurstPressure (psi)Tubing4.5 3.958 12.6 L80 0.6392 0 8,148 5,208 8,430Tubing4.5 3.958 12.6 L80 0.6392 8,148 21,240 8,368 8,430Total21,24013,577ft1.53ft139.9ftTop MD (ft) Btm MD (ft)AverageTVD (ft)Interval # Formation DescriptorAverage IntervalTemperature (F)Ball Drop Time(HH:MM)Ball Hit Time(HH:MM)JSV Drop(bbl)JSV SlowDown (bbl)JSV Hit (bbl)Early (bbl)Surface SeatPressure (psi)Surface PeakPressure (psi)Surface Differential (psi)BH SeatPressure (psi)BH PeakPressure (psi)BHDifferential(psi)Rate at Shift(bpm)Toe19829.4619833.32 5,1821Torok139.3Alpha Sleeve Alpha Sleeve Alpha Sleeve Alpha Sleeve Alpha Sleeve Alpha Sleeve Alpha Sleeve Alpha Sleeve Alpha Sleeve Alpha Sleeve Alpha Sleeve Alpha Sleeve Alpha Sleeve19299.01 19302.875,1812Torok139.310:04:00 AM 10:14:00 AM 2,165 2,429 2,44117.71,573 4,674 3,101 3,708 6,807 3,099 10.118777.4718781.33 5,1793Torok139.212:37:00 PM 12:47:00 PM 5,038 5,294 5,31013.81,695 6,716 5,021 3,801 9,145 5,344 10.118255.02 18258.885,1744Torok139.21:39:00 PM 1:49:00 PM 6,933 7,181 7,19713.81,638 7,706 6,068 3,737 7,706 3,969 10.117733.53 17737.39 5,1745Torok139.29:35:00 AM 9:53:00 AM 18 257 2798.41,594 6,591 4,997 3,578 8,380 4,802 11.317213.0417216.905,1716Torok139.110:52:00 AM 11:01:00 AM 2,067 2,299 2,31712.01,619 4,918 3,299 3,650 6,830 3,180 10.416692.72 16696.585,1657Torok139.011:54:00 AM 12:03:00 PM 3,948 4,172 4,18814.01,777 4,998 3,221 3,753 6,814 3,061 10.916170.9016174.765,1688Torok139.112:56:00 PM 1:05:00 PM 5,805 6,021 6,03912.11,630 4,750 3,120 3,621 6,842 3,221 10.315652.12 15655.985,1709Torok139.11:54:00 PM 2:02:00 PM 7,545 7,753 7,76914.21,712 4,951 3,239 3,667 6,875 3,208 10.3254.0246.1238.210,67010,33610,00512,003 285.811,66911,33511,003Displacement to TopSleeve/Perf (gal)(BBLS)12,675 301.812,336 293.7277.8269.9262.0Interval #1Max Pressure (psi)7,600Isolation TypeSwell PackerTreatment TubularsCustomerFormationLeaseAPIDateDirectional Data2,2373/31/2024KOPTemperature DataSleeve/Perf Depth Sleeves78923456Temp. Gradient(°F/100 ft)BHST(°F)TVD at Bottom PerfMD at Bottom Perf5,22019,833Conoco Phillips3S606 Wellbore Information 6
3/31/24 8:40
3/31/24 10:14
94 min
Alpha Sleeve bpm
Alpha Sleeve psi
Alpha Sleeve psi
Alpha Sleeve bbl
29.4 bpm
3,949 psi
5,823 psi
32.3 bpm
3,073 psi
2,865 psi
4,826 psi
2,436 hhp
308 psi
73 psi
429 psi
7.26 ppg
5
5
32 %
31 %
28 cP
94.2 F
9.2
DFIT
9.990 bpm
1494 psi
3585 psi
10.12 bpm
1543 psi
1623 psi
3162 psi
0.610 psi/ft
3075 psi
2956 psi
2808 psi
203,086 lbs
3,779 lbs
206,865 lbs
206,764 lbs
86,914 gal 2,069 bbls
4,200 gal 100 bbls
2,697 gal 64 bbls
4,200 gal 100 bbls
8,021 gal 191 bbls
15,987 gal 381 bbls
44,395 gal 1,057 bbls
10,997 gal 262 bbls
4,200 gal 100 bbls
7,514 gal 179 bbls
2,697 gal 64 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Establish Stable Fluid 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.
Step Rate Test Volume:
Spacer and Ball Drop Volume:
Interval Status:
Craig Karpinski
Dan Faur
Minifrac Max Rate:
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
ISDP:
Final Fracture Gradient:
Final 10 min:
A step rate test was pumped at the beginning of interval 1. The stage was pumped to
completion.
DFIT Volume:
Proppant Summary
Minifrac Average Pressure:
Minifrac Average DH Pressure:
Freeze Protect Volume:
Chad Burkett
Willie Martin
Total Proppant Pumped* :
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Average Visc:
Average Temp:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Max Rate:
Max Surface Pressure:
Max BH Pressure:
Interval Summary
3S-606 - Torok - 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:
Pumps Starting Stage:
Pad Percentage Design
Average Missile HHP:
Initial BH Pressure (Breakdown):
Average BH Pressure:
Pumps Ending Stage:
Max Proppant Concentration:
Pad Volume:
Minifrac Max Surface Pressure:
100M Pumped:
Final 15 min:
Proppant in Formation:
32# Hybor G Volume:
32# Linear Volume:
Seawater Volume:
Minifrac Max DH Pressure:
Final 5 min:
Dart/Ball Early :
Average pH:
Minifrac Average Rate:
Pump Time:
Pad Percentage Actual
Wanli 16/20 Ceramic Pumped:
Diagnostic method
Conoco Phillips 3S 606 Interval Summary 7
3/31/24 11:21
3/31/24 12:47
86 min
10.1 bpm
4,674 psi
6,807 psi
18 bbl
32.4 bpm
3,959 psi
5,748 psi
31.0 bpm
3,084 psi
2,876 psi
4,830 psi
2,340 hhp
420 psi
539 psi
7.79 ppg
5
5
32 %
31 %
26 cP
94.8 F
9.1
Minifrac
28.860 bpm
2597 psi
4310 psi
32.15 bpm
3071 psi
4624 psi
2940 psi
0.568 psi/ft
3182 psi
3168 psi
3158 psi
197,235 lbs
3,746 lbs
200,981 lbs
200,935 lbs
98,057 gal 2,335 bbls
13,319 gal 317 bbls
8,130 gal 194 bbls
15,968 gal 380 bbls
44,373 gal 1,057 bbls
1,062 gal 25 bbls
9,610 gal 229 bbls
18,914 gal 450 bbls
13,319 gal 317 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Status:
At the beginning of interval 2, a minifrac was pumped. After monitoring decline for 45 minutes,
the main interval was started. Interval 02 was pumped as per 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
Willie Martin
Craig Karpinski
Dan Faur
Wanli 16/20 Ceramic Pumped:
100M Pumped:
Total Proppant Pumped* :
32# Hybor G Volume:
32# Linear Volume:
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Spacer and Ball Drop Volume:
Establish Stable Fluid Volume:
Minifrac Average Pressure:
Minifrac Average DH Pressure:
Final 15 min:
Proppant Summary
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:
Minifrac Average Rate:
3S-606 - Torok - Interval 2
Average BH Pressure:
Average Missile HHP:
Initial OA Pressure:
Max OA Pressure:
Max Proppant Concentration:
Pumps Starting Stage:
Pumps Ending Stage:
Average Visc:
Average Temp:
Average pH:
Diagnostic method
Pad Percentage Design
Pad Percentage Actual
ISDP:
Final Fracture Gradient:
Final 5 min:
Minifrac Max DH Pressure:
Final 10 min:
Proppant in Formation:
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Minifrac Max Rate:
Minifrac Max Surface Pressure:
Pad Volume:
Minifrac - Treatment Volume:
Minifrac - Flush Volume:
Conoco Phillips 3S 606 Interval Summary 8
3/31/24 12:47
3/31/24 1:49
min
10.1 bpm
6,716 psi
9,145 psi
14 bbl
32.3 bpm
3,926 psi
5,684 psi
30.5 bpm
3,189 psi
2,981 psi
4,949 psi
2,383 hhp
504 psi
555 psi
7.40 ppg
5
5
32 %
31 %
23 cP
96.7 F
9
202,386 lbs
4,153 lbs
206,539 lbs
206,482 lbs
70,416 gal 1,677 bbls
8,022 gal 191 bbls
16,033 gal 382 bbls
45,274 gal 1,078 bbls
1,087 gal 26 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
32# Hybor G Volume:
Willie Martin
Craig Karpinski
Dan Faur
Interval Status:
The 4.0 ppg 16/20 sand stage was extended because gel viscosity dropped to 15 cP. The
proppant concentration dropped because the ADP hopper dump valve kept gel from getting to
the mixer. After rectifying the issue, the sand stages were resumed.
*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.
Total Proppant Pumped* :
Proppant in Formation:
Fluid Summary (by fluid description)
Proppant Laden Fluid Volume:
Chad Burkett
3S-606 - Torok - 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):
Fluid Summary (by stage description)
Conditioning Pad Volume:
Initial Surface Pressure (Breakdown):
Start Date/Time:
Initial OA Pressure:
Average Missile HHP:
Average Temp:
Average Missile Pressure:
Average Surface Pressure:
Average BH Pressure:
Pumps Starting Stage:
Pumps Ending Stage:
Average pH:
100M Pumped:
Max OA Pressure:
Max Proppant Concentration:
Pad Percentage Design
Pad Percentage Actual
Average Visc:
Interval Summary
Wanli 16/20 Ceramic Pumped:
Pad Volume:
Proppant Summary
Spacer and Ball Drop Volume:
Conoco Phillips 3S 606 Interval Summary 9
3/31/24 1:49
3/31/24 14:42
773 min
10.1 bpm
7,706 psi
7,706 psi
14 bbl
32.6 bpm
5,495 psi
7,436 psi
30.4 bpm
3,774 psi
3,581 psi
5,535 psi
2,811 hhp
528 psi
551 psi
6.89 ppg
5
5
32 %
31 %
30 cP
86.2 F
9.3
3431 psi
0.663 psi/ft
3261 psi
3205 psi
3151 psi
199,977 lbs
3,909 lbs
203,886 lbs
203,886 lbs
69,380 gal 1,652 bbls
12,531 gal 298 bbls
1,050 gal 25 bbls
7,827 gal 186 bbls
15,995 gal 381 bbls
45,558 gal 1,085 bbls
12,531 gal 298 bbls
1,050 gal 25 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:Chad Burkett
Willie Martin
Craig Karpinski
After shifting the sleeve, pressure was relatively high and rate had to be slowly walked up to
stay within the pressure limitations. After 100 mesh hit downhole, pressure slowly broke down
and the stage treated at pressures similar to the previous stages. Interval 4 was the last
interval pumped on day 1 of pumping. Dan Faur
Pad Volume:
Conditioning Pad Volume:
Freeze Protect Volume:
Proppant Laden Fluid Volume:
Fluid Summary (by stage description)
Interval Status:
Max BH Pressure:
Proppant Summary
Wanli 16/20 Ceramic Pumped:
Total Proppant Pumped* :
Pad Percentage Design
Average Surface Pressure:
Pumps Starting Stage:
Final Fracture Gradient:
Final 5 min:
100M Pumped:
ISDP:
Max OA Pressure:
Max Proppant Concentration:
Average Visc:
Final 10 min:
Final 15 min:
Average Temp:
Average pH:
Initial OA Pressure:
Initial Surface Pressure (Breakdown):
End Date/Time:
Pump Time:
3S-606 - Torok - Interval 4
Interval Summary
Start Date/Time:
Average Rate:
Average Missile Pressure:
Average BH Pressure:
Average Missile HHP:
Pumps Ending Stage:
Pad Percentage Actual
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Max Rate:
Flush Volume:
32# Hybor G Volume:
32# Linear Volume:
Freeze Protect 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.
Initial Rate (Breakdown):
Proppant in Formation:
Max Surface Pressure:
Fluid Summary (by fluid description)
Conoco Phillips 3S 606 Interval Summary 10
4/1/24 9:33
4/1/24 11:01
88 min
11.3 bpm
6,591 psi
8,380 psi
8 bbl
33.0 bpm
3,540 psi
5,232 psi
30.3 bpm
2,866 psi
2,754 psi
4,640 psi
2,126 hhp
402 psi
92 psi
492 psi
6.99 ppg
5
5
32 %
31 %
27 cP
88.2 F
9.2
198,701 lbs
3,998 lbs
202,699 lbs
202,639 lbs
77,172 gal 1,837 bbls
880 gal 21 bbls
2,100 gal 50 bbls
7,817 gal 186 bbls
16,390 gal 390 bbls
44,411 gal 1,057 bbls
2,173 gal 52 bbls
7,261 gal 173 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
End Date/Time:
Max BH Pressure:
Average Surface Pressure:
Interval Summary
Proppant Summary
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Wanli 16/20 Ceramic Pumped:
Conditioning Pad Volume:
Freeze Protect Volume:
32# Linear Volume:
100M Pumped:
3S-606 - Torok - Interval 5
Average BH Pressure:
Initial OA Pressure:
Max Proppant Concentration:
Start Date/Time:
Pad Percentage Design
Average Rate:
Proppant in Formation:
Pad Volume:
Willie Martin
Average Missile HHP:
Open Well Pressure:
Average Visc:
Max Surface Pressure:
Total Proppant Pumped* :
Initial Rate (Breakdown):
Spacer and Ball Drop Volume:
Establish Stable Fluid Volume:
32# Hybor G Volume:
Proppant Laden Fluid Volume:
Interval Status:
Average pH:
Pad Percentage Actual
Craig Karpinski
Interval 5 was the first interval pumped on the second day of pumping. During 5.5 ppg, a pump
kicked out due to pre-load pressure. Stage was pumped as per design.
Pumps Starting Stage:
Pumps Ending Stage:
*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
Dan Faur
Pump Time:
Average Missile Pressure:
Max OA Pressure:
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Average Temp:
Initial Surface Pressure (Breakdown):
Max Rate:
Conoco Phillips 3S 606 Interval Summary 11
4/1/24 11:01
4/1/24 12:03
62 min
10.4 bpm
4,918 psi
6,830 psi
12 bbl
32.3 bpm
3,529 psi
5,225 psi
30.1 bpm
2,764 psi
2,670 psi
4,547 psi
2,042 hhp
494 psi
562 psi
7.04 ppg
5
5
32 %
31 %
27 cP
90.6 F
9
195,198 lbs
3,413 lbs
198,611 lbs
198,435 lbs
69,858 gal 1,663 bbls
7,720 gal 184 bbls
15,981 gal 381 bbls
45,163 gal 1,075 bbls
994 gal 24 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Pump Time:
Initial Rate (Breakdown):
Average Missile HHP:
3S-606 - Torok - Interval 6
Interval Summary
Average pH:
Proppant Summary
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Pumps Starting Stage:
Max Rate:
Average Missile Pressure:
Average Rate:
Willie Martin
Craig Karpinski
Dan Faur
*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
Interval 6 was pumped as per design.
32# Hybor G Volume:
Proppant in Formation:
Dart/Ball Early :
Average BH Pressure:
100M Pumped:
Pumps Ending Stage:
Conditioning Pad Volume:
Interval Status:
Average Visc:
Initial OA Pressure:
Start Date/Time:
Average Surface Pressure:
Max OA Pressure:
Spacer and Ball Drop Volume:
Pad Volume:
Wanli 16/20 Ceramic Pumped:
Pad Percentage Design
Average Temp:
Total Proppant Pumped* :
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Proppant Laden Fluid Volume:
End Date/Time:
Max Surface Pressure:
Max BH Pressure:
Max Proppant Concentration:
Pad Percentage Actual
Conoco Phillips 3S 606 Interval Summary 12
4/1/24 12:03
4/1/24 13:05
62 min
10.9 bpm
4,998 psi
6,814 psi
14 bbl
32.3 bpm
3,374 psi
5,075 psi
30.4 bpm
2,756 psi
2,668 psi
4,544 psi
2,054 hhp
527 psi
588 psi
6.83 ppg
5
5
32 %
31 %
27 cP
93 F
9.2
200,461 lbs
3,856 lbs
204,317 lbs
204,129 lbs
68,853 gal 1,639 bbls
7,731 gal 184 bbls
16,015 gal 381 bbls
44,110 gal 1,050 bbls
997 gal 24 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Status:
Interval 7 was pumped as per design.
Fluid Summary (by fluid description)
Spacer and Ball Drop Volume:
32# Hybor G Volume:
Chad Burkett
Willie Martin
Dan Faur
Fluid Summary (by stage description)
Craig Karpinski
Interval Summary
3S-606 - Torok - Interval 7
End Date/Time:
Dart/Ball Early :
Pad Percentage Actual
Initial OA Pressure:
Pad Percentage Design
Pumps Starting Stage:
Proppant Summary
Pumps Ending Stage:
100M Pumped:
Average Temp:
Average Missile HHP:
Average pH:
Max Proppant Concentration:
Pad Volume:
Pump Time:
Max Rate:
Initial BH Pressure (Breakdown):
Start Date/Time:
Conditioning Pad Volume:
Total Proppant Pumped* :
Max Surface Pressure:
Max BH Pressure:
Average Rate:
Average Missile Pressure:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Max OA Pressure:
Average BH Pressure:
Average Surface Pressure:
Wanli 16/20 Ceramic Pumped:
Average Visc:
*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.
Proppant in Formation:
Proppant Laden Fluid Volume:
Conoco Phillips 3S 606 Interval Summary 13
4/1/24 13:05
4/1/24 14:02
57 min
10.3 bpm
4,750 psi
6,842 psi
12 bbl
32.5 bpm
3,328 psi
3,426 psi
30.3 bpm
2,598 psi
2,503 psi
4,404 psi
1,929 hhp
532 psi
594 psi
8.06 ppg
4
4
32 %
30 %
28 cP
95 F
9.3
199,112 lbs
4,205 lbs
203,317 lbs
203,229 lbs
63,948 gal 1,523 bbls
7,772 gal 185 bbls
13,894 gal 331 bbls
41,323 gal 984 bbls
959 gal 23 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Status:
Willie Martin
Chad Burkett
Conditioning Pad Volume:
Average Missile HHP:
Fluid Summary (by stage description)
Wanli 16/20 Ceramic Pumped:
100M Pumped:
Fluid Summary (by fluid description)
Pad Percentage Actual
Pad Percentage Design
Proppant in Formation:
Craig Karpinski
Dan Faur
Pumps Starting Stage:
*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.
Average Rate:
Max Proppant Concentration:
Average BH Pressure:
Average pH:
Average Surface Pressure:
Pad Volume:
Interval Summary
3S-606 - Torok - Interval 8
Max Rate:
Initial Surface Pressure (Breakdown):
Start Date/Time:
Initial BH Pressure (Breakdown):
32# Hybor G Volume:
Initial Rate (Breakdown):
Max Surface Pressure:
Max BH Pressure:
Dart/Ball Early :
End Date/Time:
Pump Time:
Spacer and Ball Drop Volume:
Initial OA Pressure:
Average Missile Pressure:
Max OA Pressure:
Pumps Ending Stage:
Average Visc:
Total Proppant Pumped* :
Average Temp:
Proppant Summary
At the end of the 5.5 ppg sand stage, the crew had to swap movers which caused sand
concentration to drop before it was quickly brought back up. The interval was pumped to
completion.
Proppant Laden Fluid Volume:
Conoco Phillips 3S 606 Interval Summary 14
4/1/24 14:02
4/1/24 15:01
59 min
10.3 bpm
4,951 psi
6,875 psi
14 bbl
32.9 bpm
3,347 psi
4,976 psi
31.1 bpm
2,650 psi
2,575 psi
4,422 psi
2,019 hhp
580 psi
612 psi
7.62 ppg
4
4
32 %
32 %
26 cP
86.8 F
9.3
3296 psi
0.638 psi/ft
3207 psi
3159 psi
3109 psi
194,890 lbs
4,182 lbs
199,072 lbs
199,052 lbs
65,510 gal 1,560 bbls
10,776 gal 257 bbls
7,837 gal 187 bbls
15,916 gal 379 bbls
41,757 gal 994 bbls
10,776 gal 257 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Start Date/Time:
End Date/Time:
Pump Time:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Willie Martin
Craig Karpinski
Average Temp:
Max Proppant Concentration:
Pumps Starting Stage:
Average Surface Pressure:
Final 5 min:
Chad Burkett
Flush Volume:
32# Hybor G Volume:
32# Linear Volume:
3S-606 - Torok - Interval 9
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Interval Summary
ISDP:
Proppant Summary
Wanli 16/20 Ceramic Pumped:
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Average pH:
Average Visc:
Pad Percentage Design
Total Proppant Pumped* :
Max Surface Pressure:
Max BH Pressure:
Initial Rate (Breakdown):
Proppant in Formation:
Max Rate:
Final 15 min:
Pumps Ending Stage:
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Dan Faur
Dart/Ball Early :
Average BH Pressure:
Average Missile Pressure:
Max OA Pressure:
During 4.0 ppg, proppant concentration dropped because the crew had to swap movers. The
remainder of the stage was pumped as per design.
Interval Status:
Pad Volume:
Average Missile HHP:
Initial OA Pressure:
Average Rate:
Final Fracture Gradient:
100M Pumped:
Final 10 min:
Pad Percentage Actual
Conoco Phillips 3S 606 Interval Summary 15
Event Log
Sieve Analysis
Fann 15 Minute
Field Break Test
Real Time QC
Well Summary
Stimulation Treatment
Appendix
Chemical Summary
Planned Design
Water Straps
Water Analysis
Prepared for: Manabu Nozaki
April 1, 2024
Harrison Bay County, AK
Conoco Phillips
3S-606
Intervals 1-9
Torok Formation
API: 50-103-20870
Conoco Phillips 3S 606 Appendix 68
Interval Date
Designed
Proppant
(lbs)
Proppant in
Formation
(lbs)
Designed Fluid
(bbl)
Vol Clean
(bbl)
Vol Slurry
(bbl)
Pad
Percentage
Design
Pad
Percentage
Actual
Proppant
Aggressivness
(lb/bbl Clean)
Top
Packer
(ft)
Bottom
Packer
(ft)
Fluid
System
1 3/31/2024 204,000 206,764 1,902 2334 2,553 32.0 31 192 19573 20102 Hybor
2 3/31/2024 204,000 200,935 2,556 2652 2,865 32.0 31 187 19051 19551 Hybor
3 3/31/2024 204,000 206,482 1,598 1677 1,896 32.0 31 188 18529 19030 Hybor
4 3/31/2024 204,000 203,886 1,895 1975 2,192 32.0 31 184 18007 18507 Hybor
5 4/1/2024 204,000 202,639 1,852 1908 2,124 32.0 31 188 17486 17986 Hybor
6 4/1/2024 204,000 198,435 1,598 1663 1,874 32.0 31 182 16964 17465 Hybor
7 4/1/2024 204,000 204,129 1,598 1639 1,856 32.0 31 191 16445 16943 Hybor
8 4/1/2024 204,000 203,229 1,598 1523 1,739 32.0 30 202 15923 16424 Hybor
9 4/1/2024 204,000 199,052 1,856 1831 2,043 32.0 32 196 15403 15902 Hybor
3S 606 Interval Highlights
Conoco Phillips 3S 606 Well Summary 69
CustomerConoco PhillipsFormationTorokLease3S606API5010320870DateInterval SummaryChemicalsCL28M Losurf300D MO67 Cat3 WG36 OPTIFLOIII OPTIFLOII BE6(gal) (gal) (gal) (gal) (lbs) (lbs) (lbs) (lbs)Prime Up0 0 0 0 0 0 0 01215 105 60 48 2881 150 150 752218 127 60 40 2872 150 150 03199 66 47 42 1767 125 125 04168 72 48 50 2378 125 125 605155 85 45 50 2473 230 230 06135 85 45 50 1796 130 130 07150 70 50 45 2125 130 130 08135 65 40 35 1817 120 120 09135 75 40 40 2186 140 140 0Total 1510 750 435 400 20295 1300 1300 135w/o Prime Up1510 750 435 400 20295 1300 1300 135Interval3/31/2024Dry AdditivesLiquid AdditivesConoco Phillips3S606 Chemical Summary 70
Interval 1Torok@ 19829.46 - 19833.32 ft 139.3 °FInterval 2Torok@ 19299.01 - 19302.87 ft 139.3 °FInterval 3Torok@ 18777.47 - 18781.33 ft 139.2 °FInterval 4Torok@ 18255.02 - 18258.88 ft 139.2 °F
Interval 9Torok@ 15652.12 - 15655.98 ft 139.1 °FInterval 5Torok@ 17733.53 - 17737.39 ft 139.2 °FInterval 6Torok@ 17213.04 - 17216.9 ft 139.1 °FInterval 7Torok@ 16692.72 - 16696.58 ft 139 °FInterval 8Torok@ 16170.9 - 16174.76 ft 139.1 °F
Customer:
Well:
Date:
Formation:
SO#:
Tank Type Water Source Inches Gallons Barrels Temperature (°F) Inches Gallons Barrels
1 Tiger CPF3 110 20,160 480 116 30 3,360 80
2 Tiger CPF3 112 20,160 480 117 30 3,360 80
3 Tiger CPF3 117 20,160 480 115 30 3,360 80
4 Atigan CPF3 97 18,401 438 118 10 1,627 39
5 Atigan CPF3 96 18,208 434 118 10 1,627 39
6 Wichita CPF3 103 20,790 495 125 10 1,890 45
7 Wichita CPF3 102 20,580 490 125 10 1,890 45
8 Wichita CPF3 102 20,580 490 122 10 1,890 45
9 Wichita CPF3 104 21,000 500 122 10 1,890 45
10 Wichita CPF3 102 20,580 490 128 50 9,660 230
11 Wichita CPF3 97 19,530 465 127 93 18,690 445
12 Wichita CPF3 108 21,000 500 104 92 18,480 440
13 Wichita CPF3 103 20,790 495 130 98 19,530 465
14 Wichita CPF3 105 21,000 500 118 102 20,580 490
15 Wichita CPF3 100 20,160 480 132 45 8,610 205
16 Wichita CPF3 102 20,580 490 138 45 8,610 205
17 Atigan CPF3 102 19,368 461 135 10 1,627 39
18 Atigan CPF3 103 19,562 466 103 10 1,627 39
19 Wichita CPF3 103 20,790 495 126 10 1,890 45
20 Wichita CPF3 107 21,000 500 133 10 1,890 45
21 Wichita CPF3 102 20,580 490 126 10 1,890 45
22 Wichita CPF3 101 20,370 485 126 10 1,890 45
23 Wichita CPF3 100 20,160 480 125 10 1,890 45
24 Wichita CPF3 101 20,370 485 126 10 1,890 45
25 Wichita CPF3 102 20,580 490 126 10 1,890 45
Flow Rate Stop Flowing
0
Gallons Barrels Gallons Barrels Gallons Barrels
506,459 12,059 141,538 3,370 364,920 8,689
General Beginning Strap Ending Strap
Location Summary
Starting Volume Ending Volume Total Used
On the Fly Load Summary
Start flowing
Conoco Phillips
3S 606
3/31/2204
Torok
909244035
Date
31 Mar No on the fly flowing
Flowing Temp
Conoco Phillips 3S 606 Water Straps 3 31 74
Customer:
Well:
Date:
Formation:
SO#:
Tank Type Water Source Inches Gallons Barrels Temperature (°F) Inches Gallons Barrels
1 Tiger CPF3 30 0 0 30 0 0
2 Tiger CPF3 30 0 0 30 0 0
3 Tiger CPF3 30 0 0 30 0 0
4 Atigan CPF3 10 1,627 39 10 1,627 39
5 Atigan CPF3 10 1,627 39 10 1,627 39
6 Wichita CPF3 98 19,740 470 10 1,890 45
7 Wichita CPF3 98 19,740 470 10 1,890 45
8 Wichita CPF3 98 19,740 470 10 1,890 45
9 Wichita CPF3 98 19,740 470 111 10 1,890 45
10 Wichita CPF3 98 19,740 470 110 37 7,014 167
11 Wichita CPF3 97 19,530 465 110 37 7,014 167
12 Wichita CPF3 94 18,900 450 88 37 7,014 167
13 Wichita CPF3 20 3,780 90 37 7,014 167
14 Wichita CPF3 98 19,740 470 105 37 7,014 167
15 Wichita CPF3 99 19,950 475 110 37 7,014 167
16 Wichita CPF3 99 19,950 475 112 10 1,890 45
17 Wichita CPF3 100 20,160 480 109 10 1,890 45
18 Wichita CPF3 101 20,370 485 110 10 1,890 45
19 Wichita CPF3 99 19,950 475 111 10 1,890 45
20 Wichita CPF3 98 19,740 470 107 10 1,890 45
21 Wichita CPF3 100 20,160 480 110 10 1,890 45
22 Wichita CPF3 99 19,950 475 111 10 1,890 45
23 Wichita CPF3 99 19,950 475 110 10 1,890 45
24 Wichita CPF3 100 20,160 480 110 10 1,890 45
25 Wichita CPF3 99 19,950 475 110 10 1,890 45
Flow Rate Stop Flowing
5 bpm 14:00
Gallons Barrels Gallons Barrels Gallons Barrels
384,194 9,147 71,798 1,709 375,396 8,938
Conoco Phillips
3S 606
3/31/2204
Torok
909244035
General Beginning Strap Ending Strap
On the Fly Load Summary
Date Start flowing Estimated Volume
1 Apr 9:00 1500
Location Summary
Starting Volume Ending Volume Total Used
Conoco Phillips 3S 606 Water Straps 4 1 75
Specific
Gravity
Testing
Temperature
Dissolved Iron
(Fe2+)
Chloride
(Cl )
Sulfate
(SO42 )
Calcium
(Ca2+)
Magnesium
(Mg2+)
Total
Hardness
Linear
Viscosity
Water
pH
Gel
pH
Post Crosslink
pH Crosslink Bacteria
°F mg/L mg/L mg/L mg/L mg/L mg/L cP (Y/N) BQ Value
Tank #
H2S
present?
Y/N
Hydrometer Digital
Thermometer Strip Strip Strip Titration
Total Hardness
MinusCalcium Titration FANN 35 Probe Probe Probe Mycometer
1 N 1.026 75.0 2 38,030 1,600 2,400 800 3,200 194
2 N 1.026 75.0 2 20,830 1,200 2,400 0 2,400 102
3 N 1.026 75.0 2 28,960 1,200 2,000 0 2,000 141
4 N 1.028 78.0 2 24,480 1,200 2,400 800 3,200 78
5 N 1.028 78.0 2 28,960 1,200 2,400 800 3,200 96
6 N 1.026 89.0 5 34,600 1,200 2,000 800 2,800 2,106
7 N 1.026 89.0 5 38,030 1,200 1,800 200 2,000 171
8 N 1.026 88.0 5 31,600 1,200 1,800 200 2,000 147
9 N 1.026 89.0 5 34,600 1,200 2,000 400 2,400 327
10 N 1.026 90.0 5 38,030 1,200 2,000 800 2,800 1,858
11 N 1.026 89.0 5 26,600 1,200 2,600 0 2,600 120
12 N 1.026 75.0 2 17,790 1,200 2,400 200 2,600 229
13 N 1.026 75.0 2 28,960 1,200 2,400 400 2,800 156
14 N 1.024 120.0 5 20,830 1,200 2,400 600 3,000 630
15 N 1.022 126.0 2 26,600 1,200 2,600 200 2,800 249
16 N 1.024 95.0 2 38,030 1,200 2,400 800 3,200 322
17 N 1.026 85.0 2 38,030 1,200 2,600 600 3,200 370
18 N 1.028 100.0 5 38,030 1,200 2,400 800 3,200 106
19 N 1.026 89.0 2 22,570 1,200 2,400 800 3,200 176
20 N 1.024 89.0 2 26,600 1,200 3,000 200 3,200 125
21 N 1.026 89.0 2 20,830 1,200 2,400 600 3,000 60
22 N 1.024 90.0 2 22,570 1,200 2,400 400 2,800 85
23 N 1.026 90.0 2 20,830 1,200 2,600 400 3,000 105
24 N 1.024 89.0 2 26,600 1,200 2,400 800 3,200 141
25 N 1.024 87.0 2 22,570 1,200 2,800 400 3,200 93
Average 1.027 78.3 3 29,310 1267 2,267 533 2,800 29.5 7.10 7.40 9.45 453
Maximum 1.028 89.0 5 38,030 1,600 2,400 800 3,200 31.0 7.30 7.50 9.50 2,106
Minimum 1.026 75.0 2 20,830 1,200 2,000 0 2,000 28.0 6.90 7.30 9.40 78
Range 0.002 14.0 3 17,200 400 400 800 1,200 3.0 0.40 0.20 0.10 2,028
Alaska District Field QC
PrejobWater Analysis on Location
Company:Conoco Phillips
Well Name:3S 606
Water Source:CPF 3
31.0 7.30 7.50 9.50 Y
28.0 6.90 7.30 9.40 Y
28.0 7.10 7.20 9.30 Y
31.0 7.20 7.30 9.40 Y
28.0 7.30 7.50 9.20 Y
28.0 7.20 7.50 9.20 Y
Conoco Phillips 3S 606 Water Analysis 3 31 76
Specific
Gravity
Testing
Temperature
Dissolved Iron
(Fe2+)
Chloride
(Cl )
Sulfate
(SO42 )
Calcium
(Ca2+)
Magnesium
(Mg2+)
Total
Hardness
Linear
Viscosity
Water
pH
Gel
pH
Post Crosslink
pH Crosslink Bacteria
°F mg/L mg/L mg/L mg/L mg/L mg/L cP (Y/N) BQ Value
Tank #
H2S
present?
Y/N
Hydrometer Digital
Thermometer Strip Strip Strip Titration
Total Hardness
MinusCalcium Titration FANN 35 Probe Probe Probe Mycometer
9 N 1.026 85.0 2 26,600 1,200 2,400 600 3,000 417
10 N 1.026 85.0 2 24,480 1,200 2,400 600 3,000 595
11 N 1.026 85.0 2 24,480 1,200 2,600 600 3,200 1,104
12 N 1.026 75.0 2 17,790 1,200 2,400 200 2,600 183
13 N 1.026 75.0 2 28,960 1,200 2,400 400 2,800 156
14 N 1.024 120.0 5 20,830 1,200 2,400 600 3,000 630
15 N 1.022 126.0 2 26,600 1,200 2,600 200 2,800 249
16 N 1.024 95.0 2 38,030 1,200 2,400 800 3,200 322
17 N 1.026 85.0 2 38,030 1,200 2,600 600 3,200 370
18 N 1.026 104.1 2 28,960 1,200 2,800 200 3,000 326
19 N 1.024 100.5 2 22,570 1,200 2,600 600 3,200 859
20 N 1.026 101.4 2 20,830 1,200 2,400 1,000 3,400 2,528
21 N 1.027 100.4 2 26,600 1,200 2,800 400 3,200 650
22 N 1.026 98.0 2 24,480 1,200 2,600 600 3,200 278
23 N 1.027 96.5 2 22,570 1,200 2,600 600 3,200 49
24 N 1.025 98.5 2 26,600 1,200 2,400 800 3,200 62
25 N 1.026 94.1 2 26,600 1,200 2,800 400 3,200 24
Average 1.025 95.6 2 26177 1200 2541 541 3082 28.0 7.1 7.4 9.3 518
Maximum 1.027 126.0 5 38030 1200 2800 1000 3400 29.0 7.2 7.6 9.4 2528
Minimum 1.022 75.0 2 17790 1200 2400 200 2600 27.0 7.1 7.2 9.2 24
Range 0.005 51.0 3 20240 0 400 800 800 2.0 0.1 0.4 0.2 2504
Alaska District Field QC
PrejobWater Analysis on Location
Company:Conoco Phillips
Well Name:3S 606
Water Source:CPF 3
28.0 7.10 7.20 9.30 Y
27.0 7.20 7.60 9.40 Y
28.0 7.10 7.40 9.40 Y
29.0 7.10 7.30 9.20 Y
Conoco Phillips 3S 606 Water Analysis 4 1 77
Linear Linear XL XL Lip Linear Linear XL XL Lip
Interval Stage Visc pH Temp °F pH Time Interval Stage Visc pH Temp °F pH Time
1 Pad 25 8.4 95 9.1 1 8 Pad
.25# 27 8.6 101 9.1 0.5 28 Avg Linear Visc .25# 29 8.4 95 9.3 1 28 Avg Linear Visc
1# 27 8.3 95 9.2 1.5 94.2 Avg XLTemp 1# 95.0 Avg XLTemp
2# 9.2 Avg XL pH 2# 29 8.4 101 9.2 1 9.3 Avg XL pH
3# 3#
4# 28 8.3 92 9.2 1 4#
4.5# 4.5# 28 8.6 95 9.2 1
5# 5#
5.5# 29 8.3 90 9.2 1.5 5.5# 28 8.2 88 9.3 1
6# 6#
6.5# 6.5# 27 8.2 96 9.3 1
7# 29 8.4 92 9.2 1.5 7#
2 Pad 25 8.5 85 9.2 2 9 Pad
.25# 25 8.4 100 9.2 1 26 Avg Linear Visc .25# 26 8.1 95 9.1 1 26 Avg Linear Visc
1# 94.8 Avg XLTemp 1# 86.8 Avg XLTemp
2# 26 8.1 95 9 1 9.1 Avg XL pH 2# 26 8.1 85 9.3 1 9.3 Avg XL pH
3# 3#
4# 26 8.2 100 9 1 4#
4.5# 4.5# 26 8.3 85 9.3 1
5# 26 8.5 95 9 1 5#
5.5# 5.5# 26 8.4 82 9.4 1
6# 26 8.4 94 9 1 6#
6.5# 6.5#
7# 7#
3 Pad 26 8.5 102 9 1
.25# 23 Avg Linear Visc
1# 96.7 Avg XLTemp
2# 18 8.6 95 9 5 9.0 Avg XL pH
3#
4# 21 8.6 95 9.1 5
4.5#
5# 21 8.7 98 9 5
5.5#
6# 25 8.4 95 9 1
6.5#
7# 25 8.3 95 9 1
4 Pad 30 8.6 88 9.3 1
.25# 30 Avg Linear Visc
1# 86.2 Avg XLTemp
2# 9.3 Avg XL pH
3# 33 8.6 90 9.4 1
4#
4.5#
5# 32 8.5 85 9.3 1
5.5#
6# 31 8.6 85 9.3 1
6.5#
7# 26 8.5 83 9.3 1
5 Pad 26 8.3 80 9.1 1
.25# 25 8.3 95 9.2 1 27 Avg Linear Visc
1# 88.2 Avg XLTemp
2# 31 8.2 95 9.2 1 9.2 Avg XL pH
3#
4# 27 8.2 85 9.3 2
4.5#
5# 27 8.2 86 9.4 1
5.5#
6# 26 8.3 88 9.2 1
6.5#
7#
6 Pad
.25# 27 8.3 97 9.1 3 27 Avg Linear Visc
1# 90.6 Avg XLTemp
2# 26 8.4 95 9 1 9.0 Avg XL pH
3#
4#
4.5# 28 8.5 90 9 1
5#
5.5# 26 8.6 86 9.1 1
6#
6.5# 27 8.6 85 9 1
7#
7 Pad
.25# 27 8.4 100 9.2 1 27 Avg Linear Visc
1# 93.0 Avg XLTemp
2# 27 8.4 95 9.2 1 9.2 Avg XL pH
3#
4# 27 8.3 95 9.2 1
4.5#
5# 28 8.3 90 9.3 1
5.5#
6#
6.5# 28 8.4 85 9.3 1
7#
Customer:ConocoPhillips Alaska, Inc.
Wellname & #:3S - 606
Date:March 31, 2024
Comments Comments
Conoco Phillips 3S 606 Real TimeQC 78
Seq No. Time Activity Code Comment Job Slurry Vol Treating Pressure Treating Pressure @Pump Slurry Rate Tubing Gauge BH Pres
1 06:33:29 (03/30/24) Start Job Starting Job 0 0 0 0 0
1 06:33:29 (03/30/24) Next Treatment Treatment Interval 1 0 0 1 0 0
2 8:25:24 Other Pre Job Safety Meeting 0 4 3774 0 2633
3 8:44:28 Other Bring on Brine 0 0 2 0 2633
4 8:51:34 Other Prime Pumps 0 75 83 0 2633
5 9:01:41 Other Perform Loop Test 0 153 151 0 2633
6 9:27:36 Pressure Test ePRV Primary Tubing 0 1450 450 0 2633
7 9:29:58 Pressure Test ePRV Primary IA 0 1416 1020 0 2633
8 9:32:36 Pressure Test ePRV Secondary Tubing 0 1338 702 0 2633
9 9:34:05 Pressure Test ePRV Secondary IA 0 1815 1201 0 2633
2 9:36:45 Next Stage Prime Up and Pressure Test 0 2021 97 0 2633
10 9:38:03 Pressure Test Pressure Test Global 0 2004 1072 0 2633
11 9:38:14 Pressure Test Pressure Test Local 0 2002 1061 0 2633
12 9:43:28 Pressure Test Pressure Test Max 0 8971 8928 0 2633
13 9:48:27 Pressure Test Pressure Test Pass 0 8787 8756 0 2632
14 10:15:26 Other Bring Tank Water 0 72 94 0 2785
4 10:17:54 Next Stage DFIT 0 1002 1032 0 2786
15 10:18:51 Open Well Open Well 0 630 590 0 2797
16 10:20:20 Other Alpha Sleeve Shift 3.88 6413 6418 9.7 8398
17 10:21:11 Other Start DFIT 11 1516 1576 9.4 3547
18 10:26:36 ISIP ISIP 64.21 845 356 0.2 3162
19 10:31:34 Shut In Pressure @ 5 Minutes Shut In Pressure @ 5 Minutes 64.21 539 158 0 3075
20 10:36:34 Shut In Pressure @ 10 Minutes Shut In Pressure @ 10 Minutes 64.21 453 61 0 2956
21 10:41:35 Shut In Pressure @ 15 Minutes Shut In Pressure @ 15 Minutes 64.21 410 25 0 2808
22 11:12:21 Other Pulling on Chemicals 64.21 303 21 0 2544
5 11:59:04 Next Stage Shut In 64.8 56 66 0 2376
23 5:46:31 End Job Ending Job 64.8 64 8 0 2233
Event Log 3 30
Conoco Phillips 3S 606 Event Log 3 30 79
Seq No. Time Activity Code Comment Job Slurry Vol Treating Pressure Treating Pressure@Pump Slurry Rate Tubing Gauge BH Pres
1 06:22:38(03/31/24) Start Job Starting Job 0 0 0 0 0
1 06:22:38(03/31/24) Next Treatment Treatment Interval 1 0 0 0 0 0
2 6:50:21 Pre Job Safety Meeting Pre Job Safety Meeting 0 25 30 0 2230
3 7:04:15 Prime Pumps Prime Pumps 0 38 53 0 2229
4 7:17:17 Other Acid Pumper Pressure Tested 0 14 20 0 2228
5 7:20:01 PressureTest ePRV Primary Tubing 0 1177 978 0 2228
6 7:21:35 PressureTest ePRV Primary IA 0 1187 961 0 2228
7 7:23:15 PressureTest ePRV Secondary Tubing 0 927 991 0 2228
8 7:24:18 PressureTest ePRV Secondary IA 0 925 989 0 2228
9 7:26:44 PressureTest Pressure Test Global 0 611 112 0 2228
10 7:26:53 PressureTest Pressure Test Locals 0 611 111 0 2228
11 7:29:46 PressureTest Pressure Test Max 0 9327 9260 0 2228
12 7:34:44 PressureTest Pressure Test Pass 0 9255 9036 0 2228
13 7:37:23 Other Bring on Chemicals 0 747 171 0 2227
14 7:45:29 Other Bring on Blender Chemicals 0 3 163 0 2228
5 7:51:27 Next Stage Shut In 0 15 158 0 2292
15 8:11:53 Other Troubleshooting LA 4 Micromotion 0 24 141 0 2266
6 8:39:32 Next Stage Step Rate Test 0 395 380 0 2281
16 8:40:08 Open Well Open Well 0 308 261 0 2287
17 8:40:27 Start Step Rate Start Step Rate 0.05 467 552 0.7 2538
18 8:41:54 Other Step Rate Test 1stStep 2.53 1137 1178 2 3159
19 8:42:44 Other Step Rate Test 2nd Step 4.61 1197 1244 2.8 3223
20 8:43:16 Other Step Rate Test 3rd Step 6.44 1259 1316 3.8 3278
21 8:44:28 Other Step Rate Test 4th Step 11.94 1286 1327 4.9 3302
22 8:45:38 Other Step Rate Test 5th Step 18.11 1313 1360 5.8 3358
23 8:46:41 Other Step Rate Test 6th Step 24.95 1380 1432 7 3437
24 8:47:40 Other Step Rate Test 7th Step 32.73 1588 1665 8.9 3606
25 8:48:43 Other Step Rate Test 8th Step 42.75 1747 1825 10 3720
26 8:49:47 Other Step Rate Test 9th Step 54.15 1903 2011 11 3845
27 8:50:46 Other Step Rate Test 10th Step 65.44 2028 2232 11.9 3959
28 8:51:46 Other Step Rate Test 11th Step 78.1 2136 2329 12.9 4074
29 8:52:42 Other Step Rate Test 12th Step 90.44 2230 2416 13.7 4190
7 8:53:22 Next Stage Establish StableFluid 99.99 2328 2518 14.6 4312
30 8:53:23 Other Step Rate Test 13th Step 99.99 2328 2518 14.6 4312
8 9:05:19 Next Stage Pad 278.89 1849 1971 15 3891
31 9:05:20 Start Pad Start Pad 279.14 1848 1971 15 3892
32 9:07:04 Alarm Delta Stage At Top Perf = 6 318.66 3177 3452 30.2 4938
33 9:10:12 Alarm Delta Stage At Top Perf = 7 418.08 2817 3055 32.1 4555
9 9:11:50 Next Stage Conditioning Pad 470.4 2716 2946 32 4473
34 9:15:48 Alarm Delta Stage At Top Perf = 8 597.61 2713 2931 32 4465
35 9:21:47 Alarm Delta Stage At Top Perf = 9 789.03 2805 3005 31.9 4577
10 9:23:49 Next Stage 1.0 ppg 16/20Proppant 853.52 2807 2995 31.9 4578
36 9:25:10 Other Patina Tracer Dropped 897.02 2803 2984 31.8 4576
11 9:25:22 Next Stage 2.0 ppg 16/20Proppant 902.91 2793 2981 31.8 4570
12 9:27:19 Next Stage 3.0 ppg 16/20Proppant 965.3 2723 2936 32 4575
13 9:30:41 Next Stage 4.0 ppg 16/20Proppant 1072.98 2596 2823 32 4586
37 9:33:48 Alarm Delta Stage At Top Perf = 10 1172.45 2709 2927 31.9 4740
14 9:34:58 Next Stage 4.5 ppg 16/20Proppant 1209.52 2769 2995 32 4817
38 9:35:20 Alarm Delta Stage At Top Perf = 11 1221.87 2790 3016 31.9 4837
39 9:37:18 Alarm Delta Stage At Top Perf = 12 1284.23 2858 3092 32 4941
15 9:39:27 Next Stage 5.0 ppg 16/20Proppant 1353.12 2912 3147 32 5009
40 9:40:39 Alarm Delta Stage At Top Perf = 13 1391.89 2945 3202 32 5055
16 9:44:22 Next Stage 5.5 ppg 16/20Proppant 1510.43 3028 3269 32 5133
41 9:44:55 Alarm Delta Stage At Top Perf = 14 1528.2 3041 3278 32 5150
42 9:49:25 Alarm Delta Stage At Top Perf = 15 1671.73 3110 3343 32 5233
17 9:49:26 Next Stage 6.0 ppg 16/20Proppant 1672.27 3111 3342 32 5237
43 9:54:20 Alarm Delta Stage At Top Perf = 16 1828.63 3202 3425 31.9 5353
18 9:54:58 Next Stage 6.5 ppg 16/20Proppant 1849.07 3221 3454 32 5382
19 9:58:54 Next Stage 7.0 ppg 16/20Proppant 1974.94 3338 3565 32 5489
44 9:59:25 Alarm Delta Stage At Top Perf = 17 1991.11 3347 3594 32 5506
45 10:01:10 Other Shut Mover Gate 2047.08 3397 3640 32 5566
20 10:03:40 Next Stage Spacer & Ball Drop 2127.61 3558 3792 32.3 5627
46 10:04:50 Drop Ball Drop Ball 2 2164.96 3714 3950 32 5632
47 10:04:55 Alarm Delta Stage At Top Perf = 18 2167.65 3752 3983 32 5630
2 10:05:00(03/31/24) Next Treatment Treatment Interval 2 2170.32 3898 4133 32 5768
48 10:05:01 Start Minifrac Start Minifrac 2170.32 3912 4152 32 5768
1 10:05:01 Next Stage Minifrac Treatment 2170.85 3913 4153 32 5768
49 10:08:33 Alarm Delta Stage At Top Perf = 19 2284.04 3657 3848 32 5387
50 10:12:55 Other Slow Down For Ball 2 2423.88 2370 2504 31.8 4381
51 10:13:48 Alarm Delta Stage At Top Perf = 20 2436.95 1544 1602 10.3 3694
52 10:14:11 Ball on Seat Ball 2 on Seat 2440.71 1573 1632 10.1 3708
53 10:14:30 Break Formation Break Formation 2443.94 4658 4686 10 6807
54 10:17:18 Alarm Delta Stage At Top Perf = 1 2479.96 2234 2418 22.4 4137
2 10:21:55 Next Stage Minifrac Displacement 2622.82 2656 2853 32 4390
55 10:31:36 Alarm Delta Stage At Top Perf = 2 2932.66 3060 3281 31.9 4612
56 10:31:54 ISIP ISIP 2939.83 1039 412 12.4 3210
3 10:35:23 Next Stage Shut In 2940.75 874 353 0 3187
57 10:36:55 Shut In Pressure @ 5 Minutes Shut In Pressure @ 5 Minutes 2940.75 792 267 0 3182
58 10:41:54 Shut In Pressure @10 Minutes Shut In Pressure @10 Minutes 2940.75 493 66 0 3168
59 10:46:53 Shut In Pressure @15 Minutes Shut In Pressure @15 Minutes 2940.75 202 54 0 3158
60 11:21:44 Open Well Open Well 2940.75 818 837 0 3059
4 11:21:54 Next Stage Establish StableFluid 2940.75 812 833 0 3059
5 11:37:43 Next Stage Pad 3169.55 1629 1726 15.9 3697
61 11:37:44 Start Pad Start Pad 3169.82 1633 1726 15.9 3701
62 11:40:53 Alarm Delta Stage At Top Perf = 4 3250.53 2793 3021 32 4527
6 11:44:24 Next Stage Conditioning Pad 3363.12 2605 2810 32.1 4349
63 11:46:38 Other Drop Rate on Pump 621 3434.79 2601 2805 32.1 4356
64 11:47:49 Other 261 Brought Back Up 3466.8 2092 2247 24.6 4022
65 11:48:17 Alarm Delta Stage At Top Perf = 5 3479.47 2617 2833 30.8 4428
66 11:54:19 Alarm Delta Stage At Top Perf = 6 3672.93 2665 2873 32.1 4436
7 11:56:37 Next Stage 1.0 ppg 16/20Proppant 3746.3 2662 2840 32 4425
8 11:58:31 Next Stage 2.0 ppg 16/20Proppant 3807.27 2617 2806 31.8 4421
9 12:00:29 Next Stage 3.0 ppg 16/20Proppant 3869.2 2571 2778 31.8 4443
10 12:03:49 Next Stage 4.0 ppg 16/20Proppant 3975.97 2534 2745 32 4494
67 12:06:19 Alarm Delta Stage At Top Perf = 7 4055.94 2591 2815 32 4610
11 12:08:09 Next Stage 4.5 ppg 16/20Proppant 4113.97 2672 2876 32 4706
68 12:08:13 Alarm Delta Stage At Top Perf = 8 4116.66 2676 2888 32 4708
69 12:10:10 Alarm Delta Stage At Top Perf = 9 4179.01 2774 2981 32 4805
12 12:12:32 Next Stage 5.0 ppg 16/20Proppant 4254.17 2852 3054 31.9 4912
70 12:13:31 Alarm Delta Stage At Top Perf = 10 4285.84 2889 3087 31.9 4939
13 12:17:28 Next Stage 5.5 ppg 16/20Proppant 4411.86 2957 3171 32 5037
71 12:17:50 Alarm Delta Stage At Top Perf = 11 4423.68 2963 3161 32 5054
72 12:22:14 Alarm Delta Stage At Top Perf = 12 4563.86 3088 3291 31.9 5178
14 12:22:38 Next Stage 6.0 ppg 16/20Proppant 4576.62 3107 3311 31.9 5202
73 12:27:10 Alarm Delta Stage At Top Perf = 13 4721.54 3186 3414 32 5327
15 12:28:17 Next Stage 6.5 ppg 16/20Proppant 4756.68 3194 3408 32 5365
74 12:31:05 Other Load Ball 3 4845.84 3291 3528 32 5465
16 12:32:10 Next Stage 7.0 ppg 16/20Proppant 4880.58 3343 3576 32.1 5502
75 12:32:19 Alarm Delta Stage At Top Perf = 14 4885.93 3339 3576 32.1 5508
17 12:36:19 Next Stage Spacer & Ball Drop 5013.63 3522 3801 32.3 5656
76 12:37:04 Drop Ball Drop Ball 3 5037.85 3696 3973 32.3 5670
3 12:37:05(03/31/24) Next Treatment Treatment Interval 3 5038.93 3701 3977 32.3 5672
1 12:37:06 Next Stage Pad 5039.47 3704 3979 32.3 5672
77 12:37:42 Alarm Delta Stage At Top Perf = 15 5058.84 3804 4043 32.3 5676
78 12:41:32 Alarm Delta Stage At Top Perf = 16 5182.52 3656 3815 32.3 5385
2 12:43:00 Next Stage Conditioning Pad 5229.93 3323 3535 32.4 5067
79 12:44:43 Other Slow Down For Ball 3 5285.02 808 879 23.2 3345
80 12:47:01 Ball on Seat Ball 3 on Seat 5309.98 1695 1749 10.1 3801
81 12:47:30 Break Formation Break Formation 5314.86 6687 6722 10 9145
82 12:47:34 Alarm Delta Stage At Top Perf = 17 5315.46 1593 1743 8.2 6125
83 12:50:02 Alarm Delta Stage At Top Perf = 1 5341.02 2618 2801 24.1 4459
84 12:56:06 Alarm Delta Stage At Top Perf = 2 5532.58 2869 3071 32 4566
3 12:58:42 Next Stage 1.0 ppg 16/20Proppant 5615.1 2843 3028 31.9 4534
4 13:00:13 Next Stage 2.0 ppg 16/20Proppant 5663.93 2750 2966 31.9 4490
5 13:02:17 Next Stage 3.0 ppg 16/20Proppant 5729.49 2662 2882 32 4497
6 13:05:41 Next Stage 4.0 ppg 16/20Proppant 5838.62 2493 2729 32 4499
85 13:08:08 Alarm Delta Stage At Top Perf = 3 5917.03 2547 2779 31.9 4583
86 13:09:40 Alarm Delta Stage At Top Perf = 4 5965.96 2667 2881 32 4711
87 13:11:43 Alarm Delta Stage At Top Perf = 5 6031.48 2811 3058 31.9 4865
7 13:12:54 Next Stage 4.5 ppg 16/20Proppant 6069.06 2896 3129 32 4952
88 13:15:07 Alarm Delta Stage At Top Perf = 6 6140.59 2977 3224 32 5077
8 13:16:21 Next Stage 5.0 ppg 16/20Proppant 6179.29 3006 3210 32 5108
9 13:20:24 Next Stage 5.5 ppg 16/20Proppant 6308.8 3034 3278 31.9 5127
89 13:22:20 Alarm Delta Stage At Top Perf = 7 6370.88 2994 3229 31.8 5142
10 13:25:30 Next Stage 6.0 ppg 16/20Proppant 6471.48 3139 3384 31.9 5232
90 13:25:48 Alarm Delta Stage At Top Perf = 8 6481.13 3163 3403 31.9 5253
91 13:29:52 Alarm Delta Stage At Top Perf = 9 6610.96 3336 3567 31.9 5458
11 13:30:59 Next Stage 6.5 ppg 16/20Proppant 6646.37 3369 3606 31.9 5519
12 13:34:54 Next Stage 7.0 ppg 16/20Proppant 6771.2 3371 3589 31.9 5503
92 13:34:57 Alarm Delta Stage At Top Perf = 10 6773.34 3377 3596 31.9 5505
13 13:39:12 Next Stage Spacer & Ball Drop 6908.31 3593 3838 32.1 5597
93 13:39:58 Other Drop Ball 4 6932.61 3759 3950 32.1 5630
4 13:40:00(03/31/24) Next Treatment Treatment Interval 4 6934.24 3760 3962 32.1 5636
1 13:40:01 Next Stage Pad 6934.78 3760 3967 32.1 5636
94 13:40:12 Alarm Delta Stage At Top Perf = 11 6940.7 3785 3978 32.1 5642
95 13:43:53 Alarm Delta Stage At Top Perf = 12 7058.18 3712 3836 32.1 5423
2 13:45:52 Next Stage Conditioning Pad 7121.14 3156 3339 30.8 4903
96 13:47:26 Other Slow Down For Ball 4 7169.38 2808 3014 31.5 4550
97 13:49:38 Ball on Seat Ball on Seat 7196.55 1638 1696 10.1 3736
98 13:49:59 Break Formation Break Formation 7200.12 5655 5707 10.1 7706
99 13:50:12 Alarm Delta Stage At Top Perf = 13 7202.49 4232 4260 10 6524
100 13:52:43 Alarm Delta Stage At Top Perf = 1 7228.54 5080 5144 13.2 7187
101 14:00:07 Alarm Delta Stage At Top Perf = 2 7415.8 4771 4953 32.1 6487
3 14:02:54 Next Stage 1.0 ppg 16/20Proppant 7504.94 3818 4009 32.1 5566
4 14:04:30 Next Stage 2.0 ppg 16/20Proppant 7556.08 3619 3791 32 5411
5 14:06:38 Next Stage 3.0 ppg 16/20Proppant 7623.7 3422 3604 31.9 5296
6 14:10:00 Next Stage 4.0 ppg 16/20Proppant 7732.03 3320 3492 31.9 5250
102 14:12:06 Alarm Delta Stage At Top Perf = 3 7799 3095 3280 31.9 5099
103 14:13:43 Alarm Delta Stage At Top Perf = 4 7850.45 3097 3281 31.9 5149
7 14:14:20 Next Stage 4.5 ppg 16/20Proppant 7869.76 3131 3310 31.9 5157
104 14:15:50 Alarm Delta Stage At Top Perf = 5 7918.04 3091 3277 31.9 5122
8 14:19:07 Next Stage 5.0 ppg 16/20Proppant 8022.11 3055 3233 31.9 5105
105 14:19:13 Alarm Delta Stage At Top Perf = 6 8025.86 3047 3238 31.9 5109
106 14:23:32 Alarm Delta Stage At Top Perf = 7 8163.61 3034 3234 31.9 5117
9 14:24:02 Next Stage 5.5 ppg 16/20Proppant 8179.17 3055 3251 31.9 5125
107 14:28:19 Alarm Delta Stage At Top Perf = 8 8316.24 3063 3260 32 5169
10 14:29:08 Next Stage 6.0 ppg 16/20Proppant 8342.08 3075 3287 32 5181
108 14:33:14 Alarm Delta Stage At Top Perf = 9 8473.49 3133 3347 31.9 5263
109 14:34:32 Other Swapped Movers 8514.73 3151 3371 31.9 5293
11 14:35:20 Next Stage 6.5 ppg 16/20Proppant 8539.93 3164 3388 32 5310
110 14:38:21 Alarm Delta Stage At Top Perf = 10 8636.6 3282 3519 32 5395
12 14:39:00 Next Stage 7.0 ppg 16/20Proppant 8657.58 3316 3542 32 5408
111 14:43:08 Other Screws Clean and Cut 8789.48 3372 3625 32.2 5426
112 14:43:33 Start Flush Start Flush 8803.04 3476 3702 32.3 5435
13 14:43:33 Next Stage Flush 8803.04 3478 3704 32.3 5435
113 14:44:30 Alarm Delta Stage At Top Perf = 11 8834.14 3597 3828 32.5 5471
114 14:48:07 Alarm Delta Stage At Top Perf = 12 8951.51 3617 3839 32.5 5199
115 14:52:39 Alarm Delta Stage At Top Perf = 13 9097.67 2734 2949 31.9 4574
116 14:52:50 ISIP ISIP 9100.97 1391 1464 8 3431
14 14:52:57 Next Stage Freeze Protect 9101.44 1338 1344 1.9 3661
117 14:57:51 Shut In Pressure @ 5 Minutes Shut In Pressure @ 5 Minutes 9101.6 11 21 0.5 3261
118 15:02:51 Shut In Pressure @10 Minutes Shut In Pressure @10 Minutes 9105.42 6 28 0 3205
119 15:07:49 Shut In Pressure @15 Minutes Shut In Pressure @15 Minutes 9105.42 32 48 0 3151
Event Log 3 31
Conoco Phillips 3S 606 Event Log 3 31 80
Seq No. Time Activity Code Comment Job Slurry Vol Treating Pressure Treating Pressure @Pump Slurry Rate Tubing Gauge BH Pres
1 06:29:28 (04/01/24) Start Job Starting Job 0 96 22 0 0
1 06:29:28 (04/01/24) Next Treatment Treatment Interval 1 0 96 22 0 0
2 6:55:42 Pre Job Safety Meeting Pre Job Safety Meeting 0 95 22 0 2341
3 7:27:49 Other Bring on Brine 0 96 22 0 2339
4 7:34:35 Other Prime Pumps 0 96 20 0 2338
5 7:39:40 Prime Pumps Prime Pumps 0 183 90 0 2338
6 7:56:32 Pressure Test ePRV Primary Tubing 0 632 425 0 2337
7 7:57:50 Pressure Test ePRV Primary IA 0 1412 1309 0 2337
8 7:59:32 Other ePRV Secondary Tubing 0 1278 1137 0 2336
9 8:00:56 Pressure Test ePRV Secondary IA 0 987 184 0 2336
10 8:06:11 Other Leak at the Prime Up Line 0 5039 4885 0 2336
11 8:37:18 Prime Pumps Prime Pumps 0 114 51 0 2334
12 8:46:07 Pressure Test Pressure Test Global 0 145 70 0 2333
13 8:46:14 Pressure Test Pressure Test Locals 0 146 68 0 2333
14 8:49:34 Pressure Test Pressure Test Max 0 9148 8977 0 2333
15 8:54:34 Pressure Test Pressure Test Pass 0 9127 8813 0 2333
16 9:01:11 Other Pulling on Chemicals 0 131 72 0 2332
17 9:13:37 Other Mixing Gel 0 137 68 0 2335
5 09:30:25 (04/01/24) Next Treatment Treatment Interval 5 0 155 61 0 2331
18 9:31:36 Other Load Ball 5 0 119 57 0 2331
19 9:33:09 Open Well Open Well 0 402 291 0 2321
20 9:35:39 Drop Ball Drop Ball 5 17.4 2290 2422 14.9 4008
21 9:46:30 Start Pad Start Pad 186.72 2009 2040 15.7 3990
22 9:50:31 Other Slow Down for Ball 5 250.14 1943 1979 15.7 3901
23 9:53:01 Ball on Seat Ball 5 on Seat 279.33 1594 1593 11.3 3578
24 9:53:24 Break Formation Break Formation 283.66 6456 6401 11.2 8380
25 9:53:46 Alarm Delta Stage AtTop Perf = 4 286.79 2000 1957 6.2 4020
26 9:56:05 Alarm Delta Stage AtTop Perf = 5 307.94 1999 2030 14 3933
27 10:02:16 Alarm Delta Stage AtTop Perf = 6 481.16 2818 2963 32.1 4481
28 10:08:05 Alarm Delta Stage AtTop Perf = 7 667.21 2708 2825 32.1 4394
29 10:20:26 Alarm Delta Stage AtTop Perf = 8 1060.95 2471 2582 31.7 4430
30 10:21:56 Alarm Delta Stage AtTop Perf = 9 1108.37 2550 2648 31.7 4504
31 10:23:58 Alarm Delta Stage AtTop Perf = 10 1172.79 2619 2740 31.7 4602
32 10:27:17 Alarm Delta Stage AtTop Perf = 11 1277.62 2719 2824 31.6 4707
33 10:31:29 Alarm Delta Stage AtTop Perf = 12 1410.92 2772 2892 31.9 4789
34 10:36:00 Alarm Delta Stage AtTop Perf = 13 1555.08 2829 2959 31.9 4888
35 10:37:40 Other Pump 043 Preload Pressure 1607.69 2861 2988 31.9 4911
36 10:41:05 Alarm Delta Stage AtTop Perf = 14 1711.98 2931 3063 31.9 4978
37 10:45:08 Other Load Ball 6 1841.15 3005 3126 31.9 5047
38 10:46:11 Alarm Delta Stage AtTop Perf = 15 1874.35 3015 3143 31.9 5063
39 10:51:32 Alarm Delta Stage AtTop Perf = 16 2044.97 3128 3263 32.1 5129
40 10:52:13 Drop Ball Drop Ball 6 2066.59 3286 3421 32.3 5175
6 10:52:26 (04/01/24) Next Treatment Treatment Interval 6 2073.64 3328 3462 32.3 5180
41 10:54:58 Alarm Delta Stage AtTop Perf = 17 2155.73 3532 3638 32.3 5205
42 10:59:17 Other Slow Down For Ball 8 2295.17 1521 1589 32.2 4366
43 11:01:03 Ball on Seat Ball 6 on Seat 2316.69 1619 1590 10.4 3650
44 11:01:19 Break Formation Break Formation 2319.3 4799 4742 10.3 6830
45 11:01:25 Alarm Delta Stage AtTop Perf = 18 2320.34 960 906 10.3 3130
46 11:03:47 Alarm Delta Stage AtTop Perf = 1 2351.29 2223 2255 20.3 4018
47 11:09:45 Alarm Delta Stage AtTop Perf = 2 2535.72 2559 2660 32 4235
48 11:21:48 Alarm Delta Stage AtTop Perf = 3 2919.4 2417 2509 31.7 4338
49 11:23:19 Alarm Delta Stage AtTop Perf = 4 2967.36 2482 2574 31.7 4417
50 11:25:16 Alarm Delta Stage AtTop Perf = 5 3029.19 2557 2654 31.7 4501
51 11:28:38 Alarm Delta Stage AtTop Perf = 6 3135.75 2642 2740 31.6 4598
52 11:32:53 Alarm Delta Stage AtTop Perf = 7 3270.37 2712 2814 31.7 4678
53 11:37:21 Alarm Delta Stage AtTop Perf = 8 3411.69 2762 2878 31.6 4764
54 11:42:19 Alarm Delta Stage AtTop Perf = 9 3569.2 2861 2978 31.8 4861
55 11:46:28 Other Load Ball 07 3701.17 2939 3052 31.7 4946
56 11:47:24 Alarm Delta Stage AtTop Perf = 10 3731.05 2963 3079 31.7 4975
57 11:52:55 Alarm Delta Stage AtTop Perf = 11 3905.9 3126 3225 31.9 5121
58 11:54:13 Drop Ball Drop Ball 7 3947.38 3386 3513 32.1 5179
7 11:54:15 (04/01/24) Next Treatment Treatment Interval 7 3948.46 3389 3518 32.1 5182
59 11:56:28 Alarm Delta Stage AtTop Perf = 12 4019.69 3523 3632 32.1 5205
60 12:00:29 Other Slow Down For Ball 7 4148.82 2771 2857 32.2 4390
61 12:03:33 Ball on Seat Ball 7 on Seat 4187.85 1777 1757 10.9 3753
62 12:03:49 Break Formation Break Formation 4190.6 4998 4951 10.9 6814
63 12:04:10 Alarm Delta Stage AtTop Perf = 13 4194.62 1771 1678 10.9 3674
64 12:06:07 Alarm Delta Stage AtTop Perf = 1 4218.57 2115 2090 18 3958
65 12:12:22 Alarm Delta Stage AtTop Perf = 2 4403.17 2667 2769 31.9 4339
66 12:24:24 Alarm Delta Stage AtTop Perf = 3 4787.79 2427 2525 32 4347
67 12:25:59 Alarm Delta Stage AtTop Perf = 4 4838.32 2479 2582 32 4424
68 12:28:01 Alarm Delta Stage AtTop Perf = 5 4903.28 2551 2659 31.9 4502
69 12:31:25 Alarm Delta Stage AtTop Perf = 6 5011.61 2637 2741 31.9 4594
70 12:35:41 Alarm Delta Stage AtTop Perf = 7 5148.09 2671 2774 32 4658
71 12:40:07 Alarm Delta Stage AtTop Perf = 8 5289.47 2760 2876 31.9 4755
72 12:44:56 Alarm Delta Stage AtTop Perf = 9 5442.87 2832 2931 31.8 4837
73 12:50:01 Alarm Delta Stage AtTop Perf = 10 5605.12 2920 3039 32 4946
74 12:51:26 Other Ball 8 Loaded 5650.39 2923 3032 31.9 4963
75 12:55:47 Alarm Delta Stage AtTop Perf = 11 5789.6 3198 3275 32.2 5042
76 12:56:15 Drop Ball Drop Ball 8 5804.22 3267 3350 32.2 5067
8 12:56:16 (04/01/24) Next Treatment Treatment Interval 8 5805.31 3269 3352 32.2 5070
77 12:59:19 Alarm Delta Stage AtTop Perf = 12 5903.14 3266 3334 32.1 4940
78 13:02:41 Other Slow Down For Ball 8 6011.29 1352 1362 31.1 4040
79 13:05:03 Ball on Seat Ball 8 on Seat 6038.63 1630 1594 10.3 3621
80 13:05:18 Break Formation Break Formation 6041.4 4750 4730 10.3 6842
81 13:05:32 Alarm Delta Stage AtTop Perf = 13 6043.82 2114 2036 10.3 4095
82 13:07:44 Alarm Delta Stage AtTop Perf = 1 6067.84 1821 1788 14.4 3744
83 13:14:10 Alarm Delta Stage AtTop Perf = 2 6253.82 2429 2546 32 4131
84 13:24:38 Alarm Delta Stage AtTop Perf = 3 6588.37 2273 2361 31.9 4208
85 13:26:00 Alarm Delta Stage AtTop Perf = 4 6631.84 2327 2434 31.9 4276
86 13:28:00 Alarm Delta Stage AtTop Perf = 5 6695.77 2384 2485 31.9 4356
87 13:31:01 Alarm Delta Stage AtTop Perf = 6 6792.35 2483 2587 31.9 4450
88 13:35:21 Alarm Delta Stage AtTop Perf = 7 6930.36 2583 2671 32 4567
89 13:36:23 Other Mover Swap 6963.12 2599 2710 31.9 4587
90 13:39:37 Alarm Delta Stage AtTop Perf = 8 7066.9 2631 2736 31.9 4632
91 13:44:26 Alarm Delta Stage AtTop Perf = 9 7220.98 2560 2668 32 4631
92 13:49:33 Alarm Delta Stage AtTop Perf = 10 7384.22 2745 2860 31.9 4829
9 13:54:34 (04/01/24) Next Treatment Treatment Interval 9 7544.63 3091 3238 32.5 4962
93 13:54:35 Drop Ball Drop Ball 9 7545.17 3101 3242 32.5 4952
94 13:54:40 Alarm Delta Stage AtTop Perf = 11 7547.9 3126 3260 32.5 4974
95 13:58:06 Alarm Delta Stage AtTop Perf = 12 7659.99 3172 3278 32.5 4842
96 14:00:37 Other Slow Down For Ball 9 7741 2627 2711 32.2 4259
97 14:02:49 Ball on Seat Ball 9 on Seat 7768.85 1712 1691 10.3 3667
98 14:03:04 Break Formation Break Formation 7771.28 4951 4895 10.3 6875
99 14:03:32 Alarm Delta Stage AtTop Perf = 13 7776.32 1766 1753 10.3 3701
100 14:05:23 Alarm Delta Stage AtTop Perf = 1 7799.47 2125 2124 19.4 3942
101 14:11:42 Alarm Delta Stage AtTop Perf = 2 7986.79 2532 2610 32 4226
102 14:23:42 Alarm Delta Stage AtTop Perf = 3 8369.6 2302 2364 32 4200
103 14:25:17 Alarm Delta Stage AtTop Perf = 4 8420.08 2371 2443 31.9 4296
104 14:27:18 Alarm Delta Stage AtTop Perf = 5 8484.52 2443 2533 32 4389
105 14:29:10 Other Mountain Mover Swap 8544.31 2512 2589 32 4451
106 14:30:39 Alarm Delta Stage AtTop Perf = 6 8592.24 2595 2690 32 4507
107 14:34:57 Alarm Delta Stage AtTop Perf = 7 8729.37 2520 2606 32 4537
108 14:39:17 Alarm Delta Stage AtTop Perf = 8 8867.92 2626 2722 31.9 4654
109 14:43:46 Alarm Delta Stage AtTop Perf = 9 9011.15 2719 2810 31.9 4728
110 14:48:42 Alarm Delta Stage AtTop Perf = 10 9168.1 2720 2841 31.8 4772
111 14:52:48 Other Screws Clean and Cut 9298.94 3007 3095 32.1 4849
112 14:53:21 Start Flush Start Flush 9316.21 3106 3211 32.1 4868
113 14:53:43 Alarm Delta Stage AtTop Perf = 11 9328.65 3164 3259 32.2 4888
114 14:57:21 Alarm Delta Stage AtTop Perf = 12 9446.18 3029 3089 32.2 4586
115 15:01:15 Alarm Delta Stage AtTop Perf = 13 9570.79 325 292 25.6 2550
116 15:01:23 ISIP ISIP 9572.67 1390 897 11.1 3296
117 15:06:26 Shut In Pressure @ 5 Minutes Shut In Pressure @ 5 Minutes 9573.8 71 17 0 3207
118 15:11:26 Shut In Pressure @ 10 Minutes Shut In Pressure @ 10 Minutes 9573.8 69 19 0 3159
119 15:16:27 Shut In Pressure @ 15 Minutes Shut In Pressure @ 15 Minutes 9584.67 105 16 0 3109
Event Log 4 1
Conoco Phillips 3S 606 Event Log 4 1 81
02004006008001000120014001600180000:00 02:00 04:00 10:00 20:00 30:00 1:00 30:00 00:00 30:00 00:00 00:00 00:00 00:00 00:00 00:00Viscosity (cp)Time (min:sec)Prejob Crosslink Break TestsBreak Test 1Break Test 2Break Test 3Fluid is broken at 200cp
020040060080010001200140000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 1 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cp
0200400600800100012001400160000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 1 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cp
02004006008001000120014001600180000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 1 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cp
020040060080010001200140000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 1 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cp
010020030040050060070080000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 1 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cp
010020030040050060070080090000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 1 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cp
0500100015002000250000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 1 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cp
02004006008001000120014001600180000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 1 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cp
020040060080010001200140000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 1 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cp
Company: Conoco Phillips
Well: 3S 606
Sand Type 16/20 Proppant
Date Tested 3/28/2024
Total Sample Size Seive Weight Seive Weight 100.0 g
Sieve Size Before Sand With sand WT. rtn'd % rtn'd % API Spec
12 353.1 353.1 0 0.0% 0.00% <0.1%
16 325.6 326.7 1.1 1.1%
18 406.2 497 90.8 90.8%
20 303.9 311.7 7.8 7.8%
25 314.3 314.5 0.2 0.2%
30 300.4 300.4 0 0.0%
40 275.1 275.1 0 0.0%
Pan 371 371 0 0.0% 0.00% <1.0%
Total: 99.9 100%
Total Sample Size Seive Weight Seive Weight 100.0 g
Sieve Size Before Sand With sand WT. rtn'd % rtn'd % API Spec
12 353.1 353.1 0 0.0% 0.00% <0.1%
16 325.6 331.7 6.1 6.1%
18 406.2 494.6 88.4 88.4%
20 303.9 309.2 5.3 5.3%
25 314.3 314.4 0.1 0.1%
30 300.4 300.5 0.1 0.1%
40 275.1 275.1 0 0.0%
Pan 371 371 0 0.0% 0.00% <1.0%
Total: 100 100%
93.90% >/= 90%
Sample: 16/20 04/01
98.80% >/= 90%
Ceramic Proppant Sieves
Sample: 16/20 03/28
Conoco Phillips 3S 606 Sand Sieve Analysis 92
Hydraulic Fracturing Fluid Product Component Information Disclosure
3/31/2024
Alaska
HARRISON BAY
50-103-20870
CONOCOPHILLIPS
3S 606
-150.1955
70.3942
NAD83
none
Oil
5261
714511
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%75.79737%6087634 Density = 8.52 Halliburton
BA-20
BUFFERING
AGENT Halliburton Buffer Listed Below Listed Below 0
BE-6(TM)
Bactericide Halliburton Microbiocide Listed Below Listed Below 0
CAT-3
ACTIVATOR Halliburton Activator Listed Below Listed Below 0
CL-28M
CROSSLINKER Halliburton Crosslinker Listed Below Listed Below 0
LoSurf-300D Halliburton Non-ionic Surfactant Listed Below Listed Below 0 NA
LVT-200
Baker
Hughes Additive Listed Below Listed Below 0 NA
MO-67 Halliburton pH Control Listed Below Listed Below 0
OPTIFLO-II
DELAYED
RELEASE
BREAKER Halliburton Breaker Listed Below Listed Below 0
OPTIFLO-III
DELAYED
RELEASE
BREAKER Halliburton Breaker Listed Below Listed Below 0
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
BROWN 100
MESH Halliburton Proppant Listed Below Listed Below 0 NA
A 1-25
Patina
Energy Tracer Listed Below Listed Below 0 NA
Flow Insurance
Copper
Patina
Energy Tracer Listed Below Listed Below 0 NA
Potassium
Formate Brine MI Swaco
Completion/Stimulati
on Listed Below Listed Below 0 NA
Ingredients
Listed
Above Listed Above 0.00%0.00000%0
1,2,4 Trimethylbenzene 95-63-6 1.00%0.00071%57
2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00%0.00168%135
2-Methyl-4-isothiazolin-3-one 2682-20-4 0.01%0.00002%2
5-Chloro-2-methyl-3(2H)-
Isothaiazolone 26172-55-4 0.01%0.00002%2
A 1-25 Proprietary 20.00%0.00000%0
Patina
Energy Product Stewardship
test@patinae
nergy.com 6692416025
Acetic acid 64-19-7 30.00%0.00000%0
Ammonia 7664-41-7 1.00%0.00042%34
Ammonium acetate 631-61-8 100.00%0.00000%0
Ammonium chloride 12125-02-9 5.00%0.00208%167
Ammonium persulfate 7727-54-0 100.00%0.03237%2600
Borate salts Proprietary 60.00%0.11946%9595
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
C.I. pigment Orange 5 3468-63-1 1.00%0.00016%13
Calcium magnesium carbonate 16389-88-1 1.00%0.00199%160
Corundum 1302-74-5 65.00%14.98791%1203748
Crystalline silica, quartz 14808-60-7 100.00%0.49226%39536
Distillates (petroleum),
hydrotreated light 64742-47-8 100.00%0.00000%0
EDTA/Copper chelate Proprietary 30.00%0.01246%1001 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Ethanol 64-17-5 60.00%0.04258%3420
Flow Insurance Copper Proprietary 100.00%0.00299%241
Patina
Energy Product Stewardship
test@patinae
nergy.com 6692416025
Gluteraldehyde 111-30-8 1.00%0.00199%160
Guar gum 9000-30-0 100.00%0.25269%20295
Heavy aromatic petroleum
naphtha 64742-94-5 30.00%0.02129%1710
Inorganic mineral 1317-65-3 5.00%0.00996%800
Inorganic mineral Proprietary 1.00%0.00199%160 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Magensium chloride 7786-30-3 0.01%0.00002%2
Magnesium nitrate 10377-60-3 0.01%0.00002%2
Methanesulfonic acid, 1-hydroxy-,
sodium salt 870-72-4 0.10%0.00020%16
Mullite 1302-93-8 45.00%10.37625%833364
Naphthalene 91-20-3 5.00%0.00355%285
Oxyalkylated nonyl phenolic resin Proprietary 30.00%0.02129%1710 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Oxyalkylated phenolic resin Proprietary 10.00%0.00710%570 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Oxylated phenolic resin Proprietary 30.00%0.00971%780 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%0.00355%285
Polymer Proprietary 1.00%0.00199%160 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Potassium chloride 7447-40-7 5.00%0.00996%800
Potassium Formate 590-29-4 100.00%0.00000%0
Sodium bisulfate 7681-38-1 0.10%0.00020%16
Sodium chloride 7647-14-5 5.00%3.79044%304428
Sodium hydroxide 1310-73-2 30.00%0.01721%1382
Sodium persulfate 7775-27-1 100.00%0.00000%0
Sodium sulfate 7757-82-6 0.10%0.00000%0
Water 7732-18-5 100.00%0.21836%17538
* 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 wasobtained from the suppliers Material SafetyData 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 criteriafor
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:
Prepared By:
Steven Sanders
Daniel Faur
Nannook Crew
Intervals 10 - 24
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.
3S-606
Conoco Phillips
Harrison Bay County, AK
Post Job Report
Stimulation Treatment
API: 50-103-20870
Prepared for: Manabu Nozaki
June 10, 2024
Torok Formation
30# Hybor G
Table of Contents
Section Page(s)
Executive Summary
Actual Design
Wellbore Information
Interval Summary
Fluid System-Proppant Summary
Interval 10 Plots
Interval 11 Plots
Interval 12 Plots
Interval 13 Plots
Interval 14 Plots
Interval 15 Plots
Interval 16 Plots
Interval 17 Plots
Interval 18 Plots
Interval 19 Plots
Interval 20 Plots
Interval 21 Plots
Interval 22 Plots
Interval 23 Plots
Interval 24 Plots
Appendix
Well Summary
Chemical Summary
Planned Design
Water Straps 5-29
Water Straps 5-30
Water Straps 5-31
Water Straps 6-10
Water Analysis 5-29
Water Analysis 5-30
Water Analysis 5-31
Water Analysis 6-10
Real-Time QC
Event Log- 5-29
Event Log- 5-30
Event Log- 5-31
Event Log- 6-10
Prejob Break Test 5-28-24
Prejob Break Test - 6-09-24
Fann 15 Min Test Zone 10
Zone 11
Zone 12
Zone 13
Zone 14
Zone 15
Zone 16
Zone 17
Zone 18
Zone 19
Zone 20
Zone 21
Zone 22
Zone 23
Zone 24
Sand Sieve Analysis
118
139
134
135
136
137
138
129
130
131
132
133
124
125
126
127
128
119
120
121
122
123
114
115
116
117
109
110
111
112
113
97 - 100
101
102
103
104 - 108
61 - 64
65 - 72
73 - 76
77 - 80
81 - 84
93 - 96
3
4 - 7
8
37 - 40
41 - 48
49 - 52
8 - 23
24
25 - 32
33 - 36
53 - 56
57 - 60
85 - 92
Conoco Phillips - 3S-606 TOC 2
905,486 gallons of 30# Hybor G
62,292 gallons of 30# Linear
4,003 gallons of Produced Water
2,520,000 pounds of Wanli 16/20 Ceramic
64,000 pounds of 100M
896,905 gallons of 30# Hybor G
66,602 gallons of 30# Linear
4,819 gallons of Produced Water
2,480,250 pounds of Wanli 16/20 Ceramic
66,000 pounds of 100M
Thank you,
Steven Sanders William Martin
Senior Technical Professional 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 May 29, 2024 a stimulation treatment was performed in the Torok formation on the 3S-606 well in Harrison Bay County,
AK. The 3S-606 was a 24 stage Horizontal Sleeve Design. The proposed treatment consisted of:
The actual treatment fully completed 24 of 24 stages. 0 stages were skipped, 0 stage screened out and 0 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:
The first 9 intervals on this well were flowed back prior to completing intervals 10-24. Intervals 10-23 were all pumped as per
design. For interval 24, no dart signature was observed, so the well flushed and a new dart was prepared. After the second dart
was dropped, a signature was observed and the stage was completed with no further issues.
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.
Conoco Phillips - 3S-606 Executive Summary 3
CUSTOMERConoco Phillips APIBFD (lb/gal)8.54LAT 70.39424917LEASE3S-606SALES ORDEBHST (°F)143LONG-150.1955657FORMATIONTorokDATE Max Pressure (psi)8000*Exceeds 80% of burst pressure*10-1 Shut-In Shut-In -10-2 Produced Water Prime Up Pressure Test 5.0 1,000 1,205 29 2910-3 Shut-In Shut-In -10-4 30# Linear Spacer and Ball Drop 15.0 1,260 22 1 1 1.00 30.00 2.00 2.00 0.1510-5 30# Linear Displace Ball to Seat 15.0 9,671 9,506 226 226 1.00 30.00 2.00 2.00 0.1510-6 30# Linear DFIT 10.0 1,680 1,989 47 47 1.00 30.00 2.00 2.00 0.1510-7 Shut-In Shut-In -10-8 30# Hybor G Establish Stable Fluid 15.0 8,400 5,745 137 137 2.00 1.00 1.10 0.33 30.00 2.00 2.00 0.1510-9 30# Hybor G Pad 37.0 7,810 7,825 186 186 2.00 1.00 1.10 0.33 30.00 2.00 2.00 0.1510-10 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 16,009 381 385 4,000 3,676 2.00 1.00 1.10 0.33 30.00 2.00 2.00 0.1510-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 2,000 1,987 47 49 2,000 1,596 2.00 1.00 1.10 0.33 30.00 2.00 2.00 0.1510-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 2,500 2,528 60 65 5,000 4,627 2.00 1.00 1.10 0.33 30.00 2.00 2.00 0.1510-13 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 4,000 3,990 95 106 12,000 10,080 2.00 1.00 1.10 0.33 30.00 2.00 2.00 0.1510-14 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 4,850 4,890 116 135 19,400 17,724 2.00 1.00 1.10 0.33 30.00 2.00 2.00 0.1510-15 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 5,000 5,029 120 143 22,500 21,901 2.00 1.00 1.10 0.33 30.00 2.00 2.00 0.1510-16 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 5,410 5,458 130 158 27,050 26,811 2.00 1.00 1.10 0.33 30.00 2.00 4.00 0.1510-17 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 5,500 5,385 128 159 30,250 29,086 2.00 1.00 1.10 0.33 30.00 2.00 4.00 0.1510-18 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 5,800 5,671 135 170 34,800 33,334 2.00 1.00 1.10 0.33 30.00 2.00 4.00 0.1510-19 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 4,000 4,035 96 124 26,000 25,891 2.00 1.00 1.10 0.33 30.00 2.00 4.00 0.1510-20 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 3,000 5,306 126 158 21,000 30,164 2.00 1.00 1.10 0.25 0.33 30.00 2.00 4.00 0.1510-21 30# Hybor G Spacer and Ball Drop 37.0 1,260 1,506 36 36 2.00 1.00 1.10 0.25 0.33 30.00 2.00 4.00 0.1511-1 30# Hybor G Pad 37.0 7,810 7,804 186 186 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1511-2 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 15,753 375 379 4,000 3,812 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1511-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 2,000 1,895 45 47 2,000 1,492 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1511-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 2,500 2,410 57 62 5,000 4,289 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1511-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 4,000 3,910 93 105 12,000 11,512 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1511-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 4,850 4,742 113 134 19,400 19,876 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1511-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 5,000 4,979 119 142 22,500 22,082 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1511-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 5,410 5,355 128 154 27,050 24,488 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1511-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 5,500 5,422 129 160 30,250 28,900 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1511-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 5,800 5,714 136 173 34,800 34,698 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1511-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 4,000 3,913 93 122 26,000 26,784 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1511-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 3,000 4,760 113 141 21,000 25,925 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1511-13 30# Hybor G Spacer and Ball Drop 37.0 1,260 1,323 32 32 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1512-1 30# Hybor G Pad 37.0 7,810 8,166 194 194 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1512-2 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 15,946 380 384 4,000 4,063 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1512-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 2,000 1,904 45 47 2,000 1,659 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1512-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 2,500 2,421 58 62 5,000 4,147 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1512-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 4,000 4,011 96 108 12,000 11,414 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1512-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 4,850 4,857 116 136 19,400 18,724 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1512-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 5,000 4,993 119 143 22,500 22,599 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1512-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 5,410 5,366 128 157 27,050 27,741 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1512-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 5,500 5,485 131 164 30,250 31,087 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1512-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 5,800 5,614 134 172 34,800 35,835 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1512-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 4,000 3,923 93 121 26,000 26,215 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1512-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 3,000 4,148 99 121 21,000 21,296 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1512-13 30# Linear Flush 37.0 10,129 10,298 245 245 1.00 0.25 30.00 2.00 4.00 0.1512-14 Produced Water Freeze Protect 37.0 1 - 4.0012-15 Shut-In Shut-In 37.0-13-1 Shut-In Shut-In -13-2 Produced Water Prime Up Pressure Test 5.0 1,000 1,205 29 2913-3 Shut-In Shut-In -13-4 30# Linear Spacer and Ball Drop 15.0 1,260 22 1 1 1.00 30.00 2.00 2.00 0.1513-5 30# Hybor G Establish Stable Fluid 15.0 8,400 4,874 116 116 2.00 1.00 1.20 0.25 0.33 30.00 2.00 2.00 0.1513-6 30# Hybor G Pad 37.0 7,810 7,770 185 185 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1513-7 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 16,014 381 387 4,000 5,337 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1513-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 2,000 1,986 47 49 2,000 1,303 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1513-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 2,500 2,506 60 64 5,000 4,499 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1513-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 4,000 4,002 95 108 12,000 11,801 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1513-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 4,850 4,896 117 137 19,400 19,586 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1513-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 5,000 5,059 120 146 22,500 23,590 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1513-13 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 5,410 5,320 127 156 27,050 27,808 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1513-14 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 5,500 5,493 131 164 30,250 31,591 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1513-15 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 5,800 5,732 136 174 34,800 35,609 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1513-16 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 4,000 4,017 96 123 26,000 25,953 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1513-17 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 3,000 4,691 112 131 21,000 18,616 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1513-18 30# Hybor G Spacer and Ball Drop 37.0 1,260 1,319 31 31 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1514-1 30# Hybor G Pad 37.0 7,810 7,740 184 184 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1514-2 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 16,006 381 385 4,000 3,968 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1514-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 2,000 1,995 48 49 2,000 1,473 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1514-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 2,500 2,534 60 65 5,000 4,750 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1514-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 4,000 4,130 98 112 12,000 12,453 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1514-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 4,850 4,852 116 136 19,400 19,531 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1514-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 5,000 5,032 120 143 22,500 22,244 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1514-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 5,410 5,438 129 159 27,050 28,027 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1514-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 5,500 5,530 132 167 30,250 32,808 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1514-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 5,800 5,736 137 174 34,800 35,179 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1514-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 4,000 3,946 94 121 26,000 25,354 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1514-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 3,000 4,094 97 118 21,000 19,411 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1514-13 30# Hybor G Spacer and Ball Drop 37.0 1,260 1,378 33 33 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1550-103-20870909244035/909372632Liquid Additives Dry AdditivesInterval 10Torok@ 15129.98 - 15133.84 ft 142.2 °FInterval 11Torok@ 14609.01 - 14612.87 ft 142.2 °FInterval 12Torok@ 14092.08 - 14095.94 ft 142.2 °FInterval 13Torok@ 13571.43 - 13575.29 ft 142.2 °FInterval 14Torok@ 13050.33 - 13054.19 ft 142.2 °FConoco Phillips - 3S-606 Actual Design 4
CUSTOMERConoco Phillips APIBFD (lb/gal)8.54LAT 70.39424917LEASE3S-606SALES ORDEBHST (°F)143LONG-150.1955657FORMATIONTorokDATE Max Pressure (psi)8000*Exceeds 80% of burst pressure*50-103-20870909244035/909372632Liquid Additives Dry Additives15-1 30# Hybor G Pad 37.0 7,810 7,683 183 183 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1515-2 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 15,995 381 385 4,000 3,868 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1515-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 2,000 1,962 47 48 2,000 1,663 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1515-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 2,500 2,541 61 66 5,000 4,718 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1515-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 4,000 4,034 96 109 12,000 12,216 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1515-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 4,850 4,915 117 139 19,400 20,440 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1515-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 5,000 5,008 119 143 22,500 22,316 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1515-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 5,410 5,332 127 155 27,050 26,808 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1515-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 5,500 5,517 131 163 30,250 29,988 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1515-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 5,800 5,804 138 175 34,800 34,443 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1515-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 4,000 4,014 96 123 26,000 26,053 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1515-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 3,000 4,253 101 123 21,000 20,579 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1515-13 30# Hybor G Spacer and Ball Drop 37.0 1,260 1,395 33 33 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1516-1 30# Hybor G Pad 37.0 7,810 7,764 185 185 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1516-2 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 16,051 382 386 4,000 3,531 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1516-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 2,000 2,000 48 49 2,000 1,326 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1516-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 2,500 2,540 60 65 5,000 4,634 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1516-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 4,000 4,025 96 108 12,000 11,120 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1516-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 4,850 4,812 115 134 19,400 18,668 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1516-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 5,000 4,929 117 141 22,500 22,371 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1516-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 5,410 5,488 131 160 27,050 27,640 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1516-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 5,500 5,501 131 163 30,250 30,169 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1516-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 5,800 5,790 138 174 34,800 33,923 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1516-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 4,000 4,206 100 128 26,000 25,856 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1516-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 3,000 4,326 103 125 21,000 21,171 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1516-13 30# Hybor G Spacer and Ball Drop 37.0 1,260 1,350 32 32 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1517-1 30# Hybor G Pad 37.0 1,000 1,068 25 25 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1517-2 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 15,988 381 385 4,000 3,872 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1517-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 1,400 1,398 33 35 1,400 1,398 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1517-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 1,750 1,746 42 45 3,500 3,404 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1517-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 2,800 2,817 67 76 8,400 8,301 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1517-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 3,395 3,404 81 96 13,580 13,977 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1517-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 3,500 3,501 83 101 15,750 16,518 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1517-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 3,787 3,781 90 110 18,935 19,031 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1517-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 3,850 3,853 92 114 21,175 21,381 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1517-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 4,060 4,093 97 123 24,360 24,164 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1517-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 2,800 2,714 65 84 18,200 18,415 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1517-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 2,100 3,409 81 96 14,700 13,518 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1517-13 30# Linear Flush 37.0 8,462 8,696 207 207 1.00 30.00 2.00 4.00 0.1517-14 Produced Water Freeze Protect 37.0 -17-15 Shut-In Shut-In 37.0-Interval 15Torok@ 12530.39 - 12534.25 ft 142.3 °FInterval 17Torok@ 11486.71 - 11490.57 ft 142.4 °FInterval 16Torok@ 12009.32 - 12013.18 ft 142.4 °FConoco Phillips - 3S-606 Actual Design 5
CUSTOMERConoco Phillips APIBFD (lb/gal)8.54LAT 70.39424917LEASE3S-606SALES ORDEBHST (°F)143LONG-150.1955657FORMATIONTorokDATE Max Pressure (psi)8000*Exceeds 80% of burst pressure*50-103-20870909244035/909372632Liquid Additives Dry Additives18-1 Shut-In Shut-In -18-2 Produced Water Prime Up Pressure Test 5.0 1,000 1,205 29 2918-3 Shut-In Shut-In -18-4 30# Linear Spacer and Ball Drop 15.0 42 16 0 0 1.00 30.00 2.00 2.00 0.1518-5 30# Linear Displace Ball to Seat 15.0 7,009 7,179 171 171 1.00 30.00 2.00 2.00 0.1518-6 30# Linear DFIT 10.0 2,100 2,124 51 51 1.00 30.00 2.00 2.00 0.1518-7 Shut-In Shut-In -18-8 30# Hybor G Establish Stable Fluid 15.0 8,400 6,268 149 149 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1518-9 30# Hybor G Pad 37.0 1,000 1,007 24 24 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1518-10 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 16,099 383 388 4,000 3,940 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1518-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 1,400 1,554 37 38 1,400 922 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1518-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 1,750 1,754 42 45 3,500 3,211 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1518-13 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 2,800 2,849 68 77 8,400 8,718 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1518-14 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 3,395 3,355 80 95 13,580 14,066 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1518-15 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 3,500 4,120 98 118 15,750 18,930 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1518-16 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 3,787 3,201 76 94 18,935 16,491 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1518-17 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 3,850 3,818 91 114 21,175 21,686 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1518-18 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 4,060 4,009 95 121 24,360 24,109 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1518-19 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 2,800 2,769 66 85 18,200 17,581 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1518-20 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 2,100 3,295 78 93 14,700 14,144 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1518-21 30# Hybor G Spacer and Ball Drop 37.0 1,260 1,342 32 32 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1519-1 30# Hybor G Pad 37.0 1,000 1,342 32 32 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1519-2 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 16,089 383 387 4,000 3,763 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1519-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 1,400 1,398 33 35 1,400 1,345 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1519-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 1,750 1,769 42 46 3,500 3,357 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1519-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 2,800 2,822 67 76 8,400 8,270 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1519-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 3,395 3,397 81 96 13,580 14,226 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1519-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 3,500 3,470 83 100 15,750 16,338 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1519-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 3,787 3,736 89 109 18,935 19,264 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1519-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 3,850 3,845 92 114 21,175 21,366 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1519-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 4,060 3,929 94 119 24,360 24,167 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1519-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 2,800 2,735 65 85 18,200 18,259 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1519-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 2,100 3,300 79 95 14,700 15,716 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1519-13 30# Hybor G Spacer and Ball Drop 37.0 1,260 1,314 31 31 2.00 1.00 1.00 0.25 0.33 30.00 2.00 4.00 0.1520-1 30# Hybor G Pad 37.0 1,000 974 23 23 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1520-2 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 16,107 384 388 4,000 4,033 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1520-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 1,400 1,385 33 34 1,400 964 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1520-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 1,750 1,767 42 46 3,500 3,260 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1520-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 2,800 2,770 66 75 8,400 8,722 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1520-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 3,395 3,423 82 96 13,580 13,924 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1520-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 3,500 3,521 84 101 15,750 15,931 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1520-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 3,787 3,750 89 110 18,935 19,236 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1520-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 3,850 3,839 91 114 21,175 20,984 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1520-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 4,060 4,075 97 123 24,360 24,029 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1520-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 2,800 2,801 67 87 18,200 18,847 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1520-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 2,100 3,645 87 105 14,700 16,919 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1520-13 30# Hybor G Spacer and Ball Drop 37.0 1,260 1,358 32 32 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1521-1 30# Hybor G Pad 37.0 1,000 961 23 23 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1521-2 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 15,842 377 382 4,000 4,562 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1521-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 1,400 1,383 33 34 1,400 1,289 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1521-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 1,750 1,731 41 45 3,500 3,239 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1521-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 2,800 2,809 67 76 8,400 8,363 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1521-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 3,395 3,374 80 94 13,580 13,337 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1521-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 3,500 3,607 86 103 15,750 16,281 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1521-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 3,787 3,916 93 114 18,935 19,348 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1521-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 3,850 3,760 90 111 21,175 20,506 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1521-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 4,060 4,070 97 124 24,360 25,054 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1521-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 2,800 2,762 66 85 18,200 18,372 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1521-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 2,100 3,680 88 105 14,700 16,521 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1521-13 30# Linear Flush 37.0 7,101 7,304 174 174 1.00 30.00 2.00 4.00 0.1521-14 Produced Water Freeze Protect 37.0 1 -21-15 Shut-In Shut-In 37.0-Interval 18Torok@ 10964.74 - 10968.6 ft 142.5 °FInterval 19Torok@ 10443.93 - 10447.79 ft 142.5 °FInterval 20Torok@ 9920.79 - 9924.65 ft 142.6 °FInterval 21Torok@ 9358.46 - 9362.32 ft 142.8 °FConoco Phillips - 3S-606 Actual Design 6
CUSTOMERConoco Phillips APIBFD (lb/gal)8.54LAT 70.39424917LEASE3S-606SALES ORDEBHST (°F)143LONG-150.1955657FORMATIONTorokDATE Max Pressure (psi)8000*Exceeds 80% of burst pressure*50-103-20870909244035/909372632Liquid Additives Dry Additives22-1 Shut-In Shut-In -22-2 Produced Water Prime Up Pressure Test 5.0 1,000 1,205 29 2922-3 Shut-In Shut-In -22-4 30# Linear Spacer and Ball Drop 15.0 1,260 6,888 164 164 1.00 30.00 2.00 2.00 0.1522-5 30# Hybor G Establish Stable Fluid 15.0 8,400 3,944 94 94 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1522-6 30# Hybor G Pad 37.0 1,000 689 16 16 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1522-7 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 16,096 383 387 4,000 3,625 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1522-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 1,400 1,480 35 36 1,400 1,175 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1522-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 1,750 1,754 42 45 3,500 3,013 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1522-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 2,800 2,822 67 75 8,400 7,595 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1522-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 3,395 3,418 81 96 13,580 13,901 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1522-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 3,500 3,508 84 100 15,750 15,793 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1522-13 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 3,787 3,806 91 111 18,935 19,486 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1522-14 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 3,850 3,892 93 116 21,175 21,590 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1522-15 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 4,060 4,070 97 123 24,360 24,956 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1522-16 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 2,800 2,847 68 88 18,200 18,677 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1522-17 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 2,100 3,301 79 94 14,700 14,489 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1522-18 30# Hybor G Spacer and Ball Drop 37.0 1,260 1,839 44 44 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1523-1 30# Hybor G Pad 37.0 1,000 1,089 26 26 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1523-2 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 15,985 381 385 4,000 3,864 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1523-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 1,400 1,443 34 36 1,400 1,517 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1523-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 1,750 1,845 44 48 3,500 3,411 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1523-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 2,800 2,802 67 75 8,400 8,093 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1523-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 3,395 3,408 81 95 13,580 13,509 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1523-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 3,500 3,539 84 102 15,750 16,263 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1523-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 3,787 3,778 90 110 18,935 19,167 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1523-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 3,850 3,839 91 113 21,175 20,684 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1523-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 4,060 4,071 97 121 24,360 22,969 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1523-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 2,800 2,836 68 87 18,200 18,595 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1523-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 2,100 3,904 93 114 14,700 19,554 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1523-13 30# Hybor G Spacer and Ball Drop 37.0 1,260 1,771 42 42 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1524-1 30# Hybor G Pad 37.0 1,000 985 23 23 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1524-2 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 5,798 138 139 809 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1524-3 30# Linear Flush 15.0 6,159 6,234 148 148 1.00 1.20 30.00 2.00 2.00 0.1524-4 30# Hybor G Establish Stable Fluid 15.0 8,400 4,008 95 95 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1524-5 30# Hybor G Pad 37.0 1,000 2,079 50 50 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1524-6 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 8,179 195 197 4,000 1,699 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1524-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 1,400 1,368 33 34 1,400 1,138 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1524-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 1,750 1,779 42 46 3,500 3,242 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1524-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 2,800 2,810 67 75 8,400 7,983 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1524-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 3,395 3,430 82 96 13,580 13,685 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1524-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 3,500 3,566 85 103 15,750 16,927 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1524-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 3,787 3,761 90 110 18,935 19,701 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1524-13 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 3,850 3,896 93 116 21,175 21,702 2.00 1.00 1.00 2.00 0.33 30.00 2.00 4.00 0.1524-14 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 4,060 4,122 98 124 24,360 24,012 2.00 1.00 1.00 0.25 0.33 30.00 2.00 2.00 0.1524-15 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 2,800 2,875 68 88 18,200 18,215 2.00 1.00 1.00 0.33 30.00 2.00 4.00 0.1524-16 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 2,100 5,302 126 156 14,700 27,954 2.00 1.00 1.00 0.25 0.33 30.00 2.00 2.00 0.1524-17 30# Linear Flush 37.0 6,159 6,324 151 151 1.00 30.00 2.00 2.00 0.1524-18 Produced Water Freeze Protect 10.0 1 -24-19 Shut-In Shut-In-971,781 968,326 23,055 25,822 2,580,000 2,604,482Design Total (gal)Actual Total (gal)Design Total (lbs)Calculated Total (lbs)Ticket Total (lbs)CL-28M Losurf-300D MO-67 Cat-3 BA-20 WG-36 OPTIFLO-III OPTIFLO-II BE-6905,486 896,905 2,520,000 2,546,060 2,480,250(gal) (gal) (gal) (gal) (gal) (lbs) (lbs) (lbs) (lbs)62,292 66,602 64,000 58,422 66,000 Initial Design Material Volume 1,811.0 967.8 1,081.9 26.6 298.8 29,033.3 1,935.6 2,622.7 145.2- - - Actual Design Material Volume 1,793.8 963.5 1,072.7 32.2 296.0 28,905.2 1,927.0 2,657.5 144.54,003 4,819 - - - Physical Material Volume Pumped 1,784 946 932 31 217 26187 2,040 2,700 157- - - Physical Material Volume Deviance -1% -2% -13% -4% -27% -9% 6% 2% 9%- -** IFS numbers for proppant are taken from software calculations based on multiple variablesMicroMotion Volume Pumped 1,799 981 1,063 32 206 32,668 1,914 2,643 -- -** Proppant is billed from Weight Ticket volumesMicroMotion Volume Deviance 0% 2% -1% -1% -30% 13% -1% -1% -- --Fluid Type30# Hybor G30# LinearSeawaterProduced WaterFreeze ProtectProppant TypeWanli 16/20 Ceramic100M--Interval 22Torok@ 8790.6 - 8794.46 ft 143 °FInterval 23Torok@ 8232.54 - 8236.4 ft 143.1 °FInterval 24Torok@ 7751.56 - 7755.42 ft 142.5 °F---Conoco Phillips - 3S-606 Actual Design 7
Conoco Phillips Torok3S-60650-103-20870*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 8,148 5,208 8,430Tubing4.5 3.958 12.6 L-80 0.6392 8,148 21,240 8,368 8,430Total21,24013,577ft1.60ft143.1ftft1.58ft143.1ftTop 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)15130 15134 5,20010Torok142.211:52:00 AM 12:09:00 PM 1 191 21615.3384 4,075 3,691 2,438 6,000 3,562 10.214609 14613 5,20211Torok142.21:42:00 PM 1:49:00 PM 2,287 2,469 2,5018.32,235 5,600 3,365 3,935 7,108 3,173 9.914092 14096 5,20512Torok142.22:35:00 PM 2:43:00 PM 4,123 4,297 4,3307.51,900 4,487 2,587 3,754 6,185 2,431 10.013571 13575 5,20513Torok142.29:15:00 AM 9:30:00 AM 1 168 19710.11,266 4,086 2,820 2,674 5,376 2,702 10.213050 13054 5,20014Torok142.210:20:00 AM 10:27:00 AM 1,974 2,133 2,1702.62,214 4,918 2,704 3,901 6,464 2,563 10.112530 12534 5,20615Torok142.311:14:00 AM 11:21:00 AM 3,821 3,972 4,0092.72,011 6,031 4,020 3,750 7,764 4,014 10.112009 12013 5,21216Torok142.412:08:00 PM 12:14:00 PM 5,667 5,810 5,8454.81,889 4,029 2,140 3,765 5,804 2,039 10.111487 11491 5,21517Torok142.41:02:00 PM 1:08:00 PM 7,519 7,654 7,6867.81,711 4,101 2,390 3,609 5,920 2,311 10.110965 10969 5,21918Torok142.59:10:00 AM 9:22:00 AM 1 128 1589.9530 4,175 3,645 2,549 5,736 3,187 10.110444 10448 5,22219Torok142.510:45:00 AM 10:51:00 AM 1,695 1,814 1,8494.92,013 3,699 1,686 3,692 5,493 1,801 10.19921 9925 5,22920Torok142.611:25:00 AM 11:31:00 AM 3,021 3,132 3,1720.01,825 3,525 1,700 3,586 5,165 1,579 10.29358 9362 5,24121Torok142.812:04:00 PM 12:10:00 PM 4,354 4,456 4,4924.41,725 3,610 1,885 3,523 5,358 1,835 10.28791 8794 5,25422Torok143.04:38:38 PM 4:48:24 PM 27 121 1591.8369 2,903 2,534 2,736 3,676 940 12.18233 8236 5,25923Torok143.15:32:41 PM 5:39:19 PM 1,586 1,671 1,7110.31,526 4,306 2,780 3,920 5,425 1,505 12.0Heel7752 7755 5,22524Torok142.56:51:20 PM 7:00:08 PM 3,269 3,347 3,3843.01,270 4,513 3,243 3,772 6,019 2,247 12.2118.0182.8174.8166.9158.9151.0230.3222.3214.5142.4133.8125.35,2624,9557,3427,0096,6766,3415,9825,6199,0088,6758,3428,0097,6769,6719,338Displacement to Top Sleeve/Perf (gal)(BBLS)222324Interval #Max Pressure (psi)8,000Isolation TypeSwell PackerTreatment TubularsCustomerFormationLeaseAPIDateTemperature DataTemp. Gradient (°F/100 ft)BHST (°F)Directional Data5,2102,23721,240Directional Data2,2375/29/2024KOPTemperature DataSleeve/Perf Depth Sleeves206.5198.6190.7101117181920211213141516Temp. Gradient (°F/100 ft)BHST (°F)TVD at Bottom PerfMD at Bottom Perf5,25919,833KOPAvg. TVDTotal MDConoco Phillips - 3S-606 Wellbore Information 8
5/29/24 11:51
5/29/24 13:49
118 min
10.2 bpm
4,075 psi
6,000 psi
15 bbl
37.3 bpm
3,415 psi
5,065 psi
32.6 bpm
2,580 psi
2,553 psi
4,337 psi
2,064 hhp
244 psi
235 psi
656 psi
7.21 ppg
6
6
32 %
31 %
23 cP
88.4 F
8.9
DFIT
10.140 bpm
1227 psi
3287 psi
10.2 bpm
1277 psi
3332 psi
3081 psi
0.593 psi/ft
2707 psi
2511 psi
249 psi
201,214 lbs
3,676 lbs
204,890 lbs
204,890 lbs
75,364 gal 1,794 bbls
11,517 gal 274 bbls
0 gal 0 bbls
1,205 gal 29 bbls
0 gal 0 bbls
9,506 gal 226 bbls
7,825 gal 186 bbls
16,009 gal 381 bbls
44,279 gal 1,054 bbls
1,528 gal 36 bbls
5,745 gal 137 bbls
1,989 gal 47 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Craig Karpinski
James Campbell
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Greg Clayton
Initial BH Pressure (Breakdown):
Pad Percentage Actual
Pumps Starting Stage:
Dart/Ball Early :
30# Hybor G Volume:
Average Visc:
Minifrac Average Rate:
Pad Percentage Design
Max OA Pressure:
Final 5 min:
Final 10 min:
Minifrac Average DH Pressure:
Average pH:
Average BH Pressure:
ISDP:
Final Fracture Gradient:
Interval Summary
Pump Time:
Start Date/Time:
3S-606 - Torok - Interval 10
End Date/Time:
DFIT Volume:
Interval 10 was pumped on 5/29 after flowing back the first 9 intervals for reservoir analysis. A
DFIT was pumped at the beginning of the interval. Interval 10 was pumped as per design.
30# Linear Volume:
Seawater Volume:
Average Missile HHP:
Open Well Pressure:
Wanli 16/20 Ceramic Pumped:
Initial OA Pressure:
Max Proppant Concentration:
Displace Ball to Seat Volume:
Diagnostic method
Proppant Laden Fluid Volume:
Final 15 min:
100M Pumped:
Pad Volume:
Conditioning Pad Volume:
Initial Surface Pressure (Breakdown):
Produced Water Volume:
Proppant Summary
Minifrac Max Rate:
Average Missile Pressure:
Average Rate:
Average Temp:
Max Surface Pressure:
Max BH Pressure:
Pumps Ending Stage:
Max Rate:
Average Surface Pressure:
Establish Stable Fluid Volume:
Minifrac Max Surface Pressure:
Minifrac Max DH Pressure:
Total Proppant Pumped* :
Proppant in Formation:
Fluid Summary (by fluid description)
Minifrac Average Pressure:
Initial Rate (Breakdown):
Interval Status:
Spacer and Ball Drop Volume:
Fluid Summary (by stage description)
Willie Martin
Freeze Protect Volume:
Conoco Phillips - 3S-606 Interval Summary 9
5/29/24 13:49
5/29/24 14:43
54 min
9.9 bpm
5,600 psi
7,108 psi
8 bbl
37.5 bpm
3,487 psi
5,149 psi
34.6 bpm
2,581 psi
2,558 psi
4,367 psi
2,189 hhp
658 psi
754 psi
7.37 ppg
6
6
32 %
31 %
22 cP
90.3 F
9
200,046 lbs
3,812 lbs
203,858 lbs
203,858 lbs
67,980 gal 1,619 bbls
7,804 gal 186 bbls
15,753 gal 375 bbls
43,100 gal 1,026 bbls
1,323 gal 32 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Fluid Summary (by stage description)
Pad Volume:
During the 4.5 ppg sand stage, sand concentration fell due to wet sand clumping in the hopper
and castle chute. The interval was pumped to completion.
Greg Clayton
Craig Karpinski
James Campbell
*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.
Pad Percentage Design
Average Surface Pressure:
Max OA Pressure:
Max BH Pressure:
Average Rate:
Average BH Pressure:
Interval Summary
Proppant Summary
Fluid Summary (by fluid description)
Total Proppant Pumped* :
Proppant in Formation:
Pumps Ending Stage:
Pump Time:
Initial BH Pressure (Breakdown):
Dart/Ball Early :
30# Hybor G Volume:
3S-606 - Torok - Interval 11
End Date/Time:
Max Proppant Concentration:
Average Visc:
Average Temp:
Max Rate:
Wanli 16/20 Ceramic Pumped:
Average pH:
Pad Percentage Actual
Initial OA Pressure:
Willie Martin
Pumps Starting Stage:
100M Pumped:
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Start Date/Time:
Interval Status:
Average Missile HHP:
Average Missile Pressure:
Max Surface Pressure:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Spacer and Ball Drop Volume:
Conoco Phillips - 3S-606 Interval Summary 10
5/29/24 14:43
5/29/24 15:35
52 min
10.0 bpm
4,487 psi
6,185 psi
7 bbl
37.3 bpm
3,434 psi
5,092 psi
35.9 bpm
3,042 psi
3,023 psi
4,830 psi
2,676 hhp
729 psi
768 psi
7.66 ppg
6
6
32 %
32 %
23 cP
86 F
8.9
3366 psi
0.647 psi/ft
3221 psi
3149 psi
3095 psi
200,717 lbs
4,063 lbs
204,780 lbs
204,780 lbs
66,834 gal 1,591 bbls
10,298 gal 245 bbls
8,166 gal 194 bbls
15,946 gal 380 bbls
42,722 gal 1,017 bbls
10,298 gal 245 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Pumps Starting Stage:
Max Proppant Concentration:
Pump Time:
3S-606 - Torok - Interval 12
Interval Summary
Initial BH Pressure (Breakdown):
Average Missile HHP:
Initial Surface Pressure (Breakdown):
Max OA Pressure:
Average pH:
Max Rate:
Initial OA Pressure:
End Date/Time:
Dart/Ball Early :
Max BH Pressure:
Average Visc:
Craig Karpinski
Greg Clayton
Average Surface Pressure:
Start Date/Time:
Average Rate:
Average Missile Pressure:
Final Fracture Gradient:
Pad Percentage Actual
Initial Rate (Breakdown):
Average BH Pressure:
During the 1.0 ppg sand stage, rate dropped due to debris flowing through pump 458. The
interval was pumped to completion.
Willie Martin
Proppant Summary
Fluid Summary (by fluid description)
30# Hybor G Volume:
Fluid Summary (by stage description)
30# Linear Volume:
Max Surface Pressure:
ISDP:
Interval Status:
Pad Volume:
Flush Volume:
Conditioning Pad Volume:
James Campbell
*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.
Final 10 min:
Wanli 16/20 Ceramic Pumped:
Pumps Ending Stage:
Pad Percentage Design
Proppant in Formation:
Proppant Laden Fluid Volume:
Average Temp:
Final 15 min:
Final 5 min:
Total Proppant Pumped* :
100M Pumped:
Conoco Phillips - 3S-606 Interval Summary 11
5/30/24 9:15
5/30/24 10:27
72 min
10.2 bpm
4,086 psi
5,376 psi
10 bbl
37.4 bpm
3,079 psi
4,769 psi
34.7 bpm
2,657 psi
2,663 psi
4,341 psi
2,260 hhp
181 psi
269 psi
716 psi
7.33 ppg
6
6
32 %
31 %
24 cP
107 F
9
200,356 lbs
5,337 lbs
205,693 lbs
205,693 lbs
73,679 gal 1,754 bbls
22 gal 1 bbls
0 gal 0 bbls
1,205 gal 29 bbls
7,770 gal 185 bbls
16,014 gal 381 bbls
43,702 gal 1,041 bbls
1,341 gal 32 bbls
0 gal 0 bbls
0 gal 0 bbls
0 gal 0 bbls
4,874 gal 116 bbls
0 gal 0 bbls
0 gal 0 bbls
0 gal 0 bbls
0 gal 0 bbls
0 gal 0 bbls
0 gal 0 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Conditioning Pad Volume:
Spacer and Ball Drop Volume:
Pad Percentage Actual
Proppant Laden Fluid Volume:
Fluid Summary (by stage description)
Freeze Protect Volume:
DFIT Volume:
0 Volume:
0 Volume:
0 Volume:
Interval 13 was pumped as per design. Willie Martin
Craig Karpinski
James Campbell
Fluid Summary (by fluid description)
30# Linear Volume:
Interval Summary
End Date/Time:
Average Missile HHP:
Flush 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.
Pad Percentage Design
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Max Surface Pressure:
Max Proppant Concentration:
Greg Clayton
Total Proppant Pumped* :
Initial BH Pressure (Breakdown):
Average Missile Pressure:
Pump Time:
3S-606 - Torok - Interval 13
Max BH Pressure:
Average Visc:
Average pH:
Initial OA Pressure:
Pumps Ending Stage:
Open Well Pressure:
Average Surface Pressure:
Start Date/Time:
Pumps Starting Stage:
Average Rate:
Proppant Summary
Dart/Ball Early :
Produced Water Volume:
Max OA Pressure:
Average Temp:
Pad Volume:
Max Rate:
Wanli 16/20 Ceramic Pumped:
Average BH Pressure:
100M Pumped:
Minifrac - Treatment Volume:
Seawater Volume:
Proppant in Formation:
Step Rate Test Volume:
30# Hybor G Volume:
Establish Stable Fluid Volume:
Minifrac - Flush Volume:
Interval Status:
Conoco Phillips - 3S-606 Interval Summary 12
5/30/24 10:27
5/30/24 11:21
54 min
10.1 bpm
4,918 psi
6,464 psi
3 bbl
37.4 bpm
2,997 psi
4,639 psi
34.9 bpm
2,604 psi
2,610 psi
4,407 psi
2,225 hhp
716 psi
821 psi
6.97 ppg
6
6
32 %
31 %
22 cP
103.6 F
8.9
201,230 lbs
3,968 lbs
205,198 lbs
205,198 lbs
68,411 gal 1,629 bbls
7,740 gal 184 bbls
16,006 gal 381 bbls
43,287 gal 1,031 bbls
1,378 gal 33 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Conditioning Pad Volume:
Initial Surface Pressure (Breakdown):
Total Proppant Pumped* :
Proppant Laden Fluid Volume:
Pad Volume:
Proppant in Formation:
Fluid Summary (by fluid description)
30# Hybor G Volume:
Spacer and Ball Drop Volume:
Interval Summary
Start Date/Time:
Willie Martin
Max Rate:
Max BH Pressure:
3S-606 - Torok - Interval 14
Wanli 16/20 Ceramic Pumped:
Pump Time:
Average pH:
100M Pumped:
Greg Clayton
During the 5.5 ppg sand stage, a pump kicked due to preload pressure but was quickly brought
back online. Interval 14 was pumped as per design.
End Date/Time:
Average Temp:
Dart/Ball Early :
Max Surface Pressure:
Max OA Pressure:
Max Proppant Concentration:
Initial Rate (Breakdown):
Average Visc:
Initial OA Pressure:
Average Missile HHP:
Pumps Starting Stage:
Average BH Pressure:
Fluid Summary (by stage description)
Craig Karpinski
James Campbell
*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.
Proppant Summary
Pad Percentage Actual
Interval Status:
Initial BH Pressure (Breakdown):
Average Surface Pressure:
Pad Percentage Design
Average Rate:
Average Missile Pressure:
Pumps Ending Stage:
Conoco Phillips - 3S-606 Interval Summary 13
5/30/24 11:21
5/30/24 12:14
53 min
10.1 bpm
6,031 psi
7,764 psi
3 bbl
37.8 bpm
2,957 psi
4,644 psi
34.9 bpm
2,487 psi
2,469 psi
4,262 psi
2,127 hhp
808 psi
870 psi
7.26 ppg
6
6
32 %
31 %
22 cP
110.1 F
9
199,224 lbs
3,868 lbs
203,092 lbs
203,092 lbs
68,453 gal 1,630 bbls
0 gal 0 bbls
7,683 gal 183 bbls
15,995 gal 381 bbls
43,380 gal 1,033 bbls
1,395 gal 33 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval 15 pumped as per design.
Dart/Ball Early :
3S-606 - Torok - Interval 15
Interval Summary
Average Missile Pressure:
Pad Percentage Actual
Pumps Ending Stage:
Pad Percentage Design
End Date/Time:
Max BH Pressure:
Max Rate:
Initial Surface Pressure (Breakdown):
Average Missile HHP:
Initial BH Pressure (Breakdown):
Average BH Pressure:
Pump Time:
Fluid Summary (by fluid description)
Interval Status:
Willie Martin
Craig Karpinski
James Campbell
Pad Volume:
Conditioning Pad Volume:
Fluid Summary (by stage description)
Max Surface Pressure:
Spacer and Ball Drop Volume:
Average Surface Pressure:
Wanli 16/20 Ceramic Pumped:
Proppant Summary
Total Proppant Pumped* :
Proppant in Formation:
Average Temp:
Initial OA Pressure:
Max OA Pressure:
Max Proppant Concentration:
Average Visc:
Average pH:
Initial Rate (Breakdown):
100M Pumped:
Proppant Laden Fluid Volume:
Pumps Starting Stage:
Displace Ball to Seat 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.Greg Clayton
Start Date/Time:
30# Hybor G Volume:
Average Rate:
Conoco Phillips - 3S-606 Interval Summary 14
5/30/24 12:14
5/30/24 13:08
54 min
10.1 bpm
4,029 psi
5,804 psi
5 bbl
37.3 bpm
2,681 psi
4,379 psi
34.8 bpm
2,264 psi
2,246 psi
4,075 psi
1,932 hhp
842 psi
880 psi
7.31 ppg
6
6
32 %
31 %
22 cP
111.2 F
8.9
196,878 lbs
3,531 lbs
200,409 lbs
200,409 lbs
68,782 gal 1,638 bbls
7,764 gal 185 bbls
16,051 gal 382 bbls
43,617 gal 1,039 bbls
1,350 gal 32 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Willie Martin
Craig Karpinski
James Campbell
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Greg Clayton
Max Proppant Concentration:
Pad Percentage Design
Average Visc:
Pump Time:
Average Temp:
Proppant in Formation:
Average pH:
Pumps Starting Stage:
Start Date/Time:
Average BH Pressure:
Average Rate:
Interval Summary
Pad Percentage Actual
Initial OA Pressure:
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Average Missile HHP:
Max OA Pressure:
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Pumps Ending Stage:
Max Surface Pressure:
End Date/Time:
Max BH Pressure:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Wanli 16/20 Ceramic Pumped:
Pad Volume:
Average Surface Pressure:
Fluid Summary (by fluid description)
100M Pumped:
30# Hybor G Volume:
Average Missile Pressure:
Proppant Summary
Max Rate:
3S-606 - Torok - Interval 16
Interval Status:
Interval 16 was pumped as per design.
Spacer and Ball Drop Volume:
Fluid Summary (by stage description)
Total Proppant Pumped* :
Conoco Phillips - 3S-606 Interval Summary 15
5/30/24 13:08
5/30/24 13:45
37 min
10.1 bpm
4,101 psi
5,920 psi
8 bbl
37.4 bpm
2,692 psi
4,330 psi
35.9 bpm
2,268 psi
2,247 psi
4,081 psi
1,993 hhp
826 psi
833 psi
7.07 ppg
6
6
33 %
32 %
21 cP
106.5 F
8.9
3390 psi
0.650 psi/ft
3310 psi
3254 psi
3197 psi
140,107 lbs
3,872 lbs
143,979 lbs
143,979 lbs
47,772 gal 1,137 bbls
8,696 gal 207 bbls
0 gal 0 bbls
0 gal 0 bbls
0 gal 0 bbls
1,068 gal 25 bbls
15,988 gal 381 bbls
30,716 gal 731 bbls
8,696 gal 207 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
3S-606 - Torok - Interval 17
Interval Summary
Average pH:
ISDP:
Final Fracture Gradient:
Proppant Summary
Average Rate:
Pad Volume:
Final 5 min:
Proppant in Formation:
Average Missile Pressure:
Initial Rate (Breakdown):
Dart/Ball Early :
Freeze Protect Volume:
Fluid Summary (by fluid description)
Wanli 16/20 Ceramic Pumped:
Final 10 min:
30# Hybor G 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.
Produced Water Volume:
30# Linear Volume:
Greg Clayton
100M Pumped:
Flush Volume:
Fluid Summary (by stage description)
Interval 17 was pumped as per design. Willie Martin
Craig Karpinski
James Campbell
Seawater Volume:
Final 15 min:
Total Proppant Pumped* :
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Start Date/Time:
End Date/Time:
Max Proppant Concentration:
Average BH Pressure:
Pumps Ending Stage:
Pad Percentage Design
Pad Percentage Actual
Max Surface Pressure:
Initial BH Pressure (Breakdown):
Interval Status:
Average Visc:
Average Temp:
Max OA Pressure:
Average Surface Pressure:
Max Rate:
Initial OA Pressure:
Max BH Pressure:
Initial Surface Pressure (Breakdown):
Pumps Starting Stage:
Average Missile HHP:
Pump Time:
Conoco Phillips - 3S-606 Interval Summary 16
5/31/24 9:09
5/31/24 10:51
102 min
10.1 bpm
4,175 psi
5,736 psi
10 bbl
37.8 bpm
2,633 psi
4,231 psi
31.4 bpm
2,227 psi
2,209 psi
3,961 psi
1,712 hhp
184 psi
137 psi
570 psi
7.61 ppg
6
6
33 %
32 %
24 cP
104.5 F
8.9
DFIT
10.060 bpm
1291 psi
3301 psi
10.08 bpm
1354 psi
3333 psi
3146 psi
0.603 psi/ft
2892 psi
2686 psi
2578 psi
139,858 lbs
3,940 lbs
143,798 lbs
143,798 lbs
55,440 gal 1,320 bbls
9,319 gal 222 bbls
1,205 gal 29 bbls
7,179 gal 171 bbls
1,007 gal 24 bbls
16,099 gal 383 bbls
30,724 gal 732 bbls
1,358 gal 32 bbls
6,268 gal 149 bbls
2,124 gal 51 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
ISDP:
Proppant Summary
Produced Water Volume:
100M Pumped:
Displace Ball to Seat Volume:
A DFIT was pumped at the beginning of interval 18. The interval was pumped as per design.
James Campbell
Interval Summary
Average Temp:
Average pH:
Minifrac Max DH Pressure:
Minifrac Max Surface Pressure:
Fluid Summary (by fluid description)
Average BH Pressure:
Minifrac Average Pressure:
Minifrac Average DH Pressure:
Pumps Starting Stage:
Pumps Ending Stage:
Final Fracture Gradient:
Final 10 min:
30# Linear Volume:
Max Rate:
Average Missile HHP:
Open Well Pressure:
Max BH Pressure:
Initial Surface Pressure (Breakdown):
3S-606 - Torok - Interval 18
Pump Time:
Interval Status:
Greg Clayton
Willie Martin
Craig Karpinski
Initial Rate (Breakdown):
Average Rate:
Conditioning Pad Volume:
Start Date/Time:
Average Surface Pressure:
Fluid Summary (by stage description)
Spacer and Ball Drop 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.
Pad Volume:
Initial OA Pressure:
Max OA Pressure:
Max Surface Pressure:
Diagnostic method
Minifrac Average Rate:
Wanli 16/20 Ceramic Pumped:
Establish Stable Fluid Volume:
Proppant Laden Fluid Volume:
Total Proppant Pumped* :
Proppant in Formation:
Final 5 min:
30# Hybor G Volume:
End Date/Time:
Dart/Ball Early :
Initial BH Pressure (Breakdown):
Pad Percentage Design
Max Proppant Concentration:
Pad Percentage Actual
Minifrac Max Rate:
Final 15 min:
DFIT Volume:
Average Visc:
Average Missile Pressure:
Conoco Phillips - 3S-606 Interval Summary 17
5/31/24 10:51
5/31/24 11:31
40 min
10.1 bpm
3,699 psi
5,493 psi
5 bbl
37.9 bpm
4,017 psi
5,556 psi
34.5 bpm
2,536 psi
2,516 psi
4,307 psi
2,146 hhp
571 psi
651 psi
7.47 ppg
6
6
33 %
32 %
22 cP
111 F
9
142,308 lbs
3,763 lbs
146,071 lbs
146,071 lbs
49,146 gal 1,170 bbls
1,342 gal 32 bbls
16,089 gal 383 bbls
30,401 gal 724 bbls
1,314 gal 31 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Status:
*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.
Spacer and Ball Drop Volume:
Greg Clayton
Average Temp:
Average Missile Pressure:
Average pH:
Average BH Pressure:
Total Proppant Pumped* :
Proppant Laden Fluid Volume:
Fluid Summary (by stage description)
30# Hybor G Volume:
After seating the ball for interval 19, pressure indicated a partial shift or entry restriction due to
high pressure. Treating pressure slowly trended downward as 100 Mesh hit downhole. Interval
19 was pumped as per design.
Willie Martin
Craig Karpinski
James Campbell
Fluid Summary (by fluid description)
Pad Volume:
Wanli 16/20 Ceramic Pumped:
Interval Summary
Average Visc:
Start Date/Time:
End Date/Time:
Dart/Ball Early :
Pumps Starting Stage:
Max Rate:
Initial Rate (Breakdown):
Max BH Pressure:
Average Rate:
Pad Percentage Actual
Max Surface Pressure:
Pump Time:
Initial OA Pressure:
Initial BH Pressure (Breakdown):
Max OA Pressure:
Proppant in Formation:
100M Pumped:
Conditioning Pad Volume:
Average Missile HHP:
Pad Percentage Design
Proppant Summary
Max Proppant Concentration:
3S-606 - Torok - Interval 19
Initial Surface Pressure (Breakdown):
Pumps Ending Stage:
Average Surface Pressure:
Conoco Phillips - 3S-606 Interval Summary 18
5/31/24 11:31
5/31/24 12:10
39 min
10.2 bpm
3,525 psi
5,165 psi
0 bbl
37.4 bpm
3,246 psi
4,785 psi
34.6 bpm
2,305 psi
2,294 psi
4,080 psi
1,954 hhp
643 psi
717 psi
7.50 ppg
6
6
33 %
32 %
21 cP
109 F
9
142,816 lbs
4,033 lbs
146,849 lbs
146,849 lbs
49,415 gal 1,177 bbls
974 gal 23 bbls
16,107 gal 384 bbls
30,976 gal 738 bbls
1,358 gal 32 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Total Proppant Pumped* :
Proppant in Formation:
30# Hybor G Volume:
Conditioning Pad Volume:
Interval Summary
Start Date/Time:
End Date/Time:
Pad Volume:
Max BH Pressure:
Average Rate:
Average Missile Pressure:
Average Surface Pressure:
Average pH:
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Max Rate:
Proppant Summary
Wanli 16/20 Ceramic Pumped:
100M Pumped:
Pumps Ending Stage:
Average BH Pressure:
Pump Time:
Pad Percentage Design
Average Temp:
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Max OA Pressure:
Pad Percentage Actual
Average Missile HHP:
Initial OA Pressure:
3S-606 - Torok - Interval 20
James Campbell
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Greg Clayton
Max Surface Pressure:
Proppant Laden Fluid Volume:
Spacer and Ball Drop Volume:
Interval Status:
Willie Martin
Craig Karpinski
Max Proppant Concentration:
Average Visc:
Initial Rate (Breakdown):
Pumps Starting Stage:
During the 4 ppg sand stage, there was a large pressure drop which presumably could have
been the fracture growing into another zone or losing isloation. The interval was pumped as per
design.
Conoco Phillips - 3S-606 Interval Summary 19
5/31/24 12:10
5/31/24 12:47
37 min
10.2 bpm
3,610 psi
5,358 psi
4 bbl
37.5 bpm
3,721 psi
5,355 psi
36.1 bpm
2,375 psi
2,372 psi
4,139 psi
2,103 hhp
700 psi
714 psi
7.25 ppg
6
6
33 %
31 %
22 cP
107.7 F
9
3315 psi
0.633 psi/ft
3247 psi
3215 psi
3188 psi
142,310 lbs
4,562 lbs
146,872 lbs
146,872 lbs
47,895 gal 1,140 bbls
7,304 gal 174 bbls
961 gal 23 bbls
15,842 gal 377 bbls
31,092 gal 740 bbls
7,304 gal 174 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Summary
Proppant Summary
Wanli 16/20 Ceramic Pumped:
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Conditioning Pad Volume:
Flush Volume:
Final 10 min:
Proppant Laden Fluid Volume:
30# Linear Volume:
Start Date/Time:
End Date/Time:
Pump Time:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Max Rate:
*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.
Initial OA Pressure:
Max OA Pressure:
Proppant in Formation:
ISDP:
Pad Volume:
100M Pumped:
Average Missile HHP:
Final 5 min:
Pumps Ending Stage:
Average Visc:
Max BH Pressure:
Pad Percentage Design
Final 15 min:
Average pH:
Average BH Pressure:
Pumps Starting Stage:
Willie Martin
Average Temp:
Average Missile Pressure:
Average Surface Pressure:
Pad Percentage Actual
Average Rate:
Max Proppant Concentration:
3S-606 - Torok - Interval 21
Craig Karpinski
James Campbell
Greg Clayton
Interval Status:
Max Surface Pressure:
Final Fracture Gradient:
Total Proppant Pumped* :
30# Hybor G Volume:
During interval 21, the pressure mirrored the same pressure trend with a high pressure in early
stages before a quick break druing 4 ppg. Interval 21 was pumped to completion.
Conoco Phillips - 3S-606 Interval Summary 20
6/10/24 16:35
6/10/24 17:39
63 min
12.1 bpm
2,903 psi
3,676 psi
2 bbl
37.4 bpm
2,255 psi
3,636 psi
30.7 bpm
1,653 psi
1,649 psi
3,436 psi
1,244 hhp
133 psi
147 psi
435 psi
7.40 ppg
6
5
33 %
31 %
25 cP
87 F
9
140,675 lbs
3,625 lbs
144,300 lbs
144,300 lbs
53,466 gal 1,273 bbls
6,888 gal 164 bbls
1,205 gal 29 bbls
689 gal 16 bbls
16,096 gal 383 bbls
30,898 gal 736 bbls
8,727 gal 208 bbls
3,944 gal 94 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Proppant in Formation:
Proppant Laden Fluid Volume:
Produced Water Volume:
Total Proppant Pumped* :
*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.
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Pad Volume:
Spacer and Ball Drop Volume:
Establish Stable Fluid Volume:
Interval 22 was pumped as per design. Steven Sanders
Craig Karpinski
Dan Faur
Interval Summary
Dart/Ball Early :
Average Missile Pressure:
Initial OA Pressure:
Average Surface Pressure:
Max OA Pressure:
Max Surface Pressure:
Average Missile HHP:
Average BH Pressure:
Max BH Pressure:
Max Rate:
Start Date/Time:
End Date/Time:
Pump Time:
Average Rate:
Pad Percentage Actual
Pumps Starting Stage:
Pumps Ending Stage:
Pad Percentage Design
Average Visc:
Average Temp:
Initial BH Pressure (Breakdown):
Average pH:
30# Linear Volume:
30# Hybor G Volume:
Conditioning Pad Volume:
Proppant Summary
Chad Burkett
Wanli 16/20 Ceramic Pumped:
Max Proppant Concentration:
Initial Surface Pressure (Breakdown):
3S-606 - Torok - Interval 22
Interval Status:
100M Pumped:
Open Well Pressure:
Initial Rate (Breakdown):
Conoco Phillips - 3S-606 Interval Summary 21
6/10/24 17:39
6/10/24 19:00
81 min
12.0 bpm
4,306 psi
5,425 psi
0 bbl
37.3 bpm
1,952 psi
3,581 psi
35.8 bpm
1,661 psi
1,661 psi
3,444 psi
1,457 hhp
509 psi
556 psi
7.00 ppg
5
5
33 %
31 %
23 cP
98 F
8.9
143,762 lbs
3,864 lbs
147,626 lbs
147,626 lbs
50,310 gal 1,198 bbls
1,089 gal 26 bbls
15,985 gal 381 bbls
31,465 gal 749 bbls
1,771 gal 42 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:Chad Burkett
Interval Status:
Craig Karpinski
Steven Sanders
Dan Faur
Dart/Ball Early :
Proppant Summary
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Spacer and Ball Drop Volume:
100M Pumped:
Average Missile Pressure:
Average Missile HHP:
Max Proppant Concentration:
Interval Summary
Pad Percentage Actual
Initial Surface Pressure (Breakdown):
Max Rate:
Pumps Ending Stage:
Max OA Pressure:
Pad Percentage Design
Average BH Pressure:
Pump Time:
End Date/Time:
Average Visc:
Average Temp:
Total Proppant Pumped* :
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Max BH Pressure:
Average Rate:
Max Surface Pressure:
Initial OA Pressure:
Pumps Starting Stage:
Initial BH Pressure (Breakdown):
3S-606 - Torok - Interval 23
Initial Rate (Breakdown):
Start Date/Time:
Average pH:
Average Surface Pressure:
Wanli 16/20 Ceramic Pumped:
Proppant in Formation:
30# Hybor G Volume:
Interval 23 was pumped as per design.
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Pad Volume:
Conoco Phillips - 3S-606 Interval Summary 22
6/10/24 19:00
6/10/24 19:37
38 min
12.2 bpm
4,513 psi
6,019 psi
3 bbl
37.2 bpm
4,069 psi
5,782 psi
35.4 bpm
2,183 psi
2,167 psi
3,994 psi
1,894 hhp
603 psi
691 psi
7.20 ppg
5
5
49 %
30 %
22 cP
95 F
8.9
1286 psi
0.246 psi/ft
3283 psi
3258 psi
3218 psi
154,559 lbs
2,508 lbs
157,067 lbs
157,067 lbs
53,958 gal 1,285 bbls
12,558 gal 299 bbls
3,064 gal 73 bbls
13,977 gal 333 bbls
32,909 gal 784 bbls
12,558 gal 299 bbls
4,008 gal 95 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Status:
The dart seat signature to isolate stage 24 was not seen so the job was shut down. A new dart
was then built. The dart was seated successfully on the next attempt and the stage was
completed as per design.
3S-606 - Torok - Interval 24
Interval Summary
Start Date/Time:
End Date/Time:
Steven Sanders
Craig Karpinski
Dan Faur
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Chad Burkett
Pad Percentage Design
Pad Percentage Actual
Proppant Summary
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Total Proppant Pumped* :
Pumps Ending Stage:
Final Fracture Gradient:
100M Pumped:
Flush 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.
Final 10 min:
Average Visc:
Proppant in Formation:
Final 15 min:
Wanli 16/20 Ceramic Pumped:
Pad Volume:
Average Surface Pressure:
30# Linear Volume:
Final 5 min:
Establish Stable Fluid Volume:
Average Missile Pressure:
Initial OA Pressure:
Initial Rate (Breakdown):
Max Proppant Concentration:
Pumps Starting Stage:
Pump Time:
30# Hybor G Volume:
Average Missile HHP:
Max OA Pressure:
Average BH Pressure:
Max Rate:
Max BH Pressure:
ISDP:
Dart/Ball Early :
Max Surface Pressure:
Initial BH Pressure (Breakdown):
Average Temp:
Average pH:
Average Rate:
Initial Surface Pressure (Breakdown):
Conoco Phillips - 3S-606 Interval Summary 23
CustomerFormationLeaseAPIDateWell SummaryWanli 16/20 Ceramic100M Total ProppantSurface PressurRate Visc Temp pHSurface PressurRate gal bbl gal bbl gal bbl gal bbl gal bbl lbs lbs lbs102553 32.6 23 88 8.9 3415 37.3 75,364 1,794 11,517 274 1,205 29 88,086 2,097 201,214 3,676 204,890 112558 34.6 22 90 9.0 3487 37.5 67,980 1,619 67,980 1,619 200,046 3,812 203,858 123023 35.9 23 86 8.9 3434 37.3 66,834 1,591 10,298 245 77,132 1,836 200,717 4,063 204,780 132663 34.7 24 107 9.0 3079 37.4 73,679 1,754 22 1 1,205 29 74,906 1,783 200,356 5,337 205,693 142610 34.9 22 104 8.9 2997 37.4 68,411 1,629 68,411 1,629 201,230 3,968 205,198 152469 34.9 22 110 9.0 2957 37.8 68,453 1,630 68,453 1,630 199,224 3,868 203,092 162246 34.8 22 111 8.9 2681 37.3 68,782 1,638 68,782 1,638 196,878 3,531 200,409 172247 35.9 21 107 8.9 2692 37.4 47,772 1,137 8,696 207 56,468 1,344 140,107 3,872 143,979 182209 31.4 24 105 8.9 2633 37.8 55,440 1,320 9,319 222 1,205 29 65,964 1,571 139,858 3,940 143,798 192516 34.5 22 111 9.0 4017 37.9 49,146 1,170 49,146 1,170 142,308 3,763 146,071 202294 34.6 21 109 9.0 3246 37.4 49,415 1,177 49,415 1,177 142,816 4,033 146,849 212372 36.1 22 108 9.0 3721 37.5 47,895 1,140 7,304 174 55,199 1,314 142,310 4,562 146,872 221649 30.7 25 87 9.0 2255 37.4 53,466 1,273 6,888 164 1,205 29 61,559 1,466 140,675 3,625 144,300 231661 35.8 23 98 8.9 1952 37.3 50,310 1,198 50,310 1,198 143,762 3,864 147,626 242167 35.4 22 95 8.9 4069 37.2 53,958 1,285 12,558 299 66,516 1,584 154,559 2,508 157,067 Minimum47772 1137 22 1 1205 29 49146 1170 139858 2508 143798 Average59794 1424 8325 198 1205 29 64555 1537 169737 3895 173632 Maximum75364 1794 12558 299 1205 29 88086 2097 201230 5337 205693 Wanli 16/20 Ceramic100M Total ProppantPressure Rate Visc Temp pH Pressure Rate gal bbl gal bbl gal bbl gal bbl gal bbl lbs lbs TotalPlanned905,486 21,559 62,292 1,483 4,003 95 0 0 971,781 23,138 2,520,000 60,000 2,584,000Recorded1933 21.2 15 53 5.28 5495 37.9 896,905 21,355 66,602 1,586 4,819 115 0 0 968,326 23,0552,546,060 58,422 2,604,482Weight Tickets2,480,250 66,000 2,546,250** Proppant is billed from Weight Ticket volumes** IFS numbers for proppant are taken from software calculations based on multiple Total FluidFluids ProppantsFluids ProppantsFreeze Protect Total FluidProduced Water Freeze ProtectProduced WaterAverage Max30# Hybor G 30# Linear30# Hybor G 30# LinearIntervalAverage MaxMay 29, 202450-103-208703S-606TorokConoco Phillips Conoco Phillips - 3S-606 Fluid System-Proppant Summary 24
<-Paste Interval 10 Plots HereConoco Phillips - 3S-606 Interval 10 Plots 25
<-Paste Interval 10 Plots HereConoco Phillips - 3S-606 Interval 10 Plots 26
<-Paste Interval 10 Plots HereConoco Phillips - 3S-606 Interval 10 Plots 27
<-Paste Interval 10 Plots HereConoco Phillips - 3S-606 Interval 10 Plots 28
Conoco Phillips - 3S-606 Interval 10 Plots 29
Conoco Phillips - 3S-606 Interval 10 Plots 30
Conoco Phillips - 3S-606 Interval 10 Plots 31
Conoco Phillips - 3S-606 Interval 10 Plots 32
<-Paste Interval 11 Plots HereConoco Phillips - 3S-606 Interval 11 Plots 33
<-Paste Interval 11 Plots HereConoco Phillips - 3S-606 Interval 11 Plots 34
<-Paste Interval 11 Plots HereConoco Phillips - 3S-606 Interval 11 Plots 35
<-Paste Interval 11 Plots HereConoco Phillips - 3S-606 Interval 11 Plots 36
<-Paste Interval 12 Plots HereConoco Phillips - 3S-606 Interval 12 Plots 37
<-Paste Interval 12 Plots HereConoco Phillips - 3S-606 Interval 12 Plots 38
<-Paste Interval 12 Plots HereConoco Phillips - 3S-606 Interval 12 Plots 39
<-Paste Interval 12 Plots HereConoco Phillips - 3S-606 Interval 12 Plots 40
<-Paste Interval 13 Plots HereConoco Phillips - 3S-606 Interval 13 Plots 41
<-Paste Interval 13 Plots HereConoco Phillips - 3S-606 Interval 13 Plots 42
<-Paste Interval 13 Plots HereConoco Phillips - 3S-606 Interval 13 Plots 43
<-Paste Interval 13 Plots HereConoco Phillips - 3S-606 Interval 13 Plots 44
Conoco Phillips - 3S-606 Interval 13 Plots 45
Conoco Phillips - 3S-606 Interval 13 Plots 46
Conoco Phillips - 3S-606 Interval 13 Plots 47
Conoco Phillips - 3S-606 Interval 13 Plots 48
<-Paste Interval 14 Plots HereConoco Phillips - 3S-606 Interval 14 Plots 49
<-Paste Interval 14 Plots HereConoco Phillips - 3S-606 Interval 14 Plots 50
<-Paste Interval 14 Plots HereConoco Phillips - 3S-606 Interval 14 Plots 51
<-Paste Interval 14 Plots HereConoco Phillips - 3S-606 Interval 14 Plots 52
<-Paste Interval 15 Plots HereConoco Phillips - 3S-606 Interval 15 Plots 53
<-Paste Interval 15 Plots HereConoco Phillips - 3S-606 Interval 15 Plots 54
<-Paste Interval 15 Plots HereConoco Phillips - 3S-606 Interval 15 Plots 55
<-Paste Interval 15 Plots HereConoco Phillips - 3S-606 Interval 15 Plots 56
<-Paste Interval 16 Plots HereConoco Phillips - 3S-606 Interval 16 Plots 57
<-Paste Interval 16 Plots HereConoco Phillips - 3S-606 Interval 16 Plots 58
<-Paste Interval 16 Plots HereConoco Phillips - 3S-606 Interval 16 Plots 59
<-Paste Interval 16 Plots HereConoco Phillips - 3S-606 Interval 16 Plots 60
<-Paste Interval 17 Plots HereConoco Phillips - 3S-606 Interval 17 Plots 61
<-Paste Interval 17 Plots HereConoco Phillips - 3S-606 Interval 17 Plots 62
<-Paste Interval 17 Plots HereConoco Phillips - 3S-606 Interval 17 Plots 63
<-Paste Interval 17 Plots HereConoco Phillips - 3S-606 Interval 17 Plots 64
<-Paste Interval 18 Plots HereConoco Phillips - 3S-606 Interval 18 Plots 65
<-Paste Interval 18 Plots HereConoco Phillips - 3S-606 Interval 18 Plots 66
<-Paste Interval 18 Plots HereConoco Phillips - 3S-606 Interval 18 Plots 67
<-Paste Interval 18 Plots HereConoco Phillips - 3S-606 Interval 18 Plots 68
Conoco Phillips - 3S-606 Interval 18 Plots 69
Conoco Phillips - 3S-606 Interval 18 Plots 70
Conoco Phillips - 3S-606 Interval 18 Plots 71
Conoco Phillips - 3S-606 Interval 18 Plots 72
<-Paste Interval 19 Plots HereConoco Phillips - 3S-606 Interval 19 Plots 73
<-Paste Interval 19 Plots HereConoco Phillips - 3S-606 Interval 19 Plots 74
<-Paste Interval 19 Plots HereConoco Phillips - 3S-606 Interval 19 Plots 75
<-Paste Interval 19 Plots HereConoco Phillips - 3S-606 Interval 19 Plots 76
<-Paste Interval 20 Plots HereConoco Phillips - 3S-606 Interval 20 Plots 77
<-Paste Interval 20 Plots HereConoco Phillips - 3S-606 Interval 20 Plots 78
<-Paste Interval 20 Plots HereConoco Phillips - 3S-606 Interval 20 Plots 79
<-Paste Interval 20 Plots HereConoco Phillips - 3S-606 Interval 20 Plots 80
<-Paste Interval 21 Plots HereConoco Phillips - 3S-606 Interval 21 Plots 81
<-Paste Interval 21 Plots HereConoco Phillips - 3S-606 Interval 21 Plots 82
<-Paste Interval 21 Plots HereConoco Phillips - 3S-606 Interval 21 Plots 83
<-Paste Interval 21 Plots HereConoco Phillips - 3S-606 Interval 21 Plots 84
<-Paste Interval 22 Plots HereConoco Phillips - 3S-606 Interval 22 Plots 85
<-Paste Interval 22 Plots HereConoco Phillips - 3S-606 Interval 22 Plots 86
<-Paste Interval 22 Plots HereConoco Phillips - 3S-606 Interval 22 Plots 87
<-Paste Interval 22 Plots HereConoco Phillips - 3S-606 Interval 22 Plots 88
Conoco Phillips - 3S-606 Interval 22 Plots 89
Conoco Phillips - 3S-606 Interval 22 Plots 90
Conoco Phillips - 3S-606 Interval 22 Plots 91
Conoco Phillips - 3S-606 Interval 22 Plots 92
<-Paste Interval 23 Plots HereConoco Phillips - 3S-606 Interval 23 Plots 93
<-Paste Interval 23 Plots HereConoco Phillips - 3S-606 Interval 23 Plots 94
<-Paste Interval 23 Plots HereConoco Phillips - 3S-606 Interval 23 Plots 95
<-Paste Interval 23 Plots HereConoco Phillips - 3S-606 Interval 23 Plots 96
<-Paste Interval 24 Plots HereConoco Phillips - 3S-606 Interval 24 Plots 97
<-Paste Interval 24 Plots HereConoco Phillips - 3S-606 Interval 24 Plots 98
<-Paste Interval 24 Plots HereConoco Phillips - 3S-606 Interval 24 Plots 99
<-Paste Interval 24 Plots HereConoco Phillips - 3S-606 Interval 24 Plots 100
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Event Log
Sand Seive
Fann 15 Minute
Field Break Test
Real-Time QC
Well Summary
Stimulation Treatment
Appendix
Chemical Summary
Planned Design
Water Straps
Water Analysis
Prepared for: Manabu Nozaki
June 10, 2024
Harrison Bay County, AK
Conoco Phillips
3S-606
Intervals 1-24
Torok Formation
API: 50-103-20870
Conoco Phillips - 3S-606 Appendix 101
Interval Date
Designed
Proppant
(lbs)
Proppant in
Formation (lbs)
Designed Fluid
(bbl)
Vol Clean
(bbl)
Vol Slurry
(bbl)
Pad
Percentage
Design
Pad
Percentage
Actual
Proppant
Aggressivness (lb/bbl
Clean)
Top
Packer (ft)
Bottom
Packer (ft)
Fluid
System
10 5/29/2024 204,000 204,890 2,122 2097 2,315 32.0 31 191 14882 15383 Hybor
11 5/29/2024 204,000 203,858 1,598 1619 1,835 32.0 31 195 14364 14861 Hybor
12 5/29/2024 204,000 204,780 1,810 1836 2,054 32.0 32 197 13843 14343 Hybor
13 5/30/2024 204,000 205,693 1,852 1783 2,002 32.0 31 193 13323 13824 Hybor
14 5/30/2024 204,000 205,198 1,598 1629 1,847 32.0 31 195 12802 13302 Hybor
15 5/30/2024 204,000 203,092 1,598 1630 1,846 32.0 31 193 12282 12781 Hybor
16 5/30/2024 204,000 200,409 1,598 1638 1,851 32.0 31 190 11761 12262 Hybor
17 5/30/2024 144,000 143,979 1,307 1344 1,497 32.5 32 192 11238 11739 Hybor
18 5/31/2024 144,000 143,798 1,577 1571 1723.355 32.5 32 191 10718 11217 Hybor
19 5/31/2024 144,000 146,071 1,136 1170 1325.346 32.5 32 197 10195 10696 Hybor
20 5/31/2024 144,000 146,849 1,136 1177 1332.583 32.5 32 194 9672 10174 Hybor
21 5/31/2024 144,000 146,872 1,275 1314 1470.335 32.5 31 192 9110 9651 Hybor
22 6/10/2024 144,000 144,300 1,390 1466 1619.01 32.5 31 191 8546 9089 Hybor
23 6/10/2024 144,000 147,626 1,136 1198 1354.714 32.5 31 192 7984 8526 Hybor
24 6/10/2024 144,000 157,067 2,004 1584 1750.564 49.1 30 197 7544 7962 Hybor
3S-606 Interval Highlights
Conoco Phillips - 3S-606 Well Summary 102
CustomerConoco Phillips FormationTorokLease3S-606API50-103-20870DateInterval Summary - Chemicals CL-28M Losurf-300D MO-67 Cat-3 BA-20 WG-36 OPTIFLO-III OPTIFLO-II BE-6(gal) (gal) (gal) (gal) (gal) (lbs) (lbs) (lbs) (lbs)Prime Up0 0 0 0 0 0 0 0 010177 98 89 1 17 2206 180 250 7511123 63 85 1 17 1855 170 180 012142 69 46 1 16 2002 170 250 013171 83 84 2 20 2221 150 150 7514102 70 68 1 17 1855 160 210 015147 69 65 2 18 1864 130 190 016143 64 79 2 18 1865 120 190 01786 45 54 1 10 1383 100 180 018110 70 69 1 13 1957 150 180 71998 50 45 1 11 1317 110 150 -2097 48 49 2 10 1347 110 150 -2180 42 43 1 10 1423 110 150 -22124 26 66 7 16 1770 120 144 023100 59 61 1 17 1439 100 140 -2484 90 29 7 7 1683 160 186 -Total 1784 946 932 31 217 26187 2040 2700 157w/o Prime Up1784 946 932 31 217 26187 2040 2700 157Interval5/29/2024Dry AdditivesLiquid AdditivesConoco Phillips - 3S-606 Chemical Summary 103
CUSTOMERConoco Phillips APIBFD (lb/ga8.54LAT 70.3942492LEASE3S-606SALES ORDEBHST (°F)143LONG-150.195566FORMATIONTorokDATEMax Press8000*Exceeds 80% of burst pressure*Prop Slurry Design CleanDesign CleaDesign Slurry Design Prop Stage Interval CL-28M Losurf-300D MO-67 Cat-3 BA-20 WG-36 OPTIFLO-III OPTIFLO-II BE-6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer Catalyst Freeze ProtectInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)######Liquid Additives Dry Additives50-103-20870909244035/90937263210-1 Shut-In Shut-In1:28:38 10-2 Produced Water Prime Up Pressure Test 5 1,000 24 24 0:04:46 1:28:38 10-3 Shut-In Shut-In 1:23:52 10-4 30# Linear Spacer and Ball Drop 15 1,260 30 30 0:02:00 1:23:52 1.00 30.00 2.00 2.00 0.1510-5 30# Linear Displace Ball to Seat 15 9,671 230 230 0:15:21 1:21:52 1.00 30.00 2.00 2.00 0.1510-6 30# Linear DFIT 10 1,680 40 40 0:04:00 1:06:31 1.00 30.00 2.00 2.00 0.1510-7 Shut-In Shut-In 1:02:31 10-8 30# Hybor G Establish Stable Fluid 15 8,400 200 200 0:13:20 1:02:31 2.00 1.00 1.10 0.33 30.00 2.00 2.00 0.1510-9 30# Hybor G Pad 37 7,810 186 186 0:05:02 0:49:11 2.00 1.00 1.10 0.33 30.00 2.00 2.00 0.1510-10 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 0:44:10 2.00 1.00 1.10 0.33 30.00 2.00 2.00 0.1510-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:33:45 2.00 1.00 1.10 0.33 30.00 2.00 2.00 0.1510-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:32:24 2.00 1.00 1.10 0.33 30.00 2.00 2.00 0.1510-13 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:30:39 2.00 1.00 1.10 0.33 30.00 2.00 2.00 0.1510-14 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:27:43 2.00 1.00 1.10 0.33 30.00 2.00 2.00 0.1510-15 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:24:02 2.00 1.00 1.10 0.33 30.00 2.00 2.00 0.1510-16 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:20:09 2.00 1.00 1.10 0.33 30.00 2.00 4.00 0.1510-17 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:15:52 2.00 1.00 1.10 0.33 30.00 2.00 4.00 0.1510-18 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:11:27 2.00 1.00 1.10 0.33 30.00 2.00 4.00 0.1510-19 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:06:42 2.00 1.00 1.10 0.33 30.00 2.00 4.00 0.1510-20 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:03:21 2.00 1.00 1.10 0.25 0.33 30.00 2.00 4.00 0.1510-21 30# Hybor G Spacer and Ball Drop 37 1,260 30 30 0:00:49 0:00:49 2.00 1.00 1.10 0.25 0.33 30.00 2.00 4.00 0.1511-1 30# Hybor G Pad 37 7,810 186 186 0:05:02 0:49:11 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1511-2 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 0:44:10 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1511-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:33:45 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1511-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:32:24 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1511-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:30:39 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1511-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:27:43 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1511-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:24:02 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1511-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:20:09 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1511-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:15:52 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1511-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:11:27 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1511-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:06:42 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1511-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:03:21 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1511-13 30# Hybor G Spacer and Ball Drop 37 1,260 30 30 0:00:49 0:00:49 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1512-1 30# Hybor G Pad 37 7,810 186 186 0:05:02 0:54:54 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1512-2 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 0:49:52 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1512-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:39:27 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1512-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:38:06 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1512-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:36:21 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1512-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:33:26 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1512-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:29:44 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1512-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:25:51 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1512-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:21:35 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1512-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:17:09 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1512-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:12:24 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1512-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:09:04 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1512-13 30# Linear Flush 37 10,129 241 241 0:06:31 0:06:31 1.00 0.25 30.00 2.00 4.00 0.1512-14 Produced Water Freeze Protect 37 1 0 0 0:00:00 0:00:00 4.0012-15 Shut-In Shut-In 37Interval 12Torok@ 14092.08 - 14095.94 ft 142.2 °FInterval 10Torok@ 15129.98 - 15133.84 ft 142.2 °FInterval 11Torok@ 14609.01 - 14612.87 ft 142.2 °FConoco Phillips - 3S-606 Planned Design 104
CUSTOMERConoco Phillips APIBFD (lb/ga8.54LAT 70.3942492LEASE3S-606SALES ORDEBHST (°F)143LONG-150.195566FORMATIONTorokDATEMax Press8000*Exceeds 80% of burst pressure*Prop Slurry Design CleanDesign CleaDesign Slurry Design Prop Stage Interval CL-28M Losurf-300D MO-67 Cat-3 BA-20 WG-36 OPTIFLO-III OPTIFLO-II BE-6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer Catalyst Freeze ProtectInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)######Liquid Additives Dry Additives50-103-20870909244035/90937263213-1 Shut-In Shut-In1:09:17 13-2 Produced Water Prime Up Pressure Test 5 1,000 24 24 0:04:46 1:09:17 13-3 Shut-In Shut-In 1:04:31 13-4 30# Linear Spacer and Ball Drop 15 1,260 30 30 0:02:00 1:04:31 1.00 30.00 2.00 2.00 0.1513-5 30# Hybor G Establish Stable Fluid 15 8,400 200 200 0:13:20 1:02:31 2.00 1.00 1.20 0.25 0.33 30.00 2.00 2.00 0.1513-6 30# Hybor G Pad 37 7,810 186 186 0:05:02 0:49:11 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1513-7 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 0:44:10 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1513-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:33:45 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1513-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:32:24 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1513-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:30:39 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1513-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:27:43 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1513-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:24:02 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1513-13 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:20:09 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1513-14 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:15:52 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1513-15 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:11:27 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1513-16 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:06:42 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1513-17 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:03:21 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1513-18 30# Hybor G Spacer and Ball Drop 37 1,260 30 30 0:00:49 0:00:49 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1514-1 30# Hybor G Pad 37 7,810 186 186 0:05:02 0:49:11 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1514-2 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 0:44:10 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1514-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:33:45 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1514-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:32:24 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1514-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:30:39 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1514-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:27:43 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1514-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:24:02 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1514-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:20:09 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1514-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:15:52 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1514-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:11:27 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1514-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:06:42 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1514-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:03:21 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1514-13 30# Hybor G Spacer and Ball Drop 37 1,260 30 30 0:00:49 0:00:49 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1515-1 30# Hybor G Pad 37 7,810 186 186 0:05:02 0:49:11 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1515-2 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 0:44:10 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1515-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:33:45 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1515-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:32:24 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1515-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:30:39 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1515-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:27:43 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1515-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:24:02 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1515-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:20:09 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1515-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:15:52 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1515-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:11:27 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1515-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:06:42 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1515-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:03:21 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1515-13 30# Hybor G Spacer and Ball Drop 37 1,260 30 30 0:00:49 0:00:49 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.15Interval 13Torok@ 13571.43 - 13575.29 ft 142.2 °FInterval 14Torok@ 13050.33 - 13054.19 ft 142.2 °FInterval 15Torok@ 12530.39 - 12534.25 ft 142.3 °FConoco Phillips - 3S-606 Planned Design 105
CUSTOMERConoco Phillips APIBFD (lb/ga8.54LAT 70.3942492LEASE3S-606SALES ORDEBHST (°F)143LONG-150.195566FORMATIONTorokDATEMax Press8000*Exceeds 80% of burst pressure*Prop Slurry Design CleanDesign CleaDesign Slurry Design Prop Stage Interval CL-28M Losurf-300D MO-67 Cat-3 BA-20 WG-36 OPTIFLO-III OPTIFLO-II BE-6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer Catalyst Freeze ProtectInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)######Liquid Additives Dry Additives50-103-20870909244035/90937263216-1 30# Hybor G Pad 37 7,810 186 186 0:05:02 0:49:11 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1516-2 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 0:44:10 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1516-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:33:45 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1516-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:32:24 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1516-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:30:39 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1516-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:27:43 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1516-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:24:02 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1516-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:20:09 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1516-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:15:52 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1516-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:11:27 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1516-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:06:42 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1516-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:03:21 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1516-13 30# Hybor G Spacer and Ball Drop 37 1,260 30 30 0:00:49 0:00:49 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1517-1 30# Hybor G Pad 37 1,000 24 24 0:00:39 0:39:33 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1517-2 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 0:38:55 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1517-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 1,400 33 35 1,400 0:00:57 0:28:30 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1517-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 1,750 42 45 3,500 0:01:14 0:27:33 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1517-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 2,800 67 76 8,400 0:02:03 0:26:20 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1517-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 3,395 81 95 13,580 0:02:35 0:24:17 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1517-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 3,500 83 100 15,750 0:02:43 0:21:42 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1517-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 3,787 90 110 18,935 0:03:00 0:18:59 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1517-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 3,850 92 114 21,175 0:03:06 0:15:59 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1517-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 4,060 97 123 24,360 0:03:20 0:12:53 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1517-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 2,800 67 86 18,200 0:02:20 0:09:34 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1517-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 2,100 50 66 14,700 0:01:47 0:07:14 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1517-13 30# Linear Flush 37 8,462 201 201 0:05:27 0:05:27 1.00 30.00 2.00 4.00 0.1517-14 Produced Water Freeze Protect 3717-15 Shut-In Shut-In 3718-1 Shut-In Shut-In 1:09:13 18-2 Produced Water Prime Up Pressure Test 5 1,000 24 24 0:04:46 1:09:13 18-3 Shut-In Shut-In1:04:27 18-4 30# Linear Spacer and Ball Drop 15 42 1 1 0:00:04 1:04:27 1.00 30.00 2.00 2.00 0.1518-5 30# Linear Displace Ball to Seat 15 7,009 167 167 0:11:08 1:04:23 1.00 30.00 2.00 2.00 0.1518-6 30# Linear DFIT 10 2,100 50 50 0:05:00 0:53:15 1.00 30.00 2.00 2.00 0.1518-7 Shut-In Shut-In 0:48:15 18-8 30# Hybor G Establish Stable Fluid 15 8,400 200 200 0:13:20 0:48:15 2.00 1.00 1.00 0.33 30.00 2.00 2.00 0.1518-9 30# Hybor G Pad 37 1,000 24 24 0:00:39 0:34:55 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1518-10 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 0:34:17 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1518-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 1,400 33 35 1,400 0:00:57 0:23:52 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1518-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 1,750 42 45 3,500 0:01:14 0:22:55 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1518-13 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 2,800 67 76 8,400 0:02:03 0:21:42 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1518-14 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 3,395 81 95 13,580 0:02:35 0:19:39 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1518-15 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 3,500 83 100 15,750 0:02:43 0:17:04 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1518-16 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 3,787 90 110 18,935 0:03:00 0:14:21 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1518-17 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 3,850 92 114 21,175 0:03:06 0:11:21 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1518-18 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 4,060 97 123 24,360 0:03:20 0:08:15 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1518-19 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 2,800 67 86 18,200 0:02:20 0:04:56 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1518-20 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 2,100 50 66 14,700 0:01:47 0:02:36 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1518-21 30# Hybor G Spacer and Ball Drop 37 1,260 30 30 0:00:49 0:00:49 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.15Interval 16Torok@ 12009.32 - 12013.18 ft 142.4 °FInterval 17Torok@ 11486.71 - 11490.57 ft 142.4 °FInterval 18Torok@ 10964.74 - 10968.6 ft 142.5 °FConoco Phillips - 3S-606 Planned Design 106
CUSTOMERConoco Phillips APIBFD (lb/ga8.54LAT 70.3942492LEASE3S-606SALES ORDEBHST (°F)143LONG-150.195566FORMATIONTorokDATEMax Press8000*Exceeds 80% of burst pressure*Prop Slurry Design CleanDesign CleaDesign Slurry Design Prop Stage Interval CL-28M Losurf-300D MO-67 Cat-3 BA-20 WG-36 OPTIFLO-III OPTIFLO-II BE-6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer Catalyst Freeze ProtectInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)######Liquid Additives Dry Additives50-103-20870909244035/90937263219-1 30# Hybor G Pad 37 1,000 24 24 0:00:39 0:34:55 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1519-2 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 0:34:17 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1519-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 1,400 33 35 1,400 0:00:57 0:23:52 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1519-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 1,750 42 45 3,500 0:01:14 0:22:55 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1519-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 2,800 67 76 8,400 0:02:03 0:21:42 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1519-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 3,395 81 95 13,580 0:02:35 0:19:39 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1519-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 3,500 83 100 15,750 0:02:43 0:17:04 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1519-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 3,787 90 110 18,935 0:03:00 0:14:21 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1519-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 3,850 92 114 21,175 0:03:06 0:11:21 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1519-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 4,060 97 123 24,360 0:03:20 0:08:15 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1519-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 2,800 67 86 18,200 0:02:20 0:04:56 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1519-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 2,100 50 66 14,700 0:01:47 0:02:36 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1519-13 30# Hybor G Spacer and Ball Drop 37 1,260 30 30 0:00:49 0:00:49 2.00 1.00 1.00 0.25 0.33 30.00 2.00 4.00 0.1520-1 30# Hybor G Pad 37 1,000 24 24 0:00:39 0:34:55 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1520-2 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 0:34:17 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1520-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 1,400 33 35 1,400 0:00:57 0:23:52 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1520-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 1,750 42 45 3,500 0:01:14 0:22:55 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1520-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 2,800 67 76 8,400 0:02:03 0:21:42 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1520-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 3,395 81 95 13,580 0:02:35 0:19:39 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1520-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 3,500 83 100 15,750 0:02:43 0:17:04 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1520-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 3,787 90 110 18,935 0:03:00 0:14:21 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1520-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 3,850 92 114 21,175 0:03:06 0:11:21 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1520-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 4,060 97 123 24,360 0:03:20 0:08:15 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1520-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 2,800 67 86 18,200 0:02:20 0:04:56 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1520-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 2,100 50 66 14,700 0:01:47 0:02:36 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1520-13 30# Hybor G Spacer and Ball Drop 37 1,260 30 30 0:00:49 0:00:49 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1521-1 30# Hybor G Pad 37 1,000 24 24 0:00:39 0:38:41 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1521-2 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 0:38:02 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1521-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 1,400 33 35 1,400 0:00:57 0:27:37 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1521-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 1,750 42 45 3,500 0:01:14 0:26:41 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1521-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 2,800 67 76 8,400 0:02:03 0:25:27 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1521-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 3,395 81 95 13,580 0:02:35 0:23:24 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1521-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 3,500 83 100 15,750 0:02:43 0:20:49 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1521-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 3,787 90 110 18,935 0:03:00 0:18:06 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1521-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 3,850 92 114 21,175 0:03:06 0:15:07 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1521-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 4,060 97 123 24,360 0:03:20 0:12:01 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1521-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 2,800 67 86 18,200 0:02:20 0:08:41 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1521-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 2,100 50 66 14,700 0:01:47 0:06:21 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1521-13 30# Linear Flush 37 7,101 169 169 0:04:34 0:04:34 1.00 30.00 2.00 4.00 0.1521-14 Produced Water Freeze Protect 37 1 0 0 0:00:00 0:00:00 21-15 Shut-In Shut-In 37Interval 21Torok@ 9358.46 - 9362.32 ft 142.8 °FInterval 19Torok@ 10443.93 - 10447.79 ft 142.5 °FInterval 20Torok@ 9920.79 - 9924.65 ft 142.6 °FConoco Phillips - 3S-606 Planned Design 107
CUSTOMERConoco Phillips APIBFD (lb/ga8.54LAT 70.3942492LEASE3S-606SALES ORDEBHST (°F)143LONG-150.195566FORMATIONTorokDATEMax Press8000*Exceeds 80% of burst pressure*Prop Slurry Design CleanDesign CleaDesign Slurry Design Prop Stage Interval CL-28M Losurf-300D MO-67 Cat-3 BA-20 WG-36 OPTIFLO-III OPTIFLO-II BE-6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer Catalyst Freeze ProtectInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)######Liquid Additives Dry Additives50-103-20870909244035/90937263222-1 Shut-In Shut-In0:55:01 22-2 Produced Water Prime Up Pressure Test 5 1,000 24 24 0:04:46 0:55:01 22-3 Shut-In Shut-In 0:50:15 22-4 30# Linear Spacer and Ball Drop 15 1,260 30 30 0:02:00 0:50:15 1.00 30.00 2.00 2.00 0.1522-5 30# Hybor G Establish Stable Fluid 15 8,400 200 200 0:13:20 0:48:15 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1522-6 30# Hybor G Pad 37 1,000 24 24 0:00:39 0:34:55 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1522-7 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 0:34:17 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1522-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 1,400 33 35 1,400 0:00:57 0:23:52 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1522-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 1,750 42 45 3,500 0:01:14 0:22:55 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1522-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 2,800 67 76 8,400 0:02:03 0:21:42 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1522-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 3,395 81 95 13,580 0:02:35 0:19:39 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1522-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 3,500 83 100 15,750 0:02:43 0:17:04 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1522-13 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 3,787 90 110 18,935 0:03:00 0:14:21 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1522-14 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 3,850 92 114 21,175 0:03:06 0:11:21 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1522-15 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 4,060 97 123 24,360 0:03:20 0:08:15 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1522-16 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 2,800 67 86 18,200 0:02:20 0:04:56 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1522-17 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 2,100 50 66 14,700 0:01:47 0:02:36 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1522-18 30# Hybor G Spacer and Ball Drop 37 1,260 30 30 0:00:49 0:00:49 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1523-1 30# Hybor G Pad 37 1,000 24 24 0:00:39 0:34:55 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1523-2 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 0:34:17 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1523-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 1,400 33 35 1,400 0:00:57 0:23:52 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1523-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 1,750 42 45 3,500 0:01:14 0:22:55 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1523-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 2,800 67 76 8,400 0:02:03 0:21:42 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1523-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 3,395 81 95 13,580 0:02:35 0:19:39 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1523-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 3,500 83 100 15,750 0:02:43 0:17:04 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1523-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 3,787 90 110 18,935 0:03:00 0:14:21 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1523-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 3,850 92 114 21,175 0:03:06 0:11:21 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1523-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 4,060 97 123 24,360 0:03:20 0:08:15 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1523-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 2,800 67 86 18,200 0:02:20 0:04:56 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1523-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 2,100 50 66 14,700 0:01:47 0:02:36 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1523-13 30# Hybor G Spacer and Ball Drop 37 1,260 30 30 0:00:49 0:00:49 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1524-1 30# Hybor G Pad 37 1,000 24 24 0:00:39 1:12:15 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1524-2 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 1:11:36 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1524-3 30# Linear Flush 15 6,159 147 147 0:09:47 1:01:11 1.00 1.20 30.00 2.00 2.00 0.1524-4 30# Hybor G Establish Stable Fluid 15 8,400 200 200 0:13:20 0:51:25 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1524-5 30# Hybor G Pad 37 1,000 24 24 0:00:39 0:38:05 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1524-6 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 0:37:26 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1524-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 1,400 33 35 1,400 0:00:57 0:27:01 2.00 1.00 1.20 0.33 30.00 2.00 2.00 0.1524-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 1,750 42 45 3,500 0:01:14 0:26:05 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1524-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 2,800 67 76 8,400 0:02:03 0:24:51 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1524-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 3,395 81 95 13,580 0:02:35 0:22:48 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1524-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 3,500 83 100 15,750 0:02:43 0:20:13 2.00 1.00 1.20 0.33 30.00 2.00 4.00 0.1524-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 3,787 90 110 18,935 0:03:00 0:17:30 2.00 1.00 1.20 0.25 0.33 30.00 2.00 4.00 0.1524-13 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 3,850 92 114 21,175 0:03:06 0:14:31 2.00 1.00 1.00 2.00 0.33 30.00 2.00 4.00 0.1524-14 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 4,060 97 123 24,360 0:03:20 0:11:25 2.00 1.00 1.00 0.25 0.33 30.00 2.00 2.00 0.1524-15 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 2,800 67 86 18,200 0:02:20 0:08:05 2.00 1.00 1.00 0.33 30.00 2.00 4.00 0.1524-16 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 2,100 50 66 14,700 0:01:47 0:05:45 2.00 1.00 1.00 0.25 0.33 30.00 2.00 2.00 0.1524-17 30# Linear Flush 37 6,159 147 147 0:03:58 0:03:58 1.00 30.00 2.00 2.00 0.1524-18 Produced Water Freeze Protect 10 1 0 0 0:00:00 0:00:00 24-19 Shut-In Shut-InInterval 22Torok@ 8790.6 - 8794.46 ft 143 °FInterval 24Torok@ 7751.56 - 7755.42 ft 142.5 °FInterval 23Torok@ 8232.54 - 8236.4 ft 143.1 °FConoco Phillips - 3S-606 Planned Design 108
Customer:Well:Date:Formation:SO#:Tank Type Water Source Inches Gallons Barrels Temperature (°F) Inches Gallons Barrels1 Atigan 3S PW 65 12,211 291 15 2,540 602 Wichita 3S PW 63 12,390 295 130 15 2,856 683 Wichita 3S PW 91 18,270 435 128 15 2,856 684 Wichita 3S PW 73 14,490 345 130 15 2,856 685 Wichita 3S PW 90 18,060 430 129 15 2,856 686 Wichita 3S PW 94 18,900 450 128 15 2,856 687 Wichita 3S PW 88 17,640 420 130 93 18,690 4458 Wichita 3S PW 69 13,650 325 128 103 20,790 4959 Wichita 3S PW 93 18,690 445 130 102 20,580 49010 Wichita 3S PW 92 18,480 440 129 15 2,856 6811 Wichita 3S PW 101 20,370 485 127 103 20,790 49512 Wichita 3S PW 69 13,650 325 129 103 20,790 49513 Wichita 3S PW 78 15,540 370 127 33 6,258 14914 Wichita 3S PW 93 18,690 445 129 16 3,024 7215 Wichita 3S PW 85 17,010 405 127 15 2,856 6816 Wichita 3S PW 75 14,910 355 130 15 2,856 6817 Atigan 3S PW 80 15,113 360 128 15 2,540 6018 Atigan 3S PW 81 15,306 364 128 15 2,540 6019 Wichita 3S PW 92 18,480 440 129 15 2,856 6820 Wichita 3S PW 93 18,690 445 128 15 2,856 6821 Wichita 3S PW 92 18,480 440 127 15 2,856 6822 Atigan 3S PW 70 13,178 314 13 2,174 5223 Atigan 3S PW 56 10,367 247 15 2,540 6024 Atigan 3S PW 27 4,730 113 15 2,540 6025 Atigan 3S PW 69 12,985 309 15 2,540 60Flow Rate Stop FlowingGallons Barrels Gallons Barrels Gallons Barrels Gallons Barrels390,280 9,292 159,751 3,804 0 0 230,530 5,489Location SummaryStarting VolumeEnding VolumeOn the Fly FlowingTotal UsedGeneral Beginning Strap Ending StrapOn the Fly Load SummaryDateStart flowingFlowing TempConoco Phillips 3S-6065/29/2204Torok909244035/909372632Conoco Phillips - 3S-606 Water Straps 5-29 109
Customer:Well:Date:Formation:SO#:Tank Type Water Source Inches Gallons Barrels Temperature (°F) Inches Gallons Barrels1 Atigan 3S PW 101 19,175 457 15 2,540 602 Wichita 3S PW 100 20,160 480 130 43 8,190 1953 Wichita 3S PW 101 20,370 485 128 43 8,190 1954 Wichita 3S PW 100 20,160 480 130 100 20,160 4805 Wichita 3S PW 100 20,160 480 129 100 20,160 4806 Wichita 3S PW 99 19,950 475 128 99 19,950 4757 Wichita 3S PW 100 20,160 480 130 100 20,160 4808 Wichita 3S PW 100 20,160 480 128 100 20,160 4809 Wichita 3S PW 102 20,580 490 130 102 20,580 49010 Wichita 3S PW 101 20,370 485 129 15 2,856 6811 Wichita 3S PW 103 20,790 495 127 91 18,270 43512 Wichita 3S PW 99 19,950 475 129 42 8,022 19113 Wichita 3S PW 96 19,320 460 127 15 2,856 6814 Wichita 3S PW 101 20,370 485 129 15 2,856 6815 Wichita 3S PW 100 20,160 480 127 15 2,856 6816 Wichita 3S PW 101 20,370 485 130 15 2,856 6817 Atigan 3S PW 100 18,981 452 128 15 2,540 6018 Atigan 3S PW 100 18,981 452 128 15 2,540 6019 Wichita 3S PW 100 20,160 480 129 15 2,856 6820 Wichita 3S PW 63 12,390 295 128 16 3,024 7221 Wichita 3S PW 67 13,230 315 127 15 2,856 6822 Atigan 3S PW 58 10,784 257 15 2,540 6023 Atigan 3S PW 56 10,367 247 15 2,540 6024 Atigan 3S PW 56 10,367 247 15 2,540 6025 Atigan 3S PW 56 10,367 247 15 2,540 60Flow Rate Stop Flowing8 13:45Gallons Barrels Gallons Barrels Gallons Barrels Gallons Barrels447,833 10,663 204,636 4,872 95,760 2280 338,957 8,070Location SummaryStarting VolumeEnding VolumeOn the Fly FlowingTotal Used30-May9:00130General Beginning Strap Ending StrapOn the Fly Load SummaryDateStart flowingFlowing TempConoco Phillips 3S-6065/30/2204Torok909244035/909372632Conoco Phillips - 3S-606 Water Straps 5-30 110
Customer:Well:Date:Formation:SO#:Tank Type Water Source Inches Gallons Barrels Temperature (°F) Inches Gallons Barrels1 Atigan 3S PW 96 18,208 434 130 15 2,540 602 Wichita 3S PW 103 20,790 495 135 15 2,856 683 Wichita 3S PW 103 20,790 495 133 15 2,856 684 Wichita 3S PW 96 19,320 460 119 15 2,856 685 Wichita 3S PW 100 20,160 480 124 24 4,536 1086 Wichita 3S PW 99 19,950 475 127 24 4,536 1087 Wichita 3S PW 85 17,010 405 24 4,536 1088 Wichita 3S PW 64 12,600 300 64 12,600 3009 Wichita 3S PW 103 20,790 495 106 92 18,480 44010 Wichita 3S PW 15 2,856 68 15 2,856 6811 Wichita 3S PW 90 18,060 430 110 44 8,400 20012 Wichita 3S PW 96 19,320 460 133 15 2,856 6813 Wichita 3S PW 82 16,380 390 15 2,856 6814 Wichita 3S PW 97 19,530 465 133 14 2,646 6315 Wichita 3S PW 0 0 0 016 Wichita 3S PW 93 18,690 445 130 15 2,856 6817 Atigan 3S PW 60 11,200 267 15 2,540 6018 Atigan 3S PW 63 11,824 282 15 2,540 6019 Wichita 3S PW 59 11,550 275 15 2,856 6820 Wichita 3S PW 59 11,550 275 15 2,856 6821 Wichita 3S PW 39 7,392 176 15 2,856 6822 Wichita 3S PW 33 6,258 149 15 2,856 68Flow Rate Stop FlowingGallons Barrels Gallons Barrels Gallons Barrels Gallons Barrels324,228 7,720 94,769 2,256 0 0 229,459 5,463Location SummaryStarting VolumeEnding VolumeOn the Fly FlowingTotal UsedNo Flow 5-31General Beginning Strap Ending StrapOn the Fly Load SummaryDateStart flowingFlowing TempConoco Phillips 3S-6065/31/2204Torok909244035/909372632Conoco Phillips - 3S-606 Water Straps 5-31 111
Customer:Well:Date:Formation:SO#:Tank Type Water Source Inches Gallons Barrels Temperature (°F) Inches Gallons Barrels1 Wichita 3S PW 95 19,110 455 92 10 1,890 452 Wichita 3S PW 96 19,320 460 95 10 1,890 453 Wichita 3S PW 98 19,740 470 97 10 1,890 454 Wichita 3S PW 99 19,950 475 95 10 1,890 455 Wichita 3S PW 106 21,000 500 98 10 1,890 456 Wichita 3S PW 104 21,000 500 100 10 1,890 457 Wichita 3S PW 102 20,580 490 116 15 2,856 688 Wichita 3S PW 98 19,740 470 125 15 2,856 689 Atigan 3S PW 97 18,401 438 115 79 14,919 35510 Atigan 3S PW 102 19,368 461 124 71 13,372 31811 Wichita 3S PW 97 19,530 465 119 71 14,070 33512 Wichita 3S PW 98 19,740 470 119 0 013 Wichita 3S PW 99 19,950 475 123 0 014 Wichita 3S PW 101 20,370 485 117 0 0Gallons Barrels Gallons Barrels Gallons Barrels Gallons Barrels277,821 6,615 59,435 1,415 0 0 218,386 5,200Location SummaryStarting VolumeEnding VolumeOn the Fly FlowingTotal UsedGeneral Beginning Strap Ending StrapConoco Phillips 3S-6066/11/2024Torok909244035/909372632Conoco Phillips - 3S-606 Water Straps 6-10 112
SpecificGravityTestingTemperatureDissolved Iron(Fe2+)Chloride(Cl-)Sulfate(SO42-)Calcium(Ca2+)Magnesium(Mg2+)TotalHardnessLinearViscosityWaterpHGelpHPost-CrosslinkpHCrosslink Bacteria- °F mg/L mg/L mg/L mg/L mg/L mg/L cP - - - (Y/N) BQ ValueTank #H2S present? Y/NHydrometer Digital ThermometerStrip Strip Strip TitrationTotal Hardness Minus CalciumTitration FANN-35 Probe Probe Probe - Mycometer1 N 1.020 92.0 0 15,160 400 800 600 1,400 1,2042 N 1.020 94.0 0 13,980 400 760 200 960 4,0043 N 1.018 95.0 0 15,160 200 800 120 920 3,7724 N 1.020 90.0 2 15,160 200 800 40 840 4,3865 N 1.020 89.0 2 15,160 200 720 80 800 4,3336 N 1.020 88.0 2 15,160 200 680 120 800 8407 N 1.022 95.0 2 15,160 200 760 40 800 3,1158 N 1.019 96.0 2 15,160 200 800 80 880 2,8709 N 1.020 95.0 2 13,950 200 640 160 800 3,08510 N 1.020 95.0 0 15,160 200 720 160 880 2,83611 N 1.022 95.0 2 15,160 400 680 280 960 25.0 7.00 7.30 9.00 Y 1,44112 N 1.020 95.0 0 15,160 400 640 200 840 25.0 7.00 7.30 9.00 Y 91613 N 1.018 95.0 2 15,160 400 600 160 760 55714 N 1.018 96.0 2 19,160 400 560 160 720 69815 N 1.018 96.0 2 15,160 200 800 120 920 92816 N 1.020 89.0 0 15,160 200 840 120 960 1,12817 N 1.020 88.0 0 13,980 200 760 240 1,000 1,00318 N 1.020 93.0 0 17,790 200 2,000 400 2,400 2,49419 N 1.020 92.0 0 20,830 200 1,600 400 2,000 12120 N 1.020 92.0 2 15,230 200 1,600 400 2,000 62521 N 1.020 92.0 2 20,830 200 1,600 400 2,000 11222 N 1.020 93.0 2 24,480 200 2,000 400 2,400 1,20223 N 1.020 93.0 0 24,480 200 2,400 0 2,400 53024 N 1.020 92.0 0 20,830 200 1,600 400 2,000 2,95625 N 1.020 92.0 0 26,600 200 2,400 400 2,800 1,035Average 1.020 1 17,169 248 1,102 227 1,330 26.0 7.06 7.41 9.01 - 1,848Maximum 1.022 2 26,600 400 2,400 600 2,800 30.0 7.10 7.60 9.10 - 4,386Minimum 1.018 0 13,950 200 560 0 720 24.00 7.00 7.20 9.00 - 112Range 0.004 2 12,650 200 1,840 600 2,080 6.0 0.10 0.40 0.10 - 4,274Alaska District Field QCPrejob Water Analysis on LocationCompany:Conoco Phillips Well Name:3S-606Water Source:3S PW Pad24.0 7.10 7.40 9.00 Y25.0 7.10 7.60 9.00 Y30.0 7.10 7.60 9.00 Y26.0 7.00 7.20 9.10 Y27.0 7.10 7.50 9.00 YConoco Phillips - 3S-606 Water Analysis 5-29 113
SpecificGravityTestingTemperatureDissolved Iron(Fe2+)Chloride(Cl-)Sulfate(SO42-)Calcium(Ca2+)Magnesium(Mg2+)TotalHardnessLinearViscosityWaterpHGelpHPost-CrosslinkpHCrosslink Bacteria- °F mg/L mg/L mg/L mg/L mg/L mg/L cP - - - (Y/N) BQ ValueTank #H2S present? Y/NHydrometer Digital ThermometerStrip Strip Strip TitrationTotal Hardness Minus CalciumTitration FANN-35 Probe Probe Probe - Mycometer1 N 1.018 95.0 0 14,100 200 360 200 560 6,6552 N 1.018 95.0 2 14,100 200 400 160 560 5,6713 N 1.018 95.0 2 15,230 200 560 -40 520 4,5444 N 1.018 95.0 2 14,100 200 400 200 600 4,2885 N 1.012 95.0 2 14,100 200 440 -40 400 7216 N 1.012 95.0 0 14,100 200 400 120 520 5597 N 1.022 95.0 0 15,160 200 760 40 800 3,1158 N 1.019 96.0 2 15,160 200 800 80 880 2,8709 N 1.020 95.0 2 13,950 200 640 160 800 3,08510 N 1.012 95.0 0 14,100 200 520 160 680 62711 N 1.022 95.0 2 15,160 400 680 280 960 25.0 7.00 7.30 9.00 Y 1,44112 N 1.020 95.0 0 15,160 400 640 200 840 25.0 7.00 7.30 9.00 Y 91613 N 1.018 95.0 2 15,160 400 600 160 760 55714 N 1.018 96.0 2 19,160 400 560 160 720 69815 N 1.018 96.0 2 15,160 200 800 120 920 92816 N 1.012 95.0 2 14,100 200 560 0 560 32017 N 1.012 95.0 2 14,100 200 560 280 840 27218 N 1.014 95.0 0 14,100 400 520 40 560 57219 N 1.014 95.0 0 12,070 200 400 480 880 49720 N 1.020 105.0 2 19,240 200 720 80 800 2,82121 N 1.020 105.0 2 34,600 200 800 80 880 50622 N 1.020 105.0 2 20,830 200 640 80 720 89223 N 1.020 105.0 2 24,480 200 640 80 720 2,36124 N 1.022 105.0 2 31,600 200 720 80 800 1,07425 N 1.022 105.0 2 22,570 200 720 80 800 2,537Average 1.018 1 17,264 240 594 130 723 25.6 7.04 7.37 9.03 - 1,941Maximum 1.022 2 34,600 400 800 480 960 27.0 7.10 7.80 9.10 - 6,655Minimum 1.012 0 12,070 200 400 -40 400 24.00 7.00 7.20 9.00 - 272Range 0.010 2 22,530 200 400 520 560 3.0 0.10 0.60 0.10 - 6,38327.0 7.00 7.80 9.10 Y26.0 7.00 7.20 9.10 Y26.0 7.10 7.20 9.00 Y26.0 7.10 7.40 9.00 Y24.0 7.10 7.40 9.00 YWell Name:3S-610Water Source:CPF3Alaska District Field QCPrejob Water Analysis on LocationCompany:Conoco Phillips Conoco Phillips - 3S-606 Water Analysis 5-30 114
SpecificGravityTestingTemperatureDissolved Iron(Fe2+)Chloride(Cl-)Sulfate(SO42-)Calcium(Ca2+)Magnesium(Mg2+)TotalHardnessLinearViscosityWaterpHGelpHPost-CrosslinkpHCrosslink Bacteria- °F mg/L mg/L mg/L mg/L mg/L mg/L cP - - - (Y/N) BQ ValueTank #H2S present? Y/NHydrometer Digital ThermometerStrip Strip Strip TitrationTotal Hardness Minus CalciumTitration FANN-35 Probe Probe Probe - Mycometer1 N 1.020 95.0 2 15,230 200 480 120 6002 N 1.018 95.0 2 14,100 200 400 160 560 5,6713 N 1.018 95.0 2 15,230 200 560 0 560 4,5444 N 1.018 95.0 2 14,100 200 400 0 400 4,2885 N 1.012 95.0 2 14,100 200 440 0 440 7216 N 1.012 95.0 0 14,100 200 400 0 400 5597 N 1.022 95.0 0 15,160 200 760 0 760 3,1158 N 1.019 96.0 2 15,160 200 800 0 800 2,8709 N 1.020 95.0 2 13,950 200 640 160 800 3,08510 N 1.012 95.0 0 14,100 200 520 160 680 62711 N 1.022 95.0 2 15,160 400 680 280 960 25.0 7.00 7.30 9.00 Y 1,44112 N 1.020 95.0 0 15,160 400 640 200 840 25.0 7.00 7.30 9.00 Y 91613 N 1.020 95.0 2 15,160 400 600 320 920 1,56014 N 1.020 95.0 0 15,160 200 640 160 800 1771516 N 1.020 95.0 2 14,100 400 480 280 760 23717 N 1.020 95.0 2 14,100 200 640 160 800 23418 N 1.020 95.0 2 14,100 200 640 160 800 11019202122Average 1.018 1 14,598 247 572 127 699 24.5 7.03 7.35 9.07 - 1,885Maximum 1.022 2 15,230 400 800 320 960 26.0 7.10 7.40 9.30 - 5,671Minimum 1.012 0 13,950 200 400 0 400 22.00 7.00 7.30 9.00 - 110Range 0.010 2 1,280 200 400 320 560 4.0 0.10 0.10 0.30 - 5,56122.0 7.00 7.30 9.30 Y25.0 7.00 7.40 9.10 Y26.0 7.10 7.40 9.00 Y24.0 7.10 7.40 9.00 YWell Name:3S-610Water Source:CPF3Alaska District Field QCPrejob Water Analysis on LocationCompany:Conoco Phillips Conoco Phillips - 3S-606 Water Analysis 5-31 115
SpecificGravityTestingTemperatureDissolved Iron(Fe2+)Chloride(Cl-)Sulfate(SO42-)Calcium(Ca2+)Magnesium(Mg2+)TotalHardnessLinearViscosityWaterpHGelpHPost-CrosslinkpHCrosslink Bacteria- °F mg/L mg/L mg/L mg/L mg/L mg/L cP - - - (Y/N) BQ ValueTank #H2S present? Y/NHydrometer Digital ThermometerStrip Strip Strip TitrationTotal Hardness Minus CalciumTitration FANN-35 Probe Probe Probe - Mycometer1 N 1.020 70.0 2 16,460 200 1,600 400 2,000 3,8872 N 1.020 70.0 2 15,230 200 1,200 400 1,600 3,3583 N 1.020 70.0 2 15,230 200 1,200 400 1,600 3,0564 N 1.020 70.0 2 15,230 200 1,600 400 2,000 3,5595 N 1.020 70.0 2 15,230 200 1,600 400 2,000 3,7656 N 1.020 65.0 2 15,230 200 800 1,200 2,000 1,1377 N 1.020 65.0 2 16,460 200 800 1,200 2,000 6178 N 1.020 65.0 2 17,790 200 800 1,200 2,000 1,0449 N 1.020 65.0 2 16,460 200 1,200 400 1,600 78110 N 1.020 65.0 2 16,460 200 1,200 400 1,600 84911 N 1.020 65.0 2 16,460 200 800 1,200 2,000 1,03812 N 1.020 65.0 2 15,230 200 800 1,200 2,000 1,20413 N 1.020 65.0 2 16,460 200 800 1,200 2,000 91814 N 1.020 65.0 2 16,460 200 800 1,200 2,000 1,061Average 1.020 2 8,976 200 608 448 1,056 23.3 6.93 7.33 9.10 - 1,877Maximum 1.020 2 17,790 200 1,600 1,200 2,000 27.0 7.00 7.60 9.20 - 3,887Minimum 1.020 2 15,230 200 800 400 1,600 21.00 6.90 7.20 9.20 - 617Range 0.000 0 2,560 0 800 800 400 6.0 0.10 0.40 0.00 - 3,27021.0 6.90 7.20 9.20 Y22.0 6.90 7.20 8.90 Y27.0 7.00 7.60 9.20 YWell Name:3S-610Water Source:CPF3Alaska District Field QCPrejob Water Analysis on LocationCompany:Conoco Phillips Conoco Phillips - 3S-606 Water Analysis 6-10 116
Linear Linear XL XL XL Lip time Linear Linear XL XL XL Lip time
Interval Stage Visc pH Temp °F pH min Interval Stage Visc pH Temp °F pH min
10 Pad 20 7.4 95 8.8 1 19 Pad 21 7.3 120 9 0
0.25#22 7.4 92 8.9 0 23 Avg Linear Visc 0.25# 22 Avg Linear Visc
1.00#25 7.3 85 9 0 88.4 Avg XLTemp 1.00# 111.0 Avg XLTemp
2.00#22 7.3 82 9 0 8.9 Avg XL pH 2.00# 22 7.3 110 9 0 9.0 Avg XL pH
3.00#24 7.3 90 9 0 3.00#
4.00#25 7.3 95 9 0 4.00# 22 7.3 107 9 0
4.50#4.50#
5.00#25 7.3 90 8.8 0 5.00#
5.50#5.50# 21 7.3 107 9 0
6.00#24 7.5 85 8.8 0 6.00#
6.50#6.50# 22 7.2 107 9 0
7.00# 24 7.2 82 8.7 0 7.00#
11 Pad 20 7.1 95 9.1 2 20 Pad 22 7.2 107 9.1 0
0.25# 22 7.1 85 9.1 1 0.25#
1.00# 1.00#
2.00# 21 7.2 95 9.1 1 22 Avg Linear Visc 2.00# 20 7.2 110 9 0 21 Avg Linear Visc
3.00# 90.3 Avg XLTemp 3.00# 109.0 Avg XLTemp
4.00# 22 7 85 8.9 1 9.0 Avg XL pH 4.00# 21 7.2 112 9 0 9.0 Avg XL pH
4.50# 4.50#
5.00# 5.00# 21 7.2 110 9 0
5.50# 23 7.3 95 8.9 0 5.50#
6.00# 6.00# 21 7.2 107 9 0
6.50# 22 7.2 87 9.1 0 6.50#
7.00# 7.00# 21 7.2 108 9 0
12 Pad 21 Pad 21 7.2 107 9 0
0.25# 21 7.4 80 8.9 0 0.25#
1.00# 1.00# 22 7.2 110 8.9 0
2.00# 24 7.4 80 8.9 0 23 Avg Linear Visc 2.00# 22 Avg Linear Visc
3.00# 86.0 Avg XLTemp 3.00# 24 7.2 105 8.9 0 107.7 Avg XLTemp
4.00# 25 7.3 90 9 0 8.9 Avg XL pH 4.00# 9.0 Avg XL pH
4.50# 4.50# 24 7.2 107 9 0
5.00# 24 7.3 90 8.9 0 5.00#
5.50# 5.50# 21 7.2 110 9 0
6.00# 6.00#
6.50# 23 7.3 90 8.9 0 6.50# 21 7.2 107 9 0
7.00# 7.00#
13 Pad 25 7.3 112 9.1 1 22 Pad 23 7.3 80 8.9 1
0.25# 22 7.3 108 9 0 0.25# 25 7.3 85 8.9 0
1.00# 1.00# 25 7.4 80 9 1
2.00# 24 7.3 105 9.1 0 24 Avg Linear Visc 2.00# 25 Avg Linear Visc
3.00# 107.0 Avg XLTemp 3.00# 26 7.3 84 8.9 1 85.1 Avg XLTemp
4.00# 23 7.3 108 9 0 9.0 Avg XL pH 4.00# 25 7.3 82 9 0 9.0 Avg XL pH
4.50# 4.50# 25 7.5 83 9 0
5.00# 23 7.3 112 9.1 0 5.00#
5.50# 24 7.3 108 8.9 0 5.50#
6.00# 24 7.3 108 8.9 0 6.00# 25 7.3 92 9.1 0
6.50# 6.50#
7.00# 23 7.3 95 8.9 0 7.00# 25 7.5 95 9.1 1
14 Pad 23 7.3 95 9 1 23 Pad
0.25# 22 7.3 100 9 0 0.25# 23 7.5 103 9 0
1.00# 1.00#
2.00# 21 7.3 105 9 0 22 Avg Linear Visc 2.00# 23 7.5 100 8.9 0 23 Avg Linear Visc
3.00# 103.6 Avg XLTemp 3.00# 95.6 Avg XLTemp
4.00# 22 7.3 102 8.9 0 8.9 Avg XL pH 4.00# 8.9 Avg XL pH
4.50# 20 7.3 112 8.9 0 4.50# 23 7.5 90 8.9 0
5.00# 21 7.3 105 8.8 0 5.00#
5.50# 5.50# 22 7.5 90 8.9 0
6.00# 22 7.3 105 8.9 0 6.00#
6.50# 6.50# 23 7.6 95 8.9 0
7.00# 22 7.3 105 8.9 0 7.00#
15 Pad 20 7.1 110 9.1 0 24 Pad 20 7.3 95 8.9 1
.25# 0.25#
1.00# 20 7 112 9 0 1.00# 21 7.5 105 8.9 0
2.00# 22 Avg Linear Visc 2.00# 20 Avg Linear Visc
3.00# 23 6.9 110 9 0 110.1 Avg XLTemp 3.00# 103.8 Avg XLTemp
4.00# 23 6.9 110 8.9 0 9.0 Avg XL pH 4.00# 21 7.6 108 8.9 0 8.9 Avg XL pH
4.50# 4.50#
5.00# 24 7 112 8.9 0 5.00# 20 7.5 105 8.9 1
5.50# 5.50# 20 7.6 107 8.9 0
6.0# 23 6.9 112 8.9 0 6.00#
6.5# 6.50# 20 7.5 103 8.9 0
7.0# 23 6.9 105 8.9 0 7.00#
16 Pad 22 6.9 115 8.9 0 25 Pad
0.25# 0.25#
1.00# 22 7 112 8.9 0 1.00#
2.00# 22 Avg Linear Visc 2.00# #DIV/0! Avg Linear Visc
3.00# 21 7 110 8.9 0 111.2 Avg XLTemp 3.00# #DIV/0! Avg XLTemp
4.00# 8.9 Avg XL pH 4.00# #DIV/0! Avg XL pH
4.50# 22 7 110 8.9 0 4.50#
5.00# 5.00#
5.50# 21 7 110 8.9 0 5.50#
6.00# 6.00#
6.50# 21 7 110 9 0 6.50#
7.00# 7.00#
17 Pad 21 7 110 9 0 26 Pad
0.25# 0.25#
1.00# 21 7 110 9 0 1.00#
2.00# 21 Avg Linear Visc 2.00# #DIV/0! Avg Linear Visc
3.00# 20 7 105 8.9 0 106.5 Avg XLTemp 3.00# #DIV/0! Avg XLTemp
4.00# 8.9 Avg XL pH 4.00# #DIV/0! Avg XL pH
4.50# 22 7 106 8.9 0 4.50#
5.00# 5.00#
5.50# 21 7 100 8.9 0 5.50#
6.00# 6.00#
6.50# 22 7 108 8.9 0 6.50#
7.0# 20 7 108 8.9 0 7.00#
18 Pad 25 7.3 105 8.7 2 27 Pad
0.25# 24 7.5 100 8.8 1 0.25#
1.00# 1.00#
2.00# 24 Avg Linear Visc 2.00# #DIV/0! Avg Linear Visc
3.00# 25 7.3 107 9 0 104.5 Avg XLTemp 3.00# #DIV/0! Avg XLTemp
4.00# 8.9 Avg XL pH 4.00# #DIV/0! Avg XL pH
4.50# 24 7.3 108 9 0 4.50#
5.00# 5.00#
5.50# 23 7.3 102 9 0 5.50#
6.00# 6.00#
6.50# 22 7.3 105 9.1 0 6.50#
7.00# 7.00#
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Customer:ConocoPhillips Alaska, Inc.
Wellname & #:3S-606
Date:May 29, 2024
Conoco Phillips - 3S-606 Real-Time QC 117
Seq No. Time Activity Code Comment Job Slurry Vol Treating Pressure Treating Pressure @Pump Slurry Rate Tubing Gauge BH Pres
1 06:02:03 (05/29/24) Other Toolbox Talk and JSA Meeting ---- ---- ---- ---- ----
2 6:15:25 Other Begin Function Test Equipment ---- ---- ---- ---- ----
3 6:17:09 Other Restart TCC Servers ---- ---- ---- ---- ----
4 6:42:17 Start Job Starting Job 0 0 0 0 1981
1 06:42:17 (05/29/24) Next Treatment Treatment Interval 1 0 0 0 0 1981
5 6:42:43 Other Blender Bucket Test 0 0 1 0 1981
6 6:47:43 Other Lynden Finished Restraints to WH 0 0 2 0 1981
7 6:49:54 Other Rig up IA Lines 0 0 1 0 1981
8 6:59:22 Other Bucket Test ADP 0 0 2 0 1981
9 7:45:07 Other Start Loop Test 0 -1 2 0 1981
10 7:54:34 Other Loop Test Complete 0 -4 2 0 1982
11 7:59:22 Other Start Prime Up 0 20 32 0 1981
12 8:20:16 Other Building More Scaffolding At WH 0 95 72 0 1982
13 8:46:59 Other Little Red Prepare for PT 0 91 72 0 1982
14 9:04:56 Other Little Red Starts IA Lines PT 0 90 72 0 1981
15 9:16:57 Other Little Red Finished 0 89 71 0 1982
16 9:17:48 Other Hal Prepare to PT 0 89 71 0 1982
17 9:22:53 Pressure Test ePRV - Primary Tubing 0 1178 1098 0 1982
18 9:24:40 Pressure Test ePRV - Primary IA 0 1177 610 0 1982
19 9:26:14 Pressure Test ePRV - Secondary Tubing 0 1189 1150 0 1982
20 9:27:46 Pressure Test ePRV - Secondary IA 0 1182 1215 0 1982
21 9:32:20 Pressure Test Pressure Test - Locals 0 1165 414 0 1982
22 9:32:31 Pressure Test Pressure Test - Global 0 1165 650 0 1982
23 9:34:40 Pressure Test Pressure Test - Max 0 9784 9708 0 1982
24 9:37:32 Pressure Test Leak on Down Joint and Chik on Goat Head 0 9571 9502 0 1982
25 10:06:41 Other Swap Double Chik Off the Goat Head 0 -17 28 0 1982
26 10:39:38 Other Replaced Double Chik and 2 High Pressure Seal 0 -26 28 0 1982
27 10:48:03 Pressure Test Pressure Test - Locals 0 79 138 0 1982
28 10:48:08 Pressure Test Pressure Test - Global 0 557 609 0 1982
29 10:49:32 Pressure Test Pressure Test - Max 0 8323 8254 0 1982
30 10:50:44 Pressure Test Pressure Test - Max 0 9786 9760 0 1982
31 10:55:39 Pressure Test Pressure Test - Max 0 9748 9699 0 1982
32 10:58:20 Pre-Job Safety Meeting Pre-Job Safety Meeting 0 54 83 0 1982
33 11:16:59 Other Start Pulling on Chemicals 0 45 82 0 1980
34 11:20:46 Other Little Red Pop-Off Leaking By 0 39 80 0 1983
35 11:32:47 Other Start Mixing Gel 0 40 82 0 1983
10 11:49:22 (05/29/24) Next Treatment Treatment Interval 10 0 38 78 0 1983
36 11:51:16 Open Well Open Well 0 243 233 0 1994
37 11:51:39 Other Load Ball 10 0.34 263 314 1.8 2011
38 11:52:35 Drop Ball Drop Ball 10 0.52 228 209 0 1988
39 11:52:48 Other Bring Acid Pumper Online 0.52 240 207 0 2047
40 12:05:34 Other Slow Down For Ball 10 178.72 802 891 15.2 2783
41 12:09:00 Ball on Seat Ball 10 on Seat 215.46 384 466 10.2 2438
42 12:09:24 Break Formation Break Formation 219.55 4075 4016 10.2 6000
43 12:13:23 Alarm Delta Stage At Top Perf = 4 260.13 1262 1325 10.2 3311
44 12:13:25 Alarm Delta Stage At Top Perf = 5 260.65 1262 1326 10.2 3312
45 12:14:49 ISIP ISIP 274.14 789 548 2.8 3081
46 12:19:49 Shut-In Pressure @ 5 Minutes Shut-In Pressure @ 5 Minutes 274.29 705 405 0 2707
47 12:24:53 Shut-In Pressure @ 10 Minutes Shut-In Pressure @ 10 Minutes 274.29 664 320 0 2511
48 12:29:51 Shut-In Pressure @ 15 Minutes Shut-In Pressure @ 15 Minutes 274.29 626 233 0 2409
49 12:50:31 Other Start Pad 417.17 1684 1754 17.8 3632
50 12:52:58 Alarm Delta Stage At Top Perf = 6 487.17 2479 2507 35 4119
51 12:54:18 Alarm Delta Stage At Top Perf = 7 534.6 2495 2545 36.8 4076
52 12:54:19 Alarm Delta Stage At Top Perf = 8 535.22 2490 2543 36.8 4085
53 12:58:04 Alarm Delta Stage At Top Perf = 9 671.21 2568 2585 35 4083
54 13:03:09 Alarm Delta Stage At Top Perf = 10 856.98 2735 2761 37.2 4278
55 13:06:20 Other Patina Tracer Dropped 975.72 2684 2717 37.3 4255
56 13:13:33 Alarm Delta Stage At Top Perf = 11 1242.19 2564 2600 36.7 4345
57 13:14:53 Alarm Delta Stage At Top Perf = 12 1291.06 2595 2619 36.7 4410
58 13:16:39 Alarm Delta Stage At Top Perf = 13 1356.07 2639 2663 36.8 4471
59 13:19:31 Alarm Delta Stage At Top Perf = 14 1461.66 2701 2723 36.8 4570
60 13:23:12 Alarm Delta Stage At Top Perf = 15 1597.1 2753 2789 36.4 4666
61 13:27:05 Alarm Delta Stage At Top Perf = 16 1740.19 2777 2798 36.9 4700
62 13:31:24 Alarm Delta Stage At Top Perf = 17 1899.14 2847 2869 36.8 4777
63 13:35:08 Other Load Ball 11 2036.37 2897 2915 36.7 4835
64 13:35:43 Alarm Delta Stage At Top Perf = 18 2057.77 2916 2935 36.7 4854
65 13:40:22 Alarm Delta Stage At Top Perf = 19 2228.28 3079 3096 36.8 4991
66 13:41:12 Other Debris in Pump 454 2259.1 3048 3074 37 4970
67 13:41:59 Drop Ball Drop Ball 11 2286.95 2951 2952 34.8 4809
11 13:42:00 (05/29/24) Next Treatment Treatment Interval 11 2286.95 2954 2955 34.8 4808
68 13:43:36 Alarm Delta Stage At Top Perf = 20 2342.95 3113 3069 34.3 4817
69 13:47:08 Other Slow Down for Ball 11 2470.9 2860 2907 37.3 4424
70 13:49:28 Ball on Seat Ball 11 on Seat 2500.51 2235 2283 9.9 3935
71 13:49:31 Alarm Delta Stage At Top Perf = 21 2501.17 2938 2954 9.9 4619
72 13:49:46 Break Formation Break Formation 2503.47 5478 5441 9.8 7108
73 13:52:10 Alarm Delta Stage At Top Perf = 1 2537.34 2440 2460 25 3990
74 13:57:41 Alarm Delta Stage At Top Perf = 2 2723.55 2523 2540 37.2 4186
75 14:07:52 Alarm Delta Stage At Top Perf = 3 3102.18 2320 2349 36.8 4165
76 14:09:08 Alarm Delta Stage At Top Perf = 4 3148.91 2334 2360 36.9 4230
77 14:10:49 Alarm Delta Stage At Top Perf = 5 3211.08 2370 2400 36.9 4280
78 14:12:56 Other Wet Sand 3288.52 2427 2456 36.8 4360
79 14:13:40 Alarm Delta Stage At Top Perf = 6 3316.17 2451 2479 36.9 4389
80 14:17:18 Alarm Delta Stage At Top Perf = 7 3450.26 2556 2581 36.8 4453
81 14:19:31 Other Wet Sand in Hopper 3531.1 2494 2518 36.7 4427
82 14:21:11 Alarm Delta Stage At Top Perf = 8 3592.41 2483 2514 36.7 4439
83 14:25:21 Alarm Delta Stage At Top Perf = 9 3745.79 2560 2579 36.6 4539
84 14:29:05 Other Load Ball 12 3882.48 2707 2721 36.8 4667
85 14:29:42 Alarm Delta Stage At Top Perf = 10 3905.83 2740 2761 36.9 4687
86 14:30:47 Other Pump 458 - Debris Passed Thru 3945.4 2563 2596 34.9 4589
87 14:34:25 Alarm Delta Stage At Top Perf = 11 4078.59 3110 3123 37.1 4961
12 14:35:37 (05/29/24) Next Treatment Treatment Interval 12 4122.47 3237 3262 37.1 4989
88 14:35:38 Drop Ball Drop Ball 12 4123.09 3240 3262 37.1 4988
89 14:37:29 Alarm Delta Stage At Top Perf = 12 4192.4 3360 3382 37.2 5041
90 14:43:01 Ball on Seat Ball 12 on Seat 4329.86 1900 1946 10 3754
91 14:43:16 Break Formation Break Formation 4332.37 4400 4371 10 6185
92 14:43:21 Alarm Delta Stage At Top Perf = 13 4333.37 1026 996 10 3281
93 14:45:32 Alarm Delta Stage At Top Perf = 1 4365.07 3040 3076 25 4763
94 14:51:07 Alarm Delta Stage At Top Perf = 2 4559.27 3324 3335 37.3 4965
95 14:52:29 Other Pump 458 Rocking 4610.26 3258 3282 37.3 4891
96 15:01:49 Alarm Delta Stage At Top Perf = 3 4943.15 3121 3136 37.1 4923
97 15:03:06 Alarm Delta Stage At Top Perf = 4 4990.76 3018 3036 37.1 4873
98 15:04:46 Alarm Delta Stage At Top Perf = 5 5052.69 2884 2908 37.2 4786
99 15:07:40 Alarm Delta Stage At Top Perf = 6 5160.36 2787 2804 37.1 4717
100 15:11:20 Alarm Delta Stage At Top Perf = 7 5296.19 2748 2772 37 4702
101 15:15:12 Alarm Delta Stage At Top Perf = 8 5439.01 2813 2837 36.9 4772
102 15:19:28 Alarm Delta Stage At Top Perf = 9 5596.33 2868 2893 36.8 4847
103 15:23:55 Alarm Delta Stage At Top Perf = 10 5759.99 2928 2956 36.7 4923
104 15:28:35 Alarm Delta Stage At Top Perf = 11 5931.6 3038 3060 37.1 4999
105 15:31:51 Alarm Delta Stage At Top Perf = 12 6052.79 3431 3451 37 4967
106 15:35:08 Alarm Delta Stage At Top Perf = 13 6174.22 516 631 33 4216
107 15:35:17 ISIP ISIP 6176.82 1371 1446 0 3366
108 15:40:15 Shut-In Pressure @ 5 Minutes Shut-In Pressure @ 5 Minutes 6176.82 -40 36 0 3221
109 15:45:15 Shut-In Pressure @ 10 Minutes Shut-In Pressure @ 10 Minutes 6176.82 -18 65 0 3149
110 15:50:17 Shut-In Pressure @ 15 Minutes Shut-In Pressure @ 15 Minutes 6176.82 -56 33 0 3095
111 15:50:58 Other LRS Bleed Down IA 6176.82 57 115 0 3088
112 15:51:16 Other Blow Down Pumps and Clean Up Chem's 6176.82 27 104 0 3085
113 16:16:47 Other Drain the Blender 6176.82 -37 48 0 2827
114 16:25:19 Other Blender Off 6176.82 841 46 0 2988
115 16:25:41 Other Suck Out ADP 6176.82 842 46 0 2985
116 16:37:33 Other End of Day Tasks 6176.82 659 43 0 2705
117 16:41:40 End Job Ending Job 6176.82 -65 41 0 2658
Event Log 5-29
Conoco Phillips - 3S-606 Event Log- 5-29 118
Seq No. Time Activity Code Comment Job Slurry Vol Treating Pressure Treating Pressure @Pump Slurry Rate Tubing Gauge BH Pres
1 06:22:13 (05/30/24) Start Job Starting Job 0 0 0 0 0
1 06:22:13 (05/30/24) Next Treatment Treatment Interval 1 0 0 0 0 0
2 6:22:48 Other Check Pump Valves 0 -6 -5 0 2157
3 6:25:58 Other Bucket Test Blender 0 -6 -4 0 2157
4 6:26:17 Other Function Test ADP 0 -6 -5 0 2157
5 6:47:54 Other Bucket Test ADP 0 -5 -4 0 2156
6 7:11:09 Other Pumps Buttoned Up 0 -5 -4 0 2155
7 7:20:17 Other Bring on Water to Blender 0 -5 -4 0 2154
8 7:24:12 Other Blender Loop Test 0 -5 -4 0 2154
9 7:38:52 Other Prime Pumps 0 -5 43 0 2153
10 7:49:02 Other LRS Rig Up & Test New Popoff 0 104 47 0 2153
11 8:11:59 Pressure Test ePRV - Primary Tubing 0 1118 1123 0 2152
12 8:14:12 Pressure Test ePRV - Primary IA 0 1208 1244 0 2152
13 8:15:25 Pressure Test ePRV - Secondary Tubing 0 1219 1027 0 2152
14 8:17:05 Pressure Test ePRV - Secondary IA 0 1270 750 0 2152
15 8:21:12 Pressure Test Pressure Test - Global 0 2080 2060 0 2151
16 8:21:22 Pressure Test Pressure Test - Locals 0 2077 2057 0 2151
17 8:24:27 Pressure Test Pressure Test - Max 0 9818 9706 0 2151
18 8:29:08 Pressure Test Pressure Test - Pass 0 9771 9629 0 2151
19 8:32:07 Pre-Job Safety Meeting Pre-Job Safety Meeting 0 239 220 0 2151
13 08:48:20 (05/30/24) Next Treatment Treatment Interval 13 0 234 211 0 2150
20 8:49:06 Other Bring on Chemicals 0 234 210 0 2150
21 8:56:25 Other Bring Up IA 0 230 206 0 2150
22 9:00:15 Other Start Mixing Gel 0 230 204 0 2152
23 9:14:25 Other Load Ball 13 0.18 178 165 0.6 2189
24 9:14:29 Open Well Open Well 0.23 181 178 0.9 2194
25 9:15:25 Drop Ball Drop Ball 13 0.53 151 137 0 2168
26 9:24:27 Start Pad Start Pad 121.89 1212 1287 15.3 2950
27 9:27:25 Other Slow Down For Ball 13 166.76 1397 1448 15.1 2959
28 9:30:19 Ball on Seat Ball 13 on Seat 197.33 1266 1298 10.2 2674
29 9:30:36 Break Formation Break Formation 200.2 3859 3790 10.1 5376
30 9:32:36 Alarm Delta Stage At Top Perf = 4 235.49 2720 2724 26.5 3923
31 9:32:38 Alarm Delta Stage At Top Perf = 5 236.38 2718 2714 26.7 3913
32 9:36:09 Alarm Delta Stage At Top Perf = 6 352.48 2791 2796 36.8 4228
33 9:41:08 Alarm Delta Stage At Top Perf = 7 536.83 2837 2838 37 4246
34 9:51:37 Alarm Delta Stage At Top Perf = 8 923.67 2680 2669 36.7 4342
35 9:52:57 Alarm Delta Stage At Top Perf = 9 972.56 2660 2648 36.8 4377
36 9:54:41 Alarm Delta Stage At Top Perf = 10 1036.53 2612 2600 36.9 4377
37 9:57:38 Alarm Delta Stage At Top Perf = 11 1144.66 2570 2562 36.8 4382
38 10:01:22 Alarm Delta Stage At Top Perf = 12 1282.02 2557 2548 36.8 4429
39 10:05:20 Alarm Delta Stage At Top Perf = 13 1427.66 2555 2559 36.6 4476
40 10:09:36 Alarm Delta Stage At Top Perf = 14 1583.97 2579 2576 36.6 4510
41 10:14:06 Alarm Delta Stage At Top Perf = 15 1748.5 2615 2627 36.2 4599
42 10:18:49 Alarm Delta Stage At Top Perf = 16 1922.62 2645 2654 37.4 4616
14 10:20:12 (05/30/24) Next Treatment Treatment Interval 14 1973.67 2927 2919 37 4624
43 10:20:13 Drop Ball Drop Ball 14 1974.29 2928 2920 37 4625
44 10:21:57 Alarm Delta Stage At Top Perf = 17 2038.61 3045 3041 37.2 4657
45 10:24:26 Other Slow Down For Ball 14 2131.03 2566 2536 37.2
4127
46 10:27:43 Alarm Delta Stage At Top Perf = 18 2169.53 2213 2224 10 3902
47 10:27:44 Ball on Seat Ball 14 on Seat 2169.53 2214 2224 10 3901
48 10:27:58 Break Formation Break Formation 2171.87 4773 4718 10 6464
49 10:30:06 Alarm Delta Stage At Top Perf = 1 2201.27 2558 2557 25.6 4078
50 10:35:30 Alarm Delta Stage At Top Perf = 2 2385.54 2936 2913 37.2
4544
51 10:45:54 Alarm Delta Stage At Top Perf = 3 2770.68 2663 2661 36.8 4473
52 10:47:14 Alarm Delta Stage At Top Perf = 4 2819.76 2648 2643 36.8 4484
53 10:49:01 Alarm Delta Stage At Top Perf = 5 2885.44 2558 2550 36.9 4418
54 10:52:02 Alarm Delta Stage At Top Perf = 6 2996.92 2517 2514 36.9 4402
55 10:55:44 Alarm Delta Stage At Top Perf = 7 3133.43 2505 2502 36.9 4403
56 10:59:37 Alarm Delta Stage At Top Perf = 8 3276.86 2494 2491 36.9 4431
57 11:00:19 Other Pump 458 Front Cap Pressure 3302.7 2492 2493 36.9 4442
58 11:04:01 Alarm Delta Stage At Top Perf = 9 3435.89 2490 2488 36.9 4468
59 11:08:32 Alarm Delta Stage At Top Perf = 10 3602.45 2544 2545 36.8 4523
60 11:13:15 Alarm Delta Stage At Top Perf = 11 3776.34 2639 2636 37.1 4586
15 11:14:27 (05/30/24) Next Treatment Treatment Interval 15 3820.92 2811 2808 37.2 4587
61 11:14:27 Other Drop Ball 15 3820.92 2811 2808 37.2 4587
62 11:16:18 Alarm Delta Stage At Top Perf = 12 3889.83 2970 2967 37.3 4634
63 11:18:27 Other Slow Down For Ball 15 3970.1 2650 2630 37.4 4206
64 11:21:16 Alarm Delta Stage At Top Perf = 13 4007.77 2001 2019 10.2 3748
65 11:21:24 Ball on Seat Ball 15 on Seat 4009.13 2011 2028 10.2 3750
66 11:21:44 Break Formation Break Formation 4012.34 5818 5691 10.1 7764
67 11:23:57 Alarm Delta Stage At Top Perf = 1 4040.71 2368 2415 22.7 3959
68 11:29:04 Alarm Delta Stage At Top Perf = 2 4224.36 2469 2494 37.3 4118
69 11:39:25 Alarm Delta Stage At Top Perf = 3 4608.88 2424 2441 37.1 4192
70 11:40:43 Alarm Delta Stage At Top Perf = 4 4657.07 2459 2478 36.9 4257
71 11:42:30 Alarm Delta Stage At Top Perf = 5 4722.99 2445 2460 37 4285
72 11:45:26 Alarm Delta Stage At Top Perf = 6 4831.51 2471 2493 36.9 4341
73 11:49:12 Alarm Delta Stage At Top Perf = 7 4970.57 2502 2513 36.8 4363
74 11:53:05 Alarm Delta Stage At Top Perf = 8 5113.61 2453 2468 36.8 4378
75 11:57:18 Alarm Delta Stage At Top Perf = 9 5268.85 2497 2512 36.8 4398
76 12:01:44 Alarm Delta Stage At Top Perf = 10 5432 2482 2507 36.8 4431
77 12:06:29 Alarm Delta Stage At Top Perf = 11 5606.99 2539 2569 37 4502
16 12:08:05 (05/30/24) Next Treatment Treatment Interval 16 5666.92 2796 2824 37.7 4578
78 12:08:05 Drop Ball Drop Ball 16 5666.92 2797 2826 37.7 4578
79 12:09:31 Alarm Delta Stage At Top Perf = 12 5721 2942 2941 37.7 4635
80 12:11:43 Other Slow Down For Ball 16 5803.19 2675 2682 37.6 4283
81 12:14:41 Alarm Delta Stage At Top Perf = 13 5844.2 1883 1917 10.1 3764
82 12:14:45 Ball on Seat Ball 16 on Seat 5844.87 1889 1923 10.1 3765
83 12:14:56 Break Formation Break Formation 5846.73 4029 4023 10.1 4894
84 12:17:14 Alarm Delta Stage At Top Perf = 1 5877.52 2184 2209 18.3 3892
85 12:22:49 Alarm Delta Stage At Top Perf = 2 6062.57 2300 2309 37.3 3963
86 12:33:12 Alarm Delta Stage At Top Perf = 3 6448.18 2152 2175 36.9 3967
87 12:34:32 Alarm Delta Stage At Top Perf = 4 6497.42 2177 2196 36.8 4002
88 12:36:19 Alarm Delta Stage At Top Perf = 5 6563.01 2172 2190 36.8 4042
89 12:39:14 Alarm Delta Stage At Top Perf = 6 6670.74 2206 2225 37 4096
90 12:42:52 Alarm Delta Stage At Top Perf = 7 6805.06 2189 2205 36.9 4134
91 12:46:41 Alarm Delta Stage At Top Perf = 8 6945.96 2230 2248 36.9 4172
92 12:51:01 Alarm Delta Stage At Top Perf = 9 7105.92 2242 2262 36.9 4210
93 12:55:27 Alarm Delta Stage At Top Perf = 10 7269.29 2306 2327 36.8 4259
94 13:00:10 Alarm Delta Stage At Top Perf = 11 7443.04 2322 2339 36.9 4314
17 13:02:11 (05/30/24) Next Treatment Treatment Interval 17 7517.93 2463 2490 37.3 4298
95 13:02:12 Drop Ball Drop Ball17 7518.55 2465 2493 37.3 4301
96 13:03:24 Alarm Delta Stage At Top Perf = 12 7563.28 2628 2655 37.3 4368
97 13:05:34 Other Slow Down for Ball 17 7644.03 2480 2490 37.3 4114
98 13:08:17 Ball on Seat Ball 17 on Seat 7685.65 1711 1746 10.2 3609
99 13:08:29 Break Formation Break Formation 7687.52 4036 4002 10.1 5920
100 13:08:34 Alarm Delta Stage At Top Perf = 13 7688.53 666 627 10.1 3262
101 13:10:53 Alarm Delta Stage At Top Perf = 1 7721.15 2501 2520 31.5 3966
102 13:11:36 Alarm Delta Stage At Top Perf = 2 7746.53 2432 2447 37 4001
103 13:21:58 Alarm Delta Stage At Top Perf = 3 8131.55 2117 2134 36.9 3986
104 13:22:54 Alarm Delta Stage At Top Perf = 4 8165.96 2109 2130 36.8 4020
105 13:24:08 Alarm Delta Stage At Top Perf = 5 8211.3 2128 2155 36.9 4061
106 13:26:11 Alarm Delta Stage At Top Perf = 6 8287.13 2146 2176 37 4115
107 13:28:47 Alarm Delta Stage At Top Perf = 7 8383.23 2171 2193 36.9 4144
108 13:31:31 Alarm Delta Stage At Top Perf = 8 8484.12 2179 2205 36.9 4161
109 13:34:30 Alarm Delta Stage At Top Perf = 9 8594.41 2218 2242 36.9 4194
110 13:37:36 Alarm Delta Stage At Top Perf = 10 8708.75 2187 2206 36.9 4179
111 13:40:17 Start Flush Start Flush 8807.36 2307 2347 37.4 4284
112 13:40:55 Alarm Delta Stage At Top Perf = 11 8831.66 2437 2462 37.3 4303
113 13:43:11 Alarm Delta Stage At Top Perf = 12 8915.91 2686 2704 37.2 4308
114 13:45:46 Alarm Delta Stage At Top Perf = 13 9011.74 403 526 34 3747
115 13:45:53 ISIP ISIP 9014.08 1213 1218 16.9 3390
116 13:50:46 Shut-In Pressure @ 5 Minutes Shut-In Pressure @ 5 Minutes 9015.7 -34 26 0 3310
117 13:55:17 Other Drain Blender Tub 9015.7 126 230 0 3261
118 13:55:55 Shut-In Pressure @ 10 Minutes Shut-In Pressure @ 10 Minutes 9015.7 120 167 0 3254
119 14:00:48 Shut-In Pressure @ 15 Minutes Shut-In Pressure @ 15 Minutes 9015.7 3 70 0 3197
120 14:01:17 Other Bleed Down IA & Freeze Protect 9015.7 0 69 0 3192
121 14:01:43 Other Clean Up Chemicals 9015.7 0 68 0 3186
122 14:11:00 Other Done Blowing Down Pumps 9015.7 -13 134 0 3072
123 14:14:20 Other Blow Down ADP 9015.7 -13 34 0 3032
124 14:21:49 Other IA Closed 9015.7 -16 18 0 2945
125 14:31:06 Other LRS Begin Freeze Protection 9015.7 4 17 0 2853
Event Log 5-30
Conoco Phillips - 3S-606 Event Log- 5-30 119
Seq No. Time Activity Code Comment Job Slurry Vol Treating Pressure Treating Pressure @Pump Slurry Rate Tubing Gauge BH Pres
1 06:01:16 (05/31/24) Other Arrive to Location 0 ---- ---- 0 ----
2 6:16:17 Other Finished Toolbox Talk & JSA ---- ---- ---- ---- ----
3 6:21:02 Other Function Test Equipment ---- ---- ---- ---- ----
4 6:40:21 Start Job Starting Job 0 0 0 0 0
1 06:40:21 (05/31/24) Next Treatment Treatment Interval 1 0 0 0 0 0
5 6:40:49 Other Bucket Test Blender 0 -1 46 0 0
6 7:16:38 Other Blender Deleted 0 -1 -8 0 2156
7 7:36:34 Other Loop Test 0 0 -7 0 2155
8 7:47:22 Prime Pumps Prime Pumps 0 0 67 0 2154
9 8:06:05 Pressure Test ePRV - Primary Tubing 0 1129 1120 0 2153
10 8:07:56 Pressure Test ePRV - Primary IA 0 1206 1171 0 2153
11 8:09:13 Pressure Test ePRV - Secondary Tubing 0 1324 1171 0 2153
12 8:10:24 Pressure Test ePRV - Secondary IA 0 1364 1079 0 2153
13 8:14:29 Pressure Test Pressure Test - Global 0 1358 319 0 2153
14 8:14:37 Pressure Test Pressure Test - Locals 0 1358 359 0 2153
15 8:16:21 Pressure Test Pressure Test - Max 0 9864 9728 0 2153
16 8:21:13 Pressure Test Pressure Test - Pass 0 9803 9654 0 2153
17 8:24:25 Pre-Job Safety Meeting Pre-Job Safety Meeting 0 184 51 0 2153
18 8:27:45 Other Bring on Chemicals 0 181 51 0 2152
19 8:45:59 Other LRS Open Up to IA 0 178 51 0 2152
20 8:55:09 Other Mix Tub of Gel 0 176 51 0 2152
18 09:05:15 (05/31/24) Next Treatment Treatment Interval 18 0 174 51 0 2152
21 9:09:06 Open Well Open Well 0.04 184 161 0.6 2182
22 9:10:03 Drop Ball Drop Ball 18 0.38 149 113 0 2152
23 9:19:04 Other Slow Down For Ball 18 123.85 851 934 15 2759
24 9:22:14 Ball on Seat Ball 18 on Seat 157.9 530 599 10.1 2549
25 9:22:33 Break Formation Break Formation 161.1 3748 3692 10.1 5736
26 9:26:01 Alarm Delta Stage At Top Perf = 4 196.14 1286 1356 10.1 3308
27 9:26:05 Alarm Delta Stage At Top Perf = 5 196.81 1287 1357 10.1 3309
28 9:28:33 ISIP ISIP 221.3 836 663 4.7 3146
29 9:33:39 Shut-In Pressure @ 5 Minutes Shut-In Pressure @ 5 Minutes 221.88 862 513 0 2892
30 9:38:36 Shut-In Pressure @ 10 Minutes Shut-In Pressure @ 10 Minutes 221.88 806 376 0 2686
31 9:43:36 Shut-In Pressure @ 15 Minutes Shut-In Pressure @ 15 Minutes 221.88 756 189 0 2578
32 10:09:06 Alarm Delta Stage At Top Perf = 6 367.5 1617 1673 14.9 3509
33 10:09:26 Start Pad Start Pad 372.48 1644 1690 14.9 3510
34 10:11:15 Alarm Delta Stage At Top Perf = 8 418.11 2450 2484 35 4010
35 10:15:16 Alarm Delta Stage At Top Perf = 9 567.32 2490 2499 37.4 3997
36 10:15:54 Alarm Delta Stage At Top Perf = 10 590.97 2496 2522 37.4 4027
37 10:26:18 Alarm Delta Stage At Top Perf = 11 978.44 2435 2436 37.2 4130
38 10:27:19 Alarm Delta Stage At Top Perf = 12 1016.25 2424 2425 37.1 4167
39 10:28:13 Other ADP Tub Level Gauge Stuck 1049.11 2404 2399 37.2 4159
40 10:28:32 Alarm Delta Stage At Top Perf = 13 1061.52 2384 2379 37.2 4152
41 10:30:36 Alarm Delta Stage At Top Perf = 14 1138.26 2311 2316 37.1 4141
42 10:33:10 Alarm Delta Stage At Top Perf = 15 1233.3 2266 2265 37 4117
43 10:36:22 Alarm Delta Stage At Top Perf = 16 1351.48 2256 2270 36.9 4115
44 10:38:56 Alarm Delta Stage At Top Perf = 17 1445.55 2262 2256 36.9 4148
45 10:42:00 Alarm Delta Stage At Top Perf = 18 1559.06 2212 2223 36.8 4139
46 10:45:17 Alarm Delta Stage At Top Perf = 19 1680.55 2338 2359 37.6 4176
47 10:45:40 Drop Ball Drop Ball 19 1694.96 2428 2447 37.6 4177
19 10:45:41 (05/31/24) Next Treatment Treatment Interval 19 1694.96 2428 2449 37.6 4177
48 10:47:19 Alarm Delta Stage At Top Perf = 20 1757.09 2597 2603 37.7 4214
49 10:48:39 Other Slow Down For Ball 19 1806.68 2515 2518 37.7 4040
50 10:51:46 Ball on Seat Ball 19 on Seat 1849.22 2013 2042 10.1 3692
51 10:51:53 Alarm Delta Stage At Top Perf = 21 1850.57 3205 3232 10.1 4983
52 10:51:57 Break Formation Break Formation 1851.07 3899 3900 10.1 5222
53 10:54:25 Alarm Delta Stage At Top Perf = 1 1882.8 3103 3122 20.8 4703
54 10:55:40 Alarm Delta Stage At Top Perf = 2 1914.98 3940 3908 32 5397
55 11:06:16 Alarm Delta Stage At Top Perf = 3 2301.9 2701 2713 36.9 4440
56 11:07:12 Alarm Delta Stage At Top Perf = 4 2336.36 2522 2530 36.9 4313
57 11:08:27 Alarm Delta Stage At Top Perf = 5 2382.05 2355 2364 36.5 4169
58 11:10:31 Alarm Delta Stage At Top Perf = 6 2458.41 2237 2257 37.2 4121
59 11:13:06 Alarm Delta Stage At Top Perf = 7 2554.28 2141 2166 37.1 4058
60 11:15:48 Alarm Delta Stage At Top Perf = 8 2654.29 2093 2117 37.1 4028
61 11:17:20 Other Load Ball 20 2711.23 2083 2106 37.1 4011
62 11:18:45 Alarm Delta Stage At Top Perf = 9 2763.71 2075 2103 37.1 4017
63 11:21:50 Alarm Delta Stage At Top Perf = 10 2877.95 2061 2087 37 4029
64 11:25:03 Alarm Delta Stage At Top Perf = 11 2997.43 2107 2136 37.7 4064
20 11:25:41 (05/31/24) Next Treatment Treatment Interval 20 3020.72 2267 2290 37.7 4069
65 11:25:41 Drop Ball Drop Ball 20 3021.35 2271 2293 37.7 4068
66 11:27:05 Alarm Delta Stage At Top Perf = 12 3074.26 2437 2453 37.9 4101
67 11:28:22 Other Slow Down For Ball 20 3122.84 2433 2444 37.8 4008
68 11:31:33 Alarm Delta Stage At Top Perf = 13 3168.91 1814 1849 10.2 3562
69 11:31:43 Break Formation Break Formation 3170.44 3525 3514 10.2 4529
70 11:31:50 Ball on Seat Ball 20 On Seat 3171.8 1825 1786 10.2 3586
71 11:33:27 Alarm Delta Stage At Top Perf = 1 3200.71 3190 3176 33.5 4640
72 11:34:07 Alarm Delta Stage At Top Perf = 2 3224.43 3183 3171 36.8 4667
73 11:44:37 Alarm Delta Stage At Top Perf = 3 3612.24 2838 2851 36.6 4649
74 11:45:32 Alarm Delta Stage At Top Perf = 4 3645.96 2688 2682 36.9 4473
75 11:46:46 Alarm Delta Stage At Top Perf = 5 3691.59 2245 2238 37.1 4051
76 11:48:48 Alarm Delta Stage At Top Perf = 6 3767 2087 2096 37.1 3960
77 11:51:24 Alarm Delta Stage At Top Perf = 7 3863.32 2009 2018 36.9 3902
78 11:54:08 Alarm Delta Stage At Top Perf = 8 3964.19 1966 1996 36.6 3916
79 11:57:06 Alarm Delta Stage At Top Perf = 9 4073.71 1998 2015 37 3912
80 12:00:11 Alarm Delta Stage At Top Perf = 10 4187.57 1998 2013 36.9 3919
81 12:03:30 Alarm Delta Stage At Top Perf = 11 4310.07 1957 2000 37.3 3929
82 12:04:31 Drop Ball Drop Ball 21 4347.4 2116 2140 37.2 3933
21 12:04:41 (05/31/24) Next Treatment Treatment Interval 21 4353.6 2164 2181 37.2 3935
83 12:04:41 Drop Ball Drop Ball 21 4353.6 2167 2183 37.2 3935
84 12:05:35 Alarm Delta Stage At Top Perf = 12 4387.66 2277 2278 37.2 3953
85 12:07:21 Other Slow Down for Ball 21 4452.38 2259 2263 37.2 3848
86 12:10:08 Ball on Seat Ball 20 on Seat 4491.52 1725 1755 10.2 3523
87 12:10:11 Alarm Delta Stage At Top Perf = 13 4492.03 2292 2259 10.2 4227
88 12:10:15 Break Formation Break Formation 4492.7 3362 3336 10.2 5358
89 12:12:05 Alarm Delta Stage At Top Perf = 1 4524.76 3600 3549 34.6 5125
90 12:12:43 Alarm Delta Stage At Top Perf = 2 4547.75 3436 3412 37 4969
91 12:23:00 Alarm Delta Stage At Top Perf = 3 4929.36 2853 2848 36.9 4561
92 12:23:56 Alarm Delta Stage At Top Perf = 4 4963.79 2577 2574 36.8 4313
93 12:25:09 Alarm Delta Stage At Top Perf = 5 5008.51 2264 2255 36.7 4039
94 12:27:13 Alarm Delta Stage At Top Perf = 6 5084.6 2131 2135 36.9 3953
95 12:29:46 Alarm Delta Stage At Top Perf = 7 5178.72 2026 2040 36.9 3914
96 12:32:34 Alarm Delta Stage At Top Perf = 8 5282.06 1936 1951 36.9 3856
97 12:35:39 Alarm Delta Stage At Top Perf = 9 5395.9 1895 1906 36.9 3817
98 12:38:40 Alarm Delta Stage At Top Perf = 10 5507.03 1866 1881 36.8 3821
99 12:42:02 Alarm Delta Stage At Top Perf = 11 5631.06 1894 1900 37.1 3823
100 12:42:33 Start Flush Start Flush 5650.25 1902 1923 37.2 3829
101 12:44:20 Alarm Delta Stage At Top Perf = 12 5716.42 2160 2167 37 3839
102 12:47:08 Alarm Delta Stage At Top Perf = 13 5820.06 1761 1981 36.9 3607
103 12:47:15 ISIP ISIP 5823.09 905 909 23.7 3315
104 12:52:13 Shut-In Pressure @ 5 Minutes Shut-In Pressure @ 5 Minutes 5824.22 0 35 0 3247
105 12:53:46 Other Begin Blow Down Pumps 5824.22 0 37 0 3235
106 12:57:12 Shut-In Pressure @ 10 Minutes Shut-In Pressure @ 10 Minutes 5824.22 17 56 0 3215
107 13:02:10 Shut-In Pressure @ 15 Minutes Shut-In Pressure @ 15 Minutes 5824.22 20 60 0 3188
108 13:05:13 Other LRS Begin Bleed Down 5824.22 0 41 0 3169
109 13:19:10 Other Blowing Down Water Lines 5824.22 -28 14 0 3077
Event Log 5-31
Conoco Phillips - 3S-606 Event Log- 5-31 120
Seq No. Time Activity Code Comment Job Slurry Vol Treating Pressure Treating Pressure @Pump Slurry Rate Tubing Gauge BH Pres
1 08:51:01 (06/10/24) Start Job Starting Job 0 0 0 0 0
1 08:51:01 (06/10/24) Next Treatment Treatment Interval 1 0 0 0 0 0
2 9:37:25 Prime Pumps Prime Pumps 4.38 4 -4 0 0
3 9:54:58 Pressure Test ePRV Test - Primary Tubing 4.38 1228 1218 0 0
4 9:56:02 Pressure Test ePRV Test - Primary IA 4.38 1146 1167 0 0
5 9:57:01 Pressure Test ePRV Test - Secondary Tubing 4.38 1204 1247 0 0
6 9:58:15 Pressure Test ePRV Test - Secondary IA 4.38 1244 1167 0 0
7 11:12:08 Pressure Test Pressure Test - Globals 4.38 261 320 0 0
8 11:12:11 Pressure Test Pressure Test - Locals 4.38 273 335 0 0
9 11:15:11 Pressure Test Pressure Test - Max 4.38 9753 9699 0 0
10 11:20:18 Pressure Test Pressure Test - Pass 4.38 9730 9656 0 0
11 12:15:06 Pre-Job Safety Meeting Pre-Job Safety Meeting 4.38 82 112 0 2082
12 12:59:51 NPT Not Due to HES - Start Waiting on Dart to be loaded 4.38 80 110 0 2082
13 14:48:05 Start Mix Mix Gel 4.38 77 13 0 2082
14 16:20:04 Other Dart Loaded 4.38 307 67 0 2082
15 16:20:28 NPT Not Due to HES - End Dart Loaded 4.38 307 66 0 2082
22 16:32:56 (06/10/24) Next Treatment Treatment Interval 22 4.38 304 67 0 2083
16 16:35:53 Open Well Open Well 4.38 133 100 0 2092
17 16:38:37 Other Dart Launched 24.7 545 580 11.9 2309
18 16:45:01 Other Slow for dart 116.3 589 624 15.1 2467
19 16:48:24 Ball on Seat Dart on Seat 158.05 369 402 12.2 2736
20 16:48:36 Break Formation Break Formation 160.49 2903 2956 12.2 3676
21 16:49:07 Alarm Delta Stage At Top Perf = 4 166.97 1243 1227 12.2 3235
22 16:55:07 Start Pad Good XL (Start Pad) 261.06 1201 1215 14.9 3167
23 16:57:48 Alarm Delta Stage At Top Perf = 5 331.01 1955 1949 36.7 3456
24 16:59:04 Other Pump 201 - Rocking 377.42 1807 1836 35.5 3400
25 17:00:23 Alarm Delta Stage At Top Perf = 6 424.77 1843 1873 36.7 3468
26 17:00:50 Alarm Delta Stage At Top Perf = 7 441.04 1875 1844 35.8 3416
27 17:11:28 Alarm Delta Stage At Top Perf = 8 827.55 1756 1753 37 3449
28 17:12:28 Alarm Delta Stage At Top Perf = 9 864.55 1732 1730 37 3462
29 17:13:40 Alarm Delta Stage At Top Perf = 10 908.9 1695 1698 37 3481
30 17:15:43 Alarm Delta Stage At Top Perf = 11 984.65 1670 1670 36.9 3506
31 17:18:19 Alarm Delta Stage At Top Perf = 12 1080.6 1666 1666 36.9 3515
32 17:21:02 Alarm Delta Stage At Top Perf = 13 1180.88 1691 1693 36.9 3546
33 17:24:03 Alarm Delta Stage At Top Perf = 14 1292.12 1730 1734 36.8 3570
34 17:27:12 Alarm Delta Stage At Top Perf = 15 1408.12 1765 1761 36.8 3594
35 17:29:39 Other Close Gates 1497.61 1765 1765 36.7 3602
36 17:30:33 Alarm Delta Stage At Top Perf = 16 1531.39 1757 1751 37 3607
37 17:32:40 Drop Ball Launch Dart 1593.37 1400 1382 24 3448
23 17:32:45 (06/10/24) Next Treatment Treatment Interval 23 1594.97 1390 1386 23.9 3436
38 17:33:25 Alarm Delta Stage At Top Perf = 17 1611.33 1458 1474 23.9 3438
39 17:35:44 Other Slow for Dart 1666.36 1477 1484 23.9 3462
40 17:38:46 Alarm Delta Stage At Top Perf = 18 1705.21 1496 1506 12.1 3369
41 17:39:19 Ball on Seat Dart on Seat 1711.67 1528 1529 12.1 3920
42 17:39:27 Break Formation Break Formation 1713.28 4306 4189 12.1 5425
43 17:42:07 Alarm Delta Stage At Top Perf = 1 1749.37 1657 1648 22 3318
44 17:43:04 Alarm Delta Stage At Top Perf = 2 1775.19 1929 1923 33.9 3422
45 17:53:27 Alarm Delta Stage At Top Perf = 3 2160.18 1657 1651 37.1 3430
46 17:54:25 Alarm Delta Stage At Top Perf = 4 2195.96 1635 1637 37 3446
47 17:55:42 Alarm Delta Stage At Top Perf = 5 2243.38 1586 1584 36.9 3446
48 17:57:45 Alarm Delta Stage At Top Perf = 6 2318.99 1568 1573 37 3450
49 18:00:19 Alarm Delta Stage At Top Perf = 7 2413.98 1556 1562 37 3456
50 18:03:04 Alarm Delta Stage At Top Perf = 8 2515.63 1566 1567 36.9 3478
51 18:06:03 Alarm Delta Stage At Top Perf = 9 2626.03 1588 1595 36.9 3486
52 18:06:24 Other Load Dart 2638.34 1602 1607 37 3496
53 18:09:08 Alarm Delta Stage At Top Perf = 10 2739.88 1583 1582 36.9 3486
54 18:11:34 Other Close Gate on Castle 2828.26 1631 1624 36.5 3519
55 18:12:27 Alarm Delta Stage At Top Perf = 11 2860.77 1661 1669 36.9 3529
56 18:14:48 Alarm Delta Stage At Top Perf = 12 2948.01 1938 1943 37.1 3581
24 18:14:52 (06/10/24) Next Treatment Treatment Interval 24 2949.88 1929 1913 37.1 3543
57 18:14:53 Ball on Seat Launch Dart 2950.5 1917 1894 37.1 3533
58 18:17:02 Other Slow for Dart 3030.13 1806 1787 37 3460
59 18:18:32 Alarm Delta Stage At Top Perf = 13 3054.2 1355 1360 12 3337
60 18:22:01 Alarm Delta Stage At Top Perf = 1 3096.26 1438 1452 12.2 3295
61 18:22:36 Other No Dart Seat - Cutting Sand 3103.34 1461 1475 12.1 3306
62 18:23:18 Other Stage to Flush 3112.04 1492 1502 12.2 3313
63 18:23:56 Alarm Delta Stage At Top Perf = 2 3119.73 1513 1524 12.1 3322
64 18:33:21 Alarm Delta Stage At Top Perf = 3 3258.71 1132 1221 15.2 3372
65 18:33:42 NPT Not Due to HES - Start Shut Down to Build Dart 3260.73 1069 538 1.5 3266
66 18:44:01 NPT Not Due to HES - End Dart Ready 3260.73 73 145 0 3177
67 18:49:19 Open Well Open Well 3260.73 961 842 0 3149
68 18:51:20 Other Launch Dart 3276.82 1316 1368 12 3307
69 19:00:08 Ball on Seat Ball on Seat 3384.02 1270 1327 12.2 3772
70 19:00:17 Break Formation Break Formation 3386.06 4303 4299 12.2 6019
71 19:05:04 Alarm Delta Stage At Top Perf = 5 3502.47 3895 3877 33.4 5709
72 19:06:35 Alarm Delta Stage At Top Perf = 6 3552.42 3653 3694 33.5 5342
73 19:11:58 Alarm Delta Stage At Top Perf = 7 3748.56 2342 2341 37.1 4094
74 19:12:53 Alarm Delta Stage At Top Perf = 8 3782.53 2231 2230 37 4003
75 19:14:07 Alarm Delta Stage At Top Perf = 9 3828.16 2007 2013 37 3866
76 19:16:10 Alarm Delta Stage At Top Perf = 10 3903.88 1803 1815 36.9 3690
77 19:18:46 Alarm Delta Stage At Top Perf = 11 4000.17 1741 1756 37 3657
78 19:21:33 Alarm Delta Stage At Top Perf = 12 4103.18 1711 1733 36.9 3660
79 19:23:06 Other Tank Swap 4160.49 1699 1722 37 3663
80 19:24:32 Alarm Delta Stage At Top Perf = 13 4213.48 1695 1718 37 3659
81 19:27:39 Alarm Delta Stage At Top Perf = 14 4329.08 1707 1730 36.8 3656
82 19:31:02 Alarm Delta Stage At Top Perf = 15 4453.06 1755 1775 36.8 3669
83 19:31:23 Other Castle Empty 4465.94 1772 1787 36.8 3676
84 19:33:25 Alarm Delta Stage At Top Perf = 16 4540.88 1808 1831 36.9 3691
85 19:37:38 Alarm Delta Stage At Top Perf = 17 4696.82 1579 1844 36.9 3576
86 19:37:48 ISIP ISIP 4700.77 1268 1104 0 3409
87 19:42:48 Shut-In Pressure @ 5 Minutes Shut-In Pressure @ 5 Minutes 4700.77 -13 28 0 3283
88 19:46:48 Shut-In Pressure @ 10 Minutes Shut-In Pressure @ 10 Minutes 4700.77 1 37 0 3250
89 19:51:47 Shut-In Pressure @ 15 Minutes Shut-In Pressure @ 15 Minutes 4700.77 120 165 0 3218
Event Log 6-10
Conoco Phillips - 3S-606 Event Log- 6-10 121
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Break Test3S-606Stage(s):Break Test140Water Source:ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:5/28/2024ConocoPhillipsProject No:EBRITTONHydration Visc: 28 80Temperature was held at 140 degres for the duration of the testAll chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:6.80Hydration pH:7.30Temp 0F PH LOSURF-300D CL-28M BA-20 MO-67 Optiflo-III OptiFlo-II CAT-391 9.20 1.00 2.00 0.33 2.00 0.002.00 0.33 0.85 2.000.85 2.004.00 0.2591 9.20 1.0005001000150020002500300000:00 02:00 04:00 10:00 20:00 30:00 1:00 1:30 2:00 2:30 3:00 4:00 5:00 6:00 7:00 8:00Viscosity (cp)Time (min:sec)Prejob Crosslink Break TestsSeries1Opti II @ 2.0 & Opti III @ 2.0Opti III @ 2.0 & Opti II @ 4.0 w/CAT3Fluid is broken at 200cpConoco Phillips - 3S-606 Prejob Break Test 5-28-24 122
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Break Test 1Break Test 2Break Test 32.00140 9.50 1.00 2.20 0.00 0.50 2.000.40 2.00140 9.50 1.00 2.20 0.00 2.00 0.00Temp 0F PH LOSURF-300D CL-28M CAT-3 MO-67 Optiflo-III OptiFlo-II OPTI HTEE.BRITTONHydration Visc: 32 68Temperature was held at 140 degres for the duration of the testAll chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:6.90TOROKHydration pH:7.303S-606Stage(s):Break Test140Water Source:CP3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:6/9/2024ConocoPhillipsProject No:02004006008001000120014001600180000:00 02:00 04:00 10:00 20:00 30:00 1:00 30:00 00:00 30:00 00:00 00:00 00:00 00:00 00:00 00:00Viscosity (cp)Time (min:sec)Prejob Crosslink Break TestsBreak Test 1Break Test 2Break Test 3Fluid is broken at 200cpConoco Phillips - 3S-606 Prejob Break Test - 6-09-24 123
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini Frac0.5 ppg 1 ppg 2 ppg3 ppg4 ppg2.008.50 1.508.50 1.50 2.00 0.50 0.252.00 0.50 0.25 2.00Temp 0F PH LOSURF-300D CL-28 WG-11 MO-67 Optiflo II Optiflo IIIEBRITTONHydration Visc: 25 80All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:Hydration pH:3S-606Stage(s):10140Water Source:3S PWALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:5/29/2024ConocoPhillipsProject No:0200400600800100012001400160000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 10 Crosslink TestsMini Frac0.5 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-606 Fann 15 Min Test Zone 10 124
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini FracPad2 ppg3 ppg4 ppg5 ppg0.33 1.00 2.00 0.00 1.20 2.00 2.00Temp 0F BA-20 LOSURF-300D CL-28 Cat3 MO-67 Optiflo II Optiflo IIIEBRITTONHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:Hydration pH:3S-606Stage(s):11140Water Source:3S PWALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:5/29/2024ConocoPhillipsProject No:02004006008001000120014001600180000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 11 Crosslink TestsPADFluid is broken at 200cpConoco Phillips - 3S-606 Zone 11 125
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini FracPad2 ppg3 ppg4 ppg5 ppg0.33 1.00 2.00 0.00 1.20 2.00 2.00Temp 0F BA-20 LOSURF-300D CL-28 Cat3 MO-67 Optiflo II Optiflo IIIEBRITTONHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:NarwhalHydration pH:3S-606Stage(s):12140Water Source:3S PWALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:5/29/2024ConocoPhillipsProject No:0500100015002000250000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 12 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-606 Zone 12 126
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini FracPad2 ppg3 ppg4 ppg5 ppg0.33 1.00 2.00 0.00 1.20 2.00 2.00Temp 0F BA-20 LOSURF-300D CL-28 Cat3 MO-67 Optiflo II Optiflo IIIEBRITTONHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:NarwhalHydration pH:3S-606Stage(s):13140Water Source:3S PWALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:5/30/2024ConocoPhillipsProject No:05001000150020002500300000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 13 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-606 Zone 13 127
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini FracPad2 ppg3 ppg4 ppg5 ppg0.33 1.00 2.00 0.00 1.20 2.00 2.00Temp 0F BA-20 LOSURF-300D CL-28 Cat3 MO-67 Optiflo II Optiflo IIIEBRITTONHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:NarwhalHydration pH:3S-606Stage(s):14140Water Source:3S PWALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:5/30/2024ConocoPhillipsProject No:050010001500200025003000350000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 14 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-606 Zone 14 128
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini FracPad2 ppg3 ppg4 ppg5 ppg0.33 1.00 2.00 0.00 1.20 2.00 2.00Temp 0F BA-20 LOSURF-300D CL-28 Cat3 MO-67 Optiflo II Optiflo IIIEBRITTONHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:NarwhalHydration pH:3S-606Stage(s):15140Water Source:3S PWALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:5/30/2024ConocoPhillipsProject No:05001000150020002500300000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 15 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-606 Zone 15 129
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini FracPad2 ppg3 ppg4 ppg5 ppg0.33 1.00 2.00 0.00 1.20 2.00 2.00Temp 0F BA-20 LOSURF-300D CL-28 Cat3 MO-67 Optiflo II Optiflo IIIEBRITTONHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:NarwhalHydration pH:3S-606Stage(s):16140Water Source:3S PWALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:5/30/2024ConocoPhillipsProject No:05001000150020002500300000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 16 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-606 Zone 16 130
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini FracPad2 ppg3 ppg4 ppg5 ppg0.33 1.00 2.00 0.00 1.20 2.00 2.00Temp 0F BA-20 LOSURF-300D CL-28 Cat3 MO-67 Optiflo II Optiflo IIIEBRITTONHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:NarwhalHydration pH:3S-606Stage(s):17140Water Source:3S PWALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:5/30/2024ConocoPhillipsProject No:02004006008001000120014001600180000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 17 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-606 Zone 17 131
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini FracPad2 ppg3 ppg4 ppg5 ppg0.33 1.00 2.00 0.00 1.20 2.00 2.00Temp 0F BA-20 LOSURF-300D CL-28 Cat3 MO-67 Optiflo II Optiflo IIIEBRITTONHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:NarwhalHydration pH:3S-606Stage(s):18140Water Source:3S PWALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:5/31/2024ConocoPhillipsProject No:020040060080010001200140016001800200000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 18 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-606 Zone 18 132
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini FracPad2 ppg3 ppg4 ppg5 ppg0.33 1.00 2.00 0.00 1.20 2.00 2.00Temp 0F BA-20 LOSURF-300D CL-28 Cat3 MO-67 Optiflo II Optiflo IIIEBRITTONHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:NarwhalHydration pH:3S-606Stage(s):19140Water Source:3S PWALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:5/31/2024ConocoPhillipsProject No:05001000150020002500300000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 19 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-606 Zone 19 133
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini FracPad2 ppg3 ppg4 ppg5 ppg0.33 1.00 2.00 0.00 1.20 2.00 2.00Temp 0F BA-20 LOSURF-300D CL-28 Cat3 MO-67 Optiflo II Optiflo IIIEBRITTONHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:NarwhalHydration pH:3S-606Stage(s):20140Water Source:3S PWALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:5/31/2024ConocoPhillipsProject No:020040060080010001200140016001800200000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 20 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-606 Zone 20 134
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini FracPad2 ppg3 ppg4 ppg5 ppg0.33 1.00 2.00 0.00 1.20 2.00 2.00Temp 0F BA-20 LOSURF-300D CL-28 Cat3 MO-67 Optiflo II Optiflo IIIEBRITTONHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:NarwhalHydration pH:3S-606Stage(s):21140Water Source:3S PWALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:5/31/2024ConocoPhillipsProject No:050010001500200025003000350000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 21 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-606 Zone 21 135
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini FracPad2 ppg3 ppg4 ppg5 ppg90 8.80 1.00 2.00 0.70 2.00 2.002.0090 8.80 1.00 2.00 0.70 2.00Temp 0F PH LOSURF-300D CL-28 Cat3 MO-67 Optiflo II Optiflo IIIEBRITTONHydration Visc: 25 80All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:NarwhalHydration pH:3S-606Stage(s):22140Water Source:CPF 3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:6/10/2024ConocoPhillipsProject No:010020030040050060000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 1 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-606 Zone 22 136
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini FracPad2 ppg3 ppg4 ppg5 ppg90 8.80 1.00 2.00 0.70 2.00 2.002.0090 8.80 1.00 2.00 0.70 2.00Temp 0F PH LOSURF-300D CL-28 Cat3 MO-67 Optiflo II Optiflo IIIEBRITTONHydration Visc: 25 80All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:NarwhalHydration pH:3S-606Stage(s):23140Water Source:CPF 3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:6/10/2024ConocoPhillipsProject No:02004006008001000120014001600180000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 1 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-606 Zone 23 137
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini FracPad2 ppg3 ppg4 ppg5 ppg90 8.80 1.00 2.00 0.70 2.00 2.002.0090 8.80 1.00 2.00 0.70 2.00Temp 0F PH LOSURF-300D CL-28 Cat3 MO-67 Optiflo II Optiflo IIIEBRITTONHydration Visc: 25 80All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:NarwhalHydration pH:3S-606Stage(s):24140Water Source:CPF 3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:6/10/2024ConocoPhillipsProject No:02004006008001000120014001600180000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 1 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-606 Zone 24 138
Company: Conoco PhillipsWell: 3S-606Sand Type 16/20 ProppantDate Tested 5/29/2024Total Sample Size Seive Weight Seive Weight 100.0 gSieve Size Before Sand With sand WT. rtn'd % rtn'd % API Spec12 355.4 355.4 0 0.0% 0.00% <0.1%16 340.5 348.23 7.73 7.7%18 673.1 757.39 84.29 84.3%20 296.8 304.01 7.21 7.2%25 419.8 419.8 0 0.0%30 281.8 281.8 0 0.0%40 408.2 408.2 0 0.0%Pan 306.8 306.8 0 0.0% 0.00% <1.0%Total: 99.23 99%Total Sample Size Seive Weight Seive Weight 100.0 gSieve Size Before Sand With sand WT. rtn'd % rtn'd % API Spec12 355.4 355.4 0 0.0% 0.00% <0.1%16 340.5 345.67 5.17 5.2%18 673.1 752.9 79.8 79.8%20 296.8 308.4 11.6 11.6%25 419.8 419.8 0 0.0%30 281.8 281.8 0 0.0%40 408.2 408.2 0 0.0%Pan 306.8 306.8 0 0.0% 0.00% <1.0%Total: 96.57 97%Total Sample Size Seive Weight Seive Weight 100.0 gSieve Size Before Sand With sand WT. rtn'd % rtn'd % API Spec12 355.4 355.4 0 0.0% 0.00% <0.1%16 340.5 343.95 3.45 3.4%18 673.1 758.66 85.56 85.6%20 296.8 307.72 10.92 10.9%25 419.8 419.8 0 0.0%30 281.8 281.8 0 0.0%40 408.2 408.2 0 0.0%Pan 306.8 306.8 0 0.0% 0.00% <1.0%Total: 99.93 100%Total Sample Size Seive Weight Seive Weight 100.0 gSieve Size Before Sand With sand WT. rtn'd % rtn'd % API Spec12 355.4 355.4 0 0.0% 0.00% <0.1%16 340.5 344 3.5 3.5%18 673.1 758.57 85.47 85.5%20 296.8 307.77 10.97 11.0%25 419.8 419.8 0 0.0%30 281.8 281.8 0 0.0%40 408.2 408.2 0 0.0%Pan 306.8 306.8 0 0.0% 0.00% <1.0%Total: 99.94 100%96.48% >/= 90%Sample:16/20 - 6/10/2496.44% >/= 90%Sample:16/20 - 5/30/2491.40% >/= 90%Sample:16/20 - 5/31/2491.50% >/= 90%Ceramic Proppant Sieves Sample:16/20 - 05/29/24Conoco Phillips - 3S-606 Sand Sieve Analysis 139
Hydraulic Fracturing Fluid Product Component Information Disclosure
2024-05-29
Alaska
HARRISON BAY
50-103-20870-00-00
CONOCOPHILLIPS
3S 606
-150.19550000
70.39428000
NAD83
none
Oil
5261
968326
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
Produced Water
(Density 8.5) Operator Base Fluid Density = 8.50
SEAWATER (SG
8.52) Operator Base Fluid Density = 8.52
BA-20
BUFFERING
AGENT Halliburton Buffer
BE-6(TM)
Bactericide Halliburton Microbiocide
CAT-3
ACTIVATOR Halliburton Activator
CL-28M
CROSSLINKER Halliburton Crosslinker
LoSurf-300D Halliburton Non-ionic Surfactant
LVT-200
Baker
Hughes Additive
MO-67 Halliburton pH Control
OPTIFLO-II
DELAYED
RELEASE
BREAKER Halliburton Breaker
OPTIFLO-III
DELAYED
RELEASE
BREAKER Halliburton Breaker
SP BREAKER Halliburton Breaker
WG-36 GELLING
AGENT Halliburton Gelling Agent
Ceramic
Proppant - Wanli Wanli Proppant
SAND,
COMMON
BROWN 100
MESH Halliburton Proppant
Flow Insurance
Brass
Patina
Energy Tracer
Flow Insurance
Copper
Patina
Energy Tracer
Potassium
Formate Brine MI Swaco
Completion/Stimulati
on
Ingredients Water 7732-18-5 100.00%75.88146%8230771
Corundum 1302-74-5 65.00%14.86291%1612163
Mullite 1302-93-8 45.00%10.28971%1116113
Crystalline silica, quartz 14808-60-7 100.00%0.61678%66901
Guar gum 9000-30-0 100.00%0.24142%26187
Water 7732-18-5 100.00%0.20340%22063
Borate salts Proprietary 60.00%0.10451%11336
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
Ammonium persulfate 7727-54-0 100.00%0.04370%4740
Ethanol 64-17-5 60.00%0.03977%4314
Sodium hydroxide 1310-73-2 30.00%0.02730%2961
Heavy aromatic petroleum
naphtha 64742-94-5 30.00%0.01988%2157
Oxyalkylated nonyl phenolic resin Proprietary 30.00%0.01988%2157 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Ammonium acetate 631-61-8 100.00%0.01839%1995
Oxylated phenolic resin Proprietary 30.00%0.01311%1422 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Potassium chloride 7447-40-7 5.00%0.00871%945
Inorganic mineral 1317-65-3 5.00%0.00871%945
Oxyalkylated phenolic resin Proprietary 10.00%0.00663%719 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Acetic acid 64-19-7 30.00%0.00552%599
Flow Insurance Brass Proprietary 100.00%0.00533%578 Patina Energy Product Stewardship
test@patinae
nergy.com 7205324886
Poly(oxy-1,2-ethanediyl), alpha-(4-
nonylphenyl)-omega-hydroxy-,
branched 127087-87-0 5.00%0.00331%360
Naphthalene 91-20-3 5.00%0.00331%360
Calcium magnesium carbonate 16389-88-1 1.00%0.00174%189
Polymer Proprietary 1.00%0.00174%189 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Inorganic mineral Proprietary 1.00%0.00174%189 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Gluteraldehyde 111-30-8 1.00%0.00174%189
2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00%0.00138%150
Sodium chloride 7647-14-5 1.00%0.00091%99
EDTA/Copper chelate Proprietary 30.00%0.00072%78 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
1,2,4 Trimethylbenzene 95-63-6 1.00%0.00066%72
C.I. pigment Orange 5 3468-63-1 1.00%0.00025%27
Sodium bisulfate 7681-38-1 0.10%0.00017%19
Methanesulfonic acid, 1-hydroxy-,
sodium salt 870-72-4 0.10%0.00017%19
Ammonium chloride 12125-02-9 5.00%0.00012%13
Ammonia 7664-41-7 1.00%0.00002%3
Magensium chloride 7786-30-3 0.01%0.00002%2
5-Chloro-2-methyl-3(2H)-
Isothaiazolone 26172-55-4 0.01%0.00002%2
Magnesium nitrate 10377-60-3 0.01%0.00002%2
2-Methyl-4-isothiazolin-3-one 2682-20-4 0.01%0.00002%2
0.00%0.00000%0
Potassium Formate 590-29-4 100.00%0.00000%0
Distillates (petroleum),
hydrotreated light 64742-47-8 100.00%0.00000%0
Sodium persulfate 7775-27-1 100.00%0.00000%0
Sodium sulfate 7757-82-6 0.10%0.00000%0
Flow Insurance Copper Proprietary 100.00%0.00000%0 Patina Energy Product Stewardship
test@patinae
nergy.com 7205324886
Water 7732-18-5 100.00%0.00000%0
Sodium chloride 7647-14-5 5.00%0.00000%0
* 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 1.4
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:
1a. Well Status:Oil SPLUG Other Abandoned Suspended
1b. Well Class:
20AAC 25.105 20AAC 25.110 Development Exploratory
GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test
2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry:
Aband.:
3. Address: 7. Date Spudded: 15. API Number:
4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number:
Surface:
Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s):
GL: 25.30 BF:
Total Depth: 1952' FNL, 4 FEL, Sec 35, T13N, R7E 10. Plug Back Depth MD/TVD: 18. Property Designation:
4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number:
Surface: x- y- Zone- 4
TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD:
Total Depth: x- y- Zone- 4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 N/A (ft MSL)
22. Logs Obtained:
23.
BOTTOM
20" H-40 235'
10 3/4" L-80 2557'
7 5/8" L-80 5148'
4 1/2" P11OS 5181'
24. Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr):
Press. 24-Hour Rate
Sr Res EngSr Pet GeoSr Pet Eng
N/A
Oil-Bbl: Water-Bbl:
7151MD/5022' TVD
7285'MD/5083' TVD
GR, RES, PWD, DIR, AZI, DEN, NEU, CALIPER, SONIC
Water-Bbl:
PRODUCTION TEST
N/A- Injection Well
Date of Test: Oil-Bbl:
DEPTH SET (MD) PACKER SET (MD/TVD)If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date perf'd or liner run):
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
TUBING RECORD
7289'4.5"
Flow Tubing
Liner ran on 3/1/24 @ 7285'MD/5083'TVD to 20,118'MD/5181'TVD
Gas-Oil Ratio:Choke Size:
Per 20 AAC 25.283 (i)(2) attach electronic information
37'
5083'
94
45.5
235'
37' 7466'
SIZE
42"
13.5"
10 yards
39'Lead: 470bbls of10.2ppg G
Blend
Tail: 56bbls of 15.8ppg Class G
12.6
40'
7285'
2922'
6.5"
140bbls of 15.3ppg Class G
9.875"
39'
40'
29.7
20118'
5998164
1744'MD/1716'TVD
SETTING DEPTH TVD
6010321
TOP HOLE SIZE AMOUNT
PULLED
474013
470928
TOP
SETTING DEPTH MD
suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud
log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing
collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary.
Kuparuk River Field/ Torok Oil Pool
N/A
BOTTOM
CASING, LINER AND CEMENTING RECORD
List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion,
CASING WT. PER
FT.GRADE CEMENTING RECORD
50-103-20870-00-00
KRU 3S-606
LONS 01-013
1/26/2024
20,119' MD/5180'TVD
N/A
65.4
P.O. Box 100360 Anchorage, AK 99510-0360
476349 5993933
3538 FNL, 3245 FEL, Sec 7, T12N, R8E
2/25/20242482' FNL, 911' FEL, Sec 18, T12N, R8E
ADL 380107, ADL 380106. ADL 393883
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
ConocoPhillips Alaska, Inc.
WAG
Gas
3/5/2024 223-111
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
By Grace Christianson at 3:55 pm, Apr 03, 2024
Complete
3/5/2024
JSB
RBDMS JSB 040924
G
DSR-5/1/24
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
Surface Surface
1380 1371
1662 1640
1744 1716
2109 2024
3018 2612
4400 3428
5201 3899
Coyote 5545 4101
7544 5172
20119 5181
(Torok)
31. List of Attachments:
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Matt Smith
Digital Signature with Date:Contact Email:matt.smith@conocophillips.com
Contact Phone:907-265-6824
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:
Top of Productive Interval
(Torok)
Authorized Title: Drilling Engineer
Direction Survey, Operations Summary, Cementing Summary, Well Schematic
Ugnu B
Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment; or 90 days after log acquisition, whichever occurs first.
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
C-50
Permafrost - Base
C-35
Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic
diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from
a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071.
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core
analysis, paleontological report, production or well test results, per 20 AAC 25.070.
Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
West Sak
C-80
Formation Name at TD:
TPI (Top of Producing Interval).
Authorized Name and
INSTRUCTIONS
Yes No
Well tested? Yes No
28. CORE DATA
If Yes, list intervals and formations tested, briefly summarizing test results for
each. Attach separate pages if needed and submit detailed test info including
reports and Excel or ASCII tables per 20 AAC 25.071.
NAME
Permafrost - Top
Ugnu C
If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if
needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired.
29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
Top Coyote 5545' MD / 4101' TVD)
3S-606 Wellbore Schematic
Grassroots Horizontal Moraine Injector
10-¾" 45.5# L80 H563 2922' MD / 2558' TVD 57° Inc
20" Conductor 235' MD
4-½" 12.6# P110S H563 20118' MD / 5181' TVD 90° Inc
4-½”12.6# L80 H563-MS9-6" Intermediate Hole
6-1/2" Production Hole
13-½" Surface Hole
03/04/2024
4-½” x 6" OD Swell Packer Frac sleeve
Sp
u
d
M
u
d
3.750", DB Nipple 7,217’ MD / 5,053’ TVD
SLZXP Liner Top Packer & Hanger 7,285' MD / 5,082’ TVD
4-½” x 7-F " HAL TNT Packer 7,151’ MD / 5,022’ TVD
SonicScope TOC 3950' MD / 3164' TVD
HAL Opsis Mandrel 7,045’ MD / 4,969’ TVD
Top Moraine 7544' MD / 5172' TVD
Gas Lift Mandrel, 4-½” x 1” 2,114’ MD / 2,027’ TVD
Wellbore Isolation Valve
Alpha Sleeve
Gas Lift Mandrel, 4-½” x 1” 6,935’ MD / 4,911’ TVD
6-½” TD 20119' MD / 5181' TVD 90° Inc
7-F" 33.7# P-110S H563 (heavy heel) 6615' - 7336' MD
7-F" 29.7# L-80 H563 7466' MD / 5148' TVD 72° Inc
Page 1/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/24/2024
00:00
1/24/2024
01:00
1.00 MIRU, MOVE DMOB P PJSM with NES. Move rock washer,
cutting boxes, Magtec vac unit. Remove
matting boards in Magtec work area.
0.0 0.0
1/24/2024
01:00
1/24/2024
01:45
0.75 MIRU, MOVE DMOB P Troubleshoot cold start in sub module
and resolve issue. Start up cold start
engines. Allow to warm and switch
electrical load over to cold start
generator.
0.0 0.0
1/24/2024
01:45
1/24/2024
02:30
0.75 MIRU, MOVE DMOB P Electrician start unplugging electrical
disconnects between modules, from pit
module to sub module.
0.0 0.0
1/24/2024
02:30
1/24/2024
03:30
1.00 MIRU, MOVE DMOB P Finish disconnecting main electrical plug
board. Raise cellar wind walls.
0.0 0.0
1/24/2024
03:30
1/24/2024
04:15
0.75 MIRU, MOVE MOB P Jack up motor module and move
module.
0.0 0.0
1/24/2024
04:15
1/24/2024
05:00
0.75 MIRU, MOVE MOB P Jack up pump module, 0.0 0.0
1/24/2024
05:00
1/24/2024
06:00
1.00 MIRU, MOVE MOB P Move and reposition rig mats. Move and
reposition motor module.
0.0 0.0
1/24/2024
06:00
1/24/2024
06:30
0.50 MIRU, MOVE MOB P Move pump module. Continue moving
matting boards from 3S-624 to 3S-606
well.
0.0 0.0
1/24/2024
06:30
1/24/2024
07:00
0.50 MIRU, MOVE MOB P Jack up pipe shed module. Move
module.
0.0 0.0
1/24/2024
07:00
1/24/2024
07:30
0.50 MIRU, MOVE MOB P Jack up pipe module. Move module. 0.0 0.0
1/24/2024
07:30
1/24/2024
08:00
0.50 MIRU, MOVE MOB P Install 5th wheel tongue package to sub
module.
0.0 0.0
1/24/2024
08:00
1/24/2024
09:00
1.00 MIRU, MOVE MOB P Skid rig floor to move position and
secure.
0.0 0.0
1/24/2024
09:00
1/24/2024
09:15
0.25 MIRU, MOVE MOB P PJSM. 5x5 warm up break. Discuss
upcoming job tasks and SOP's with
crew members.
0.0 0.0
1/24/2024
09:15
1/24/2024
10:30
1.25 MIRU, MOVE MOB P Prepare stompers lift and secure for
move.
0.0 0.0
1/24/2024
10:30
1/24/2024
12:00
1.50 MIRU, MOVE MOB P Pull Sub off 3S-624 well - witness by
CPAI REP and Pad operator.
0.0 0.0
1/24/2024
12:00
1/24/2024
12:15
0.25 MIRU, MOVE MOB P Fuel NES rig move trucks and Rig
complex modules cold start engines.
0.0 0.0
1/24/2024
12:15
1/24/2024
14:30
2.25 MIRU, MOVE MOB P Spot sub module over 3S-606 well.
Center sub and level. Witness by CPAI
Rep and CPAI pad operator.
0.0 0.0
1/24/2024
14:30
1/24/2024
15:45
1.25 MIRU, MOVE MOB P Remove 5th wheel tongue package from
sub module.
0.0 0.0
1/24/2024
15:45
1/24/2024
20:00
4.25 MIRU, MOVE MOB P Lower stoppers. Level sub module and
secure stompers.Skid rig floor to ODS
skid cylinders not operating properly due
to cold weather.
0.0 0.0
1/24/2024
20:00
1/25/2024
00:00
4.00 MIRU, MOVE MOB P Spot pipe shed module in place and
shim/level secure module, lower casttle
chute and breeze way. (Simops)
hooking up service lines from pits and
sub module..
0.0 0.0
1/25/2024
00:00
1/25/2024
02:00
2.00 MIRU, MOVE MOB P Spot pit module to the sub. Lower
transitions and put handrails in place.
0.0 0.0
1/25/2024
02:00
1/25/2024
03:00
1.00 MIRU, MOVE MOB P Spot pump module to the pits. Lower
transitions and put handrails in place.
0.0 0.0
1/25/2024
03:00
1/25/2024
04:30
1.50 MIRU, MOVE MOB P Spot motor module to the pumps. Lower
transitions and put handrails in place.
0.0 0.0
1/25/2024
04:30
1/25/2024
05:00
0.50 MIRU, MOVE MOB P Spot rockwasher to the pits. 0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 2/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/25/2024
05:00
1/25/2024
12:00
7.00 MIRU, MOVE RURD P Rig up air, steam, water, mud, and
electrical interconnects between
modules. Spot Magtec equipment and
run hoses. Berm up cellar and install
drip pans around the rig.
SIMOPS: Move equipment for coil P&A.
Quadco perform annual gauge
calibrations.
0.0 0.0
1/25/2024
12:00
1/25/2024
15:00
3.00 MIRU, MOVE RURD P Continue to rig up air, steam, water,
mud, and electrical interconnects
between modules. Continue to spot
Magtec equipment and run hoses. Berm
up cellar and install drip pans around
the rig. Troubleshoot drawworks
choppers and repair. Work on equalizer
valve in the pits. Rig accepted 15:00
hrs.
SIMOPS: Move equipment for coil P&A.
Quadco perform annual gauge
calibrations
0.0 0.0
1/25/2024
15:00
1/25/2024
17:00
2.00 MIRU, MOVE RURD P Remove top-drive handler shims used
for XT-39 saver sub. Install mouse hole.
Change out 10" butterfly equalizer valve
from pit #1 to pit #2. Install lollipop
pressure gauge on mud pump #2.
0.0 0.0
1/25/2024
17:00
1/25/2024
21:00
4.00 MIRU, MOVE RURD P Nipple up 20" surface riser from well
head riser to rig floor. Install new air-
boots. Replace valve stems on air boots
between pit #5 and pit #6. Continue
hooking up water and steam lines
through out rig.
0.0 0.0
1/25/2024
21:00
1/26/2024
00:00
3.00 MIRU, MOVE RURD P Remove MWD transducer from top-
drive stand pipe. Install new transducer
with new comm cable. Installl cellar
pump and cellar alarm and test them
(Good Test). Rig up rockwash transfer
lines and install winterizing on hoses to
cuttings tank. Function test drag chain.
Dress shakers out with proper screens
for surface hole section.
0.0 0.0
1/26/2024
00:00
1/26/2024
04:30
4.50 MIRU, MOVE RURD P Remove 2 links from drag chain and
properly adjust chain. Moblize BHA tools
and equipment to rig floor. Take on spud
mud to pits. Complere derrick
inspection. Grease crown blocks and
top-drive. Load 5" drill pipe in pipe shed.
Make up flow line room interconnects.
Change rig floor handling equipment for
surface BHA. Change out ST-100 die
blocks. Build LCM pills and hi-vis pill in
pits.
0.0 0.0
1/26/2024
04:30
1/26/2024
07:00
2.50 MIRU, MOVE PULD P Rig up handling equipment. Pick up and
rack back 5" HWDP and jar stand in the
derrick.
0.0 0.0
1/26/2024
07:00
1/26/2024
07:30
0.50 MIRU, MOVE SFTY P Pre-job safety meeting for picking up
BHA.
0.0 0.0
1/26/2024
07:30
1/26/2024
08:30
1.00 MIRU, MOVE BHAH T Locate bit breaker and 6-5/8" Reg lift
sub.
0.0 0.0
1/26/2024
08:30
1/26/2024
09:45
1.25 MIRU, MOVE BHAH P Pick up clean out assembly per SLB
DD.
0.0 45.0
1/26/2024
09:45
1/26/2024
10:15
0.50 MIRU, MOVE SFTY P Conduct pre-spud meeting with all
hands. Discuss drilling hazards, well
control drills and muster areas.
45.0 45.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 3/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/26/2024
10:15
1/26/2024
12:00
1.75 MIRU, MOVE CIRC P Flood lines, fill conductor and check for
leaks. Changed out leaking 4" ball valve
on conductor. Tag fill at 110' MD.
45.0 110.0
1/26/2024
12:00
1/26/2024
13:30
1.50 MIRU, MOVE PRTS P Charge pumps not pumping properly
due to high viscoisty spud mud. Isolate
on one pit with low viscoisty to verify
mud was working properly (Good).
Pressure mud lines to 4000 psi (Good
test).
110.0 110.0
1/26/2024
13:30
1/26/2024
14:45
1.25 MIRU, MOVE DRLG P Clean out 20" conductor from 110' MD
to 225" MD. GPM 400, PSI 400, F/O
51%, RPM 40, TQ 1k, WOB 1k.
110.0 225.0
1/26/2024
14:45
1/26/2024
15:00
0.25 MIRU, MOVE OWFF P OWFF (Well static). 225.0 225.0
1/26/2024
15:00
1/26/2024
15:30
0.50 MIRU, MOVE TRIP P POOH from 225' MD to 35' MD with 5"
drill pipe racking back in derrick. P/U
48k. Monitor displacement @ pit #5.
Blow down top-drive.
225.0 35.0
1/26/2024
15:30
1/26/2024
19:00
3.50 MIRU, MOVE BHAH P PJSM. Make up remaining 13-1/2"
directional BHA as per SLB DD, MWD
from 35' MD to 225" MD.
35.0 225.0
1/26/2024
19:00
1/27/2024
00:00
5.00 SURFAC, DRILL DDRL P Drill 13½” Surface hole from 225‘ MD to
551‘ MD / 500‘ TVD, WOB = 4K, GPM =
450, PSI = 640, RPM = 40, TQ = 1.5K,
F/O = 22%, ECD = 10.6 PPG, P/U =
71K, S/O = 85K, RT = 78K, AST= .90,
ART = 1.81, ADT = 1.08, Total bit hrs =
2.74, Total jars = 2.74.
225.0 551.0
1/27/2024
00:00
1/27/2024
06:00
6.00 SURFAC, DRILL DDRL P Drill 13½” Surface hole from 551‘ MD to
947‘ MD / 945‘ TVD, WOB = 4K, GPM =
500, PSI = 950, RPM = 40, TQ = 2K,
F/O = 56%, ECD = 9.95 PPG, P/U =
91K, S/O = 89K, RT = 90K, AST= .94,
ART = 2.14, ADT = 3.08, Total bit hrs =
5.82, Total jars = 1.3.
551.0 947.0
1/27/2024
06:00
1/27/2024
12:00
6.00 SURFAC, DRILL DDRL P Drill 13½” Surface hole from 947‘ MD to
1402‘ MD / 1385‘ TVD, WOB = 9.5K,
GPM = 450, PSI = 1120, RPM = 40, TQ
= 6K, F/O = 56%, ECD = 10.09 PPG,
P/U = 89K, S/O = 103K, RT = 94K,
AST= 2.96, ART = .96, ADT = 3.92, Total
bit hrs = 9.72, Total jars = 5.22.
Primarily clay and sand coming over the
shakers, minimal wood observations
947.0 1,402.0
1/27/2024
12:00
1/27/2024
16:00
4.00 SURFAC, DRILL DDRL P Drill 13½” Surface hole from 1402‘ MD
to 1689‘ MD / 1664‘ TVD, WOB = 9.5K,
GPM = 450, PSI = 1120, RPM = 40, TQ
= 6K, F/O = 56%, ECD = 10.09 PPG,
P/U = 89K, S/O = 103K, RT = 94K,
AST= 2.36, ART = .72, ADT = 3.08, Total
bit hrs = 12.8, Total jars = 8.3.
Primarily clay and sand coming over the
shakers. Pumped 30 bbls bit balling
sweep at 1,558' MD.
1,402.0 1,689.0
1/27/2024
16:00
1/27/2024
16:30
0.50 SURFAC, DRILL SVRG T Service rig.
SIMOPS: Gather equipment to change
out top drive wash pipe.
1,689.0 1,689.0
1/27/2024
16:30
1/27/2024
19:30
3.00 SURFAC, DRILL RGRP T Change out leaking wash pipe on top
drive. Circulating through cement line -
GPM 200. PSI 335, F/O 47%.
Reciprocate pipe every 15 minutes. P/U
99K, S/O 108K.
1,689.0 1,689.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 4/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/27/2024
19:30
1/27/2024
22:30
3.00 SURFAC, DRILL DDRL P Drill 13½” Surface hole from 1689‘ MD
to 1888‘ MD / 1729‘ TVD, WOB = 7K,
GPM = 500, PSI = 1008, RPM = 40, TQ
= 3K, F/O = 56%, ECD = 10.10 PPG,
P/U = 101K, S/O = 109K, RT = 110K.
Primarily clay and sand coming over the
shakers.
1,689.0 1,888.0
1/27/2024
22:30
1/27/2024
23:30
1.00 SURFAC, DRILL EQRP T Cutting box lines from Magtec cutting
box to ACB boxes froze. Rack back
stand in derrick. Circulate at reduced
rate while thawing lines and cleaning out
cutting box of froze cuttings. Added
another heater in work area to help out
with freezing conditions. RIH from 1790'
MD to 1885' MD.
1,888.0 1,790.0
1/27/2024
23:30
1/28/2024
00:00
0.50 SURFAC, DRILL DDRL P Drill 13½” Surface hole from 1888‘ MD
to 1923‘ MD / 1738‘ TVD, WOB = 6K,
GPM = 500, PSI = 1111, RPM = 40, TQ
= 3K, F/O = 56%, ECD = 10.03 PPG,
P/U = 101K, S/O = 109K, RT = 110K,
AST = 2, ART = .47, ADT = 2.47, Total
bit hrs = 15.22, Total jars = 10.54.
Primarily clay and sand coming over the
shakers.
1,888.0 1,923.0
1/28/2024
00:00
1/28/2024
07:15
7.25 SURFAC, DRILL DDRL P Drill 13½” Surface hole from 1,923‘ MD
to 2,347‘ MD / 2,204‘ TVD, WOB = 6K,
GPM = 500, PSI = 1290, RPM = 40, TQ
= 5K, F/O = 54%, ECD = 10.43 PPG,
P/U = 115K, S/O = 112K, RT = 114K,
AST = 3.35, ART = 1.31, ADT = 4.66,
Total bit hrs = 19.72, Total jars = 15.20.
Primarily clay coming over the shakers.
1,923.0 2,347.0
1/28/2024
07:15
1/28/2024
09:15
2.00 SURFAC, DRILL CLEN T Hole began unloading and partialy
blocked the flow line, this caused the
fluid level in the bell nipple to rise
enough to exit the drain to the cellar.
Shut down pumps and cleaned out
cellar. Cleared obstruction and staged
pumps up to GPM 550, PSI 1600 RPM,
40, TQ 6k.
2,347.0 2,347.0
1/28/2024
09:15
1/28/2024
12:00
2.75 SURFAC, DRILL DDRL P Drill 13½” Surface hole from 2,347‘ MD
to 2,575‘ MD / 2,360‘ TVD, WOB = 8K,
GPM = 600, PSI = 1830, RPM = 40, TQ
= 6K, F/O = 57%, ECD = 10.64 PPG,
P/U = 115K, S/O = 112K, RT = 114K,
AST = 2.22, ART = .48, ADT = 2.70,
Total bit hrs = 22.42, Total jars = 17.90.
Trace coal observed at the shakers,
observing minor clay patties.
2,347.0 2,575.0
1/28/2024
12:00
1/28/2024
16:15
4.25 SURFAC, DRILL DDRL P Drill 13½” Surface hole from 2,575‘ MD
to 2,900‘ MD / 2,504‘ TVD, WOB = 5K,
GPM = 700, PSI = 2250, RPM = 40, TQ
= 5K, F/O = 60%, ECD = 10.64 PPG,
P/U = 104K, S/O = 114K, RT = 104K,
AST = 2.22, ART = .48, ADT = 2.70,
Total bit hrs = 22.42, Total jars = 17.90.
Trace coal observed at the shakers,
seeing larger clay patties.
2,575.0 2,900.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 5/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/28/2024
16:15
1/28/2024
17:15
1.00 SURFAC, DRILL OTHR T Hole began unloading, -44°F
temperature resticting vac lines for
cuttings removal from cuttings tank.
Replace restricted line, lower volume in
cuttings box.
2,900.0 2,900.0
1/28/2024
17:15
1/28/2024
18:00
0.75 SURFAC, DRILL DDRL P Drill 13½” Surface hole from 2,929‘ MD
to 2,929‘ MD / 2,504‘ TVD, WOB = 5K,
GPM = 700, PSI = 2250, RPM = 40, TQ
= 5K, F/O = 60%, ECD = 10.64 PPG,
P/U = 104K, S/O = 114K, RT = 104K,
AST =.88 , ART =2.60 ., ADT = 25.90,
Total bit hrs = , Total jars =21.38. Take
final surveys and torque and drag
values.
Trace coal observed at the shakers,
seeing larger clay patties.
2,900.0 2,929.0
1/28/2024
18:00
1/28/2024
19:30
1.50 SURFAC, TRIPCAS CIRC P Circulate bottoms up 2x racking a stand
back after each bottoms up from 2929'
MD to 2743' MD. GPM 700, PSI 2225,
RPM 40, TQ 3k, F/O 60%, ECD 10.59
PPG, Pump 30 BBLS 9.8 PPG bit
balling sweep to surface. OWFF (well
static).
2,929.0 2,743.0
1/28/2024
19:30
1/29/2024
00:00
4.50 SURFAC, TRIPCAS BKRM P BROOH from 2743' MD to 2290' MD
with GPM 745', PSI 2350, RPM 60, F/O
63%, TQ 3k, ECD 10.59 PPG, ECD
11.00,PPG P/U 105, S/O 98K, RT 99K.
Pump 1x bottoms up per stand to 300'
below base permafrost.
2,743.0 2,290.0
1/29/2024
00:00
1/29/2024
01:00
1.00 SURFAC, TRIPCAS BKRM P Back Ream out of the hole from 2,290'
MD to 2,190' MD, 745 GPM, 2370 PSI,
60 RPM, 3k Tq, 62% F/O, 11.15 ECD.
Pulling at 300 ft/hr began seeing
increasing ECD trends and hole began
to unload. Slow to 50 ft/hr.
2,290.0 2,190.0
1/29/2024
01:00
1/29/2024
03:00
2.00 SURFAC, TRIPCAS CLEN T Observed indications of flow line
packing off. Attempt to work jets in flow
line to clear the restriction. Run stand in
the hole. Shut down pumps and clear
flow line from inspection hatches. Stage
up pumps to 650 GPM,1850 PSI.
2,190.0 2,271.0
1/29/2024
03:00
1/29/2024
12:00
9.00 SURFAC, TRIPCAS BKRM P Backream out of the hole from 2,271'
MD to 650' MD, 400 GPM, 725 PSI, 30
RPM, 2k Tq, 51% F/O, 10.6 ECD.
At 1,860' MD, slowed pump rate and
rotation from 700gpm to 400gpm and 60
rpm to 30 rpm respectively to low
energy ream the permafrost.
Hole unloaded combination of clay,
sand, and gravel at 1,450', 1,280', 700'.
Minor drift wood observations at the
shakers.
2,271.0 650.0
1/29/2024
12:00
1/29/2024
15:00
3.00 SURFAC, TRIPCAS BKRM P Backream out of the hole from 650' MD
to 185' MD, 400 GPM, 500 PSI, 30
RPM, 2k Tq, 51% F/O, 10.5 ECD.
Hole unloaded combination of clay,
sand, and gravel at 450', 370', and 277'
MD.
Pumped 30bbls bit balling sweep on the
last stand to scour the BHA.
650.0 185.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 6/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/29/2024
15:00
1/29/2024
15:30
0.50 SURFAC, TRIPCAS CLEN P Blow down top drive. Prep rig floor for
BHA lay down. Hold pre-job for laying
down BHA.
185.0 185.0
1/29/2024
15:30
1/29/2024
19:00
3.50 SURFAC, TRIPCAS BHAH P Lay down 13-1/2" BHA and MWD non-
mag stabilizers and mud motor.
185.0 0.0
1/29/2024
19:00
1/29/2024
20:30
1.50 SURFAC, TRIPCAS CLEN P Clean and clear surface BHA tools and
handling equipment from rig floor.
0.0 0.0
1/29/2024
20:30
1/29/2024
21:30
1.00 SURFAC, CASING RURD P Mobilize Doyon casing equipment and
tools to rig floor. Rig up 10-3/4" casing
handling equipment and Volant.
0.0 0.0
1/29/2024
21:30
1/30/2024
00:00
2.50 SURFAC, CASING PUTB P PJSM. Pick up and run 10-3/4" 45.5# L-
80 Hyd 563 casing from surface to 490'
MD. P/U 63k, S/O 63k. Make up torque
16,200 ft-lbs. Double bump each joint.
Make up shoe track. Baker loc 1-4
joints. Pump through floats (Good).
Monitor displacement via pit #1 and pill
pit#2, filling each joint on the fly. Top off
every 10 joints.
0.0 490.0
1/30/2024
00:00
1/30/2024
03:15
3.25 SURFAC, CASING PUTB P Continue running 10-3/4", 45.5#, L80,
Hyd563 surface casing in the hole with
Volant CRT from 490' to 1,263' MD. 90K
Up Wt, 87k Dn Wt. Fill pipe on the fly,
top off every 10 joints. Torque 10-3/4"
casing to 16,200 ft/lbs (double bumped
connections). Monitor displacement on
pit #1 and #2.
Observed obstruction at 1,263' MD.
490.0 1,263.0
1/30/2024
03:15
1/30/2024
09:00
5.75 SURFAC, CASING PUTB T Work pipe past obstruction from 1,263'
MD to 1,275' MD. Stage up pump rate to
5.5 bbls/min, 120 psi. Wash down and
set 10-20K. Rotated pipe 1/4 turns and
continue to work pipe. Begin rotating at
5 rpm, 4-14k tq. Slack off and work pipe
through obstruction with 10-25k down.
Mix and pump 20bbls LowVis, 5PPB
SAP, 10 Vis cups of soap, 1 drum of
drilzone.
Observed gravel, clay, wood at shakers.
1,263.0 1,275.0
1/30/2024
09:00
1/30/2024
11:00
2.00 SURFAC, CASING PUTB P Wash / ream 10-3/4", 45.5#, L80,
Hyd563 surface casing in the hole with
Volant CRT from 1,275' to 1,462' MD.
5.5 bbls/min, 130 PSI, 5 RPM, 9K tq.
90k Dn Wt. Torque connections to
16,200 ft/lbs (double bump
connections).
Fair amount of sand continuously
coming across the shakers.
1,275.0 1,462.0
1/30/2024
11:00
1/30/2024
12:00
1.00 SURFAC, CASING PUTB P Continue running 10-3/4", 45.5#, L80,
Hyd563 surface casing in the hole with
Volant CRT from 1,462' to 1,660' MD.
115K Up Wt, 95k Dn Wt. Fill pipe on the
fly, top off every 10 joints. Torque 10-
3/4" casing to 16,200 ft/lbs (double
bumped connections). Monitor
displacement on pit #1 and #2.
Observed excessive drag at 1,660' MD
1,462.0 1,660.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 7/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/30/2024
12:00
1/30/2024
17:00
5.00 SURFAC, CASING PUTB P Wash / ream 10-3/4", 45.5#, L80,
Hyd563 surface casing in the hole with
Volant CRT from 1,660' to 1,795' MD.
5.5 bbls/min, 160 PSI, 5 RPM, 9-16K tq.
98k Dn Wt. Torque connections to
16,200 ft/lbs (double bump
connections).
General observation throughout the
interval was tight hole or working past
rubble in the well bore.
Fair amount of sand continuously
coming across the shakers. Some clay,
gravel, and wood observations as well.
Pumped 10 bbls LowVis, 5PPB SAP, 10
Vis cups of soap, 1 drum of drilzone at
1,705' MD.
1,660.0 1,795.0
1/30/2024
17:00
1/30/2024
18:00
1.00 SURFAC, CASING CIRC P Pumped 20 bbls LowVis, 5PPB SAP, 10
Vis cups of soap, 1 drum of drilzone.
Stage up pump rate to 8 bbls/min and
circulate out of the hole while rotating
and reciprocating 1 full joint. 190 PSI, 7
rpm, 9-16K tq, 101K Rot Wt.
1,795.0 1,840.0
1/30/2024
18:00
1/30/2024
21:00
3.00 SURFAC, CASING PUTB P Continue running 10-3/4", 45.5#, L80,
Hyd563 surface casing in the hole with
Volant CRT from 1840' to 2515' MD.
107K Up Wt, 97k Dn Wt. Fill pipe on the
fly, top off every 10 joints. Torque 10-
3/4" casing to 16,200 ft/lbs (double
bumped connections). Monitor
displacement on pit #1 and #2.
1,840.0 2,515.0
1/30/2024
21:00
1/30/2024
21:15
0.25 SURFAC, CASING CIRC P Circulate and reciprocate bottoms up
from 2515' MD to 2490' MD 6.5 GPM
BPM, 230 PSI, 36% F/O S/O 107k, P/U
130k.
2,515.0 2,490.0
1/30/2024
21:15
1/30/2024
22:45
1.50 SURFAC, CASING PUTB P Continue running 10-3/4", 45.5#, L80,
Hyd563 surface casing in the hole with
Volant CRT from 2515' MD to 2877'
MD. 107K Up Wt, 97k Dn Wt. Fill pipe
on the fly, top off every 10 joints. Torque
10-3/4" casing to 16,200 ft/lbs (double
bumped connections). Monitor
displacement on pit #1 and #2.
2,515.0 2,877.0
1/30/2024
22:45
1/31/2024
00:00
1.25 SURFAC, CASING HOSO P Make up Cameron surface hanger.
Drain stack land out hanger on load
shoulder @ 2921' MD. S/O 107k.
2,877.0 2,921.0
1/31/2024
00:00
1/31/2024
03:00
3.00 SURFAC, CEMENT CIRC P Circulate bottoms-up and condition mud.
Stage pumps up to 5-8 bpm while
reciprocating casing landing out every
3x times. 220/300 PSI, F/O 36%
2,921.0 2,921.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 8/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/31/2024
03:00
1/31/2024
06:30
3.50 SURFAC, CEMENT CMNT P Pump 5 bbls fresh water. Test lines to
3500 psi. Pump 60 bbls of spacer w/
poly flake and red dye @ 3.8 BPM, PSI
= 230, F/O - 5%. Load bottom plug.
(Cmt Wet @ 03:30hrs). Batch-up and
pump 472 BBLS 10.7 PPG ArticCem
lead cement with BMII - pump rate 6
BPM, 298 PSI, 9% F/O. HES batch tail,
(tail wet @ 05:20). Pump 56.72 BBLS of
15.8ppg tail cement @ 3.88 BPM, 551
PSI, 6% F/O. Drop top plug. Chase plug
with 20 bbls of water from HES. Line up
rig pumps. Displace cement at 6 BPM,
ICP - 552, Reduce rate @ 2000 stks to
4 BPM, FCP - 585. Bump plug @ 2508
strokes (261.4 bbls). CIP @ 0630 hrs.
Pressure up to 1114 psi and hold for 5
min. Bleed off and check floats (good).
Observe 252 bbls of 10.7 cement
returned to surface. 0 losses during
cement job.
2,921.0 2,921.0
1/31/2024
06:30
1/31/2024
07:30
1.00 SURFAC, WHDBOP RURD P Remove cement lines from Volant CRT
tools. Blown down mud lines. Flush
riser, cellar box, flow line, knife valves
and drag chain with black water. Service
all 1502 equipment. Clean demco
valves on cement manifold.
0.0 0.0
1/31/2024
07:30
1/31/2024
08:00
0.50 SURFAC, WHDBOP RURD P Break out Volant CRT tool. Back out
landing joint and pull from hanger. Clean
and lay down to pipe shed.
0.0 0.0
1/31/2024
08:00
1/31/2024
09:30
1.50 SURFAC, WHDBOP RURD P Demobilize casing tools and equipment
from rig floor. Offload mud pits and rock
washer to trucks.
0.0 0.0
1/31/2024
09:30
1/31/2024
10:15
0.75 SURFAC, WHDBOP CLEN P Pull rotary table cover and clean out
mud/cement from flow box and drip
pans.
0.0 0.0
1/31/2024
10:15
1/31/2024
12:00
1.75 SURFAC, WHDBOP NUND P Nipple down 20" riser and well head
spool. Remove mousehole, remove
spool riser from starter head.
0.0 0.0
1/31/2024
12:00
1/31/2024
15:00
3.00 SURFAC, WHDBOP NUND P Nipple down Cameron surface starter
head. Remove conductor valves and
caps. Install Cameron well head and
test well head to 5000 PSI for 10
Minutes (CPAI Rep witnessed).
Top of cement measured 26 inches from
hanger flutes.
0.0 0.0
1/31/2024
15:00
1/31/2024
18:00
3.00 SURFAC, WHDBOP NUND P Nipple up spacer flange/adapter spool to
well head to receive BOPE. Install,and
nipple up BOPE stack on well head.
SIMOPS clean pit #1-7 and Pill pit #1-2,
Dress shakers for Intermediate hole
section.
0.0 0.0
1/31/2024
18:00
2/1/2024
00:00
6.00 SURFAC, WHDBOP NUND P Continue nippling-up BOPE stack.
Orient annular and make up to upper
rams.
0.0 0.0
2/1/2024
00:00
2/1/2024
06:00
6.00 SURFAC, WHDBOP NUND P Rig down potato masher / pup jt. Install
RCD head with orbit valve and MPD 2''
injection hardline. M/U kill hose. Install
annular and single gate hydraulic hoses.
Add flanges and block valves on OA and
IA. Pressure up Koomey. Grease HCRs,
manual valves on stack, and choke
manifold. Install mousehole.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 9/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/1/2024
06:00
2/1/2024
12:00
6.00 SURFAC, WHDBOP MPDA P Fill stack with freshwater. Install RCD
test plug as per Beyond Rep. Attempt to
test RCD head against blind (failed).
Tighten RCD to annular flange and
retest (5 min low 250psi, 5 min high
1250psi). Pulled RCD test plug. Pulled
drip riser. Install RCD riser, riser from
RCD to rig floor and air boot. Mobilize
potato masher to rig floor to service
break connection. Lay back down and
demob. Make up 2-5" FOSV dart valve.
Make up test sub to top drive and prep
for pressure test.
0.0 0.0
2/1/2024
12:00
2/1/2024
14:00
2.00 SURFAC, WHDBOP NUND P Cycle annular element 8x to purge air
and get a seal on test joint. Attempt shell
test with choke, kill lines and lines at
Otego clamp in flow line room - well
head bull plugs leaking. Tighten bull
plugs and retest - shell test (good).
0.0 0.0
2/1/2024
14:00
2/1/2024
21:00
7.00 SURFAC, WHDBOP BOPE P Test bope all test to 250 PSI low
5,000PSI high for 5 charted minutes
with exception of manual operated &
super choke tested to 250 PSI low &
2,000 PSI for 5 charted minutes, with 7
5/8" test joint test annular, with 7 5/8"
test joint test upper pipe rams test choke
valves 1-15, manual operated & super
choke, choke & kill manuals & HCR's, 4"
valve on kill line, 5" FOSV, 5" dart valve
dart ser#-1883428 FOSV #1 ser#-
1935270 FOSV #2 ser#-202660 Test
upper & lower IBOP; blind/ shear rams;
swap test joint to 5'' test lower / upper
rams, annular, perform Koomey
drawdown, ACC = 3,000 PSI. Manifold.
= 1,500 PSI. ACC = 1,500 PSI after all
functions on bottles, 9 seconds for 200
PSI. build with 2 electric pumps, 116
seconds to build full system pressure
with 2 electric & 2 air pumps, closing
times Annular = 18 seconds. Upper pipe
rams = 8 seconds. Blind / shears = 8
seconds. Lower pipe rams = 7 seconds
Choke HCR = 2 seconds. Kill HCR = 2
seconds; test PVT gain/loss and flow
out alarms, test LEL and H2S alarms;
AOGCC Rep Sully Sullivan waived
witness @ 07:05 hrs on 1/30/24
0.0 0.0
2/1/2024
21:00
2/1/2024
22:30
1.50 SURFAC, WHDBOP RURD P Rig down testing equipment. Blow down
lines. Remove test plug. Install wear ring
as per Cameron, ID = 9.8'', OD = 10.8'',
Length = 2.9'.
0.0 0.0
2/1/2024
22:30
2/1/2024
23:30
1.00 SURFAC, WHDBOP CLEN P Clean and clear rig floor of testing
equipment. Mobilize Intermediate BHA
tools to rig floor. Rig up handling
equipment.
0.0 0.0
2/1/2024
23:30
2/2/2024
00:00
0.50 SURFAC, DRILLOUT BHAH P PJSM for PU 9-7/8'' Intermediate BHA,
Pickup and makeup Intermediate hole
section BHA.
0.0 0.0
2/2/2024
00:00
2/2/2024
01:45
1.75 SURFAC, DRILLOUT BHAH P Continue picking up 9-7/8" intermediate
BHA #2 per SLB DD.
SIMOPS: Process 7-5/8" casing in the
pipe shed. Gather equipment needed for
upcoming casing test and shoe test.
0.0 144.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 10/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/2/2024
01:45
2/2/2024
03:45
2.00 SURFAC, DRILLOUT TRIP P Trip in the hole with BHA #2 on 5" drill
pipe from 144' to 2,786' MD. P/U 115k,
S/O 104k.
144.0 2,786.0
2/2/2024
03:45
2/2/2024
04:30
0.75 SURFAC, DRILLOUT CIRC P Fill drill pipe, circulate and shallow hole
test MWD tools. GPM 550, PSI 1240
F/O 70%.
2,786.0 2,786.0
2/2/2024
04:30
2/2/2024
05:30
1.00 SURFAC, DRILLOUT RURD P Rig up to pressure test casing, circulate
through lines and purge air out of the
system.
2,786.0 2,786.0
2/2/2024
05:30
2/2/2024
06:15
0.75 SURFAC, DRILLOUT PRTS P Rig up and pressure test 10-3/4" surface
casing to 3000 PSI for 30 minutes (good
test).
2,786.0 2,786.0
2/2/2024
06:15
2/2/2024
07:00
0.75 SURFAC, DRILLOUT RURD P Rig down testing equipment. Blow down
lines.
2,786.0 2,786.0
2/2/2024
07:00
2/2/2024
07:30
0.50 SURFAC, DRILLOUT WASH P Wash down at GPM 200, PSI 200, and
tag top of cement at 2,829' MD. S/O
106k.
2,786.0 2,829.0
2/2/2024
07:30
2/2/2024
11:15
3.75 SURFAC, DRILLOUT DRLG P Drill cement from 2,829' and tag float
collar on depth at 2,834' MD. Drill plugs
and float collar with WOB 5-15, RPM 50
-60,TQ 3-10k, GPM 400-700, PSI 690 -
2120 psi.
Drill cement with WOB 2-14k, RPM 80,
TQ 4-8k, GPM 750, PSI 2100.
Tag shoe on depth at 2,921' MD. Drill
out shoe with WOB 3-5k, RPM 80, TQ
4-8k, GPM 750, PSI 2100.
Worked through float collar 2 times,
work through shoe 3 times.
SIMOPS: Rack back 10 stands of 4"
HWDP in the derrick.
2,829.0 2,929.0
2/2/2024
11:15
2/2/2024
11:30
0.25 SURFAC, DRILLOUT DDRL P Drill 9Ǭ" Intermediate hole from 2929'
MD to 2949' MD / 2573' TVD, WOB=3k,
GPM=750, PSI=2080, RPM=100,
TQ=6k, F/O=54%, P/U=124k,
S/O=109k, RT=115k.
2,929.0 2,949.0
2/2/2024
11:30
2/2/2024
12:15
0.75 SURFAC, DRILLOUT CIRC P Circulate and condition mud for
FIT/LOT. GPM 750, PSI 2000, RPM
100, TQ 3-8 k. RT 115k.
Rack back stand and blow down the top
drive, install headpin and cement hose.
2,949.0 2,872.0
2/2/2024
12:15
2/2/2024
12:45
0.50 SURFAC, DRILLOUT LOT P Perform surface casing shoe test.
Pressure up down drill string and
annulus at 6 strokes minute and
observed leak off at 600 PSI (14.2 ppg
EMW). Shut in and monitor pressures
for 10 minutes. Pressure declined and
stabilized at 320 PSI. Pump 2.3bbls,
bleed back 2.1 bbls, (max pressure =
860 PSI).
2,872.0 2,872.0
2/2/2024
12:45
2/2/2024
18:00
5.25 INTRM1, DRILL DDRL P Drill 9Ǭ" Intermediate hole from 2949'
MD to 3410' MD / 2769' TVD,
WOB=4.5k, GPM=750, PSI=1480,
RPM=150, TQ=6.1k, F/O=55%,
ECD=10.42, P/U=121k, S/O=116k,
RT=115k. ADT .4.09, Bit hrs 4.09, Jars
25.47.
Displace to 9.0 ppg FWP on the fly at
2,968' MD.
2,949.0 3,410.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 11/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/2/2024
18:00
2/3/2024
00:00
6.00 INTRM1, DRILL DDRL P Drill 9Ǭ" Intermediate hole from 3410'
MD to 4037' MD / 3160' TVD,
WOB=6.7k, GPM=750, PSI=1560,
RPM=150, TQ=5.7k, F/O=56%,
ECD=10.61, P/U=121k, S/O=116k,
RT=115k. ADT .3.99, Bit hrs 8.08, Jars
29.46 Gas 130.
Pumping high sweep every 4 stands.
3,410.0 4,037.0
2/3/2024
00:00
2/3/2024
06:00
6.00 INTRM1, DRILL DDRL P Drill 9Ǭ" Intermediate hole from 4037'
MD to 4677' MD / 3493' TVD, WOB=8k,
GPM=750, PSI=1828, RPM=150,
TQ=5.2k, F/O=56%, ECD=11.03,
P/U=143k, S/O=127k, RT=130k.
ADT .4.15, Bit hrs 12.23, Jars 33.61
Gas 124.
Pumping HiVis sweep every 4 stands.
4,037.0 4,677.0
2/3/2024
06:00
2/3/2024
12:00
6.00 INTRM1, DRILL DDRL P Drill 9Ǭ" Intermediate hole from 4677'
MD to 5376' MD / 4005' TVD,
WOB=11k, GPM=770, PSI=1944,
RPM=155, TQ=7.2k, F/O=56%,
ECD=11.32, P/U=136k, S/O=130k,
RT=128k. ADT 4.83, Bit hrs 17.06, Jars
38.44 Gas 148.
Pumping 12.5 PPG weighted sweep
every 4 stands. Sweeps bringing back
large clay patties and significant
increase in fine materials.
4,677.0 5,376.0
2/3/2024
12:00
2/3/2024
18:00
6.00 INTRM1, DRILL DDRL P Drill 9Ǭ" Intermediate hole from 5376'
MD to 6115' MD / 4384' TVD, WOB=7k,
GPM=770, PSI=2090, RPM=155,
TQ=7.2k, F/O=55%, ECD=11.17,
P/U=149k, S/O=135k, RT=138k. ADT
4.34, Bit hrs 21.40, Jars 42.78, Gas 130.
Pumping 12.5 PPG weighted sweep
every 4 stands. Sweeps bringing back
large clay patties and significant
increase in fine materials.
Observed ECD relief after entering the
top of Coyote. Staged up ROP to 250
FPH.
5,376.0 6,115.0
2/3/2024
18:00
2/4/2024
00:00
6.00 INTRM1, DRILL DDRL P Drill 9Ǭ" Intermediate hole from 6115'
MD to 6753 ' MD / 4810' TVD, WOB =
12k, GPM=770, PSI=2102, RPM=155,
TQ=7.2k, F/O=52%, ECD=11.28,
P/U=154k, S/O=144k, RT=146k. ADT
4.32, Bit hrs 25.72, Jars 47.10, Gas 130.
Pumping 12.5 PPG weighted sweep
every 4 stands. Formation change at
6332' MD
6,115.0 6,753.0
2/4/2024
00:00
2/4/2024
06:00
6.00 INTRM1, DRILL DDRL P Drill 9Ǭ" Intermediate hole from 6753'
MD to TD @ 7470 ' MD / 5149' TVD,
WOB=9k, GPM=770, PSI=2192,
RPM=155, TQ=8k, F/O=32%,
ECD=10.91, P/U=155k, S/O=154k,
RT=156k. ADT 4.85, Bit hrs 30.57, Jars
51.97, Gas 261. Pumping 12.5 ppg
weighted sweep every 4 stands.
Formation change at 6332' MD. Weight
up system to 9.5 ppg.
6,753.0 7,470.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 12/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/4/2024
06:00
2/4/2024
12:30
6.50 INTRM1, TRIPCAS BKRM P BROOH racking a stand back after each
bottoms up for 2 stands from 7470' MD
to 6717' MD, GPM=770, PSI=2102,
RPM=155, TQ=7.2k, F/O=52%,
ECD=11.28, P/U=154k, S/O=136k,
RT=137k. Finish weighting mud system
to 9.5 ppg and increasing lube to 3%.
7,470.0 6,717.0
2/4/2024
12:30
2/4/2024
18:00
5.50 INTRM1, TRIPCAS BKRM P BROOH from 6717' MD to 4960' MD,
GPM=770, PSI=1856, RPM=155,
TQ=3k, F/O=52%, ECD=11.28,
P/U=131k, S/O=121k, RT=130k.
6,717.0 4,960.0
2/4/2024
18:00
2/5/2024
00:00
6.00 INTRM1, TRIPCAS BKRM P BROOH from 4960' MD to 3407' MD,
GPM=770, PSI=1775, RPM=160,
TQ=3k, F/O=52%, ECD=11.28,
P/U=115k, S/O=112k, RT=121k.
4,960.0 3,407.0
2/5/2024
00:00
2/5/2024
02:00
2.00 INTRM1, TRIPCAS BKRM P BROOH from 3,407' MD to 2,872' MD,
GPM=770, PSI=1700, RPM=160,
TQ=3k, F/O=52%, ECD=11PPG,
P/U=108k, S/O=102k, RT=104k.
Cuttings @ shakers are steady no
indication of hole unloading.
3,407.0 2,872.0
2/5/2024
02:00
2/5/2024
02:30
0.50 INTRM1, TRIPCAS CIRC P Circulate bottoms up, GPM=770,
PSI=1700, RPM=80, TQ=3k, F/O=52%,
ECD=11.28 PPG, P/U=108k, S/O=102k,
RT=104k.
Indications of hole still loaded with
cuttings.
2,872.0 2,872.0
2/5/2024
02:30
2/5/2024
06:00
3.50 INTRM1, TRIPCAS BKRM P Back Ream out of the hole from 2,872'
MD to 1,470' MD, GPM=770, PSI=1600,
RPM=80, TQ=5k, F/O=52%, ECD=10.1
PPG, P/U=97k, S/O=102k, RT=95k.
Pumped nut plug sweep at 1,775' MD,
observed significant increase in clay
patties coming over the shakers. Hole
began unloading again at 1,550' MD
Pumped nut plug sweep at 1,500' MD.
Cuttings returns diminished.
2,872.0 1,470.0
2/5/2024
06:00
2/5/2024
06:45
0.75 INTRM1, TRIPCAS OWFF P Observe well for flow (static). Blow down
top drive.
1,470.0 1,470.0
2/5/2024
06:45
2/5/2024
08:45
2.00 INTRM1, TRIPCAS TRIP P Pre-job safety meeting. Trip out of the
hole laying down singles in the pipe
shed from1,470' MD to 893' MD
1,470.0 893.0
2/5/2024
08:45
2/5/2024
11:45
3.00 INTRM1, TRIPCAS BHAH P Pre-job safety meeting. Lay down
HWDP, and SLB BHA components from
893' MD to surface as per SLB DD,
MWD.
893.0 0.0
2/5/2024
11:45
2/5/2024
14:00
2.25 INTRM1, CASING WWWH P Pull wearbushing per Cameron Rep.
Wash BOP stack, rig down and blow
down top drive.
0.0 0.0
2/5/2024
14:00
2/5/2024
15:30
1.50 INTRM1, CASING CLEN P Clear rig floor of BHA components and
clean the rig floor.
Simops, remove BHA tools from the
pipe shed.
0.0 0.0
2/5/2024
15:30
2/5/2024
17:30
2.00 INTRM1, CASING RURD P Rig up to run 7-5/8" Intermediate casing
via Volant CRT, Bails and extensions
and handling tools.
0.0 0.0
2/5/2024
17:30
2/5/2024
18:00
0.50 INTRM1, CASING PUTB P Pickup and make 7 5/8" shoe track
29.7# L-80, Hyd563 baker loc each joint.
from surface to 124' MD
0.0 124.0
2/5/2024
18:00
2/5/2024
18:30
0.50 INTRM1, CASING CIRC P Fill 7 5/8" shoe track and check floats.
Floats (good) Witness by COP Rep.
124.0 124.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 13/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/5/2024
18:30
2/5/2024
20:00
1.50 INTRM1, CASING PUTB P X/O to 7 5/8" 33.7# P-110 Hyd563
casing. Torque12100 Ft/lbs, running 7
5/8" x 9 3/8" centralizers on each joint
as per tally. Monitoring displacement
via pit #1 and pill pit #2 as per tally from
124' MD to 837' MD.
124.0 837.0
2/5/2024
20:00
2/6/2024
00:00
4.00 INTRM1, CASING PUTB P X/O to 7 5/8" 29.7# L-80 Hyd563 casing.
Torque 10300 Ft/lbs running 7 5/8" x 9
3/8" Arsenal centralizers on each joint
as per tally. Monitoring displacement
via pit #1 and pill pit #2 as per tally from
837' MD to 2462' MD.
837.0 2,462.0
2/6/2024
00:00
2/6/2024
06:15
6.25 INTRM1, CASING PUTB P Continue to run 7-5/8" 29.7# L-80
Hyd563 casing. Torque 10300 Ft/lbs
running 7 5/8" x 9 3/8" Arsenal
centralizers on each joint as per tally.
Monitoring displacement via pit #1 and
pill pit #2 as per tally from 837' MD to
2462' MD.Torque connections to10,300
Ft/lbs. Monitoring displacement via pit
#1 and pill pit #2 as per tally from 2,462
MD to 5,332' MD.
2,462.0 5,332.0
2/6/2024
06:15
2/6/2024
07:00
0.75 INTRM1, CASING CIRC P Stage up pumps to 6 bbls/min and
circulate 1 bottoms up.
3 bbls/min = 160 psi
5,332.0 5,372.0
2/6/2024
07:00
2/6/2024
07:30
0.50 INTRM1, CASING PUTB P Investigate a hook load discrepancy in
casing run and circulating pressures
lower than expected. Verify rig's and
slb's hookload sensors. Run 5 joints of
7-5/8" 29.7# L-80 Hyd563 casing from
5,372' to 5,537' MD with out filling pipe
to confirm floats in the string. Observed
fluid level inside pipe at the rotary table.
5,372.0 5,537.0
2/6/2024
07:30
2/6/2024
10:00
2.50 INTRM1, CASING CIRC T Circulate and reciprocate from 5,537'
MD to 5,533' MD. 2 bbls/min, 100
psi,126k Up Wt, 121k Dn Wt.
Discuss path forward with town,
expedite equipment to the rig floor and
rig up to lay down casing.
SIMOPS - Prejob safety meeting with all
parties on L/D csg.
5,537.0 5,537.0
2/6/2024
10:00
2/6/2024
22:30
12.50 INTRM1, CASING PULD T POOH L/D 7-5/8" Csg from 5,573' MD.
P/U WT - 118K. Monitor disp via pit #1.
L/D total of 101 jts. Observed casing
pin disconnected from collar.
Leaving 34 jts in the hole (1410.77' w/
shoe track). Recovered 26 ea Arsenal
composite centralizers. Leaving 1 free
above the fish (off jt #35) and 36 ea on
the fish in the hole.
5,537.0 0.0
2/6/2024
22:30
2/7/2024
00:00
1.50 INTRM1, CASING RURD T R/D Doyon Csg handling equipment.
SIMOPS - Clear and clean rig floor.
0.0 0.0
2/7/2024
00:00
2/7/2024
05:00
5.00 INTRM1, CASING RURD T Continue to rig down casing equipment
and clean rig floor. Load rig floor of BOT
fishing tools. Load and process 5" drill
pipe in the pipe shed.
0.0 0.0
2/7/2024
05:00
2/7/2024
05:15
0.25 INTRM1, CASING RURD T Install 10" ID wear bushing. 0.0 0.0
2/7/2024
05:15
2/7/2024
05:30
0.25 INTRM1, CASING SFTY T PJSM with rig crew on make up of
Baker Fishing BHA.
0.0 0.0
2/7/2024
05:30
2/7/2024
07:30
2.00 INTRM1, CASING BHAH T Make up Baker Spear BHA as per Baker
Rep to 235' MD. Monitor disp via pit #1.
0.0 235.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 14/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/7/2024
07:30
2/7/2024
13:00
5.50 INTRM1, CASING PULD T RIH with Baker Spear BHA from 235'
MD to 2,912' MD picking up 5" DP.
Monitor disp via Pit #1. Up Wt - 98K,
S/O WT - 100K.
235.0 2,912.0
2/7/2024
13:00
2/7/2024
13:30
0.50 INTRM1, CASING CIRC T Circ bottoms up @ 10-3/4" surface shoe
(2,912' MD). Stage pumps up to 338
gpm, ICP - 127, FCP - 179, 17% F/O,
Total stks pumped - 2720 (274 bbls).
2,912.0 2,912.0
2/7/2024
13:30
2/7/2024
18:45
5.25 INTRM1, CASING PULD T RIH with Baker Spear BHA from 2,912'
MD to top of fish @ 6,060' MD picking
up 5" DP. Monitor disp via Pit #1. Up
Wt - 138K, S/O WT - 131K.
2,912.0 6,060.0
2/7/2024
18:45
2/7/2024
20:15
1.50 INTRM1, CASING FISH T Attempt to engage fish slacking off to
nogo @ 6,072' MD observing taking
weight as expected with fish on bottom
but no indication of engaging fish. Set
down 15K-23K (3x). Kelly up. Engage
mud pump @ 1.5 bpm, 156 psi and
slack off. Observe psi spikes @ 6,063'
MD indicating packoff entering the fish.
Continue to slack off to nogo at 6,072'
MD, kill mud pump. Apply 1 rot to the
left. Pick up to 6,061' MD and observe
poor indication of fish was engaged w/
140K pick up wt. Stage pump up to 3
bpm, 152 psi. Kill pump and slack off.
Observe slight bobble again at 6,063'
MD. Continue to slack off to nogo at
6,072' MD. Pick up to 6,057' MD
observing same 140K hook load. Pump
at 1.5 bpm, 63 gpm, 164 psi and slack
off to nogo @ 6,072' MD observing
pump fluctuations indicating packoff
entered the fish. Set dn 30K. Observe
psi spike to 450. Reduce rate to .5 bpm,
244 psi and pick up slowly to 6,056' MD
observing pressure drop to 110 psi.
Increase pump to 1.5 bpm, 166 psi, 12%
f/o. Observe hook load at 136K. Kill
mud pump and slack off to nogo setting
dn 20K. Re-engage mud pump and
observe pressure spike to 319 psi. Pick
up to regain circ up to 6,054' MD.
Decision made to POOH 3 stds and circ
B/U.
6,060.0 6,072.0
2/7/2024
20:15
2/7/2024
21:30
1.25 INTRM1, CASING CIRC T Circ B/U while POOH from 6,072' MD to
5,994' MD. Stage pumps up to 6 bpm,
254 gpm, ICP - 182, FCP - 254, 26%
F/O. Up Wt - 136K. Total stks pumped
- 4180 (421 bbls).
6,072.0 5,994.0
2/7/2024
21:30
2/7/2024
22:00
0.50 INTRM1, CASING TRIP T Cont to POOH from 5,994' MD to 5,806'
MD. Monitor disp via pit #1. Up Wt -
135K.
5,994.0 5,806.0
2/7/2024
22:00
2/7/2024
22:30
0.50 INTRM1, CASING TRIP T RIH from 5,806' MD to nogo @ 6,072'
MD. S/O Wt - 131K. Monitor disp via
pit #1.
5,806.0 6,072.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 15/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/7/2024
22:30
2/7/2024
23:00
0.50 INTRM1, CASING FISH T Set 20K dn at nogo. Engage mud pump
and observe pressure spike of 263 psi
with no returns. Pick up 3' and regain
returns. Apply additional 1 wraps to the
left. Pick up and observe hook load at
136K. Slack back off, apply 1.5
additional turns to the left and observe
hook load increase to 195K indicating
successfully engagement of the fish.
Engage mud pump @ 1.5 bpm and
observe pump fluctuations from 189 psi
to max of 476 psi indicating possibly
debris on top of floats in the fish. Kill
mud pump and continue to POOH up to
5,994' MD, observing hook load of
170K.
6,072.0 5,994.0
2/7/2024
23:00
2/7/2024
23:45
0.75 INTRM1, CASING TRIP T POOH from 5,994' MD to 5,617' MD.
Monitor disp via pit #1. Up Wt - 170K.
5,994.0 5,617.0
2/7/2024
23:45
2/8/2024
00:00
0.25 INTRM1, CASING TRIP T Drop Baker dart to open circ sub. Pump
dn at 2 bpm, 204 psi, 11% f/o. Dart on
seat at 161 stks. Pressure up to 1174
and successfully open circ sub. Confirm
w/ 3 bpm, 127 gpm, 122 psi, 17% f/o.
5,617.0 5,617.0
2/8/2024
00:00
2/8/2024
06:00
6.00 INTRM1, CASING TRIP T Trip out of the hole with fish from 5,617'
to 2,898' MD (top of fish). 125k Up Wt.
Slow pull speed to 8 ft/min to pull into
the surface casing shoe. Observed 2k
overpull entering the shoe.
Pump 20bbls 11ppg dry job. Monitor
hole fill on pit#1 and pill pit #2.
5,617.0 2,898.0
2/8/2024
06:00
2/8/2024
11:30
5.50 INTRM1, CASING TRIP T Continue trip out of the hole with fish
from 2,898' MD to surface (top of fish).
89k Up Wt. No overpull observed,
monitor hole fill on pit #1 and pill pit #2.
2,898.0 0.0
2/8/2024
11:30
2/8/2024
12:30
1.00 INTRM1, CASING BHAH T Release from fish with 2 turns to the
right, lay down Baker fishing assembly.
Did not observe 7-5/8" x 9-1/4" Arsenal
centralizer with the fish. Noted damage
to the swab cup on the fishing assembly.
The box of the 7-5/8" casing was intact
but showed signs of galled threads in
the top ~ 2/3 of the box.
0.0 0.0
2/8/2024
12:30
2/8/2024
14:30
2.00 INTRM1, CASING RURD T Clear and clean the rig floor of fishing
equipment. Rig up 7-5/8" handling
equipment and prepare rig floor to lay
down 7-5/8" casing. Hold pre-job with all
parties.
0.0 1,407.0
2/8/2024
14:30
2/8/2024
21:00
6.50 INTRM1, CASING PULL T Pull and lay down 7-5/8" casing fish
from 1,407' MD to 166' MD. Monitor
hole fill on pit #1 and pill pit #2.
Monitored make up mark on
connections (all good).
Average break out torque of 29.7#, L80,
Hyd563 was 8,200 ft/lbs
Average break out torque of 33.7#,
P110S, Hyd563 was 9000 ft/lbs
1,407.0 166.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 16/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/8/2024
21:00
2/8/2024
23:00
2.00 INTRM1, CASING PULL T Pull and lay down 7-5/8" casing shoe
track. Heating Baker/Loc connections to
aid in breaking connection from 166'
MD. Remove float assembly to inspect
possible debris in joint. Found float
collar packed off w/ clay, composite
centralizer chunks, and Baker swab cup
debris. Monitor hole fill on pit #1 and pill
pit #2.
Recovered 36½ Arsenal composite
centralizers. Leaving ½ centralizer in
the hole.
Recovered 8 ea stop rings.
166.0 0.0
2/8/2024
23:00
2/9/2024
00:00
1.00 INTRM1, CASING RURD T Rig down Doyon Csg running
equipment. Clean and clear rig floor.
0.0 0.0
2/9/2024
00:00
2/9/2024
01:00
1.00 INTRM1, CASING RURD T Clean and clear rig floor. Mobilize
cleanout BHA to the rig floor.
0.0 0.0
2/9/2024
01:00
2/9/2024
03:00
2.00 INTRM1, CASING BHAH T PJSM, Make up cleanout BHA as per
SLB DD to 289' MD.
0.0 289.0
2/9/2024
03:00
2/9/2024
05:15
2.25 INTRM1, CASING TRIP T RIH with stds of 5" DP from 289' MD to
10-3/4" surface shoe @ 2,832' MD. Up
Wt - 96K, S/O Wt - 92K. Monitor disp
via pits 1-3.
289.0 2,832.0
2/9/2024
05:15
2/9/2024
06:00
0.75 INTRM1, CASING CIRC T Circ bottoms up w/ 750 GPM, 764 PSI,
54% F/O. Total stks pumped - 3111
(313 bbls). Observing minimal
formation cuttings and no debris at
bottoms up.
2,832.0 2,832.0
2/9/2024
06:00
2/9/2024
08:45
2.75 INTRM1, CASING PULD T Continue to RIH picking up 5" DP from
2,832' MD to 4,161' MD. Up Wt - 113K,
S/O Wt - 95K. Monitor disp via pits 1-3.
2,832.0 4,161.0
2/9/2024
08:45
2/9/2024
09:30
0.75 INTRM1, CASING TRIP T Continue to RIH with cleanout BHA from
4,161' MD to 5,397' MD w/ stds of 5" DP.
Up Wt - 128 K, S/O Wt - 95K. Monitor
disp via pits 1-3.
4,161.0 5,397.0
2/9/2024
09:30
2/9/2024
10:30
1.00 INTRM1, CASING CIRC T Circ bottoms up @ 5,397' MD. Stage
pumps up to 750 GPM, ICP - 283, FCP -
1,130, 50% F/O, Total stks pumped -
7,840 (790 bbls). Blow down top drive.
Observing minimal formation cuttings
and no debris at bottoms up.
5,397.0 5,397.0
2/9/2024
10:30
2/9/2024
11:30
1.00 INTRM1, CASING TRIP T Continue to RIH with cleanout BHA from
5,397' MD to 6,898' MD w/ stds of 5" DP.
Up Wt - 148 K, S/O Wt - 130K. Monitor
disp via pits 1-3.
Observe obstruction @ 6,898' MD
taking 30K down weight. Decision
made to attempt to wash by obstruction.
5,397.0 6,898.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 17/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/9/2024
11:30
2/9/2024
12:00
0.50 INTRM1, CASING WASH T Pick up to 6,895, kelly up and
successfully wash by obstruction with
254 GPM, 436 PSI, 28% F/O. Continue
to wash in the hole and observe
obstruction @ 6,937' MD, taking 16K
down weight, pump pressure increase to
1136 PSI, and F/O decrease. Killed
mud pump and picked up 5'. Re-
engage mud pump, staging up to 169
GPM, 200 PSI, 16% F/O. Attempt to
wash by obstruction at 6,937' MD
(failed). Observe pressure spike to
1,061 PSI and F/O decrease. Kill mud
pumps and decision made to POOH to
6,850' MD to get above original
obstruction. POOH to 6,895 and std
back std. Up Wt - 158K, S/O Wt - 135K.
6,898.0 6,895.0
2/9/2024
12:00
2/9/2024
12:15
0.25 INTRM1, CASING PMPO T Kelly up to std @ 6,895' MD. Pump
OOH up to 6,850' MD. Staging mud
pump up to 338 GPM, 386 PSI, 36%
F/O. Up Wt @ rate - 150K.
6,895.0 6,850.0
2/9/2024
12:15
2/9/2024
12:30
0.25 INTRM1, CASING REAM T Increase pump rate to 376 GPM, 446
PSI, 38% F/O, engage rotary to 40
RPM, 4K Tq and ream in the hole.
Successfully passing by obstructions at
6,898' MD and 6,937' MD. Decision
made to wash and ream to bottom.
6,850.0 6,937.0
2/9/2024
12:30
2/9/2024
14:00
1.50 INTRM1, CASING REAM T Wash and ream in the hole from 6,937'
MD to 7,470' MD with 400 GPM, 550
PSI, 43% F/O, 40 RPM, 5K Tq. S/O Wt
@ rate - 147K.
6,937.0 7,470.0
2/9/2024
14:00
2/9/2024
15:30
1.50 INTRM1, CASING CIRC T Pick up 5'. Rotate and reciprocate pipe
from 7,465' MD to 7,396' MD circulating
a hi-vis sweep. Stage pumps up to 750
GPM, ICP - 550, FCP - 1395, 51% F/O,
136 RPM, 4K Tq. Total stks pumped -
10,611 (1069 bbls). Acquire SPR.
Observe minimal formation cuttings and
no debris on return of sweep.
7,470.0 7,470.0
2/9/2024
15:30
2/9/2024
16:15
0.75 INTRM1, CASING OWFF T OWFF (static). Blow down top drive. 7,470.0 7,470.0
2/9/2024
16:15
2/9/2024
17:00
0.75 INTRM1, CASING TRIP T POOH racking back 5" DP from 7,470'
MD to 6,996' MD. Up Wt - 153K.
Monitor disp via trip tank.
7,470.0 6,996.0
2/9/2024
17:00
2/9/2024
17:15
0.25 INTRM1, CASING CIRC T Pump 30 bbl 11.0 ppg slug. Blow down
top drive.
6,996.0 6,996.0
2/9/2024
17:15
2/9/2024
21:00
3.75 INTRM1, CASING TRIP T Continue to POOH racking back 5" DP
from 6,996' MD to 2,900' MD. Up Wt -
150K. Monitor hole fill via trip tank.
6,996.0 2,900.0
2/9/2024
21:00
2/9/2024
21:15
0.25 INTRM1, CASING OWFF T OWFF (static). 2,900.0 2,900.0
2/9/2024
21:15
2/9/2024
23:45
2.50 INTRM1, CASING TRIP T Continue to POOH racking back 5" DP
from 2,900' MD to 289' MD. Up Wt -
100K. Monitor hole fill via trip tank.
2,900.0 289.0
2/9/2024
23:45
2/10/2024
00:00
0.25 INTRM1, CASING OWFF T OWFF (static). 289.0 289.0
2/10/2024
00:00
2/10/2024
02:15
2.25 INTRM1, CASING BHAH T POOH and lay down HWDP, jars, and
remaining BHA components from 289'
MD per SLB DD.
Monitor hole fill on the trip tank
289.0 0.0
2/10/2024
02:15
2/10/2024
03:45
1.50 INTRM1, CASING WWWH T Make up flushing tool and flush the
BOPE stack. 750 gpm, 90 psi.20 rpm,
1k tq.
Pull wear bushing per Cameron Rep.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 18/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/10/2024
03:45
2/10/2024
04:15
0.50 INTRM1, CASING CLEN T Clear and clean the rig floor in
preparation for casing run.
0.0 0.0
2/10/2024
04:15
2/10/2024
06:00
1.75 INTRM1, CASING RURD T Rig up to run 7-5/8" casing hybrid style. 0.0 0.0
2/10/2024
06:00
2/10/2024
07:30
1.50 INTRM1, CASING PUTB T Make up 7-5/8", 29.7#, L80, Hyd563,
shoe track per detail to 170' MD. Torque
connections with power tongs to 10,300
ft/lbs. Bakerlok connection to the pin of
joint #4. Circulate through shoe track to
verify flow path, 4 bbls/min, 50 psi.
0.0 170.0
2/10/2024
07:30
2/10/2024
12:30
5.00 INTRM1, CASING PUTB T Run 7-5/8", 33.7#, P110S, Hyd563, R3
casing from 170' to 850' MD. Run 7-5/8",
29.7#, L80, Hyd563, R3 casing from
850' to 2,908' MD. 110k Up Wt, 113k Dn
Wt. Fill pipe on the fly and top off every
10 joints. Install 7-5/8" x 9-1/4" arsenal
centralizer free floating on every joint to
joint #61. Monitor displacement on pit
#1, #2, and #6.
Torque 33.7# Hyd563 to 12,100 ft/lbs
Torque 29.7# Hyd563 to 10,300 ft/lbs
Wiped off any excess dope, applied thin
layer of BOL2000AG to the pin end only
as needed. Verified all connections
made up to hash marks. Replaced joint
# 66.
170.0 2,908.0
2/10/2024
12:30
2/10/2024
13:00
0.50 INTRM1, CASING CIRC T Stage up pumps to 6 bbls/min and
circulate 1 bottoms up. 110k Up Wt,
113k Dn Wt.
3 bbls/min, 100 psi
4 bbls/min, 120 psi
5 bbls/min, 135 psi
6 bbls/min, 145 psi
2,908.0 2,908.0
2/10/2024
13:00
2/10/2024
16:15
3.25 INTRM1, CASING PUTB T Run 7-5/8", 29.7#, L80, Hyd563, R3
casing from 2908' to 5,328' MD. 110k
Up Wt, 138k Dn Wt. Fill pipe on the fly
and top off every 10 joints. Monitor
displacement on pit #1 & #2.
Torque 29.7# Hyd563 to 10,300 ft/lbs
Wiped off any excess dope, applied thin
layer of BOL2000AG to the pin end only
as needed. Verified all connections
made up to hash marks.
2,908.0 5,328.0
2/10/2024
16:15
2/10/2024
16:45
0.50 INTRM1, CASING CIRC T Circulate from 5,328' MD to 5,373' MD
staging pumps up to 6 bbls/min. Up Wt
- 158K, Dn Wt - 135K. Total stks
pumped - 2698. (272 bbls)
3 bbls/min, 170 psi
4 bbls/min, 196 psi
5 bbls/min, 126 psi
6 bbls/min, 225 psi
5,328.0 5,373.0
2/10/2024
16:45
2/10/2024
17:30
0.75 INTRM1, CASING PUTB T Run 7-5/8", 29.7#, L80, Hyd563, R3
casing from 5,373' to 5,537' MD. 158k
Up Wt, 135k Dn Wt. Fill pipe on the fly
and top off every 10 joints. Monitor
displacement on pit #1 & #2.
Torque 29.7# Hyd563 to 10,300 ft/lbs
Wiped off any excess dope, applied thin
layer of BOL2000AG to the pin end only
as needed. Verified all connections
made up to hash marks.
5,373.0 5,537.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 19/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/10/2024
17:30
2/10/2024
20:30
3.00 INTRM1, CASING PUTB P Run 7-5/8", 29.7#, L80, Hyd563, R3
casing from 5,537' to 7,368' MD. 200k
Up Wt, 153k Dn Wt. Fill pipe on the fly
and top off every 10 joints. Monitor
displacement on pit #1 & #2.
Torque 29.7# Hyd563 to 10,300 ft/lbs
Wiped off any excess dope, applied thin
layer of BOL2000AG to the pin end only
as needed. Verified all connections
made up to hash marks.
5,537.0 7,368.0
2/10/2024
20:30
2/10/2024
21:15
0.75 INTRM1, CASING HOSO P Run 7-5/8", 29.7#, L80, Hyd563, R3
casing from 7,368' to 7,470' MD. M/U
4.70 & 9.85 pups on top of jt #179.
Wash dn jt #181 w/ 2 bpm, 303 psi. P/U
jt #182 and tag btm 6' dn w/ 5K tq @
7,470' MD. L/D jts #182 and #181 up to
7,432' MD. 198k Up Wt, 154k Dn Wt.
7,368.0 7,432.0
2/10/2024
21:15
2/10/2024
22:00
0.75 INTRM1, CASING HOSO P At 7,432' MD, make up 7-5/8" Cameron
hanger and landing jt. Wash down with
2 bpm, 288 psi. Land hanger on depth
@ 7,465.51' MD.
7,432.0 7,465.0
2/10/2024
22:00
2/11/2024
00:00
2.00 INTRM1, CEMENT CIRC P Recip pipe 18' from 7,465' MD to 7,447'
MD staging pumps up to 6 bpm. ICP -
264, FCP - 282. Up Wt - 178k, Dn Wt -
154k.
7,465.0 7,465.0
2/11/2024
00:00
2/11/2024
01:45
1.75 INTRM1, CEMENT CIRC P Continue to circulate, conditioning mud
while recip pipe 18' from 7,465' MD to
7,447' MD. Setting on the ring every 3rd
stroke. Circ @ 6 bpm, 296 psi, 20% f/o.
Up Wt - 178k, Dn Wt - 154k.
Total stks pumped - 11,007 (1,108 bbls).
7,465.0 7,465.0
2/11/2024
01:45
2/11/2024
02:30
0.75 INTRM1, CEMENT RURD P Rig down Volant casing running tool.
Blow down top drive. Rig up 7-5/8"
Halliburton cementing head.
7,465.0 7,465.0
2/11/2024
02:30
2/11/2024
03:15
0.75 INTRM1, CEMENT CIRC P Continue to circulate conditioning mud
while recip pipe 18' from 7,465' MD to
7,447' MD. Setting on the ring every 3rd
stroke. Circ @ 6 bpm, 311 psi, 20% f/o.
Up Wt - 178k, Dn Wt - 154k.
Total stks pumped - 2,604 (262 bbls)
SIMOPS - PJSM with rig team. Rig up
water lines from the rig to cementers.
7,465.0 7,465.0
2/11/2024
03:15
2/11/2024
03:45
0.50 INTRM1, CEMENT RURD P Shut down and blow down cement line.
Move cement sensator to cement head
for upcoming csg test. Load 3 ea
cement plugs into cement head.
7,465.0 7,465.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 20/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/11/2024
03:45
2/11/2024
06:45
3.00 INTRM1, CEMENT CMNT P Flood lines with 5 bbls of water @ 2
bpm, 100 psi and kick out lower wiper
plug. PT lines to 4000 psi (good).
Pump 61 bbls of tuned 10.5 ppg prime
spacer @ 3-5 bpm 430 psi, 15% f/o.
Kick out 2nd plug with 111 bbls of 15.3
ppg cement (with BMII, cement wet @
04:40) @ 3 bpm, ICP - 300, FCP - 294,
17% f/o. Pump 29 bbls of 15.3 ppg
cement(without BMII) @ 3 bpm 294 psi
(140 bbls total cement). Drop top plug
and chase with 20 bbls of fresh water @
5 bpm, 169 psi, 12% f/o. Line rig pumps
and chase cement with 9.6 treated FWP
@ 8 bpm, 61 psi, 24% f/o. Catch
cement @ 1883 strokes (189 bbls).
Observe psi climb to 150. Reduce rate
to 6 bpm, 700 psi, 27% f/o. Observe
pressure climb to 1184 psi @ 3000 stks.
Reduce rate to 3 bpm, 1025 psi. Bump
plug @ 3132 stks (315 bbls). Increase
pressure to 1500 and hold for 5 min.
Bleed off pressure and check floats
(good). CIP @ 6:38 hrs.
7,465.0 7,465.0
2/11/2024
06:45
2/11/2024
07:00
0.25 INTRM1, CEMENT PRTS P RU to pressure test casing. Observe
pinhole leak on a weld in the mud
manifold. Decision made to do casing
test after BOPE test.
0.0 0.0
2/11/2024
07:00
2/11/2024
08:30
1.50 INTRM1, CEMENT RURD P Blow down cement line. Rig down
Halliburton cement head. Clear and
clean rig floor of Doyon csg and
Halliburton csg running equipment.
SIMOPS - Clean out cement valves.
0.0 0.0
2/11/2024
08:30
2/11/2024
10:00
1.50 INTRM1, CEMENT WWWH P Flush and drain BOPE. SIMOPS -
mobilize 10-3/4 x 7-5/8" packoff to the
rig floor.
0.0 0.0
2/11/2024
10:00
2/11/2024
13:00
3.00 INTRM1, CEMENT WWSP P Make up running tool and set 10-3/4" x
7-5/8" packoff as per Cameron reps.
Test packoff to 5000 psi for 10 min
(good). Test witnessed by CPAI rep.
SIMOPS - prep pits for production hole
section.
0.0 0.0
2/11/2024
13:00
2/11/2024
18:00
5.00 INTRM1, WHDBOP RURD P Change out saver sub to XT-39. Clean
and inspect lower 3½" x 6" VBR's. Prep
pipe shed for laying down 5" DP. Lay
down 5" DP via 90' mousehole (2 ea
stds).
0.0 0.0
2/11/2024
18:00
2/11/2024
23:15
5.25 INTRM1, WHDBOP RURD P Lay down 5" DP via 90' mousehole (31
stds)
SIMOPS - change out upper rams to
3½" x 6".
0.0 0.0
2/11/2024
23:15
2/12/2024
00:00
0.75 INTRM1, WHDBOP RURD P Rig up to test BOPE. With the 4½" test
jt, install test plug as per Cameron rep.
0.0 0.0
2/12/2024
00:00
2/12/2024
02:00
2.00 INTRM1, WHDBOP RURD P Rig up to test BOPE. With the 4½" test
jt, install test plug as per Cameron rep.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 21/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/12/2024
02:00
2/12/2024
06:15
4.25 INTRM1, WHDBOP BOPE P Test BOPE to 250 low, 4,000 high for
5/5 charted min. w/ the exception of the
manual operated & super choke tested
to 2,000 psi. With 4” and 4½" test jts.
test annular, 3½" x 6" upr and lower
vbr's, choke valves 1-14, manual
operated and super choke, choke & kill
manuals and HCR's, 4" kill line, 4"
FOSV (x2), 4" dart valve. Test upper
and lower IBOP with blind shear rams.
Perform koomey drawdown - acc - 3000
psi, manifold - 1350 psi, acc - 1800 after
all functions, 21 sec for 200 psi build w/
2 elec pumps, 111 sec to build full
system psi w/ 2 elec pumps and 2 air
pumps. Closing times for annular - 18
sec, upr - 7 sec, blind / shears - 7 sec,
lwr - 7 sec, choke HCR - 1 sec, kill HCR
- 1 sec. 6 bottle nitrogen backup ave. -
2000 psi. Test PVT gain/loss and flow
out alarms. Test LEL and H2S alarms.
AOGCC rep Brian Bixby witness to the
test.
0.0 0.0
2/12/2024
06:15
2/12/2024
07:00
0.75 INTRM1, WHDBOP RURD P Rig down testing equipment. Blow
down choke and kill lines. pull test plug.
SIMOPS - test repaired pinhole leak on
mud manifold to 5000 psi (good).
0.0 0.0
2/12/2024
07:00
2/12/2024
07:15
0.25 INTRM1, WHDBOP MPDA P Shell test injection line used for MPD
ops to 1200 psi for 5 min (good).
0.0 0.0
2/12/2024
07:15
2/12/2024
08:00
0.75 INTRM1, WHDBOP RURD P Install 10" ID x 12.375 Length wear
bushing as per Cameron rep.
0.0 0.0
2/12/2024
08:00
2/12/2024
09:45
1.75 INTRM1, DRILLOUT BHAH P Mobilize production BHA to the rig floor.
SIMOPS - Organize BHA in the
pipeshed. Process 4" DP. Prep for csg
test and hang blocks for upcoming slip
and cut.
0.0 0.0
2/12/2024
09:45
2/12/2024
10:45
1.00 INTRM1, DRILLOUT PRTS P Pressure test 7-5/8" intermediate csg to
4000 psi for 30 min monitored via Totco
(good). 5.4 bbls to pressure up, 5.2 bbls
bled back.
0.0 0.0
2/12/2024
10:45
2/12/2024
13:00
2.25 INTRM1, DRILLOUT SLPC P Slip and cut 50' 1.375 drill line.
SIMOPS - continue to process 4" DP.
0.0 0.0
2/12/2024
13:00
2/12/2024
13:15
0.25 INTRM1, DRILLOUT SFTY P PJSM with floor crew/dd on picking up
production BHA.
0.0 0.0
2/12/2024
13:15
2/12/2024
16:15
3.00 INTRM1, DRILLOUT BHAH P Make up 6½" production BHA as per
SLB DD to 194' MD.
0.0 194.0
2/12/2024
16:15
2/12/2024
20:45
4.50 INTRM1, DRILLOUT PULD P Single in the hole with XT-39 4" DP from
194' MD to 3,029' MD. Manually
operating the ST-100 due to electrical
issues.
194.0 3,029.0
2/12/2024
20:45
2/12/2024
21:30
0.75 INTRM1, DRILLOUT DHEQ P Shallow pulse test MWD tool w/ 280
GPM, 1702 PSI. Downlink to sonic tool
for free ring pipe cement logging
operations.
3,029.0 3,029.0
2/12/2024
21:30
2/12/2024
22:00
0.50 INTRM1, DRILLOUT DLOG P Pick up to 3,000' MD. Log free ring pipe
running in the hole at 450 ft/hr with 280
GPM, 1735 PSI, 32% F/O to 3,125' MD.
3,029.0 3,125.0
2/12/2024
22:00
2/13/2024
00:00
2.00 INTRM1, DRILLOUT DLOG P Continue to log free ring pipe running in
the hole at 900 ft/hr with 280 GPM, 1735
PSI, 32% F/O to 3,689' MD.
3,125.0 3,689.0
2/13/2024
00:00
2/13/2024
02:30
2.50 INTRM1, DRILLOUT DLOG P Continue to log free ring pipe running in
the hole at 900 ft/hr with 280 GPM, 1915
PSI, 32% F/O from 3,689' to 4,415' MD.
Estimate TOC at 3,950'. At 4,415'
downlink to LWD tools and set up tools
for recorded mode and B/D top drive.
3,689.0 4,415.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 22/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/13/2024
02:30
2/13/2024
03:30
1.00 INTRM1, DRILLOUT DLOG P RIH with stands of 4" HWDP from 4,415'
to 5,250' while logging cement in
recorded mode at 5400 ft/hr max. P/U
127k, S/O 118k
4,415.0 5,250.0
2/13/2024
03:30
2/13/2024
07:30
4.00 INTRM1, DRILLOUT DLOG P Cont. to RIH picking up 4" HWDP from
5,250' to 7,151' MD while logging
cement in recorded mode at 5400 ft/hr
max. P/U 155k, S/O 138k
5,250.0 7,151.0
2/13/2024
07:30
2/13/2024
07:45
0.25 INTRM1, DRILLOUT SFTY P PJSM with rig crew, MPD advisor on
bearing install.
7,151.0 7,151.0
2/13/2024
07:45
2/13/2024
09:15
1.50 INTRM1, DRILLOUT MPDA P Pull trip nipple and install MPD bearing. 7,151.0 7,151.0
2/13/2024
09:15
2/13/2024
11:00
1.75 INTRM1, DRILLOUT MPDA P Initialize NOVOS and simulate dynamic
connections w/ bearing installed,
calibrating MPD chokes. Confirming
NOVOS system is operational after
update install.
7,151.0 7,151.0
2/13/2024
11:00
2/13/2024
12:00
1.00 INTRM1, DRILLOUT MPDA P Remove MPD bearing, racking back on
std of 4" DP. Install trip nipple & blow
down MPD choke skid.
7,151.0 7,151.0
2/13/2024
12:00
2/13/2024
12:30
0.50 INTRM1, DRILLOUT DLOG P Cont. to RIH picking up 4" DP from
7,151' MD to 7,340' MD while logging
cement in recorded mode at 5400 ft/hr
max. P/U 155k, S/O 138k. Encounter
obstruction at 7,340' MD setting 13K dn
wt. Decision made to pick up to 7,330'
MD and wash and ream in the hole.
7,151.0 7,330.0
2/13/2024
12:30
2/13/2024
13:00
0.50 INTRM1, DRILLOUT REAM P Wash and ream in the hole from 7,330'
MD to top of plugs @ 7,374' MD with
250 GPM, 2,260 PSI, 28% F/O, 50
RPM, 6K tq.
7,330.0 7,374.0
2/13/2024
13:00
2/13/2024
14:00
1.00 INTRM1, DRILLOUT DRLG P Drill out cement plugs and float collar
from 7,374' MD to 7,380' MD with
WOB=6k, GPM=250, PSI=2440,
RPM=50, TQ=6k, F/O=28%, P/U=155k,
S/O=138k, RT=142k.
7,374.0 7,380.0
2/13/2024
14:00
2/13/2024
14:30
0.50 INTRM1, DRILLOUT DRLG P Drill out cement from 7,380' MD to top of
the shoe at 7,464' MD with WOB=2k,
GPM=250, PSI=2440, RPM=80, TQ=5k,
F/O=28%, P/U=155k, S/O=138k,
RT=142k.
7,380.0 7,464.0
2/13/2024
14:30
2/13/2024
14:45
0.25 INTRM1, DRILLOUT DRLG P Drill out shoe and rat hole from 7,464'
MD to 7,470' MD with WOB=9k,
GPM=250, PSI=2245, RPM=80, TQ=6k,
F/O=28%, P/U=155k, S/O=138k,
RT=142k.
7,464.0 7,470.0
2/13/2024
14:45
2/13/2024
15:00
0.25 INTRM1, DRILLOUT DDRL P Drill 20' new formation from 7,470' MD
to 7,490' MD with WOB=6k, GPM=250,
PSI=2245, RPM=80, TQ=6k, F/O=28%,
P/U=155k, S/O=138k, RT=142k.
7,470.0 7,490.0
2/13/2024
15:00
2/13/2024
18:15
3.25 INTRM1, DRILLOUT CIRC P Rotate and reciprocate pipe from 7,490'
MD to 7,467' MD while circ at
GPM=250, PSI=1990, RPM=80, TQ=8k,
F/O=28%, P/U=155k, S/O=138k,
RT=142k. Pump 30 bbl hi-vis sweep.
Total stks pumped - 9972 (1004 bbls).
Mud wt 9.3 ppg in/out.
SIMOPS - Pickup and Makeup 15 stds
of 4" DP via mousehole to allow time for
laying down excess 5" DP in the derrick.
7,490.0 7,467.0
2/13/2024
18:15
2/13/2024
18:30
0.25 INTRM1, DRILLOUT OWFF P OWFF (static). SIMOPS - stand back
std
7,467.0 7,454.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 23/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/13/2024
18:30
2/13/2024
19:30
1.00 INTRM1, DRILLOUT FIT P Rig up and perform FIT. Pump 1.7 bbls
@ 5 spm to 1405 psi. Achieve 14.5
EMW. Bleed back 1.3 bbls.
7,454.0 7,454.0
2/13/2024
19:30
2/13/2024
20:45
1.25 PROD1, DRILL MPDA P PJSM, Pull trip nipple and install MPD
bearing. Up wt - 165k, S/O - 132K
7,454.0 7,454.0
2/13/2024
20:45
2/13/2024
22:15
1.50 PROD1, DRILL DISP P Displace well to 9.0 ppg Kla-Shield. Rot
and recip pipe from 7,454' MD to 7,490'
MD with GPM=250, PSI=1910,
RPM=50, TQ=7k, F/O=28%, P/U=148k,
S/O=137k, RT=142k. Total stks
pumped - 4,228 (426 bbls).
7,454.0 7,490.0
2/13/2024
22:15
2/14/2024
00:00
1.75 PROD1, DRILL DDRL P Drill 6½" production hole geo steering
from 7,490' MD to 7,582' MD with
WOB=4k, GPM=250, PSI=1812,
RPM=80, TQ=6k, F/O=26%,
ECD=9.94, MWT=9.0 P/U=157k,
S/O=137k, RT=142k. ADT=.88, Total bit
hrs=1.03, Max gas=35 units. MPD
connection psi=600.
7,490.0 7,582.0
2/14/2024
00:00
2/14/2024
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 7,582'
MD to 8,005' MD / 5,261' TVD, WOB 6k,
GPM 250, PSI 1881, RPM 100, TQ 8k,
ECD 10.03 ppg, MWT 9.1 ppg, P/U
169k, ROT 140k, S/O 116, ADT 4.09,
Total bit hrs 5.12, Max gas 52, MPD
connection back PSI 165.
7,582.0 8,005.0
2/14/2024
06:00
2/14/2024
12:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 8,005’
MD to 8,573' MD / 5,256' TVD, WOB 9k,
GPM 270, PSI 2241, RPM 120, TQ
9.5k, ECD 10.25 ppg, MWT 9.1 ppg,
P/U 168k, S/O 116, ROT 140k, ADT
4.63, Total bit hrs 7.75, Max gas 82,
MPD connection back PSI 230.
8,005.0 8,573.0
2/14/2024
12:00
2/14/2024
18:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 8,573’
MD to 8,872' MD / 5,254' TVD, WOB
10k, GPM 265, PSI 2172, RPM 120, TQ
8k, ECD 10.17 ppg, MWT 9.1 ppg, P/U
166k, S/O 105, ROT 138k, ADT 5.25,
Total bit hrs 15, Max gas 56, MPD
connection back PSI 250.
8,573.0 8,872.0
2/14/2024
18:00
2/15/2024
00:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 8,872’
MD to 9,452' MD / 5,239' TVD, WOB 9k,
GPM 265, PSI 2237, RPM 120, TQ 9k,
ECD 10.30 ppg, MWT 9.1 ppg, P/U
166k, S/O 106, ROT 134k, ADT 4.58,
Total bit hrs 19.58, MPD connection
back PSI 250.
Formation losses last 24 hours: 0 bbls
Total interval formation losses: 0 bbls
8,872.0 9,452.0
2/15/2024
00:00
2/15/2024
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 9,452'
MD to 9,927' MD / 5,228' TVD, WOB 2k,
GPM 265, PSI 2295, RPM 120, TQ 9k,
ECD 10.40 ppg, MWT 9.0 ppg, P/U
168k, S/O 101k, ROT 136k, ADT 4.91,
Total bit hrs 24.49, Maintaining 10.4 ppg
EMW with MPD. Max gas = 214 units.
9,452.0 9,927.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 24/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/15/2024
06:00
2/15/2024
12:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 9,927'
MD to 10,290' / 5,222' TVD, WOB 2k,
GPM 265, PSI 2295, RPM 120, TQ 9k,
ECD 10.32 ppg, MWT 9.0 ppg, P/U
174k, S/O 99k, ROT 135k, ADT 4.83,
Total bit hrs 29.32 Maintaining 10.4 ppg
EMW with MPD. Max gas = 233 units.
SIMOPS - Attempt to perform injectivity
test on 10-3/4" X 7-5/8" annulus with no
success. Made three attempts with our
maximum working EMW of 16.1 ppg.
9,927.0 10,290.0
2/15/2024
12:00
2/15/2024
18:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 10,290'
MD to 10,857' / 5,220' TVD, WOB 8k,
GPM 265, PSI 2345, RPM 120, TQ 9k,
ECD 10.40 ppg, MWT 9.0+ ppg, P/U
170k, S/O 100k, ROT 132k, ADT 4.45,
Total bit hrs 33.77 Maintaining 10.6 ppg
EMW with MPD. Max gas = 513 units.
10,290.0 10,857.0
2/15/2024
18:00
2/16/2024
00:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 10,857'
MD to 11,424' / 5,216' TVD, WOB 6k,
GPM 265, PSI 2455, RPM 120, TQ 10k,
ECD 10.62 ppg, MWT 9.0+ ppg, P/U
172k, S/O 100k, ROT 130k, ADT 4.74,
Total bit hrs 38.51 Maintaining 10.6 ppg
EMW with MPD. Max gas = 653 units.
10,857.0 11,424.0
2/16/2024
00:00
2/16/2024
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 11,424'
MD to 11,990' / 5,211' TVD, WOB 6k,
GPM 265, PSI 2487, RPM 120, TQ 10k,
ECD 10.64 ppg, MWT 9.0+ ppg, P/U
164k, S/O 95k, ROT 127k, ADT 4.77,
Total bit hrs 43.28 Maintaining 10.4 ppg
EMW with MPD. Max gas = 261 units.
11,424.0 11,990.0
2/16/2024
06:00
2/16/2024
12:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 11,990'
MD to 12,490' / 5,207' TVD, WOB 7k,
GPM 265, PSI 2537, RPM 120, TQ 11k,
ECD 10.63 ppg, MWT 9.1 ppg, P/U
165k, S/O 92k, ROT 124k, ADT 4.22,
Total bit hrs 47.5 Maintaining 10.4 ppg
EMW with MPD. Max gas = 261 units.
11,990.0 12,490.0
2/16/2024
12:00
2/16/2024
18:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 12,490'
MD to 12,968' / 5,197' TVD, WOB 7k,
GPM 265, PSI 2660, RPM 120, TQ 11k,
ECD 10.74 ppg, MWT 9.1 ppg, P/U
163k, S/O 88k, ROT 125k, ADT 4.57,
Total bit hrs 52.07 Maintaining 10.6 ppg
EMW with MPD. Max gas = 351 units.
12,490.0 12,968.0
2/16/2024
18:00
2/16/2024
22:00
4.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 12,968'
MD to 13,123' / 5,201' TVD, WOB 4.5k,
GPM 265, PSI 2556, RPM 120, TQ 10k,
ECD 10.62 ppg, MWT 9.1 ppg, P/U
163k, S/O 82k, ROT 121k, ADT 3.53,
Total bit hrs 55.6 Maintaining 10.6 ppg
EMW with MPD. Max gas = 477 units.
12,968.0 13,122.0
2/16/2024
22:00
2/16/2024
22:45
0.75 PROD1, DRILL REAM P Observe 7.58° DLS @ survey depth of
12,993' MD. Decision made to BROOH
to wipe DLS. BROOH from 13,123' MD
to 12,930' MD with GPM 265, PSI 2610,
RPM 120, TQ 9k, ECD 10.61 ppg.
Observe no overpull, tq, or pressure
spikes.
13,122.0 12,930.0
2/16/2024
22:45
2/16/2024
23:30
0.75 PROD1, DRILL REAM P Ream in the hole from 12,930' MD to
13,125' MD w/ GPM 260, PSI 2502,
RPM 110, TQ 9k, ECD 10.59 ppg.
Observe no obstructions, tq, or pressure
spikes.
12,930.0 13,122.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 25/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/16/2024
23:30
2/17/2024
00:00
0.50 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 13,122'
MD to 13,158' / 5,201' TVD, WOB 6k,
GPM 265, PSI 2575, RPM 120, TQ 10k,
ECD 10.66 ppg, MWT 9.0+ ppg, P/U
165, S/O 82k, ROT 121k, ADT .37, Total
bit hrs 55.97 Maintaining 10.6 ppg EMW
with MPD. Max gas = 477 units.
Formation losses last 24 hours: 0 bbls
Total interval formation losses: 0 bbls
13,122.0 13,158.0
2/17/2024
00:00
2/17/2024
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 13,158'
MD to 13,691' / 5,205' TVD, WOB 6k,
GPM 265, PSI 2649, RPM 120, TQ
10.5k, ECD 10.8 ppg, MWT 9.0+ ppg,
P/U 159, S/O 75k, ROT 117k, ADT 4.74,
Total bit hrs 60.71 Maintaining 10.7 ppg
EMW with MPD. Max gas = 157 units.
13,158.0 13,691.0
2/17/2024
06:00
2/17/2024
12:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 13,691'
MD to 14,244' / 5,203' TVD, WOB 8k,
GPM 265, PSI 2699, RPM 120, TQ
10.5k, ECD 10.89 ppg, MWT 9.0+ ppg,
P/U 155, S/O 80k, ROT 123k, ADT 4.69,
Total bit hrs 65.40 Maintaining 10.9 ppg
EMW with MPD. Max gas = 175 units.
13,691.0 14,244.0
2/17/2024
12:00
2/17/2024
18:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 14,244'
MD to 14,556' / 5,200' TVD, WOB 8k,
GPM 265, PSI 2692, RPM 120, TQ 11k,
ECD 10.86 ppg, MWT 9.1 ppg, P/U
159k, S/O - NA, ROT 111k, ADT 4.82,
Total bit hrs 70.22 Maintaining 10.9 ppg
EMW with MPD. Max gas = 214 units.
14,244.0 14,556.0
2/17/2024
18:00
2/18/2024
00:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 14,556'
MD to 14,894' / 5,206' TVD, WOB 4k,
GPM 265, PSI 2760, RPM 120, TQ 11k,
ECD 10.96 ppg, MWT 9.1 ppg, P/U
161k, S/O - NA, ROT 110k, ADT 5.23,
Total bit hrs 75.45 Maintaining 10.9 ppg
EMW with MPD. Max gas = 156 units.
Formation losses last 24 hours: 0 bbls
Total interval formation losses: 0 bbls
14,556.0 14,894.0
2/18/2024
00:00
2/18/2024
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 14,894'
MD to 15,220' / 5,196' TVD, WOB 1.5k,
GPM 265, PSI 2746, RPM 120, TQ 11k,
ECD 10.92 ppg, MWT 9.1 ppg, P/U
156k, S/O - NA, ROT 106k, ADT 4.71,
Total bit hrs 80.16 Max gas = 97 units.
Maintaining 10.9 ppg EMW with MPD.
14,894.0 15,220.0
2/18/2024
06:00
2/18/2024
12:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 15,220'
MD to 15,632' / 5,192' TVD, WOB 5k,
GPM 265, PSI 2770, RPM 120, TQ 11k,
ECD 10.97 ppg, MWT 9.0 ppg, P/U
159k, S/O - NA, ROT 105k, ADT 4.74,
Total bit hrs 84.90 Max gas = 197 units.
Maintaining 10.9 ppg EMW with MPD.
Attempt 10-3/4" x 7-5/8" annular
injection. Observe FIT to 18.0 EMW.
15,220.0 15,632.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 26/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/18/2024
12:00
2/18/2024
18:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 15,632'
MD to 16,200' / 5,206' TVD, WOB 6k,
GPM 265, PSI 2775, RPM 120, TQ
11.5k, ECD 11.05 ppg, MWT 9.0 ppg,
P/U 170k, S/O - NA, ROT 105k, ADT
5.35, Total bit hrs 90.25 Max gas = 234
units. Maintaining 10.9 ppg EMW with
MPD.
Pump 30 bbl bit balling sweep. @
16,080' MD to
Pump 30 bbl 300 vis hi vis sweep @
16,270' MD observing a fair increase in
cuttings at the shaker.
15,632.0 16,200.0
2/18/2024
18:00
2/19/2024
00:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 16,200'
MD to 16,630' / 5,191' TVD, WOB 4.5k,
GPM 265, PSI 2803, RPM 120, TQ 12k,
ECD 11.15 ppg, MWT 9.0+ ppg, P/U
173k, S/O - NA, ROT 109k, ADT 3.73,
Total bit hrs 93.82 Max gas = 349 units.
Maintaining 10.9 ppg EMW with MPD.
Formation losses last 24 hours: 0 bbls
Total interval formation losses: 0 bbls
16,200.0 16,630.0
2/19/2024
00:00
2/19/2024
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 16,630'
MD to 17,147' MD / 5,200' TVD, WOB
7k, GPM 265, PSI 2875, RPM 120, TQ
12k, ECD 11.25 ppg, MWT 9.0+ ppg,
P/U 167k, S/O - NA, ROT 103k, ADT
4.91, Total bit hrs 98.73, Max gas = 156
units. Maintaining 10.9 ppg EMW with
MPD.
16,630.0 17,147.0
2/19/2024
06:00
2/19/2024
11:15
5.25 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 17,147'
MD to 17,443' MD / 5,201' TVD, WOB
8k, GPM 265, PSI 2975, RPM 120, TQ
11.5k, ECD 11.19 ppg, MWT 9.0+ ppg,
P/U 170k, S/O - NA, ROT 106k, ADT
3.84, Total bit hrs 102.57, Max gas =
165 units. Maintaining 10.9 ppg EMW
with MPD.
At 17,443 cycled pumps to reset
directional tools and send downlink.
Once pumps were back at full drilling
rate of 260 gpm saw a 400 psi reduction
from 2975 PSI to 2575 PSI and lost
communication with directional/logging
tools.
Performed 3rd injectivity test on 10--3/4"
X 7-5/8" OA. Observing max pressure
limit of 20 ppg EMW. Was not able to
get formation to break over and
establish an injection rate, but was able
to squeeze 15 bbls FWP into formtion.
17,147.0 17,443.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 27/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/19/2024
11:15
2/19/2024
14:15
3.00 PROD1, DRILL CIRC T Troubleshoot pressure loss and
directional tools. Swap mud pumps with
no success. Pressure test surface lines
to 3000 psi and confirm pressure loss
was not on surface. Vary flow rates and
cycle pumps with no success. Pump 30
bbl high vis followed by 30 bbl low vis
sweeps with no success. Increase flow
rate to max of 290 GPM / 3000 PSI and
no communication with
directional/logging tools. Discuss plan
forward options with town and decide to
drill ahead 10' with no communication.
17,443.0 17,443.0
2/19/2024
14:15
2/19/2024
14:30
0.25 PROD1, DRILL DDRL T Drill 6-1/2” production hole from 17,453'
MD / 5,205' TVD, WOB 5k, GPM 265,
PSI 2600, RPM 120, TQ 12k. ADT .12,
Total bit hrs 102.69, No communication
with directional/logging tools.
17,443.0 17,453.0
2/19/2024
14:30
2/19/2024
16:00
1.50 PROD1, DRILL CIRC T Continue to circulate and troubleshoot
directional tools at 265 GPM, 2650 PSI,
reciprocate full stand at 120 RPM, 10 k
Trq. Send multiple downlinks to change
configuration of tools and attempt to un-
jam the modulator. No success.
Decision made to BROOH and change
out BHA. Prep derrick for BROOH.
Service rig and grease wash pipe.
Collect SPR's.
17,453.0 17,453.0
2/19/2024
16:00
2/19/2024
18:00
2.00 PROD1, DRILL BKRM T BROOH from 17,453' MD to 17,141'
MD, GPM=263, PSI=2600, RPM=100,
TQ=11k, F/O=29%, P/U=170k, S/O=NA,
RT=103k.
17,453.0 17,141.0
2/19/2024
18:00
2/20/2024
00:00
6.00 PROD1, DRILL BKRM T BROOH from 17,141' MD to 15,050'
MD, GPM=263, PSI=2348, RPM=100,
TQ=10k, F/O=29%, P/U @ rate = 109K.
17,141.0 15,050.0
2/20/2024
00:00
2/20/2024
06:00
6.00 PROD1, DRILL BKRM T BROOH from 15,050' MD to 12,730'
MD, GPM=263, PSI=2057, RPM=100,
TQ=8.5k, F/O=30%, P/U @ rate = 126K.
Maintaining 10.9 EMW on connections.
15,050.0 12,730.0
2/20/2024
06:00
2/20/2024
12:00
6.00 PROD1, DRILL BKRM T BROOH from 12,730' MD to 10,358'
MD, GPM=263, PSI=2045, RPM=100,
TQ=7.5k, F/O=29%, P/U @ rate = 135K.
Maintaining 10.9 EMW on connections.
12,730.0 10,358.0
2/20/2024
12:00
2/20/2024
20:30
8.50 PROD1, DRILL BKRM T BROOH from 10,358' MD to 8,024' MD,
GPM=263, PSI=1970, RPM=100,
TQ=5.5k, F/O=29%, P/U @ rate = 142K.
Maintaining 10.9 EMW on connections.
10,358.0 8,024.0
2/20/2024
20:30
2/20/2024
22:15
1.75 PROD1, DRILL CIRC T Weight mud system up to from 9.1 to
9.5 via 12.0 ppg spike fluid while
BROOH w/ GPM=263, ICP - 1725, FCP
- 2252, RPM=100, TQ=5k, F/O=29%,
P/U @ rate = 136K. Start additions @
8,024' MD to 7,820' and achieve 9.5 ppg
mwt in/out. Total stks pumped - 6100
(614 bbls).
Observe increase in cuttings at the
shaker upon 9.5 ppg return to surface.
8,024.0 7,820.0
2/20/2024
22:15
2/20/2024
23:15
1.00 PROD1, DRILL BKRM T BROOH from 7,820' MD to 7,646 MD,
GPM=263, PSI=1944, RPM=100,
TQ=5k, F/O=29%, P/U @ rate = 143K.
Maintaining 10.9 EMW on connections.
7,820.0 7,646.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 28/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/20/2024
23:15
2/21/2024
00:00
0.75 PROD1, DRILL PMPO T Continue to POOH while pumping up
into the 7-5/8" csg shoe from 7,646' MD
to 7,528' MD w/ GPM=263, PSI=1993,
RPM=10, TQ=5k, F/O=29%, P/U @ rate
= 147K. Maintaining 10.9 EMW on
connections.
7,646.0 7,528.0
2/21/2024
00:00
2/21/2024
01:00
1.00 PROD1, DRILL PMPO T Pump OOH up into the 7-5/8" csg shoe
from 7,528' MD to 7,457' MD w/
GPM=263, PSI=1995, RPM=20,
TQ=5.5k, F/O=30%, P/U @ rate = 147K.
Maintaining 10.9 EMW on connections.
7,528.0 7,457.0
2/21/2024
01:00
2/21/2024
03:00
2.00 PROD1, DRILL CIRC T Rot and recip pipe from 7,457' MD to
7,363' MD w/ GPM=263, PSI=1905,
RPM=120, TQ=4.5k, F/O=30%, UP WT
- 157K, S/O WT - 129K, ROT WT - 140.
Total stks pumped = 6871(692 bbls).
Pumped 30 bbls low vis high weighted
followed by 30 bbls hi-vis sweep.
Observing small increase in cuttings at
the shakers upon returns to surface.
7,457.0 7,457.0
2/21/2024
03:00
2/21/2024
03:15
0.25 PROD1, DRILL CIRC T Obtain SPR's. Final T&D values. Blow
down the top drive.
7,457.0 7,457.0
2/21/2024
03:15
2/21/2024
03:30
0.25 PROD1, DRILL SMPD T Slowly bleed down annular psi in 50 psi
increments from 300 psi via MPD
chokes.
7,457.0 7,457.0
2/21/2024
03:30
2/21/2024
04:00
0.50 PROD1, DRILL OWFF T OWFF (static) 7,457.0 7,457.0
2/21/2024
04:00
2/21/2024
05:00
1.00 PROD1, DRILL WAIT T Phase 3 weather conditions. Monitor
wellbore via charge pump on #1 pump
through MPD choke. SIMOPS - clean
and clear the rig floor.
7,457.0 7,457.0
2/21/2024
05:00
2/21/2024
05:30
0.50 PROD1, DRILL CIRC T Drop 1.75 well commander activation
ball. Pump ball down @ GPM=84,
PSI=402. Ball on seat @ 313 stks.
Pressure up to 1220 and hold for 1min.
Increase to 2750 psi in 200 psi
increments holding ea pressure
increase 30 sec. Confirm open w/
GPM=263, PSI=900, F/O=25%
observing lower pressure at same gpm.
7,457.0 7,457.0
2/21/2024
05:30
2/21/2024
08:15
2.75 PROD1, DRILL CIRC T Rot and recip pipe from 7,457' MD to
7,363' MD. Stage pumps up to 450
GPM, ICP 900, FCP 2245 w/ 46% F/O,
120 RPM, 4.5K TQ. Total stks pumped
= 14,410(1451 bbls)
7,457.0 7,457.0
2/21/2024
08:15
2/21/2024
16:15
8.00 PROD1, DRILL WAIT T Phase 3 weather conditions. Monitor
wellbore via charge pump on #1 pump
through MPD choke. SIMOPS -
Housekeeping and light PM's on rig
equipment.
Phase 3 conditions lifted at 16:00 hrs.
7,457.0 7,457.0
2/21/2024
16:15
2/21/2024
17:00
0.75 PROD1, DRILL CIRC T Rot and recip pipe from 7,457' MD to
7,363' MD. Stage pumps up to 450
GPM, PSI 2455 w/ 46% F/O, 40 RPM,
4.5K TQ. Total stks pumped = 2,980
(300 bbls)
7,457.0 7,457.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 29/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/21/2024
17:00
2/21/2024
18:00
1.00 PROD1, DRILL CIRC T Drop 1.75 OD activation ball to close
well commander. Pump ball down @
GPM=84, PSI=485. Ball on seat @ 283
stks. Pressure up to 1100 and hold for
1min. Increase to 2360 psi in 500 psi
increments holding ea pressure
increase 30 sec. Confirm close w/
GPM=263, PSI=1967, F/O=35%
observing higher pressure at same gpm.
B/D top drive.
7,457.0 7,457.0
2/21/2024
18:00
2/21/2024
19:00
1.00 PROD1, DRILL RURD T Expedite BHA source box to the rig floor.
Expedite MPD trip nipple to the rig floor.
SIMOPS - ready rig floor for Stripping
OOH.
7,457.0 7,457.0
2/21/2024
19:00
2/21/2024
23:15
4.25 PROD1, DRILL SMPD T Strip OOH from 7,457' MD to 3,316' MD
racking back 2ea stds of 4" DP and 43
stds of 4" HWDP. Follow Beyond
stripping schedule staging up to 5400' hr
(90' min). Monitor disp via pits 1-3. Up
wt - 158K, Dn wt - 129K.
7,457.0 3,316.0
2/21/2024
23:15
2/22/2024
00:00
0.75 PROD1, DRILL SMPD T Strip OOH from 3,316' MD to 2,458' MD
racking back 10ea stds of 4" DP. Follow
Beyond stripping schedule staging up to
5400' hr (90' min). Monitor disp via pits
1-3. Up wt - 80K.
3,316.0 2,458.0
2/22/2024
00:00
2/22/2024
02:00
2.00 PROD1, DRILL SMPD T Strip OOH from 2,458' MD to 310' MD
racking back stds of 4" DP. Follow
Beyond stripping schedule staging up to
5400' hr (90' min). Monitor disp via pits
1-3. Up wt - 80K.
2,458.0 310.0
2/22/2024
02:00
2/22/2024
03:00
1.00 PROD1, DRILL OWFF T OWFF through Beyond manifold (static).
SIMOPS - PJSM on pulling MPD
bearing and install trip nipple.
310.0 310.0
2/22/2024
03:00
2/22/2024
04:45
1.75 PROD1, DRILL MPDA T Pull MPD bearing and install trip nipple. 310.0 310.0
2/22/2024
04:45
2/22/2024
05:30
0.75 PROD1, DRILL TRIP T POOH from 310' MD to 194' MD
standing back 2ea stnds of 4" DP.
310.0 194.0
2/22/2024
05:30
2/22/2024
09:30
4.00 PROD1, DRILL BHAH T L/D BHA as per SLB DD from 194' MD.
Remove source and well commander.
Monitor disp via pits 3-5.
194.0 0.0
2/22/2024
09:30
2/22/2024
10:45
1.25 PROD1, DRILL BHAH T Clean and clear rig floor. SIMOPS -
inspect saver sub.
0.0 0.0
2/22/2024
10:45
2/22/2024
11:15
0.50 PROD1, DRILL WWWH T Flush BOPE w/ 650 GPM, 75 PSI.
SIMOPS - function test annular, upper
and lower 3½" x 6" VBR's.
0.0 0.0
2/22/2024
11:15
2/22/2024
11:45
0.50 PROD1, DRILL BHAH T Mobilize production BHA #4 to the rig
floor.
0.0 0.0
2/22/2024
11:45
2/22/2024
12:00
0.25 PROD1, DRILL SFTY T PJSM on M/U of production BHA #4 with
rig crew, SLB DD, and CPAI rig
supervisor.
0.0 0.0
2/22/2024
12:00
2/22/2024
13:45
1.75 PROD1, DRILL BHAH T M/U production BHA #4 as per SLB DD
to 147' MD. Monitor disp via pits 3-5.
Dn Wt - 57k.
0.0 147.0
2/22/2024
13:45
2/22/2024
15:00
1.25 PROD1, DRILL TRIP T RIH with production BHA #4 from 147'
MD to 2,065' MD w/ 4" DP from the
derrick. Dn Wt - 75k. Monitor disp via
pits 3-5.
147.0 2,065.0
2/22/2024
15:00
2/22/2024
15:30
0.50 PROD1, DRILL DHEQ T Shallow hole test MWD tools w/ 250
GPM, 1270 PSI, 25% F/O (good).
2,065.0 2,065.0
2/22/2024
15:30
2/22/2024
19:15
3.75 PROD1, DRILL TRIP T RIH with production BHA #4 from 2,065'
MD to 7,340' MD w/ 4" DP/HWDP from
the derrick. Up Wt- 150k, Dn Wt - 113k.
Fill pipe every 20 stds. B/D top drive
after every fill. Monitor disp via pits 3-5.
2,065.0 7,340.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 30/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/22/2024
19:15
2/22/2024
20:00
0.75 PROD1, DRILL CIRC T Rot and recip pipe from 7,340' MD to
7,300' MD w/ 263 GPM, 2120 PSI, 20
RPM, 4K TQ. Up Wt - 156k, Dn Wt -
134k, Rot Wt - 144k. Total stks pumped
- 2276 (229 bbls).
7,340.0 7,340.0
2/22/2024
20:00
2/22/2024
20:30
0.50 PROD1, DRILL OWFF T OWFF (static). SIMOPS - PJSM on
pulling trip nipple and install MPD
bearing.
7,340.0 7,340.0
2/22/2024
20:30
2/22/2024
21:15
0.75 PROD1, DRILL MPDA T Pull trip nipple and install MPD bearing.
Up Wt - 156k, Dn Wt - 134k.
7,340.0 7,340.0
2/22/2024
21:15
2/23/2024
00:00
2.75 PROD1, DRILL TRIP T RIH with production BHA #4 from 7,340'
MD to 11,127' MD w/ 4" DP from the
derrick. Up Wt - 170K, Dn Wt - 100k.
Fill pipe every 20 stds, B/D top drive
after ea fill. Monitor disp via pits 3-5.
Leaving MPD "gut" line open bypassing
the chokes.
7,340.0 11,127.0
2/23/2024
00:00
2/23/2024
03:00
3.00 PROD1, DRILL TRIP T RIH with production BHA #4 from
11,127' MD to 14,986' MD w/ 4" DP from
the derrick. Up Wt - 157K, Dn Wt - 70k.
Fill pipe every 20 stds, B/D top drive
after ea fill. Monitor disp via pits 3-5.
Leaving MPD "gut" line open bypassing
the chokes.
11,127.0 14,986.0
2/23/2024
03:00
2/23/2024
11:15
8.25 PROD1, DRILL REAM T Loose slack off weight @ 14,986' MD.
Initiate rotation and pumps and RIH
from 14,986' MD to 17,453' MD with
GPM 265, PSI 2798, RPM 100, TQ 9k,
ECD 10.92 ppg, MWT 9.1 ppg, P/U
156k, S/O - NA, ROT 106k.
SIMOPS - Freeze protect 10-3/4" x 7-
5/8" OA via LRS. Pump 81 bbls of 6.8
ppg diesel staging pump up to 1/2 bpm.
Initial injection psi - 1250 @ 1/4 bpm.
FCP - 1175 @ 1/2 bpm. ISIP - 1175.
FSIP - 810 after 20 min. Pump
additional 5 bbls at 1/2 bpm. FCP -
1250. ISIP - 1245. FSIP - 803 after 20
min. Bleed off 3 bbls observe OA psi @
420. Leaving 83 bbls in OA.
14,986.0 17,453.0
2/23/2024
11:15
2/23/2024
15:45
4.50 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 17,453'
MD to 17,655' / 5,204' TVD, WOB 2k,
GPM 280, PSI 3120, RPM 100, TQ
10.5k, ECD 10.98 ppg, MWT 9.1+ ppg,
P/U 174k, S/O - NA, ROT 108k, ADT
2.9, Total bit hrs 2.9, Max gas = 252
units. Maintaining 10.9 ppg EMW with
MPD @ connections.
17,453.0 17,655.0
2/23/2024
15:45
2/23/2024
17:15
1.50 PROD1, DRILL BKRM P BROOH due to high DLS of 6-5°, from
17,655' MD to 17,365' MD w/ GPM 280,
PSI 3095, RPM 100, TQ 10k, ECD
11.04 ppg, MWT 9.1+ ppg, ROT 104k
@ rate.
17,655.0 17,365.0
2/23/2024
17:15
2/23/2024
19:00
1.75 PROD1, DRILL REAM P Ream in the hole from 17365' MD to
17,655' MD w/ GPM 280, PSI 3160,
RPM 100, TQ 10k, ECD 11.03 ppg,
MWT 9.1+ ppg, DnWt @ rate - 105k.
17,365.0 17,655.0
2/23/2024
19:00
2/24/2024
00:00
5.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 17,655'
MD to 18,031' / 5,195' TVD, WOB 6k,
GPM 280, PSI 3169, RPM 100, TQ
11.8k, ECD 11.06 ppg, MWT 9.1+ ppg,
P/U 152k, S/O - NA, ROT 104k, ADT
4.41, Total bit hrs 7.70 Max gas = 78
units. Maintaining 10.9 ppg EMW with
MPD @ connections.
17,655.0 18,031.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 31/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/24/2024
00:00
2/24/2024
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 18,031'
MD to 18,573' / 5,197' TVD, WOB 5k,
GPM 280, PSI 3243, RPM 120, TQ 12k,
ECD 11.14 ppg, MWT 9.1+ ppg, P/U
164k, S/O - NA, ROT 105k, ADT 4.96,
Total bit hrs 12.66, Max gas = 58 units.
Maintaining 10.9 ppg EMW with MPD @
connections.
18,031.0 18,573.0
2/24/2024
06:00
2/24/2024
12:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 18,573'
MD to 18,720' / 5,194' TVD, WOB 1k,
GPM 276, PSI 3153, RPM 100, TQ 11k,
ECD 11.05 ppg, MWT 9.1+ ppg, P/U
171k, S/O - NA, ROT 110k, ADT 5.09,
Total bit hrs 17.75, Max gas = 214 units.
Maintaining 10.9 ppg EMW with MPD @
connections.
18,573.0 18,720.0
2/24/2024
12:00
2/24/2024
18:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 18,720'
MD to 18,926' / 5,194' TVD, WOB 10k,
GPM 276, PSI 3210, RPM 100, TQ 14k,
ECD 11.14 ppg, MWT 9.1+ ppg, P/U
171k, S/O - NA, ROT 110k, ADT 4.37,
Total bit hrs 22.12, Max gas = 114 units.
Maintaining 10.9 ppg EMW with MPD @
connections.
18,720.0 18,926.0
2/24/2024
18:00
2/25/2024
00:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 18,926'
MD to 19,367' / 5,189' TVD, WOB 9k,
GPM 276, PSI 3284, RPM 100, TQ 13k,
ECD 11.20 ppg, MWT 9.1+ ppg, P/U
180k, S/O - NA, ROT 110k, ADT 4.64,
Total bit hrs 26.76, Max gas = 137 units.
Maintaining 10.9 ppg EMW with MPD @
connections.
SIMOPS - C/O keeper on upper jaw
spinner assembly on ST-100.
18,926.0 19,367.0
2/25/2024
00:00
2/25/2024
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 19,367'
MD to 19,823' / 5,183' TVD, WOB 4k,
GPM 276, PSI 3305, RPM 100, TQ
12.7k, ECD 11.27 ppg, MWT 9.1+ ppg,
P/U 177k, S/O - NA, ROT 113k, ADT
4.69, Total bit hrs 31.45, Max gas = 40
units. Maintaining 10.9 ppg EMW with
MPD @ connections.
19,367.0 19,823.0
2/25/2024
06:00
2/25/2024
10:30
4.50 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 19,823'
MD to production section TD of 20,119'' /
5,181' TVD, WOB 5k, GPM 276, PSI
3382, RPM 100, TQ 13.5k, ECD 11.31
ppg, MWT 9.1+ ppg, P/U 179k, S/O -
NA, ROT 115k, ADT 3.83, Total bit hrs
34.83, Max gas = 54 units. Maintaining
10.9 ppg EMW with MPD @
connections.
19,823.0 20,119.0
2/25/2024
10:30
2/25/2024
12:00
1.50 PROD1, TRIPCAS CIRC P Circ B/U while reciprocating full stand.
GPM 276, PSI 3321, RPM 100, TQ
11.5k, ECD 11.18 ppg, MWT 9.1+ ppg,
ROT P/U 175k, ROT S/O 108k. Pump
up final survey and downlink neutral
command to directional tools.
20,119.0 20,119.0
2/25/2024
12:00
2/25/2024
15:15
3.25 PROD1, TRIPCAS CIRC P Perform well bore clean up for 3X B/U.
GPM 276, PSI 3255, RPM 150, TQ 12k,
ECD 11.10 ppg, MWT 9.1+ ppg, ROT
P/U 170k. Obtain final T&D Parameters
and SPR's. L/D two stands drill pipe via
90' mouse hole from 20,119' to 19,921'
20,119.0 19,921.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 32/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/25/2024
15:15
2/26/2024
00:00
8.75 PROD1, TRIPCAS BKRM P BROOH from 19,921' to 17,797' MD @
150-750 ft/hr with GPM 276, ICP 3191,
FCP 3160, RPM 150, TQ 12k, (I)ECD
11.10 ppg, (F)ECD 11.08, MWT 9.1+
ppg, Up Wt @ rate - 106K. Maintain
10.9 EMW at connections via MPD.
Observe pump pressure fluctuations @
18,730', 18,469', 18,342', 18,200',
17,776'.
SIMOPS - L/D 4" DP stds via 90'
mousehole.
Note: Observe pulverized cuttings at
the shakers.
Formation losses last 24 hours: 0 bbls
Total interval formation losses: 0 bbls
19,921.0 17,797.0
2/26/2024
00:00
2/26/2024
06:00
6.00 PROD1, TRIPCAS BKRM P BROOH from 17,797' to 16,040' MD @
500-900 ft/hr with GPM 276, PSI 2921,
RPM 150, TQ 11k, ECD 10.65, MWT 9.1
ppg, Up Wt @ rate - 111K. Maintain
10.7 EMW at connections via MPD.
SIMOPS - L/D 4" DP stds via 90'
mousehole.
Note: Observe pulverized cuttings at
the shakers.
17,797.0 16,040.0
2/26/2024
06:00
2/26/2024
12:00
6.00 PROD1, TRIPCAS BKRM P BROOH from 16,040' to 14,150' MD @
900 ft/hr with GPM 276, PSI 2735, RPM
120, TQ 9k, ECD 10.47, MWT 9.1 ppg,
Up Wt @ rate - 110K. Maintain 10.5
EMW at connections via MPD.
SIMOPS - L/D 4" DP stds via 90'
mousehole.
Begin to weight up to 9.5 ppg via 12.0
ppg spike fluid @ 14,242' MD.
Note: Observe pulverized cuttings at
the shakers.
16,040.0 14,150.0
2/26/2024
12:00
2/26/2024
18:00
6.00 PROD1, TRIPCAS BKRM P BROOH from 14,150' to 12,200' MD @
900 ft/hr with GPM 276, PSI 2800, RPM
120, TQ 8k, ECD 10.94, MWT 9.5 ppg,
Up Wt @ rate - 121K. Maintain 10.8
EMW at connections via MPD.
SIMOPS - L/D 4" DP stds via 90'
mousehole.
Note: Observe pulverized cuttings at
the shakers.
14,150.0 12,200.0
2/26/2024
18:00
2/27/2024
00:00
6.00 PROD1, TRIPCAS BKRM P BROOH from 12,200' to 10,169' MD @
900 ft/hr with GPM 276, PSI 2921, RPM
130, TQ 11k, ECD 10.65, MWT 9.5 ppg,
Up Wt @ rate - 131K. Maintain 10.8
EMW at connections via MPD.
SIMOPS - L/D 4" DP stds via 90'
mousehole.
Note: Observe pulverized cuttings at
the shakers.
Formation losses last 24 hours: 0 bbls
Total interval formation losses: 0 bbls
12,200.0 10,169.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 33/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/27/2024
00:00
2/27/2024
06:00
6.00 PROD1, TRIPCAS BKRM P BROOH from 10,169' MD to 8,095' MD
@ 900 ft/hr with GPM 276, PSI 2390,
RPM 130, TQ 6k, ECD 10.5 ppg, MWT
9.5 ppg, Up Wt @ rate - 130K.
Maintain 10.6 EMW at connections via
MPD.
SIMOPS - L/D 4" DP stds via 90' mouse
hole.
10,169.0 8,095.0
2/27/2024
06:00
2/27/2024
09:00
3.00 PROD1, TRIPCAS BKRM P BROOH from 8,095' MD to inside 7-5/8"
casing @ 7,440' MD @ 900 ft/hr with
GPM 276, PSI 2390, RPM 130, TQ 6k,
ECD 10.5 ppg, MWT 9.5 ppg, Up Wt @
rate - 130K. Maintain 10.6 EMW at
connections via MPD. (Had to rotate
BHA into casing with 15 rpm).
SIMOPS - L/D 4" DP stds via 90' mouse
hole.
8,095.0 7,440.0
2/27/2024
09:00
2/27/2024
12:00
3.00 PROD1, TRIPCAS CIRC P Drop 1-3/4" activation ball and open well
commander, GPM 82, PSI 520. Shifted
well commander open with 1600 PSI.
Stage up flow rate to GPM 500, PSI
2900. Reciprocate full stand with RPM
100 - 130, TQ 4 - 5 k, ROT wt 140k and
perform well bore cleanup. Pump 30
bbls low vis 8.7 ppg un-weighted sweep
followed by 30 bbls 11.5 ppg weighted
sweep. Saw a moderate increase in
PDC cuttings on shakers during first two
B/Us. No signs of well bore instability
observed at surface. Circ to total of 5X
B/Us. Drop 1-3/4" closing ball and close
well commander with 1800 PSI.
Continue to circ GPM 276, PSI 2296.
Observed good MWD signal and
confirm well commander closed.
SIMOPS - Troubleshoot ST-100 Iron
Roughneck for 2 hours.
7,440.0 7,440.0
2/27/2024
12:00
2/27/2024
12:45
0.75 PROD1, TRIPCAS OWFF P Perform MPD now flow test and relax
formation. Open well up for few secs,
shut in and monitor pressure 3X. No
pressure build up. Open up 2" at RCD
and OWFF for 30 min (static). Line up
MPD and prep to StripOOH.
7,440.0 7,440.0
2/27/2024
12:45
2/27/2024
19:00
6.25 PROD1, TRIPCAS SMPD P StripOOH from 7,440' MD to 930' MD @
90 ft/min mantaining 9.7 ppg EMW.
Rack back 4" DP and 4" HWDP in
derrick. P/U ~ 63k.
7,440.0 930.0
2/27/2024
19:00
2/27/2024
20:30
1.50 PROD1, TRIPCAS MPDA P MPD flow check. Observe zero pressure
build up. Open well observe flow - well
static. PJSM. Pull drip nipple as per
Beyound Rep. Pull RCD bearing to rig
floor.
930.0 930.0
2/27/2024
20:30
2/27/2024
22:00
1.50 PROD1, TRIPCAS MPDA P PJSM. Remove RCD bearing from drill
pipe. Install trip nipple as per Beyond
Rep. Lay down drip nipple via beaver
slide.
930.0 930.0
2/27/2024
22:00
2/27/2024
23:00
1.00 PROD1, TRIPCAS TRIP P TOOH from 930' MD to 175' MD with 4"
drill pipe racking pipe in derrick. P/U ~
46k. Monitoring displacement via trip
tank.
930.0 175.0
2/27/2024
23:00
2/28/2024
00:00
1.00 PROD1, TRIPCAS BHAH P Lay Down 6.5" directional BHA as per
SLB DD from 175' MD to 105' MD.
PJSM Remove Radioactive sources at
105' MD.
175.0 105.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 34/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/28/2024
00:00
2/28/2024
02:00
2.00 PROD1, TRIPCAS BHAH P Lay Down 6 .5" directional BHA as per
SLB DD from 105' MD.
105.0 0.0
2/28/2024
02:00
2/28/2024
04:00
2.00 PROD1, TRIPCAS BHAH P Clean and clear floor of BHA
components and handling equipment.
0.0 0.0
2/28/2024
04:00
2/28/2024
08:30
4.50 COMPZN, CASING RURD P Mobilize casing tools and equipment to
rig floor. Prep top drive for Volant 4-1/2"
CRT. M/U Volant to top drive and torque
to spec. R/U 4-1/2" handling equipment
and double stack power tongs. Bring
Baker and Interra frac sleeves to rig
floor. Drift and stage in order as per
CoMan, Baker, and Interra reps. QC all
lower completion jewelry in pipe shed
and prep shed for running liner.
0.0 0.0
2/28/2024
08:30
2/28/2024
09:00
0.50 COMPZN, CASING SFTY P PJSM with all personnel for running
lower completion.
0.0 0.0
2/28/2024
09:00
2/28/2024
11:45
2.75 COMPZN, CASING PUTB P Run 4-1/2" 12.6# P110S Hyd 563 lower
liner completion to 1,292' MD. Monitor
displacement on pit #1. P/U 63k / S/O
60k. QC all swell packers, frac sleeves
and proper M/U torque to diamond
before running below rotary table.
0.0 1,292.0
2/28/2024
11:45
2/28/2024
12:15
0.50 COMPZN, CASING OWFF P Perform 30 min inflow test to confirm
floats are holding
1,292.0 1,292.0
2/28/2024
12:15
2/28/2024
13:45
1.50 COMPZN, CASING PUTB P Run 4-1/2" 12.6# P110S Hyd 563 lower
liner completion from 1,292' MD to
2,107' MD. Monitor displacement on pit
#1. P/U 64k / S/O 60k. QC all swell
packers, frac sleeves and proper M/U
torque to diamond before running below
rotary table.
1,292.0 2,107.0
2/28/2024
13:45
2/28/2024
14:15
0.50 COMPZN, CASING OWFF P Perform 30 min inflow test to confirm
floats are holding
2,107.0 2,107.0
2/28/2024
14:15
2/28/2024
18:00
3.75 COMPZN, CASING PUTB P Run 4-1/2" 12.6# P110S Hyd 563 lower
liner completion from 2,107' MD to 4461'
MD. Monitor displacement on pit #1. P/U
65k / S/O 66k. QC all swell packers, frac
sleeves and proper M/U torque to
diamond before running below rotary
table. Running speed 80ft/min.
2,107.0 4,461.0
2/28/2024
18:00
2/29/2024
00:00
6.00 COMPZN, CASING PUTB P Run 4-1/2" 12.6# P110S Hyd 563 lower
liner completion from 4461' MD to 7628'
MD. Monitor displacement on pit #1. P/U
75k / S/O 71k. QC all swell packers, frac
sleeves and proper M/U torque to
diamond before running below rotary
table. Running speed 80ft/min. Obtain
T&D P/U 75k, S/O 71k, ROT 72k, TQ 20
RPM 2.7k TQ 30 RPM 2.9K. @ 7372'
MD
4,461.0 7,628.0
2/29/2024
00:00
2/29/2024
01:00
1.00 COMPZN, CASING PUTB P Run 4-1/2" 12.6# P110S Hyd 563 lower
liner completion from 7,628' MD to
8,100' MD @ 80' ft/min max and monitor
displacement on pit #1. P/U 78k / S/O
66k. QC all swell packers, frac sleeves
and proper M/U torque to diamond
before running below rotary table.
7,628.0 8,100.0
2/29/2024
01:00
2/29/2024
01:30
0.50 COMPZN, CASING OWFF P Perform 30 min inflow test to confirm
floats are holding.
8,100.0 8,100.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 35/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/29/2024
01:30
2/29/2024
06:00
4.50 COMPZN, CASING PUTB P Run 4-1/2" 12.6# P110S Hyd 563 lower
liner completion from 8,100' MD to
10,027' MD @ 80' ft/min max and
monitor displacement on pit #1. P/U
79k / S/O 67k. QC all swell packers, frac
sleeves and proper M/U torque to
diamond before running below rotary
table. (Lost slack off weight at 9,876'
and had to rotate with 30 RPM / 4k Trq
to 9,881').
T&D Check @ 9,660' = P/U 79k, S/O
71k, ROT 73k, 20 & 30 RPM 3.5 k Trq.
8,100.0 10,027.0
2/29/2024
06:00
2/29/2024
12:30
6.50 COMPZN, CASING PUTB P Run 4-1/2" 12.6# P110S Hyd 563 lower
liner completion from 10,027' MD to
12,800' MD (294 joints in the hole) @
80' ft/min max and monitor displacement
on pit #1. P/U 79k / S/O 67k. QC all
swell packers, frac sleeves and proper
M/U torque to diamond before running
below rotary table. (Lost slack off weight
at 10,637' and had to rotate with 20
RPM / 4k Trq to 10,672') (Rotated last 3
joints w/15 RPM / 4k Trq) SIMOPS - R/D
4-1/2" elevators and dog bones and
install 4" DP elevators on last joint.
T&D Check @ 10,964' = P/U 78k, S/O
67k, ROT 71k, 20 & 30 RPM 3.5 k Trq.
10,027.0 12,800.0
2/29/2024
12:30
2/29/2024
12:45
0.25 COMPZN, CASING RURD P R/D Volant CRT and 4-1/2" handling
equipment.
12,800.0 12,800.0
2/29/2024
12:45
2/29/2024
13:30
0.75 COMPZN, CASING OTHR P M/U SLZXP as per Baker reps and fill
with PAL mix. RIH to 12,840' MD. (Had
to work liner through dog legs).
12,800.0 12,840.0
2/29/2024
13:30
2/29/2024
19:45
6.25 COMPZN, CASING RUNL P RIH with 4-1/2" 12.6# P110S Hyd 563
lower liner completion assy on 4"
DP/HWDP from 12,840' MD to 18145'
MD @ 80 ft/min max. Continue to run
liner fully evacuated monitoring
displacement on pit #1. Collect T&D
data every 10 stands. Lost block weight.
Make up top drive and rotate.
T&D Check @ 16492' = P/U108 k, S/O
82k, ROT 85, 20 & 30 RPM 6k Trq.
12,840.0 18,145.0
2/29/2024
19:45
3/1/2024
00:00
4.25 COMPZN, CASING RUNL P Rotating down each stand at 20 RPM.
RIH with 4-1/2" 12.6# P110S Hyd 563
lower liner completion assy on 4"
DP/HWDP from 18145' MD to 19110'
MD. Continue to run liner fully
evacuated monitoring displacement on
pit #1. Collect T&D data every 10
stands.
T&D Check @ 19092' = P/U 130k, S/O
72k, ROT 92k, 20 & 30 RPM 6.9 to 9.0k
Trq.
18,145.0 19,110.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 36/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/1/2024
00:00
3/1/2024
04:30
4.50 COMPZN, CASING RUNL P RIH with 4-1/2" 12.6# P110S Hyd 563
lower liner completion assy on 4"
DP/HWDP, rotating each stand at 20
rpm with no issues from 19,110' MD to
set depth of 20,118'' MD. Continue to
run liner fully evacuated monitoring
displacement on pit #1. Collect T&D
data every 10 stands. Tag bottom at
20,119' with 10k WOB, pick up 1' and
space out on depth at 20,118' MD
T&D Check @ 20,118' = P/U 155k, S/O
N/A, ROT 124k, 20 & 30 RPM 7.5 to
9.0k Trq.
19,110.0 20,118.0
3/1/2024
04:30
3/1/2024
06:00
1.50 COMPZN, CASING RURD P Rig up to fill pipe and bleed air with
closed loop burping manifold assy. M/U
TIW, head pin, 1502 T, lotorq valves,
cement hose and bleeder hose to mud
manifold. Prep for filling liner.
Troubleshoot mud pumps. Mud lines
frozen in the centrifugal room. Thaw out
lines.
20,118.0 20,118.0
3/1/2024
06:00
3/1/2024
07:30
1.50 COMPZN, CASING CIRC P Fill drill pipe and liner with 9.5 ppg
KlaShield at 5 bpm, while continuously
pumping down drill string with cement
hose and letting air u-tube and burp out
through bleeder line. Pump calculated
275 bbls, plus an additional 50 bbls for
325 bbls total. Shut down and OWFF
(static).
20,118.0 20,118.0
3/1/2024
07:30
3/1/2024
12:15
4.75 COMPZN, CASING DISP P Displace entire wellbore from 9.5 ppg
KlaShield to 9.5 ppg FWP at 2 bpm /
1100 PSI. Pumped 30 bbl high vis
spacer followed by 780 bbls FWP.
20,118.0 20,118.0
3/1/2024
12:15
3/1/2024
15:15
3.00 COMPZN, CASING DISP T Continued to circ and condition mud and
get mud properties in spec.(Adjust pH,
add biocide, and oxygen scavenger)
Once properties were in spec going
down hole pumped 550 bbls to spot
good mud in open hole at 3 bpm / 1300
PSI.
20,118.0 20,118.0
3/1/2024
15:15
3/1/2024
15:45
0.50 COMPZN, CASING RURD P B/D lines and R/D closed loop manifold
assembly. R/D head pin and TIW.
20,118.0 20,118.0
3/1/2024
15:45
3/1/2024
18:00
2.25 COMPZN, CASING PACK P Drop 1.125" primary WIV ball. M/U
working single. Pick up to 215 k max (no
pipe movement). S/O to 88k (no pipe
movement). Pull pipe in tension with
170k. Pump 10 BBLS high vis pill and
chase with 9.5 PPG FWP at 3 BPM /
800 PSI for 150 BBLS. Slow down to 1.5
BPM / 380 PSI for last 100 BBLS. Shut
down pumps and relax string. Bring
pumps up @ 2bbl/min for 200 strokes.
Shut down and bleed off pressure.
20,118.0 7,285.0
3/1/2024
18:00
3/1/2024
21:00
3.00 COMPZN, CASING PACK P Pumps on @ 2.5 BPM / 728 PSI for 300
strokes. Shut down and bleed off.
Pumps on @ 3-3.5 BPM / 910-1124 PSI
for 600 strokes. Ball on seat at 360 bbls
total. (calculated 240 bbls) Pressure up
to 2800 PSI and hold for 10 min. Set
SLZXP. Slack off and stack 50k WOB.
Pressure up to 4000 PSI and hold for 10
minutes. Pick up to neutral. Close upper
pipe rams and test liner top packer to
3850 PSI for 10 minutes (Good Test).
7,285.0 7,285.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 37/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/1/2024
21:00
3/2/2024
00:00
3.00 COMPZN, WELLPR DISP P Space out above liner top. Pump 30bbl
high vis spacer and displace well from
9.5 PPG FWP to 9.5 PPG CI 3%
KCL/NACL @ 3-5 BPM, PSI = 327-802,
F/O = 15-25%, total pumped: 449
BBLS.
7,285.0 7,285.0
3/2/2024
00:00
3/2/2024
01:00
1.00 COMPZN, WELLPR DISP P Continue to displace to 9.5 PPG CI 3%
KCL/NACL @ 4 BPM, PSI = 508, F/O =
15%. Total displacement bbls pumped:
662 bbls.
7,285.0 7,285.0
3/2/2024
01:00
3/2/2024
01:30
0.50 COMPZN, WELLPR OWFF P OWFF (static). SIMOPS - Service rig
and PJSM on L/D drill pipe.
7,285.0 7,285.0
3/2/2024
01:30
3/2/2024
06:00
4.50 COMPZN, WELLPR PULD P POOH while laying down drill pipe from
7,285' MD to 3,741' MD. Inspect tool
joints for damage and hard band wear.
Monitor hole fill via trip tank. P/U 100k.
7,285.0 3,741.0
3/2/2024
06:00
3/2/2024
11:00
5.00 COMPZN, WELLPR PULD P POOH while laying down drill pipe from
3,741' MD to surface. Inspect tool joints
for damage and hard band wear.
Monitor hole fill via trip tank. Inspect and
lay down liner running tools. All
indications show running tools
functioned properly.
3,741.0 0.0
3/2/2024
11:00
3/2/2024
12:00
1.00 COMPZN, WELLPR RURD P Clean and clear floor from tripping
activities. M/U wear ring puller. Pull wear
ring as per Cameron rep. Mobilize
tubing hanger to rig floor.
0.0 0.0
3/2/2024
12:00
3/2/2024
13:30
1.50 COMPZN, WHDBOP WWWH P M/U stack washer and flush stack.
Function upper/lower pipe rams and
annular.
0.0 0.0
3/2/2024
13:30
3/2/2024
15:00
1.50 COMPZN, WHDBOP RURD P Set test plug as per Cameron rep. R/U
to test BOPE's. Purge air from system
and perform shell test to 4000 PSI.
0.0 0.0
3/2/2024
15:00
3/2/2024
22:00
7.00 COMPZN, WHDBOP BOPE P Test BOPE - all tests to 250 low 4,000
high for 5 charted minutes with
exception of manual operated & super
choke tested to 250 low & 2000 psi for 5
charted minutes & annular tests to 3500
psi, with 4.5" test jt. Test annular with 4-
1/2" test jt test 3-1/2" x 6" upper rams &
3-1/2" x 6" Lower rams, test choke
valves 1-14, manual operated & super
choke, choke & kill manuals & HCRs, 4"
valve on kill line, 4" FOSV x2, 4" dart
valve, upper & lower IBOP; blind/ shear
rams; perform Koomey drawdown, acc
= 3000 psi, manifold = 1550 psi, acc =
1850 psi after all functions on bottles, 10
seconds for 200 psi build with 2 electric
pumps, 50 seconds to build a full
system pressure with 2 electric & 2 air
pumps, 6 bottle average=1978, closing
times - annular = 15 sec, upper rams =
7 sec, blind / shears = 7 sec, Lower
rams = 7 sec. choke HCR = 2 sec, kill
HCR = 2 sec. Test PVT gain/loss and
flow out alarms, test LEL and H2S
alarms. AOGCC Rep Brian Bixby
wavied witness @ 19.53 hrs on 3-1-24.
0.0 0.0
3/2/2024
22:00
3/2/2024
23:00
1.00 COMPZN, WHDBOP RURD P R/D testing equipment, pull test plug,
laydown test joint, drain stack. Blow
down all service lines. Clean and clear
rig floor.
0.0 0.0
3/2/2024
23:00
3/3/2024
00:00
1.00 COMPZN, RPCOMP RURD P PJSM. Rig up HES spool and control
line. R/U Doyon casing crew and
equipment.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 38/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/3/2024
00:00
3/3/2024
03:00
3.00 COMPZN, RPCOMP RURD P Mobilize 4-1/2" handling equipment and
power tongs to rig floor. R/U HES TEC
spool. Hang sheave and stage cannon
claps and clamping tools. R/U power
tongs and 4-1/2" handling equipment.
PJSM on running upper completion.
SIMOPS - C/O drag chain paddles and
rig town tank farm pump skid.
0.0 0.0
3/3/2024
03:00
3/3/2024
03:30
0.50 COMPZN, RPCOMP PUTB P RIH 4-1/2" 12.6# L-80 Hyd563 upper
completion tubing to 254' MD. Fill pipe
with fill up hose on the fly every joint and
top off every 10 joints. Monitor
displacement on pit #1.
0.0 254.0
3/3/2024
03:30
3/3/2024
04:15
0.75 COMPZN, RPCOMP PUTB P M/U Halliburton OPSIS Gauge Mandrel
and test to 10,000 PSi for 10 min
(good).
254.0 254.0
3/3/2024
04:15
3/3/2024
06:00
1.75 COMPZN, RPCOMP PUTB P RIH 4-1/2" 12.6# L-80 Hyd563 upper
completion tubing from 254' MD to
1,274' MD. Fill pipe with fill up hose on
the fly every joint and top off every 10
joints. Monitor displacement on pit #1.
Continuously monitor pressure and
connectivity with HES downhole gauge.
S/O 65k.
254.0 1,274.0
3/3/2024
06:00
3/3/2024
12:00
6.00 COMPZN, RPCOMP PUTB P RIH 4-1/2" 12.6# L-80 Hyd563 upper
completion tubing from 1,274' MD to
5,950' MD. Fill pipe with fill up hose on
the fly every joint and top off every 10
joints. Monitor displacement on pit #1.
Continuously monitor pressure and
connectivity with HES downhole gauge.
Perform 10,000 PSI test on DHG every
50 joints. S/O 65k.
1,274.0 5,950.0
3/3/2024
12:00
3/3/2024
15:00
3.00 COMPZN, RPCOMP PUTB P RIH 4-1/2" 12.6# L-80 Hyd563 upper
completion tubing from 5,950' MD to
7,290' MD and fully locate. Saw shear
out of pins w/5 k WOB and fully locate
w/20 k WOB. Fill pipe with fill up hose
on the fly every joint and top off every
10 joints. Monitor displacement on pit
#1. Continuously monitor pressure and
connectivity with HES downhole gauge.
Perform 10,000 PSI test on DHG every
50 joints. P/U 110k / S/O 91k.
POOH from 7,290' MD to 7,168' MD and
prepare for space out (170 joints in the
hole).
5,950.0 7,168.0
3/3/2024
15:00
3/3/2024
16:45
1.75 COMPZN, RPCOMP HOSO P Mobilize space out pups from KCS
warehouse and make up pups on top of
joint 170. P/U last full joint #171 and RIH
from 7,168' to 7,248' MD. P/U 110k /
S/O 91k.
7,168.0 7,248.0
3/3/2024
16:45
3/3/2024
19:00
2.25 COMPZN, RPCOMP THGR P M/U tubing hanger and terminate
Halliburton TEC wire. Pressure test TEC
wire ports to 5000 PSI. M/U landing joint
assembly and RIH and land hanger on
depth 1.6' from fully located at 7,288.89'.
RILDS and pressure test tubing hanger
seals to 5000 PSI for 15 min.
7,248.0 0.0
3/3/2024
19:00
3/3/2024
20:30
1.50 COMPZN, RPCOMP RURD T Trouble shoot pressure sensor. Found
calibration was off causing sensor not to
read on Totco system. SIMOPS: Rig
down Doyon casing equipment and HES
control lines spool.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 39/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/3/2024
20:30
3/3/2024
22:30
2.00 COMPZN, RPCOMP PACK P Pressure test 4.5" tubing and set HES
packer @ 4550 PSI. Hold for 30
minutes. Bleed pressure down to 2000
PSI. Pressure test IA to 3850 PSI and
hold for 30 minutes - 3/BBLS pumped.
Bleed down IA to 3000 PSI. Dunp tubing
preesure to 0 PSI to shear SOV ( Good)
- bleed back 3/BBLS.
0.0 0.0
3/3/2024
22:30
3/4/2024
00:00
1.50 COMPZN, RPCOMP RURD P Rig down test equipment. Blow down
cement line. Lay down spooling unit and
remaining upper completion control line
clamps.
0.0 0.0
3/4/2024
00:00
3/4/2024
02:00
2.00 COMPZN, RPCOMP RURD P Continue to attempt to back out landing
joint from tubing hanger. Landing joint
backed out at XO from DP to tubing
pup. Mouse hole partial landing joint
assy. M/U T-bar and BPV assembly and
attempt to RIH to set "HP BPV". OD of
BPV would not fit inside tubing pup. L/D
BPV and T-bar assembly. Call town and
WSC to discuss plan forward options.
SIMOPS - B/D mud lines, jet lines and
hole fill lines. Pull trip nipple and N/D
riser. R/D tank farm and rock washer.
0.0 0.0
3/4/2024
02:00
3/4/2024
09:00
7.00 COMPZN, RPCOMP RURD T R/U vac hose and water hose. Wash out
top of tubing pup and vacuum out any
debris and excess water. P/U partial
landing joint assy and bakerlok pin end
of XO. RIH and make up to tubing pup
and chain tong tight. Let bakerlok cure.
SIMOPS - R/D MPD lines and catch
can. break loose RCD head bolts and
prep tools and equipment to N/D
BOPE's. L/D mouse hole. Flush mud
lines and clean pits. Service rig, draw
works and top drive. Prep to test BPV in
direction of flow.
0.0 0.0
3/4/2024
09:00
3/4/2024
09:30
0.50 COMPZN, RPCOMP RURD P Back out landing joint. All components
recovered successfully. Break out TIW
from landing joint and L/D to pipe shed.
0.0 0.0
3/4/2024
09:30
3/4/2024
10:00
0.50 COMPZN, RPCOMP MPSP P M/U T-bar and BPV assembly. RIH and
set "HP BPV". L/D T-bar assembly.
Pressure test HP BPV in direction of
flow to 2500 PSI and chart for 10 min on
Totco. (good). Blow down injection and
testing lines.
0.0 0.0
3/4/2024
10:00
3/4/2024
12:00
2.00 COMPZN, WHDBOP NUND P N/D MPD RCD head and orbit valve.
(left orbit valve on RCD) N/D choke and
kill lines from BOPE stack.
0.0 0.0
3/4/2024
12:00
3/4/2024
15:00
3.00 COMPZN, WHDBOP NUND P N/D BOPE's. Rack back on BOPE
pedestal and secure for rig move.
Remove DSA's from well head and
stage in BOPE mezz deck. SIMOPS -
Clean pits, rock washer, and cuttings
tank. Remove lower jaw on ST100 and
send to shop for repair.
0.0 0.0
3/4/2024
15:00
3/4/2024
18:00
3.00 COMPZN, WHDBOP NUND P N/U tree adaptor and terminate TEC
wire. Test adaptor void 250/5000 PSI
(good). N/U frac tree and orient. CPAI
and pad operator witness.
0.0 0.0
3/4/2024
18:00
3/4/2024
20:30
2.50 COMPZN, WHDBOP PRTS P Fluid pack frac tree with diesel pressure
test lines to 10000K. Pressure test tree
250 low for 5 minutes and 5000 high for
10 minutes. Pressures test tree to
10000 PSI for 5 minutes. (Good Test)
5000 psi test did not pass.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
Page 40/40
3S-606
Report Printed: 3/28/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/4/2024
20:30
3/4/2024
21:30
1.00 COMPZN, WHDBOP PRTS P Rig back up and fluid pack test lines and
re-test frac tree to 5000 psi as per CPAI.
Attempt to test frac test to 5000 PSI, 10k
test pump leaking at pump air modules,
bled off pressure and rig down pump.
0.0 0.0
3/4/2024
21:30
3/4/2024
23:15
1.75 COMPZN, WHDBOP PRTS P Rig up LRS to pressure test frac tree to
250 PSI low, 5000 PSI high,
unsuccessful test bleed pressure and rig
down LRS.
0.0 0.0
3/4/2024
23:15
3/5/2024
00:00
0.75 COMPZN, WHDBOP PRTS P Rig up rig 5000k test pump and lines
from rig floor to frac tree. Thaw lines, Fill
lines with diesel and purge air from
lines,
0.0 0.0
3/5/2024
00:00
3/5/2024
01:30
1.50 COMPZN, WHDBOP RURD P Rig down LRS and rig up BOP test
pump, fluid pack lines and shell test rig
equipment.
0.0 0.0
3/5/2024
01:30
3/5/2024
04:00
2.50 COMPZN, WHDBOP PRTS P Pressure test 10K frac tree to t 5,000 psi
for 5 minutes using the BOP test pump
and chart on recorder.
0.0 0.0
3/5/2024
04:00
3/5/2024
06:00
2.00 COMPZN, WHDBOP FRZP P Freeze protect well with LRS with 90
bbls of diesel. Pump at 1.25 BPM down
the IA taking returns to the cellar thru
the tubing until good diesel is seen.
Shutdown and shut in IA and tubing .
Rig down LRS.
0.0 0.0
3/5/2024
06:00
3/5/2024
08:00
2.00 DEMOB, MOVE RURD P Rig down LRS, Rig down freeze protect
return manifold, Magtec vac out cellar
and clean up cellar area. Install H/BPV.
Remove all 1502 lines and service
valves from OA and IA, Secure tree and
install 10k gauges on frac tree.
0.0 0.0
3/5/2024
08:00
3/5/2024
12:00
4.00 DEMOB, MOVE DMOB P PJSM complete rig move checklist as
per SOP. Unplug all modules, clear all
landing prep and retract breezeways
and transitions. Prep motor, pump,
pipeshed, rockwasher for trucks.
Release rig at 12:00 hrs
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 3/5/2024
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-<& %&<- -&%) -<)&' & )&--) & %2//2/%-& '- 2%&- &/ & < &%=)()*
<--& & ' & ' <-%&- &% )<&<<) & %2//2/ & '- 2 & )& &<) &%=)()*
/-&< <&% &< /- &% '& '&'/ %& %2//2/--& '- 2%& )&- '/& - &%=)()*
)2 )&/ <&' '& )2 ))& '<&/ -& /'%&/ %2//2/<& '- 2&' & %'&/< .?=@?:? (*
)2) <&% <& < & ' )2) '&- )&% &)2 /&' %2//2//%& '- 2) & &' <&/) .?=@?:? (*
)2 &/ /&-) &%' )2)/<&/ -%& ' &')2)&% %2//'2 <&- '- 2 /&) )& <&/ .?=@?:? (*
)2/ &/ ))& / /&% )2/ & </&/ '/&))2'&/ %2//'2 & '- 2 &% &) ) &<% .?=@?:? (*
)2</&< )'&// /&<) )2< &- ) <&' %/&/)2)%& %2//'2 '& '- 2</&- & ))&< .?=@?:? (*
)2'<%&/ )-& /& )2'-& ))&' -&')2' -& %2//'2 %& '- 2- & &' )'-&/ .?=@?:? (*
)2%< & )<&/ &'- )2% &' )% &- <<&))2'/-&) %2//'2 / &% '- 2 )&- )&< )- &%% .?=@?:? (*
)2 -'&< )&'/ )&</ )2 %)&' )<%&' ) &<)2%< & %2//'2))/& '- 2' &) &< <&-% .?=@?:? (*
)2- /& '&- &% )2-<& )<&) ))&))2 -& %2//'2)%& '- 2<&/ &' '%& .?=@?:? (*
)2< &< & & )2<)& %%&/ )')&<)2-%%&/ %2//'2)</&/ '- 2 <&' %&- <-& - .?=@?:? (*
)2/%-& %&< )&/ )2/ &< &/ ) &<)2<%&' %2//'2%& '- 2)<&% &) <&% .?=@?:? (*
2 %& %&) &' )2/-<&) '/& )/&<)2/)&- %2//'2<&< '- 2)%-& &< /&- .?=@?:? (*
2)' &< -&'< &'/ 2 %'& /<&- )/& )2/<<& %2//'2&/ '- 2))& & ''-&-% .?=@?:? (*
2')&- '& <&% 2) &< '%)&) % &%2 )&' %2//'2<%&' '- 2) & %& % -&- .?=@?:? (*
2%& '&// /&'/ 2)/%& % %&% <&2) & %2//'2'/&/ '- 2 -&< )& % /&) .?=@?:? (*
2'/&) ' & /&< 2 &% % & ) &'2)/-&) %2//'2'/ &< '- 2 '&- & &% .?=@?:? (*
2%& '/&- &) 2%&- &< %)&2 & %2//'2%%-&' '- 2 &) &/ - & .?=@?:? (*
2 )-&% %'&)- &'- 2<&- <-& <-&<2)<&' %2//'2 & '-%2/ &- '&- --'&- .?=@?:? (*
2-)&) %'&- &<- 2'/& -%'&) '%&'2-& %2//'2 <<&/ '-%2/ & &' <% & - .?=@?:? (*
2< -& %%&' &%/ 2'/&< <& ' &'2'<&% %2//'2-% &/ '-%2<<<&% )& / &% .?=@?:? (*
2<&< %%&-% &/ 2% & <&/ '- &)2'-&< %2//'2- <&/ '-%2<<)&/ &- //&/ .?=@?:? (*
2/ -&- %-& &'/ 2%'/&- </'&/ % '&2'<'& %2//'2</&/ '-%2<'-&/ )& )2 <&%/ . =15A(*
2/)& % &- & 2%% &/ / '&% % /&<2'/)&% %2//'2</& '-%2<'&' &% )2 )/&'/ .?=@?:? ('*
%#4 =
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2 /%&< %& < &- 2 %-&) )2 <& %<)&-2%/)&< %2//'2/ & '-%2-- &/ )& )2)%/&- .?=@?:? ('*
2)</&/ %&%% <&- 2-)& )2 /& &)2 '-& %2//%2 /&) '-%2-&- )&' )2&<' .?=@?:? ('*
2<'&/ %& /&' 2- /&' )2)%/& %/&'2- '& %2//%2 /'&- '-%2 /& &% )2 <&' .?=@?:? ('*
2< &- %&% /&) 2< & )2%&' /<&/2- &/ %2//%2) )& '-%2 %'&' & )2<&- .?=@?:? ('*
2'-&' %& % /& 2<< &- )2<<&< - &-2<)%& %2//%2'& '-%2 ) &< & )2'%%&<< .?=@?:? ('*
2% -& %&% <&<- 2/-&) )2%'& -- & 2<-)&- %2//%2/ & '-%2%--&- & )2% &'- .?=@?:? ('*
2 )&- %& /&- 2//&) )2')/&' <)%& 2/-&- %2//%2%%&' '-%2%<&/ &' )2 '& .?=@?:? ('*
2-% & %&-- &/< 2 '/& )2'<%&' <%&/2/<& %2//%2')&% '-%2% )& )&% )2 -/&)' .?=@?:? ('*
2<% &% %&< )&)' 2) '&- )2%%& <</&-2 /& %2//%2'<<& '-%2' '& & )2-%'& - .?=@?:? ('*
2/''& %&%- )&-) 2) & )2 )<&% /%&/2 /'&/ %2//%2%%'&< '-%2'<& & )2<<&% .?=@?:? ('*
'2 -&< %& )&%' 2)%&< )2 <'&- / )&-2)% &' %2//%2 )&) '-%2/& & )2/ & - .?=@?:? ('*
'2)&/ %'&- )&% 2-& )2-%& //<&-2 &/ %2//%2 </&% '-%2% & &- )2/-/&) .?=@?:? ('*
.?=@?:? ('* .?=@?:? ('* .?=@?:? ('* .?=@?:? ('*InterpolatedInterpolated #
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'2<& %'&' )&< 2-&' )2< & )2 %&'2 & %2//%2-%-& '-%2)/&< &) 2 %'& < .?=@?:? ('*
'2&/ %'& )&'- 2<& )2<<-&- )2 -&)2)-& %2//%2<'&% '-%2<& & 2) &- .?=@?:? ('*
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'2/< &) %'&) <& 2--& 2'-&% )2'<&%2- &/ %2// 2<%&) '-%2 <& & 2 %'& .?=@?:? ('*
%2 < &< %&/) /&' 2<-&/ 2')& )2<<&2- & %2// 2% &< '-'2/ <&< &/ 2-<&-' .?=@?:? ('*
%2)-%& %'& /&- 2<<&% 2'-<&< )2'-&)2<)<&) %2// 2') & '-'2/ & &' 2< &/ .?=@?:? ('*
%2 /&- %'& )& 2//& 2%'%& )2' '&<2<-& %2// 2'<& '-'2</& )&) 2<-<&/ .?=@?:? ('*
%2 '&/ %&/< &'- 2//%& 2 )&) )2% )&2//& %2// 2%%)& '-'2<% &' )& 2/%'& .?=@?:? ('*
%2'%<&< %&</ )&/- '2 % & 2 < & )2% &-2/<'&< %2// 2 )<&' '-'2<)& &' 2 /&)< .?=@?:? ('*
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%2-'&) %&/% &)' '2)-&- 2<<&/ )2 '%& '2)%& %2// 2<)& '-'2-)& & 2%%&-) .?=@?:? ('*
%2<<& %'& &)/ '2-&% 2/% &- )2 < &/'2 <&) %2// 2<</& '-'2 --&/ &) 2)&' .?=@?:? ('*
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Page 1/1
3S-606
Report Printed: 3/28/2024
Cement
Cement Details
Description
Surface String Cement
Cementing Start Date
1/31/2024 03:00
Cementing End Date
1/31/2024 06:30
Wellbore Name
3S-606
Comment
Pump 5 bbls fresh water. Test lines to 3500 psi. Pump 60 bbls of spacer w/ poly flake and red dye @ 3.8 BPM, PSI = 230. F/O - 5%. Load bottom plug. (Cmt Wet
@ 03:30hrs) Batch up and pump 472 BBLS 10.7 PPG ArticCem lead cement with BMII - pump rate 6 BPM, 298 PSI, 9% F/O. HES batch tail, (tail wet @ 5:20)
Pump 56.72 BBLS of 15.8ppg tail cement @ 3.88 BPM, 551 PSI, 6% F/O. Drop top plug. Chase plug with 20 bbls of water from HES. Line up rig pumps.
Displace cement at 6 BPM, ICP - 552, Reduce rate @ 2000 stks to 4 BPM, FCP - 585. Bump plug @ 2508 strokes (261.4 bbls). CIP @ 0630 hrs. Pressure up to
1114 psi and hold for 5 min. Bleed off and check floats (good). Observe 252 bbls of 10.7 cement returned to surface. 0 losses during cement job.
Cement Stages
Stage # 1
Description
Surface String Cement
Objective Top Depth (ftKB)
40.1
Bottom Depth (ftKB)
2,921.8
Full Return?
Yes
Vol Cement …
310.0
Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
6
Q Pump Final (bbl/…
2
Q Pump Avg (bbl/…
6
P Pump Final (psi)
1,113.0
P Plug Bump (psi) Recip?
No
Stroke (ft) Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
Pump 5 bbls fresh water. Test lines to 3500 psi. Pump 60 bbls of spacer w/ poly flake and red dye @ 3.8 BPM, PSI = 230. F/O - 5%. Load bottom plug. (Cmt Wet
@ 03:30hrs) Batch up and pump 472 BBLS 10.7 PPG ArticCem lead cement with BMII - pump rate 6 BPM, 298 PSI, 9% F/O. HES batch tail, (tail wet @ 5:20)
Pump 56.72 BBLS of 15.8ppg tail cement @ 3.88 BPM, 551 PSI, 6% F/O. Drop top plug. Chase plug with 20 bbls of water from HES. Line up rig pumps.
Displace cement at 6 BPM, ICP - 552, Reduce rate @ 2000 stks to 4 BPM, FCP - 585. Bump plug @ 2508 strokes (261.4 bbls). CIP @ 0630 hrs. Pressure up to
1114 psi and hold for 5 min. Bleed off and check floats (good). Observe 310 bbls of 10.7 cement returned to surface. 0 losses during cement job.
Cement Fluids & Additives
Fluid
Fluid Type
Lead Cement
Fluid Description Estimated Top (ftKB)
40.1
Est Btm (ftKB)
2,421.0
Amount (sacks)
871
Class
Blend
Volume Pumped (bbl)
470.0
Yield (ft³/sack)
2.92
Mix H20 Ratio (gal/sack)
14.94
Free Water (%) Density (lb/gal)
10.20
Plastic Viscosity (cP)
0.0
Thickening Time (hr)
0.00
CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Fluid
Fluid Type
Tail Cement
Fluid Description Estimated Top (ftKB)
2,421.0
Est Btm (ftKB)
2,921.8
Amount (sacks)
275
Class
Blend
Volume Pumped (bbl)
56.0
Yield (ft³/sack)
1.16
Mix H20 Ratio (gal/sack)
4.98
Free Water (%) Density (lb/gal)
15.80
Plastic Viscosity (cP)
0.0
Thickening Time (hr)
0.00
CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Surface String Cement
Page 1/1
3S-606
Report Printed: 3/28/2024
Cement
Cement Details
Description
Intermediate String 1 Cement
Cementing Start Date
2/11/2024 04:00
Cementing End Date
2/11/2024 06:38
Wellbore Name
3S-606
Comment
Flood lines with 5 bbls of water @ 2 bpm, 100 psi and kick out lower wiper plug. PT lines to 4000 psi (good). Pump 61 bbls of tuned 10.5 ppg prime spacer @ 3-
5 bpm 430 psi, 15% f/o. Kick out 2nd plug with 111 bbls of 15.3 ppg cement (with BMII, cement wet @ 04:40) @ 3 bpm, ICP - 300, FCP - 294, 17% f/o. Pump 29
bbls of 15.3 ppg cement(without BMII) @ 3 bpm 294 psi (140 bbls total cement). Drop top plug and chase with 20 bbls of fresh water @ 5 bpm, 169 psi, 12% f/o.
Line rig pumps and chase cement with 9.6 treated FWP @ 8 bpm, 61 psi, 24% f/o. Catch cement @ 1883 strokes (189 bbls). Observe psi climb to 150. Reduce
rate to 6 bpm, 700 psi, 27% f/o. Observe pressure climb to 1184 psi @ 3000 stks. Reduce rate to 3 bpm, 1025 psi. Bump plug @ 3132 stks (315 bbls). Increase
pressure to 1500 and hold for 5 min. Bleed off pressure and check floats (good). CIP @ 6:38 hrs.
Cement Stages
Stage # 1
Description
Intermediate String 1
Cement
Objective
Place cement ~250'
above Coyote formation
Top Depth (ftKB)
3,950.0
Bottom Depth (ftKB)
7,470.0
Full Return?
Yes
Vol Cement …
0.0
Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
3
Q Pump Final (bbl/…
3
Q Pump Avg (bbl/…
6
P Pump Final (psi)
1,000.0
P Plug Bump (psi)
1,025.0
Recip?
Yes
Stroke (ft)
18.00
Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
61 bbls 10.5 spacer
111 bbls 15.3 with BMII
29 bbls 15.3 without BMII
20 bbls H2O to kick out top plug
Chase with rig - 183 bbls to catch cement
Bump plug with 315 bbls (calculated - 321)
Cement Fluids & Additives
Fluid
Fluid Type
Intermediate Cement
Fluid Description Estimated Top (ftKB)
5,045.0
Est Btm (ftKB)
7,470.0
Amount (sacks)
622
Class
G
Volume Pumped (bbl)
140.0
Yield (ft³/sack)
1.25
Mix H20 Ratio (gal/sack)
5.56
Free Water (%) Density (lb/gal)
15.30
Plastic Viscosity (cP) Thickening Time (hr)
5.50
CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Intermediate String 1 Cement
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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?KRU 3S-606
Yes No
9. Property Designation (Lease Number):10. Field:
Kuparuk F Torok Oil Pool
11.
Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
Casing Collapse
Structural
Conductor
Surface 2470
Intermediate 4790
Production 7850
Liner 9210
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:Manabu Nozaki
3/6/2024 Contact Email:
Manabu.Nozaki@cop.com
Contact Phone: 907-265-6519
Authorized Title:
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other Conditions of Approval:
Post Initial Injection MIT Req'd? Yes No
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
Manabu Nozaki
Subsequent Form Required:
Suspension Expiration Date:
Will perfs require a spacing exception due to property boundaries?
Current Pools:
MPSP (psi):Plugs (MD):
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
Tubing Size:
PRESENT WELL CONDITION SUMMARY
AOGCC USE ONLY
11590
Tubing Grade:Tubing MD (ft):
TNT Packer: 7151' MD / 5022' TVD
SLZXP: 7285' MD / 5082' TVD
Perforation Depth TVD (ft):
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL380107 / ADL380106 / ADL025528 / ADL393883
223-085
P.O. Box 100360 Anchorage, Alaska, 99510-0360 50-103-20870-00-00
ConocoPhillips Alaska, Inc.
Length Size
Proposed Pools:
L-80
TVD Burst
7289 MD / 5085 TVD (ft)
10860
MD
6890
5210
235
2558
4730
235
2922
51487-5/8"
20"
10-3/4"
235
7-5/8"6615
2922
7466
Perforation Depth MD (ft):
6615
851
4-1/2"
14-Mar-24
2011812833
4-1/2"
5181
Halliburton TNT Production Packer
Baker SLZXP Liner Packer, no SSSV
m
n
P
2
6
5
6
t
_
N
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
By Samantha Coldiron at 8:35 am, Mar 08, 2024
324-150
10-404X
CDW 03/12/2024
A.Dewhurst 12MAR24
X
VTL 03/11/2024
14-Mar-24
DSR-3/11/24
223-111
*&:
Brett W. Huber,
Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2024.03.12 15:29:50
-08'00'3/12/24
RBDMS JSB 031324
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
Section 2 – Plat 20 AAC 25.283 (2)(A)
Plat 1: Wells within 1/2 mile
Superseded by updated plat showing location of fault between and parallel to 3S-617
and 3S-624. -A.Dewhurst 12MAR24
Table 1: Wells within 1/2 miles (2)(C)
3S-606 Frac Sundry Well - Wells within 1/2 Mile Buffer of Well Track
Business
Unit ID
Business
Area ID Field Name API * Well Name Status Symbology
Well in Frac
Port 1/2 mi
Buffer
Open Interval in
Frac Port 1/2 mi
Buffer
KUP KRU KUPARUK RIVER UNIT 501032045800 3S-03 SUSP Suspended
KUP KRU KUPARUK RIVER UNIT 501032045400 3S-06 PA Plugged and Abandoned Well is P&A Well is P&A
KUP KRU KUPARUK RIVER UNIT 501032045401 3S-06A PA Plugged and Abandoned Well is P&A Well is P&A
KUP KRU KUPARUK RIVER UNIT 501032043000 3S-07 ACTIVE Oil
KUP KRU KUPARUK RIVER UNIT 501032045000 3S-08 PA Plugged and Abandoned
KUP KRU KUPARUK RIVER UNIT 501032045001 3S-08A PA Plugged and Abandoned
KUP KRU KUPARUK RIVER UNIT 501032045002 3S-08B PA Plugged and Abandoned
KUP KRU KUPARUK RIVER UNIT 501032045003 3S-08C ACTIVE Oil
KUP KRU KUPARUK RIVER UNIT 501032045060 3S-08CL1 ACTIVE Oil
KUP KRU KUPARUK RIVER UNIT 501032045070 3S-08CL1PB1 PA Plugged and Abandoned
KUP KRU KUPARUK RIVER UNIT 501032043200 3S-09 ACTIVE Injector Miscible Water Alternating Gas
KUP KRU KUPARUK RIVER UNIT 501032044000 3S-10 PA Plugged and Abandoned
KUP KRU KUPARUK RIVER UNIT 501032043900 3S-14 PA Plugged and Abandoned Well is P&A Well is P&A
KUP KRU KUPARUK RIVER UNIT 501032044400 3S-15 PA Plugged and Abandoned Well is P&A Well is P&A
KUP KRU KUPARUK RIVER UNIT 501032044500 3S-16 ACTIVE Injector Miscible Water Alternating Gas
KUP KRU KUPARUK RIVER UNIT 501032044800 3S-17 PA Plugged and Abandoned
KUP KRU KUPARUK RIVER UNIT 501032044801 3S-17A PA Plugged and Abandoned
KUP KRU KUPARUK RIVER UNIT 501032043300 3S-18 SUSP Suspended
KUP KRU KUPARUK RIVER UNIT 501032046000 3S-19 SUSP Suspended
KUP KRU KUPARUK RIVER UNIT 501032045200 3S-21 PA Plugged and Abandoned
KUP KRU KUPARUK RIVER UNIT 501032044600 3S-22 SUSP Suspended
KUP KRU KUPARUK RIVER UNIT 501032045300 3S-23 PA Plugged and Abandoned
KUP KRU KUPARUK RIVER UNIT 501032045301 3S-23A SUSP Suspended
KUP KRU KUPARUK RIVER UNIT 501032045600 3S-24 PA Plugged and Abandoned
KUP KRU KUPARUK RIVER UNIT 501032045601 3S-24A PA Plugged and Abandoned
KUP COYOTR01 TRACT OPERATION COYOTR01 501032045602 3S-24B PA Plugged and Abandoned
KUP KRU KUPARUK RIVER UNIT 501032036101 3S-26 PA Plugged and Abandoned
KUP MORTR04 TRACT OPERATION MORTR04 501032077400 3S-611 ACTIVE Oil YES
KUP MORTR04 TRACT OPERATION MORTR04 501032077470 3S-611PB1 PA Plugged and Abandoned
KUP MORTR04 TRACT OPERATION MORTR04 501032077700 3S-612 ACTIVE Injector Miscible Water Alternating Gas YES
KUP MORTR03 TRACT OPERATION MORTR03 501032073500 3S-613 ACTIVE Injector Produced Water
KUP MORTR05 TRACT OPERATION MORTR05 501032084400 3S-615 ACTIVE Oil
KUP MORTR05 TRACT OPERATION MORTR05 501032086400 3S-617 PROP Proposed YES (New drill) YES
KUP MORTR02 TRACT OPERATION MORTR02 501032069500 3S-620 ACTIVE Oil
KUP MORTR06 TRACT OPERATION MORTR06 501032086800 3S-624 PROP Proposed YES (New drill) YES
KUP MORTR05 TRACT OPERATION MORTR05 501032084200 3S-625 ACTIVE Injector Produced Water
KUP COYOTR02 TRACT OPERATION COYOTR02 501032084700 3S-701 PA Plugged and Abandoned
KUP COYOTR02 TRACT OPERATION COYOTR02 501032084701 3S-701A ACTIVE Injector Produced Water
KUP COYOTR03 TRACT OPERATION COYOTR03 501032084800 3S-704 ACTIVE Oil
NAK OU OOOGURUK UNIT 501032066000 NDST-02 SUSP Suspended Well is P&A Well is Suspended
NAK OU OOOGURUK UNIT 501032066070 NDST-02PB1 PA Plugged and Abandoned Well is P&A Well is P&A
KUP KRU KUPARUK RIVER UNIT 501032036100 PALM 1 PA Plugged and Abandoned
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.
None as per Aquifer Exemption Title 40 CFR 147.102(b)(3), “That portions of the aquifers on
the North Slope described by a ¼ mile area beyond and lying directly below the Kuparuk
River Unit oil and gas producing field”.
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.
Top Coyote 5545' MD / 4101' TVD)
3S-606 Wellbore Schematic
Grassroots Horizontal Moraine Injector
10-¾" 45.5# L80 H563 2922' MD / 2558' TVD 57° Inc
20" Conductor 235' MD
4-½" 12.6# P110S H563 20118' MD / 5181' TVD 90° Inc
4-½”12.6# L80 H563-MS9-и" Intermediate Hole
6-1/2" Production Hole
13-½" Surface Hole
03/04/2024
4-½” x 6" OD Swell Packer Frac sleeve
Sp
u
d
M
u
d
3.750", DB Nipple 7,217’ MD / 5,053’ TVD
SLZXP Liner Top Packer & Hanger 7,285' MD / 5,082’ TVD
4-½” x 7-з " HAL TNT Packer 7,151’ MD / 5,022’ TVD
SonicScope TOC 3950' MD / 3164' TVD
HAL Opsis Mandrel 7,045’ MD / 4,969’ TVD
Top Moraine 7544' MD / 5172' TVD
Gas Lift Mandrel, 4-½” x 1” 2,114’ MD / 2,027’ TVD
Wellbore Isolation Valve
Alpha Sleeve
Gas Lift Mandrel, 4-½” x 1” 6,935’ MD / 4,911’ TVD
6-½” TD 20119' MD / 5181' TVD 90° Inc
7-з" 33.7# P-110S H563 (heavy heel) 6615' - 7336' MD
7-з" 29.7# L-80 H563 7466' MD / 5148' TVD 72° Inc
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:
10 & 3/4” casing cement pump report on 1/31/2024 shows that the original job pumped as
designed. The cement job was pumped with 472 barrels of 10.7 ppg lead cement and 56
barrels 15.8 ppg tail cement, displaced with 9.8 ppg mud. The plug bumped at 1114 psi and
the floats held. Cement returns came to surface.
The 7 & 5/8” casing cement report on 2/11/2024 shows that the job was pumped as designed,
indicating competent cementing operations. The cement job was pumped with 111 barrels of
15.3 ppg with BM-II (Bridge Maker II), followed with 29 barrels of 15.3 ppg without BMII. The
plug was bumped, pressure increased to 1500 psi and held for 5 minutes. A cement bond log
indicates competent cement with a cement top @ 3,950 MD (3,164’ TVD).
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 2/2/2024 the 10-3/4” casing was pressure tested to 3,000 psi for 30 minutes
On 2/12/2024 the 7-5/8” casing was pressure tested to 4,000 psi for 30 minutes.
On 3/3/2024 the 4-1/2” tubing was pressure tested to 4,550 psi. Good Test
On 3/3/2024 the 7-5/8” casing by 4.5 tubing annulus was pressure tested to 3,850 psi. Good
Test
AOGCC Required Pressures [all in psi]
Maximum Predicted Treating Pressure (MPTP) 7,075
Annulus pressure during frac 3,500
Annulus PRV setpoint during frac 3,600
7-5/8" Annulus pressure test 3,850
4-1/2" Tubing pressure Test 4,550
Electronic PRV 8,075
Highest pump trip 7,575
SECTION 8 – PRESSURE RATINGS AND SCHEMATICS FOR THE
WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC
25.283(a)(8)
Size Weight, ppf Grade API Burst, psi API Collapse, psi
10-3/4” 45.5 L-80 5,209 2474
7-5/8” 29.7 L-80 6,885 4,789
7-5/8” 33.7 P-110 10,860 7,870
4-1/2” 12.6 L-80 8,430 7,500
Table 2: Wellbore pressure ratings
Stimulation Surface Rig-Up
Kuparuk 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, the Torok Oil Pool, has an average thickness of approximately 240 ft TVD
over the course of the lateral section of well 3S-606, from where it intersects the top formation
at 7,544’ MD to TD of the well. The Torok Oil Pool is comprised of thinly interbedded sandstone,
siltstone, and silty shale layers. The sandstone and siltstone components are litharenites,
moderately to well sorted, and very fine grained. The silty shales are composed of clay-rich,
moderately to poorly sorted silt and clay. The estimated fracture pressure for the Moraine
interval is approximately 12.5-13.5 ppg.
The overlying confining interval of the Torok Formation consists of mudstones and siltstones
with an average thickness of approximately 795’ TVD. The top of the Torok confining intervals
starts at 4,564’ TVDSS (6,437’ MD). The estimated fracture gradient of the overlying Torok
formation is approximately 0.82 psi/ft.
The underlying confining zone below the Base Moraine consists of lower Torok, HRZ, and
Kalubik shales totaling approximately 500’ TVD. The estimated fracture gradient for this section
ranges from 15-18 ppg, with the gradient increasing down section. The Base Moraine is
estimated from seismic to be at 5,265 ft TVDSS at the heel, and 5,250’ ft TVDSS at the toe of
the well.
The estimated formation pressure within the Torok Oil Pool is 2285psi at a depth of 5200’
TVDSS.
SECTION 10 – LOCATION, ORIENTATION AND A REPORT ON
MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT
CONFINING ZONE 20 AAC 25.283(a)(10)
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:
3S-06 & 3S-06A: ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations
on 3S-06 and 3S-06A (sidetrack from 3S-06 on 5/14/2003), commencing operations on
9/4/2023 and completing the Plug and Abandonment on 10/16/2023. The top cement job was
performed on 9/30/2023. The casing was cemented with TOC at 5,215’ MD (tag depth).
3S-14: ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations on 3S-14,
commencing operations on 8/92023 and completing the Plug and Abandonment on January
18, 2024. The top cement job was performed on 12/24/2023. The casing was cemented with
TOC at 3,514’ MD (tag depth).
3S-15: The well is targeting Kuparuk formation. The well is completely plugged and abandoned
per state regulations on 9/8/2020. Per Form 10-407 report on the AOGCC website, casing was
cemented with TOC at 297’ MD based on observation from THA (Tubing Head Adapter). Top
cement job was performed to surface on 8/30/2020. The 7” CBL log data was re-evaluated.
The log was run from 7,650’ to 8,202’ MD. The effective top of the CBL was 7,807’ MD where
the WLEG was entered. The top of quality cement is confirmed at 8,130’ MD (5,923’ TVDRKB),
above this poor cement distribution was seen to the WLEG. We have no data to evaluate
cement coverage across the Moraine and Coyote intervals. However, given the vertical and
longitudinal orientation of our planned stimulation operations in both zones, the hydraulic
fractures will not intersect the 3S-15 well in either the Moraine or Coyote sand.
Source: 202-254 - Laserfiche WebLink (state.ak.us)
3S-611: The 7-5/8” casing cement report on 10/13/2018 shows that the job was pumped as
designed, indicating competent cementing operations. 12.5 ppg MPII was pumped before
dropping bottom plug, this was then chased with 15.8 ppg Class G cement and the top plug
was dropped. This was chased with 9.4 ppg LSND mud. The plug bumped, pressured up to
1500 psi and held for 5 min. Floats were checked and they held.
3S-612: The 7-5/8” casing cement report on 11/4/2018 shows that the job was pumped as
designed, indicating competent cementing operations. 12.5 ppg MPII was pumped before
dropping bottom plug, this was then chased with 15.8 ppg Class G cement and the top plug
was dropped. This was chased with 9.5 ppg LSND mud. The plug bumped, pressured up to
1500 psi and held for 5 min. Floats were checked and they held.
3S-617: The 7 & 5/8” casing cement report on 11/5/2023 shows that the job was pumped as
designed, indicating competent cementing operations. The cement job was pumped with 142
barrels of 15.3 ppg. The plug was not bumped. Pressure was being monitored and no pressure
built up indicating that the floats held. A cement bond log indicates competent cement with a
cement top @ 3,841’ MD (3,157’ TVD).
3S-624: The 7-5/8” casing cement report on 12/24/2023 shows that the job was pumped as
designed, indicating competent cementing operations. The cement job was pumped with 125
barrels of 15.3ppg primary cement with LCM and 22 barrels of 15.3ppg primary cement without
LCM. The plug was bumped and the floats held. A cement bond log indicates competent
cement with a cement top @ 3,435’ MD (2,778’ TVD).
NDST-02PB1: According to the Pioneer Natural Resources Operation Summary Report on the
AOGCC website, on 1/30/2013, the bottom plug was pumped with 254 sxs of Premium
Cement. TOC was tagged at 8,012’ MD. On 1/31/2013, the top plug was pumped with 60 bbl
of 17ppg Premium Class G Cement was pumped. Tagged firm cement at 5,236’ MD.
Source: 212-163- Laserfiche WebLink (state.ak.us)
NDST-02: According to the Pioneer Natural Resources Operation Summary Report on the
AOGCC website, the 7-5/8” casing was cemented on 2/8/2013. The cement report indicates
that the job was pumped with 60 bbl of 15.8ppg Premium Cement with 3% Halad (R)-344 low
fluid loss control. Full circulation was seen throughout the entire job. Frac operations could not
be completed because a lodged ball damaged the tubing, and 60 bbl of CaCO3 was spotted
on 4/13/2013. On 4/14/2013, XX plug was set in nipple at 4,550’ WLMD. ConocoPhillips Alaska
Inc. re-entered on 1/3/2023, pulled the XX plug at 8,360’ CTMD (restriction) instead of at the
nipple and performed injectivity test at 0.5 bpm on 1/21/2023.
Source: 212-163- Laserfiche WebLink (state.ak.us)
SECTION 10 – LOCATION, ORIENTATION AND A REPORT ON
MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT
CONFINING ZONE 20 AAC 25.283(a)(10)
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:
3S-06 & 3S-06A: ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations
on 3S-06 and 3S-06A (sidetrack from 3S-06 on 5/14/2003), commencing operations on
9/4/2023 and completing the Plug and Abandonment on 10/16/2023. The top cement job was
performed on 9/30/2023. The casing was cemented with TOC at 5,215’ MD (tag depth).
3S-14: ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations on 3S-14,
commencing operations on 8/92023 and completing the Plug and Abandonment on January
18, 2024. The top cement job was performed on 12/24/2023. The casing was cemented with
TOC at 3,514’ MD (tag depth).
3S-15: The well is completely plugged and abandoned per state regulations on 9/8/2020. Per
Form 10-407 report on the AOGCC website, casing was cemented with TOC at 297’ MD based
on observation from THA (Tubing Head Adapter). Top cement job was performed to surface
on 8/30/2020.
Source: 202-254 - Laserfiche WebLink (state.ak.us)
3S-611: The 7-5/8” casing cement report on 10/13/2018 shows that the job was pumped as
designed, indicating competent cementing operations. 12.5 ppg MPII was pumped before
dropping bottom plug, this was then chased with 15.8 ppg Class G cement and the top plug
was dropped. This was chased with 9.4 ppg LSND mud. The plug bumped, pressured up to
1500 psi and held for 5 min. Floats were checked and they held.
3S-612: The 7-5/8” casing cement report on 11/4/2018 shows that the job was pumped as
designed, indicating competent cementing operations. 12.5 ppg MPII was pumped before
dropping bottom plug, this was then chased with 15.8 ppg Class G cement and the top plug
was dropped. This was chased with 9.5 ppg LSND mud. The plug bumped, pressured up to
1500 psi and held for 5 min. Floats were checked and they held.
3S-617: The 7 & 5/8” casing cement report on 11/5/2023 shows that the job was pumped as
designed, indicating competent cementing operations. The cement job was pumped with 142
barrels of 15.3 ppg. The plug was not bumped. Pressure was being monitored and no pressure
built up indicating that the floats held. A cement bond log indicates competent cement with a
cement top @ 3,841’ MD (3,157’ TVD).
3S-624: The 7-5/8” casing cement report on 12/24/2023 shows that the job was pumped as
designed, indicating competent cementing operations. The cement job was pumped with 125
barrels of 15.3ppg primary cement with LCM and 22 barrels of 15.3ppg primary cement without
Superseded by updated Section 10 with modified description of 3S-15. -A.Dewhurst 12MAR24
LCM. The plug was bumped and the floats held. A cement bond log indicates competent
cement with a cement top @ 3,435’ MD (2,778’ TVD).
NDST-02PB1: According to the Pioneer Natural Resources Operation Summary Report on the
AOGCC website, on 1/30/2013, the bottom plug was pumped with 254 sxs of Premium
Cement. TOC was tagged at 8,012’ MD. On 1/31/2013, the top plug was pumped with 60 bbl
of 17ppg Premium Class G Cement was pumped. Tagged firm cement at 5,236’ MD.
Source: 212-163- Laserfiche WebLink (state.ak.us)
NDST-02: According to the Pioneer Natural Resources Operation Summary Report on the
AOGCC website, the 7-5/8” casing was cemented on 2/8/2013. The cement report indicates
that the job was pumped with 60 bbl of 15.8ppg Premium Cement with 3% Halad (R)-344 low
fluid loss control. Full circulation was seen throughout the entire job. Frac operations could not
be completed because a lodged ball damaged the tubing, and 60 bbl of CaCO3 was spotted
on 4/13/2013. On 4/14/2013, XX plug was set in nipple at 4,550’ WLMD. ConocoPhillips Alaska
Inc. re-entered on 1/3/2023, pulled the XX plug at 8,360’ CTMD (restriction) instead of at the
nipple and performed injectivity test at 0.5 bpm on 1/21/2023.
Source: 212-163- Laserfiche WebLink (state.ak.us)
Superseded by updated Section 10 with modified description of 3S-15. -A.Dewhurst 12MAR24
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 a single fault transects the Torok Oil Pool reservoir within one half mile
radius of the 3S-606 wellbore trajectory. While the fault doesn’t intersect the 3S-617 or any
other nearby well trajectories, it is interpreted to have offset the toe section of the 3S-617 well
downwards by about 40ft. The fault trace has been mapped on seismic to run wellbore-parallel
between the 3S-617 and 3S-624 trajectories, as shown in Plat 1. It is interpreted to not affect
overburden integrity and therefore its presence will not interfere with containment.
If there is any indication that a fracture has intersected the mapped fault (or any other faults
unmapped to date) during fracturing operations, ConocoPhillips will go to flush and terminate
the stage immediately.
SECTION 12 – PROPOSED HYDRAULIC FRACTURING PROGRAM
20 AAC 25.283(a)(12)
3S-617 was completed in 2023 as a horizontal injector in the Torok 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 will be pumped through a toe initiator valve in the toe
of the lateral. After the 1st stage frac balls will be dropped to shift open the 2nd stage sleeve and
isolate the first stage. 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 pre-existing conditions.
2. Ensure the frac tree was tested to 10,000 psi on the rig.
3. Ensure all pre-frac Well work has been completed and confirm the tubing and annulus
are filled with a freeze protect fluid to 2,027’ TVD.
4. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC.
5. MIRU 30 clean insulated Frac tanks, with a berm surrounding the tanks that can hold
a single tank volume plus 10%. Load tanks with 100ºF 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 to 3,500 psi as the tubing pressures
up.
10. Perform DFIT after opening the Alpha Sleeve according to the attached pump
schedule. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to
shut down. Resume pumping to pump Frac Stage 1.
11. Perform minifrac test after opening the frac sleeve for Stage 2. Resume pumping to
pump Frac Stage 2.
12. Pump Frac Stages 3 through 9 by following attached pump schedule at ~37bpm with
a maximum expected treating pressure of 7,075 psi.
13. RDMO Halliburton Equipment. Freeze Protect the tubing and wellhead if not able to
complete following the flush.
14. The well is ready for Post Frac well prep/production tree installation and flowback for
21 days (after Slickline and Coiled Tubing Cleanout).
15. Swap the 5k production tree with the frac tree and test the Frac Tree to 10,000 psi.
16. Take the same steps to pump Frac Stages 10 through 24 as per the pump schedule.
17. The well is ready for Post Frac well prep/production tree installation and flowback for
21 days (after Slickline and Coiled Tubing Cleanout).
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.
Hydraulic Fracturing Fluid Product Component Information Disclosure
ProTechnics Division
6510 West Sam Houston Parkway North
Houston, Texas 77041
Phone: (346) 328-9474
North Slope
ATTN: Jeremiah Diaz
Hydraulic
Fracturing Fluid
Product
Component
Information
Disclosure
Supplier Purpose Ingredients
Chemical Abstract
Service Number (CAS
#)
Maximum Ingredient
Concentration in
Additive
(% by mass)**
Maximum Ingredient
Concentration in HF
Fluid
(% by mass)**
Comments
Ingredient
Volume
Pumped
Mass of
Additive
Pumped
S.G Manufacturer Contact
ZeroWash Tracer ProTechnics Diagnostics Ceramic Proppant proprietary 14.00%
Water (major) 7732-18-5 70.00%Core Laboratories
Methanol (major) 67-56-1 30.00%ProTechnics Division
Dipropylene glycol methyl ether (minor) 34590-94-8 1.00%HSE (346) 328-9474
Xanthan gum (minor) 11138-66-2 1.00%ATTN: Jeremiah Diaz
Jeremiah.Diaz@corelab.com
One ingredient in the Chemical Frac Tracer additive (Sodium Salt) and one ingredient in the ZeroWash Tracer additive (Ceramic Proppant) is trade secret.
For any questions contact regulatory compliance at (346) 328-9474
State:Alaska
County:
COP
Well Name and Number:3S-606
API Number:
1
Dewhurst, Andrew D (OGC)
From:Dewhurst, Andrew D (OGC)
Sent:Tuesday, March 12, 2024 13:23
To:Nozaki, Manabu
Cc:Loepp, Victoria T (OGC); Roby, David S (OGC); Wallace, Chris D (OGC); Davies, Stephen F (OGC); Guhl, Meredith D
(OGC); Hobbs, Greg S; Tejo, Baskoro
Subject:RE: [EXTERNAL]KRU 3S-606 Frac Sundry (PTD 223-085; Sundry 324-150): Question
Perfect. Thanks.
Andy
From: Nozaki, Manabu <Manabu.Nozaki@conocophillips.com>
Sent: Tuesday, March 12, 2024 13:16
To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>; Wallace, Chris D
(OGC) <chris.wallace@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC)
<meredith.guhl@alaska.gov>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Tejo, Baskoro
<Baskoro.Tejo@conocophillips.com>; Nozaki, Manabu <Manabu.Nozaki@conocophillips.com>
Subject: RE: [EXTERNAL]KRU 3S-606 Frac Sundry (PTD 223-085; Sundry 324-150): Question
Hi Andy,
Thanks again. Sorry for that we mirrored what we wrote for the 3S-617 frac sundry application to be consistent. It
makes sense to put the full description into the document.
As you suggested, we will not resubmit it to the permitting email address.
Regards,
Manabu
From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Sent: Tuesday, March 12, 2024 1:00 PM
To: Nozaki, Manabu <Manabu.Nozaki@conocophillips.com >
Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>; Wallace, Chris D
(OGC) <chris.wallace@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC)
<meredith.guhl@alaska.gov>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com >; Tejo, Baskoro
<Baskoro.Tejo@conocophillips.com>
Subject: RE: [EXTERNAL]KRU 3S-606 Frac Sundry (PTD 223-085; Sundry 324-150): Question
Manabu,
Thank you for the updated content For future reference, if there are small changes like this, it is not necessary to
resubmit the sundry applicaƟon to the permiƫng email address. You can send me the updates and I will ensure that the
updated pages are inserted into the original applicaƟon.
However, the descripƟon of the mechanical condiƟon of 3S-15 in the updated SecƟon 10 is currently insuĸcient. Would
you please add the content from your analysis into SecƟon 10? The only change I see is the sentence that 3S-15 targeted
the Kuparuk formaƟon.
You don't often get email from manabu.nozaki@conocophillips.com . Learn why this is important
2
Thanks,
Andy
From: Nozaki, Manabu <Manabu.Nozaki@conocophillips.com >
Sent: Tuesday, March 12, 2024 12:26
To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>; Wallace, Chris D
(OGC) <chris.wallace@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC)
<meredith.guhl@alaska.gov>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com >; Tejo, Baskoro
<Baskoro.Tejo@conocophillips.com>; Nozaki, Manabu <Manabu.Nozaki@conocophillips.com>
Subject: RE: [EXTERNAL]KRU 3S-606 Frac Sundry (PTD 223-085; Sundry 324-150): Question
Hi Andy,
Thank you for reviewing the KRU 3S-606 frac sundry.
We revised Sections 2 and 10 of the sundry application:
x Section 2 (Page 8) – Added the fault between the 3S-624 and 3S-617 (one described in Section 11) to Plat 1.
x Section 10 (Page 19) – Revised the section for the 3S-15. The 7” CBL log data was re-evaluated when we
prepared for the 3S-617 frac sundry application. The log was run from 7,650’ to 8,202’ MD. The effective top
of the CBL was 7,807’ MD where the WLEG was entered. The top of quality cement is confirmed at 8,130’ MD
(5,923’ TVDRKB), above this poor cement distribution was seen to the WLEG. We have no data to evaluate
cement coverage across the Moraine and Coyote intervals. However, give the vertical and longitudinal
orientation of our planned stimulation operations in both zones, the hydraulic fractures will not intersect the
3S-15 well in either the Moraine or Coyote sand.
Please let us know if you have any other comments or questions on these matters.
We will resubmit it through agocc.permitting@alaska.gov.
Best Regards,
Manabu Nozaki | Completions Engineer, Alaska Drilling & Wells | ConocoPhillips
O: +1-907-265-6519 | M: +1-907-917-9567 | ATO-1578, Anchorage, AK, USA
Email: Manabu.Nozaki@ConocoPhillips.com
From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Sent: Monday, March 11, 2024 4:42 PM
To: Nozaki, Manabu <Manabu.Nozaki@conocophillips.com >
Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>; Wallace, Chris D
(OGC) <chris.wallace@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC)
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attachments unless you recognize the sender and know the content is safe.
3
<meredith.guhl@alaska.gov>
Subject: [EXTERNAL]KRU 3S-606 Frac Sundry (PTD 223-085; Sundry 324-150): Question
CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you
recognize the sender and know the content is safe.
Manabu,
I am compleƟng my review of the KRU 3S-606 frac sundry and have a quesƟon for you.
x On a recent review of the 3S-617 frac sundry, the AOGCC idenƟĮed a compromise of the conĮning zones in the
oīset well 3S-15 (50-103-20444-00-00; PTD 202-254 - Baskoro Tejo was the CPAI contact for that sundry). This
well is also within the ½ mile radius of the sƟmulated zone of 3S-606. Would you please review that well,
propose a miƟgaƟon/monitoring plan, and provide an updated Sec Ɵon 10?
Thanks,
Andy
Andrew Dewhurst
Senior Petroleum Geologist
Alaska Oil and Gas ConservaƟon Commission
333 W. 7th Ave, Anchorage, AK 99501
andrew.dewhurst@alaska.gov
Direct: (907) 793-1254
20 AAC 25.283 Hydraulic Fracturing Application – Checklist
KRU 3S-606 (PTD No. 223-085; Sundry No. 324-150)
Paragraph Sub-Paragraph Section Complete?
AOGCC Page 1 March 12, 2024
(a) Application for
Sundry Approval (a)(1) Affidavit Provided with application. A.Dewhurst
08 MAR 24
(a)(2) Plat Provided with application. A.Dewhurst
08 MAR 24
(a)(2)(A) Well location
Provided with application. Well lies in Section 18 of T12N,
R8E, UM.
A.Dewhurst
08 MAR 24
(a)(2)(B) Each water well within ½ mile
None: According to the Water Estate map available through
DNR’s Alaska Mapper application (accessed online 08 MAR
24), there are no wells are used for drinking water purposes
are known to lie within ½ mile of the surface location of KRU
3S-606. The closest subsurface or temporary subsurface
water rights location is approximately 7 miles from the
surface location of KRU 3S-606.
A.Dewhurst
08 MAR 24
(a)(2)(C) Identify all well types within ½
mile Provided with application. A.Dewhurst
08 MAR 24
(a)(3) Freshwater aquifers: geological
name; measured and true vertical depth
None.
There is an EPA Aquifer Exemption for the KRU.
For an outline of the Area, see the EPA’s “Alaska Oil & Gas
Aquifer Exemptions Interactive Map” available online under
the “Permits” section of EPA Region 10’s web page at
https://www.epa.gov/uic/underground-injection-control-
region-10-ak-id-or-and-wa.
A.Dewhurst
08 MAR 24
(a)(4) Baseline water sampling plan None required. A.Dewhurst
08 MAR 24
(a)(5) Casing and cementing information Provided with application. Proposed schematic attached, as
built not generated to date.
CDW
3/11/24
(a)(6) Casing and cementing operation
assessment
See (a)(6)(B) below. Cement logs verified cement in regions
required. No issues with cement for the upcoming
stimulation.
CDW
3/11/24
20 AAC 25.283 Hydraulic Fracturing Application – Checklist
KRU 3S-606 (PTD No. 223-085; Sundry No. 324-150)
Paragraph Sub-Paragraph Section Complete?
AOGCC Page 2 March 12, 2024
(a)(6)(A) Casing cemented below
lowermost freshwater aquifer and
conforms to 20 AAC 25.030
No freshwater aquifers present. (See Section (a)(3), above.) A.Dewhurst
08 MAR 24
(a)(6)( B) Each hydrocarbon zone is
isolated
Yes:
10-3/4” surface casing was set at 2,922’ MD (2,558’ TVD)
and cemented with cement returns at surface.
7-5/8” intermediate casing was set at 7,466’ MD (5,148’
TVD) and cemented with a CBL indicated TOC of 3,950’ MD
(3,164’ TVD).
The Coyote/K-3 hydrocarbon zone at 5,545’ MD (4,101’ TVD)
is completely covered with “good cement” bond (SLB TOC
evaluation 22 FEB 24)
A.Dewhurst
08 MAR 24
(a)(7) Pressure test: information and
pressure-test plans for casing and tubing
installed in well
Provided with application. 3850 psi MITIA 3/3/2024, 4550
psi MITT plan.
CDW
3/11/24
(a)(8) Pressure ratings and schematics:
wellbore, wellhead, BOPE, treating head
Provided with application. 10K psi wellhead max. frac.
Pressure 7075 psi. Pump knock out 7575 and GORV 8075
psi., lines test 10,000 psi.
CDW
3/11/24
(a)(9)(A) Fracturing and confining zones:
lithologic description for each zone
(a)(9)(B) Geological name of each zone
(a)(9)(C) and (a)(9)(D) Measured and true
vertical depths
(a)(9)(E) Fracture pressure for each zone
Upper confining zones: The Torok Formation consists of
mudstones and siltstones with an average thickness of
approximately 795’ TVD. The top of the Torok confining zone
starts at 6,437’ MD (4,627’ TVD). The estimated fracture
gradient of the Torok formation is approximately 0.82 psi/ft
(13.5 ppg EMW).
Fracturing Zone: The Moraine interval (Torok Formation) has
an average thickness of approximately 240’ TVD over the
A.Dewhurst
08 MAR 24
20 AAC 25.283 Hydraulic Fracturing Application – Checklist
KRU 3S-606 (PTD No. 223-085; Sundry No. 324-150)
Paragraph Sub-Paragraph Section Complete?
AOGCC Page 3 March 12, 2024
course of the lateral section of KRU 3S-606, from where it
intersects the top of the formation at 7,544’ MD to TD of the
well. It is comprised of thinly interbedded sandstone,
siltstone, and silty shale layers. The sandstone and siltstone
components are litharenites, moderately to well sorted, and
very fine grained. The silty shales are composed of clay-rich,
moderately to poorly sorted silt and clay. The estimated
fracture gradient for the Moraine interval is approximately
0.65 psi/ft - 0.70 psi/ft (12.5 ppg – 13.5 ppg EMW).
Lower confining zones: The lower confining zone consists of
lower Torok, HRZ, and Kalubik shales which have a total
thickness of approximately 500’ TVD. The base of the
Moraine is estimated from seismic to be at -5,565’ TVDSS at
the heel, and -5,250’ TVDSS at the toe of the well. The
estimated fracture gradient for this section ranges from 0.78
psi/ft - 0.936 psi/ft (15 ppg – 18 ppg EMW), with the
gradient increasing down section.
(a)(10) Location, orientation, report on
mechanical condition of each well
3S pad is crowded with over 40 wells and/or sidetracks
within the ½ mile.
CDW
3/12/2024
(a)(11) Sufficient information to determine
wells will not interfere with containment
within ½ mile
Revised list provided with application. CBL of 7” casing at
KRU 3S-15 shows evidence that Kuparuk, Moraine, and
Coyote are not isolated. CPAI stated in updated application
that planned frac orientations will not intersect 3S-15 in
Moraine or Coyote sands.
A.Dewhurst
12 MAR 24
(a)(11) Faults and fractures, Location,
orientation
(a)(11) Faults and fractures, Sufficient
information to determine no interference
with containment within ½ mile
One fault that is not anticipated to affect overburden
integrity/containment. CPAI has identified a single fault
that transects the Moraine within a ½-mile radius of the
KRU 3S-617 wellbore trajectory. While the fault does not
intersect the KRU 3S-617 or any other nearby wells, it is
interpreted to have offset the toe section of the KRU 3S-617
A.Dewhurst
12 MAR 24
20 AAC 25.283 Hydraulic Fracturing Application – Checklist
KRU 3S-606 (PTD No. 223-085; Sundry No. 324-150)
Paragraph Sub-Paragraph Section Complete?
AOGCC Page 4 March 12, 2024
well downwards by about 40’. The fault trace has been
mapped on seismic to run parallel to the KRU 3S-617 and
KRU 3S-624 laterals, as shown in the revised plat. It is
interpreted to not affect overburden integrity and therefore
its presence will not interfere with containment.
(a)(12) Proposed program for fracturing
operation Provided with application. CDW
3/11/24
(a)(12)(A) Estimated volume Provided with application. 42876 bbl total dirty vol. 4.4M lb
total proppant
CDW
3/11/24
(a)(12)(B) Additives: names, purposes,
concentrations Provided with application. CDW
3/11/24
(a)(12)(C) Chemical name and CAS
number of each
Provided with application. Halliburton, Petina, ProTechnics
disclosure provided. Proprietary products on file with
AOGCC.
CDW
3/11/24
(a)(12)(D) Inert substances , weight or
volume of each Provided with application. CDW
3/11/24
(a)(12)(E) Maximum treating pressure with
supporting info to determine
appropriateness for program
CPAI identified 7075 psi as max surface pressure. Max
pressure is 7575 psi to Pump shutdown and PRV set at 8075
psi. With 3500 psi back pressure IA (IA popoff set 3600 psi),
max tubing differential should be 3575 psi.
CDW
3/11/24
(a)(12)(F) Fractures – height, length, MD
and TVD to top, description of fracturing
model
Provided with application. The anticipated maximum half-
length of the induced fractures is 1,260’ according to the
Operator’s computer simulation. Computer simulation
indicates the anticipated height of the induced fractures will
be 155’ (top TVD of about 5,036’), so induced fractures will
likely penetrate into, but not through, the overlying
confining Torok shales.
A.Dewhurst
11 MAR 24
(a)(13) Proposed program for post-
fracturing well cleanup and fluid recovery
Well cleanout and flowback procedure provided with
application. No disposal identified
CDW
3/11/24
20 AAC 25.283 Hydraulic Fracturing Application – Checklist
KRU 3S-606 (PTD No. 223-085; Sundry No. 324-150)
Paragraph Sub-Paragraph Section Complete?
AOGCC Page 5 March 12, 2024
(b)Testing of casing
or intermediate
casing
Tested >110% of max anticipated pressure 3500 psi back pressure, test to 3850 psi, popoff set as 3600
psi
CDW
3/11/24
(c) Fracturing string (c)(1) Packer >100’ below TOC of
production or intermediate casing
4.5” tubing will be anchored with a 7151 ft retrievable
packer and 7285 ft tubing hanger. Shallowest frac port is
8233 ft. 10-3/4” surface casing cemented to surface. TOC
in 7-5/8” casing at 3950 ft by CBL/SonicScope tool. Cement
at area of interest so no cement concerns.
CDW
3/11/24
(c)(2) Tested >110% of max anticipated
pressure differential
Tubing test plan of 4550 psi. Max pressure differential is
estimated as 3575 psi (7075 psi with 3500 psi backpressure)
so test of 4550 psi satisfies 110%
CDW
3/11/24
(d) Pressure relief
valve
Line pressure <= test pressure, remotely
controlled shut-in device
10K psi line pressure test, pump knock out 7575 psi with
max. global kickout 8075 psi. IA PRV set as 3600 psi.
CDW
3/11/24
(e) Confinement Frac fluids confined to approved
formations Provided with application. CDW
3/11/24
(f) Surface casing
pressures
Monitored with gauge and pressure relief
device
IA PRV set at 3600 psi. Surface annulus open. Frac pressures
continuously monitored.
CDW
3/11/24
(g) Annulus
pressure
monitoring &
notification
500 psi criteria
During hydraulic fracturing operations, all annulus pressures
must be continuously monitored and recorded. If at any
time during hydraulic fracturing operations the annulus
pressure increases more than 500 psig above those
anticipated increases caused by pressure or thermal
transfer, the operator shall:
CDW
3/11/24
(g)(1) Notify AOGCC within 24 hours
(g)(2) Corrective action or surveillance
(g)(3) Sundry to AOGCC
(h) Sundry Report
(i) Reporting (i)(1) FracFocus Reporting
20 AAC 25.283 Hydraulic Fracturing Application – Checklist
KRU 3S-606 (PTD No. 223-085; Sundry No. 324-150)
Paragraph Sub-Paragraph Section Complete?
AOGCC Page 6 March 12, 2024
(i)(2) AOGCC Reporting: printed &
electronic
(j) Post-frac water
sampling plan Not required (see Section (a)(3), above) A.Dewhurst
11 MAR 24
(k) Confidential
information
Clearly marked and specific facts
supporting nondisclosure No confidential material identified. A.Dewhurst
11 MAR 24
(l) Variances
requested
Modifications of deadlines, requests for
variances or waivers
No plan for post fracture water well analysis. Commission may require this depending on performance of the fracturing operation.
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Chris Brillon
Wells Engineering Manager
Conoco Phillips Alaska, Inc.
700 G Street
Anchorage, AK, 99501
Re: Kuparuk River Field, Torok Oil Pool, KRU 3S-606
Conoco Phillips Alaska, Inc.
Permit to Drill Number: 223-111
Surface Location: 2798' FSL, 910' FEL, NWNE S18 T12N R8E
Bottomhole Location: 1916' FSL, 5' FEL, NENE S35 T13N R7E
Dear Mr. Brillon:
Enclosed is the approved application for the permit to drill the above referenced well.
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well
logs run must be submitted to the AOGCC within 90 days after completion, suspension, or
abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first.
This permit to drill does not exempt you from obtaining additional permits or an approval required
by law from other governmental agencies and does not authorize conducting drilling operations
until all other required permits and approvals have been issued. In addition, the AOGCC reserves
the right to withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska
Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply
with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code,
or an AOGCC order, or the terms and conditions of this permit may result in the revocation or
suspension of the permit.
Sincerely,
Brett W. Huber, Sr.
Chair, Commissioner
DATED this 19 day of December 2023.
Brett W. Huber,
Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.12.19 13:05:36 -09'00'
1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for:
Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates
Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas
2. Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number:
Bond No.
3. Address: 6. Proposed Depth: 12. Field/Pool(s):
MD: 20119 TVD: 5150
4a. Location of Well (Governmental Section): 7. Property Designation:
Surface:
Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date:
12/20/2023
Total Depth: 9. Acres in Property: 14. Distance to Nearest Property:
3363' to ADL025528
4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 64.3 15. Distance to Nearest Well Open
Surface: x-476349 y- 5993934 Zone- 4 25.3 to Same Pool: 4952' to 3S-611
16. Deviated wells: Kickoff depth: 300 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 90 degrees Downhole: Surface:
Hole Casing Weight Grade Coupling Length MD TVD MD TVD
42" 20" 94 H-40 Welded 58 39 39 97 97
13.5" 10.75" 45.5 L-80 Hyd563 2877 39 39 2916 2565
9.875" 7.625" 29.7 L80 Hyd563 6511 39 39 6550 4806
9.875" 7.625" 33.7 P110S Hyd563 800 6550 4806 7350 5113
6.5" 4.5" 12.6 P110S Hyd563 12919 7200 5091 20119 5150
19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations)
Junk (measured):
TVD
Hydraulic Fracture planned? Yes No
20. Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis
Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements
Contact Name: Matt Smith
Chris Brillon Contact Email:matt.smith2@cop.com
Wells Engineering Manager Contact Phone:907-263-4324
Date:
Permit to Drill API Number: Permit Approval
Number:Date:
Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales:
Samples req'd: Yes No Mud log req'd: Yes No
H2S measures: Yes No Directional svy req'd: Yes No
Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No
Post initial injection MIT req'd: Yes No
APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
P.O. Box 100360 Anchorage, Alaska, 99510-0360 Kuparuk River Field
Torok Oil Pool
2798' FSL, 910' FEL, NWNE S18 T12N R8E ADL380107 / ADL380106 / ADL025528 / ADL393883
(including stage data)
1632' FSL, 2077' FWL, SWNE S7 T12N R8E LONS 01-013
1916' FSL, 5' FEL, NENE S35 T13N R7E 2448 / 2437 / 2560 / 5759
GL / BF Elevation above MSL (ft):
2303 1788
18. Casing Program:
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
ConocoPhillips Alaska Inc. 59-52-180 3S-606
900sks 10.7ppg, 280sks 15.8ppg
570sks 15.3ppg
Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks
Casing Length Size Cement Volume MD
Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft):
Surface
Conductor/Structural
Liner
Production
Intermediate
Perforation Depth MD (ft): Perforation Depth TVD (ft):
21. I hereby certify that the foregoing is true and the procedure approved herein will not be
deviated from without prior written approval.
Authorized Name:
Authorized Title:
Authorized Signature:
Commission Use Only
See cover letter for other
requirements.
Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g)
By Grace Christianson at 8:39 am, Nov 21, 2023
Initial BOP test to 5000 psig; subsequent BOP test to 3500 psig
Annular preventer test to 2500 psig
Waiver for CPAI Rotary Rig BOPE Test Frequency applies according to order OTH-21-018 extension attached
Intermediate II cement evaluation may use SonicScope under the attached Conditions of Approval
Surface casing LOT and annular LOT to the AOGCC as soon as available.
Results of Sonic required to verify competent cement behind casing.
50-103-20870-00-00
X
DSR-11/22/23
Umiat Meridian
KRU
223-111
A.Dewhurst 05DEC23
Diverter variance request granted per 20 AAC 20.035(h)(2), based on CPAI offset analysis of
3S-06, 3S-14, 3S-17, 3S-611, and 3S-617. -A.Dewhurst 01DEC23
VTL 12/19/2023
*&:
Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr.
Date: 2023.12.19 13:06:04 -09'00'
12/19/23
12/19/23
<Zhϯ^ͲϲϬϲ
Conditions of Approval:
Approval is granted to run the LWD-Sonic on upcoming well with the following provisions:
1. CPAI will provide a written log evaluation/interpretation to the AOGCC along with the log as
soon as they become available. The evaluation is to include/highlight the intervals of competent
cement that CPAI is using to meet the objective requirements for annular isolation, reservoir
isolation, or confining zone isolation etc. Providing the log without an evaluation/interpretation
is not acceptable.
2. LWD sonic logs must show free pipe and Top of Cement, just as the e-line log does. CPAI must
start the log at a depth to ensure the free pipe above the TOC is captured as well as the TOC.
Starting the log below the actual TOC based on calculations predicting a different TOC will not
be acceptable.
3. CPAI will provide a cement job summary report and evaluation along with the cement log and
evaluation to the AOGCC when they become available
4. CPAI will provide the results of the FIT when available.
5. Depending on the cement job results indicated by the cement job report, the logs and the FIT,
remedial measures or additional logging may be required.
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
March 2, 2023
Mr. Luke Lawrence
Wells Manager
ConocoPhillips Alaska
700 G Street
Anchorage, AK 99501
Re: Docket Number: OTH-21-018
CPAI Rotary Rig BOPE Test Frequency
Dear Mr. Lawrence:
By letter dated January 12, 2023, ConocoPhillips Alaska, Inc. (CPAI) requested a continuance of
the waiver granted under Docket OTH-21-018 allowing certain CPAI rotary drilling rigs to test
blowout prevention equipment (BOPE) on a 21-day test schedule. The Alaska Oil and Gas
Conservation Commission (AOGCC) grants CPAI’s request for a limited duration and scope.
OTH-21-018 approved the 21-day test interval for a 1-year period which expired on January 25,
2023. The AOGCC approved an extension to the pilot program by electronic mail on February 6,
2023, to accommodate review of the July-December 2022 BOPE Between Wells Maintenance
Report (received January 27, 2023, and revised February 3, 2023). AOGCC met with CPAI on
February 22, 2023 to discuss the Between Wells Maintenance Report and BOPE performance of
the CPAI-operated rigs during 2022 in considering the requested continuance.1
During the past year, CPAI-operated rigs Doyon 25 and Doyon 26 were authorized to participate
in the pilot – the other rigs working for CPAI failed to meet the conditions for testing BOPE at 21-
day intervals.2
CPAI’s request to continue the pilot project allowing BOPE testing on a 21-day interval is
approved for drilling rigs Doyon 25 and Doyon 26, with the following conditions:
- The pilot test duration is for ONE year from the approval date of this letter, subject to
potential extension and expansion to include other CPAI operated rigs with at least 3
months of continuous rig work and AOGCC review of a rig’s BOPE system reliability.
1 AOGCC approval of the Between Wells Maintenance program has enabled CPAI workover rigs to extend the
interval between BOPE tests from every 7 days to not exceeding 14 days and was also part of the justification for
allowing certain rigs to test BOPE on a 21-day interval. CPAI data shows the BWM has reduced the number of
component failures during BOPE testing by replacing components that indicate suspect integrity before those
components fail during testing.
2 Doyon 26 has additionally been approved (Permit-to-Drill) to test BOPE on an event-basis instead of at pre-
determined time intervals while drilling specific sections in an ultra-extended reach well.
Docket Number: OTH-21-018
March 2, 2023
Page 2 of 2
- CPAI must continue to implement the BWM program as approved by AOGCC.
- Development drilling wells only are included in this approval.
- The initial test after rigging up BOPE to drill a well must be to the rated working pressure
as provided in API Standard 53.
- CPAI is encouraged to take advantage of opportunities to test.
- CPAI must adhere to original equipment manufacturer recommendations and replacement
parts for BOPE.
- Requests for extensions beyond 21 days must include justification with supporting
information demonstrating the additional time is necessary for well control purposes or to
mitigate a stuck drill string.
- 48-hour advance notice for a BOPE test shall be provided to AOGCC for opportunity to
witness.
If you have questions regarding this, please contact Jim Regg at (907) 793-1236.
Sincerely,
Brett W. Huber, Sr.
Chair, Commissioner
cc: Greg Hobbs (CPAI)
Mike Kneale (CPAI)
Victoria Loepp (AOGCC)
AOGCC Inspectors (email)
Brett W. Huber,
Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.03.02 11:09:23
-09'00'
ConocoPhillips Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907-276-1215
November 20, 2023
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
Re: Application for Permit to Drill 3S-606
Dear Sir or Madam:
ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Moraine Injector well from the 3S drilling pad.
The intended spud date for this well is 12/20/2023. It is intended that Doyon 142 be used to drill the well.
3S-606 will utilize a 13 1/2” surface hole drilled to TD and 10 3/4” casing will be set and cemented to surface. As noted in
section 4 of the attached proposed drilling program, the low maximum anticipated surface pressure of the well allows use of a
three preventer BOPE per 20 AAC 25.035 (e) (1) (A) (i-iii). The fourth preventer will contain solid body pipe rams that will
be sized for the intermediate casing string. The 9 7/8” intermediate hole will be drilled and topset the Moraine reservoir. A 7
5/8” casing string will be set and cemented from TD to secure the shoe and cover 500’MD or 250’TVD above any
hydrocarbon-bearing zones (Coyote).
The production interval will be comprised of a 6 1/2” horizontal hole that will be landed and geo-steered in the Moraine
formation. The well will be completed as an uncemented, fracture stimulated Injector with 4 1/2” liner, frac sleeves and swell
packers. The upper completion will include a production packer with GLM’s and tied back to surface.
It is requested that a variance of the diverter requirement under 20AAC 25.035(h)(2) is granted for well 3S-606. At 3S, there
has not been a significant indication of shallow gas hydrates though the surface hole interval.
Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information
attached to this application includes the following:
1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a)
2. A proposed drilling program
3. A proposed completion diagram
4. A drilling fluids program summary
5. Pressure information as required by 20 ACC 25.035 (d)(2)
6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b)
Information pertinent to the application that is presently on file at the AOGCC:
1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC
25.035 (a) and (b).
2. A description of the drilling fluids handling system.
3. Diagram of riser set up.
If you have any questions or require further information, please contact Abby Warren at 907-240-9293
(abby.warren@conocophillips.com) or Chris Brillon at 907-265-6120.
Sincerely, cc:
3S-606 Well File / Jenna Taylor ATO 1560
David Lee ATO 1552
Abby Warren Chris Brillon ATO 1548
Drilling Engineer Roland Kirschner ATO 636
a variance of the diverter requirement u
Application for Permit to Drill, 3S-606
Saved: 20-Nov-23
3S-606 PTD
Page 1 of 9
Printed: 20-Nov-23
3S-606
Application for Permit to Drill Document
Table of Contents
1. Well Name (Requirements of 20 AAC 25.005 (f)) ........................................................................................................ 1
2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) ......................................................................................... 1
3. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) ........................................................................ 2
4. Blowout Prevention Equipment (Requirements of 20 AAC 25.005(c)(3)) ............................................................. 3
5. Diverter System (Requirements of 20 AAC 25.005(c)(7)) ..................................................................................... 4
6. MASP Calculations (Requirements of 20 AAC 25.005(c)(4)) ................................................................................ 4
7. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) ............................ 5
8. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) ........................................................... 5
9. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) .................................................................................. 6
10. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) ........................................ 7
11. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) ................................................................................... 7
12. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) ................................................................... 7
13. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) ............................................................................. 7
14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005 (c)(14)) ......... 7
15. Drilling Hazards Summary ................................................................................................................................. 7
16. Proposed Completion Schematic ....................................................................................................................... 9
1. Well Name (Requirements of 20 AAC 25.005 (f))
The well for which this application is submitted will be designated as 3S-606
2. Location Summary (Requirements of 20 AAC 25.005(c)(2))
Location at Surface 2,798‘ FSL, 910‘ FEL, NWNE S18 T12N R8E, UM
NAD 1927
Northings: 5993934
Eastings:476349
RKB Elevation 64.3’AMSL
Pad Elevation 25.3’AMSL
Top of Productive Horizon
(Heel)
1632‘ FSL, 2077‘ FWL, SWNE S7 T12N R8E, UM
NAD 1927
Northings: 5998055
Eastings: 474054
Measured Depth, RKB:
7,350
Total Vertical Depth, RKB:5,113
Total Vertical Depth, SS:5,049
Total Depth (Toe) 1916‘ FSL, 5‘ FEL, NENE S35 T13N R7E, UM
NAD 1927
Northings: 6010356
Eastings: 470927
Measured Depth, RKB:20,119
Total Vertical Depth, RKB:5,150
Total Vertical Depth, SS:5,086
Pad Layout
3. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13))
The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic.
1. MIRU Doyon 142 onto 3S-606
2. Rig up and test riser, dewater cellar as needed.
3. Drill 13 1/2” hole to the surface casing point as per the directional plan.
4. Run and cement 10 3/4” surface casing to surface.
5. Install BOPE and MPD equipment.
6. Test BOPE to 250 psi low / 5,000 psi high (24-48 hr regulatory notice).
7. Pick up and run in hole with 9 7/8” drilling BHA to drill the intermediate hole section.
8. Chart casing pressure test to 3000 psi for 30 minutes.
9. Drill out 20’ of new hole and perform LOT. Maximum LOT to 18 ppg. Minimum LOT required to drill ahead is 11.5
ppg EMW.
10. Drill 9 7/8” hole to section TD, setting pipe above the Moraine Reservoir. (LWD Program: GR/RES/Den/Neu).
11. Run 7 5/8” casing and cement to a minimum of 500’ MD or 250’ TVD above any hydrocarbon bearing zones
(cementing schematic attached). Pressure test casing if possible on plug bump to 4000 psi.
12. Test BOPE to 250 psi low / 4,000 psi high (24-48 Regulatory notice).
13. Pick up and run in hole with 6 1/2” drilling BHA. Log top of cement with sonic tool in recorded mode.
14. Chart casing pressure test to 4,000 psi for 30 minutes if not tested on plug bump.
15. Drill out shoe track and 20 feet of new formation. Perform LOT to a maximum of 14.5 ppg. Minimum required leak-
off value is 11.5 ppg EMW.
16. Drill 6 1/2” hole to section TD (LWD Program: GR/RES/Den/Neu).
17. Pull out of hole with drilling BHA. Review cement job details and sonic log TOC.
18. Run 4 1/2” liner with toe valve, frac sleeves and swell packers and liner hanger to TD.
19. Run 4 1/2” upper completion with landing nipple, production packer, downhole gauge, and gas lift mandrels.
Displace mud in production casing to kill weight brine, space out and land tubing hanger with pre-installed and pre-
tested BPV.
20. Pressure test hanger seals to 3,850 psi.
21. Pressure to dual flapper valve to set production packer, test tubing to 4,550 psi, chart test.
22. Bleed tubing pressure to 2200 psi and test IA to 3,850 psi, chart test.
23. Install HP-BPV and test to 2500 psi.
24. Nipple down BOP.
25. Install tubing head adapter assembly. N/U tree and test to 5000 psi/10 minutes.
26. Freeze protect down tubing and annulus.
27. Secure well. Rig down and move out.
Please note – This well will be frac’d
4. Blowout Prevention Equipment (Requirements of 20 AAC 25.005(c)(3))
Please reference BOP schematics on file for Doyon 142.
Doyon 142 will use a BOPE stack equipped with an annular preventer, fixed 7 5/8” solid body rams, blind/shear rams and
variable rams while drilling and running casing in the intermediate section of 3S-606.
3S-606 has a MASP of 1,788 psi in the intermediate hole section using the methodology in section 6 MASP calculations.
With a MASP less than 3000 psi ConocoPhillips classifies the operation as a Class 2.
Per 20AAC 25.035.e.a.A:
For an operation with a maximum potential surface pressure of 3,000 psi or less, BOPE must have at least
three preventers, including:
i. One equipped with pipe rams that fit the size of drill pipe, tubing or casing begin used, except that
pipe rams need not be sixed to bottom-hole assemblies and drill collars.
ii. One with blind rams
iii. One annular type
Intermediate Drilling/Casing Production
Proposed Configuration: Proposed Configuration:
Annular Preventer (iii) Annular Preventer
7 5/8” fixed rams during drilling Intermediate VBRs in Upper Cavity
Blind/Shear Rams (ii) Blind/Shear Rams
VBRs (i) VBRs in Lower Cavity
5. Diverter System (Requirements of 20 AAC 25.005(c)(7))
It is requested that a variance of the diverter requirement under 20 AAC 25.035(h)(2) is granted. At 3S, there has not been
significant indication of shallow gas or gas hydrates through the surface hole interval. There are 5 previously drilled wells
(3S-06, 3S-14, 3S-17, 3S-611, 3S-617) within 500’ of the proposed 3S-606 surface shoe location. None of these wells
encountered any significant indication of shallow gas or gas hydrates.
6. MASP Calculations (Requirements of 20 AAC 25.005(c)(4))
The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well:
Casing
Size (in)
Csg Setting Depth
MD/TVD(ft)
Fracture
Gradient (ppg)
Pore pressure
(psi)
ASP Drilling
(psi)
20 97 / 97 10.9 54 56
10 3/4 2,916 / 2,565 12.5 1,147 1,411
7 5/8 7350 / 5,113 13.5 2,287 1,788
4 1/2 20,119 / 5,150 13.0 2,303 n/a
PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP)
ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the
surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows:
1) ASP = [(FG x 0.052) - 0.1]*D
Where: ASP = Anticipated Surface pressure in psi
FG = Fracture gradient at the casing seat in lb/gal
0.052 = Conversion from lb./gal to psi/ft
0.1 = Gas gradient in psi/ft
D = true Vertical depth of casing seat in ft RKB
OR
2) ASP = FPP – (0.1 x D)
Where: FPP = Formation Pore Pressure at the next casing point
FPP = 0.4525 x TVD
1. ASP CALCULATIONS
1. Drilling below 20” conductor
ASP = [(FG x 0.052) – 0.1] D
= [(10.9 x 0.052) – 0.1] x 97 = 56 psi
OR
ASP = FPP – (0.1 x D)
= 1,147 – (0.1 x 2,565 ) = 891 psi
2. Drilling below 10.75” surface casing
ASP = [(FG x 0.052) – 0.1] D
= [(12.5 x 0.052) – 0.1] x 2,565 = 1,411 psi
OR
ASP = FPP – (0.1 x D)
= 2,287 – (0.1 x 5,113 ) = 1,775 psi
3. Drilling below 7.625” intermediate casing
ASP = [(FG x 0.052) – 0.1] D
= [(13.0 x 0.052) – 0.1] x 5,113 = 3,078 psi
OR
ASP = FPP – (0.1 x D)
= 2,303 – (0.1 x 5,150 )= 1,788 psi
(B) data on potential gas zones;
The well bore is not expected to penetrate any shallow gas zones.
(C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones,
and zones that have a propensity for differential sticking;
Please see Drilling Hazards Summary
7. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5))
Drill out the casing shoe and perform LOT/FIT as per the procedure that ConocoPhillips Alaska has on file with
the Commission.
8. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6))
Casing and Cementing Program
Csg/Tbg
OD (in)
Hole Size
(in)
Weight
(lb/ft) Grade Conn. Cement Program
20 42 94 H-40 Welded Cemented to surface with 10 yds slurry
10 3/4 13 1/2 45.50 L-80 Hyd563 Cement to Surface
7 5/8 9 7/8 29.70
33.70
L80
P110S Hyd563 250’ TVD or 500’ MD, whichever is greater, above upper
most producing zone (Coyote)
4 1/2 6 1/2 12.60 P110S Hyd563 Unemented liner with frac sleeves and swell packers
Cementing Calculations
10 3/4” Surface Casing run to 2,916 ’ MD / 2,565 ’ TVD
Cement 2,916’ MD to 2,416’ (500’ of tail) with Class G + Add's@ 15.8 PPG, and from 2,416' to surface with 10.7 ppg
Arctic Lite Crete. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost (1,693 ’
MD), zero excess in 20” conductor.
Lead slurry from 2,416’ MD to surface with Arctic Lite Crete @ 10.7 ppg
Total Volume = 2,550 ft3 => 900 sx of 10.7 ppg Class G + Add's @ 2.86 ft3 /sk
Tail slurry from 2,916 MD to 2,416’ MD with 15.8 ppg Class G + Add's
Total Volume = 316 ft3 => 280 sx of 15.8ppg Class G + Add's @ 1.16 ft3/sk
7 5/8” Intermediate Casing run to 7350’ MD / 5,113 ’ TVD
Top of slurry is designed to be at 5,100 ’ MD, which is 500’MD or 250’ TVD above the prognosis shallowest
hydrocarbon bearing zone, Coyote. If a shallower hydrocarbon zone of producible volumes, is encountered while
drilling, a 2-stage cement job will be performed to isolate this zone. Assume 40% excess annular volume.
Tail slurry from 7,350’ MD to 5,100’ MD with 15.3 ppg Class G + Add's
Total Volume = 697 ft3 => 570 sx of 15.3 ppg Class G + Add's @ 1.24 ft3/sk
9. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8))
Surface Intermediate Production
Hole Size in. 13 1/2 9 7/8 6 1/2
Casing Size in. 10 3/4 7 5/8 4 1/2
Density PPG 9.0 – 10.5 9.0 – 9.8 9.0 – 10.0
PV cP 20-50 8-15 7-12
YP lb./100 ft2 30 - 80 20 - 30 15 - 25
Funnel Viscosity s/qt.
250 – 300 to
base perm
200-300 to TD
40-60 35-50
Initial Gels lb./100 ft2 30 - 50 8 - 15 5- 10
10 Minute Gels lb./100 ft2 50 - 70 <20 7 - 15
API Fluid Loss cc/30 min. N.C. – 15.0 < 10.0 < 6.0
HPHT Fluid Loss cc/30 min. N/A N/A < 10.0
pH 9.0 – 10.0 9.0 – 10.0 9.5 – 10.5
Surface Hole:
A water based spud mud will be used for the surface interval. Mud engineer to perform regular mud checks to maintain
proper specifications The mud weight will be maintained at N10.0 ppg by use of solids control system and dilutions
where necessary.
Intermediate:
p
f producible volumes,
See note in email exchange. -A.Dewhurst 05DEC23
Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular
velocity. Maintain mud weight at or below 9.5 ppg for formation stability and be prepared to add loss circulation
material if necessary. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required)
will all be important. The mud will be weighted up to 9.5 ppg before pulling out of the hole.
Production Hole:
The horizontal production interval will be drilled with a water-based mud drill-in fluid (KlaShield) weighted to 9 – 10
ppg. MPD will be available for adding backpressure during connections if necessary.
Diagram of Doyon 142 Mud System on file.
Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033.
10. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9))
N/A - Application is not for an exploratory or stratigraphic test well.
11. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10))
N/A - Application is not for an exploratory or stratigraphic test well.
12. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11))
N/A - Application is not for an offshore well.
13. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12))
Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.
14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC
25.005 (c)(14))
Waste fluids and cuttings generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II
disposal well at the 1B Facility. If needed, excess cuttings generated will be hauled to Milne Point or Prudhoe Bay Grind
and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored,
tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in
accordance with a permit from the State of Alaska.
15. Drilling Hazards Summary
13 1/2" Hole / 10 3/4” Casing Interval
Event Risk Level Mitigation Strategy
Conductor Broach Low Monitor cellar continuously during interval.
Well Collision Low Follow real time surveys very closely, gyro survey as
needed to ensure survey accuracy.
Gas Hydrates Low If observed – control drill, reduce pump rates and
circulating time, reduce mud temperatures
Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),
pumping out
Washouts/Hole Sloughing Low Cool mud temperatures, minimize circulating times
when possible
Running sands and gravels Low Maintain planned mud properties, increase mud
weight, use weighted sweeps
9 7/8” Hole /7 5/8” Liner - Casing Interval
Event Risk Level Mitigation Strategy
Sloughing shale / Tight hole /
Stuck Pipe
Low Good hole cleaning, pre-treatment with LCM, stabilized
BHA, maintain planned mud weights and adjust as
needed, real time equivalent circulating density (ECD)
monitoring
Lost circulation Moderate Reduce pump rates, reduce trip speeds, real time ECD
monitoring, mud rheology, add lost circulation material
Hole swabbing on trips Moderate Reduce trip speeds, condition mud properties, proper
hole filling, pump out of hole, real time ECD monitoring,
Liner will be in place at TD
Abnormal Reservoir Pressure
(Coyote / K3)
Low Well control drills, check for flow during connections,
increase mud weight if necessary
6 1/2” Hole / 4 1/2” Liner - Horizontal Production Hole
Event Risk Level Mitigation Strategy
Lost circulation Moderate Reduce pump rates, real time ECD monitoring,
maintain mud rheology, add lost circulation material
Hole swabbing on trips Moderate Reduce trip speeds, condition mud properties, proper
hole filling, pump out of hole, real time ECD monitoring
Abnormal Reservoir Pressure Low Well control drills, check for flow during connections,
increased mud weight
Differential Sticking Moderate Uniform reservoir pressure along lateral, keep pipe
moving, control mud weight
Running Liner to Bottom Moderate Properly clean hole on the trip out with BHA, perform
clean out run if necessary, utilize super sliders for
weight transfer if needed, monitor T&D real time
Well Proximity Risks:
3S is a multi-well pad. Directional drilling / collision avoidance information as required by AOGCC 20 ACC 25.050 (b) is
provided in the following attachments.
Drilling Area Risks:
Reservoir Pressure: Offset injection has the potential to increase reservoir pressure over predicted. Although this is unlikely,
the rig will be prepared to weight up if required.
Weak sand stringers could be present in the overburden. LCM material will be available to seal in losses in the intermediate
section.
Lost Circulation: Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost
circulation if needed.
Good drilling practices will be stressed to minimize the potential of taking swabbed kicks.
16. Proposed Completion Schematic
2
T12NR8E
T13NR8E
T1
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T12NR8E
T13NR7E
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T12NR7E
T13NR7E
ADL380107
ADL355032
ADL380106
ADL393883
ADL025528
ADL025532
ADL025544
ADL025546
ADL025549ADL025551ADL392374
3S
Kuparuk River Unit
25
2
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7
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1923
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3S-26
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Document Path: S:\ANC\Longterm\AK GIS\GKA\DM\GKA_Wells_AD01\CPF_3_Wells\Well_3S-606\Well_3S-606.aprx
k11/8/2023
3S-606
PTD
3
S
-
6
0
6
00.80.4
Miles
Open Interval
Well Trajectory
2 Well Pad
Suspended Well
P+A Well
Active Well
Roads and Pads
Kuparuk PA
Torok PA (Proposed)
Unit Boundary
ADNR Township
ADNR Section
CPAI Lease
Attachment 1 – 3S-606 Area of Review (AOR)
An Area of Review plot is show below of the 3S-606 Injector planned wellpath and offset wells. 3S-15 is
the offset wells from the planned 3S-606 injector.
Well
Name Status Production Casing
MD / TVD
TOC
(MD/TVD)
Cement Volumes Pumped
3S-15 P&A’d
Producer 8,404’ / 6,193’ Currently P&A’d
3S-15 is the only well within the quarter mile radius, it was P&A’d in 2020.
39 498
498 798
798 1098
1098 1498
1498 1998
1998 2498
2498 2998
2998 4998
4998 7998
7998 11998
11998 16998
16998 20118
3S-606 wp06.1 Plan Summary
0
3
Do
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S
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v
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0 3000 6000 9000 12000 15000 18000
Measured Depth
10-3/4" Surface Casing 7-5/8" Intermediate Casing
4-1/2" Production Liner
30.0
30.0
60.0
60.0
0
90
180
270
30
210
60
240 120
300
150
330
Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in]
58108158208258308358408457
506
555
604
653
7023S-03
58
108158208258308358407
457
506
555
604
653
702
7513S-06
58
108158208258308358407
457
506
555
604
653
702
751
3S-06A
58108158208258308358408458507557606655705754804852 900 3S-0758
108158208258308358
407
457
505
554
6013S-08
58
108158208258308358
407
457
505
554
6013S-08A
58
108158208258308358
407
457
505
554
6013S-08B
59
109159209259309359
408
458
506
555
6023S-08C
59
109159209259309359
408
458
506
555
6023S-08CL1
59
109159209259309359
408
458
506
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6023S-08CL1PB1
58108158208258308358408458508558608658707756806855 904 953 1002 1050 3S-09
559610659709
758
807
856
905
954
1003
3S-10
795
843
891
939
987
1035
10823S-701
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891
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10823S-701A
3953103153203253303353402452
501
550
599
648
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397447
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796
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0 2500 5000 7500 10000 12500 15000 17500
Vertical Section at 341.54°
10-3/4" Surface Casing
7-5/8" Intermediate Casing 4-1/2" Production Liner
0
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0 400 800 1200 1600 2000 2400 2800
Measured Depth
Equivalent Magnetic Distance
DDI
7.074
SURVEY PROGRAM
Date: 2021-02-19T00:00:00 Validated: Yes Version:
Depth From Depth To Survey/Plan Tool
39.00 1300.00 3S-606 wp06.1 (3S-606) SDI_URSA1_I4
1300.00 2760.00 3S-606 wp06.1 (3S-606) MWD+IFR2+SAG+MS
2760.00 8130.00 3S-606 wp06.1 (3S-606) MWD+IFR2+SAG+MS
8130.00 20117.57 3S-606 wp06.1 (3S-606) MWD+IFR2+SAG+MS
Ground / 25.30
CASING DETAILS
TVD MD Name
2565.30 2916.81 10-3/4" Surface Casing
5113.30 7350.18 7-5/8" Intermediate Casing
5150.20 20118.55 4-1/2" Production Liner
Mag Model & Date: BGGM2023 15-Jan-24
Magnetic North is 14.39° East of True North (Magnetic Declinatio
Mag Dip & Field Strength: 80.64° 57223.28nT
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00
2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.50
3 600.00 4.50 330.30 599.69 10.23 -5.83 1.50 330.30 11.55 Start 200.00 hold at 600.00 MD
4 800.00 4.50 330.30 799.08 23.86 -13.61 0.00 0.00 26.94 Start Build 2.00
5 1000.00 8.50 330.30 997.75 43.52 -24.82 2.00 0.00 49.14 Start Build 2.50
6 1524.67 21.62 330.30 1503.30 161.67 -92.21 2.50 0.00 182.54 Start 107.57 hold at 1524.67 MD
7 1632.24 21.62 330.30 1603.30 196.09 -111.85 0.00 0.00 221.41 Start DLS 3.00 TFO -0.03
8 2712.82 54.03 330.28 2445.49 763.97 -435.97 3.00 -0.03 862.70 Start 4118.16 hold at 2712.82 MD
9 6830.98 54.03 330.28 4864.10 3658.55 -2088.54 0.00 0.00 4131.56 Start DLS 3.00 TFO 23.68
10 7934.45 85.00 343.00 5246.93 4598.27 -2481.64 3.00 23.68 5147.39 Start Build 2.00
11 8134.45 89.00 343.00 5257.40 4789.23 -2540.02 2.00 0.00 5347.01 3S-606 T01 062923 Start 20.00 hold at 8134.45 MD
12 8154.45 89.00 343.00 5257.75 4808.35 -2545.87 0.00 0.00 5367.00 Start DLS 1.50 TFO 64.62
13 8368.63 90.38 345.90 5258.91 5014.66 -2603.27 1.50 64.62 5580.87 Start 4089.85 hold at 8368.63 MD
1412458.48 90.38 345.90 5231.93 8981.24 -3599.44 0.00 0.00 9658.81 Start DLS 1.00 TFO -3.02
1512500.74 90.80 345.88 5231.50 9022.23 -3609.74 1.00 -3.02 9700.95 3S-606 T02 062923 Start DLS 1.00 TFO -6.51
1612557.47 91.36 345.82 5230.43 9077.22 -3623.61 1.00 -6.51 9757.50 Start 3274.37 hold at 12557.47 MD
1715831.84 91.36 345.82 5152.51 12250.87 -4425.74 0.00 0.0013021.85 Start DLS 1.00 TFO 179.67
1815908.20 90.60 345.82 5151.20 12324.89 -4444.45 1.00 179.6713097.99 3S-606 T03 062923 Start DLS 1.00 TFO 179.76
1915967.25 90.01 345.82 5150.89 12382.14 -4458.91 1.00 179.7613156.88 Start 4151.30 hold at 15967.25 MD
20 20118.56 90.01 345.82 5150.20 16407.00 -5475.68 0.00 0.0017296.61 3S-606 T04 062923 TD at 20118.56
FORMATION TOP DETAILS
TVDPath Formation
1370.30 Top Ugnu C
1652.30 Bop Ugnu B
1693.30 Base Permafrost
1764.30 Top Ugnu A
2025.30 Top West Sak
2442.30 Base West Sak
2605.30 C-80
3430.30 C-50
3898.30 C-35
4096.30 Top Coyote
5113.30 Base Coyote
5133.30 Top Torok
By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surroundingwells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basiis
for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance.
Prepared by Checked by Accepted by Approved by
Plan 25.3+39 @ 64.30usft (D142)
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30
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Ce
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C
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S
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p
a
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a
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0 450 900 1350 1800 2250
Partial Measured Depth
3S
-
0
3
3S
-06
3S
-06
A
3S
-
0
7
3S-0
8
3S-0
8
A
3S-0
8
B
3S-0
8
C
3S-0
8
C
L
1
3S-0
8
C
L
1
P
B
1
3S-
09
3S
-
1
0
3S
-
7
0
1
3S
-
7
0
1
A
3S
-
7
0
4
3S
-
6
0
5
w
p
0
4
Equivalent Magnetic Distance
3S-606 wp06.1 Ladder View
0
150
300
Ce
n
t
r
e
t
o
C
e
n
t
r
e
S
e
p
a
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a
t
i
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0 3000 6000 9000 12000 15000 18000
Measured Depth
3S
-
0
3
3S
-
0
6
3S-
0
6
A
3S
-
0
7
3S
-
0
8
3S
-
0
8
A
3S
-
0
8
B
3S
-
0
8
C
3S
-
0
8
C
L1
3S
-
0
8
C
L1
P
B
1
3S
-0
9
3S
-
1
0
3S
-
1
4
3S
-
1
5
3S
-
1
6
3S
-
1
7
3S
-
1
7
A
3S
-
6
11
3S
-
6
11
P
B
1
3S
-
6
1
1A
w
p
0
4
3S
-
6
1
2
3S
-
6
1
3
3S
-
6
1
5
3S
-
6
1
7
3S
-
6
1
7
w
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0
7
3S-701
3S
-70
1
A
3S
-
7
0
4
3S
-
6
0
2
w
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4
3S-6
0
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3S
-
61
0
w
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5
3S-7
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4
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3
3S
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7
1
8
w
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4
3S
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72
2
w
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4
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2
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2
3T
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6
0
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Equivalent Magnetic Distance
SURVEY PROGRAM
Depth From Depth To Survey/Plan Tool
39.00 1300.00 3S-606 wp06.1 (3S-606) SDI_URSA1_I4
1300.00 2760.00 3S-606 wp06.1 (3S-606) MWD+IFR2+SAG+MS
2760.00 8130.00 3S-606 wp06.1 (3S-606) MWD+IFR2+SAG+MS
8130.00 20117.57 3S-606 wp06.1 (3S-606) MWD+IFR2+SAG+MS
12:02, October 31 2023
CASING DETAILS
TVD MD Name
2565.30 2916.81 10-3/4" Surface Casing
5113.30 7350.18 7-5/8" Intermediate Casing
5150.20 20118.55 4-1/2" Production Liner
39 500
500 800
800 1100
1100 1500
1500 2000
2000 2500
2500 3000
3000 5000
5000 8000
8000 12000
12000 17000
17000 20119
3S-606 wp06.1 TC View
30
30
60
60
90
90
120
120
150
150
0
90
180
270
30
210
60
240 120
300
150
330
Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in]
486888108128148168188208
228248268288308328348368388408427447467487506526546565585604624643663682702721740760779
798
817
835
853
872
890
908
925
943
961
978
995
1013
1029
1046
3S-03
48
68881081281481681882082282482682883083283483683884074274474674865065265455655846046236436636827027227427617818008208408598788989179369569759941014103310521071109011091128114711671186120512241243126212811300131913381357137613951414143314521471
149015091528154815681588160816281647166516841700172117401758177717951813183218501868188619041923194119591976199420122029204720652082210021172134
3S-06
48
68881081281481681882082282482682883083283483683884074274474674865065265455655846046236436636827027227427617818008208408598788989179369569759941014103310521071109011091128114711671186120512241243126212811300131913381357137613951414143314521471
149015091528154815681588160816281647166516841700172117401758177717951813183218501868188619041923194119591976199420122029204720652082210021172134
486888108128148168188208228248268288308328348368388408428448468487507527547567586606626646665685705725744764784
804823
8428628819009209399589779961014103310511070
10881106112511431160117811961214
3S-07
48
6888108128148168188208228248268288308328348368387407427447466486505525544563582601621640659678697716735754773791
810
827
845
862
880
897
914
931 3S-08
48
6888108128148168188208228248268288308328348368387407427447466486505525544563582601621640659678697716735754773791
810
827
845
862
880
897
914
931
48
6888108128148168188208228248268288308328348368387407427447466486505525544563582601621640659678697716735754773791
810
827
845
862
880
897
914
931
49
6989109129149169189209229249269289309329349369389408428448467487506526545564583602622641660679698717736755774792
811
828
846
863
881
900
915
932
49
6989109129149169189209229249269289309329349369389408428448467487506526545564583602622641660679698717736755774792
811
828
846
863
881
900
915
932
49
6989109129149169189209229249269289309329349369389408428448467487506526545564583602622641660679698717736755774792
811
828
846
863
881
900
915
932
4868881081281481681882082282482682883083283483683884084284484684885085285485685886086286486676877077277467667868068258458658859049249439639821002102110401059107810971116113511531172119012091227124512631281129813161333
3S-09
48
6888108128148168188208228248268288308328348368388409429449469489509529549569590610630649669689709729748768787807827846866886905925944964983100310221041106110801099111811381157117611941213123212501269128713061324
3S-10
48688810812814816818820822824826828830832934936939041043045047149151153155257259261263265267269271173175177179081083085187189191293295297399310141034105510761096111711381159117912001221
26072627264626652684270227202738275627742792
3S-14
40416181101121141161181201221241261281301
321
34136138140142244246248250252254356358360362364366368370372374376378380382384386488490492494496598510051025104610661086110711271147116711871208122812481269128913091330135013711391141114323S-611
40416181101121141161181201221241261281301
321
3413613814014224424624825025225435635836036236436636837037237437637838038238438648849049249449659851005102510461066108611071127114711671187120812281248126912891309133013501371139114111432
3S-611PB1 416181101121141161181201221241261281301
321
3413613814024224424624825025235435635836036236436636837037237437637838038238438648849049249459659851005102610461066108611071127114711671188120812281249126912891310133013501371139114111432
40416181101121141
161181201221241261281301321341361381402422442
462482503523543563583604
624643663683703723743763783803823844864884905925945966986
10061027104710681088110911291149
3S-612
40406080100120140160180200220240260280300320340360381401421441461481501521541561581601621641660680700720739759779798818838857877
3S-613
406080100120140160180200220240260280300320
3403593793994194394594784985185385585775976176376566766967167357557757958148338538728919119309499689871006102510441063108211001119113711561174
11921211
12291247
1265
1283
1300
1319
1336
1354
1372
1389
1406
3S-701
406080100120140160180200220240260280300320
3403593793994194394594784985185385585775976176376566766967167357557757958148338538728919119309499689871006102510441063108211001119113711561174
11921211
12291247
1265
1283
1300
1319
1336
1354
1372
1389
1406
394363831031231431631832032232432632833033233433623824024224424624815015215415605805996196396586786977177377567767958158348538718909099289469659831000
1020
1038
1056
1074
1092
1110
1127
1145
1162
3S-704
587898118138158178198218238258278298318337357377397417437457477496516
53655657659661663665667669671673675677679681583585587589591593495497499410141034105410741094111411341154117411941214123412541274129413141334135413741395141514351455147514961516153615561575159516151635165516761696
3S-602 wp04
587898118138158178198218238258278298318338358
378397417437457
477497517537557577597617637657677697717737757777796816836856876896916936955975995101510351055107510951115113511551175119512151235125512751295131513351355137513951415143514551475149515151534
3S-605 wp04
587898118138158178198218238258278298318338358378398418438458479499519539559579599619639659679699719739759779799819839859879899919939959979999101910391059107910991119113911591179119912181238125812781298131813381357137713971417143614561476149515151535155415741594161416331653167216921711
3S-610 wp05
5878981181381581781982182382582782983183383583783994194394594805005205405615816016216416616817017217417617808008218418618819029229429629831003102410441065108511061126114711671188120912291250127112921312133313543S-714 wp03
587898118138158178198218238258278298318338358379399419439460480500520541561581
601621641661681701721741761781801821842862882903923943
3S-723 wp02
19767197861980519823198421986119879198981991719936199551997419993200122003220051200702009020109
3T-605 wp04 v5
SURVEY PROGRAM
Date: 2021-02-19T00:00:00 Validated: Yes Version:
From To Tool
39.00 1300.00 SDI_URSA1_I4
1300.00 2760.00 MWD+IFR2+SAG+MS
2760.00 8130.00 MWD+IFR2+SAG+MS
8130.00 20117.57 MWD+IFR2+SAG+MS
CASING DETAILS
TVD MD Name
2565.30 2916.81 10-3/4" Surface Casing
5113.30 7350.18 7-5/8" Intermediate Casing
5150.20 20118.55 4-1/2" Production Liner
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00
2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.50
3 600.00 4.50 330.30 599.69 10.23 -5.83 1.50 330.30 11.55 Start 200.00 hold at 600.00 MD
4 800.00 4.50 330.30 799.08 23.86 -13.61 0.00 0.00 26.94 Start Build 2.00
5 1000.00 8.50 330.30 997.75 43.52 -24.82 2.00 0.00 49.14 Start Build 2.50
6 1524.67 21.62 330.30 1503.30 161.67 -92.21 2.50 0.00 182.54 Start 107.57 hold at 1524.67 MD
7 1632.24 21.62 330.30 1603.30 196.09 -111.85 0.00 0.00 221.41 Start DLS 3.00 TFO -0.03
8 2712.82 54.03 330.28 2445.49 763.97 -435.97 3.00 -0.03 862.70 Start 4118.16 hold at 2712.82 MD
9 6830.98 54.03 330.28 4864.10 3658.55 -2088.54 0.00 0.00 4131.56 Start DLS 3.00 TFO 23.68
10 7934.45 85.00 343.00 5246.93 4598.27 -2481.64 3.00 23.68 5147.39 Start Build 2.00
11 8134.45 89.00 343.00 5257.40 4789.23 -2540.02 2.00 0.00 5347.01 3S-606 T01 062923 Start 20.00 hold at 8134.45 MD
12 8154.45 89.00 343.00 5257.75 4808.35 -2545.87 0.00 0.00 5367.00 Start DLS 1.50 TFO 64.62
13 8368.63 90.38 345.90 5258.91 5014.66 -2603.27 1.50 64.62 5580.87 Start 4089.85 hold at 8368.63 MD
1412458.48 90.38 345.90 5231.93 8981.24 -3599.44 0.00 0.00 9658.81 Start DLS 1.00 TFO -3.02
1512500.74 90.80 345.88 5231.50 9022.23 -3609.74 1.00 -3.02 9700.95 3S-606 T02 062923 Start DLS 1.00 TFO -6.51
1612557.47 91.36 345.82 5230.43 9077.22 -3623.61 1.00 -6.51 9757.50 Start 3274.37 hold at 12557.47 MD
1715831.84 91.36 345.82 5152.51 12250.87 -4425.74 0.00 0.0013021.85 Start DLS 1.00 TFO 179.67
1815908.20 90.60 345.82 5151.20 12324.89 -4444.45 1.00 179.6713097.99 3S-606 T03 062923 Start DLS 1.00 TFO 179.76
1915967.25 90.01 345.82 5150.89 12382.14 -4458.91 1.00 179.7613156.88 Start 4151.30 hold at 15967.25 MD
20 20118.56 90.01 345.82 5150.20 16407.00 -5475.68 0.00 0.0017296.61 3S-606 T04 062923 TD at 20118.56
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Ea
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9
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30
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3S-
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30
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3S-09
30
35
40
45
50
3S-
1
0
3
0
3
5
4
0
4
5
5
0
3S-14
3
0
3
5
4
0
4
5
5
0
3S-15
3
0
35 4 0
45
5 03S-16
30
35
40
45
50
3S-
1
7
30
35
40
45
50
3S-17
A
30
35
40
45
50
3S-
1
8 30
35
40
45
3S-
1
9
3S-
2
1
30
35
3S-
22
3S-23
3S-23
A
3S-
2
4
3S-
2
4
A
3S-
24
B 30
35
4 0
45
50
3S-
2
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30
35
40
45
50
PA
L
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1
30
35
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3S-
611
3S-611P
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1
30
35
40
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3S-611A
w
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30
35
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3S-61
2
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40
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1
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3S-
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3
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3S-
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30
35
40
45
50
3S-
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30
35
40
45
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30
3 5
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wp03
3S-721
wp03
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35
40 3S-7
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0
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3
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Northing (750 usft/in)
Ea
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7
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2 03S-03
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20
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1
20
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20
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3S-
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2
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2
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3
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3
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4
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4
5
5
0
3S-15
2
0
253
0
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3S-
1
6
20
25
30
35
40
45
50
3S-
17
20
25
30
35
40
45
50
3S-17
A
20
25
30
35
40
45
50
3S-
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20
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35
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3S-19
3S-21
20
25
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35
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3S-23
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3S-
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20
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20
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20
25
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35
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Ea
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2
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1
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10
12
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1
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1
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1
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1
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3S-606wp06.1 Surface Location
3S-606wp06.1 Surface Location
# Schlumberger-Confidential
3S-606wp06.1 Surface Casing
3S-606wp06.1 Surface Casing
# Schlumberger-Confidential
3S-606wp06.1 Intermediate Csg
3S-606wp06.1 Intermediate Csg
# Schlumberger-Confidential
3S-606wp06.1 Top Torok
3S-606wp06.1 Top Torok
# Schlumberger-Confidential
3S-606wp06.1 TD
3S-606wp06.1 TD
# Schlumberger-Confidential
1
Dewhurst, Andrew D (OGC)
From:Smith, Matt <Matt.Smith2@conocophillips.com>
Sent:Tuesday, December 5, 2023 06:29
To:Dewhurst, Andrew D (OGC)
Cc:Davies, Stephen F (OGC); Guhl, Meredith D (OGC); Roby, David S (OGC); Loepp, Victoria T (OGC); Warren, Abby
Subject:RE: [EXTERNAL]KRU 3S-606 (PTD 223-111) - Questions
HeyAndy,
ͲWedoplantopreͲproducethewellfor31days.We’llperformatoetestfor21days,thencompletethefrac,and
preproducetheremainderofthewellfor10more.
ͲAsfarasH2S,ourliŌgasfromCPF3has~200Ͳ250pppminit,asofa12/2sample,perourreservoirengineer.
IfyouhaveanyotherquesƟonspleasereachouttomyselforAbby,copiedhere.
Thankyou,
Matt Smith
Drilling Engineer – Kuparuk
700 G ST ANCHORAGE ALASKA, ATO-1566
OFFICE: +1.907.263.4324
CELL: +1.432.269.6432
MATT.SMITH2@COP.COM
From:Dewhurst,AndrewD(OGC)<andrew.dewhurst@alaska.gov>
Sent:Friday,December1,20233:12PM
To:Smith,Matt<Matt.Smith2@conocophillips.com>
Cc:Davies,StephenF(OGC)<steve.davies@alaska.gov>;Guhl,MeredithD(OGC)<meredith.guhl@alaska.gov>;Roby,
DavidS(OGC)<dave.roby@alaska.gov>;Loepp,VictoriaT(OGC)<victoria.loepp@alaska.gov>
Subject:[EXTERNAL]KRU3SͲ606(PTD223Ͳ111)ͲQuestions
CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you
recognize the sender and know the content is safe.
MaƩ,
IamcompleƟngthereviewoftheKRU3SͲ606andhaveacouplequesƟons:
x AreyouplanningonpreͲproducingthisinjector?Ihaverecordedthatthe3SͲ617wasplannedtodosofor~10
days.
x Also,anyupdated3SH2Sreadings?LastIreceivedwas:
615Ͳ160ppmon3/10/23
625–200ppmon01/01/23
704–100ppmon05/13/23
AddiƟonally,Iwantedtohighlighttheissuearoundwhat“signiĮcanthydrocarbons”couldmean(asforexamplein20
AAC25.030(d)(5)).ItdoesnotrelatetocommercialityormeeƟngaparƟcularproducƟonrate.However,inaddressing
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open
attachments unless you recognize the sender and know the content is safe.
2
thisquanƟtaƟvely,CPAIhasbeensharingresultswiththeAOGCCofapetrophysicalmodeldevelopedfromthelearnings
atCD1toanalyzeshallowHaloandTuluvaksandsandsiltsatCD4.NoacƟonneededatthisƟme,justFYI.
Thanks,
Andy
AndrewDewhurst
SeniorPetroleumGeologist
AlaskaOilandGasConservaƟonCommission
333W.7thAve,Anchorage,AK99501
andrew.dewhurst@alaska.gov
Direct:(907)793Ͳ1254
Revised 7/2022
TRANSMITTAL LETTER CHECKLIST
WELL NAME: ______________________________________
PTD: _____________________________________________
___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional
FIELD: __________________________ POOL: ____________________________________
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK OPTIONS TEXT FOR APPROVAL LETTER
MULTI
LATERAL
(If last two digits
in API number are
between 60-69)
The permit is for a new wellbore segment of existing well Permit
Number _____________, API Number 50-______________________.
Production from or injection into this wellbore must be reported under
the original API Number stated above.
Spacing
Exception
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce or inject is contingent upon issuance of a
conservation order approving a spacing exception. The Operator
assumes the liability of any protest to the spacing exception that may
occur.
Dry Ditch Sample
All dry ditch sample sets submitted to the AOGCC must be in no greater
than 30-foot sample intervals from below the permafrost or from where
samples are first caught and 10-foot sample intervals through target
zones.
Non-
Conventional
Well
Please note the following special condition of this permit: Production or
production testing of coal bed methane is not allowed for this well until
after the Operator has designed and implemented a water-well testing
program to provide baseline data on water quality and quantity. The
Operator must contact the AOGCC to obtain advance approval of such
a water-well testing program.
Well Logging
Requirements
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types
of well logs to be run. In addition to the well logging program proposed
by the Operator in the attached application, the following well logs are
also required for this well:
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
composite curves for all well logs run must be submitted to the AOGCC
within 90 days after completion, suspension, or abandonment of this
well, or within 90 days of acquisition of the data, whichever occurs first.
X
223-111
TOROK OIL POOLKUPARUK RIVER
KRU 3S-606
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16
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17
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24
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25
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26
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27
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28
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29
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30
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31
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32
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33
Is
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34
Me
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35
Pe
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.
36
Da
t
a
p
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s
e
n
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d
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n
p
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t
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a
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p
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s
s
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e
z
o
n
e
s
NA
37
Se
i
s
m
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c
a
n
a
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y
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o
f
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h
a
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o
w
g
a
s
z
o
n
e
s
NA
38
Se
a
b
e
d
c
o
n
d
i
t
i
o
n
s
u
r
v
e
y
(
i
f
o
f
f
-
s
h
o
r
e
)
NA
39
Co
n
t
a
c
t
n
a
m
e
/
p
h
o
n
e
f
o
r
w
e
e
k
l
y
p
r
o
g
r
e
s
s
r
e
p
o
r
t
s
[
e
x
p
l
o
r
a
t
o
r
y
o
n
l
y
]
Ap
p
r
AD
D
Da
t
e
12
/
5
/
2
0
2
3
Ap
p
r
VT
L
Da
t
e
12
/
1
9
/
2
0
2
3
Ap
p
r
AD
D
Da
t
e
12
/
1
/
2
0
2
3
Ad
m
i
n
i
s
t
r
a
t
i
o
n
En
g
i
n
e
e
r
i
n
g
Ge
o
l
o
g
y
Ge
o
l
o
g
i
c
Co
m
m
i
s
s
i
o
n
e
r
:
Da
t
e
:
En
g
i
n
e
e
r
i
n
g
Co
m
m
i
s
s
i
o
n
e
r
:
Da
t
e
Pu
b
l
i
c
Co
m
m
i
s
s
i
o
n
e
r
Da
t
e
