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HomeMy WebLinkAbout223-104KƌŝŐŝŶĂƚĞĚ͗ ĞůŝǀĞƌĞĚƚŽ͗ϭϭͲ&ĞďͲϮϲ,ĂůůŝďƵƌƚŽŶ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵ͘tŝƌĞůŝŶĞΘWĞƌĨŽƌĂƚŝŶŐ ƚƚŶ͗͘EĂƚƵƌĂůZĞƐŽƵƌĐĞdĞĐŚŶŝĐŝĂŶƚƚŶ͗&ĂŶŶLJ,ĂƌŽƵŶ ϯϯϯtĞƐƚϳƚŚǀĞŶƵĞ͕^ƵŝƚĞϭϬϬϲϵϬϬƌĐƚŝĐůǀĚ͘ ŶĐŚŽƌĂŐĞ͕ůĂƐŬĂϵϵϱϬϭŶĐŚŽƌĂŐĞ͕ůĂƐŬĂϵϵϱϭϴKĨĨŝĐĞ͗ϵϬϳͲϮϳϱͲϮϲϬϱ&Z^ͺEΛŚĂůůŝďƵƌƚŽŶ͘ĐŽŵdŚĞƚĞĐŚŶŝĐĂůĚĂƚĂůŝƐƚĞĚďĞůŽǁŝƐďĞŝŶŐƐƵďŵŝƚƚĞĚŚĞƌĞǁŝƚŚ͘WůĞĂƐĞĂĚĚƌĞƐƐĂŶLJƉƌŽďůĞŵƐŽƌĐŽŶĐĞƌŶƐƚŽƚŚĞĂƚƚĞŶƚŝŽŶŽĨƚŚĞƐĞŶĚĞƌĂďŽǀĞt >>ED W/η ^ Zs/ KZ Zη &/ >ED :KdzW ddzW >K''/E'd WZ/Ed^η /'/d>η ^ dηϭ ϭͲϮϬ ϱϬͲϬϮϵͲϮϮϭϭϮͲϬϬ ϵϭϬϱϵϳϯϰϯ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϮͲ&ĞďͲϮϲ Ϭ ϭϮ ϭͲϭϰϱ ϱϬͲϬϮϵͲϮϯϱϮϲͲϬϬ ϵϭϬϱϵϲϳϵϭ <ƵƉĂƌƵŬZŝǀĞƌ DƵůƚŝ&ŝŶŐĞƌĂůŝƉĞƌ&ŝĞůĚΘWƌŽĐĞƐƐĞĚ ϳͲ&ĞďͲϮϲ Ϭ ϭϯ ϭ&ͲϬϵ ϱϬͲϬϮϵͲϮϬϵϴϯͲϬϬ ϵϭϬϱϯϵϯϭϮ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϮϲͲ:ĂŶͲϮϲ Ϭ ϭϰ ϭ,ͲϭϬϭ ϱϬͲϬϮϵͲϮϯϱϴϱͲϬϬ ϵϭϬϱϯϵϰϯϭ <ƵƉĂƌƵŬZŝǀĞƌ DƵůƚŝ&ŝŶŐĞƌĂůŝƉĞƌ&ŝĞůĚΘWƌŽĐĞƐƐĞĚ ϭϴͲ:ĂŶͲϮϲ Ϭ ϭϱ ϮͲϭϰ ϱϬͲϭϬϯͲϮϬϬϰϬͲϬϬ ϵϭϬϱϵϳϯϰϮ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϳͲ&ĞďͲϮϲ Ϭ ϭϲ ϯ^ͲϲϮϰ ϱϬͲϭϬϯͲϮϬϴϲϴͲϬϬ ϵϭϬϱϯϵϭϴϰ <ƵƉĂƌƵŬZŝǀĞƌ WůƵŐ^ĞƚƚŝŶŐZĞĐŽƌĚ&ŝĞůĚͲ&ŝŶĂů ϮϯͲ:ĂŶͲϮϲ Ϭ ϭϳ ϯ^ͲϲϮϰ ϱϬͲϭϬϯͲϮϬϴϲϴͲϬϬ ϵϭϬϱϯϵϭϴϰ <ƵƉĂƌƵŬZŝǀĞƌ WůƵŐ^ĞƚƚŝŶŐZĞĐŽƌĚ&ŝĞůĚͲ&ŝŶĂů ϮϰͲ:ĂŶͲϮϲ Ϭ ϭϴ ϯ^ͲϲϮϰ ϱϬͲϭϬϯͲϮϬϴϲϴͲϬϬ ϵϭϬϱϯϵϭϴϰ <ƵƉĂƌƵŬZŝǀĞƌ dƵďŝŶŐWƵŶĐŚZĞĐŽƌĚ&ŝĞůĚͲ&ŝŶĂů ϮϱͲ:ĂŶͲϮϲ Ϭ ϭϵϭϬW> ^ <EKt> ' Z /Wdz^/'E/E'EZ dhZE/E'KWzK&d, dZE^D/dd>> dd ZdKd, dd Ed/KEK&͗&ĂŶŶLJ,ĂƌŽƵŶ͕,ĂůůŝďƵƌƚŽŶtŝƌĞůŝŶĞΘWĞƌĨŽƌĂƚŝŶŐ͕ϲϵϬϬƌĐƚŝĐůǀĚ͕͘ŶĐŚŽƌĂŐĞ͕<ϵϵϱϭϴ&Z^ͺEΛŚĂůůŝďƵƌƚŽŶ͘ĐŽŵĂƚĞ͗^ŝŐŶĞĚ͗dƌĂŶƐŵŝƚƚĂůĂƚĞ͗190-162214-138183-104217-138185-145223-104T41362T41363T41364T41365T41366T41367T41367T41367ϲ ϯ^ͲϲϮϰϱϬͲϭϬϯͲϮϬϴϲϴͲϬϬ ϵϭϬϱϯϵϭϴϰ<ƵƉĂƌƵŬZŝǀĞƌWůƵŐ^ĞƚƚŝŶŐZĞĐŽƌĚ&ŝĞůĚͲ&ŝŶĂůϮϯͲ:ĂŶͲϮϲϬϭϳ ϯ^ͲϲϮϰϱϬͲϭϬϯͲϮϬϴϲϴͲϬϬ ϵϭϬϱϯϵϭϴϰ<ƵƉĂƌƵŬZŝǀĞƌWůƵŐ^ĞƚƚŝŶŐZĞĐŽƌĚ&ŝĞůĚͲ&ŝŶĂůϮϰͲ:ĂŶͲϮϲϬϭϴ ϯ^ͲϲϮϰϱϬͲϭϬϯͲϮϬϴϲϴͲϬϬ ϵϭϬϱϯϵϭϴϰ<ƵƉĂƌƵŬZŝǀĞƌdƵďŝŶŐWƵŶĐŚZĞĐŽƌĚ&ŝĞůĚͲ&ŝŶĂůϮϱͲ:ĂŶͲϮϲϬϭ185 145223-104Gavin GluyasDigitally signed by Gavin Gluyas Date: 2026.02.11 13:44:36 -09'00'
Originated: Delivered to:31-Jan-26Alaska Oil & Gas Conservation Commiss31Jan26-NR
! "# $$%$ !&$$'($)*%+
($)*%,- .WELL NAME API #SERVICE ORDER #FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED3S-08C 50-103-20450-03-00 207163 Kuparuk River WL Cutter FINAL FIELD 5-Jan-263S-08C 50-103-20450-03-00 207163 Kuparuk River WL SCMT FINAL FIELD 6-Jan-263S-08C 50-103-20450-03-00 207163 Kuparuk River WL IBC-ASLT FINAL FIELD 12-Jan-26CD4-210B 50-103-20533-02-00 217182 Colville River WL LDL FINAL FIELD 19-Jan-26CD2-25 50-103-20418-00-00 202074 Colville River WL RBP-MechCutter FINAL FIELD 21-Jan-26CD1-40 50-103-20298-00-00 199044 Colville River WL RBP-MechCutter FINAL FIELD 24-Jan-263S-624 50-103-20868-00-00 223104 Kuparuk River WL MechCutter FINAL FIELD 26-Jan-26Transmittal Receipt//////////////////////////////// 0/////////////////////////////////
+
! 1 Please return via courier or sign/scan and email a copy to Schlumberger. " 2"3 +45
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T41299T41299T41299T41300T41301T41302T413033S-62450-103-20868-00-00223104Kuparuk RiverWLMechCutterFINAL FIELD26-Jan-26Gavin GluyasDigitally signed by Gavin Gluyas Date: 2026.02.02 09:10:17 -09'00'
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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 Replace Tubing/ESP:
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?
Yes No
9. Property Designation (Lease Number): 10. Field:
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
20485' None
Casing Collapse
Conductor
Surface
Intermediate
Liner
Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft):
12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations: OIL WINJ WDSPL Suspended
16. Verbal Approval: Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name:
Contact Email:
Contact Phone:
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
1/10/2026
19685'13082'
4-1/2"
5158'
Packer: HAL TNT Production Packer
ZXP Liner Top Packer
SSSV: None
Perforation Depth MD (ft):
L-80
7544'
2968'
7581'
None
4-1/2"
None
Perforation Depth TVD (ft):
155'
3049'
20"
10-3/4"
115'
7-5/8"
6610' MD
MD
155'
2555'
5128'
ConocoPhillips Alaska, Inc.
Length Size
Proposed Pools:
PRESENT WELL CONDITION SUMMARY
Torok Oil Pool
TVD Burst
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0025528, ADL00380107, ADL00380106, ADL00393883
223-104
P.O. Box 100360, Anchorage, AK 99510 50-103-20868-00-00
Kuparuk River Field Torok Oil Pool
AOGCC USE ONLY
Tubing Grade: Tubing MD (ft):
6368' MD and 4521' TVD
6603'MD and 4662' TVD
N/A
Adam Klem
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:
adam.klem@conocophillips.com
(907) 263-4529
CTD/RWO Engineer
KRU 3S-624
5156' 20485' 5156' 1132' None
N/A
approval: Notify AOGCC so that a representative may witness Sundry Number:
BOP Test Mechanical Integrity Test Location Clearance
ons of Approval:
ection MIT Req'd? Yes No Subsequent Form Required:
Suspension Expiration Date:
AOGCC USE ONLY
Contact Name:
Contact Email:
Contact Phone:
e:
Adam Klem
certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
me and
ure with Date:adam.klem@conocophillips.com
(907) 263-4529
CTD/RW O Engineer
15. Well Status after proposed work:
OIL WINJ WDSPL Suspended
GAS WAG GSTOR SPLUG
GINJ Op Shutdown Abandoned
proval:Date:
esentative:
Date for
Operations:1/10/2026
13. Well Class after proposed work:
Exploratory Stratigraphic Development Service
nts: Proposal Summary Wellbore schematic
ations Program BOP Sketch
SSSV Type:Packers and SSSV MD (ft) and TVD (ft):Packer: HAL TNT Production Packer
ZXP Liner Top Packer
SSSV: None
6368'MD and 4521'TVD
6603'MD and 4662' TVD
N/A
4-1/2"
pth MD (ft):
L-80None
Perforation Depth TVD (ft):
6610' MD
Tubing Grade: Tubing MD (ft):Tubing Size:
5158'19685'4-1/2"13082'
5128'7581'7-5/8"7544'ate
2555'3049'10-3/4"2968'e
155'155'20"115'or
CollapseBurstTVDMDSizeLengthg
Junk (MD):
None
Plugs (MD):MPSP (psi):Effective Depth TVD:Effective Depth MD:Total Depth TVD (ft):D (ft):
5156'20485'5156'1132'None
PRESENT WELL CONDITION SUMMARY
esignation (Lease Number):10. Field:Proposed Pools:
Torok Oil PoolADL00380107, ADL00380106, ADL00393883 Kuparuk River Field Torok Oil Pool
Current Pools:
8. Well Name and Number:g:
ation or Conservation Order governs well spacing in this pool?
Yes Noquire a spacing exception due to property boundaries?
KRU 3S-624N/A
5.Permit to Drill Number:
6.API Number:
223-104
50-103-20868-00-00
4.Current W ell Class:
Exploratory Development
Stratigraphic Service
360, Anchorage, AK 99510
ame:
s Alaska, Inc.
quest: Abandon Plug Perforations Fracture Stimulate Reppair Well Operations shutdown
Suspend Perforate Other Stimulate Pulll Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alteer Casing Replace Tubing/ESP:
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
325-753
By Grace Christianson at 3:50 pm, Dec 11, 2025
AOGCC witnessed BOP and Annular test to 2500 psi.
TS 12/12/25 DSR-12/19/25
10-404
X
J.Lau 12/30/25
12/30/25
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
December 9, 2025
Commissioner
State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 99501
Dear Commissioner:
ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KRU 3S-624 (PTD#
223-104).
Well 3S-624 was spudded in December of 2023 and completed in January of 2024. Immediately after
completion, drifts for the ESP pump and motor failed. Further diagnostics have revealed a restriction at a gas lift
mandrel, hindering our ability to run the ESP pump and motor.
We are requesting approval to proceed with a rig workover. We plan to pull the 4-1/2 ESP completion, perform
a cleanout run as needed, then install a new 4-1/2 ESP completion.
If you have any questions or require any further information, please contact me at 907-263-4529.
Adam Klem
Rig Workover Engineer
CPAI Drilling and Wells
3S-624 Moraine Producer Pull and Replace ESP Completion PTD: 223-104
Page 1 of 2
Pre-Rig Work Remaining
1. T-POT and PPPOT. IC-POT and PPPOT.
2. Pull iso sleeve from ACP
3. Dummy off GLM
4. New SBHP
5. Set plug below TNT packer
6. PT tbg and IA to 2,500 psi for 30 minutes.
7. Shift sliding sleeve or pull valve from GLM for circulation point.
8. Cut tubing at ~6,300 MD
9. Prepare well for rig arrival.
Rig Work
MIRU
1. MIRU Nabors 7ES on 3S-624. No BPV will be set for MIRU due to Nabors 7ES internal risk
assessment.
2. Circulate seawater and complete 30-minute NFT. Verify well is dead.
3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test
annular 250/2,500 psi.
Retrieve 4-1/2 Access ESP Completion
4. Pull BPV, MU landing joint and BOLDS.
5. Pull 4-1/2 tubing string and jewelry from pre rig tubing cut at ~6,300 MD
Casing Cleanout/Drift Run
6. MU cleanout/drift BHA, PU drillpipe and perform casing cleanout to tubing stub as needed,
based on tubing condition.
Install New 4-1/2 Access ESP Completion
7. MU new 4-1/2 completion with poorboy overshot, packer, nipples, AccessESP assembly,
downhole gauge, and gas lift mandrels. RIH to tubing stub.
8. Once on depth, overshot stub, calculate space out. Circulate corrosion inhibited fluid.
9. Land tubing, land tubing hanger, RILDS.
10. Drop ball and rod. Pressure up to set packer.
11. Pressure test tubing to 3,000 psi for 30 minutes.
12. Pressure test IA to 2,500 psi for 30 minutes.
ND BOP, NU Tree
13. Confirm pressure tests, then shear out SOV.
14. Install BPV and test. ND BOPE. NU tree and PT packoffs.
15. Pull BPV and freeze protect well.
16. RDMO.
3S-624 Moraine Producer Pull and Replace ESP Completion PTD: 223-104
Page 2 of 2
Post-Rig Work
1. Pull SOV. Install new DMY.
2. Pull ball and rod, RHC plug
3. Pull pre rig set plug
4. Install retrievable AccessESP assembly.
General Well Information:
Estimated Start Date: 1/10/25
Current Operations: Flowing on gas lift
Well Type: Producer
Wellhead Type: Cameron MBS 5k
Scope of Work: Perform a like-kind pull and replace of the 4-1/2 AccessESP. Pull the existing 4-
1/2 AccessESP completion from cut, perform a cleanout run as needed based
on tubing condition, then install a new 4-1/2 AccessESP completion.
BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams
Following subject to change with Pre-Rig Work:
MIT Results:
MIT-IA: Passed when installed (2,500 psi) and planned pre rig
MIT-OA: Open Shoe
Tubing POT & PPPOT: Passed when installed and planned pre rig
IC POT & PPPOT: Passed when installed and planned pre rig
Static BHP: 1,560 psi / 4,278 TVD measured in June 2025 (new one planned)
MPSP: 1132 psi using 0.1 psi/ft gradient
Personnel:
Workover Engineer: Adam Klem (907-263-4529 / adam.klem@conocophillips.com)
Production Engineer: Sydney Autry
Top Coyote @ 5649' MD / 4092' TVD
3S-624 Wellbore Schematic
Grassroots Horizontal Moraine Producer
10-¾" 45.5# L-80 H563 @ 3,049 MD / 2,555' TVD, 55° Inc
Conductor @ 155'
4-½" 12.6# P110S H563 @19,685' MD / 5,158' TVD
4-½12.6# L80 H563-MS
9-" Intermediate Hole
6-1/2" Production Hole
KlaShield WBM13-½" Surface Hole
7-" 29.7# L-80 H563 @ 7,581' MD / 5,128' TVD, 73° Inc
1/24/2024
6" OD Swell Packer Frac sleeveFWPSpud Mud5-½ x 7-5/8" SLZXP Packer @6,603' MD / 4,661' TVD
TOC @ 3,435' MD / 2,778' TVD
Gauge Mandrel, Dual Opsis
Top Torok (Moraine) @ 7690' MD / 5157' TVD
Rigless ESP, ACP ~6170' MD/4403' TVD 53° Inc
Sliding sleeve (3.813" ID)
Gas Lift Mandrel, 4-½ x 1 (DV installed)
Gas Lift Mandrel, 4-½ x 1
Alpha Sleeve (close)
WIV (open)
6-½" TD @ 20,485' MD / 5,156' TVD, 90° INC
4-½ x 7-5/8" Production Packer @6368' MD/4521' TVD
Swell Packer #24 @6,965' MD
Swell Packer #23 @7,458' MD
7-" 29.7# L80 H563 to 6,862' MD
7-" 33.7# P-110S H563 from 6,862' to 7,454' MD (heavy heel)
3.813" X nipple
4-½ x 7-5/8" Production Packer w/ Seal assembly
Top Coyote @ 5649' MD / 4092' TVD
3S-624 Wellbore Schematic
Grassroots Horizontal Moraine Producer
10-¾" 45.5# L-80 H563 @ 3,049 MD / 2,555' TVD, 55° Inc
Conductor @ 155'
4-½" 12.6# P110S H563 @19,685' MD / 5,158' TVD
4-½12.6# L80 H563-MS
9-" Intermediate Hole
6-1/2" Production Hole
KlaShield WBM13-½" Surface Hole
7-" 29.7# L-80 H563 @ 7,581' MD / 5,128' TVD, 73° Inc
1/24/2024
6" OD Swell Packer Frac sleeveFWPSpud Mud5-½ x 7-5/8" SLZXP Packer @6,603' MD / 4,661' TVD
TOC @ 3,435' MD / 2,778' TVD
Gauge Mandrel, Dual Opsis 5961' MD/4278' TVD 53° Inc
Top Torok (Moraine) @ 7690' MD / 5157' TVD
Rigless ESP, ACP 6170' MD/4403' TVD 53° Inc
Sliding sleeve (3.813" ID) 6263' MD/4458' TVD 53° Inc
Gas Lift Mandrel, 4-½ x 1 (DV installed) 4491' MD/3400' TVD 53° Inc
Gas Lift Mandrel, 4-½ x 1 (SOV sheard) 2105' MD/1975' TVD 41° Inc
Alpha Sleeve (close)
WIV (open)
6-½" TD @ 20,485' MD / 5,156' TVD, 90° INC
4-½ x 7-5/8" Production Packer @6368' MD/4521' TVD
Swell Packer #24 @6,965' MD
Swell Packer #23 @7,458' MD
7-" 29.7# L80 H563 to 6,862' MD
7-" 33.7# P-110S H563 from 6,862' to 7,454' MD (heavy heel)
Diesel Freeze Protect
9.5# Corrosion Inhibited Brine
Originated: Delivered to:8-Jul-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPEDATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 2A-18 50-103-20220-00 910149874 Kuparuk River Packer Setting Record Field- Final 24-Jun-25 0 12 2K-29 50-103-20867-00 910153613 Kuparuk River Multi Finger Caliper Field & Processed 5-Jul-25 0 13 3S-624 50-103-20868-00 910133399 Kuparuk River Multi Finger Caliper Field & Processed 18-Jun-25 0 145678910PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:195-059214-025223-104T40650T40651T406527/9/202533S-62450-103-20868-00910133399Kuparuk RiverMulti Finger CaliperField & Processed18-Jun-2501Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.07.09 09:32:58 -08'00'
Originated: Delivered to:27-Mar-25Alaska Oil & Gas Conservation Commiss27Mar25-NR
! "# $$%$ !&$$'($)*%+
($)*%,- .WELL NAME API #SERVICE ORDER #FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPE DATE LOGGEDMT7-15 50-103-20885-00-00 224-037 Greater Mooses Tooth WL TTiX-PPROF FINAL FIELD 5-Feb-251H-106 50-029-23800-00-00 224-117 Kuparuk River WL TTiX-PPROF FINAL FIELD 22-Feb-251C-157 50-029-23754-00-00 223-038 Kuparuk River WL TTiX-FSI FINAL FIELD 27-Feb-25CD3-127 50-103-20634-00-00 211-005 Colville River WL Patch&Packer FINAL FIELD 8-Mar-251C-151 50-029-23497-00-00 213-123 Kuparuk River WL TTiX-FSI FINAL FIELD 12-Mar-253S-624 50-103-20868-00-00 223-104 Kuparuk River WL TTiX-FSI FINAL FIELD 22-Mar-25Transmittal Receipt//////////////////////////////// 0/////////////////////////////////
+
! 1 Please return via courier or sign/scan and email a copy to Schlumberger. " 2"3 +45
%TRANSMITTAL DATETRANSMITTAL #1
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T40238T40239T40240T40241T40242T402433S-62450-103-20868-00-00223-104Kuparuk RiverWLTTiX-FSIFINAL FIELD22-Mar-25Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.03.28 08:11:16 -08'00'
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 20485 feet feet
true vertical 5156 feet feet
Effective Depth measured 20485 feet 6368/ 6603 feet
true vertical 5156 feet 4521/ 4661 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# L-80 6,609' MD 4,665' TVD
SLZXP LTP 6,603' MD 4,661' TVD
Packers and SSSV (type, measured and true vertical depth)HAL TNT 6,368' MD 4,521' 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:12-Mar-24 Contact Name:Baskoro Tejo
Contact Email:Baskoro.tejo@conocophillips.com
Authorized Title:Completion Engineer Contact Phone:907-265-6462
3048.5 2554.7
Burst Collapse
2470
4790
7850
5210
6890
10860
measured
TVD
Intermediate
Liner
6824.9
592
13081.7
Casing
Structural
5217.6
5130
4-1/2"
6862
7581.3
19685 5157.6
Plugs
Junk measured
3.998 MMlbs of 16/20 Wanli Ceramic Proppant, 98,000 lbs of 100 Mesh, and 3400 psi treating pressure/ 4500 psi BHG pressure
Length
115.3
3008.8
155Conductor
Surface
Intermediate
20"
10-3/4"
Job logs attached
5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work:
ADL380107 / ADL380106 / ADL0255528 / ADL393883
Kuparuk Field/ Torok Oil Pool
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
223-104
50-103-20868-00-00
Size
155
N/A
7-5/8"
11590
7-5/8"
P.O. Box 100360 Anchorage, AK 99510-03603. Address:
KRU 3S-624
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
TBD
Gas-Mcf
MD
8401' MD - 19444' MD
measured
true vertical
Packer
Representative Daily Average Production or Injection Data
Casing Pressure Tubing Pressure
324-048
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.
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 10:10 am, Mar 12, 2024
RBDMS JSB 031424
CDW 03/18/2024
DSR-3/12/24
Sales Order#
Prepared By:
William Martin
Daniel Faur
Nannook Crew
909143939
Intervals 1-22
Notice:Althoughtheinformationcontainedinthisreportisbasedonsoundengineeringpractices,thecopyright
owner(s)does(do)notacceptanyresponsibilitywhatsoever,innegligenceorotherwise,foranylossordamage
arisingfromthepossessionoruseofthereportwhetherintermsofcorrectnessorotherwise.Theapplication,
therefore,bytheuserofthisreportoranypartthereof,issolelyattheuser’sownrisk.
3S-624
Conoco Phillips
Harrison Bay County, AK
Post Job Report
Stimulation Treatment
API: 50-103-20868
Prepared for: Manabu Nozaki
February 20, 2024
Torok Formation
30# Hybor G
Table of Contents
Section Page(s)
ExecutiveSummary
ActualDesign
WellboreInformation
IntervalSummary
FluidSystemͲProppantSummary
Interval1Plots
Interval2Plots
Interval3Plots
Interval4Plots
Interval5Plots
Interval6Plots
Interval7Plots
Interval8Plots
Interval9Plots
Interval10Plots
Interval11Plots
Interval12Plots
Interval13Plots
Interval14Plots
Interval15Plots
Interval16Plots
Interval17Plots
Interval18Plots
Interval19Plots
Interval20Plots
Interval21Plots
Interval22Plots
Appendix
WellSummary
ChemicalSummary
PlannedDesign
WaterStrapsDay1
WaterStrapsDay2
WaterStrapsDay3
WaterStrapsDay4
WaterStrapsDay5
WaterStrapsDay6
WaterStrapsDay7
WaterAnalysis2Ͳ10
WaterAnalysis2Ͳ16
WaterAnalysis2Ͳ17
WaterAnalysis2Ͳ18
WaterAnalysis2Ͳ19
RealͲTimeQC
RealͲTimeQC2
EventLogDay1
EventLogDay2
EventLogDay3
EventLogDay4
EventLogDay5
EventLogDay6
EventLogDay7
PrejobBreakTest
Zone1
Zone2
Zone3
Zone4
Zone5
Zone6
Zone7
Zone8
Zone9
Zone10
Zone11
Zone12
Zone13
Zone14
Zone15
Zone16
SandSieveAnalysis 213Ͳ214
208
209
210
211
212
203
204
205
206
207
198
199
200
201
202
193
194
195
196
197
188
189
190
191
192
183
184
185
186
187
178
179
180
181
182
168
169Ͳ174
175
176
177
150Ͳ156
157Ͳ160
161Ͳ165
166
167
126Ͳ133
134Ͳ137
138Ͳ141
142Ͳ145
146Ͳ149
122Ͳ125
3
4Ͳ8
9
64Ͳ67
68Ͳ75
76Ͳ81
10Ͳ40
41
42Ͳ55
56Ͳ63
82Ͳ89
90Ͳ93
118Ͳ121
94Ͳ97
98Ͳ101
102Ͳ109
110Ͳ113
114Ͳ117
ConocoPhillipsͲ3SͲ624 TOC 2
1,830,778 gallons of 30# Hybor G
124,893 gallons of 30# Linear
91,438 gallons of Seawater
9,730 gallons of Freeze Protect
3,980,000 pounds of Wanli 16/20 Ceramic
88,000 pounds of 100M
1,882,815 gallons of 30# Hybor G
130,876 gallons of 30# Linear
101,818 gallons of Seawater
19,506 gallons of Freeze Protect
3,998,163 pounds of Wanli 16/20 Ceramic
98,000 pounds of 100M
Thank you,
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 February 12, 2024 a stimulation treatment was performed in the Torok formation on the 3S-624 well in Harrison Bay
County, AK. The 3S-624 was a 24 stage Horizontal Sleeve Design. The proposed treatment consisted of:
The actual treatment fully completed 22 of 22 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:
Interval 1 was successfully pumped through the toe, however after seating the first ball drop to open Interval 02 the sleeve did
not initially shift. Frac operations were paused until the ball dissolved and XL in the wellbore could be displaced to formation. A
second ball was dropped with seawater and the sleeve succesfully shifted after pressuring up and bleeding off multiple time. The
decision was made to cut XL and displace the ball with gel through interval 7. After Interval 7 the ball was displaced in XL but
breakers were kept at a high concentration. These changes in the design increased the fluid volume and chemical volumes
beyond the initial design.
Between Interval 14 and 15, operations were shut down for a day to run a WL imaging log. Frac pumped down 41,948 gal of SW
and 1,680 gal of gel during the Wireline Operations.
Intervals 1-22 were pumped to completion. There was an attempt to open the sleeve for interval 24 but no pressure indication
that the ball seated in the collet and opened the sleeve.
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.
This was the first job that water was injected on the fly. Decision was made to increase the supply side water temperature to aid
in the CL-28M activation time. It was observed that lip time decreased in the QA with warmer water. During the job, MO-67 was
pumped raw at a set point of 0.33 to acheive a pH in the 8.9-9.1 range.
Willie Martin
Senior Technical Professional
Conoco PhillipsͲ3SͲ624 Executive Summary 3
22 of 22 stages.
CUSTOMERConocoPhillipsAPI BFD(lb/gal)8.54LAT70.39402791LEASE3SͲ624SALESORDEBHST(°F)141LONGͲ150.1984279FORMATIONTorokDATE MaxPressure(psi)8500*Exceeds80%ofburstpressure*Prop Slurry DesignClean ActualClean ActualClean CalculatedSlurry DesignProp CalculatedProp CLͲ28M LosurfͲ300D MOͲ67 WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total TotalCrosslinker Surfactant BufferInterval Number Description Description Description(ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)1Ͳ1 ShutͲIn ShutͲInͲ1Ͳ2 FreezeProtect PrimeUpPressureTest 5.0 1,000 50 1 11Ͳ3 ShutͲIn ShutͲInͲ1Ͳ4 Seawater ArsenalSleeveShift 5.0 1,260 107 3 30.151Ͳ5SeawaterDisplaceBalltoSeat 5.0 12,427 12,976 309 3090.151Ͳ6 Seawater DFIT 10.0 1,680 2,605 62 620.151Ͳ7 ShutͲIn ShutͲInͲ1Ͳ8 30#Linear Flush 10.0 1,680 5,355 128 128 1.00 30.00 2.00 0.25 0.151Ͳ9 ShutͲIn ShutͲInͲ1Ͳ10 ShutͲIn ShutͲIn 10.0Ͳ1Ͳ11 FreezeProtect PrimeUpPressureTest 5.0 1,000 50 1 11Ͳ12 ShutͲIn ShutͲInͲ1Ͳ13 30#Linear StepRateTest 10.0 2,000 3,925 93 93 1.00 30.00 2.00 0.25 0.151Ͳ14 30#HyborG EstablishStableFluid15.0 8,400 23,994 571 571 2.00 1.00 0.33 30.00 2.00 0.25 0.151Ͳ15 30#HyborG Pad 37.0 48,400 52,434 1,248 1,248 2.00 1.00 0.33 30.00 2.00 0.25 0.151Ͳ16 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 18,560 442 445 4,000 3,231 2.00 1.00 0.33 30.00 2.00 0.25 0.151Ͳ17 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 12,000 12,796 305 318 12,000 12,832 2.00 1.00 0.33 30.00 2.00 0.25 0.151Ͳ18 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 18,000 17,837 425 456 36,000 29,732 2.00 1.00 0.33 30.00 2.00 0.25 0.151Ͳ19 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 18,000 17,988 428 487 54,000 55,725 2.00 1.00 0.33 30.00 2.00 0.25 0.151Ͳ20 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 12,000 11,986 285 338 48,000 49,233 2.00 1.00 0.33 30.00 2.00 0.25 0.151Ͳ21 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 10,000 13,519 322 384 50,000 58,132 2.00 1.00 0.33 30.00 2.00 2.00 0.151Ͳ22 30#HyborGSpacerandBallDrop 37.0 1,260 9,302 221 221 2.00 1.00 0.33 30.00 2.00 0.25 0.152Ͳ1 30#HyborG MinifracͲTreatment 37.0 18,900 12,192 290 290 2.00 1.00 0.33 30.00 2.00 0.25 0.152Ͳ2SeawaterDisplaceBalltoSeat 37.0 12,454 146 3 30.152Ͳ3 Seawater ShutͲInͲ0.152Ͳ4 ShutͲIn ShutͲInͲ2Ͳ5 FreezeProtect PrimeUpPressureTest 15.0 1,260 2,000 48 482Ͳ6 ShutͲIn ShutͲInͲ2Ͳ7SeawaterSpacerandBallDrop 15.0 1,260 3,472 83 83 1.00 0.152Ͳ8SeawaterDisplaceBalltoSeat 37.0 12,089 11,906 283 283 1.00 0.152Ͳ9 Seawater ShutͲInͲ0.152Ͳ10 30#HyborG EstablishStableFluid15.0 8,400 12,000 286 286 2.00 1.00 0.45 30.00 2.00 0.25 0.152Ͳ11 30#HyborG Pad 37.0 36,450 37,291 888 888 2.00 1.00 0.43 30.00 2.00 0.25 0.152Ͳ12 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 17,303 412 417 4,000 4,295 2.00 1.00 0.39 30.00 2.00 0.25 0.152Ͳ13 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 12,000 12,288 293 305 12,000 11,647 2.00 1.00 0.39 30.00 2.00 0.25 0.152Ͳ14 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 18,000 18,011 429 472 36,000 40,456 2.00 1.00 0.35 30.00 2.00 0.25 0.152Ͳ15 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 18,000 18,000 429 489 54,000 56,972 2.00 1.00 0.33 30.00 2.00 0.25 0.152Ͳ16 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 12,000 11,758 280 332 48,000 48,737 2.00 1.00 0.33 30.00 2.00 0.25 0.152Ͳ17 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 10,000 9,712 231 277 50,000 42,933 2.00 1.00 0.33 30.00 2.00 2.00 0.152Ͳ18 30#Linear SpacerandBallDrop 37.0 1,260 1,774 42 42 1.00 30.00 2.00 2.00 0.153Ͳ1 30#Linear DisplaceBalltoSeat 15.0 11,757 11,694 278 278 1.00 30.00 2.00 0.25 0.153Ͳ2 30#HyborG EstablishStableFluid15.0 8,400 8,739 208 208 2.00 1.00 0.33 30.00 2.00 0.25 0.153Ͳ3 30#HyborG Pad 37.0 27,000 27,561 656 656 2.00 1.00 0.33 30.00 2.00 0.25 0.153Ͳ4 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 16,381 390 395 4,000 4,622 2.00 1.00 0.33 30.00 2.00 0.25 0.153Ͳ5 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 12,000 12,091 288 301 12,000 11,907 2.00 1.00 0.33 30.00 2.00 0.25 0.153Ͳ6 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 18,000 17,995 428 465 36,000 34,320 2.00 1.00 0.33 30.00 2.00 0.25 0.153Ͳ7 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 18,000 17,983 428 488 54,000 56,368 2.00 1.00 0.33 30.00 2.00 0.25 0.153Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 12,000 12,009 286 337 48,000 48,254 2.00 1.00 0.33 30.00 2.00 0.25 0.153Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 10,000 9,697 231 274 50,000 40,737 2.00 1.00 0.33 30.00 2.00 2.00 0.153Ͳ10 30#Linear Flush 37.0 12,122 12,227 291 291 1.00 30.00 2.00 2.00 0.153Ͳ11 ShutͲIn ShutͲInͲ4Ͳ1 ShutͲIn ShutͲInͲ4Ͳ2 FreezeProtect PrimeUpPressureTest 15.0 1,000 3,000 71 714Ͳ3 ShutͲIn ShutͲInͲ4Ͳ4 30#Linear SpacerandBallDrop 15.0 1,260 1,129 27 27 1.00 30.00 2.00 0.25 0.154Ͳ5 30#Linear DisplaceBalltoSeat 15.0 11,424 11,749 280 280 1.00 30.00 2.00 0.25 0.154Ͳ6 30#HyborG EstablishStableFluid15.0 8,400 7,454 177 177 2.00 1.00 0.33 30.00 2.00 0.25 0.154Ͳ7 30#HyborG Pad 37.0 28,250 28,381 676 676 2.00 1.00 0.33 30.00 2.00 0.25 0.154Ͳ8 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 16,360 390 394 4,000 4,095 2.00 1.00 0.33 30.00 2.00 0.25 0.154Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 12,000 12,044 287 297 12,000 9,821 2.00 1.00 0.33 30.00 2.00 0.25 0.154Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 18,000 18,052 430 469 36,000 36,738 2.00 1.00 0.33 30.00 2.00 0.25 0.154Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 18,000 18,015 429 488 54,000 55,955 2.00 1.00 0.33 30.00 2.00 0.25 0.154Ͳ12 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 12,000 12,027 286 339 48,000 49,494 2.00 1.00 0.33 30.00 2.00 0.25 0.154Ͳ13 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 10,000 10,950 261 311 50,000 47,446 2.00 1.00 0.33 30.00 2.00 2.00 0.154Ͳ14 30#Linear SpacerandBallDrop 37.0 1,260 1,020 24 24 1.00 30.00 2.00 2.00 0.155Ͳ1 30#Linear DisplaceBalltoSeat 15.0 11,090 12,412 296 296 1.00 30.00 2.00 2.00 0.155Ͳ2 Seawater DFIT 10.0 1,680 2,816 67 670.155Ͳ3 ShutͲIn ShutͲInͲ5Ͳ4 30#HyborG EstablishStableFluid15.0 8,400 9,518 227 227 2.00 1.00 0.33 30.00 2.00 0.25 0.155Ͳ5 30#HyborG Pad 37.0 24,500 24,772 590 590 2.00 1.00 0.33 30.00 2.00 0.25 0.155Ͳ6 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 16,285 388 392 4,000 3,791 2.00 1.00 0.33 30.00 2.00 0.25 0.155Ͳ7 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 12,000 12,008 286 297 12,000 10,186 2.00 1.00 0.33 30.00 2.00 0.25 0.155Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 18,000 18,039 430 470 36,000 37,847 2.00 1.00 0.33 30.00 2.00 0.25 0.155Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 18,000 17,995 428 486 54,000 54,639 2.00 1.00 0.33 30.00 2.00 0.25 0.155Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 12,000 12,047 287 338 48,000 48,645 2.00 1.00 0.33 30.00 2.00 0.25 0.155Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 10,000 11,139 265 316 50,000 47,445 2.00 1.00 0.33 30.00 2.00 0.25 0.155Ͳ12 30#Linear Flush 37.0 11,455 11,568 275 275 1.00 30.00 2.00 2.00 0.155Ͳ13 ShutͲIn ShutͲInͲInterval 1Torok@ 19441 - 19444.86 ft 139.5 °FInterval 2Torok@ 18913.47 - 18917.33 ft 139.6 °FInterval 3Torok@ 18392.71 - 18396.57 ft 139.6 °FInterval 4Torok@ 17871.67 - 17875.53 ft 139.7 °FInterval 5Torok@ 17349.2 - 17353.06 ft 139.7 °FLiquidAdditives DryAdditives50Ͳ103Ͳ20868909143939ConocoPhillipsͲ3SͲ624ActualDesign4
CUSTOMERConocoPhillipsAPI BFD(lb/gal)8.54LAT70.39402791LEASE3SͲ624SALESORDEBHST(°F)141LONGͲ150.1984279FORMATIONTorokDATE MaxPressure(psi)8500*Exceeds80%ofburstpressure*Prop Slurry DesignClean ActualClean ActualClean CalculatedSlurry DesignProp CalculatedProp CLͲ28M LosurfͲ300D MOͲ67 WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total TotalCrosslinker Surfactant BufferInterval Number Description Description Description(ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)LiquidAdditives DryAdditives50Ͳ103Ͳ208689091439396Ͳ1 ShutͲIn ShutͲInͲ6Ͳ2 FreezeProtect PrimeUpPressureTest 5.0 1,000 2,100 50 506Ͳ3 ShutͲIn ShutͲInͲ6Ͳ4 30#Linear SpacerandBallDrop 15.0 1,260 1,000 24 24 1.00 30.00 2.00 0.25 0.156Ͳ5 30#Linear DisplaceBalltoSeat 15.0 10,757 10,838 258 258 1.00 30.00 2.00 0.25 0.156Ͳ6 30#Linear DFIT 10.0 1,680 2,415 58 58 1.00 30.00 2.00 0.25 0.156Ͳ7 ShutͲIn ShutͲInͲ6Ͳ8 30#HyborG EstablishStableFluid15.0 8,400 7,597 181 181 2.00 1.00 0.33 30.00 2.00 0.25 0.156Ͳ9 30#HyborG Pad 37.0 19,500 20,027 477 477 2.00 1.00 0.33 30.00 2.00 0.25 0.156Ͳ10 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 15,757 375 379 4,000 3,423 2.00 1.00 0.33 30.00 2.00 0.25 0.156Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 12,000 12,027 286 297 12,000 10,164 2.00 1.00 0.33 30.00 2.00 0.25 0.156Ͳ12 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 15,000 15,129 360 393 30,000 30,939 2.00 1.00 0.33 30.00 2.00 0.25 0.156Ͳ13 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 16,600 16,627 396 449 49,800 49,723 2.00 1.00 0.33 30.00 2.00 0.25 0.156Ͳ14 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 7,500 7,522 179 212 30,000 30,610 2.00 1.00 0.33 30.00 2.00 0.25 0.156Ͳ15 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 6,200 6,395 152 184 27,900 29,516 2.00 1.00 0.33 30.00 2.00 0.25 0.156Ͳ16 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,220 5,375 128 157 26,100 27,753 2.00 1.00 0.33 30.00 2.00 2.00 0.156Ͳ17 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 4,400 5,507 131 152 24,200 19,469 2.00 1.00 0.33 30.00 2.00 2.00 0.156Ͳ18 30#Linear SpacerandBallDrop 37.0 1,260 956 23 23 1.00 30.00 2.00 2.00 0.157Ͳ1 30#Linear DisplaceBalltoSeat 37.0 10,424 11,396 271 271 1.00 30.00 2.00 2.00 0.157Ͳ2 30#HyborG EstablishStableFluid15.0 8,400 6,835 163 163 2.00 1.00 0.33 30.00 2.00 0.25 0.157Ͳ3 30#HyborG Pad 37.0 18,600 18,774 447 447 2.00 1.00 0.33 30.00 2.00 0.25 0.157Ͳ4 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 15,949 380 384 4,000 3,689 2.00 1.00 0.33 30.00 2.00 0.25 0.157Ͳ5 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 12,000 12,079 288 299 12,000 10,274 2.00 1.00 0.33 30.00 2.00 0.25 0.157Ͳ6 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 15,000 15,014 357 390 30,000 30,811 2.00 1.00 0.33 30.00 2.00 0.25 0.157Ͳ7 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 14,000 14,002 333 379 42,000 42,865 2.00 1.00 0.33 30.00 2.00 0.25 0.157Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 10,000 10,048 239 283 40,000 41,123 2.00 1.00 0.33 30.00 2.00 0.25 0.157Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 8,000 8,008 191 234 40,000 40,344 2.00 1.00 0.33 30.00 2.00 2.00 0.157Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 6,000 7,428 177 216 36,000 36,907 2.20 1.00 0.33 30.00 2.00 2.00 0.157Ͳ11 30#HyborGSpacerandBallDrop 37.0 1,260 1,211 29 29 2.20 1.00 0.33 30.00 2.00 2.00 0.158Ͳ1 30#HyborGDisplaceBalltoSeat 37.0 10,093Ͳ2.00 1.00 0.33 30.00 2.00 2.00 0.158Ͳ2 30#HyborG EstablishStableFluid15.0 8,400Ͳ2.00 1.00 0.33 30.00 2.00 0.25 0.158Ͳ3 30#HyborG Pad 37.0 13,425 14,027 334 334 2.00 1.00 0.33 30.00 2.00 0.25 0.158Ͳ4 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 16,388 390 394 4,000 3,729 2.00 1.00 0.33 30.00 2.00 0.25 0.158Ͳ5 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 8,500 8,528 203 210 8,500 6,881 2.00 1.00 0.33 30.00 2.00 0.25 0.158Ͳ6 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 8,500 8,537 203 221 17,000 17,005 2.00 1.00 0.33 30.00 2.00 0.25 0.158Ͳ7 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 8,000 8,060 192 219 24,000 25,519 2.20 1.00 0.33 30.00 2.00 0.25 0.158Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 9,000 9,002 214 254 36,000 37,322 2.20 1.00 0.33 30.00 2.00 0.25 0.158Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 8,000 8,524 203 250 40,000 43,947 2.20 1.00 0.33 30.00 2.00 2.00 0.158Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 7,000 7,034 167 214 42,000 43,386 2.20 1.00 0.33 30.00 2.00 2.00 0.158Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 5,000 5,261 125 153 32,500 26,574 2.20 1.00 0.33 30.00 2.00 2.00 0.158Ͳ12 30#HyborGSpacerandBallDrop 37.0 1,260 1,571 37 37 2.20 1.00 0.33 30.00 2.00 2.00 0.159Ͳ1 30#HyborG Pad 37.0 7,800 12,175 290 290 2.20 1.00 0.33 30.00 2.00 2.00 0.159Ͳ2 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 15,723 374 379 4,000 4,440 2.20 1.00 0.33 30.00 2.00 0.25 0.159Ͳ3 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 1,966 47 48 2,000 780 2.20 1.00 0.33 30.00 2.00 0.25 0.159Ͳ4 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 2,505 60 64 5,000 4,409 2.20 1.00 0.33 30.00 2.00 0.25 0.159Ͳ5 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 4,000 3,977 95 107 12,000 11,938 2.20 1.00 0.33 30.00 2.00 0.25 0.159Ͳ6 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 4,850 4,859 116 137 19,400 19,836 2.20 1.00 0.33 30.00 2.00 0.25 0.159Ͳ7 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 5,000 5,006 119 144 22,500 23,056 2.20 1.00 0.33 30.00 2.00 0.25 0.159Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,410 5,446 130 159 27,050 27,758 2.20 1.00 0.33 30.00 2.00 2.00 0.159Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 5,500 5,502 131 163 30,250 30,604 2.20 1.00 0.33 30.00 2.00 2.00 0.159Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 5,800 5,803 138 175 34,800 34,321 2.20 1.00 0.33 30.00 2.00 2.00 0.159Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 4,000 4,018 96 123 26,000 26,151 2.20 1.00 0.33 30.00 2.00 2.00 0.159Ͳ12 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 3,000 4,346 103 125 21,000 20,390 2.20 1.00 0.33 30.00 2.00 2.00 0.159Ͳ13 30#Linear Flush 37.0 10,124 10,208 243 243 1.00 30.00 2.00 0.25 0.159Ͳ14 ShutͲIn ShutͲInͲ9Ͳ15 FreezeProtect FreezeProtect 1,000 2,100 50 509Ͳ16 ShutͲIn ShutͲInͲInterval 6Torok@ 16828.89 - 16832.75 ft 139.5 °FInterval 7Torok@ 16308.51 - 16312.37 ft 139.3 °FInterval 8Torok@ 15789.31 - 15793.17 ft 139.4 °FInterval 9Torok@ 15268.05 - 15270.1 ft 139.4 °FConocoPhillipsͲ3SͲ624ActualDesign5
CUSTOMERConocoPhillipsAPI BFD(lb/gal)8.54LAT70.39402791LEASE3SͲ624SALESORDEBHST(°F)141LONGͲ150.1984279FORMATIONTorokDATE MaxPressure(psi)8500*Exceeds80%ofburstpressure*Prop Slurry DesignClean ActualClean ActualClean CalculatedSlurry DesignProp CalculatedProp CLͲ28M LosurfͲ300D MOͲ67 WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total TotalCrosslinker Surfactant BufferInterval Number Description Description Description(ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)LiquidAdditives DryAdditives50Ͳ103Ͳ2086890914393910Ͳ1 ShutͲIn ShutͲInͲ10Ͳ2 FreezeProtect PrimeUpPressureTest 5.0 1,000 1,890 45 4510Ͳ3 ShutͲIn ShutͲInͲ10Ͳ4 30#Linear SpacerandBallDrop 15.0 1,260 1,093 26 26 1.00 30.00 2.00 0.25 0.1510Ͳ5 30#HyborG EstablishStableFluid15.0 8,400 9,198 219 219 2.00 1.00 0.33 30.00 2.00 0.25 0.1510Ͳ6 30#HyborG Pad 37.0 7,800 8,293 197 197 2.00 1.00 0.33 30.00 2.00 0.25 0.1510Ͳ7 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 16,662 397 401 4,000 4,003 2.00 1.00 0.33 30.00 2.00 0.25 0.1510Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 2,012 48 49 2,000 1,191 2.00 1.00 0.33 30.00 2.00 0.25 0.1510Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 2,662 63 68 5,000 4,768 2.00 1.00 0.33 30.00 2.00 0.25 0.1510Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 4,000 4,013 96 109 12,000 12,233 2.00 1.00 0.33 30.00 2.00 0.25 0.1510Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 4,850 5,193 124 146 19,400 21,110 2.00 1.00 0.35 30.00 2.00 0.25 0.1510Ͳ12 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 5,000 4,649 111 132 22,500 20,096 2.00 1.00 0.35 30.00 2.00 0.25 0.1510Ͳ13 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,410 5,428 129 158 27,050 27,092 2.00 1.00 0.35 30.00 2.00 2.00 0.1510Ͳ14 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 5,500 5,503 131 163 30,250 30,457 2.00 1.00 0.35 30.00 2.00 2.00 0.1510Ͳ15 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 5,800 5,817 139 176 34,800 35,446 2.00 1.00 0.35 30.00 2.00 2.00 0.1510Ͳ16 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 4,000 4,023 96 124 26,000 26,363 2.00 1.00 0.35 30.00 2.00 2.00 0.1510Ͳ17 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 3,000 3,917 93 113 21,000 18,844 2.00 1.00 0.35 30.00 2.00 2.00 0.1510Ͳ18 30#HyborGSpacerandBallDrop 37.0 1,260 1,155 28 28 2.00 1.00 0.35 30.00 2.00 2.00 0.1511Ͳ1 30#HyborG Pad 37.0 7,800 9,110 217 217 2.00 1.00 0.35 30.00 2.00 2.00 0.1511Ͳ2 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 15,881 378 382 4,000 3,505 2.00 1.00 0.35 30.00 2.00 0.25 0.1511Ͳ3 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 2,018 48 50 2,000 1,646 2.00 1.00 0.35 30.00 2.00 0.25 0.1511Ͳ4 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 2,502 60 65 5,000 4,717 2.00 1.00 0.35 30.00 2.00 0.25 0.1511Ͳ5 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 4,000 4,002 95 108 12,000 12,162 2.00 1.00 0.35 30.00 2.00 0.25 0.1511Ͳ6 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 4,850 5,093 121 143 19,400 20,710 2.00 1.00 0.35 30.00 2.00 0.25 0.1511Ͳ7 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 5,000 5,005 119 143 22,500 22,688 2.00 1.00 0.35 30.00 2.00 0.25 0.1511Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,410 5,369 128 158 27,050 27,954 2.00 1.00 0.35 30.00 2.00 2.00 0.1511Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 5,500 5,510 131 164 30,250 31,155 2.00 1.00 0.35 30.00 2.00 2.00 0.1511Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 5,800 5,791 138 175 34,800 35,090 2.00 1.00 0.35 30.00 2.00 2.00 0.1511Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 4,000 4,009 95 124 26,000 26,448 2.00 1.00 0.35 30.00 2.00 2.00 0.1511Ͳ12 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 3,000 3,682 88 107 21,000 18,032 2.00 1.00 0.35 30.00 2.00 2.00 0.1511Ͳ13 30#HyborGSpacerandBallDrop 37.0 1,260 1,728 41 41 2.00 1.00 0.35 30.00 2.00 2.00 0.1512Ͳ1 30#HyborG Pad 37.0 7,800 7,994 190 190 2.00 1.00 0.35 30.00 2.00 2.00 0.1512Ͳ2 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 16,250 387 391 4,000 3,597 2.00 1.00 0.35 30.00 2.00 0.25 0.1512Ͳ3 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 2,474 59 61 2,000 1,607 2.00 1.00 0.35 30.00 2.00 0.25 0.1512Ͳ4 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 2,325 55 59 5,000 3,781 2.00 1.00 0.35 30.00 2.00 0.25 0.1512Ͳ5 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 4,000 4,032 96 109 12,000 12,030 2.00 1.00 0.35 30.00 2.00 0.25 0.1512Ͳ6 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 4,850 4,842 115 136 19,400 19,699 2.00 1.00 0.35 30.00 2.00 0.25 0.1512Ͳ7 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 5,000 4,998 119 144 22,500 23,283 2.00 1.00 0.35 30.00 2.00 0.25 0.1512Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,410 5,429 129 159 27,050 27,642 2.00 1.00 0.35 30.00 2.00 2.00 0.1512Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 5,500 5,404 129 160 30,250 29,925 2.00 1.00 0.35 30.00 2.00 2.00 0.1512Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 5,800 5,811 138 176 34,800 35,308 2.00 1.00 0.35 30.00 2.00 2.00 0.1512Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 4,000 4,016 96 124 26,000 26,502 2.00 1.00 0.35 30.00 2.00 2.00 0.1512Ͳ12 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 3,000 4,737 113 138 21,000 23,574 2.00 1.00 0.35 30.00 2.00 2.00 0.1512Ͳ13 30#HyborGSpacerandBallDrop 37.0 1,260 701 17 17 2.00 1.00 0.35 30.00 2.00 2.00 0.1513Ͳ1 30#HyborG Pad 37.0 7,800 7,859 187 187 2.00 1.00 0.35 30.00 2.00 1.00 0.1513Ͳ2 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 15,071 359 363 4,000 3,518 2.00 1.00 0.35 30.00 2.00 0.25 0.1513Ͳ3 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 3,088 74 76 2,000 2,409 2.00 1.00 0.35 30.00 2.00 0.25 0.1513Ͳ4 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 2,558 61 65 5,000 4,304 2.00 1.00 0.35 30.00 2.00 0.25 0.1513Ͳ5 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 4,000 3,881 92 105 12,000 12,083 2.00 1.00 0.35 30.00 2.00 0.25 0.1513Ͳ6 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 4,850 4,858 116 136 19,400 19,588 2.00 1.00 0.35 30.00 2.00 0.25 0.1513Ͳ7 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 5,000 4,934 117 141 22,500 22,455 2.00 1.00 0.35 30.00 2.00 0.25 0.1513Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,410 5,404 129 158 27,050 27,350 2.00 1.00 0.35 30.00 2.00 2.00 0.1513Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 5,500 5,486 131 163 30,250 30,360 2.00 1.00 0.35 30.00 2.00 2.00 0.1513Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 5,800 5,775 138 174 34,800 34,810 2.00 1.00 0.35 30.00 2.00 2.00 0.1513Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 4,000 3,976 95 123 26,000 26,430 2.00 1.00 0.35 30.00 2.00 2.00 0.1513Ͳ12 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 3,000 4,100 98 119 21,000 19,724 2.00 1.00 0.35 30.00 2.00 2.00 0.1513Ͳ13 30#HyborGSpacerandBallDrop 37.0 1,260 970 23 23 2.00 1.00 0.35 30.00 2.00 2.00 0.1514Ͳ1 30#HyborG Pad 37.0 7,800 9,673 230 230 2.00 1.00 0.35 30.00 2.00 1.00 0.1514Ͳ2 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 16,190 385 389 4,000 3,439 2.00 1.00 0.35 30.00 2.00 0.25 0.1514Ͳ3 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 2,298 55 57 2,000 1,685 2.00 1.00 0.35 30.00 2.00 0.25 0.1514Ͳ4 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 2,520 60 64 5,000 3,742 2.00 1.00 0.35 30.00 2.00 0.25 0.1514Ͳ5 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 4,000 3,996 95 107 12,000 11,568 2.00 1.00 0.35 30.00 2.00 0.25 0.1514Ͳ6 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 4,850 4,838 115 136 19,400 19,804 2.00 1.00 0.35 30.00 2.00 0.25 0.1514Ͳ7 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 5,000 4,999 119 143 22,500 22,650 2.00 1.00 0.35 30.00 2.00 0.25 0.1514Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,410 5,421 129 158 27,050 27,666 2.00 1.00 0.35 30.00 2.00 2.00 0.1514Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 5,500 5,568 133 166 30,250 31,194 2.00 1.00 0.35 30.00 2.00 2.00 0.1514Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 5,800 5,809 138 176 34,800 35,040 2.00 1.00 0.35 30.00 2.00 2.00 0.1514Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 4,000 4,012 96 123 26,000 26,077 2.00 1.00 0.35 30.00 2.00 2.00 0.1514Ͳ12 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 3,000 4,423 105 129 21,000 21,971 2.00 1.00 0.35 30.00 2.00 2.00 0.1514Ͳ13 30#Linear Flush 37.0 8,448 9,347 223 223 1.00 30.00 2.00 0.25 0.1514Ͳ14 ShutͲIn ShutͲInͲ14Ͳ15 Seawater WLPumpDownSW 5.0 41,958 41,958 999 999 1.00 0.1514Ͳ16 30#Linear WLPumpDownGel 5.0 1,680 1,680 40 40 1.00 30.00 2.00 0.25 0.15Interval 10Torok@ 14755.92 - 14757.97 ft 139.5 °FInterval 11Torok@ 14244.82 - 14246.87 ft 140 °FInterval 12Torok@ 13728.28 - 13730.33 ft 140 °FInterval 13Torok@ 13207.85 - 13209.9 ft 140.1 °FInterval 14Torok@ 12645.62 - 12647.67 ft 140.1 °FConocoPhillipsͲ3SͲ624ActualDesign6
CUSTOMERConocoPhillipsAPI BFD(lb/gal)8.54LAT70.39402791LEASE3SͲ624SALESORDEBHST(°F)141LONGͲ150.1984279FORMATIONTorokDATE MaxPressure(psi)8500*Exceeds80%ofburstpressure*Prop Slurry DesignClean ActualClean ActualClean CalculatedSlurry DesignProp CalculatedProp CLͲ28M LosurfͲ300D MOͲ67 WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total TotalCrosslinker Surfactant BufferInterval Number Description Description Description(ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)LiquidAdditives DryAdditives50Ͳ103Ͳ2086890914393915Ͳ1 ShutͲIn ShutͲInͲ15Ͳ2 FreezeProtect PrimeUpPressureTest 5.0 1,000 4,536 108 10815Ͳ3 ShutͲIn ShutͲInͲ15Ͳ4 30#Linear SpacerandBallDrop 15.0 1,260 1,211 29 29 1.00 30.00 2.00 0.25 0.1515Ͳ5 30#HyborG EstablishStableFluid15.0 8,400 6,777 161 161 2.00 1.00 0.33 30.00 2.00 0.25 0.1515Ͳ6 30#HyborG Pad 37.0 7,800 8,060 192 192 2.00 1.00 0.33 30.00 2.00 0.25 0.1515Ͳ7 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 16,045 382 387 4,000 4,143 2.00 1.00 0.33 30.00 2.00 0.25 0.1515Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 2,003 48 49 2,000 1,100 2.00 1.00 0.33 30.00 2.00 0.25 0.1515Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 2,530 60 65 5,000 4,242 2.00 1.00 0.33 30.00 2.00 0.25 0.1515Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 4,000 4,033 96 109 12,000 12,350 2.00 1.00 0.33 30.00 2.00 0.25 0.1515Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 4,850 4,861 116 137 19,400 19,908 2.00 1.00 0.33 30.00 2.00 0.25 0.1515Ͳ12 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 5,000 5,122 122 147 22,500 23,321 2.00 1.00 0.33 30.00 2.00 0.25 0.1515Ͳ13 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,410 5,402 129 158 27,050 27,494 2.00 1.00 0.33 30.00 2.00 2.00 0.1515Ͳ14 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 5,500 27,411 653 709 30,250 53,157 2.00 1.00 0.33 30.00 2.00 2.00 0.1515Ͳ15 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 5,800 2,166 52 65 34,800 12,817 2.00 1.00 0.33 30.00 2.00 2.00 0.1515Ͳ16 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 4,000 3,784 90 117 26,000 24,912 2.00 1.00 0.33 30.00 2.00 2.00 0.1515Ͳ17 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 3,000 3,562 85 102 21,000 16,533 2.00 1.00 0.33 30.00 2.00 2.00 0.1515Ͳ18 30#HyborGSpacerandBallDrop 37.0 1,260 929 22 22 2.00 1.00 0.33 30.00 2.00 2.00 0.1516Ͳ1 30#HyborG Pad 37.0 7,800 7,362 175 175 2.00 1.00 0.33 30.00 2.00 1.00 0.1516Ͳ2 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 14,394 343 347 4,000 3,497 2.00 1.00 0.33 30.00 2.00 0.25 0.1516Ͳ3 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 2,024 48 50 2,000 1,525 2.00 1.00 0.33 30.00 2.00 0.25 0.1516Ͳ4 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 2,590 62 66 5,000 4,373 2.00 1.00 0.33 30.00 2.00 0.25 0.1516Ͳ5 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 4,000 4,084 97 110 12,000 12,021 2.00 1.00 0.33 30.00 2.00 0.25 0.1516Ͳ6 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 4,850 4,896 117 138 19,400 20,091 2.00 1.00 0.33 30.00 2.00 0.25 0.1516Ͳ7 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 5,000 5,302 126 152 22,500 24,425 2.00 1.00 0.33 30.00 2.00 0.25 0.1516Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,410 5,419 129 158 27,050 27,612 2.00 1.00 0.33 30.00 2.00 2.00 0.1516Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 5,500 5,529 132 165 30,250 31,251 2.00 1.00 0.33 30.00 2.00 2.00 0.1516Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 5,800 5,817 139 176 34,800 35,024 2.20 1.00 0.33 30.00 2.00 2.00 0.1516Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 4,000 4,017 96 123 26,000 26,130 2.20 1.00 0.33 30.00 2.00 2.00 0.1516Ͳ12 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 3,000 3,506 83 101 21,000 16,604 2.20 1.00 0.33 30.00 2.00 2.00 0.1516Ͳ13 30#HyborGSpacerandBallDrop 37.0 1,260 1,061 25 25 2.20 1.00 0.33 30.00 2.00 2.00 0.1517Ͳ1 30#HyborG Pad 37.0 1,000 4,729 113 113 2.20 1.00 0.33 30.00 2.00 1.00 0.1517Ͳ2 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 16,430 391 395 4,000 3,420 2.20 1.00 0.33 30.00 2.00 0.25 0.1517Ͳ3 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 1,300 1,316 31 32 1,300 876 2.20 1.00 0.33 30.00 2.00 0.25 0.1517Ͳ4 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 1,600 1,598 38 41 3,200 2,661 2.20 1.00 0.33 30.00 2.00 0.25 0.1517Ͳ5 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 2,600 2,598 62 69 7,800 6,995 2.20 1.00 0.33 30.00 2.00 0.25 0.1517Ͳ6 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 3,140 3,128 74 88 12,560 12,527 2.20 1.00 0.33 30.00 2.00 0.25 0.1517Ͳ7 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 3,240 3,260 78 93 14,580 14,810 2.20 1.00 0.33 30.00 2.00 0.25 0.1517Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 3,540 3,546 84 104 17,700 18,112 2.20 1.00 0.33 30.00 2.00 2.00 0.1517Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 3,580 3,599 86 106 19,690 19,259 2.20 1.00 0.33 30.00 2.00 2.00 0.1517Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 3,770 3,782 90 114 22,620 22,492 2.20 1.00 0.33 30.00 2.00 2.00 0.1517Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 2,600 2,615 62 81 16,900 17,250 2.20 1.00 0.33 30.00 2.00 2.00 0.1517Ͳ12 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 1,950 3,660 87 106 13,650 17,460 2.20 1.00 0.33 30.00 2.00 2.00 0.1517Ͳ13 30#HyborGSpacerandBallDrop 37.0 1,260 1,220 29 29 2.20 1.00 0.33 30.00 2.00 2.00 0.1518Ͳ1 30#HyborG Pad 37.0 1,000 1,276 30 30 2.20 1.00 0.33 30.00 2.00 1.00 0.1518Ͳ2 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 14,868 354 358 4,000 3,473 2.20 1.00 0.33 30.00 2.00 0.25 0.1518Ͳ3 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 1,300 1,328 32 33 1,300 1,040 2.20 1.00 0.33 30.00 2.00 0.25 0.1518Ͳ4 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 1,600 1,591 38 41 3,200 2,657 2.20 1.00 0.33 30.00 2.00 0.25 0.1518Ͳ5 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 2,600 2,609 62 70 7,800 7,107 2.20 1.00 0.33 30.00 2.00 0.25 0.1518Ͳ6 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 3,140 3,140 75 88 12,560 12,647 2.20 1.00 0.33 30.00 2.00 0.25 0.1518Ͳ7 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 3,240 3,348 80 96 14,580 15,552 2.20 1.00 0.33 30.00 2.00 0.25 0.1518Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 3,540 3,547 84 103 17,700 17,843 2.20 1.00 0.33 30.00 2.00 2.00 0.1518Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 3,580 3,752 89 110 19,690 19,690 2.20 1.00 0.33 30.00 2.00 2.00 0.1518Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 3,770 3,755 89 112 22,620 21,298 2.20 1.00 0.33 30.00 2.00 2.00 0.1518Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 2,600 2,586 62 79 16,900 16,704 2.20 1.00 0.33 30.00 2.00 2.00 0.1518Ͳ12 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 1,950 3,463 82 101 13,650 17,122 2.20 1.00 0.33 30.00 2.00 2.00 0.1518Ͳ13 30#HyborGSpacerandBallDrop 37.0 1,260 1,190 28 28 2.20 1.00 0.33 30.00 2.00 2.00 0.1519Ͳ1 30#HyborG Pad 37.0 1,000 1,432 34 34 2.20 1.00 0.33 30.00 2.00 1.00 0.1519Ͳ2 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 16,465 392 396 4,000 3,761 2.20 1.00 0.33 30.00 2.00 0.25 0.1519Ͳ3 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 1,300 1,316 31 32 1,300 776 2.20 1.00 0.33 30.00 2.00 0.25 0.1519Ͳ4 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 1,600 1,618 39 41 3,200 2,634 2.20 1.00 0.33 30.00 2.00 0.25 0.1519Ͳ5 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 2,600 2,595 62 70 7,800 7,329 2.20 1.00 0.33 30.00 2.00 0.25 0.1519Ͳ6 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 3,140 3,160 75 89 12,560 12,656 2.20 1.00 0.33 30.00 2.00 0.25 0.1519Ͳ7 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 3,240 3,239 77 93 14,580 15,090 2.20 1.00 0.33 30.00 2.00 0.25 0.1519Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 3,540 3,535 84 103 17,700 17,917 2.20 1.00 0.33 30.00 2.00 2.00 0.1519Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 3,580 3,571 85 106 19,690 19,727 2.20 1.00 0.33 30.00 2.00 2.00 0.1519Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 3,770 3,935 94 119 22,620 24,182 2.20 1.00 0.33 30.00 2.00 2.00 0.1519Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 2,600 2,615 62 80 16,900 17,161 2.20 1.00 0.33 30.00 2.00 2.00 0.1519Ͳ12 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 1,950 2,748 65 78 13,650 11,793 2.20 1.00 0.33 30.00 2.00 2.00 0.1519Ͳ13 30#HyborGSpacerandBallDrop 37.0 1,260 804 19 19 2.20 1.00 0.33 30.00 2.00 2.00 0.15Interval 17Torok@ 11045.96 - 11048.01 ft 140.4 °FInterval 16Torok@ 11563.81 - 11565.86 ft 140.2 °FInterval 18Torok@ 10524.89 - 10526.94 ft 140.6 °FInterval 19Torok@ 10004.52 - 10006.57 ft 140.7 °FInterval 15Torok@ 12083.6 - 12085.65 ft 140.1 °FConocoPhillipsͲ3SͲ624ActualDesign7
CUSTOMERConocoPhillipsAPI BFD(lb/gal)8.54LAT70.39402791LEASE3SͲ624SALESORDEBHST(°F)141LONGͲ150.1984279FORMATIONTorokDATE MaxPressure(psi)8500*Exceeds80%ofburstpressure*Prop Slurry DesignClean ActualClean ActualClean CalculatedSlurry DesignProp CalculatedProp CLͲ28M LosurfͲ300D MOͲ67 WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total TotalCrosslinker Surfactant BufferInterval Number Description Description Description(ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)LiquidAdditives DryAdditives50Ͳ103Ͳ2086890914393920Ͳ1 30#HyborG MinifracͲTreatment 37.0 18,900 15,431 367 367 2.20 1.00 0.33 30.00 2.00 2.00 0.1520Ͳ2 30#Linear MinifracͲFlush37.0 6,062 2,503 60 60 1.00 30.00 2.00 2.00 0.1520Ͳ3 ShutͲIn ShutͲInͲ20Ͳ4 30#HyborG EstablishStableFluid15.0 8,400 6,463 154 154 2.20 1.00 0.33 30.00 2.00 0.25 0.1520Ͳ5 30#HyborG Pad 37.0 1,000 1,018 24 24 2.20 1.00 0.33 30.00 2.00 0.25 0.1520Ͳ6 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 15,717 374 378 4,000 3,329 2.20 1.00 0.33 30.00 2.00 0.25 0.1520Ͳ7 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 1,300 1,330 32 33 1,300 1,132 2.20 1.00 0.33 30.00 2.00 0.25 0.1520Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 1,600 1,597 38 41 3,200 2,714 2.20 1.00 0.33 30.00 2.00 0.25 0.1520Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 2,600 2,585 62 69 7,800 7,371 2.20 1.00 0.33 30.00 2.00 0.25 0.1520Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 3,140 3,138 75 88 12,560 12,515 2.20 1.00 0.33 30.00 2.00 0.25 0.1520Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 3,240 3,264 78 93 14,580 14,780 2.20 1.00 0.33 30.00 2.00 0.25 0.1520Ͳ12 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 3,540 3,517 84 103 17,700 17,777 2.20 1.00 0.33 30.00 2.00 2.00 0.1520Ͳ13 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 3,580 3,581 85 107 19,690 20,230 2.20 1.00 0.33 30.00 2.00 2.00 0.1520Ͳ14 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 3,770 3,785 90 115 22,620 23,012 2.20 1.00 0.33 30.00 2.00 2.00 0.1520Ͳ15 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 2,600 2,599 62 80 16,900 16,966 2.20 1.00 0.33 30.00 2.00 2.00 0.1520Ͳ16 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 1,950 3,593 86 103 13,650 16,602 2.20 1.00 0.33 30.00 2.00 2.00 0.1520Ͳ17 30#HyborGSpacerandBallDrop 37.0 1,260 1,199 29 29 2.20 1.00 0.33 30.00 2.00 2.00 0.1521Ͳ1 30#HyborG Pad 37.0 1,000 1,854 44 44 2.20 1.00 0.33 30.00 2.00 1.00 0.1521Ͳ2 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 10,322 246 248 4,000 2,014 2.20 1.00 0.33 30.00 2.00 0.25 0.1521Ͳ3 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 1,300 1,168 28 28 1,300 577 2.20 1.00 0.33 30.00 2.00 0.25 0.1521Ͳ4 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 1,600 1,515 36 38 3,200 2,101 2.20 1.00 0.33 30.00 2.00 0.25 0.1521Ͳ5 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 2,600 2,161 51 58 7,800 6,096 2.20 1.00 0.33 30.00 2.00 0.25 0.1521Ͳ6 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 3,140 2,705 64 76 12,560 10,815 2.20 1.00 0.33 30.00 2.00 0.25 0.1521Ͳ7 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 3,240 2,830 67 81 14,580 13,222 2.20 1.00 0.33 30.00 2.00 0.25 0.1521Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 3,540 3,176 76 93 17,700 16,574 2.20 1.00 0.33 30.00 2.00 2.00 0.1521Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 3,580 3,241 77 97 19,690 18,533 2.20 1.00 0.33 30.00 2.00 2.00 0.1521Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 3,770 3,407 81 103 22,620 20,990 2.20 1.00 0.33 30.00 2.00 2.00 0.1521Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 2,600 2,328 55 72 16,900 15,542 2.20 1.00 0.33 30.00 2.00 2.00 0.1521Ͳ12 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 1,950 4,501 107 132 13,650 23,767 2.20 1.00 0.33 30.00 2.00 2.00 0.1521Ͳ13 30#HyborGSpacerandBallDrop 37.0 1,260 1,194 28 28 2.20 1.00 0.33 30.00 2.00 2.00 0.1522Ͳ1 30#HyborG Pad 37.0 1,000 2,037 49 49 2.20 1.00 0.33 30.00 2.00 1.00 0.1522Ͳ2 30#HyborG ConditioningPad Wanli16/20Ceramic 0.25 37.0 16,000 10,975 261 264 4,000 2,482 2.20 1.00 0.33 30.00 2.00 0.25 0.1522Ͳ3 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 1,300 1,313 31 32 1,300 826 2.20 1.00 0.33 30.00 2.00 0.25 0.1522Ͳ4 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 1,600 1,634 39 42 3,200 2,952 2.20 1.00 0.33 30.00 2.00 0.25 0.1522Ͳ5 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 2,600 2,523 60 68 7,800 7,413 2.20 1.00 0.33 30.00 2.00 0.25 0.1522Ͳ6 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 3,140 2,743 65 77 12,560 11,123 2.20 1.00 0.33 30.00 2.00 0.25 0.1522Ͳ7 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 3,240 2,912 69 84 14,580 13,653 2.20 1.00 0.33 30.00 2.00 0.25 0.1522Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 3,540 3,197 76 94 17,700 16,369 2.20 1.00 0.33 30.00 2.00 2.00 0.1522Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 3,580 3,312 79 99 19,690 18,838 2.20 1.00 0.33 30.00 2.00 2.00 0.1522Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 3,770 3,509 84 107 22,620 21,672 2.20 1.00 0.33 30.00 2.00 2.00 0.1522Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 2,600 2,314 55 71 16,900 15,390 2.20 1.00 0.33 30.00 2.00 2.00 0.1522Ͳ12 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 1,950 4,447 106 130 13,650 22,687 2.20 1.00 0.33 30.00 2.00 2.00 0.1522Ͳ13 30#Linear Flush 37.0 5,370 5,376 128 128 1.00 30.00 2.00 2.00 0.1522Ͳ14 FreezeProtect FreezeProtect 10.0 1,470 3,780 90 9024Ͳ1SeawaterSpacerandDartDrop 15.0 1,260 1,172 28 280.1524Ͳ2SeawaterDisplaceDarttoSeat 15.0 5,370 24,660 587 5870.152,056,839 2,160,847 51,449 55,761 4,068,000 4,059,031DesignTotal(gal)ActualTotal(gal)DesignTotal(lbs)CalculatedTotal(lbs)TicketTotal(lbs)CLͲ28M LosurfͲ300D MOͲ67 WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ61,830,778 1,882,815 3,980,000 3,982,017 3,998,163(gal) (gal) (gal) (lbs) (lbs) (lbs) (lbs)123,213 129,196 88,000 77,014 98,000 InitialDesignMaterialVolume 3,661.6 2,011.0 604.2 58,703.7 3,911.3 1,154.2 307.149,480 59,860Ͳ34,000 ActualDesignMaterialVolume 3,851.4 2,071.0 634.9 60,410.7 4,027.4 1,453.3 317.39,730 19,506 7560ͲͲ ͲPhysicalMaterialVolumePumped 3,910 2,158 645 58083 4,392 1,515 282.141,958 41,958ͲͲ ͲPhysicalMaterialVolumeDeviance 1.5% 4.2% 1.6%Ͳ3.9% 9.1% 4.2%Ͳ11%1,680 1,680**IFSnumbersforproppantaretakenfromsoftwarecalculationsbasedonmultiplevariablesMicroMotionVolumePumped 3,834 2,034 646 68,305 3,986 1,493ͲͲͲ**ProppantisbilledfromWeightTicketvolumesMicroMotionVolumeDeviance 0%Ͳ2% 2% 13%Ͳ1% 3%ͲͲͲWirelinePumpDownGelͲͲInterval 20Torok@ 9483.92 - 9485.97 ft 140.9 °FInterval 21Torok@ 8922.65 - 8924.7 ft 140.9 °FInterval 22Torok@ 8401.59 - 8403.64 ft 141.1 °FInterval 24TorokͲFluidType30#HyborG30#LinearSeawaterFreezeProtectWirelinePumpDownSeawaterProppantTypeWanli16/20Ceramic100M100MVac'edUpͲConocoPhillipsͲ3SͲ624ActualDesign8
ConocoPhillipsTorok3SͲ62450Ͳ103Ͳ20868*Exceeds80%ofburstpressure*Description OD(in) ID(in) Wt(#) GradeFUF(gal/ft)MDTop(ft)MDBtm(ft) Volume(gal)TubularBurstPressure(psi)Tubing4.5 3.958 12.6 LͲ80 0.6392 0 13,109 8,379 8,430Tubing4.5 3.958 12.6 LͲ80 0.6392 13,109 20,942 5,007 8,430Total20,94213,386ft1.54ft141.1ftft1.54ft141.1ftTopMD(ft)BtmMD(ft)AverageTVD(ft)Interval# FormationDescriptorAverageIntervalTemperature(F)BallDropTime(HH:MM)BallHitTime(HH:MM)JSVDrop(bbl)JSVSlowDown(bbl)JSVHit(bbl)Early(bbl)SurfaceSeatPressure(psi)SurfacePeakPressure(psi)SurfaceDifferential(psi)BHSeatPressure(psi)BHPeakPressure(psi)BHDifferential(psi)RateatShift(bpm)Toe19,441 19,445 5,1611Torok139.512:00:00AM 12:00:00AM 12:00:00AM 266 12:00:00AMͲ12:00:00AM 12:00:00AM 0 12:00:00AM 12:00:00AM 12:00:00AM18,913 18,917 5,1672Torok139.612:07:00PM 12:26:00PM 50 308 32810.02,2622,5973354,2128,4374,22510.018,393 18,397 5,1713Torok139.64:34:00PM 4:44:00PM 3,865 4,115 4,13212.91,9825,0873,1053,6446,7103,06610.317,872 17,876 5,1734Torok139.710:50:42AM 11:08:00AM 22 264 2877.01,8716,0744,2033,5477,5944,04712.217,349 17,353 5,1755Torok139.712:45:29PM 12:53:00PM 3,472 3,706 3,72313.01,8766,2694,3933,5278,1804,6531.716,829 16,833 5,1626Torok139.59:22:56AM 9:40:00AM 22 248 2717.61,9595,3243,3653,6356,8653,23010.716,309 16,312 5,1527Torok139.311:41:49AM 11:48:00AM 3,235 3,453 3,4749.21,8225,0293,2073,4826,5413,05910.315,789 15,793 5,1538Torok139.41:14:00PM 1:22:00PM 6,320 6,530 6,5528.31,9034,0832,1803,6135,6692,0569.115,268 15,270 5,1549Torok139.42:20:00PM 2:28:00PM 8,602 8,804 8,8268.41,9984,0342,0363,6585,6642,00610.014,756 14,758 5,16210Torok139.58:53:00AM 9:09:00AM 25 220 2437.11,3123,1041,7922,9984,5041,50610.014,245 14,247 5,19311Torok140.010:02:00AM 10:09:00AM 2,102 2,289 2,3135.81,9143,6621,7483,5645,2241,66010.213,728 13,730 5,19812Torok140.010:51:00AM 11:03:00AM 3,971 4,150 4,1736.92,2004,6802,4804,1736,2272,05410.213,208 13,210 5,20013Torok140.111:51:00AM 11:57:00AM 5,826 5,997 6,0225.01,9793,9711,9923,5765,5391,96310.312,646 12,648 5,20014Torok140.112:50:00PM 12:56:00PM 7,653 7,815 7,83510.52,0326,2954,2633,6468,0734,42710.312,08412,086 5,19915Torok140.19:31:00AM 9:43:00AM 29 183 2048.99652,8701,9052,6134,4151,80210.211,56411,566 5,21116Torok140.210:54:00AM 10:59:00AM 2,442 2,588 2,6126.01,5803,6942,1143,3035,4142,11110.311,046 11,048 5,22317Torok140.411:45:00AM 12:00:00PM 4,221 4,359 4,3854.11,5565,8944,3383,2717,1603,8899.010,525 10,527 5,23118Torok140.612:25:00PM 12:30:00PM 5,586 5,716 5,7406.21,7172,1394223,4043,82241810.210,005 10,007 5,24219Torok140.71:02:00PM 1:07:00PM 6,831 6,953 6,9803.31,5433,2421,6993,2464,8921,6469.99,484 9,486 5,25420Torok140.91:38:00PM 1:44:00PM 8,087 8,201 8,2301.31,5993,1041,5053,2154,6761,4619.98,923 8,925 5,25521Torok140.93:51:00PM 3:56:00PM 9,925 10,031 10,0573.81,5293,8472,3183,1515,3932,2429.98,402 8,404 5,26322Torok141.14:24:00PM 4:31:00PM 11,023 11,121 11,1437.91,3871,7523653,0633,48742412.2Temp.Gradient(°F/100ft)BHST(°F)TVDatBottomPerfMDatBottomPerf5,26319,445KOPAvg.TVDTotalMD78910112345617181920211213141516Sleeve/PerfDepthSleeves201.0192.5183.9Interval#1MaxPressure(psi)8,500IsolationTypeSwellPackerTreatmentTubularsCustomerFormationLeaseAPIDateTemperatureDataTemp.Gradient(°F/100ft)BHST(°F)DirectionalData4,5872,23720,942DirectionalData2,2372/12/2024KOPTemperatureData2211,757 279.911,42411,09010,757DisplacementtoTopSleeve/Perf(gal)(BBLS)12,427 295.912,089 287.8272.0264.0256.18,7758,4428,0837,7247,39210,42410,0939,7599,4329,1057,0616,7286,3956,0625,7035,370248.2240.3232.4224.6216.8208.9135.8127.9176.0168.1160.2152.3144.3ConocoPhillipsͲ3SͲ624 WellboreInformation9
2/13/24 9:27
2/13/24 12:34
187 min
37.1 bpm
5,084 psi
6,700 psi
24.8 bpm
3,822 psi
3,838 psi
5,390 psi
2,319 hhp
751 psi
243 psi
464 psi
5.63 ppg
5
5
45 %
46 %
29 cP
75 F
8.87
DFIT
8.623 bpm
3600 psi
3574 psi
10.1 bpm
4194 psi
5805 psi
3810 psi
0.738 psi/ft
3055 psi
2994 psi
2967 psi
205,654 lbs
3,231 lbs
208,885 lbs
208,885 lbs
178,416 gal 4,248 bbls
9,280 gal 221 bbls
15,688 gal 374 bbls
100 gal 2 bbls
Minifrac Max Surface Pressure:
100M Pumped:
Final 15 min:
Proppant in Formation:
30# Hybor G Volume:
30# Linear Volume:
Seawater Volume:
Minifrac Max DH Pressure:
Final 5 min:
Average pH:
Minifrac Average Rate:
Pump Time:
Pad Percentage Actual
Wanli 16/20 Ceramic Pumped:
Diagnostic method
Average Visc:
Average Temp:
Max Rate:
Max Surface Pressure:
Max BH Pressure:
3S-624 - 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:
Average BH Pressure:
Pumps Ending Stage:
Max Proppant Concentration:
Minifrac Max Rate:
ISDP:
Final Fracture Gradient:
Final 10 min:
Proppant Summary
Minifrac Average Pressure:
Minifrac Average DH Pressure:
Freeze Protect Volume:
Total Proppant Pumped* :
Fluid Summary (by fluid description)
Conoco PhillipsͲ3SͲ624 Interval Summary 10
5,084
12,976 gal 309 bbls
52,434 gal 1,248 bbls
18,560 gal 442 bbls
74,126 gal 1,765 bbls
9,302 gal 221 bbls
5,355 gal 128 bbls
3,925 gal 93 bbls
23,994 gal 571 bbls
2,605 gal 62 bbls
107 gal 3 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Displace Ball to Seat Volume:
Pad Volume:
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
While trying to burst the arsenal disk, pressured up the wellhead and pop-offs activated at
6,490 surface pressure. After bleeding down and pressuring up again, the arsenal disk burst at
4576 psi. While mixing a tub of gel, a leak was noticed on the Y strainer, the repair took the
remainder of the 1st day of pumping. Pumping was resumed on Day 2 after fixing the ADP. The
establish stable fluid stage, went over the design due to issues getting good XL. While
increasing rate during Pad, there were issues maintaing suction on the blender. Crew had to
shut down to avoid losing the tub and open water tanks from the other tank bank and add
suction hoses. During 1 ppg 16/20 crew shut down due to losing suction again. Sand Stages 2
thru 5 ppg were pumped as per design. Before dropping the ball for interval 2, the acid pumper
shut down and had to be restarted. Rate was held at 15 bpm while displacing the ball to avoid
pushing proppant too far into the formation.
DFIT Volume:
Arsenal Sleeve Shift Volume:
Chad Burkette
Willie Martin
Fluid Summary (by stage description)
Flush Volume:
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:
Zach Thomas
Dan Faur
ConocoPhillipsͲ3SͲ624 IntervalSummary 11
2/15/24 14:44
2/15/24 16:44
120 min
10.0 bpm
2,597 psi
8,437 psi
10 bbl
39.1 bpm
5,072 psi
6,209 psi
31.4 bpm
3,695 psi
3,727 psi
5,157 psi
2,844 hhp
655 psi
157 psi
157 psi
5.26 ppg
5
4
40 %
41 %
29.8 cP
88 F
9.08
200,745 lbs
4,295 lbs
205,040 lbs
205,040 lbs
148,555 gal 3,537 bbls
1,774 gal 42 bbls
15,524 gal 370 bbls
2,000 gal 48 bbls
Pad Percentage Design
Pad Percentage Actual
Proppant in Formation:
Fluid Summary (by fluid description)
Interval Summary
Start Date/Time:
End Date/Time:
Pump Time:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Max Rate:
Max Surface Pressure:
Max BH Pressure:
Average Rate:
Average Missile Pressure:
Average Surface Pressure:
3S-624 - Torok - Interval 2
Average BH Pressure:
Average Missile HHP:
Open Well Pressure:
Initial OA Pressure:
Max OA Pressure:
Max Proppant Concentration:
Pumps Starting Stage:
Pumps Ending Stage:
Average Visc:
Average Temp:
Average pH:
Proppant Summary
Wanli 16/20 Ceramic Pumped:
100M Pumped:
Total Proppant Pumped* :
30# Hybor G Volume:
30# Linear Volume:
Seawater Volume:
Freeze Protect Volume:
ConocoPhillipsͲ3SͲ624 IntervalSummary 12
12,052 gal 287 bbls
37,291 gal 888 bbls
17,303 gal 412 bbls
69,769 gal 1,661 bbls
5,246 gal 125 bbls
12,000 gal 286 bbls
12,192 gal 290 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Pad Volume:
Minifrac - Treatment Volume:
Displace Ball to Seat Volume:
Fluid Summary (by stage description)
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Spacer and Ball Drop Volume:
Establish Stable Fluid Volume:
Interval Status:
The ball did not shift the sleeve for interval 2 on the first try. CoP made the decision to let the
ball dissolve, flush XL out of the well with SW, drop another ball, and attempt to shift the
sleeve. The sleeve ended up shifting on the second attempt. During the stage, rate was
fluctuating due to losing suction pressure and mechanical pump issues. All proppant was
placed downhole.
*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 Burkette
Willie Martin
Nathan- Brzezinski
Dan Faur
ConocoPhillipsͲ3SͲ624 IntervalSummary 13
2/15/24 16:44
2/15/24 18:30
106 min
10.3 bpm
5,087 psi
6,710 psi
13 bbl
37.3 bpm
4,866 psi
5,995 psi
32.5 bpm
3,566 psi
3,612 psi
5,045 psi
2,836 hhp
440 psi
440 psi
5.16 ppg
4
4
35 %
36 %
30 cP
85 F
9.1
3022 psi
0.584 psi/ft
3058 psi
3031 psi
3012 psi
191,586 lbs
4,622 lbs
196,208 lbs
196,208 lbs
122,456 gal 2,916 bbls
23,921 gal 570 bbls
Final 10 min:
Final 15 min:
Proppant Summary
Wanli 16/20 Ceramic Pumped:
ISDP:
Interval Summary
Average Missile HHP:
Average Temp:
Average Missile Pressure:
Average Surface Pressure:
Average BH Pressure:
Pumps Starting Stage:
Pumps Ending Stage:
Average pH:
Final 5 min:
30# Linear Volume:
100M Pumped:
Max OA Pressure:
Max Proppant Concentration:
Pad Percentage Design
Pad Percentage Actual
Final Fracture Gradient:
Average Visc:
Initial OA Pressure:
Initial Surface Pressure (Breakdown):
Start Date/Time:
3S-624 - 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):
30# Hybor G Volume:
Total Proppant Pumped* :
Proppant in Formation:
Fluid Summary (by fluid description)
ConocoPhillipsͲ3SͲ624 IntervalSummary 14
11,694 gal 278 bbls
27,561 gal 656 bbls
16,381 gal 390 bbls
69,775 gal 1,661 bbls
12,227 gal 291 bbls
8,739 gal 208 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Pad Volume:
Displace Ball to Seat Volume:
Fluid Summary (by stage description)
Conditioning Pad Volume:
Establish Stable Fluid Volume:
Willie Martin
Nathan- Brzezinski
Dan Faur
Interval Status:
The ball for interval 3 seated and shifted the sleeve as expected. During 2 ppg 16/20, rate was
dropped due to losing suction on the blender and the tub level dropping. Prime was recovered
quickly, and rate brought back up. Proppant 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.
Proppant Laden Fluid Volume:
Flush Volume:
Chad Burkette
ConocoPhillipsͲ3SͲ624 IntervalSummary 15
2/16/24 10:47
2/16/24 12:53
126 min
12.2 bpm
6,074 psi
7,594 psi
7 bbl
36.7 bpm
4,446 psi
5,700 psi
33.1 bpm
3,702 psi
3,706 psi
5,152 psi
3,002 hhp
522 psi
160 psi
546 psi
5.19 ppg
5
5
36 %
36 %
27 cP
86.3 F
9.1
199,454 lbs
4,095 lbs
203,549 lbs
203,549 lbs
123,283 gal 2,935 bbls
13,898 gal 331 bbls
3,000 gal 71 bbls
11,749 gal 280 bbls
28,381 gal 676 bbls
16,360 gal 390 bbls
71,088 gal 1,693 bbls
2,149 gal 51 bbls
7,454 gal 177 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Fluid Summary (by fluid description)
*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:
Freeze Protect Volume:
30# Hybor G Volume:
30# Linear Volume:
Average Rate:
Average Missile Pressure:
Average BH Pressure:
Average Missile HHP:
Pumps Ending Stage:
Pad Percentage Actual
Initial BH Pressure (Breakdown):
Open Well Pressure:
Dart/Ball Early :
Max Rate:
Interval Summary
Start Date/Time:
Initial Surface Pressure (Breakdown):
End Date/Time:
Pump Time:
3S-624 - Torok - Interval 4
Max BH Pressure:
Proppant Summary
Wanli 16/20 Ceramic Pumped:
Total Proppant Pumped* :
Pad Percentage Design
Average Surface Pressure:
Pumps Starting Stage:
100M Pumped:
Max OA Pressure:
Max Proppant Concentration:
Average Visc:
Average Temp:
Average pH:
Initial OA Pressure:
Interval 04 was pumped as per design.
Dan Faur
Displace Ball to Seat Volume:
Pad Volume:
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Spacer and Ball Drop Volume:
Fluid Summary (by stage description)
Establish Stable Fluid Volume:
Interval Status:
Chad Burkette
Willie Martin
Nathan- Brzezinski
ConocoPhillipsͲ3SͲ624 IntervalSummary 16
2/16/24 15:30
2/16/24 17:15
106 min
1.7 bpm
6,269 psi
8,180 psi
13 bbl
37.1 bpm
4,663 psi
5,781 psi
33.0 bpm
3,636 psi
3,691 psi
5,110 psi
2,941 hhp
543 psi
572 psi
5.23 ppg
5
5
34 %
34 %
27 cP
86.3 F
9.1
DFIT
9.497 bpm
2205 psi
3868 psi
10.43 bpm
2603 psi
4277 psi
3064 psi
0.592 psi/ft
2826 psi
2757 psi
2711 psi
198,762 lbs
3,791 lbs
202,553 lbs
202,553 lbs
121,803 gal 2,900 bbls
23,980 gal 571 bbls
2,816 gal 67 bbls
Average Missile Pressure:
Max OA Pressure:
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Average Temp:
Initial Surface Pressure (Breakdown):
Max Rate:
Pump Time:
ISDP:
Pumps Starting Stage:
Pumps Ending Stage:
Final Fracture Gradient:
Total Proppant Pumped* :
Initial Rate (Breakdown):
30# Hybor G Volume:
Minifrac Max DH Pressure:
Average pH:
Pad Percentage Actual
3S-624 - Torok - Interval 5
Average BH Pressure:
Initial OA Pressure:
Max Proppant Concentration:
Start Date/Time:
Pad Percentage Design
Average Rate:
Proppant in Formation:
Seawater Volume:
Final 5 min:
Average Missile HHP:
Average Visc:
Max Surface Pressure:
Interval Summary
Minifrac Max Surface Pressure:
Final 10 min:
Final 15 min:
Proppant Summary
Fluid Summary (by fluid description)
Minifrac Average Rate:
Minifrac Average Pressure:
Minifrac Average DH Pressure:
Minifrac Max Rate:
Wanli 16/20 Ceramic Pumped:
30# Linear Volume:
100M Pumped:
Diagnostic method
End Date/Time:
Max BH Pressure:
Average Surface Pressure:
ConocoPhillipsͲ3SͲ624 IntervalSummary 17
12,412 gal 296 bbls
24,772 gal 590 bbls
16,285 gal 388 bbls
71,228 gal 1,696 bbls
11,568 gal 275 bbls
9,518 gal 227 bbls
2,816 gal 67 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Nathan- Brzezinski
While seating the ball for interval 05, the sleeve did not shift initially. Pressure was bled off and
brought back up 12 times before the sleeve shifted. A DFIT was pumped after shifting the
sleeve. The Stage 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 Burkette
Dan Faur
Establish Stable Fluid Volume:
Proppant Laden Fluid Volume:
Interval Status:
DFIT Volume:
Pad Volume:
Willie Martin
Fluid Summary (by stage description)
Conditioning Pad Volume:
Displace Ball to Seat Volume:
Flush Volume:
ConocoPhillipsͲ3SͲ624 IntervalSummary 18
2/17/24 9:20
2/17/24 11:48
148 min
10.7 bpm
5,324 psi
6,865 psi
8 bbl
37.5 bpm
4,229 psi
5,427 psi
33.8 bpm
3,209 psi
3,243 psi
4,692 psi
2,658 hhp
589 psi
139 psi
481 psi
5.64 ppg
5
5
32 %
32 %
26 cP
83.2 F
9
DFIT
10.480 bpm
1824 psi
3497 psi
10.69 bpm
1937 psi
3624 psi
3065 psi
0.594 psi/ft
2881 psi
2775 psi
2726 psi
198,174 lbs
3,423 lbs
201,597 lbs
201,597 lbs
111,963 gal 2,666 bbls
15,209 gal 362 bbls
2,100 gal 50 bbls
Max Proppant Concentration:
Diagnostic method
Pad Percentage Actual
Freeze Protect Volume:
End Date/Time:
Max Surface Pressure:
Max BH Pressure:
Open Well Pressure:
Max OA Pressure:
Wanli 16/20 Ceramic Pumped:
Pad Percentage Design
Average Temp:
Total Proppant Pumped* :
Final Fracture Gradient:
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Initial OA Pressure:
Start Date/Time:
Average Surface Pressure:
Dart/Ball Early :
Average BH Pressure:
100M Pumped:
Pumps Ending Stage:
Minifrac Average Rate:
Minifrac Max DH Pressure:
Average Visc:
Proppant in Formation:
Minifrac Average DH Pressure:
30# Hybor G Volume:
30# Linear Volume:
Final 15 min:
Minifrac Max Surface Pressure:
Minifrac Max Rate:
3S-624 - Torok - Interval 6
Interval Summary
Average pH:
Minifrac Average Pressure:
Final 5 min:
Final 10 min:
Proppant Summary
Fluid Summary (by fluid description)
Pumps Starting Stage:
Max Rate:
Average Missile Pressure:
ISDP:
Average Rate:
Pump Time:
Initial Rate (Breakdown):
Average Missile HHP:
ConocoPhillipsͲ3SͲ624 IntervalSummary 19
10,838 gal 258 bbls
20,027 gal 477 bbls
15,757 gal 375 bbls
68,582 gal 1,633 bbls
1,956 gal 47 bbls
7,597 gal 181 bbls
2,415 gal 58 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Proppant Laden Fluid Volume:
Spacer and Ball Drop Volume:
Pad Volume:
DFIT Volume:
Conditioning Pad Volume:
Interval Status:
Displace Ball to Seat Volume:
A DFIT was pumped after seating the ball for interval 06. Stage pumped as per design. Willie Martin
Nathan- Brzezinski
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 Burkette
Fluid Summary (by stage description)
Establish Stable Fluid Volume:
ConocoPhillipsͲ3SͲ624 IntervalSummary 20
2/17/24 11:48
2/17/24 13:22
94 min
10.3 bpm
5,029 psi
6,541 psi
9 bbl
37.1 bpm
4,873 psi
6,430 psi
33.1 bpm
3,537 psi
3,580 psi
5,050 psi
2,865 hhp
480 psi
529 psi
6.20 ppg
5
5
32 %
32 %
27 cP
87.5 F
9.1
202,324 lbs
3,689 lbs
206,013 lbs
206,013 lbs
109,348 gal 2,604 bbls
11,396 gal 271 bbls
11,396 gal 271 bbls
18,774 gal 447 bbls
15,949 gal 380 bbls
66,579 gal 1,585 bbls
1,211 gal 29 bbls
6,835 gal 163 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Proppant in Formation:
Proppant Laden 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.
Average Visc:
Average BH Pressure:
Average Surface Pressure:
Wanli 16/20 Ceramic Pumped:
Max Surface Pressure:
Max BH Pressure:
Average Rate:
Average Missile Pressure:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Max OA Pressure:
Max Rate:
Initial BH Pressure (Breakdown):
Start Date/Time:
Conditioning Pad Volume:
Total Proppant Pumped* :
Average Temp:
Average Missile HHP:
Average pH:
Max Proppant Concentration:
Displace Ball to Seat Volume:
Pad Volume:
Pump Time:
3S-624 - 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:
Interval Summary
Interval Status:
The sleeve for Interval 07 shifted without issue. Pressure was high initially but broke over and
the stage was pumped as per design.
Fluid Summary (by fluid description)
Spacer and Ball Drop Volume:
30# Hybor G Volume:
Chad Burkette
Establish Stable Fluid Volume:
Willie Martin
Dan Faur
Fluid Summary (by stage description)
Nathan- Brzezinski
30# Linear Volume:
ConocoPhillipsͲ3SͲ624 IntervalSummary 21
2/17/24 13:22
2/17/24 14:28
66 min
9.1 bpm
4,083 psi
5,669 psi
8 bbl
36.6 bpm
3,979 psi
5,326 psi
34.7 bpm
3,127 psi
3,157 psi
4,680 psi
2,660 hhp
493 psi
536 psi
6.88 ppg
5
5
32 %
32 %
26 cP
88.3 F
9.1
200,634 lbs
3,729 lbs
204,363 lbs
204,363 lbs
86,932 gal 2,070 bbls
14,027 gal 334 bbls
16,388 gal 390 bbls
54,946 gal 1,308 bbls
1,571 gal 37 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
The Displacement for the ball on interval 8 was done with XL to prevent having to establish
stable XL after seating again. The sleeve shifted without issue. Interval 08 was pumped as per
design.
Proppant Laden Fluid Volume:
Proppant Summary
Max OA Pressure:
Pumps Ending Stage:
Spacer and Ball Drop Volume:
Initial OA Pressure:
Average Missile Pressure:
Max BH Pressure:
Dart/Ball Early :
End Date/Time:
Pump Time:
Initial Rate (Breakdown):
Max Surface Pressure:
Initial Surface Pressure (Breakdown):
Start Date/Time:
Initial BH Pressure (Breakdown):
30# Hybor G Volume:
Max Rate:
Interval Summary
3S-624 - Torok - Interval 8
Nathan Brzezinski
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:
Average Visc:
Total Proppant Pumped* :
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:
Average Temp:
Interval Status:
Willie Martin
Chad Burkette
ConocoPhillipsͲ3SͲ624 IntervalSummary 22
2/17/24 14:28
2/17/24 15:22
54 min
10.0 bpm
4,034 psi
5,664 psi
8 bbl
37.8 bpm
4,136 psi
5,328 psi
36.1 bpm
3,436 psi
3,473 psi
4,956 psi
3,043 hhp
500 psi
550 psi
7.23 ppg
5
5
32 %
35 %
28 cP
95.5 F
9.1
3166 psi
0.614 psi/ft
3086 psi
3053 psi
3021 psi
199,243 lbs
4,440 lbs
203,683 lbs
203,683 lbs
71,326 gal 1,698 bbls
10,208 gal 243 bbls
2,100 gal 50 bbls
Average Missile HHP:
Initial OA Pressure:
Average Rate:
Final Fracture Gradient:
100M Pumped:
Final 10 min:
Pad Percentage Actual
Max OA Pressure:
Dart/Ball Early :
Average BH Pressure:
Average Missile Pressure:
Interval Summary
ISDP:
Proppant Summary
Wanli 16/20 Ceramic Pumped:
Fluid Summary (by fluid description)
Freeze Protect Volume:
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):
30# Hybor G Volume:
30# Linear Volume:
3S-624 - Torok - Interval 9
Initial BH Pressure (Breakdown):
Start Date/Time:
End Date/Time:
Pump Time:
Average Temp:
Max Proppant Concentration:
Pumps Starting Stage:
Average Surface Pressure:
Final 5 min:
ConocoPhillipsͲ3SͲ624 IntervalSummary 23
12,175 gal 290 bbls
15,723 gal 374 bbls
43,428 gal 1,034 bbls
10,208 gal 243 bbls
2,100 gal 50 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Status:
Pad Volume:
Interval 9 was pumped as per design. This was the last interval on Day 4 of pumping.
Dan Faur
Fluid Summary (by stage description)
Flush Volume:
Freeze Protect Volume:
Conditioning Pad Volume:
Proppant Laden 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.
Willie Martin
Nathan Brzezinski
Chad Burkette
ConocoPhillipsͲ3SͲ624 IntervalSummary 24
2/18/24 8:50
2/18/24 10:09
79 min
10.0 bpm
3,104 psi
4,504 psi
7 bbl
37.0 bpm
3,719 psi
5,032 psi
34.3 bpm
2,945 psi
2,946 psi
4,469 psi
2,472 hhp
418 psi
0 psi
300 psi
7.27 ppg
5
5
32 %
33 %
28 cP
90.7 F
8.9
197,600 lbs
4,003 lbs
201,603 lbs
201,603 lbs
78,525 gal 1,870 bbls
1,093 gal 26 bbls
1,890 gal 45 bbls
8,293 gal 197 bbls
16,662 gal 397 bbls
43,217 gal 1,029 bbls
2,248 gal 54 bbls
9,198 gal 219 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Average Surface Pressure:
Establish Stable Fluid Volume:
Proppant Laden Fluid Volume:
Max Proppant Concentration:
Interval Status:
Pad Volume:
Conditioning Pad Volume:
100M Pumped:
Wanli 16/20 Ceramic Pumped:
Average Temp:
Initial Rate (Breakdown):
Max Surface Pressure:
Max BH Pressure:
Pumps Ending Stage:
Initial Surface Pressure (Breakdown):
Freeze Protect Volume:
Proppant Summary
Average Missile Pressure:
Average Rate:
Spacer and Ball Drop Volume:
Fluid Summary (by stage description)
Willie Martin
Max Rate:
Total Proppant Pumped* :
Proppant in Formation:
Interval 10 was pumped as per design. This was the first stage of pumping of the day
Interval Summary
Pump Time:
Start Date/Time:
3S-624 - Torok - Interval 10
End Date/Time:
Fluid Summary (by fluid description)
30# Linear Volume:
Average Missile HHP:
Open Well Pressure:
Initial OA Pressure:
Initial BH Pressure (Breakdown):
Pad Percentage Actual
Pumps Starting Stage:
Dart/Ball Early :
30# Hybor G Volume:
Average Visc:
Pad Percentage Design
Max OA Pressure:
Average pH:
Average BH Pressure:
Nathan Brzezinski
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 Burkette
ConocoPhillipsͲ3SͲ624 IntervalSummary 25
2/18/24 10:09
2/18/24 11:04
55 min
10.2 bpm
3,662 psi
5,224 psi
6 bbl
37.1 bpm
3,741 psi
5,081 psi
34.7 bpm
3,139 psi
3,152 psi
4,677 psi
2,666 hhp
300 psi
369 psi
7.26 ppg
5
5
32 %
33 %
26 cP
95.8 F
8.8
200,602 lbs
3,505 lbs
204,107 lbs
204,107 lbs
69,700 gal 1,660 bbls
9,110 gal 217 bbls
15,881 gal 378 bbls
42,981 gal 1,023 bbls
1,728 gal 41 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Max Surface Pressure:
Spacer and Ball Drop Volume:
Average Missile Pressure:
Proppant Laden Fluid Volume:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Max BH Pressure:
Average Rate:
Average BH Pressure:
Start Date/Time:
Interval Status:
Initial OA Pressure:
Willie Martin
Average Missile HHP:
Pumps Starting Stage:
100M Pumped:
Conditioning Pad Volume:
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-624 - 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
Nathan Brzezinski
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.
Pad Percentage Design
Average Surface Pressure:
Max OA Pressure:
Fluid Summary (by stage description)
Pad Volume:
Stage 11 was pumped as per design.
Chad Burkette
ConocoPhillipsͲ3SͲ624 IntervalSummary 26
2/18/24 11:04
2/18/24 11:57
53 min
10.2 bpm
4,680 psi
6,227 psi
7 bbl
37.3 bpm
4,930 psi
6,339 psi
34.4 bpm
3,333 psi
3,349 psi
4,874 psi
2,809 hhp
368 psi
405 psi
7.31 ppg
5
5
32 %
31 %
28 cP
99.3 F
8.8
203,351 lbs
3,597 lbs
206,948 lbs
206,948 lbs
69,013 gal 1,643 bbls
7,994 gal 190 bbls
16,250 gal 387 bbls
44,068 gal 1,049 bbls
701 gal 17 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Conditioning Pad Volume:
Pad Volume:
Proppant in Formation:
Total Proppant Pumped* :
100M Pumped:
Max Surface Pressure:
Spacer and Ball Drop Volume:
Wanli 16/20 Ceramic Pumped:
Pumps Ending Stage:
Pad Percentage Design
Proppant Laden Fluid Volume:
Average Temp:
Interval Status:
Interval 12 was pumped as per design. Sand was offloaded into the mover on the fly. Willie Martin
Nathan Brzezinski
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 Burkette
Proppant Summary
Fluid Summary (by fluid description)
30# Hybor G Volume:
Fluid Summary (by stage description)
Start Date/Time:
Average Rate:
Average Missile Pressure:
Pad Percentage Actual
Initial Rate (Breakdown):
Average BH Pressure:
Dart/Ball Early :
Max BH Pressure:
Average Visc:
Average Surface Pressure:
Max OA Pressure:
Average pH:
Max Rate:
Initial OA Pressure:
End Date/Time:
Pumps Starting Stage:
Max Proppant Concentration:
Pump Time:
3S-624 - Torok - Interval 12
Interval Summary
Initial BH Pressure (Breakdown):
Average Missile HHP:
Initial Surface Pressure (Breakdown):
ConocoPhillipsͲ3SͲ624 IntervalSummary 27
2/18/24 11:57
2/18/24 12:56
59 min
10.3 bpm
3,971 psi
5,539 psi
5 bbl
37.2 bpm
3,922 psi
5,257 psi
31.0 bpm
2,743 psi
2,755 psi
4,356 psi
2,084 hhp
373 psi
413 psi
7.43 ppg
5
5
32 %
30 %
28 cP
95.3 F
8.9
199,513 lbs
3,518 lbs
203,031 lbs
203,031 lbs
67,960 gal 1,618 bbls
7,859 gal 187 bbls
15,071 gal 359 bbls
44,060 gal 1,049 bbls
970 gal 23 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
100M Pumped:
Proppant in Formation:
30# Hybor G Volume:
Max Rate:
Wanli 16/20 Ceramic Pumped:
Average BH Pressure:
Interval Status:
Dart/Ball Early :
Pumps Ending Stage:
Average Temp:
Pad Volume:
Average Surface Pressure:
Start Date/Time:
3S-624 - Torok - Interval 13
Average Rate:
Pad Percentage Design
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Max Surface Pressure:
Max Proppant Concentration:
Proppant Summary
Pumps Starting Stage:
Max BH Pressure:
*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 BH Pressure (Breakdown):
Average Missile Pressure:
Pump Time:
Chad Burkette
Max OA Pressure:
Average Visc:
Average pH:
Initial OA Pressure:
Average Missile HHP:
Interval Summary
End Date/Time:
Total Proppant Pumped* :
Conditioning Pad Volume:
Spacer and Ball Drop Volume:
Pad Percentage Actual
Proppant Laden Fluid Volume:
Fluid Summary (by stage description)
During 3 ppg sand, town requested to drop rate from 37 to 30 bpm due to Net Pressure
decreasing. Stage was pumped as per design.
Willie Martin
Nathan Brzezinski
Dan Faur
Fluid Summary (by fluid description)
ConocoPhillipsͲ3SͲ624 IntervalSummary 28
2/18/24 12:56
2/18/24 13:55
59 min
10.3 bpm
6,295 psi
8,073 psi
10 bbl
37.5 bpm
6,456 psi
7,930 psi
32.9 bpm
3,542 psi
3,549 psi
5,064 psi
2,853 hhp
354 psi
417 psi
7.06 ppg
5
5
32 %
33 %
27 cP
94.7 F
8.8
2997 psi
0.576 psi/ft
2937 psi
2900 psi
2842 psi
201,397 lbs
3,439 lbs
204,836 lbs
204,836 lbs
69,747 gal 1,661 bbls
11,027 gal 263 bbls
41,958 gal 999 bbls
Initial BH Pressure (Breakdown):
Average Surface Pressure:
Pad Percentage Design
Pad Percentage Actual
ISDP:
Final Fracture Gradient:
Final 5 min:
100M Pumped:
Average Rate:
Average Missile Pressure:
Pumps Ending Stage:
End Date/Time:
Average Temp:
Dart/Ball Early :
Max Surface Pressure:
Max OA Pressure:
Max Proppant Concentration:
Initial Rate (Breakdown):
Final 15 min:
Proppant Summary
Pump Time:
Average pH:
Wanli 16/20 Ceramic Pumped:
Max Rate:
Max BH Pressure:
3S-624 - Torok - Interval 14
Final 10 min:
Average Visc:
Initial OA Pressure:
Interval Summary
Start Date/Time:
Average Missile HHP:
Pumps Starting Stage:
Average BH Pressure:
Initial Surface Pressure (Breakdown):
Total Proppant Pumped* :
Seawater Volume:
30# Linear Volume:
Proppant in Formation:
Fluid Summary (by fluid description)
30# Hybor G Volume:
ConocoPhillipsͲ3SͲ624 IntervalSummary 29
9,673 gal 230 bbls
16,190 gal 385 bbls
43,884 gal 1,045 bbls
9,347 gal 223 bbls
41,958 gal 999 bbls
1,680 gal 40 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Status:
Flush Volume:
WL Pump Down SW Volume:
WL Pump Down Gel Volume:
Chad Burkette
While shifting the sleeve, all pumps kicked out. The sleeve shifted but after getting rate back
BH Pressure was high and rate was limited. Once 100 Mesh hit downhole, pressure broke and
the pressure trend mirrored previous stages. Interval 14 was the final interval pumped for the
day.
Fluid Summary (by stage description)
Nathan Brzezinski
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.
Proppant Laden Fluid Volume:
Pad Volume:
Willie Martin
Conditioning Pad Volume:
ConocoPhillipsͲ3SͲ624 IntervalSummary 30
2/20/24 9:28
2/20/24 10:59
91 min
10.2 bpm
2,870 psi
4,415 psi
9 bbl
37.1 bpm
4,201 psi
5,649 psi
31.8 bpm
2,722 psi
2,648 psi
4,195 psi
2,122 hhp
216 psi
185 psi
390 psi
7.31 ppg
5
5
32 %
26 %
30 cP
86 F
9
195,834 lbs
4,143 lbs
199,977 lbs
199,977 lbs
92,685 gal 2,207 bbls
1,211 gal 29 bbls
4,536 gal 108 bbls
8,060 gal 192 bbls
16,045 gal 382 bbls
60,874 gal 1,449 bbls
2,140 gal 51 bbls
6,777 gal 161 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Average Rate:
Start Date/Time:
30# Hybor G Volume:
Proppant Laden Fluid Volume:
Proppant Summary
Total Proppant Pumped* :
Proppant in Formation:
Average Temp:
Open Well Pressure:
Fluid Summary (by fluid description)
Freeze Protect Volume:
Spacer and Ball Drop Volume:
Average Surface Pressure:
Wanli 16/20 Ceramic Pumped:
30# Linear Volume:
Max Surface Pressure:
Fluid Summary (by stage description)
Pump Time:
Initial Rate (Breakdown):
Initial OA Pressure:
Max OA Pressure:
Max Proppant Concentration:
Pumps Starting Stage:
Conditioning Pad Volume:
100M Pumped:
Average Visc:
Average pH:
Chad Burkette
Average Missile HHP:
During the 5.5 ppg sand stage, Suction on the blenders was lost. Sand and XL'ers were cut
until prime was regained, once prime was achieved and XL fluid established, the stage was
resume and proppant was stepped back up to 7 ppg.
Dart/Ball Early :
3S-624 - 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):
Initial BH Pressure (Breakdown):
Average BH Pressure:
Pad 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.
Establish Stable Fluid Volume:
Willie Martin
Nathan Brzezinski
Dan Faur
Interval Status:
ConocoPhillipsͲ3SͲ624 IntervalSummary 31
2/20/24 10:59
2/20/24 12:00
61 min
10.3 bpm
3,694 psi
5,414 psi
6 bbl
37.2 bpm
3,687 psi
4,986 psi
35.3 bpm
2,824 psi
2,763 psi
4,327 psi
2,441 hhp
378 psi
414 psi
7.14 ppg
5
5
32 %
30 %
28 cP
84.6 F
8.9
199,056 lbs
3,497 lbs
202,553 lbs
202,553 lbs
66,001 gal 1,571 bbls
7,362 gal 175 bbls
14,394 gal 343 bbls
43,184 gal 1,028 bbls
1,061 gal 25 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Spacer and Ball Drop Volume:
Fluid Summary (by stage description)
Total Proppant Pumped* :
100M Pumped:
30# Hybor G Volume:
Pad Volume:
Average Surface Pressure:
Fluid Summary (by fluid description)
Pumps Starting Stage:
Start Date/Time:
Average BH Pressure:
Average Rate:
Wanli 16/20 Ceramic Pumped:
Average Temp:
Average pH:
Interval Status:
Interval Summary
Pad Percentage Actual
Initial OA Pressure:
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Average Missile HHP:
Max OA Pressure:
Max Proppant Concentration:
Pad Percentage Design
Average Visc:
Pump Time:
3S-624 - Torok - Interval 16
Max Rate:
End Date/Time:
Max BH Pressure:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Proppant in Formation:
Pumps Ending Stage:
Max Surface Pressure:
Average Missile Pressure:
Proppant Summary
Willie Martin
Nathan Brzezinski
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 Burkette
Interval 16 was pumped as per design.
ConocoPhillipsͲ3SͲ624 IntervalSummary 32
2/20/24 12:00
2/20/24 12:30
30 min
9.0 bpm
5,894 psi
7,160 psi
4 bbl
37.3 bpm
2,716 psi
4,045 psi
34.8 bpm
2,306 psi
2,251 psi
3,768 psi
1,966 hhp
376 psi
436 psi
7.06 ppg
5
5
34 %
38 %
28 cP
88.7 F
8.9
132,442 lbs
3,420 lbs
135,862 lbs
135,862 lbs
51,481 gal 1,226 bbls
4,729 gal 113 bbls
16,430 gal 391 bbls
29,102 gal 693 bbls
1,220 gal 29 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Pad Volume:
Interval Status:
Initial Rate (Breakdown):
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:
Average BH Pressure:
Total Proppant Pumped* :
Fluid Summary (by stage description)
Interval 17 was pumped as per design. This was the first interval with the 130k lb design. Willie Martin
Nathan Brzezinski
Dan Faur
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Spacer and Ball Drop Volume:
Start Date/Time:
End Date/Time:
Max Proppant Concentration:
100M Pumped:
Fluid Summary (by fluid description)
Chad Burkette
3S-624 - Torok - Interval 17
Interval Summary
Average pH:
Proppant Summary
Average Missile Pressure:
Max Surface Pressure:
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Pumps Ending Stage:
Pad Percentage Design
Pad Percentage Actual
Proppant in Formation:
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.
Wanli 16/20 Ceramic Pumped:
Average Rate:
ConocoPhillipsͲ3SͲ624 IntervalSummary 33
2/20/24 12:30
2/20/24 13:07
37 min
10.2 bpm
2,139 psi
3,822 psi
6 bbl
37.2 bpm
3,367 psi
4,668 psi
33.5 bpm
2,482 psi
2,424 psi
3,990 psi
2,039 hhp
414 psi
442 psi
7.10 ppg
5
5
34 %
32 %
27 cP
84.4 F
8.9
131,660 lbs
3,473 lbs
135,133 lbs
135,133 lbs
46,453 gal 1,106 bbls
1,276 gal 30 bbls
14,868 gal 354 bbls
29,119 gal 693 bbls
1,190 gal 28 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Initial Rate (Breakdown):
Average Rate:
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Initial OA Pressure:
Max OA Pressure:
Average Missile Pressure:
Fluid Summary (by fluid description)
Total Proppant Pumped* :
Proppant in Formation:
Wanli 16/20 Ceramic Pumped:
30# Hybor G Volume:
Start Date/Time:
Average Surface Pressure:
Fluid Summary (by stage description)
Spacer and Ball Drop Volume:
Chad Burkette
3S-624 - Torok - Interval 18
Pump Time:
Interval Status:
Willie Martin
Nathan Brzezinski
Dan Faur
Interval 18 was pumped as per design.
Average Visc:
Max Surface Pressure:
Average BH Pressure:
100M Pumped:
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.
Pad Volume:
Average Missile HHP:
Max Rate:
Max BH Pressure:
Initial Surface Pressure (Breakdown):
Interval Summary
Average Temp:
Average pH:
End Date/Time:
Dart/Ball Early :
Initial BH Pressure (Breakdown):
Pad Percentage Design
Max Proppant Concentration:
Pad Percentage Actual
Proppant Summary
ConocoPhillipsͲ3SͲ624 IntervalSummary 34
2/20/24 13:07
2/20/24 13:44
37 min
9.9 bpm
3,242 psi
4,892 psi
3 bbl
37.2 bpm
3,695 psi
5,025 psi
34.3 bpm
2,519 psi
2,457 psi
4,011 psi
2,115 hhp
414 psi
453 psi
7.13 ppg
5
5
34 %
35 %
29 cP
89.5 F
9
129,265 lbs
3,761 lbs
133,026 lbs
133,026 lbs
47,033 gal 1,120 bbls
1,432 gal 34 bbls
16,465 gal 392 bbls
28,332 gal 675 bbls
804 gal 19 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Pad Percentage Design
Proppant Summary
Max Proppant Concentration:
3S-624 - Torok - Interval 19
Initial Surface Pressure (Breakdown):
Pad Volume:
Average Surface Pressure:
Proppant in Formation:
100M Pumped:
Conditioning Pad Volume:
Total Proppant Pumped* :
Proppant Laden Fluid Volume:
Fluid Summary (by stage description)
Average Missile HHP:
Pumps Ending Stage:
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
Average BH Pressure:
Max Surface Pressure:
Pump Time:
Initial OA Pressure:
Initial BH Pressure (Breakdown):
Max OA Pressure:
Chad Burkette
Average Temp:
Average Missile Pressure:
Average pH:
30# Hybor G Volume:
Interval 19 was pumped as per design. Willie Martin
Nathan Brzezinski
Dan Faur
Fluid Summary (by fluid description)
Spacer and Ball Drop Volume:
Wanli 16/20 Ceramic Pumped:
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.
ConocoPhillipsͲ3SͲ624 IntervalSummary 35
2/20/24 13:44
2/20/24 15:56
132 min
9.9 bpm
3,104 psi
4,676 psi
1 bbl
37.4 bpm
2,301 psi
3,629 psi
30.2 bpm
1,897 psi
1,845 psi
3,364 psi
1,402 hhp
362 psi
449 psi
7.26 ppg
5
5
34 %
33 %
27 cP
93 F
8.9
Minifrac
32.910 bpm
3249 psi
4607 psi
37.09 bpm
3547 psi
4827 psi
2898 psi
0.552 psi/ft
2846 psi
2824 psi
2803 psi
133,099 lbs
3,329 lbs
136,428 lbs
136,428 lbs
68,817 gal 1,639 bbls
2,503 gal 60 bbls
Pad Percentage Design
Minifrac Average Pressure:
Max Surface Pressure:
Pumps Ending Stage:
Minifrac Average Rate:
Average BH Pressure:
Max Proppant Concentration:
Average Visc:
Initial Rate (Breakdown):
Pumps Starting Stage:
3S-624 - Torok - Interval 20
Minifrac Max DH Pressure:
Final 5 min:
Max OA Pressure:
Pad Percentage Actual
Minifrac Max Surface Pressure:
ISDP:
Average Missile HHP:
Minifrac Max Rate:
Initial OA Pressure:
Pump Time:
Interval Summary
Start Date/Time:
End Date/Time:
Final 10 min:
Final Fracture Gradient:
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:
Diagnostic method
Proppant Summary
Wanli 16/20 Ceramic Pumped:
100M Pumped:
Minifrac Average DH Pressure:
Average Temp:
Fluid Summary (by fluid description)
Final 15 min:
Total Proppant Pumped* :
Proppant in Formation:
30# Linear Volume:
30# Hybor G Volume:
ConocoPhillipsͲ3SͲ624 IntervalSummary 36
1,018 gal 24 bbls
15,717 gal 374 bbls
28,989 gal 690 bbls
1,199 gal 29 bbls
6,463 gal 154 bbls
15,431 gal 367 bbls
2,503 gal 60 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Establish Stable Fluid Volume:
Minifrac - Treatment Volume:
Minifrac - Flush Volume:
After displacing the ball for interval 20 a minifrac was pumped. While pumping XL a leak was
observed from a chiksan on the surface. Decision was made to flush the surface lines and shut
down. After fixing the leak and analysing minifrac data, the stage was pumped to completion
without issue.
Interval Status:
Willie Martin
Nathan Brzezinski
Proppant Laden Fluid Volume:
Spacer and Ball Drop Volume:
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 Burkette
Pad Volume:
Fluid Summary (by stage description)
Conditioning Pad Volume:
ConocoPhillipsͲ3SͲ624 IntervalSummary 37
2/20/24 15:56
2/20/24 16:31
35 min
9.9 bpm
3,847 psi
5,393 psi
4 bbl
37.3 bpm
3,285 psi
4,693 psi
31.7 bpm
2,204 psi
2,175 psi
3,764 psi
1,710 hhp
413 psi
442 psi
7.33 ppg
5
5
34 %
27 %
27 cP
93 F
9
128,217 lbs
2,014 lbs
130,231 lbs
130,231 lbs
40,402 gal 962 bbls
1,854 gal 44 bbls
10,322 gal 246 bbls
27,032 gal 644 bbls
1,194 gal 28 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Total Proppant Pumped* :
30# Hybor G Volume:
Interval 21 was pumped as per design.
3S-624 - Torok - Interval 21
Nathan Brzezinski
Dan Faur
Chad Burkette
Interval Status:
Average BH Pressure:
Pumps Starting Stage:
Willie Martin
Average Temp:
Average Missile Pressure:
Average Surface Pressure:
Pad Percentage Actual
Average Rate:
Max Surface Pressure:
Max BH Pressure:
Pad Volume:
Max Proppant Concentration:
Pad Percentage Design
Average pH:
Proppant in Formation:
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:
100M Pumped:
Average Missile HHP:
Pumps Ending Stage:
Average Visc:
Interval Summary
Proppant Summary
Wanli 16/20 Ceramic Pumped:
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Spacer and Ball Drop Volume:
Start Date/Time:
End Date/Time:
Pump Time:
ConocoPhillipsͲ3SͲ624 IntervalSummary 38
2/20/24 16:31
2/20/24 17:05
34 min
12.2 bpm
1,752 psi
3,487 psi
8 bbl
37.3 bpm
3,391 psi
4,904 psi
36.6 bpm
2,115 psi
2,073 psi
3,641 psi
1,898 hhp
410 psi
367 psi
7.29 ppg
5
5
34 %
28 %
26 cP
89.7 F
8.9
2966 psi
0.564 psi/ft
2910 psi
2888 psi
2869 psi
133,405 lbs
0 lbs
133,405 lbs
133,405 lbs
40,916 gal 974 bbls
5,376 gal 128 bbls
3,780 gal 90 bbls
Final 15 min:
100M Pumped:
Initial Rate (Breakdown):
3S-624 - Torok - Interval 22
ISDP:
Proppant Summary
Wanli 16/20 Ceramic Pumped:
Final Fracture Gradient:
Max Proppant Concentration:
Initial Surface Pressure (Breakdown):
Final 5 min:
30# Linear Volume:
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:
Total Proppant Pumped* :
Fluid Summary (by fluid description)
Freeze Protect Volume:
30# Hybor G Volume:
Proppant in Formation:
Final 10 min:
ConocoPhillipsͲ3SͲ624 IntervalSummary 39
2,037 gal 49 bbls
10,975 gal 261 bbls
27,904 gal 664 bbls
5,376 gal 128 bbls
3,780 gal 90 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Status:
Chad Burkette
*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 stage description)
Pad Volume:
Flush Volume:
Freeze Protect Volume:
Interval 22 sleeve was shifted with the Collet dart. During interval 21, all 100 Mesh was
pumped from the hopper and there was no more 100 Mesh loaded for Interval 22. The
remaining of interval 22 was pumped as per design. This was the final proppant frac for the
day. However, another Collet Dart was dropped to shift sleeve 24. There was no indication on
surface or on the DH guage that the sleeve shifted. A second ball was dropped, but there was
no pressure indication it seated or shifted the sleeve.
Willie Martin
Nathan Brzezinski
Dan Faur
Proppant Laden Fluid Volume:
Conditioning Pad Volume:
ConocoPhillipsͲ3SͲ624 IntervalSummary 40
CustomerFormationLeaseAPIDateWellSummaryWanli16/20Ceramic 100M TotalProppantrfacePress Rate Visc Temp pHrfacePress Rate bbl gal bbl gal bbl gal bbl gal bbl lbs lbs lbs13838 24.8 29 75 8.9 5084 37.1 4,2489,28022115,6883741002203,4844,845205,6543,231208,88523727 31.4 30 88 9.1 5072 39.1 3,5371,7744215,5243702,00048167,8533,997200,7454,295205,04033612 32.5 30 85 9.1 4866 37.3 2,91623,921570146,3773,485191,5864,622196,20843706 33.1 27 86 9.1 4446 36.7 2,93513,8983313,00071140,1813,338199,4544,095203,54953691 33.0 27 86 9.1 4663 37.1 2,90023,9805712,81667148,5993,538198,7623,791202,55363243 33.8 26 83 9.0 4229 37.5 2,66615,2093622,10050129,2723,078198,1743,423201,59773580 33.1 27 88 9.1 4873 37.1 2,60411,396271120,7442,875202,3243,689206,01383157 34.7 26 88 9.1 3979 36.6 2,07086,9322,070200,6343,729204,36393473 36.1 28 96 9.1 4136 37.8 1,69810,2082432,1005083,6341,991199,2434,440203,683102946 34.3 28 91 8.9 3719 37.0 1,8701,093261,8904581,5081,941197,6004,003201,603113152 34.7 26 96 8.8 3741 37.1 1,66069,7001,660200,6023,505204,107123349 34.4 28 99 8.8 4930 37.3 1,64369,0131,643203,3513,597206,948132755 31.0 28 95 8.9 3922 37.2 1,61867,9601,618199,5133,518203,031143549 32.9 27 95 8.8 6456 37.5 1,66111,02726341,958999122,7322,922201,3973,439204,836152648 31.8 30 86 9.0 4201 37.1 2,2071,211294,53610898,4322,344195,8344,143199,977162763 35.3 28 85 8.9 3687 37.2 1,57166,0011,571199,0563,497202,553172251 34.8 28 89 8.9 2716 37.3 1,22651,4811,226132,4423,420135,862182424 33.5 27 84 8.9 3367 37.2 1,10646,4531,106131,6603,473135,133192457 34.3 29 90 9.0 3695 37.2 1,12047,0331,120129,2653,761133,026201845 30.2 27 93 8.9 2301 37.4 1,6392,5036071,3201,698133,0993,329136,428212175 31.7 27 93 9.0 3285 37.3 96240,402962128,2172,014130,231222073 36.6 26 90 8.9 3391 37.3 9745,3761283,7809075,9041,807133,405133,405230 0.0 0 0 0.0 0 0.0240 0.0 0 0 0.0 0 0.0 25,83261525,832615Minimum9621093262816671002258326151282172014130231Average203810067240203644852438589395022371810013667184501Maximum42482398057141958999453610820348448452056544622208885Wanli16/20Ceramic 100M TotalProppantPressure Rate Visc Temp pH Pressure Rate bbl gal bbl gal bbl gal bbl gal bbl lbs lbs TotalPlanned43,590 124,893 2,974 91,438 2,177 9,730 232 2,056,839 48,972 3,984,000 84,000 4,068,000Recorded3456 33.0 28 88 9.00 6456 39.1 44,829 130,876 3,116 101,818 2,424 19,506 464 2,160,847 51,449 3,982,017 77,014 4,059,031WeightTickets3,998,163 98,000 4,130,163**ProppantisbilledfromWeightTicketvolumesFebruary12,202450Ͳ103Ͳ208683SͲ624TorokConocoPhillipsIntervalAverage MaxSeawaterAverage MaxSeawater30#HyborG 30#Linear30#HyborG 30#Linear**IFSnumbersforproppantaretakenfromsoftwarecalculationsbasedonTotalFluidFluidsProppantsFluidsProppantsTotalFluidFreezeProtectFreezeProtectConocoPhillipsͲ3SͲ624 FluidSystemͲProppantSummary41
Hydraulic Fracturing Fluid Product Component Information Disclosure
2/12/2024
Alaska
HARRISON BAY
50-103-20868
CONOCOPHILLIPS
3S 624
-150.1984
70.3340
NAD83
none
Oil
5263
1933316
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%79.58579%16471853 Density = 8.52 Halliburton
BE-6(TM)
Bactericide Halliburton Microbiocide 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
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
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%0.00079%165
2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00%0.00136%282
2-Methyl-4-isothiazolin-3-one 2682-20-4 0.01%0.00002%5
5-Chloro-2-methyl-3(2H)-
Isothaiazolone 26172-55-4 0.01%0.00002%5
A 1-25 Proprietary 20.00%0.00005%11 Patina Energy Product Stewardship
test@patinae
nergy.com 6692416025
Ammonium persulfate 7727-54-0 100.00%0.02854%5907
Borate salts Proprietary 60.00%0.12004%24845
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%0.00007%16
Calcium magnesium carbonate 16389-88-1 1.00%0.00200%415
Corundum 1302-74-5 65.00%12.55645%2598806
Crystalline silica, quartz 14808-60-7 100.00%0.48080%99511
Ethanol 64-17-5 60.00%0.04755%9841
Flow Insurance Copper Proprietary 100.00%0.00000%0 Patina Energy Product Stewardship
test@patinae
nergy.com 6692416025
Gluteraldehyde 111-30-8 1.00%0.00200%415
Guar gum 9000-30-0 100.00%0.28064%58083
Heavy aromatic petroleum
naphtha 64742-94-5 30.00%0.02377%4921
Inorganic mineral 1317-65-3 5.00%0.01000%2071
Inorganic mineral Proprietary 1.00%0.00200%415 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Magensium chloride 7786-30-3 0.01%0.00002%5
Magnesium nitrate 10377-60-3 0.01%0.00002%5
Methanesulfonic acid, 1-hydroxy-,
sodium salt 870-72-4 0.10%0.00020%42
Mullite 1302-93-8 45.00%8.69293%1799174
Naphthalene 91-20-3 5.00%0.00396%821
Oxyalkylated nonyl phenolic resin Proprietary 30.00%0.02377%4921 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Oxyalkylated phenolic resin Proprietary 10.00%0.00792%1641 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Oxylated phenolic resin Proprietary 30.00%0.00856%1773 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%0.00396%821
Polymer Proprietary 1.00%0.00200%415 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Potassium chloride 7447-40-7 5.00%0.01000%2071
Potassium Formate 590-29-4 100.00%0.00000%0
Sodium bisulfate 7681-38-1 0.10%0.00020%42
Sodium chloride 7647-14-5 5.00%3.97962%823661
Sodium hydroxide 1310-73-2 30.00%0.00990%2050
Water 7732-18-5 100.00%0.15324%31716
* 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
Allcomponentinformationlistedwasobtainedfromthesupplier’sMaterialSafetyDataSheets(MSDS).Assuch,theOperatorisnotresponsibleforinaccurateand/orincompleteinformation.AnyquestionsregardingthecontentoftheMSDSshouldbedirectedtothesupplier
whoprovidedit.TheOccupationalSafetyandHealthAdministration’s(OSHA)regulationsgovernthecriteriaforthedisclosureofthisinformation.PleasenotethatFederalLawprotects"proprietary","tradesecret",and"confidentialbusinessinformation"andthecriteriaforhow
thisinformationisreportedonanMSDSissubjectto29CFR1910.1200(i)andAppendixD.
Production Type:
True Vertical Depth (TVD):
Total Water Volume (gal)*:
MSDS and Non-MSDS Ingredients are listed below the green line
Well Name and Number:
Longitude:
Latitude:
Long/Lat Projection:
Indian/Federal:
Fracture Date
State:
County:
API Number:
Operator Name:
Page 1/2Procedure Closeout3S-624Primary Job TypeINITIAL COMPLETIONStart Date2/7/2024End Date2/22/2024Final Job StatusCOMPLETEDTotal Time Log Hours (hr)330.87SummaryNetwork/Order NumberProject DescEstimator10441030 3S-624 - Frac - FracStart Date ZX Code Time Log Hrs (hr)Cum Time Log (days)Last 24hr Sum2/7/2024 ZX02 Fracturing 18.49 0.77 HALLIBURTON, SPOTTED IN THE PROPPANT EQUIPMENT, STAGED EQUIPMENT ON PADLYNDEN, PRELOADING PROPPANT, AND TANK FARM MAINTENANCE2/8/2024 ZX02 Fracturing 5.49 1.00 CONTINUED LOADING PROPPANT, TANK FARM MAINTENANCE, SPOTTED FRAC EQUIPMENT RAN THE SEAWATER HARD LINE.2/9/2024 ZX02 Fracturing 23.99 2.00 HALLIBURTON CONTINUED SPOTTING THE LAST OF THE FRAC EQUIPMENT, RESUMED RUNNING HARD LINE, INSTALLED THE STAGE COMPLETIONS EROSION TEST FIXTURE, SPOTTED THE BLEED TANKS, AND IA/OA PRV TANKSLYNDEN, CONTINUED PROPPANT OPERATIONS, STARTED FLOWING SEAWATER UNTIL SUPPLY LINE SHUTDOWN @22:452/10/2024 ZX02 Fracturing 23.99 3.00 CONTINUED RIGGING IN, NIPPLED UP THE LAUNCHER EQUIPMENT, HUNG THE RISER, SET THE CVA, AND BLEED SKID. STARTED TRUCKING WATER IN THE AFTERNOON, SEAWATER LINE WAS BACK UP FLOWING @ 18:00 LOW FLOW RATE, SECONDARY HEATER ON LOCATION @19:00 FOR HEATING TRUCKED SEAWATER.PROPPANT ON PAD LOADING COMPLETED.2/11/2024 ZX02 Fracturing 23.99 4.00 COMPLETED THE RIG IN, RUNNING THE LAUNCHER RISER TO THE LAUNCH STACK, DROPPED THE TUBING DOWN JOINT RAN HARD LINE TO THE TANKS AND IA IRON TO PRV SKID, SPOTTED AND RIGGED PRV SKID, INSTALLED THE OA PRV AND THE LINE TO THE POP TANK, SPOTTED IN CHEMS, TIED IN COLDBORE, CONNECTED TO THE DHG, COMPLETED ALL IRON TIE INNS.CONTINUED FLOWING WATER, SHUT DOWN @4:30PM 23 TANKS USABLE.2/12/2024 ZX02 Fracturing 23.99 5.00 POPPED THE ARSNEL GLASS DISC, FIRST ATTEMPT WE PRESSURED UP TO 7000 PSI, BLED PRESSURE DOWN TO 500 PSI, CAME BACK UP WITH PRESSURE, THE DISC BROKE @ 4576 PSI, DROPPED THE WIV PHENOLIC BALL, PUMPED 220 BBL @ 5BPM, SLOWED TO 3 BPM BALL SEATED @267BBL DISPLACED, SHUT PUMPS DOWN, BROUGHT PRESSURE UP TO A 6500 PSI TARGET FOR THE ALPHA SLEEVE GOOD SHIFT, ROLLED INTO THE DFIT PUMPED @ 10BPM FOR 5 MINUTES FOLLOWED BY A HARD SHUTDOWN. DURING CHEM LOADING AND GEL MIXING A CRACKED STRAINER T WAS FOUND ON THE GEL BLENDER, WE PUSHED OFF THE TUB DOWN HOLE @9 BPM SHUT DOWN RIGGED IN LRS TO DO THE 37 BBL FREEZE PROTECT.2/13/2024 ZX02 Fracturing 23.99 6.00 COMPLETED STAGE 1 TO DESIGNJSV 4835, TOTAL PROPPANT PLACED 208,885 LBSTAGE 2 BALL ON SEAT 7BBL EARLY @ 4835 JSV, UNABLE TO SHIFT, MULTIPLE ATTEMPTS MADE BLEEDING PRESSURE RE PRESSURING AND HOLDING PSI FLOWED BACK MINIMAL RETURNS, REATTEMPTED SHIFT MULTIPLE TIMES, FLOWED BACK , ATTEMPTED FREEZE PROTECT 2.3BBL DIESEL DISPLACED.2/14/2024 ZX02 Fracturing 24.00 7.00 LRS SPOTTED UP, PUMPED 35 BBL DIESEL, MAX PRESSURE 3950, MAX RATE 1.58 BPM.2/15/2024 ZX02 Fracturing 23.99 8.00 DROPPED 2ND BALL FOR STAGE 2 BALL 2.116, BALL ON SEAT BALL LANDED 12 BBL EARLY @ 326BBL JSV, NO SHIFT PUMPS KICKED OUT, BLED DOWN REPEATING THE CYCLE 3 RD TIME AFTER HOLDING SLEEVE SHIFTED, PUMPED STAGE TOP DESIGN;START TIME 14:44, END TIME 16:44, AVG RATE 31.4, AVG BHP 5157, AVG SURFACE PSI 3727, TOTAL PROPPANT 205040 LB, TOTAL CLEAN 3655 BBLJSV 4132,STAGE 3 GOOD SHIFT 12 BBL EARLY @ 4132 JSV, STAGE PUMPED TO DESIGN;START TIME, 16:44, END TIME, 18:30, AVG RATE 32.5 BPM, AVG BHP 542, AVG SURFACE PSI 3612, TOTAL PROPPANT 196208 LB, TOTAL CLEAN 3485, JSV 39622/16/2024 ZX02 Fracturing 23.99 9.00 STAGE 4 START TIME 10:47, STAGE END TIME 12:53, DROPPED BALL 3 2.184" MEASURED, BALL ON SEAT 12 BBL EARLY @ 286 BBL JSV, DIFFERENTIAL PSI 4047 BBL, PUMPED STAGE TO DESIGN, TCV 3266 BBL, TSV 3475, TOTAL PROPPANT PLACED 203,549 LB,STAGE 5 START TIME 15:30, STAGE END TIME 17:15, DROPPED BALL 2.217" MEASURED, BALL ON SEAT 13 BBL EARLY @ 3723 BBL JSV, INITIAL DIFFERENTIAL PSI 5499 NO SHIFT, BLED OFF AND PRESSURED UP 12 TIMES, THE SLEEVE SHIFTED WITH A DIFFERENTIAL OF 4653 PSI, CONTINUED WITH STAGE 5 TCV 3538 BBL, TOTAL JSV 3746 BBL, TOTAL PROPPANT PLACED 202,553 LB
Page 2/2Procedure Closeout3S-624Start Date ZX Code Time Log Hrs (hr)Cum Time Log (days)Last 24hr Sum2/17/2024 ZX02 Fracturing 23.99 10.00 COMPLETED STAGES 6-9 STAGE 6 LANDED BALL 2.250" MEASURED GOOD SEAT AND SHIFT 6 BBL EARLY STAGE COMPLETED AS DESIGNED TOTAL CLEAN 3028 BBL, TOTAL PROPPANT 201,597 LBSTAGE 7 BALL 2.283" MEASURED GOOD SEAT/SHIFT 9 BBL EARLY, STAGE COMPLETED AS DESIGNED, TOTAL CLEAN 2875 BBL, TOTAL PROPPANT 206,013 LBSTAGE 8 BALL 2.317" MEASURED GOOD SEAT/SHIFT, 8 BBL EARLY STAGE COMPLETED AS DESIGNED, TOTAL CLEAN 2070 BBL, TOTAL PROPPANT 204,363 LB. STAGE 9 BALL 2.350" MEASURED GOOD SEAT/SHIFT 9 BBL EARLY, STAGE COMPLETED AS DESIGNED, TOTAL CLEAN 1698BBL, TOTAL PROPPANT 203,683 LB. LRS CAPPED WITH DIESEL 35 BBL2/18/2024 ZX02 Fracturing 23.99 11.00 COMPLETED STAGES 10-14, STAGE 10 LANGED BALL 2.385" GOOD SEAT/SHIFT @224 BBL JSV 5 BBL EARLY TOTAL JSV 2313 BBL TOTAL PROPPANT 201,603 LB AVG RATE 34.3 BBL, AVG PSI SURFACE 2,946, AVG PSI BH 4469, AVG HHP 2472STAGE 11 BALL 2.421" GOOD SEAT/SHIFT @ 2313 JSV 5 BBL EARLY, TOTAL JSV 1859 BBL TOTAL PROPPANT 204,107 LB, AVG RATE 37, AVG PSI SURFACE 3,152, AVG PSI BH 4677, AVG HHP 2,667STAGE 12 BALL 2.456" GOOD SEAT/SHIFT @ 4172 JSV 5 BBL EARLY, TOTAL JSV 1850 BBL, TOTAL PROPPANT 206,948 LB, AVG RATE 34 BPM, AVG PSI SURFACE 3,349, AVG PSI BH 4874, AVG HHP 2,809BALL 13 2.491" GOOD SEAT/SHIFT @ 6022 JSV. 4 BBL EARLY, TOTAL JSV 1813 BBL, TOTAL PROPPANT 203,031 LB, AVG RATE 31, AVG PSI SURFACE 2,755, ANG PSI BH 4,356, AVG HHP 2,084STAGE 14 BALL 2.527" GOOD SEAT/SHIFT 10 BBL EARLY, TOTAL JSV 1,643 BBL, TOTAL PROPPANT 204,836 LB, AVG RATE 32.9, AVG PSI SURFACE 3,549, AVG PSI BH 5,064, AVG HHP 2,8532/19/2024 ZX03 General Pumping (Load Well / Freeze Protect /3.00 11.12 FREEZE PROTECT TBG WITH 35 BBLS DSL AFTER E-LINE RDMO, TBG FP'D READY FOR FRAC2/20/2024 ZX02 Fracturing 21.99 12.04 COMPLETED STAGES 15-22. STAGE 15 BALL 2.561" GOOD SEAT/SHIFT RESPONCE@205 BBL JSV 8 BBL EARLY, TOTAL JSV 2612 BBL TOTAL PROPPANT PLACED 199,197 LB., AVG RATE 31.8 BPM, AVG PSI SURFACE 2648, AVG PSI BH 4195 AVG HHP 2122.STGE 16 BALL 2.598" GOOD SEAT/SHIFT RESPONCE@2612BBL JSV 4 BBL EARLY, TOTAL JSV 1773 BBL TOTAL PROPPANT PLACED 202,553 LB., AVG RATE 53.3 BPM, AVG PSI SURFACE 2763, AVG PSI BH 4327 AVG HHP 2441STAGE 17, BALL 2.635" GOOD SEAT/SHIFT RESPONCE@ 4385 BBL JSV 8 BBL EARLY, TOTAL JSV 1355 BBL TOTAL PROPPANT PLACED 135862 LB., AVG RATE 34.8 BPM, AVG PSI SURFACE 2251, AVG PSI BH 3768 AVG HHP 1966STAGE 18 BALL 2.672" GOOD SEAT/SHIFT RESPONCE@205 BBL JSV 6 BBL EARLY, TOTAL JSV 1240 BBL TOTAL PROPPANT PLACED 132442 LB., AVG RATE 33.5 BPM, AVG PSI SURFACE 2424, AVG PSI BH 3990 AVG HHP 2039STAGE 19 BALL 2.710" GOOD SEAT/SHIFT RESPONCE@6980 BBL JSV 3 BBL EARLY, TOTAL JSV 1250 BBL TOTAL PROPPANT PLACED 133026 LB., AVG RATE 34.3 BPM, AVG PSI SURFACE 2457, AVG PSI BH 4011 AVG HHP 2115STAGE 20 BALL 2.749" GOOD SEAT/SHIFT RESPONCE@8230 BBL JSV 1 BBL EARLY, PUMPED MINI FRAC, DURING PUMPING HAD A LEAK ON THE TREATING LINE ON A CHICKSAN WEEP HOLE, SWAPPED CHICKSAN , AND COUGHT UP ON WATER TO COMPLETE THE DAYS FRAC PLANS DURING THE MINI FRAC CLOSURE, TOTAL JSV 1827 BBL TOTAL PROPPANT PLACED 136428 LB., AVG RATE 30.2 BPM, AVG PSI SURFACE 1845, AVG PSI BH 3364 AVG HHP 1402.STAGE 21 BALL 2.787" GOOD SEAT/SHIFT RESPONCE@10157 BBL JSV 3 BBL EARLY, TOTAL JSV 1099 BBL TOTAL PROPPANT PLACED 130231 LB., AVG RATE 31.7 BPM, AVG PSI SURFACE 2175, AVG PSI BH 3764 AVG HHP 1710.STAGE 22 COLLET 168 GOOD SEAT/SHIFT RESPONCE@205 BBL JSV 8 BBL EARLY, TOTAL JSV 1248 BBL TOTAL PROPPANT PLACED 133045 LB., AVG RATE 36.6 BPM, AVG PSI SURFACE 2073, AVG PSI BH 3641 AVG HHP 1898.COLLET #166 DROPPED PUMPED NO SIGNATURE, DROPPED 2ND BALL NO SIGNATURE,LRS PUMPED 35 BBL FREEZE PROTECT2/21/2024 ZX02 Fracturing 23.99 13.04 WEATHER HOLD2/22/2024 ZX02 Fracturing 18.00 13.79 RIG DOWN ALL FRAC EQUIPMENT FROM WELLHEAD. FRAC COMPLETE. READY FOR SLICKLINE
Hydraulic Fracturing Fluid Product Component Information Disclosure
Job Start Date: 02/12/2024
Job End Date: 02/20/2024
State: Alaska
County: Harrison Bay
API Number: 50-103-20868-00-00
Operator Name:ConocoPhillips
Company/Burlington Resources
Well Name and Number: 3S-624
Latitude: 70.39403
Longitude: -150.198416
Datum: NAD83
Federal Well: NO
Indian Well: NO
True Vertical Depth: 5263
Total Base Water Volume (gal)*: 1933316
Total Base Non Water Volume: 0
Water Source Percent
Other, > 1000TDS 100.00%
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)**
Comments
A 1-25 Patina
Energy Tracer
BE-6(TM)
Bactericide Halliburton Microbiocide
Ceramic Proppant -
Wanli Wanli Proppant
CL-28M
CROSSLINKER Halliburton Crosslinker
Flow Insurance
Copper
Patina
Energy Tracer
LoSurf-300D Halliburton
Non-ionic
Surfactant
MO-67 Halliburton pH Control
OPTIFLO-II
DELAYED
RELEASE
BREAKER
Halliburton Breaker
OPTIFLO-III
DELAYED
Halliburton Breaker
RELEASE
BREAKER
SAND, COMMON
BROWN 100
MESH
Halliburton Proppant
WG-36 GELLING
AGENT Halliburton Gelling
Agent
Items above are Trade Names. Items below are the individual ingredients.
Water 7732-18-5 100.00000 79.74000
Corundum 1302-74-5 65.00000 12.55645
Mullite 1302-93-8 45.00000 8.69293
Sodium chloride 7647-14-5 5.00000 3.97962
Crystalline silica,
quartz 14808-60-7 100.00000 0.48080
Guar gum 9000-30-0 100.00000 0.28064
Borate Salts Proprietary 60.00000 0.12004
Ethanol 64-17-5 60.00000 0.04755
Ammonium persulfate 7727-54-0 100.00000 0.02854
Heavy aromatic
petroleum naphtha 64742-94-5 30.00000 0.02377
Oxyalkylated nonyl
phenolic resin Proprietary 30.00000 0.02377
Potassium chloride 7447-40-7 5.00000 0.01000
Inorganic mineral 1317-65-3 5.00000 0.01000
Sodium hydroxide 1310-73-2 30.00000 0.00990
Oxylated phenolic
resin Proprietary 30.00000 0.00856
Oxyalkylated
phenolic resin Proprietary 10.00000 0.00792
Poly(oxy-1,2-
ethanediyl), alpha-(4-
nonylphenyl)-omega-
hydroxy-, branched
127087-87-0 5.00000 0.00396
Naphthalene 91-20-3 5.00000 0.00396
Calcium magnesium
carbonate 16389-88-1 1.00000 0.00200
Polymer Proprietary 1.00000 0.00200
Glutaraldehyde 111-30-8 1.00000 0.00200
Inorganic mineral Proprietary 1.00000 0.00200
2-Bromo-2-
nitropropane-1,3-diol 52-51-7 100.00000 0.00136
1,2,4
Trimethylbenzene 95-63-6 1.00000 0.00079
Sodium bisulfate 7681-38-1 0.10000 0.00020
Methanesulfonic acid,
1-hydroxy-sodium
salt
870-72-4 0.10000 0.00020
C.I. pigment Orange 5 3468-63-1 1.00000 0.00007
A 1-25 Proprietary 20.00000 0.00005
Magnesium chloride 7786-30-3 0.01000 0.00002
2-Methyl-4-
isothiazolin-3-one 2682-20-4 0.01000 0.00002
Magnesium nitrate 10377-60-3 0.01000 0.00002
* Total Water Volume sources may include various types of water including fresh water, produced water, and recycled water
** Information is based on the maximum potential for concentration and thus the total may be over 100%
Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided.
Ingredient information for chemicals subject to 29 CFR 1910.1200(i) and Appendix D are obtained from suppliers Material Safety Data Sheets
(MSDS)
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: 24.3 BF:
Total Depth: 1956' FNL, 1136 FEL, Sec 35, T13N, R7E, UM 10. Plug Back Depth MD/TVD: 18. Property Designation:
4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number:
Surface: x- y- Zone- 4
TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD:
Total Depth: x- y- Zone- 4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 N/A (ft MSL)
22. Logs Obtained:
23.
BOTTOM
20" H-40 155'
10 3/4" L-80 2555'
7 5/8" L-80 5128'
4 1/2" P110S 5158'
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
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
ConocoPhillips Alaska, Inc.
WAG
Gas
1/23/2024 223-104
50-103-20868-00-00
KRU 3S-624
ADL 380107, ADL 380106,
ADL 025528, ADL 393883
LONS 01-013
12/12/2023
20,485' MD/5,156'TVD
N/A
63.3
P.O. Box 100360 Anchorage, AK 99510-0360
475999 5993853
1540' FSL, 4321' FEL, Sec. 7, T12N, R8E, UM
1/2/20242563' FNL, 1261' FEL, Sec 12, T12N, R8E, UM
5997966
1780'MD/1709'TVD
SETTING DEPTH TVD
6010321
TOP HOLE SIZE AMOUNT
PULLED
472936
469796
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
9.875"
40'
40'
29.7
19685'
37'
12.6
40'
6603'
3049'
6.5"
222 bbls of 15.3 ppg Class G
94
45.5
155'
37' 7581'
SIZE
42"
DEPTH SET (MD)If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date perf'd or liner run):
TUBING RECORD
6610'4.5"
4661'
13.5"
10 yards
40'
Lead: 477 bbls of 10.7 ppg Class G
Tail: 56 bbls of 15.8ppg Class G
Liner ran 1/16/2024 @ 6,603'MD/4661' TVD to 19,685'MD/5,158'TVD
Gas-Oil Ratio:Choke Size:
Per 20 AAC 25.283 (i)(2) attach electronic information
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
Flow Tubing
Sr Res EngSr Pet GeoSr Pet Eng
N/A
Oil-Bbl: Water-Bbl:
6368'MD/4521' TVD
6603'MD/4662' TVD
GR, RES, PWD, DIR, AZI, DEN, NEU, POR, SONIC
Water-Bbl:
PRODUCTION TEST
N/A
Date of Test: Oil-Bbl:
PACKER SET (MD/TVD)
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
By Grace Christianson at 11:55 am, Feb 23, 2024
Completed
1/23/2024
JSB
RBDMS JSB 030624
GDSR-3/11/24
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
Surface Surface
1387 1358
Ugnu B 1688 1629
1780 1709
Top Ugnu A 1809 1734
2170 2020
2830 2430
3132 2603
4489 3399
C-35 5315 3893
Top Coyote 5649 4092
Base Coyote 6456 4574
7690 5157
20485 5156
(Torok)
31. List of Attachments:
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Digital Signature with Date:
Contact Phone:907-265-6926
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:
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
C-80
Permafrost - Base
C-50
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.
Top West Sak
Base West Sak
Formation Name at TD:
TPI (Top of Producing Interval).
Authorized Name and
INSTRUCTIONS
Top of Productive Interval
(Torok)
Authorized Title: Drilling Engineer
Direction Survey, Operations Summary, Cementing Summary, Well Schematic
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.
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
Contact Name: Shane McCracken
Contact Email:shane.m.mccracken@cop.com
Page 1 of 1
2/19/2024file:///C:/Users/jennalt/Downloads/3S-624%20Schematic_As_Drilled.vsdx
Page 1/41
3S-624
Report Printed: 2/12/2024
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)
12/10/2023
00:00
12/10/2023
03:00
3.00 MIRU, MOVE RURD P Rig move. Hang pipe skate rail with
tuggers. Blow down steam loop. Secure
landings. Clean up cellar area. Move
cutting boxes. Unplug smoke shack.
Raise pipe shed loading arms. Jack up
rock washer. Switch to cold start power
@ 01:00 hrs. Work on unplugging
interconnects.
0.0 0.0
12/10/2023
03:00
12/10/2023
06:00
3.00 MIRU, MOVE MOB P PJSM with NES rig movers. Move and
stage rockwasher. Jack up and move
pipe shed and stage. Jack up and move
motor complex. Jack up and move
pump room complex. Loader operations
- picking up and stacking rig mats. Rig
up tow hitch to drilling sub.
0.0 0.0
12/10/2023
06:00
12/10/2023
09:00
3.00 MIRU, MOVE MOB P PJSM. Move pit complex. Skid rig floor.
Raise and secure sub stompers.
Conduct final inspection on sub before
moving. Raise rear sub door and
secure.
0.0 0.0
12/10/2023
09:00
12/10/2023
12:00
3.00 MIRU, MOVE MOB P Jack up sub and move off 3S-617 well.
Remove rig mats off well 3S-617. Fuel
cold starts. Set BOP riser and Frac tree
in cellar on 3S-624 well. Orientate sub
to move to 3S-624.
0.0 0.0
12/10/2023
12:00
12/10/2023
15:00
3.00 MIRU, MOVE MOB P Continue to orient sub to back over well
3S-624. Set rig mat layout and
transitions for substructure. Back sub
onto mats and spot level sub over well
3S-624 center.
0.0 0.0
12/10/2023
15:00
12/10/2023
18:00
3.00 MIRU, MOVE MOB P Lower sub stompers. Lower rear sub
doors. Skid rig floor. Remove sub tow
hitch. Set mats for pits. Spot pit module.
0.0 0.0
12/10/2023
18:00
12/11/2023
00:00
6.00 MIRU, MOVE MOB P Set mats and spot pump module. Spot
motor complex. Spot pipeshed. Lower
stairs and landings around modules and
secure. Clean around 3S-617 well area.
Utilize manlift and hang driller side
wheel curtain. Install tubing gauge on
top of frac tree for 3S-617 well.
0.0 0.0
12/11/2023
00:00
12/11/2023
00:30
0.50 MIRU, MOVE MOB P Spread herculite, spot
rockwasher/cuttings box, release NES
trucks @ 00:30hrs
0.0 0.0
12/11/2023
00:30
12/11/2023
06:00
5.50 MIRU, MOVE RURD P Spot Magtec unit, rig electrician begin
plugging in the electrical interconnect,
motor man bringing steam online/ water,
air, hydraulic lines between complexes,
pit watcher rig up mud pits interconnect,
floorhand rig up mud, choke, kill, cement
lines through rig floor to mezz, tool
house hands laying herculite, building
containment and setting up the tank
farm, derrick hand hooking up mud
lines, lower skate rail and string up
sheaves, function test drawworks/ top
drive, switched from cold start power to
generator power @ 04:00
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 2/41
3S-624
Report Printed: 2/12/2024
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)
12/11/2023
06:00
12/11/2023
09:00
3.00 MIRU, MOVE RURD P PJSM- continue pre rig acceptance
checklist- air up flowline air boots finish
pit inter connect, steam to sub,
weatherization of cellar doors & wind
walls, rig up cellar pump, plug drains on
centrifugal pumps, hammer up mud
pump fast caps fill rod wash check gear
oil verify line ups, lower stair landings on
pump & pits complex, function test
skate, install mousehole, set rig mats for
mag tec, eliminate gaps in rig mats with
ply wood, anchor Geronimo line,
function test rock washer auger & ESD
& shaker, function test pits shakers,
drag chain & ESD, install & function test
cellar alarms. Simops- tool house
setting up tank farm.
0.0 0.0
12/11/2023
09:00
12/11/2023
12:00
3.00 MIRU, MOVE RURD P Continue, pre rig acceptance check list-
spot cement silo, house keeping around
rig, verify all clear egresses, spread
bags of traction material on outside
egresses, construct containment for
transfer lines tank farm to rig rock wash
& cattle chute of skate, install rig floor
drain hoses to cellar, vac out pump
room containment, Take on spud mud.
0.0 0.0
12/11/2023
12:00
12/11/2023
15:00
3.00 MIRU, MOVE RURD P Plug in Magtec power disconnect, shim
top drive gripper for short saver sub,
swap floor handling tools to 5" elevators
floor valves slips, make up riser to
conductor, Conduct Derrick & Top drive
inspection, Swap to hi line 14:00 hrs
0.0 0.0
12/11/2023
15:00
12/11/2023
18:00
3.00 MIRU, MOVE SVRG P Plug in tank farm transfer house, install
upper riser from rig floor to conductor
riser, chain falls on riser, c/o standpipe
4" high pressure Demco valve, mobilize
small bha tools to rig floor, calibrate pit
sensors // Simops/ steam heater core on
rig floor, change out high-pressure
valves on pressure test manifold, tally 5"
Hwdp move to short side of shed
0.0 0.0
12/11/2023
18:00
12/11/2023
21:30
3.50 MIRU, MOVE SVRG P Continue to assemble high pressure
standpipe Demo valve, begin
processing surface casing, build sweep
in mud pits/ stock mud products,
mobilize bha to rig floor, adjust surface
riser
0.0 0.0
12/11/2023
21:30
12/11/2023
23:00
1.50 MIRU, MOVE BHAH P Pick up make up clean out BHA, make
up stands of Hwdp needed for cleanout
run, continue processing surface casing
and 5” drill pipe in pipe shed.
0.0 0.0
12/11/2023
23:00
12/12/2023
00:00
1.00 MIRU, MOVE BHAH P Hold pre spud meeting with all parties,
decision made to make up and rack
back surface heavy weight and jar
stand, continue processing 5” drill pipe
and 10 ¾” casing in shed.
0.0 0.0
12/12/2023
00:00
12/12/2023
02:45
2.75 MIRU, MOVE RURD P Pick up Hwdp and jars stand and rack
back with single joint elevators, while
process 5''drill pipe and 10 ¾” casing in
pipe shed. Test mud lines with air (no
leaks observed)
0.0 0.0
12/12/2023
02:45
12/12/2023
03:30
0.75 MIRU, MOVE WASH P Fill conductor checking for leaks, wash
down staging up pumps with 500 GPM,
RPM 15, tagged up at 115'. Continue
processing 5'' drill pipe and 10 3/4''
casing in pipe shed.
0.0 115.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 3/41
3S-624
Report Printed: 2/12/2024
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)
12/12/2023
03:30
12/12/2023
05:15
1.75 MIRU, MOVE PRTS P Attempt to pressure test mudlines to
4000 psi, observe leak tighten bolts and
fixed leak. Pressure test 4000 psi
(GOOD TEST) Continue processing 5''
DP AND 10 3/4'' casing in pipe shed.
115.0 115.0
12/12/2023
05:15
12/12/2023
06:00
0.75 SURFAC, DRILL DDRL P Drill 13 ½” Surface hole from 115‘ MD -
to 225‘ MD, WOB = 3, GPM = 400, PSI
= 435, RPM = 40, TQ ON = 4, TQ OFF
= 3, F/O = 25% (Jets on), P/U= 52 K,
S/O = 50K
115.0 225.0
12/12/2023
06:00
12/12/2023
06:30
0.50 SURFAC, DRILL TRIP P POOH from 225' to 134' POOH @
15'/minute rack back in derrick.
225.0 134.0
12/12/2023
06:30
12/12/2023
11:00
4.50 SURFAC, DRILL BHAH P Pick up Gyro, Arc vision, Trulock, x/o, 9
3/4 stabilizer, 2x Nmdc, spin up all smart
tools with chain tongs, make up jars to
bottom of double & rack back in derrick.
134.0 225.0
12/12/2023
11:00
12/12/2023
11:30
0.50 SURFAC, DRILL SRVY P Break circ, shut down pumps and take
1st Gyro survey GPM=450 RPM= 0
225.0 225.0
12/12/2023
11:30
12/12/2023
12:00
0.50 SURFAC, DRILL DDRL P Drill 13 ½” Surface hole from 225‘ MD –
to 275‘ MD 275‘ TVD, WOB = 4, GPM
=450, PSI =640, RPM =40, TQ ON
=1.5K, TQ OFF =1.2, F/O=22%, ECD
=10.6 PPG, P/U = 68K, S/O =70K, RT
WT = 64K, AST=0, ART =1.08, ADT
=1.08, Total bit hrs =1.08, Total jars
=1.08
225.0 275.0
12/12/2023
12:00
12/12/2023
18:00
6.00 SURFAC, DRILL DDRL P Drill 13 ½” Surface Hole from 275‘ MD -
to 744‘ MD 592‘ TVD, WOB = , GPM =
450, PSI = 831, RPM = 40, TQ ON = 2,
TQ OFF = 1, F/O = 22%, ECD = 10.33
PPG, P/U = 76K, S/O= 82K, RT = 77K,
AST= 1.45, ART = 1.67, ADT = 3.12,
Total bit hrs = 4.2, Total jars = 0
275.0 744.0
12/12/2023
18:00
12/13/2023
00:00
6.00 SURFAC, DRILL DDRL P Drill 13 ½” Surface hole from 744‘ MD –
to 1,213‘ MD 1140‘ TVD, WOB = 5,
GPM = 450, PSI = 1060, RPM = 40, TQ
= 5, F/O = 22%, ECD = 10.58 PPG,
P/U= 92K, S/O= 99K, RT = 96K, AST=
1.21, ART = 2.02, ADT = 3.23, Total bit
hrs = 7.43, Total jars= 3.23
744.0 1,213.0
12/13/2023
00:00
12/13/2023
06:00
6.00 SURFAC, DRILL DDRL P Drill 13 ½” Surface hole from 1213‘ MD
– to 1685‘ MD 1600‘ TVD, WOB = 3,
GPM = 450, PSI = 1015, RPM = 40, TQ
= 5, F/O = 23%, ECD = 9.92 PPG,
P/U= 105K, S/O= 104K, RT = 103K,
AST= 2.21, ART = 1.85, ADT = 4.06,
Total bit hrs = 11.49, Total jars= 7.29
Pumped 30 bbls LCM sweep at 1530'
MD
1,213.0 1,685.0
12/13/2023
06:00
12/13/2023
12:00
6.00 SURFAC, DRILL DDRL P Drill 13 ½” Surface hole from 1685‘ MD
– to 2156‘ MD 1920‘ TVD, WOB = 4,
GPM =600, PSI = 1650, RPM = 40, TQ
= 5, F/O = 24%, ECD = 10.41 PPG,
P/U= 115K, S/O= 106K, RT = 109K,
AST= 2.52, ART = 1.23, ADT = 3.75,
Total bit hrs = 15.24, Total jars= 11.04
1,685.0 2,156.0
12/13/2023
12:00
12/13/2023
18:00
6.00 SURFAC, DRILL DDRL P Drill 13 ½” Surface hole from 2156‘ MD
– to 2660‘ MD ‘ TVD, WOB = 8,5 GPM =
665, PSI = 2170, RPM = 40, TQ = 6.5,
F/O = 25%, ECD = 11. PPG, P/U= 114K,
S/O= 104K, RT =107K, AST= 1.70, ART
= 2.58, ADT = 4.28, Total bit hrs = 19.52,
Total jars= 15.32 Pumped 30 bbl bit
balling sweep @ 2565' MD
2,156.0 2,660.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 4/41
3S-624
Report Printed: 2/12/2024
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)
12/13/2023
18:00
12/13/2023
22:30
4.50 SURFAC, DRILL DDRL P Drill 13 ½” Surface hole from 2660‘ MD
– to 3056‘ MD 2517‘ TVD, WOB = 8
GPM = 660, PSI = 2209, RPM = 40, TQ
= 7, F/O = 26%, ECD = 11.28 PPG,
P/U= 114K, S/O= 104K, RT = 107K,
AST= .72, ART = 1.93, ADT = 2.65, Total
bit hrs = 22.17, Total jars= 17.97. @ TD
obtain last surveys and Torque and drag
values.
2,660.0 3,056.0
12/13/2023
22:30
12/14/2023
00:00
1.50 SURFAC, TRIPCAS CIRC P From 3056' to 3016' MD Pump 30 bbls
nut plug sweep. Circulate hole clean,2x
BU, Rack 1 stand back after each
bottoms up. Observe increase in cutting
coming over shaker pumped 30 bbls
LCM sweep and circulate bottoms up.
GPM 668, PSI 2127, RT 107K, RPM 40,
F/O 28% ECD 10.76 Total strokes
pumped 13862
3,056.0 3,016.0
12/14/2023
00:00
12/14/2023
00:15
0.25 SURFAC, TRIPCAS OWFF P OWFF (Well Static) 3,016.0 3,016.0
12/14/2023
00:15
12/14/2023
05:15
5.00 SURFAC, TRIPCAS BKRM P BROOH from 3016' MD to 2100' MD.
GPM 670, PSI 1898, RPM 40, TQ 6k,
F/O 28%, ECD 10.68 ppg, P/U 107k,
S/O 105k, RT 110k
3,016.0 2,100.0
12/14/2023
05:15
12/14/2023
07:30
2.25 SURFAC, TRIPCAS BKRM P BROOH 2100' MD to 1780' MD circulate
and condition for 3x bottoms up and
racking stand back on each bottoms up.
GPM 660, PSi 1875, RPM 40, TQ 7k,
F/O 26% ECD 10.66, Total strokes
pumped 6100.
2,100.0 1,780.0
12/14/2023
07:30
12/14/2023
10:00
2.50 SURFAC, TRIPCAS TRIP P POOH on elevators from 1780' MD to
1219' , (Orientate high side) observe for
swabbing, P/U 108k overpull of 30k
encountered @ 1219', TIH to 1500' MD
1,780.0 1,500.0
12/14/2023
10:00
12/14/2023
14:00
4.00 SURFAC, TRIPCAS PMPO T Pump out hole from1500' MD to 1215'
MD, stage pumps up from GPM 380,
PSI 820, to GPM 550 PSI 1240, Well
unloaded packing off flow box, work
string and manipulate jet lines to clear
obstructions in flow box. Break
circulation with mud pumps periodically
1,500.0 1,215.0
12/14/2023
14:00
12/14/2023
15:00
1.00 SURFAC, TRIPCAS PMPO T Pump out hole orientated high side,
from 1215' MD to 1035' MD, GPM 300-
400, PSI 1015, F/O 23%,, P/U 105k,
S/O 85k, Losses observe at GPM 400,
Decreased pump rate to GPM 300.
Pumped 30 bbl LCM sweep.
1,215.0 1,035.0
12/14/2023
15:00
12/14/2023
18:00
3.00 SURFAC, TRIPCAS CIRC T Circulate and reciprocate from 1035' MD
to 1000' MD, GPM 42, PSI, F/O 1%, P/U
94k, S/O 87k. Minimal returns observe,
Pump 30 bbl-40 ppb LCM sweep, Build
75 bbl- 40 ppb, LCM sweep and ready it
to be pumped.
1,035.0 1,000.0
12/14/2023
18:00
12/14/2023
19:45
1.75 SURFAC, TRIPCAS CIRC T Circulate and reciprocate from 1035' MD
to 1000' MD, GPM 42, PSI, F/O 1%, P/U
94k, S/O 87k. Minimal returns observe,
Build 75 bbl- 40 ppb, LCM sweep and
ready it to be pumped.
1,035.0 1,000.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 5/41
3S-624
Report Printed: 2/12/2024
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)
12/14/2023
19:45
12/14/2023
21:45
2.00 SURFAC, TRIPCAS BKRM T BROOH from 1000' MD to 933' MD
Stage pumps rates. GPM 250-600, PSI
346-1342, RPM 20, TQ 2k, F/O 22%,
ECD 9.16ppg, P/U 90k, S/O 88k, RT
95k. Pump 35 bbls 40 ppb LCM sweep
circulate over loss zone. returns are
normal over shakers. Work through
obstruction @ 980' started getting
increase of cutting across shakers.
Allow returns to clean up over shakers.
1,000.0 933.0
12/14/2023
21:45
12/14/2023
22:45
1.00 SURFAC, TRIPCAS WASH T Wash and ream down from 933' MD to
1212' MD with 2x stands from derrick,
GPM 600, PSI 1382, RPM 20, TQ 2k,
F/O 22%, ECD 9.16, P/U 90k, S/O 88K
RT 95k.
933.0 1,212.0
12/14/2023
22:45
12/15/2023
00:00
1.25 SURFAC, TRIPCAS BKRM P BROOH from 1212' MD to 1055' MD
GPM 600, PSI 1342, RPM 30, TQ 3k,
F/O 22% ECD 10.84 ppg, P/U 87, S/O
86k, RT 91K
1,212.0 1,055.0
12/15/2023
00:00
12/15/2023
06:00
6.00 SURFAC, TRIPCAS BKRM P BROOH from 1055' MD to 360' MD
GPM 600, PSI 1116, RPM 35, TQ 3k,
F/O 24%, ECD 11.01 ppg, RT 65k.
1,055.0 360.0
12/15/2023
06:00
12/15/2023
08:15
2.25 SURFAC, TRIPCAS BKRM P BROOH from 360' MD to 180' MD GPM
600, PSI 990, RPM 35, TQ 1k, F/O
23%, ECD 11.4 ppg, RT 61k. Pump BHA
scoring sweep on last stand of heavy
weight drill pipe.
360.0 180.0
12/15/2023
08:15
12/15/2023
08:30
0.25 SURFAC, TRIPCAS OWFF P OWFF, Hold PJSM on laying down
surface BHA .
180.0 180.0
12/15/2023
08:30
12/15/2023
11:00
2.50 SURFAC, TRIPCAS BHAH P Lay down surface BHA monitoring
displacement via pit #1
180.0 0.0
12/15/2023
11:00
12/15/2023
12:00
1.00 SURFAC, TRIPCAS CLEN P Clean and clear rig floor, Rig up to run
10 3/4" 45.5# L-80 Hyd563 surface
casing. SIMOPS prepare pits for running
casing and cement job.
0.0 0.0
12/15/2023
12:00
12/15/2023
14:00
2.00 SURFAC, CASING RURD P Continue to rig up casing handling tools
as per DDI casing crew, mobilize
handling equipment to rig floor, Prepare
pits to run 10 3/4" surface casing.
0.0 0.0
12/15/2023
14:00
12/15/2023
16:15
2.25 SURFAC, CASING PUTB P PJSM pickup and makeup 10 3/4" 45.5#
L-80 Hyd563 surface casing shoe track
and float collar, as per detail, from 0 to
160' MD Bakerlok first 4 joints, Break
circulation and circulate through floats.
Floats are good.
0.0 160.0
12/15/2023
16:15
12/15/2023
18:00
1.75 SURFAC, CASING PUTB P Pickup and run 10 3/4" 45.5# L-80
Hyd563 surface casing as per detail,
from 160' MD to 644' MD with Volant
CRT, torque each connection to 16.2k
double bumping each connection. Fill
pipe on the fly and top off every 10 joints
ran. Monitoring displacement via pit #1
and Pill pit #1
160.0 644.0
12/15/2023
18:00
12/15/2023
19:00
1.00 SURFAC, CASING PUTB P Pickup and run 10 3/4" 45.5# L-80
Hyd563 surface casing as per detail,
from 644' MD to 929' MD with Volant
CRT, torque each connection to 16.2k,
double bumping each connection. Fill
pipe on the fly and top off every 10
joints. Monitoring displacement via pit
#1 and Pill pit #1
644.0 929.0
12/15/2023
19:00
12/15/2023
19:15
0.25 SURFAC, CASING CIRC P Circulate and condition mud with 1-3
bpm, 66-111 psi, 637 stroke total
pumped.
929.0 929.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 6/41
3S-624
Report Printed: 2/12/2024
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)
12/15/2023
19:15
12/15/2023
21:00
1.75 SURFAC, CASING PUTB P Pickup and run 10 3/4" 45.5# L-80
Hyd563 surface casing as per detail,
from 929' MD to 1715' MD with Volant
CRT, torque each connection to 16.2k,
double bumping each connection. Fill
pipe on the fly and top off every 10
joints. Monitoring displacement via pit
#1 and Pill pit #1 Note @ 1715' MD
observe loss of 12k, P/U 116k S/O 76k,
Prepare to circulate.
929.0 1,715.0
12/15/2023
21:00
12/15/2023
23:00
2.00 SURFAC, CASING WASH P Wash Down and stage pumps up from
1715' MD to 1789' MD, BPM 0.5 -4, PSI
214- 254, pumped 2232 strokes total,
Circulate bottoms up with 4 BPM PSI
234.
1,715.0 1,789.0
12/15/2023
23:00
12/16/2023
00:00
1.00 SURFAC, CASING PUTB P Pickup and run 10 3/4" 45.5# L-80
Hyd563 surface casing as per detail,
from 1789' MD to 2012' MD with Volant
CRT, torque each connection to 16.2k,
double bumping each connection. P/U
82k S/O 82K Fill pipe on the fly and top
off every 10 joints. Monitoring
displacement via pit #1 and Pill pit #1
1,789.0 2,012.0
12/16/2023
00:00
12/16/2023
01:30
1.50 SURFAC, CASING PUTB P Pickup and run 10 3/4" 45.5# L-80
Hyd563 surface casing as per detail,
from 2012' MD to 2360' MD with Volant
CRT, torque each connection to 16.2k,
double bumping each connection. P/U
82k S/O 82K Fill pipe on the fly and top
off every 10 joints. Monitoring
displacement via pit #1 and Pill pit #1
2,012.0 2,360.0
12/16/2023
01:30
12/16/2023
02:15
0.75 SURFAC, CASING WASH P Wash Down and stage pumps up from
2360' MD to 2401' MD, P/U 146k, S/O
93k, F/O 8%, BPM 0.5 -4, PSI 214-
254, Circulate bottoms up.
2,360.0 2,401.0
12/16/2023
02:15
12/16/2023
03:15
1.00 SURFAC, CASING PUTB P Pickup and run 10 3/4" 45.5# L-80
Hyd563 surface casing as per detail,
from 2401' MD to 2605' MD with Volant
CRT, torque each connection to 16.2k,
double bumping each connection. P/U
82k S/O 82K Fill pipe on the fly and top
off every 10 joints. Monitoring
displacement via pit #1 and Pill pit #1
2,401.0 2,605.0
12/16/2023
03:15
12/16/2023
05:30
2.25 SURFAC, CASING HOSO P Wash Down and stage pumps up from
2605' MD to 3006' MD, BPM 0.5 -4, PSI
214- 254, pumped 3682 strokes.
2,605.0 3,006.0
12/16/2023
05:30
12/16/2023
08:30
3.00 SURFAC, CASING HOSO P Make up 10 3/4" casing hanger assy.
and RIH from 3006' MD to 3051' MD to
landing ring profile, and wash at BPM 4,
PSI 243, P/U 172k, S/O 101.
3,006.0 3,051.0
12/16/2023
08:30
12/16/2023
10:15
1.75 SURFAC, CASING HOSO P Unable to land hanger due to hole fill,
Confirm drill pipe and casing tally are
correct. Decision made lay down joint
#47 (40.70') replaced with 37.95' joint.
3,051.0 3,006.0
12/16/2023
10:15
12/16/2023
10:45
0.50 SURFAC, CASING HOSO T Lay down landing joint and hanger assy,
Swap out casing joints, Pickup hanger
assy and landing joint as per Cameron
and DDI casing Rep.
3,006.0 3,006.0
12/16/2023
10:45
12/16/2023
11:15
0.50 SURFAC, CASING HOSO T Wash down from 3006' MD, land out
hanger @ 3047.30' while staging up
pumps from 1 bpm 148 psi, 2 bpm 160
psi, 3 bpm 187 psi, 4 bpm 201 psi, 5
bpm 206 psi, 6 bpm 223 psi.
3,006.0 3,047.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 7/41
3S-624
Report Printed: 2/12/2024
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)
12/16/2023
11:15
12/16/2023
14:30
3.25 SURFAC, CEMENT CIRC P Circulate and condition mud for cement
job @ 6 bpm 233 psi. Simops, Clean up
casing equipment, blow down cement
line verify cement manifold is ready for
cement job. Stage cement retardant.
offload pit and black water pill to return
trucks.
3,047.0 3,047.0
12/16/2023
14:30
12/16/2023
19:00
4.50 SURFAC, CEMENT CMNT P Pump 5 bbls fresh water. Test lines to
3500 psi. Pump 54 bbls of spacer w/
poly flake and red dye @ 3.8 BPM, PSI
= 230. F/O - 5%. Load bottom plug.
(Cmt Wet @ 15:30hrs) Batch up and
pump 476 BBLS 10.7 PPG ArticCem
lead cement w/ BMII - pump rate 6
BPM, 575 PSI, 9% F/O. HES batch tail,
(tail wet @ 17:16) Pump 56.72 BBLS of
15.8ppg tail cement @ 3.88 BPM, 96
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 T/ 3 BPM, FCP - 585. Bump plug
@ 2596 strokes (261.4 bbls). CIP @
18:47 hrs. Pressure up to 1114 psi and
hold for 5 min. Bleed off and check
floats (good). Observe 260 bbls of 10.7
cement returned to surface. 0 losses
during cement job.
3,047.0 3,047.0
12/16/2023
19:00
12/16/2023
20:00
1.00 SURFAC, CEMENT RURD P Flush riser and flow line with black
water, drain riser to cellar, rig down
casing running equipment, Rig down 10
3/4" Volant CRT and bell extension,
elevators
3,047.0 3,047.0
12/16/2023
20:00
12/16/2023
20:30
0.50 SURFAC, CEMENT RURD P Lay Down 10 3/4" landing joint to pipe
shed as per Cameron Rep.
3,047.0 3,047.0
12/16/2023
20:30
12/17/2023
00:00
3.50 SURFAC, CEMENT CLEN P Continue to clean and clear rig floor,
laying down casing running equipment
via beaver slide, clean under the rig
floor and rotary table, clean shakers
underflows, pits, rock washer pits.
Prepare to remove riser and nipple
down. clean all cement line valves,
Prepare BOPE stack flange for re
assembly.
3,047.0 3,047.0
12/17/2023
00:00
12/17/2023
01:30
1.50 SURFAC, WHDBOP NUND P Nipple down upper surface riser section,
Install drip nipple, remove lower riser
section and prepare starting head flange
head for removal.
0.0 0.0
12/17/2023
01:30
12/17/2023
04:30
3.00 SURFAC, WHDBOP WWSP P Remove starting head assy. as per
Cameron Rep. Install Cameron
wellhead and orient as per CPAI pad
operator. Test wellhead seal to 5000 psi
for 10 minutes. Witness by CPAI Rep.
0.0 0.0
12/17/2023
04:30
12/17/2023
15:30
11.00 SURFAC, WHDBOP NUND P Nipple up dual stud adapter and spacer
spool to Cameron well head, Nipple up
BOPE stack, Koomey hoses, choke and
kill lines, SIMOPS: continue cleaning
pits, stocking product in pits for the well
section. Process 7 5/8" casing in pipe
shed. Mobilize 2 piece riser to rig floor.
Nipple up MPD equipment, Install
flanges and valves on OA / IA. Install air
boots in 2 piece MPD riser. Grease mud
cross valves.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 8/41
3S-624
Report Printed: 2/12/2024
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)
12/17/2023
15:30
12/17/2023
17:00
1.50 SURFAC, WHDBOP NUND P Install MPD RCD test cap and flood
lines, Mobilize and make up BOP testing
equipment. Send out surface starting
head SIMOPS: Continue to process
intermediate casing, connect tank farm
to pump house manifold.
0.0 0.0
12/17/2023
17:00
12/17/2023
17:15
0.25 SURFAC, WHDBOP PRTS P Test RCD head up against test plug and
HCR valve 1200 psi ( Shell test Good
MPD)
0.0 0.0
12/17/2023
17:15
12/17/2023
19:00
1.75 SURFAC, WHDBOP NUND P Remove drip nipple and install MPD two
part riser, P/U 5" test joint make up test
plug, flood and purge lines taking
returns out choke line, MPD trip nipple
air boot leaking Prep an change out air
boot.
0.0 0.0
12/17/2023
19:00
12/17/2023
22:00
3.00 SURFAC, WHDBOP NUND P Continue to change purge air from
system and work annular to seal with 5"
test joint. Note leak @ kill line in
mezzanine corridor( Tighten Good) MPD
RCD clamp and riser seal leaking(Re-
seal and verify good) SHell test BOPE"S
to 3500 psi (Good)
0.0 0.0
12/17/2023
22:00
12/18/2023
00:00
2.00 SURFAC, WHDBOP BOPE P Test bope all tests to 250 low 5,000 high
for 5 charted min. with exception of
manual operated & super choke tested
to 250 low & 2,000 psi for 5 charted min,
with 5" test jt test annular to 250 low
3500 high, 3 1/2" x 6" upper ram, 3 1/2"
x 6" lower ram, with 5" test jt test 3 1/2"
x 6" upper ram & 3 1/2" x 6" lower ram,
test choke valves 1-15, manual
operated & super choke, choke & kill
manuals & Hcr's, 4" valve on kill line, 5"
FOSV, 5" dart valve, upper & lower
IBOP; blind/ shear rams; Witness
waived by AOGCC Rep Brian Bixby 12-
15-23 20:59 hrs.
0.0 0.0
12/18/2023
00:00
12/18/2023
03:00
3.00 SURFAC, WHDBOP BOPE P Perform Koomey drawdown,
accumulator = 3000 psi. manifold. =
1500 psi. accumulator = 1900 psi after
all functions on bottles, 9 sec for 200
psi. build w/ 2 electric. pumps, 50
seconds to build full systems. pressure
with 2 electric. & 2 air pumps, closing
times annular = 23 seconds. upper ram
= 18 sec. blind ram , shears ram = 16
seconds. lower ram = 16 seconds.
choke Hcr = 2 seconds. kill Hcr = 2
second; test PVT gain/loss and flow out
alarms, test LEL and H2S alarms;
witnessed waived by AOGCC Rep Brian
Bixby 12-16-23 16:44 hrs
0.0 0.0
12/18/2023
03:00
12/18/2023
03:30
0.50 SURFAC, WHDBOP RURD P Pull test plug and set wear bushing as
per Cameron Rep. Wear Bushing ID
10, OD 10 3/4", Length 30"
0.0 0.0
12/18/2023
03:30
12/18/2023
06:30
3.00 SURFAC, DRILLOUT RURD P Rig down BOPE testing equipment,
Drain stack, blow down choke and kill
lines, Line up choke manifold to drill out.
Clean and clear rig floor of excess tools
and equipment. Mobilize BHA
components to the rig floor, prepare rig
floor to pickup intermediate section BHA
0.0 0.0
12/18/2023
06:30
12/18/2023
08:15
1.75 SURFAC, DRILLOUT BHAH P PJSM, Pickup Intermediate hole section
BHA as per SLB DD/MWD from Surface
to 798' MD
0.0 798.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 9/41
3S-624
Report Printed: 2/12/2024
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)
12/18/2023
08:15
12/18/2023
09:15
1.00 SURFAC, DRILLOUT TRIP P RIH with 5" drill pipe out derrick from
798' MD to 2870' MD. Monitoring
displacement via trip tank.
798.0 2,870.0
12/18/2023
09:15
12/18/2023
10:00
0.75 SURFAC, DRILLOUT CIRC P Rig up to shallow hole test MWD,
(Good Test) Circulate and condition mud
surface to surface. SIMOPS process 4"
drill pipe in pipe shed
2,870.0 2,870.0
12/18/2023
10:00
12/18/2023
11:45
1.75 SURFAC, DRILLOUT PRTS P Flood lines and test 10 3/4" casing to
3000psi for 30 minute on chart.
2,870.0 2,870.0
12/18/2023
11:45
12/18/2023
12:30
0.75 SURFAC, DRILLOUT RURD P Rig down casing test equipment, blow
down choke/ kill lines and cement line.
Prepare tools and equip to slip and cut
drill line.
2,870.0 2,870.0
12/18/2023
12:30
12/18/2023
15:15
2.75 SURFAC, DRILLOUT SLPC P Slip and Cut drill line 74' Inspect brass/
Dog nut, Torque deadman to spec.
Remove cut line from rig floor, Remove
and tie back block hanging line.
2,870.0 2,870.0
12/18/2023
15:15
12/18/2023
15:30
0.25 SURFAC, DRILLOUT WASH P Wash down from 2870' MD to 2968' MD
tag cement 10K, RPM 20, TQ 7k,GPM
400, PSI 620, P/U 115k, S/O 95K, RT
115k
2,870.0 2,968.0
12/18/2023
15:30
12/18/2023
20:30
5.00 SURFAC, DRILLOUT DRLG P Drill surface cement / shoe track assy
from 2968' to 3056'MD.WOB 5-12, GPM
550,PSI 1200, RPM 60, TQ 5k F/O
16%, P/U 120k S/O 108k ROT 109k.
Work through shoe 2x times observe no
over pull. (SIMOPS processing 5" pipe
in pipe shed.) Pumped 15 bbls high vis
sweep @ 2973'MD, Pumped 25 bbl high
vis sweep 3058' MD
2,968.0 3,056.0
12/18/2023
20:30
12/18/2023
22:30
2.00 SURFAC, DRILLOUT DRLG P Drill 20' new formation from 3056'MD to
3076'MD.WOB 5-12, GPM 550,PSI
1200, RPM 60, TQ 5k F/O 16%, P/U
120k S/O 108k ROT 109k. Work through
shoe 3x times observe no over pull.
(SIMOPS processing 5" pipe in pipe
shed.) Pumped 25 bbl high vis sweep
3076' MD
3,056.0 3,076.0
12/18/2023
22:30
12/19/2023
00:00
1.50 SURFAC, DRILLOUT CIRC P BROOH from 3076' MD to 3056' MD,
Circulate and condition hole clean for
FIT test GPM 550, PSI 1134 RPM 60
TQ7k, F/O 18%, ECD 10.07, P/U 118k,
S/O 98k, RT 106k. Obtain survey @
3074'MD Pumped 25 bbls high vis
sweep @ 3076' MD
3,076.0 3,056.0
12/19/2023
00:00
12/19/2023
00:30
0.50 SURFAC, DRILLOUT RURD P R/U for LOT test and ready test
equipment for charted test.
3,056.0 3,056.0
12/19/2023
00:30
12/19/2023
01:30
1.00 SURFAC, DRILLOUT LOT P @ 2969' MD LOT/FIT test pressure up
to 792 psi with 9.7 ppg mud pumped 2.8
bbls to pressure up. LOT was observed
at 563 psi EMW 13.8 ppg. Bled back 1.3
bbls
3,056.0 2,969.0
12/19/2023
01:30
12/19/2023
02:00
0.50 SURFAC, DRILLOUT RURD P R/D from LOT and all test equipment.
R/D chart recorder and blow down all
lines.
2,969.0 2,969.0
12/19/2023
02:00
12/19/2023
03:00
1.00 SURFAC, DRILLOUT RGRP T Trouble shoot Electrical on Rig
operating system. Reboot on complete
system.
2,969.0 2,969.0
12/19/2023
03:00
12/19/2023
04:15
1.25 INTRM1, DRILL DISP P @ 3076' displace well to 9.0 ppg FWP
GPM 500, PSI 715, RT 110k, RPM 40,
TQ 4k, F/O 19%, ECD 9.47 ppg
2,969.0 3,076.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 10/41
3S-624
Report Printed: 2/12/2024
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)
12/19/2023
04:15
12/19/2023
06:00
1.75 INTRM1, DRILL DDRL P Drill 9Ǭ" Interm hole from 3076' MD to
3115' MD, 2371' TVD, WOB=2.6k,
GPM=650, PSI=925, RPM=100, TQ=6k,
F/O 17%, ECD=9.59, P/U=111k,
S/O=104k, RT=106k. ADT .42, Bit hrs
1.4, Jars 19.37,
3,076.0 3,115.0
12/19/2023
06:00
12/19/2023
12:00
6.00 INTRM1, DRILL DDRL P Drill 9Ǭ" Interm hole from 3115' MD to
3570' MD, 2855' TVD, WOB=1.6k,
GPM=750, PSI=1283, RPM=150,
TQ=6k, F/O 20%, ECD=10.00,
P/U=114k, S/O=107k, RT=109k.
ADT .4.41, Bit hrs 5.81, Jars 23.87.
3,115.0 3,570.0
12/19/2023
12:00
12/19/2023
18:00
6.00 INTRM1, DRILL DDRL P Drill 9Ǭ" Interm hole from 3570' MD to
4376' MD, 3244' TVD, WOB=9k,
GPM=750, PSI=1776, RPM=150,
TQ=5k, F/O 21%, ECD=11.34,
P/U=138k, S/O=114k, RT=119k.
ADT .4.17, Bit hrs 9.98, Jars 27.95
Pumped 30 bbl high vis sweep @
4188' .
3,570.0 4,376.0
12/19/2023
18:00
12/19/2023
20:00
2.00 INTRM1, DRILL DDRL P Drill 9Ǭ" Interm hole from 4376' MD to
4502' MD, 3358' TVD, WOB=9k,
GPM=750, PSI=1776, RPM=150,
TQ=5k, F/O 21%, ECD=11.30,
P/U=138k, S/O=114k, RT=119k. ADT
1.5, Bit hrs 11.48, Jars 29.45 Pumped
30 bbl high vis sweep @ 4387' MD and
4481' MD ' .
4,376.0 4,502.0
12/19/2023
20:00
12/19/2023
22:00
2.00 INTRM1, DRILL CIRC T @ 4502'MD while drilling ahead with
GPM 750, PSI 1778, ROT 110k, with
RPM 150 TQ 6k, Observe pressure
increase 350 psi from initial pump rate
pressure and ECD spike to 13.69 while
downlinking command to tool, pick up
off bottom to separate from loss zone,
noted immediate losses due to well
(pack-off around string), reduced pump
rate to GPM 400, PSI 1116, in attempt to
re-establish circulation to mitigate
losses, loaded string with 25 bbl hi-vis
LCM pill, decided to POOH to 4474'MD
and rotate and reciprocate while
prepping to circulate LCM pill with GPM
400, PSI 1079, RT- 108k, RPM 120,
TQ 7k, pumped 25bbl hi-vis LCM pill
around and re-established circulation
staging pumps from GPM 400-750, ICP
1079 psi, clean circulate well PSI 850-
FCP 1544 psi F/O= 21% clean ECD @
10.33ppg while hole continually un-
loaded. Circulate until returns clear up.
LCM sweeps 35 PPB,
4,502.0 4,474.0
12/19/2023
22:00
12/20/2023
00:00
2.00 INTRM1, DRILL DDRL P Drill 9Ǭ" Interm hole from 4502' MD to
4612' MD, 3358' TVD, WOB=9k,
GPM=750, PSI=1776, RPM=150,
TQ=5k, F/O 21%, ECD=11.30,
P/U=138k, S/O=114k, RT=119k. ADT
1.5, Bit hrs 11.48, Jars 29.45 Pumped
30 bbl high vis sweep @ 4671' MD ' .
4,502.0 4,612.0
12/20/2023
00:00
12/20/2023
06:00
6.00 INTRM1, DRILL DDRL P Drill 9Ǭ" Interm hole from 4612' MD to
5006' MD, 3748' TVD, WOB=4k,
GPM=750, PSI=1838, RPM=150,
TQ=5k, F/O 28%, ECD=10.60,
P/U=132k, S/O=124k, RT=125k. ADT
4.75, Bit hrs 17.70, Jars 35.67 Pumped
30 bbl high vis sweep @ 4954' MD ' .
4,612.0 5,006.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 11/41
3S-624
Report Printed: 2/12/2024
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)
12/20/2023
06:00
12/20/2023
12:00
6.00 INTRM1, DRILL DDRL P Drill 9Ǭ" Interm hole from 5006' MD to
5644' MD, 4090 TVD, WOB=8k,
GPM=750, PSI=2039, RPM=160,
TQ=5k, F/O 28%, ECD=10.94,
P/U=137k, S/O=128k, RT=130k. ADT
4.62, Bit hrs 22.32, Jars 40.29 Pumped
30 bbl high vis sweep @ 5618' MD ' .
5,006.0 5,644.0
12/20/2023
12:00
12/20/2023
15:30
3.50 INTRM1, DRILL DDRL P Drill 9Ǭ" Interm hole from 5644' MD to
5897' MD, 4246' TVD, WOB=7k,
GPM=750, PSI=2112, RPM=156,
TQ=8k, F/O 28%, ECD=11.00,
P/U=140k, S/O=131k, RT=134k. ADT
2.64, Bit hrs 24.96, Jars 42.93
5,644.0 5,897.0
12/20/2023
15:30
12/20/2023
17:15
1.75 INTRM1, DRILL RGRP T Top-Drive top IBOP connection loosen
at fetter ring when breaking out top-drive
connection fron stand of 5" drill pipe.
Loosen and remove fetter ring and re-
torque IBOP connection to spec. Install
fetter ring and re-torque bolts to spec.
and secure with safety wire. Ready to
continue drilling.
5,897.0 5,897.0
12/20/2023
17:15
12/20/2023
18:00
0.75 INTRM1, DRILL DDRL P Drill 9Ǭ" Interm hole from 5897' MD to
5991' MD, 4203' TVD, WOB=6k,
GPM=750, PSI=2093, RPM=160,
TQ=7k, F/O 28%, ECD=10.93,
P/U=140k, S/O=131k, RT=134k.
ADT .48, Bit hrs 25.44, Jars 43.41
Pumped 30 bbl high vis sweep @ 5900'
MD ' .
5,897.0 5,991.0
12/20/2023
18:00
12/21/2023
00:00
6.00 INTRM1, DRILL DDRL P Drill 9Ǭ" Interm hole from 5991' MD to
6550 ' MD,4942 ' TVD, WOB=5.5k,
GPM=750, PSI=2158, RPM=150,
TQ=7k, F/O 24%, ECD=11.08,
P/U=154k, S/O=142k, RT=137k. ADT
4.41, Bit hrs 29.85 Jars 47.82 Pumped
30 bbls high vis sweep 6550' MD
5,991.0 6,550.0
12/21/2023
00:00
12/21/2023
06:00
6.00 INTRM1, DRILL DDRL P Drill 9Ǭ" Interm hole from 6550' MD to
7095 ' MD, ' 4942 TVD, WOB=5.5k,
GPM=750, PSI=2099, RPM=140,
TQ=7k, F/O 26%, ECD=10.51,
P/U=155k, S/O=151k, RT=142k. ADT
4.92, Bit hrs 34.77 Jars 52.74.
6,550.0 7,095.0
12/21/2023
06:00
12/21/2023
11:00
5.00 INTRM1, DRILL DDRL P Drill 9Ǭ" Interm hole from 7095' MD to
7590' MD TD, 5126 TVD, WOB=5.5k,
GPM=750, PSI=2209, RPM=180,
TQ=7k, F/O 23%, ECD=10.92,
P/U=153k, S/O=151k, RT=152k. ADT
4.04, Bit hrs 38.81 Jars 52.74. Obtain
final survey, SPR's, Torque and Drag
values.
7,095.0 7,590.0
12/21/2023
11:00
12/21/2023
12:00
1.00 INTRM1, TRIPCAS CIRC P Circulate and Condition hole clean
surface to surface while BROOH from
7590' MD to 7518' MD GPM750 PSI
2055, RPM 140, TQ 5k, F/O 35% ECD
10.72 RT 139k.
7,590.0 7,518.0
12/21/2023
12:00
12/21/2023
13:30
1.50 INTRM1, TRIPCAS CIRC P Circulate and Condition hole while
BROOH 7518' MD to 7311' MD
GPM750 PSI 2055, RPM 140, TQ 5k,
F/O 32% ECD 10.84 RT 139k.
7,518.0 7,311.0
12/21/2023
13:30
12/21/2023
14:00
0.50 INTRM1, TRIPCAS OWFF P OWFF well static 7,311.0 7,311.0
12/21/2023
14:00
12/22/2023
00:00
10.00 INTRM1, TRIPCAS BKRM P BROOH 7311' MD to 4280' MD
GPM750 PSI 1645, RPM 140, TQ 3.5k,
F/O 36% ECD 10.63 RT 111k.Laying
down 5" drill pipe Via mousehole.
7,311.0 4,280.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 12/41
3S-624
Report Printed: 2/12/2024
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)
12/22/2023
00:00
12/22/2023
03:45
3.75 INTRM1, TRIPCAS BKRM P BROOH 4280' MD to 3020' MD
GPM750 PSI 1503, RPM 140, TQ 3.5k,
F/O 35% ECD 10.58 RT 100k. Laying
down 5" drill pipe Via mouse hole.
4,280.0 3,020.0
12/22/2023
03:45
12/22/2023
04:30
0.75 INTRM1, TRIPCAS CIRC P Circulate and condition mud while
rotating reciprocating pipe from 3020'
MD to 2790' MD GPM 750, PSI 1506,
F/O 30%, RPM 20, TQ 2k, ECD 10.41,
P/U 100k, S/O 107k, Pump 30 bbl high
vis sweep, followed by 30 bbl LCM
sweep 35ppb, total strokes pumped
9500 strokes 2x bottoms up.
3,020.0 2,970.0
12/22/2023
04:30
12/22/2023
09:30
5.00 INTRM1, TRIPCAS BKRM P BROOH 2790' MD to 1241' MD
GPM775 PSI 1303, RPM 60, TQ 3.5k,
F/O 35% ECD 10.28 RT 87k. Laying
down 5" drill pipe Via mouse hole.
2,970.0 1,241.0
12/22/2023
09:30
12/22/2023
10:30
1.00 INTRM1, TRIPCAS OWFF P OWFF(well static) SIMOPS- Blow down
top-drive and ready rig floor to lay down
5" drill pipe singles to pipe shed
1,241.0 1,241.0
12/22/2023
10:30
12/22/2023
12:30
2.00 INTRM1, TRIPCAS TRIP P TOOH from 1241' MD to 145' MD. Lay
down 5" drill pipe and 5" heavy weight
drill pipe to shed. P/U 90k. Monitor
displacement via trip tank.
1,241.0 145.0
12/22/2023
12:30
12/22/2023
12:45
0.25 INTRM1, TRIPCAS OWFF P OWFF(well static) 145.0 145.0
12/22/2023
12:45
12/22/2023
14:15
1.50 INTRM1, TRIPCAS BHAH P Lay down BHA from 145' MD to surface
as per SLB DD, MWD to pipe shed,
Monitoring well via trip tank.
145.0 0.0
12/22/2023
14:15
12/22/2023
15:15
1.00 INTRM1, TRIPCAS BOPE P Clean and clear rig floor, Make up
stack/wellhead washing tool, wash
stack/wellhead, with GPM 672, PSI 70,
P/U and S/O 43k Weekly BOP function
test.(Good Function test)
0.0 0.0
12/22/2023
15:15
12/22/2023
15:45
0.50 INTRM1, CASING BOPE P Make up wearbushing pulling tools, pull
wearbushing as per Cameron wellhead
Rep.
0.0 0.0
12/22/2023
15:45
12/22/2023
18:00
2.25 INTRM1, CASING BOPE P Change upper pipe rams from 3.5" x 6"
VBR's to 7 5/8" solid body casing rams.
SIMOPS- rig up Doyon casing handling
equipment.
0.0 0.0
12/22/2023
18:00
12/22/2023
18:45
0.75 INTRM1, CASING BOPE P Rig up and set test plug as per Cameron
wellhead Rep. Shell test BOP 3500 psi
0.0 0.0
12/22/2023
18:45
12/22/2023
19:30
0.75 INTRM1, CASING BOPE P Test upper pipe rams with 7 5/8" test
joint 250 psi low 4000 psi high, Test
annular 250 psi low, 3500 psi high. Note
charted test.
0.0 0.0
12/22/2023
19:30
12/22/2023
20:00
0.50 INTRM1, CASING BOPE P Pull test plug as per Cameron. Rig down
testing equipment. clean and clear rig
floor.
0.0 0.0
12/22/2023
20:00
12/22/2023
20:30
0.50 INTRM1, CASING RURD P Finishing rigging up Doyon casing
handling equipment.
0.0 0.0
12/22/2023
20:30
12/22/2023
20:45
0.25 INTRM1, CASING SFTY P PJSM with all hand involved with
running 7 5/8" casing.
0.0 0.0
12/22/2023
20:45
12/23/2023
00:00
3.25 INTRM1, CASING PUTB P Pick up and run 7 5/8" 29.7# L-80
Hyd563 and 33.7# P-110 Hyd563
intermediate casing as per tally. Baker
loc shoe track assy, make up torque
29.7# 10300 ft/lbs, 33.7# 12100 ft/lbs,
Monitoring displacement on pit #1 and
Pill pit #2, fill pipe on the fly, top off after
every 10 joints. RIH From surface to
965' MD
0.0 965.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 13/41
3S-624
Report Printed: 2/12/2024
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)
12/23/2023
00:00
12/23/2023
04:00
4.00 INTRM1, CASING PUTB P Pick up and run 7 5/8" 29.7# L-80
Hyd563 and 33.7# P-110 Hyd563
intermediate casing as per tally. 29.7#
10300 ft/lbs, 33.7# 12100 ft/lbs,
Monitoring displacement on pit #1 and
Pill pit #2, fill pipe on the fly, top off after
every 10 joints. RIH From surface to
965' MD to 3045' MD. S/O 107k
965.0 3,045.0
12/23/2023
04:00
12/23/2023
04:30
0.50 INTRM1, CASING CIRC P Circulate and condition mud bottoms up
@ 3045' MD. GPM 250, PSI 170, F/O
13%, P/U 107k, S/O 106k, Total strokes
pumped 1432 strokes.
3,045.0 3,045.0
12/23/2023
04:30
12/23/2023
09:00
4.50 INTRM1, CASING PUTB P Pick up and run 7 5/8" 29.7# L-80
Hyd563 and 33.7# P-110 Hyd563
intermediate casing as per tally. 29.7#
10300 ft/lbs, 33.7# 12100 ft/lbs,
Monitoring displacement on pit #1 and
Pill pit #2, fill pipe on the fly, top off after
every 10 joints. RIH From surface to
3045' MD to 5332' MD. S/O 134k
3,045.0 5,332.0
12/23/2023
09:00
12/23/2023
10:00
1.00 INTRM1, CASING CIRC P Circulate and condition mud bottoms
up@ 5332, BPM 0.5-6, PSI 150-284,
F/O 20%, P/U 146k, S/O 134k, Total
strokes pumped 2605 strokes.
5,332.0 5,332.0
12/23/2023
10:00
12/23/2023
12:00
2.00 INTRM1, CASING PUTB P Pick up and run 7 5/8" 29.7# L-80
Hyd563 and 33.7# P-110 Hyd563
intermediate casing as per tally. 29.7#
10300 ft/lbs, 33.7# 12100 ft/lbs,
Monitoring displacement on pit #1 and
Pill pit #2, fill pipe on the fly, top off after
every 10 joints. RIH From surface to
5332' MD to 6475' MD. S/O 134k
5,332.0 6,475.0
12/23/2023
12:00
12/23/2023
13:00
1.00 INTRM1, CASING CIRC P Circulate and condition mud bottoms
up@ 6475, BPM 0.5-6, PSI 133-380,
F/O 20%, P/U 162k, S/O 1149k, Total
strokes pumped 2893 strokes.
6,475.0 6,475.0
12/23/2023
13:00
12/23/2023
16:15
3.25 INTRM1, CASING PUTB P Pick up and run 7 5/8" 29.7# L-80
Hyd563 and 33.7# P-110 Hyd563
intermediate casing as per tally. 29.7#
10300 ft/lbs, 33.7# 12100 ft/lbs,
Monitoring displacement on pit #1 and
Pill pit #2, fill pipe on the fly, top off after
every 10 joints. RIH From surface to
6475' MD to 7453' MD. S/O 154k
6,475.0 7,453.0
12/23/2023
16:15
12/23/2023
16:45
0.50 INTRM1, CASING THGR P M/U 7 5/8" Space out pups, 7 5/8"
Cameron hanger assy. to landing joint
and wash down @ BPM 2, PSI 312,
Land out hanger. S/O to 46 k Good.
7,453.0 7,580.0
12/23/2023
16:45
12/23/2023
18:45
2.00 INTRM1, CEMENT CIRC P @ 7580' MD circulate and condition
mud for cement job stage rates up to 6
BPM, while reciprocating 7 5/8" casing
Stage rates, BPM 2-6 PSI 315-446, P/U
175, S/O 150k
7,580.0 7,580.0
12/23/2023
18:45
12/23/2023
20:45
2.00 INTRM1, CEMENT RURD P Rig up cement lines to Volant, Break
circulation stage rate to BPM 6 PSI 412,
F/O 45% P/U 175k, S/O 150k,
Reciprocating pipe from 7580' to 7568'
7,580.0 7,568.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 14/41
3S-624
Report Printed: 2/12/2024
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)
12/23/2023
20:45
12/23/2023
23:45
3.00 INTRM1, CEMENT CMNT P Perform cement job for 7-5/8”"
intermediate. casing as per Halliburton
program, Flood lines with 5 bpm H2O
278 psi, Pressure Test lines to 4000psi.
Drop #1 bottom plug , pump 60 bbls
tuned 10.5 ppg spacer @ 4.5 bpm/ 435
psi 12% F/O, Drop #2 bottom plug,
pump 123 bbls 15.3 ppg primary cmt
with BM11 @ 5.7 bpm 500 psi 14% f/o,
pump 22 bbls 15.3 ppg primary cmt
without BM11 @ 5.5 bpm 2212 psi 10%
f/o, Drop top plug, pump 20 bbls fresh
H2O, line up to rig pumps to displace.
with 321 bbls @ 6 bpm 1230 psi 14% f/o
from 2979 strokes. Cont. displacement
@ 3 bpm 1135 psi F/O 13%, Slow rate
to 3 bpm @ 1135 psi, Bump plug 3189
strokes.1824 psi, Stop pumping at
strokes hold for 5 min. Bleed off/ check
floats. floats held.Cement in place at
23:00 hrs.
7,580.0 7,580.0
12/23/2023
23:45
12/24/2023
00:00
0.25 INTRM1, CEMENT RURD P Ready rig floor to test 7 5/8" casing. 7,580.0 7,580.0
12/24/2023
00:00
12/24/2023
01:15
1.25 INTRM1, CEMENT PRTS P Pressure test 7 5/8" intermediate casing
to 4000 psi for 30 minutes Pump rate .5
bpm 59 strokes pumped, 5.9 bbls to
pressure up Bled back 5.9 bbls
0.0 0.0
12/24/2023
01:15
12/24/2023
02:30
1.25 INTRM1, CEMENT RURD P Rig down running equipment, clean
surface equipment and manifold valves
after cement job.
0.0 0.0
12/24/2023
02:30
12/24/2023
03:30
1.00 INTRM1, CEMENT WWWH P M/U stack washer tool, and wash
Hanger packoff profile as per Cameron
Reps. GPM 400 PSI 251, RPM 10.
0.0 0.0
12/24/2023
03:30
12/24/2023
04:00
0.50 INTRM1, CEMENT WWSP P RIH with 7 5/8" pack off assy. Set
packoff and rig up to test packoff to
5000 psi, After 10 minutes pressure bled
off to zero.(Fail Test).
0.0 0.0
12/24/2023
04:00
12/24/2023
10:45
6.75 INTRM1, CEMENT WWSP T POOH with packoff assy. Inspect seals
on packoff, seen no visible damage, RIH
and re-set packoff attempt to test, (fail
test), POOH packoff assy for inspection
found upper o-ring seal failure. change o
-ring seal, RIH attempt to test fail test,
POOH with packoff assy found upper
seal had fail again. Rig up and flush
BOP stack and flush wellhead profile.
Changed out packoff assy. RIH set
packoff attempted to test fail test, POOH
with packoff assy, Upper seal fail again.
Changed of upper seal with upper seal
from emergency packoff, RIH set
packoff and test packoff to 5000 psi for
10 minutes. Rig down handling tools.
0.0 0.0
12/24/2023
10:45
12/24/2023
11:30
0.75 INTRM1, WHDBOP WWWH P Make up stack washer tool and wash
and flush stack as per Cameron GPM
756, PSI 151, RPM 22.
0.0 0.0
12/24/2023
11:30
12/24/2023
12:00
0.50 INTRM1, WHDBOP WWSP P Set test plug as per Cameron Reps.
Blow down top-drive.
0.0 0.0
12/24/2023
12:00
12/24/2023
12:30
0.50 INTRM1, WHDBOP RURD P Laydown over torque drill pipe from
derrick to pipe shed
0.0 0.0
12/24/2023
12:30
12/24/2023
15:00
2.50 INTRM1, WHDBOP RGRP P Change top-drive saver sub from 4 1/2
IF to XT-39, Change out upper pipe
rams from 7 5/8" solid body to 3.5"x6"
VBR's
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 15/41
3S-624
Report Printed: 2/12/2024
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)
12/24/2023
15:00
12/24/2023
17:00
2.00 INTRM1, WHDBOP RURD P Rig up to test BOPE's with 4" and 4.5"
test joints, Flood lines. Purge air from
system and shell test BOPE to 3500 psi.
0.0 0.0
12/24/2023
17:00
12/24/2023
22:30
5.50 INTRM1, 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" test jt test annular, 3-1/2" x
6" upper rams, 3-1/2" x 6" lower rams,
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 &
Hcr's, 4" valve on kill line, 4" FOSV x2,
4" dart valve, upper & lower IBOP; blind/
shear rams; perform Koomey
drawdown, acc = 2950 psi. manifold =
1600 psi. acc = 1850 psi after all
functions on bottles, 10 seconds for 200
psi. build with 2 electrics. 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 seconds. 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 Adam Earl witness @
09:21 hrs on 12-24-23
0.0 0.0
12/24/2023
22:30
12/24/2023
22:45
0.25 INTRM1, WHDBOP RURD P Rig up and pull test plug, Set wear
bushing as per Cameron Rep. Length
13" OD 10 3/4" ID 10"
0.0 0.0
12/24/2023
22:45
12/25/2023
00:00
1.25 INTRM1, WHDBOP RUNL P Rig down testing equipment, blow down
lines
0.0 0.0
12/25/2023
00:00
12/25/2023
02:30
2.50 INTRM1, DRILLOUT CLEN P Clean and clear rig floor of excess tool
and equipment. Mobilize production
BHA to rig floor via beaver slide. Load
and process 4'' drill pipe and heavy
weight drill pipe in the shed.
0.0 0.0
12/25/2023
02:30
12/25/2023
06:00
3.50 INTRM1, DRILLOUT BHAH P PJSM. Make up 6-1/2'' production BHA
as per SLB, DD, MWD to 192’. S/O 60k.
0.0 192.0
12/25/2023
06:00
12/25/2023
10:00
4.00 INTRM1, DRILLOUT PUTB P Single in the hole from 192‘MD to
3219‘MD with 4” drill pipe. P/U 79k, S/O
77k. Monitor displacement on pit #1 and
pill pit #2. Fill pipe each 20 stands.
192.0 3,219.0
12/25/2023
10:00
12/25/2023
10:30
0.50 INTRM1, DRILLOUT SRVY P @ 3219' MD - shallow test BHA as per
SLB, DD, MWD with 250gpm 1445psi,
P/U 80k, S/O 80k. Downlink tool for
Sonic Scope USIT log and ready to free
ring pipe for top of cement.
3,219.0 3,219.0
12/25/2023
10:30
12/25/2023
12:00
1.50 INTRM1, DRILLOUT DLOG P From 3219' MD to 3631'MD Sonic
Scope log top of cement with 250gpm
1527psi, P/U 89k, S/O 89k. Logging @
900-450fph.
3,219.0 3,631.0
12/25/2023
12:00
12/25/2023
19:30
7.50 INTRM1, DRILLOUT DLOG P From 3631' MD to 5430' MD Sonic
Scope log top of cement with 25 gpm,
183 psi, P/U 122k, S/O 122k. Logging
@ 450fph.
3,631.0 5,430.0
12/25/2023
19:30
12/25/2023
23:00
3.50 INTRM1, DRILLOUT DLOG P Single in the hole from 5430‘ MD to
7450‘ MD with 4” drill pipe. S/O 123k.
Monitor displacement on pit #1 and pill
pit #2. Fill pipe each 20 stands.
Continue to log cement free ring @
5400'/hr while RIH.
5,430.0 7,450.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 16/41
3S-624
Report Printed: 2/12/2024
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)
12/25/2023
23:00
12/26/2023
00:00
1.00 INTRM1, DRILLOUT MPDA P PJSM. Remove trip nipple and install
MPD bearing as per beyond.
7,450.0 7,450.0
12/26/2023
00:00
12/26/2023
02:30
2.50 INTRM1, DRILLOUT MPDA P @ 7450' MD. Practice ramping up and
down pump schedule with MPD chokes
and Novos system. GPM 250, 2221 PSI,
ECD 10.16, RPM 40, TQ 6k, ROT 131k .
7,450.0 7,450.0
12/26/2023
02:30
12/26/2023
03:45
1.25 INTRM1, DRILLOUT MPDA P PJSM. Remove MPD bearing. Install trip
nipple as per Beyond Rep.
7,450.0 7,450.0
12/26/2023
03:45
12/26/2023
04:00
0.25 INTRM1, DRILLOUT REAM P Wash and ream from 7450' MD to 7483'
MD. Tag top of cement with 11k, GPM
250, PSI 2185, ECD 10.27, F/O 7%,
S/O 146k.
7,450.0 7,483.0
12/26/2023
04:00
12/26/2023
09:00
5.00 INTRM1, DRILLOUT DRLG P Drill out 7-5/8" shoe track from 7483'
MD to 7590' MD with GPM 250, PSI
2230, RPM 80, TQ 9k, F/O 6% RT 139k.
7,483.0 7,590.0
12/26/2023
09:00
12/26/2023
09:30
0.50 INTRM1, DRILLOUT DRLG P Drill new formation from 7590' MD to
7610' MD @ GPM 250, PSI 2330, RPM
80, TQ 9k, ECD 10.37 ppg, RT 145k.
7,590.0 7,610.0
12/26/2023
09:30
12/26/2023
10:45
1.25 INTRM1, DRILLOUT CIRC P Circulate, rotate & reciprocate from
7610‘ MD to 7590‘ MD, with GPM 250,
PSI 2230, F/O 6%, RPM 80, TQ 8k,
ECD 10.53 ppg, P/U 148k, S/O 138k,
RT 145k, while pumping 30 bbl, 10 ppg
hi-vis nut plug sweep & getting uniform
mud all the way around prior to FIT/LOT.
7,610.0 7,590.0
12/26/2023
10:45
12/26/2023
11:00
0.25 INTRM1, DRILLOUT OWFF P OWFF (Well static). 7,597.0 7,579.0
12/26/2023
11:00
12/26/2023
11:45
0.75 INTRM1, DRILLOUT RURD P Blow down top-drive and rig up for
FIT/LOT.
7,579.0 7,579.0
12/26/2023
11:45
12/26/2023
12:00
0.25 INTRM1, DRILLOUT FIT P Perform FIT @ 5 spm to 1730 psi max.
Shut in and monitor for 10 minutes, 3.1
bbls pumped, 2.2 bbls bled back. R/D &
blow down test equipment. 16 ppg EMW
FIT. Monitor pressure via Totco.
7,579.0 7,579.0
12/26/2023
12:00
12/26/2023
12:30
0.50 PROD1, DRILL RURD P Rig down FIT test tools and equipment.
Blow down lines. Rig up on OA valve.
Move and calibrate OA sensors.
7,579.0 7,579.0
12/26/2023
12:30
12/26/2023
14:00
1.50 PROD1, DRILL FRZP P Perform OA injection test at 0.3 bpm,
760 psi max. 3.3 bbls pumped. Monitor
injection pressure for Freeze protection
via Totco OA gauge. Pressure bled
down from 710 psi to 350 psi in 10
minutes on OA. OA final - 54 psi.
7,579.0 7,579.0
12/26/2023
14:00
12/26/2023
15:00
1.00 PROD1, DRILL MPDA P PJSM pull trip nipple and install MPD
RCD as per Beyond Rep. P/U 171k, S/O
130k, Flood system and function test
MPD equipment.
7,579.0 7,579.0
12/26/2023
15:00
12/26/2023
17:30
2.50 PROD1, DRILL DISP P Displace well @ 7610' MD with 9.0 ppg
Kla-shield mud, GPM 250, PSI 2247,
RPM 60, TQ 9.5k, F/O 6%, ECD 10.73.
7,579.0 7,610.0
12/26/2023
17:30
12/26/2023
18:00
0.50 PROD1, DRILL OWFF P OWFF (Well Static). 7,610.0 7,610.0
12/26/2023
18:00
12/27/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 7610’
MD to 8017' MD / 5208' TVD, WOB 7k,
GPM 250, PSI 1887, RPM 110, TQ 10k,
F/O 7%, ECD 10.11 ppg, P/U 167k,
ROT 142k, S/O 121k, ADT 4.20, Total bit
hrs 4.71, MPD connection back PSI
200.
7,610.0 8,017.0
12/27/2023
00:00
12/27/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 8017’
MD to 8585' MD / 5263' TVD, WOB 7k,
GPM 250, PSI 1951, RPM 110, TQ 8k,
ECD 10.21 ppg, P/U 167k, ROT 118k,
S/O 143k, ADT 4.13, Total bit hrs 8.84,
MPD connection back PSI 220.
8,017.0 8,585.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 17/41
3S-624
Report Printed: 2/12/2024
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)
12/27/2023
06:00
12/27/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 8585’
MD to 9182' MD / 5252' TVD, WOB 12k,
GPM 260, PSI 2217, RPM 125, TQ 10k,
ECD 10.36 ppg, P/U 168k, ROT 113k,
S/O 138k, ADT 4.54, Total bit hrs 13.38,
MPD connection back PSI 280.
8,585.0 9,182.0
12/27/2023
12:00
12/27/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 9182’
MD to 9786' MD / 5250' TVD, WOB 6k,
GPM 265, PSI 2347, RPM 140, TQ
10.5k, ECD 10.58 ppg, P/U 166k, ROT
110k, S/O 135k, ADT 4.47, Total bit hrs
17.85, MPD connection back PSI 280.
@ 1600hrs ST-100 down trouble
shooting working on electrical issues.
9,182.0 9,786.0
12/27/2023
18:00
12/28/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 9786’
MD to 10417' MD / 5234' TVD, WOB 9k,
GPM 265, PSI 2476, RPM 140, TQ 11k,
ECD 10.77 ppg, P/U 163k, ROT 98k,
S/O 125k, ADT 4.53, Total bit hrs 22.38,
MPD connection back PSI 320. @
2200hrs ST-100 Back up and running .
9,786.0 10,417.0
12/28/2023
00:00
12/28/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 10,417’
MD to 10,948' MD / 5,223' TVD, WOB
10k, GPM 265, PSI 2610, RPM 140, TQ
10k, ECD 10.84 ppg, MWT 9.3 ppg, P/U
163k, ROT 126k, S/O 101k, ADT 4.22,
Total bit hrs 26.60, MPD connection
back PSI 300.
10,417.0 10,948.0
12/28/2023
06:00
12/28/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 10,948’
MD to 11,558' MD / 5,211' TVD, WOB
11k, GPM 265, PSI 2670, RPM 140, TQ
11k, ECD 10.91 ppg, MWT 9.3 ppg, P/U
160k, ROT 129k, S/O 99k, ADT 4.72,
Total bit hrs 31.32, MPD connection
back PSI 370.
10,948.0 11,558.0
12/28/2023
12:00
12/28/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 11,558’
MD to 12,206' MD / 5,198' TVD, WOB
8k, GPM 265, PSI 2756, RPM 140, TQ
11k, ECD 11.1 ppg, MWT 9.3 ppg, P/U
164k, ROT 127k, S/O 93k, ADT 4.50,
Total bit hrs 35.82, MPD connection
back PSI 450.
11,558.0 12,206.0
12/28/2023
18:00
12/29/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 12,206’
MD to 12,734' MD / 5,200' TVD, WOB
7k, GPM 265, PSI 2830, RPM 140, TQ
12k, ECD 11.12 ppg, P/U 160k, ROT
120k, S/O 88k, ADT 4.85, Total bit hrs
40.67, MPD connection back PSI 440.
Formation losses last 24 hours: 0 bbls
Total interval formation losses: 0 bbls
12,206.0 12,734.0
12/29/2023
00:00
12/29/2023
06:30
6.50 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 12,734’
MD to 13,172' MD / 5,199' TVD, WOB
9k, GPM 270, PSI 2895, RPM 140, TQ
13k, ECD 11.37 ppg, MWT 9.3+ ppg,
P/U 160k, ROT 120k, S/O 88k, ADT
5.17, Total bit hrs 45.84, MPD
connection back PSI 500.
12,734.0 13,172.0
12/29/2023
06:30
12/29/2023
07:45
1.25 PROD1, DRILL CIRC P Rot and recip pipe from 13,172' MD to
13,115' MD w/ GPM 260, PSI 2840,
RPM 110, TQ 10k, ECD 11.17 ppg,
MWT 9.3+ ppg. Total stks pumped -
5100 (514 bbls). Consult town Geo.
SIMPOS - pump Hi-Vis 10 ppg Nut Plug
sweep.
13,172.0 13,172.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 18/41
3S-624
Report Printed: 2/12/2024
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)
12/29/2023
07:45
12/29/2023
12:00
4.25 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 13,172’
MD to 13,404' MD / 5,202' TVD, WOB
8k, GPM 270, PSI 2874, RPM 130, TQ
12k, ECD 11.03 ppg, MWT 9.3+ ppg,
P/U 161k, ROT 116k, S/O 75k, ADT
3.84, Total bit hrs 49.27, MPD
connection back PSI 475.
13,172.0 13,404.0
12/29/2023
12:00
12/29/2023
15:45
3.75 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 13,404’
MD to 13,735' MD / 5,182' TVD, WOB
8k, GPM 270, PSI 2874, RPM 130, TQ
12k, ECD 11.03 ppg, MWT 9.3+ ppg,
P/U 161k, ROT 116k, S/O 75k, ADT
2.76, Total bit hrs 52.03, MPD
connection back PSI 475.
13,404.0 13,735.0
12/29/2023
15:45
12/29/2023
16:45
1.00 PROD1, DRILL CIRC P Rot and recip pipe from 13,735' MD to
13,695' MD w/ GPM 270, PSI 2854,
RPM 110, TQ 9.5k, ECD 10.87 ppg,
MWT 9.3 ppg. Total stks pumped - 3950
(398 bbls). Consult town Geo.
13,735.0 13,735.0
12/29/2023
16:45
12/30/2023
00:00
7.25 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 13,735’
MD to 14,139' MD / 5,196' TVD, WOB
7k, GPM 270, PSI 2289, RPM 100, TQ
10.8k, ECD 10.82 ppg, MWT 9.1+ ppg,
P/U 160k, ROT 112k, S/O N/A, ADT
5.63, Total bit hrs 57.75, MPD
connection back PSI 475. Slow RPM
and ROP to help mitigate deflections.
Formation losses last 24 hours: 0 bbls
Total interval formation losses: 0 bbls
13,735.0 14,139.0
12/30/2023
00:00
12/30/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 14,139’
MD to 14,402' MD / 5,181' TVD, WOB
4k, GPM 270, PSI 2845, RPM 100, TQ
10.5k, ECD 10.82 ppg, MWT 9.1+ ppg,
P/U 169k, ROT 106k, S/O N/A, ADT
5.25, Total bit hrs 63.00, MPD
connection back PSI 475.
14,139.0 14,402.0
12/30/2023
06:00
12/30/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 14,402’
MD to 14,804' MD / 5,158' TVD, WOB
7k, GPM 270, PSI 2915, RPM 120, TQ
12.5k, ECD 10.86 ppg, MWT 9.1+ ppg,
P/U 162k, ROT 107k, S/O N/A, ADT
4.81, Total bit hrs 67.81, MPD
connection back PSI 475.
14,402.0 14,804.0
12/30/2023
12:00
12/30/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 14,804’
MD to 15,264' MD / 5,154' TVD, WOB
9.5k, GPM 270, PSI 2957, RPM 120,
TQ 13k, ECD 11.05 ppg, MWT 9.1+
ppg, P/U 162k, ROT 107k, S/O N/A,
ADT 4.59, Total bit hrs 72.4. MPD
connections back PSI 475.
14,804.0 15,264.0
12/30/2023
18:00
12/31/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 15,264’
MD to 15,672' MD / 5,152' TVD, WOB
9.5k, GPM 270, PSI 2992, RPM 100,
TQ 12.2k, ECD 10.97 ppg, MWT 9.1+
ppg, P/U 160k, ROT 105k, S/O N/A,
ADT 4.63, Total bit hrs 77.03, MPD
connection back PSI 475.
Formation losses last 24 hours: 0 bbls
Total interval formation losses: 0 bbls
15,264.0 15,672.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 19/41
3S-624
Report Printed: 2/12/2024
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)
12/31/2023
00:00
12/31/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 15,672’
MD to 16,020' MD / 5,152' TVD, WOB
10k, GPM 270, PSI 3000, RPM 100, TQ
13.5k, ECD 10.96 ppg, MWT 9.1+ ppg,
P/U 164k, ROT 104k, S/O N/A, ADT
4.85, Total bit hrs 81.88, MPD
connection back PSI 475.
15,672.0 16,020.0
12/31/2023
06:00
12/31/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 16,020’
MD to 16,620' MD / 5,156' TVD, WOB
8k, GPM 270, PSI 3155, RPM 120, TQ
13.5k, ECD 11.47 ppg, MWT 9.1+ ppg,
P/U 167k, ROT 100k, S/O N/A, ADT
4.50, Total bit hrs 86.38, MPD
connection back PSI 500.
16,020.0 16,620.0
12/31/2023
12:00
12/31/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 16,620’
MD to 17,171' MD / 5,167' TVD, WOB
8.5k, GPM 270, PSI 3200, RPM 120,
TQ 13.5k, ECD 11.64 ppg, MWT 9.1+
ppg, P/U 172k, ROT 103k, S/O N/A,
ADT 4.37, Total bit hrs 90.75, MPD
connection back PSI 475.
16,620.0 17,171.0
12/31/2023
18:00
1/1/2024
00:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 17,171’
MD to 17,522' MD / 5,175' TVD, WOB
10k, GPM 270, PSI 3182, RPM 120, TQ
14k, ECD 11.45 ppg, MWT 9.1+ ppg,
P/U 183k, ROT 103k, S/O N/A, ADT
4.92, Total bit hrs 95.67, MPD
connection back PSI 475.
Formation losses last 24 hours: 0 bbls
Total interval formation losses: 0 bbls
17,171.0 17,522.0
1/1/2024
00:00
1/1/2024
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 17,522’
MD to 18,040' MD / 5,172' TVD, WOB
9k, GPM 270, PSI 3326, RPM 120, TQ
14.8k, ECD 11.74 ppg, MWT 9.2 ppg,
P/U 1187k, ROT 99k, S/O N/A, ADT
4.57, Total bit hrs 100.24, MPD
connection back PSI 475.
17,522.0 18,040.0
1/1/2024
06:00
1/1/2024
12:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 8,040’
MD to 18,542' MD / 5,170' TVD, WOB
9k, GPM 270, PSI 3412, RPM 120, TQ
14.5k, ECD 11.84 ppg, MWT 9.3 ppg,
P/U 192k, ROT 97k, S/O N/A, ADT 4.21,
Total bit hrs 104.45, MPD connection
back PSI 475.
18,040.0 18,542.0
1/1/2024
12:00
1/1/2024
18:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 18,542’
MD to 19,013' MD / 5,166' TVD, WOB
9k, GPM 270, PSI 3375, RPM 120, TQ
14.5k, ECD 11.86 ppg, MWT 9.3 ppg,
P/U 197k, ROT 101k, S/O N/A, ADT
4.65, Total bit hrs 109.10, MPD
connection back PSI 475.
18,542.0 19,013.0
1/1/2024
18:00
1/2/2024
00:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 19,013’
MD to 19,457' MD / 5,162' TVD, WOB
8k, GPM 270, PSI 3440, RPM 120, TQ
14k, ECD 11.98 ppg, MWT 9.4 ppg, P/U
192k, ROT 98k, S/O N/A, ADT 4.82,
Total bit hrs 113.92, MPD connection
back PSI 390.
Formation losses last 24 hours: 0 bbls
Total interval formation losses: 0 bbls
19,013.0 19,457.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 20/41
3S-624
Report Printed: 2/12/2024
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)
1/2/2024
00:00
1/2/2024
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 19,457’
MD to 19,877' MD / 5,154' TVD, WOB
7k, GPM 270, PSI 3505, RPM 140, TQ
13.8k, ECD 12.10 ppg, MWT 9.2+ ppg,
P/U 195k, ROT 100k, S/O N/A, ADT
4.59, Total bit hrs 118.51, MPD
connection back PSI 380.
19,457.0 19,877.0
1/2/2024
06:00
1/2/2024
12:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 19,877’
MD to 20,309' MD / 5,154' TVD, WOB
9k, GPM 270, PSI 3529, RPM 120, TQ
14k, ECD 12.1 ppg, MWT 9.3 ppg, P/U
195k, ROT 100k, S/O N/A, ADT 4.54,
Total bit hrs 123.05, MPD connection
back PSI 380.
19,877.0 20,309.0
1/2/2024
12:00
1/2/2024
14:45
2.75 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 20,309’
MD to 20,485' MD / 5,155' TVD, WOB
8k, GPM 270, PSI 3543, RPM 120, TQ
13.5k, ECD 12.04 ppg, MWT 9.3 ppg,
P/U 217k, ROT 107k, S/O N/A, ADT
2.34, Total bit hrs 125.39, MPD
connection back PSI 380.
20,309.0 20,485.0
1/2/2024
14:45
1/2/2024
15:00
0.25 PROD1, TRIPCAS CIRC P Obtain final survey, SPR's, and T&D
values. Downlink powerdrive to neutral.
20,485.0 20,485.0
1/2/2024
15:00
1/2/2024
19:30
4.50 PROD1, TRIPCAS CIRC P Conduct wellbore clean up cycles. Circ
3x B/U per stand while POOH from
20,485' MD to 20,443' MD w/ GPM 270,
PSI 3541, RPM 120, TQ 11.5k, ECD
12.04 ppg, MWT 9.3 ppg, UP WT @
rate - 105K.
NOTE: Field in phase 3 weather
conditions @ 17:05 hrs.
20,485.0 20,443.0
1/2/2024
19:30
1/2/2024
21:00
1.50 PROD1, TRIPCAS CIRC P Observe slight packoff and tq swings at
20,443' MD. Reduce rate to 254 GPM,
3246 PSI, 120 RPM, 12k tq, Max ECD
13.71 and successfully work by issue up
to 20,412' MD.
20,443.0 20,412.0
1/2/2024
21:00
1/3/2024
00:00
3.00 PROD1, TRIPCAS CIRC P Continue with wellbore clean up cycles.
Circ 3x B/U per stand while POOH from
20,412' MD to 20,344' MD w/ GPM 270,
PSI 3590, RPM 120, TQ 11.5k, ECD
11.84 ppg, MWT 9.3 ppg, UP WT @
rate - 105K.
Total wellbore clean up strokes - 33,860
(3410 bbls)
20,412.0 20,344.0
1/3/2024
00:00
1/3/2024
06:00
6.00 PROD1, TRIPCAS CIRC P Continue with wellbore clean up cycles.
Circ 3x B/U per stand while POOH from
20,344' MD to 20,269' MD w/ GPM 270,
PSI 3618, RPM 120, TQ 11.3k, ECD
11.77 ppg, MWT 9.3 ppg, UP WT @
rate - 105K. Total wellbore clean up
strokes - 54,306 (5469 bbls).
20,344.0 20,269.0
1/3/2024
06:00
1/3/2024
11:15
5.25 PROD1, TRIPCAS CIRC P Continue with wellbore clean up cycles.
Circ 3x B/U per stand while POOH from
20,269' MD to 20,201' MD w/ GPM 270,
PSI 3649, RPM 120, TQ 12.1k, ECD
11.77 ppg, MWT 9.3 ppg, UP WT @
rate - 105K. Total wellbore clean up
strokes - 77,069 (7761 bbls) = 14 B/U
total.
20,269.0 20,201.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 21/41
3S-624
Report Printed: 2/12/2024
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)
1/3/2024
11:15
1/3/2024
18:00
6.75 PROD1, TRIPCAS CIRC T Decision made to reduce rate and wait
on weather. Rot and recip pipe from
20,201' MD to 20,150' MD w/ GPM 100,
PSI 1034, RPM 10, TQ 12.8k, MWT 9.4
ppg, UP WT @ rate - 105K. Keeping
40 psi on wellbore via MPD = 11.25
EMW at bit and 10.11 at the shoe.
Observe 5 bph loss rate.
20,201.0 20,201.0
1/3/2024
18:00
1/4/2024
00:00
6.00 PROD1, TRIPCAS CIRC T Continue to wait on weather. Rot and
recip pipe from 20,201' MD to 20,124'
MD w/ GPM 100, PSI 1034, RPM 10,
TQ 12.8k, MWT 9.4 ppg, UP WT @ rate
- 105K. Reduce wellbore psi to 0 - ECD
= 11.1 EMW at bit and 9.96 EMW at the
shoe. Continue to observe 5 bph loss
rate.
Formation losses last 24 hours: 52 bbls
Total interval formation losses: 52 bbls
20,201.0 20,201.0
1/4/2024
00:00
1/4/2024
06:00
6.00 PROD1, TRIPCAS CIRC T Continue to wait on weather. Rot and
recip pipe from 20,197' MD to 20,125'
MD w/ GPM 100, PSI 1049, RPM 10,
TQ 12.8k, MWT 9.4 ppg, UP WT @ rate
- 105K. Total stks pumped = 7,928 (798
bbls). Observe 5 bph loss rate.
20,197.0 20,197.0
1/4/2024
06:00
1/4/2024
12:00
6.00 PROD1, TRIPCAS CIRC T Continue to wait on weather. Rot and
recip pipe from 20,197' MD to 20,125'
MD w/ GPM 100, PSI 1072, RPM 10,
TQ 12.4k, MWT 9.4 ppg, UP WT @ rate
- 105K. Total stks pumped = 8,974 (904
bbls). Observe 5 bph loss rate.
20,197.0 20,197.0
1/4/2024
12:00
1/4/2024
18:00
6.00 PROD1, TRIPCAS CIRC T Continue to wait on weather. Rot and
recip pipe from 20,197' MD to 20,125'
MD w/ GPM 100, PSI 1072, RPM 10,
TQ 12.4k, MWT 9.4 ppg, UP WT @ rate
- 105K. Total stks pumped = 8974 (904
bbls). Observe 5 bph loss rate.
Begin to add maintenance fluid @ 17:30
hrs @ 10 BPH.
20,197.0 20,197.0
1/4/2024
18:00
1/5/2024
00:00
6.00 PROD1, TRIPCAS CIRC T Continue to wait on weather. Rot and
recip pipe from 20,189' MD to 20,128'
MD w/ GPM 100, PSI 1071, RPM 10,
TQ 12.4k, MWT 9.4 ppg, UP WT @ rate
- 105K. Total stks pumped = 9180 (925
bbls) Continue to observe 5 bph loss
rate.
Total stks at 100 gpm last 24 hrs =
35,056 (3530 bbls)
Cumulative stks at 100 gpm = 80,339
(8090 bbls)
Formation losses last 24 hours: 98 bbls
Total interval formation losses: 150 bbls
20,189.0 20,189.0
1/5/2024
00:00
1/5/2024
06:00
6.00 PROD1, TRIPCAS CIRC T Continue to wait on weather. Rot and
recip pipe from 20,189' MD to 20,128'
MD w/ GPM 100, PSI 1045, RPM 10,
TQ 12.4k, MWT 9.4 ppg, UP WT @ rate
- 105K. Total stks pumped = 9105 (917
bbls). Observe 4 bph loss rate.
20,189.0 20,189.0
1/5/2024
06:00
1/5/2024
12:00
6.00 PROD1, TRIPCAS CIRC T Continue to wait on weather. Rot and
recip pipe from 20,189' MD to 20,128'
MD w/ GPM 100, PSI 993, RPM 10, TQ
12.5k, MWT 9.4 ppg, UP WT @ rate -
105K. Total stks pumped = 8997 (904
bbls). Observe 4 bph loss rate.
20,189.0 20,189.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 22/41
3S-624
Report Printed: 2/12/2024
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)
1/5/2024
12:00
1/5/2024
18:00
6.00 PROD1, TRIPCAS CIRC T Continue to wait on weather. Rot and
recip pipe from 20,189' MD to 20,128'
MD w/ GPM 100, PSI 993, RPM 10, TQ
12.5k, MWT 9.4 ppg, UP WT @ rate -
105K. Total stks pumped = 9323 (939
bbls). Observe 4 bph loss rate.
20,189.0 20,189.0
1/5/2024
18:00
1/5/2024
18:30
0.50 PROD1, TRIPCAS REAM T Wash and ream to bottom from 20,189'
MD to 20.483' MD w/ GPM 100, PSI
990, RPM 30, TQ 14K. S/O WT @ rate -
95K.
20,189.0 20,483.0
1/5/2024
18:30
1/5/2024
20:30
2.00 PROD1, TRIPCAS CIRC T Continue to wait on weather. Rot and
recip pipe from 20,481' MD to 20,447'
MD w/ GPM 100, PSI 993, RPM 10, TQ
13k, MWT 9.4 ppg, UP WT @ rate -
108K. Total stks pumped = 2580 (260
bbls). Observe 4 bph loss rate.
20,481.0 20,481.0
1/5/2024
20:30
1/6/2024
00:00
3.50 PROD1, TRIPCAS CIRC T Continue to wait on weather. Rot and
recip pipe from 20,478' MD to 20,415'
MD w/ GPM 100, PSI 993, RPM 10, TQ
13k, MWT 9.4 ppg, UP WT @ rate -
105K. Total stks pumped = 5235 (527
bbls) Continue to observe 4 bph loss
rate.
Prep 10-3/4" X 7-5/8" OA for freeze
protect. Pump 1 bbl of 9.4 ppg
KlaShield @ .5 bpm, observe breakover
@ 650 psi. Cont to pump additional 1
bbl @ .5 bpm w/ FCP of 620 psi. Shut
in and observe psi drop to 429 in 10
min. R/D injection line and R/U LRS.
Total stks at 100 gpm last 24 hrs =
35,240 (3549 bbls)
Cumulative stks at 100 gpm = 115,579
(11,639 bbls)
Formation losses last 24 hours: 82 bbls
Total interval formation losses: 260
bbls
20,478.0 20,478.0
1/6/2024
00:00
1/6/2024
06:00
6.00 PROD1, TRIPCAS CIRC T Continue to wait on weather. Rot and
recip pipe from 20,478' MD to 20,415'
MD w/ GPM 100, PSI 1010, RPM 10,
TQ 12k, MWT 9.4 ppg, UP WT @ rate -
108K. Total stks pumped = 8999 (906
bbls). Observe 4 bph loss rate.
SIMOPS - Freeze protect 10-3/4" x 7-
5/8" OA via LRS. Pump 80 bbls of 6.8
ppg diesel staging pump up to 1.2 bpm
ICP - 950, FCP - 1260. Observe
pressure decrease to 795 in 20 min.
20,478.0 20,478.0
1/6/2024
06:00
1/6/2024
08:00
2.00 PROD1, TRIPCAS CIRC T Continue to wait on weather. Rot and
recip pipe from 20,478' MD to 20,415'
MD w/ GPM 100, PSI 1010, RPM 10,
TQ 12k, MWT 9.4 ppg, UP WT @ rate -
108K. Total stks pumped = 3069 (309
bbls). Observe 4 bph loss rate.
20,478.0 20,478.0
1/6/2024
08:00
1/6/2024
11:00
3.00 PROD1, TRIPCAS CIRC T Stage pumps up to 220 GPM and pump
28 bbl LCM pill w/ PSI 2854, RPM 10,
TQ 12.8k, MWT 9.4 ppg, ECD 11.76.
Total stks pumped = 7789 (784 bbls).
20,478.0 20,478.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 23/41
3S-624
Report Printed: 2/12/2024
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)
1/6/2024
11:00
1/6/2024
18:00
7.00 PROD1, TRIPCAS CIRC T Continue to wait on weather. Rot and
recip pipe from 20,478' MD to 20,415'
MD w/ GPM 100, PSI 1010, RPM 10,
TQ 12k, MWT 9.4 ppg, UP WT @ rate -
105K. Total stks pumped = 10,174
(1024 bbls). Observe 4 bph loss rate.
20,478.0 20,478.0
1/6/2024
18:00
1/7/2024
00:00
6.00 PROD1, TRIPCAS CIRC T Continue to wait on weather. Rot and
recip pipe from 20,481' MD to 20,447'
MD w/ GPM 100, 1010 PSI , RPM 10,
TQ 13k, MWT 9.4 ppg, UP WT @ rate -
105K. Total stks pumped = xx (xx bbls).
Observe 4 bph loss rate.
Formation losses last 24 hours: 117
bbls
Total interval formation losses: 377
bbls
20,478.0 20,478.0
1/7/2024
00:00
1/7/2024
06:00
6.00 PROD1, TRIPCAS CIRC T Continue to wait on weather. Rot and
recip pipe from 20,484' MD to 20,420'
MD w/ GPM 100, 975 PSI , RPM 10, TQ
12k, MWT 9.4+ ppg, UP WT @ rate -
107K. Total stks pumped = 8605 (866
bbls). Observe 4 bph loss rate.
20,484.0 20,484.0
1/7/2024
06:00
1/7/2024
12:00
6.00 PROD1, TRIPCAS CIRC T Continue to wait on weather. Rot and
recip pipe from 20,484' MD to 20,420'
MD w/ GPM 100, 975 PSI , RPM 10, TQ
12.5k, MWT 9.5 ppg, UP WT @ rate -
109K. Total stks pumped = 8604 (866
bbls). Observe 4 bph loss rate.
20,484.0 20,484.0
1/7/2024
12:00
1/7/2024
18:00
6.00 PROD1, TRIPCAS CIRC T Continue to wait on weather. Rot and
recip pipe from 20,484' MD to 20,420'
MD w/ GPM 100, 975 PSI , RPM 10, TQ
12.5k, MWT 9.5 ppg, UP WT @ rate -
109K. Total stks pumped = 8711 (877
bbls). Observe 4 bph loss rate.
20,484.0 20,484.0
1/7/2024
18:00
1/8/2024
00:00
6.00 PROD1, TRIPCAS CIRC T Continue to wait on weather. Rot and
recip pipe from 20,482' MD to 20,442'
MD w/ GPM 100, 1005 PSI , RPM 10,
TQ 12.5k, MWT 9.5 ppg, UP WT @ rate
- 107K. Total stks pumped = 8711 (877
bbls). Observe 4 bph loss rate.
Formation losses last 24 hours: 101
bbls
Total interval formation losses: 478
bbls
20,482.0 20,482.0
1/8/2024
00:00
1/8/2024
06:00
6.00 PROD1, TRIPCAS CIRC T Continue to wait on weather. Rot and
recip pipe from 20,480' MD to 20,444'
MD w/ GPM 100, 1002 PSI , RPM 10,
TQ 12.5k, MWT 9.5 ppg, UP WT @ rate
- 107K. Total stks pumped = 8625 (869
bbls). Observe 4 bph loss rate.
20,480.0 20,480.0
1/8/2024
06:00
1/8/2024
07:00
1.00 PROD1, TRIPCAS CIRC T Continue to wait on weather. Rot and
recip pipe from 20,480' MD to 20,444'
MD w/ GPM 100, 1002 PSI , RPM 10,
TQ 12.5k, MWT 9.5 ppg, UP WT @ rate
- 107K. Total stks pumped = 1680 (169
bbls). Observe 4 bph loss rate.
20,480.0 20,480.0
1/8/2024
07:00
1/8/2024
11:00
4.00 PROD1, TRIPCAS SFTY T Complete derrick inspection after Phase
3. Repair energy track.
20,485.0 20,485.0
1/8/2024
11:00
1/8/2024
14:45
3.75 PROD1, TRIPCAS CIRC T Circ 2.5x B/U w/ GPM 265, 3869 PSI ,
RPM 120, TQ 13.2k, MWT 9.5 ppg,
ECD - 12.5, UP WT @ rate - 100K.
Total stks pumped = 13,780 (1388 bbls).
Note: Observing pulvarized cuttings
retuns at B/U.
20,485.0 20,485.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 24/41
3S-624
Report Printed: 2/12/2024
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)
1/8/2024
14:45
1/8/2024
16:15
1.50 PROD1, TRIPCAS DISP P Disp open hole to new 9.5 ppg Kla-
Shield w/ GPM 265, 3408 PSI , RPM 85,
TQ 12.4k, MWT 9.5 ppg, ECD - 12.5,
UP WT @ rate - 100K. Total stks
pumped = 6826 (687 bbls).
20,485.0 20,485.0
1/8/2024
16:15
1/8/2024
20:30
4.25 PROD1, TRIPCAS SMPD P Strip OOH from 20,485' MD to 18,205'
MD following Beyond stripping
schedule. 400 psi pulling and 270 psi in
slips. Up WT - 207K. Monitor disp via
active pit system #1-5.
Observe steady overpull of 20-30K w/
intermittent overpull of 40-60K from
18,920' to 18,205' MD. Decision made
to ream in the hole to 18,980' MD and
BROOH up to 12,500' MD.
20,485.0 18,205.0
1/8/2024
20:30
1/8/2024
23:30
3.00 PROD1, TRIPCAS REAM P RIH with rotation/low flow from 18,205'
MD to 18,980' MD w/ GPM 100, 980
PSI , RPM 30, TQ 114k. S/O wt - 94K.
Note: Lost SO weight at 13,700’ MD
while drilling.
18,205.0 18,980.0
1/8/2024
23:30
1/9/2024
00:00
0.50 PROD1, TRIPCAS BKRM P BROOH from 18,980' MD to 18,937' MD
staging pumps up to 220 GPM, ICP -
1308, FCP - 2708, ECD - 11.82, RPM
100, TQ 11k, Up wt @ rate - 102K.
MPD holding 270 @ connections.
Note: Observe pulvarized
cuttings/sludge at the shakers.
Formation losses last 24 hours: 157
bbls
Total interval formation losses: 635 bbls
18,980.0 18,937.0
1/9/2024
00:00
1/9/2024
06:00
6.00 PROD1, TRIPCAS BKRM P BROOH from 18,937' MD to 17,901' MD
w/ 250 GPM, 3000 PSI, ECD - 11.92,
RPM 120, TQ 12k, Up wt @ rate - 102K.
MPD holding 240 @ connections (10.5
EMW).
18,937.0 17,901.0
1/9/2024
06:00
1/9/2024
12:00
6.00 PROD1, TRIPCAS BKRM P BROOH from 17,901' MD to 16,341 MD
w/ 250 GPM, 3030 PSI, ECD - 11.40,
RPM 120, TQ 12k, Up wt @ rate - 103K.
MPD holding 250 @ connections (10.5
EMW).
17,901.0 16,341.0
1/9/2024
12:00
1/9/2024
18:00
6.00 PROD1, TRIPCAS BKRM P BROOH from 16,341 MD to 14,980 w/
250 GPM, 2850 PSI, ECD - 11.30, RPM
120, TQ 11k, Up wt @ rate - 102K.
MPD holding 230 @ connections (10.5
EMW).
16,341.0 14,980.0
1/9/2024
18:00
1/10/2024
00:00
6.00 PROD1, TRIPCAS BKRM P BROOH from 14,980 MD to 13,396 w/
250 GPM, 2750 PSI, ECD - 11.22, RPM
120, TQ 11k, Up wt @ rate - 112K.
MPD holding 230 @ connections (10.5
EMW).
Note: Observe mixture of mud additives
and pulvarized cuttings at the shakers.
Formation losses last 24 hours: 217 bbls
Total interval formation losses: 852 bbls
14,980.0 13,396.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 25/41
3S-624
Report Printed: 2/12/2024
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)
1/10/2024
00:00
1/10/2024
04:30
4.50 PROD1, TRIPCAS BKRM P BROOH from 13,396' MD to 12,179' MD
w/ 250 GPM, 2500 PSI, ECD - 11.22,
RPM 120, TQ 11k, Up wt @ rate - 118K.
MPD holding 230 @ connections (10.5
EMW).
Note: L/D stds via mousehole. Continue
to see small pulverized cuttings at the
shaker.
13,396.0 12,179.0
1/10/2024
04:30
1/10/2024
08:00
3.50 PROD1, TRIPCAS CIRC P Circ 3X B/U while reaming up from
12,179' MD to 11,881' MD w/ 250 GPM,
2390 PSI, ECD - 11.22, RPM 120, TQ
9.5k, Up wt @ rate - 125K. Total stks
pumped - 10,320 (1039 bbls).
Note: L/D stds via mousehole. Continue
to see small pulverized cuttings at the
shaker.
12,179.0 11,881.0
1/10/2024
08:00
1/10/2024
08:45
0.75 PROD1, TRIPCAS SMPD P Strip OOH from 11,881' MD to 11,650'
MD maintaining 10.0 ppg mud wt as per
MPD stripping schedule. Observed 20-
30K drag w/ 60K max.
Decision made to RIH to 11,693' MD
and BROOH.
11,881.0 11,693.0
1/10/2024
08:45
1/10/2024
12:00
3.25 PROD1, TRIPCAS BKRM P BROOH from 11,693' MD to 10,808' MD
w/ 250 GPM, 2350 PSI, ECD - 10.57,
RPM 120, TQ 8.3k, Up wt @ rate -
132K. MPD holding 150 @ connections
(10.5 EMW).
Note: L/D stds via mousehole. Continue
to see small pulverized cuttings at the
shaker.
11,693.0 10,808.0
1/10/2024
12:00
1/10/2024
18:00
6.00 PROD1, TRIPCAS BKRM P BROOH from 10,808' MD to 8,923' MD
w/ 250 GPM, 2170 PSI, ECD - 10.38,
RPM 120, TQ 7k, Up wt @ rate - 130K.
MPD holding 150 @ connections (10.5
EMW).
Note: L/D stds via mousehole. Continue
to see small pulverized cuttings at the
shaker.
10,808.0 8,923.0
1/10/2024
18:00
1/10/2024
19:30
1.50 PROD1, TRIPCAS BKRM P BROOH from 8,923' MD to 8,505' MD w/
250 GPM, 2135 PSI, ECD - 10.31, RPM
80, TQ 5k, Up wt @ rate - 135K. MPD
holding 150 @ connections (10.5 EMW).
Note: L/D stds via mousehole. Continue
to see small pulverized cuttings at the
shaker.
8,923.0 8,505.0
1/10/2024
19:30
1/10/2024
22:00
2.50 PROD1, TRIPCAS BKRM P Encounter pressure fluctuations (~100
psi spikes) and tq swings @ landing
point of the lower Moraine formation @
8,505' MD. Work drill string down to
8,577' MD(x2) and adj parameters to
work up through trouble zone starting at
8,505' MD. Adj pulling speeds from 60'
hr to 300' hr and RPMs from 80-110.
Successfully work past trouble zone up
to 8,482' MD w/ 80 RPM, 250 GPM, 300
ft/hr.
Note: Observe fine cuttings returns at
shakers.
8,505.0 8,482.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 26/41
3S-624
Report Printed: 2/12/2024
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)
1/10/2024
22:00
1/11/2024
00:00
2.00 PROD1, TRIPCAS BKRM P BROOH from 8,482' MD to 8,164' MD w/
250 GPM, 2112 PSI, ECD - 10.34, RPM
80, TQ 5k, Up wt @ rate - 138K. MPD
holding 150 @ connections (10.5 EMW).
Formation losses last 24 hours: 140 bbls
Total interval formation losses: 992 bbls
Note: L/D stds via mousehole. Continue
to see small pulverized cuttings at the
shaker.
8,482.0 8,164.0
1/11/2024
00:00
1/11/2024
02:45
2.75 PROD1, TRIPCAS BKRM P BROOH from 8,164' MD to 7,781' MD w/
250 GPM, 2112 PSI, ECD - 10.34, RPM
80, TQ 5k, Up wt @ rate - 139K. MPD
holding 120 @ connections (10.5 EMW).
Note: L/D stds via mousehole. Continue
to see small pulverized cuttings at the
shaker.
8,164.0 7,781.0
1/11/2024
02:45
1/11/2024
04:30
1.75 PROD1, TRIPCAS PMPO P Pump OOH f/ 7,781' MD to 7,543' MD
w/ 250 GPM, 2046 PSI, ECD - 10.34,
RPM 10, TQ 5k, Up wt @ rate - 145K.
MPD holding 120 @ connections (10.5
EMW).
Note: Attempt to Pump OOH w/o
rotation. Observe 40K overpull.
Decision made to rotate at 10 rpm and
work into the shoe.
7,781.0 7,543.0
1/11/2024
04:30
1/11/2024
05:45
1.25 PROD1, TRIPCAS CIRC P Rot and Recip pipe from 7,543' MD to
7,448' MD circ B/U (2x) w/ 270 GPM,
2378 PSI, 100 RPM, 4k TQ. Rot wt
143K. Total stks pumped - 4967 (500
bbls).
7,543.0 7,543.0
1/11/2024
05:45
1/11/2024
06:15
0.50 PROD1, TRIPCAS CIRC P Drop 1.75 OD steel ball to open well
commander. Pump ball at 80 GPM, 374
PSI, 10 RPM, 4.6k TQ. Ball on seat @
307 stks with 1500 psi. Increase
pressure to 3275 and observe pressure
dump confirming well commander open.
SIMOPS - L/D 4" DP stds off the DS of
the derrick.
7,543.0 7,543.0
1/11/2024
06:15
1/11/2024
08:00
1.75 PROD1, TRIPCAS CIRC P Rot and Recip pipe from 7,530' MD to
7,450' MD circ B/U (2x) w/ 580 GPM,
4130 PSI, 120 RPM, 5k TQ. Rot wt
143K. Pump Hi-Vis sweep. Total stks
pumped - 12,318 (1240 bbls).
Note: Observe significant amount of
PDC cuttings at the shaker on first B/U.
7,530.0 7,530.0
1/11/2024
08:00
1/11/2024
16:30
8.50 PROD1, TRIPCAS RGRP T Observe damage to energy track of the
top drive. Repair damage and inspect
energy track. Attach secondary
restraints to cable saddles.
SIMOPS - L/D 4" DP stds off the DS of
the derrick. Circ w/ 210 GPM, 650 PSI.
Rot drill string periodically to insure free
pipe. Load pipeshed w/ 4 and 4½ test
jts. Service pipe skate. Stage MPD
source box on the rig floor.
7,530.0 7,530.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 27/41
3S-624
Report Printed: 2/12/2024
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)
1/11/2024
16:30
1/11/2024
17:45
1.25 PROD1, TRIPCAS CIRC P Rot and Recip pipe from 7,530' MD to
7,450' MD circ Hi-Vis sweep w/ 600
GPM, 4005 PSI, 100 RPM, 4k TQ. Rot
wt 134K. Pump Hi-Vis sweep. Total stks
pumped - 7300 (735 bbls).
Note: Observe small pulverized cuttings
at the shaker.
7,530.0 7,530.0
1/11/2024
17:45
1/11/2024
18:45
1.00 PROD1, TRIPCAS OWFF P Relax wellbore and OWFF. SIMOPS -
B/D TD.
7,530.0 7,530.0
1/11/2024
18:45
1/11/2024
19:15
0.50 PROD1, TRIPCAS SMPD P Attempt to Strip OOH. Observe upper
flapper floats not holding. Drop 1.75
OD steel ball to close well commander.
Pump ball at 84 GPM, 278 psi. Ball on
seat at 310 stks w/1500 psi. Pressure
up to 2460 psi @ 200 psi increments
and observe tool shift close. Confrim
with 250 GPM, 1984 PSI and observe
coms with MWD tools. B/D TD. Attempt
to Strip OOH and observe flapper and
plunger floats not holding. Kelly up and
pressure up on std pipe. Rotate string
at 10 RPM, dump std pipe pressure, and
successfully close floats.
7,543.0 7,543.0
1/11/2024
19:15
1/12/2024
00:00
4.75 PROD1, TRIPCAS SMPD P Strip OOH from 7,543' MD to 3,295' MD
following Beyond MPD stripping
schedule maintaining 9.7 ppg EMW at
the shoe. Monitor disp via Pit #1. UP
WT - 85K, S/O W - 73K.
Formation losses last 24 hours: 0 bbls
Total interval formation losses: 992 bbls
7,543.0 3,295.0
1/12/2024
00:00
1/12/2024
02:30
2.50 PROD1, TRIPCAS SMPD P Strip OOH from 3,295' MD to 322' MD
following Beyond MPD stripping
schedule maintaining 9.7 ppg EMW at
the shoe. Monitor disp via Pit #1. UP
WT - 52K.
3,295.0 322.0
1/12/2024
02:30
1/12/2024
03:15
0.75 PROD1, TRIPCAS OWFF P OWFF - Static. 322.0 322.0
1/12/2024
03:15
1/12/2024
04:45
1.50 PROD1, TRIPCAS MPDA P Pull MPD drip nipple, bearing, and
install trip nipple.
322.0 322.0
1/12/2024
04:45
1/12/2024
05:30
0.75 PROD1, TRIPCAS TRIP P POOH on elevators from 322' MD to
192' MD. Monitor disp via TT. Up wt -
47K.
322.0 192.0
1/12/2024
05:30
1/12/2024
08:00
2.50 PROD1, TRIPCAS BHAH P L/D production BHA from 192' MD as
per SLB DD/MWD.
192.0 0.0
1/12/2024
08:00
1/12/2024
09:45
1.75 PROD1, TRIPCAS BHAH P Clear and clean rig floor. 0.0 0.0
1/12/2024
09:45
1/12/2024
10:30
0.75 PROD1, WHDBOP RURD P Pull wear bushing as per Cameron rep. 0.0 0.0
1/12/2024
10:30
1/12/2024
11:45
1.25 PROD1, WHDBOP WWWH P Flush BOPE w/ 680 GPM, 15 RPM.
Passing through stack 3x. B/D surface
lines/MPD choke and injection lines.
0.0 0.0
1/12/2024
11:45
1/12/2024
12:00
0.25 PROD1, WHDBOP RURD P Install test plug as per Cameron rep. 0.0 0.0
1/12/2024
12:00
1/12/2024
13:00
1.00 PROD1, WHDBOP RURD P R/U to test BOPE. 0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 28/41
3S-624
Report Printed: 2/12/2024
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)
1/12/2024
13:00
1/12/2024
19:30
6.50 PROD1, 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 1,500 psi. With the 4½" test jt, test
Annular, 3½" x 6" upr & lwr pipe rams,
choke valves 1-14, manual operated
and super choke, choke & kill manuals
and HCR's, 4" kill line, 4" FOSV (x2), 4"
dart valve. Perform koomey drawdown -
acc - 3000 psi, manifold - 1500 psi, acc -
1850 after all functions, 4 sec for 200 psi
build w/ 2 elec pumps, 46 sec to build
full system psi w/ 2 elec pumps and 2 air
pumps. Closing times for annular - 23
sec, upr - 18 sec, blind / shears - 16
sec, lwr - 16 sec, choke HCR - 2 sec, kill
HCR - 2 sec. 6 bottle nitrogen backup
ave. - 2000 psi. Test PVT gain/loss and
flow out alarms. Test LEL and H2S
alarms. AOGCC rep Austin MCLeod
waived witness to the test @ 15:32 on
1/11/24.
0.0 0.0
1/12/2024
19:30
1/12/2024
20:00
0.50 PROD1, WHDBOP EQRP T Lose hi-line power to the rig. Fire up
3512 cat engine and restore power to
the rig.
0.0 0.0
1/12/2024
20:00
1/12/2024
22:00
2.00 PROD1, WHDBOP BOPE P With 4” test jt test Annular, 3½” x 6” upr
& lwr pipe rams, upr & lwr IBOP, HCR
and Manual Choke.
Note: Kuparuk field in Phase 3
conditions @ 20:30 hrs.
0.0 0.0
1/12/2024
22:00
1/12/2024
22:45
0.75 PROD1, WHDBOP RURD P Kuparuk field in Phase 3 condtions.
SIMOPS - Pull test plug and install 10"
ID wear bushing. RILDS (x2).
0.0 0.0
1/12/2024
22:45
1/12/2024
23:45
1.00 PROD1, WHDBOP RURD P Kuparuk field in Phase 3 conditions.
SIMOPS - L/D 4" test jt. B/D all
associated tests lines, choke manifold
and kill line. Line up manifold for drilling
ops. Drain stack of test water.
0.0 0.0
1/12/2024
23:45
1/13/2024
00:00
0.25 COMPZN, CASING WAIT T Kuparuk field in Phase 3 conditions.
SIMOPS - Line up pit #1 and monitor
wellbore.
0.0 0.0
1/13/2024
00:00
1/13/2024
05:00
5.00 COMPZN, CASING WAIT T Kuparuk field in Phase 3 conditions.
SIMOPS - Monitor wellbore via pit #1.
General housekeeping.
0.0 0.0
1/13/2024
05:00
1/13/2024
12:00
7.00 COMPZN, CASING RURD T Kuparuk field in Phase 2 conditions.
SIMOPS - Monitor wellbore via pit #1.
Expedite Baker frac sleeves to the rig
floor and drift. Complete MP-2 rig
maintenance and service rig floor
handling equipment.
0.0 0.0
1/13/2024
12:00
1/13/2024
18:00
6.00 COMPZN, CASING RURD T Kuparuk field in Phase 2 conditions.
SIMOPS - Monitor wellbore via pit #1.
Expedite Doyon Csg handling
equipment to the rig floor. Test run
double stack power tongs. C/O shaker
isolation knife valve. QC connections
on frac tree.
0.0 0.0
1/13/2024
18:00
1/13/2024
18:45
0.75 COMPZN, CASING RURD P QC running order in pipe shed. QC
handling equipment on the rig floor.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 29/41
3S-624
Report Printed: 2/12/2024
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)
1/13/2024
18:45
1/13/2024
21:30
2.75 COMPZN, CASING PUTB P RIH w/ 4½ Hyd563-MS lower
completion as per detail floating to
1,036' MD. Monitor disp via Pit #1. S/O
WT - 54K. Tq all connections to 5500
ft/lbs.
0.0 1,036.0
1/13/2024
21:30
1/13/2024
22:00
0.50 COMPZN, CASING OWFF P OWFF - Conduct inflow test @ 1,036'
MD, confirming floats holding.
1,036.0 1,036.0
1/13/2024
22:00
1/13/2024
23:45
1.75 COMPZN, CASING PUTB P RIH w/ 4½ Hyd563-MS lower
completion as per detail floating from
1,036' MD to 2,203' MD. Monitor disp
via Pit #1. S/O WT - 56K. Tq all
connections to 5500 ft/lbs.
1,036.0 2,203.0
1/13/2024
23:45
1/14/2024
00:00
0.25 COMPZN, CASING OWFF P OWFF - Conduct inflow test @ 2,203'
MD, confirming floats holding.
SIMOPS - Inspect top drive energy
track.
2,203.0 2,203.0
1/14/2024
00:00
1/14/2024
00:15
0.25 COMPZN, CASING OWFF P OWFF - Conduct inflow test @ 2,203'
MD, confirming floats holding. SIMOPS
- Inspect top drive energy track.
2,203.0 2,203.0
1/14/2024
00:15
1/14/2024
06:00
5.75 COMPZN, CASING PUTB P RIH w/ 4½ Hyd563-MS lower
completion as per detail floating from
2,203 MD to 5,748' MD. Monitor disp
via Pit #1. S/O WT - 72K. Tq all
connections to 5500 ft/lbs.
Note: Change out swell pkr #6 w/
backup swell pkr #25 @ 3,103' MD, due
to machined grooves cut in sealing
surface of #6.
2,203.0 5,748.0
1/14/2024
06:00
1/14/2024
11:00
5.00 COMPZN, CASING PUTB P RIH w/ 4½ Hyd563-MS lower
completion as per detail floating from
5,748 MD to 8,283' MD. Monitor disp
via Pit #1. P/U WT - 72K S/O WT - 67K.
Tq all connections to 5500 ft/lbs.
Note: Tight spot @ 7,998', 8,241'.
Losing all S/O WT. Attempt to work past
obstruction 2X (failed). Rot string 1/4
turn and successfully work past
obstruction. Obtain T&D at the 7-5/8"
shoe @ 7,556' MD = P/U WT - 75K, S/O
WT - 67K, Rot WT - 68K, 20 RPM =
2.4K Tq, 30 RPM = 2.5K Tq.
5,748.0 8,283.0
1/14/2024
11:00
1/14/2024
11:30
0.50 COMPZN, CASING OWFF P OWFF - Conduct inflow test @ 8,283'
MD, confirming floats holding w/ 5 RPM,
2K Tq.
8,283.0 8,283.0
1/14/2024
11:30
1/14/2024
17:45
6.25 COMPZN, CASING PUTB P RIH w/ 4½ Hyd563-MS lower
completion as per detail floating from
8,283 MD to 13,052' MD. Monitor disp
via Pit #1. S/O WT - 55K. Tq all
connections to 5500 ft/lbs.
8,283.0 13,052.0
1/14/2024
17:45
1/14/2024
18:15
0.50 COMPZN, CASING OTHR P P/U and M/U Baker SLZXP. RIH to
13,081' MD. S/O WT - 53K.
13,052.0 13,081.0
1/14/2024
18:15
1/14/2024
21:45
3.50 COMPZN, CASING RUNL P RIH w/ 4½ Hyd563-MS lower
completion on 4" DP floating from
13,081' MD to 16,095' MD. Monitor disp
via Pit #1. S/O WT - 55K. Obtain T&D
every 10 stds at 20 & 30 RPM.
Note: Unable to work past obstruction
at 16,095' MD.
13,081.0 16,095.0
1/14/2024
21:45
1/14/2024
23:15
1.50 COMPZN, CASING RUNL P Kelly up and rotate in the hole from
16,095' MD to 16,498' MD @ 10-20
RPM, 4-6K Tq, S/O WT - 64K.
16,095.0 16,498.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 30/41
3S-624
Report Printed: 2/12/2024
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)
1/14/2024
23:15
1/15/2024
00:00
0.75 COMPZN, CASING RUNL P RIH w/ 4½ Hyd563-MS lower
completion on 4" HWDP floating and
rotating from 16,498' MD to 16,682' MD.
Monitor disp via Pit #1. Rot @ 20 RPM,
5K Tq, S/O WT - 70K.
16,498.0 16,682.0
1/15/2024
00:00
1/15/2024
06:00
6.00 COMPZN, CASING RUNL P RIH w/ 4½ Hyd563-MS lower
completion on 4" HWDP floating and
rotating from 16,882' MD to 17,877' MD.
Monitor disp via Pit #1. Rot @ 20-30
RPM, 6.5K Tq, S/O WT - 82K, P/U WT -
118K.
Note: Observing no pipe displacement.
16,882.0 17,877.0
1/15/2024
06:00
1/15/2024
12:00
6.00 COMPZN, CASING RUNL P RIH w/ 4½ Hyd563-MS lower
completion on 4" HWDP floating and
rotating from 17,877' MD to 18,895' MD.
Monitor disp via Pit #1. Rot @ 10 RPM,
6.5K Tq, S/O WT - 98K, P/U WT - 125K
Note: Observing no pipe displacement.
17,877.0 18,895.0
1/15/2024
12:00
1/15/2024
14:00
2.00 COMPZN, CASING RUNL P RIH w/ 4½ Hyd563-MS lower
completion on 4" HWDP floating and
rotating from 18,895' MD to 19,260' MD.
Monitor disp via Pit #1. Rot @ 25 RPM,
7.5K Tq, S/O WT - 85K, P/U WT - 120K
Note: Observing no pipe displacement.
18,895.0 19,260.0
1/15/2024
14:00
1/15/2024
16:00
2.00 COMPZN, CASING RUNL P Cont to RIH w/ liner working tight hole
conditions from 19,260' MD to 19,275'
MD stalling out top drive at tq limit of
11K. Decision made to kill rot and
attempt to work past obstruction setting
entire dn entire hookload at 19,275' MD
(unsuccessful). P/U WT - 122K, S/O
WT - 97K.
19,260.0 19,275.0
1/15/2024
16:00
1/15/2024
18:00
2.00 COMPZN, CASING RUNL P Engage rot to 15-25 RPM and
successfully work past obstruction from
19,275' MD to 19,541' MD. Set tq stall
limit to 12K. Observing tq @ 9-12K.
ROT WT - 98K.
Note: Observing no pipe displacement.
19,275.0 19,541.0
1/15/2024
18:00
1/16/2024
00:00
6.00 COMPZN, CASING RUNL P RIH w/ 4½ Hyd563-MS lower
completion on 4" HWDP floating and
rotating from 19,541' MD to 19,705' MD.
Monitor disp via Pit #1. Rot @ 25 RPM,
7.5-12K Tq, S/O WT - 85K, P/U WT -
120K
Note: Observing no pipe displacement.
Formation losses last 24 hours: 49 bbls
Total interval formation losses: 1,041
bbls
19,541.0 19,705.0
1/16/2024
00:00
1/16/2024
02:00
2.00 COMPZN, CASING RUNL T Continue to rotate and work 4.5" Hyd
563 12.6# P-110 liner assy. in hole on 4"
Hwdp working through tight hole from
19,705' MD to 19,708' MD. Ream
through tight w/10 - 25 Rpm / 9 - 12 k
ft/lbs torque Rot. Wt.= 118k @ 25 Rpm.
Torque limit set at 12 k ft/lbs as per
section plan. Not able to make forward
progress.
19,705.0 19,708.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 31/41
3S-624
Report Printed: 2/12/2024
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)
1/16/2024
02:00
1/16/2024
06:00
4.00 COMPZN, CASING RUNL P Rotate & reciprocate from 19,708' MD -
to 19,650' MD. Discuss plan forward
options with WSC and Drilling
Superintendent. Decision made to fill
fully evacuated liner and drill pipe to aid
in washing and reaming liner to TD. Fill
pipe w/9.5ppg Kla-Shield @ 40bbl
intervals, bleeding air from pipe each
interval pumped for 10/15 min.
Reciprocate pipe up and down to ensure
free travel, Free P/U = 181k, S/O N/A,
Rotate pipe periodically w/10 rpm 7.3k
torque ROT wt 112k. 297 bbls total to fill
liner and DP.
19,708.0 19,708.0
1/16/2024
06:00
1/16/2024
10:45
4.75 COMPZN, CASING CIRC P Establish circulation while working pipe
off bottom from 19,680' MD to 19,650'
MD. ROT at 20 Rpm / 10.5k, Rotating
hook load with pumps on = 128k, Stage
up flow rate. Initial 0.5 Bpm @ 700 Psi.
Final 0.75 Bpm @ 860 Psi. @ 08:15 Hrs
pump 30bbl, 9.5#, 5% lube sweep to aid
in T&D parameters. Observing swell
packer rubber across shakers.
19,708.0 19,708.0
1/16/2024
10:45
1/16/2024
12:00
1.25 COMPZN, CASING CIRC P Continue to circ and condition mud/hole
working free pipe from 19,680' MD to
19,650' MD. ROT at 20 Rpm / 10.5 k/ft
lbs trq, Rotating hook load with pumps
on = 128k. Stage rate up f/0.75 Bpm @
860 Psi to 1.5 Bpm @ 1200 Psi. (5%
lube sweep exiting the shoe at 12:00
hrs). Cont. to observe swell packer
rubber across shakers.
19,708.0 19,708.0
1/16/2024
12:00
1/16/2024
14:00
2.00 COMPZN, CASING CIRC P Continue to circulate & condition mud @
1.5 Bpm 1200 Psi work free pipe from
19,680' MD to 19,650' MD. Saw a
reduction in hook load from 128k to
118k and a decrease in torque at 20
Rpm from10.5 k ft/lbs to 9 k/ft/lbs trq
as5% lube sweep is circulated up the
open hole. (On B/U from initially
breaking circulation hole unloaded thick
flaculated mud weighing 10.5 ppg and a
funnel vis of over 400 sec's per qt)
19,708.0 19,708.0
1/16/2024
14:00
1/16/2024
14:15
0.25 COMPZN, CASING RUNL P Wash and ream liner back to bottom
from 19,650'MD to 19,708' MD w/1.5
Bpm, 1150 Psi, ROT 118 k, 20 Rpm, 9 -
10.5 k ft/lbs trq. No issues reaming back
to bottom.
19,708.0 19,708.0
1/16/2024
14:15
1/16/2024
15:00
0.75 COMPZN, CASING RUNL P Wash & Ream 4.5" Hyd 563 12.6# P-
110 liner assy. in hole on 4" Hwdp from
19,708' MD to 19,724' MD. working tight
hole. Staged rate up f/1.5 Bpm @ 1150
Psi to 2 Bpm @ 1215 Psi. ICP and 1100
Psi FCP. (Pump pressure decreased as
hole condition improved) ROT and work
pipe as needed ROT P/U wt 118k -
128k, 20 - 25 RPM, 10.5 - 13.5 k ft/lbs
trq. Not able to make forward progress
past 19,724'. Continue to observe swell
packer rubber on shakers w/fine
pulverized cuttings.
19,708.0 19,724.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 32/41
3S-624
Report Printed: 2/12/2024
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)
1/16/2024
15:00
1/16/2024
15:45
0.75 COMPZN, CASING RUNL P Cont. to attempt to make forward
progress with no success. While
working pipe on the up stroke from
19,724' MD to 19,720' MD. Rotating
w/10 Rpm @ 12 - 13.5 k/ft lbs trq and
P/U of 130k we started increasing flow
rate f/2.0 Bpm @ 1100 Psi to 2.5 Bpm.
Top drive stalled out at 13.5 k/ft lbs (max
surface torque limit) and pressure
spiked to 1,293 Psi. Hole packed off.
Lost full returns and liner stuck at
19,720' MD.
19,724.0 19,720.0
1/16/2024
15:45
1/16/2024
17:45
2.00 COMPZN, CASING RUNL P Attempt to free stuck liner and re-
establish returns at 19,720' MD with no
success. P/U without rotation to 227 k
and slack off to block wt of 43 k. No pipe
movement. Try to rotate working 6 k
ft/lbs of torque down with no success.
Consult plan forward with town and
decision made to set SLZXP and
proceed with completion well.
19,720.0 19,720.0
1/16/2024
17:45
1/16/2024
19:00
1.25 COMPZN, CASING PACK P Establish an injection rate of .5 Bpm at
1750 Psi and 2 Bpm at 2350 Psi. Drop
1.5'' secondary ball to set SLZXP. Pump
ball down @ 2 Bpm / Psi = 2,350 Psi
ICP and 1,820 Psi. FCP. At 45 bbls
pumped pressure spiked to 3,233 Psi,
then immediately decreased to 1,619
Psi. Continue to pump varying
parameters f/1.5 Bpm @ 1600 Psi to 6
Bpm @ 3,725 Psi, to ensure ball is not
off seat. Pumped 100 bbls total (2X
volume to land). Bleed pressure down
from 3725 Psi to 1000 Psi. Confident at
this point ball landed early and blew thru
ball seat.
S/O to 80k verifying hanger set as per
Baker Rep. bleed off all pressure pickup
to 138k to verify release, pickup
additional 6' to expose packer setting
dogs, slack off on liner top, dog sub
shear @ 44k S/O, P/U to neutral 124k.
Top of liner= 6638' MD, Shoe depth=
19,720' MD
19,720.0 19,720.0
1/16/2024
19:00
1/16/2024
21:30
2.50 COMPZN, CASING PRTS P R/U to IA for pressure test. Test SLZXP
liner top packer to 3,850 Psi and chart
for 10 min. Bleed off pressure. Discuss
plan forward options with town and
decision made to re-test for 30 min. Re-
test liner top packer to 3850 Psi and
chart for 30 min ( Good Test)
6,638.0 6,638.0
1/16/2024
21:30
1/16/2024
23:15
1.75 COMPZN, WELLPR RURD P Blow down/ rig down testing equipment,
prepare rig for laying down 4” drill pipe,
monitor well via jet line on pit 1. Prep for
displacement to CI Brine.
6,638.0 6,638.0
1/16/2024
23:15
1/17/2024
00:00
0.75 COMPZN, WELLPR DISP P Space out liner running tools just above
liner top at 6,632' (TOL @ 6,638') Pump
35 bbls high vis spacer and displace
wellbore to 9.5ppg Corrosion Inhibited
3% KCI/NaCL w/126 Gpm @ 430 Psi,
19% F/O.
6,638.0 6,632.0
1/17/2024
00:00
1/17/2024
01:00
1.00 COMPZN, WELLPR DISP P @ 6632' MD pump 30 bbl spacer,
displace well to 9.5 PPG Corrosion
inhibitor 3% KCL/NACL @ GPM 126,
PSI 430, Total strokes pumped 3336.
6,632.0 6,632.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 33/41
3S-624
Report Printed: 2/12/2024
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)
1/17/2024
01:00
1/17/2024
01:30
0.50 COMPZN, WELLPR OWFF P OWFF( well u-tubing) Fluid was out off
balance, make up top-drive to circulate.
6,632.0 6,632.0
1/17/2024
01:30
1/17/2024
02:15
0.75 COMPZN, WELLPR CIRC P Circulate @ 6632' MD with GPM 84, PSI
118, F/O 8%, Total strokes pumped
1000. Fluid weight in and out 9.5 PPG
6,632.0 6,632.0
1/17/2024
02:15
1/17/2024
02:45
0.50 COMPZN, WELLPR OWFF P OWFF ( well static) 6,632.0 6,632.0
1/17/2024
02:45
1/17/2024
10:45
8.00 COMPZN, WELLPR TRIP P POOH from 6632' MD to 42' MD with 4"
drill pipe laying down 4" drill pipe to
shed P/U 142k. Monitoring displacement
via trip tank.
6,632.0 42.0
1/17/2024
10:45
1/17/2024
11:45
1.00 COMPZN, WELLPR PULD P L/D Baker hanger running tools as per
Baker Rep. P/U S/O 42k. Inspected
tools all in place. Monitoring
displacement via trip tank.
42.0 0.0
1/17/2024
11:45
1/17/2024
12:30
0.75 COMPZN, WELLPR CLEN P Clean and Clear rig floor and lay down
excess tools and equipment.
0.0 0.0
1/17/2024
12:30
1/17/2024
13:30
1.00 COMPZN, WELLPR RGRP T Trouble shoot iron roughneck( Jaws
rotation actuation not working properly)
Run new wire to solenoid control box.
0.0 0.0
1/17/2024
13:30
1/17/2024
14:30
1.00 COMPZN, WELLPR PULD P TIH from surface to 757' MD with
remaining HWDP from derrick.
Monitoring displacement via trip tank.
P/U / S/O 63K
0.0 757.0
1/17/2024
14:30
1/17/2024
16:00
1.50 COMPZN, WELLPR PULD P POOH f/757' laying down 4" HWDP/DP.
Monitoring displacement via trip tank.
757.0 0.0
1/17/2024
16:00
1/17/2024
17:00
1.00 COMPZN, WELLPR RURD P M/U wearing bushing pulling tool and
pull wear bushing as per Cameron Rep.
0.0 0.0
1/17/2024
17:00
1/17/2024
18:00
1.00 COMPZN, WELLPR WWWH P M/U stack washing tool, flush stack and
wellhead profile, GPM 756, PSI 200, L/D
wash tool and 2 joints of 4" HWDP to
pipe shed. Blow down top drive.
0.0 0.0
1/17/2024
18:00
1/18/2024
00:00
6.00 COMPZN, RPCOMP RURD P Mobilize and spot Halliburton slick line,
Summits ESP, Halliburton Tec wire
sheaves and equipment to rig floor. Rig
up Doyon casing running equipment.
Note install warming house around
Halliburton Tec line spools equipment at
ground level.
0.0 0.0
1/18/2024
00:00
1/18/2024
03:30
3.50 COMPZN, RPCOMP RURD P Continue, Rig up HES slick-line, HES
Tec-line and Summit ESP lines to rig
floor, Hang sheaves in derrick,
Equipment ready on rig floor. Inspect
Top-drive energy track(Inspection
Good). PJSM on running upper
completion with HES slick-line, HES Tec
-line, Summit ESP, Doyon casing crew
and Doyon rig crew.
0.0 0.0
1/18/2024
03:30
1/18/2024
05:30
2.00 COMPZN, RPCOMP PUTB P Pickup and run 4.5" 12.6# L-80 Hyd 563
upper completion as per detail plan.
from surface to 445' MD. Make up
torque 3800 ft/bls. Fill liner on the fly via
fill up hose, topping off every 20 joints,
Monitor displacement via pit #1.
0.0 445.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 34/41
3S-624
Report Printed: 2/12/2024
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)
1/18/2024
05:30
1/18/2024
12:00
6.50 COMPZN, RPCOMP DHEQ T Make up motor shroud and ACP assy.
as per Access ESP Rep. Decision made
to change out ACP due to damaged o-
ring seals. Lay down primary and pick-
up back up ACP. (Determined potential
damage to PLE (power lead ext) and o-
ring seals). Discuss plan forward options
with Access ESP engineers and CPAI
completion engineers. ( Wait on
fabricated poly PLE guard from
Deadhorse) Access engineers and poly
guard arrived at location 11:50 hrs.
445.0 445.0
1/18/2024
12:00
1/18/2024
13:45
1.75 COMPZN, RPCOMP DHEQ P Access ESP engineer inspected ACP
and PLE and determine it was okay to
run in hole as is. (O-ring seal would not
compromise integrity of ACP/PLE
connectivity) confirm decision with CPAI
completion engineer to proceed ahead.
Attempt to make up PLE to ACP and
observe damage to PLE. Rig down HES
slick-line and change out primary spool
to back up spool. Connect PLE to ACP
and continue making up shroud assy.
445.0 445.0
1/18/2024
13:45
1/18/2024
16:00
2.25 COMPZN, RPCOMP PUTB P Continue to RIH from 445' MD to 577'
MD ( 10 joints 4.5" 12.6# L-80 Hyd 563
tubing in the hole) P/U, S/O 49k.
455.0 577.0
1/18/2024
16:00
1/18/2024
18:45
2.75 COMPZN, RPCOMP DHEQ P @ 577' MD make up ESP splice as per
Access ESP and test connection
continuity. (Good Test)
577.0 577.0
1/18/2024
18:45
1/18/2024
19:30
0.75 COMPZN, RPCOMP PUTB P RIH from 577' MD to 650' MD make up
HES gauge mandrel to DHG (Down
Hole Gauge) as per HES procedure and
pressure test connection to 5000 PSI,
for 5 minutes.
577.0 650.0
1/18/2024
19:30
1/18/2024
22:15
2.75 COMPZN, RPCOMP PUTB P RIH 4.5" 12.6# L-80 Hyd 563 ESP upper
completion tubing as per detail from
650' to 2100, make up torque = 3,800
ft/lbs. Fill tubing on fly via fill up hose,
topping off tubing every 20 joints,
monitor displacement via pit #1.
S/O=66k
650.0 2,100.0
1/18/2024
22:15
1/18/2024
23:00
0.75 COMPZN, RPCOMP DHEQ P Electrical check on HES Tec line Good
Test. Electrical check on Summit ESP
cable.Failed test. Cable did not test,
outside phase showed ground. Decision
made to POOH to ACP/PLE inspecting
ESP cable for damage.
2,100.0 2,100.0
1/18/2024
23:00
1/19/2024
00:00
1.00 COMPZN, RPCOMP PULD T PJSM, POOH with 4.5" 12.6# L-80 HYD
563 tubing inspecting Summit ESP
cable for damage from 2100’ MD to
1799’ MD. Monitoring displacement via
pit #1
2,100.0 1,799.0
1/19/2024
00:00
1/19/2024
00:45
0.75 COMPZN, RPCOMP RGRP T Repair failed hydraulic fitting on power
tong system
1,799.0 1,799.0
1/19/2024
00:45
1/19/2024
02:45
2.00 COMPZN, RPCOMP PUTB T POOH laying down 4-1/2" tubing to pipe
shed looking for damaged ESP cable
from 1,799' to 650', Monitor hole fill on
pit #1
1,799.0 650.0
1/19/2024
02:45
1/19/2024
03:15
0.50 COMPZN, RPCOMP DHEQ T Perform test on HES tech line and
downhole gauge (good) 23.88 Psi,
74.52° F
650.0 650.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 35/41
3S-624
Report Printed: 2/12/2024
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)
1/19/2024
03:15
1/19/2024
04:15
1.00 COMPZN, RPCOMP PUTB T POOH laying down 4-1/2" tubing to pipe
shed looking for damaged ESP cable
from 650' to 475', Monitor hole fill on pit
#1
Observe damage to Access ESP PLE
cable below splice. Damaged cable
shows significant wear on outer metal
protective coating and inner cable is
exposed causing it to ground out.
Damaged cable correlates to motor
shroud #6 on completion tally.
650.0 475.0
1/19/2024
04:15
1/19/2024
05:00
0.75 COMPZN, RPCOMP PUTB T POOH laying down Access ESP motor
shroud assemblies to ACP and PLE
connection from 470' to 440', Monitor
hole fill on pit #1
475.0 440.0
1/19/2024
05:00
1/19/2024
06:00
1.00 COMPZN, RPCOMP WAIT T Discuss plan forward options with town
and CPAI Completions Engineer.
Decision made to swap out PLE
assembly
440.0 440.0
1/19/2024
06:00
1/19/2024
07:00
1.00 COMPZN, RPCOMP RURD T Cut out and remove splice from PLE
spool to ESP spool. Remove PLE from
ACP. L/D ACP and motor shroud
assembly to pipe shed. R/D HES Slick
Line and make beaver slide accessible.
440.0 440.0
1/19/2024
07:00
1/19/2024
07:30
0.50 COMPZN, RPCOMP PUTB T POOH from 440' to 240' laying down 4-
1/2" tubing and SLB sliding sleeves
assembly to pipe shed. Inspect HES
TNT packer assembly (good)
440.0 240.0
1/19/2024
07:30
1/19/2024
08:00
0.50 COMPZN, RPCOMP PUTB T RIH 4-1/2" 12.6# L-80 Hyd 563 tubing
from 240' to 440'. P/U Access motor
shroud #1 and ACP assembly.
240.0 440.0
1/19/2024
08:00
1/19/2024
11:00
3.00 COMPZN, RPCOMP WAIT T Wait on new Access ESP PLE spools to
be mobilized from Deadhorse. SIMOPS
- L/D both compromised and damaged
PLE spools via beaver slide. Take
measurements for hang off points in
derrick for future completion jobs. R/D
tank farm. Clean and prep MPD/BOPE's
for N/D once upper completion is
complete. Housekeeping and PM's
440.0 440.0
1/19/2024
11:00
1/19/2024
11:30
0.50 COMPZN, RPCOMP DHEQ T Bring new PLE spool to rig floor via
beaver slide.Perform initial connectivity
test on PLE (good). M/U new PLE to
ACP and perform connectivity test
(good).
440.0 440.0
1/19/2024
11:30
1/19/2024
13:00
1.50 COMPZN, RPCOMP PUTB T RIH with 4-1/2" 12.6# L-80 Hyd 563
tubing from 440' to 577', Monitor
displacement on pit #1, SO 51k
440.0 577.0
1/19/2024
13:00
1/19/2024
14:45
1.75 COMPZN, RPCOMP DHEQ T Splice Access ESP PLE cable to
Summit ESP cable and perform
connectivity test (good). SIMOPS - R/U
HES Slick Line and 3.83" OD drift
assembly.
577.0 577.0
1/19/2024
14:45
1/19/2024
15:00
0.25 COMPZN, RPCOMP PUTB T RIH with 4-1/2" 12.6# L-80 Hyd 563
tubing from 577' to 644' (11 joints in the
hole, Monitor displacement on pit #1,
S/O 53k
577.0 644.0
1/19/2024
15:00
1/19/2024
15:45
0.75 COMPZN, RPCOMP DHEQ T M/U HES OPSIS gauge mandrel as per
HES reps. M/U tech wire to mandrel and
perform connectivity test (good)
644.0 644.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 36/41
3S-624
Report Printed: 2/12/2024
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)
1/19/2024
15:45
1/19/2024
18:00
2.25 COMPZN, RPCOMP PUTB T RIH with 4-1/2" 12.6# L-80 Hyd 563
tubing from 644' MD to 1766' MD, Top
fill tubing every perform ESP
connectivity check every 500'. Perform
3.83" OD gauge run and HES downhole
gauge check every 2000'. Monitor
displacement on pit #1, S/O 59k.
644.0 1,766.0
1/19/2024
18:00
1/19/2024
18:15
0.25 COMPZN, RPCOMP PUTB T RIH with 4-1/2" 12.6# L-80 Hyd 563
tubing from 1766' MD to 1850' MD, Top
fill tubing every perform ESP
connectivity check every 500'. Perform
3.83" OD gauge run and HES downhole
gauge check every 2000'. Monitor
displacement on pit #1, S/O 65k.
1,766.0 1,850.0
1/19/2024
18:15
1/19/2024
19:15
1.00 COMPZN, RPCOMP SLKL T Run HES slick-line 3.83" drift from Joint
#40 to NoGo, @ 403', ESP readings A-
leg 11/G, B-leg 12G, C-leg 11G HES Tec
line readings, Tubing 609 PSI, Annular
595 PSI, Temperature 52 Degrees.
1,850.0 1,850.0
1/19/2024
19:15
1/19/2024
23:30
4.25 COMPZN, RPCOMP PUTB P RIH with 4-1/2" 12.6# L-80 Hyd 563
tubing from 1850' MD to 3950' MD, Top
fill tubing every perform ESP
connectivity check every 500'. Perform
3.83" OD gauge run and HES downhole
gauge check every 2000'. Monitor
displacement on pit #1, S/O 74 k.
1,850.0 3,950.0
1/19/2024
23:30
1/20/2024
00:00
0.50 COMPZN, RPCOMP SLKL P Run HES slick-line 3.83" drift from joint
# 90 to Joint #47, ESP readings @
2295' MD A-leg 12/G, B-leg 13/G, C-leg
14/G @ 2709' MD A-leg 14/G, B-leg
13/G, C-leg 12/G @ 3120' MD A-leg
13/G, B-leg 14G, C-leg 12G, @ 3540'
MD A-leg 13/G, B-leg 13/G, C-leg 12/G
HES Tec line readings, Tubing 1287
PSI, Annular 1346 PSI, Temperature 69
Degrees. Note unable to drift KBMG
4.5" inconel dummy with 3.83" drift.
Made call to town supervisors for
instruction.
3,950.0 3,950.0
1/20/2024
00:00
1/20/2024
01:00
1.00 COMPZN, RPCOMP SLKL P Perform 3.83" slick line drift run to
1,840' (good) Perform ESP connectivity
test. (A-leg/12G, B-leg/13G, C-leg/11G)
Perform HES downhole gauge check
(Tubing 1287 Psi, IA 1346 Psi, 69*F)
SIMOPS - P/U upper KBMG GLM with
1" SOV (2000 Psi Shear). Drift on rig
floor to 3.83" (good) L/D back to pipe
3,950.0 3,950.0
1/20/2024
01:00
1/20/2024
01:15
0.25 COMPZN, RPCOMP PUTB P RIH with 4-1/2" 12.6# L-80 Hyd 563
tubing from 3950' MD to 4115' MD
Monitor displacement on pit #1, S/O 77
k.
3,950.0 4,115.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 37/41
3S-624
Report Printed: 2/12/2024
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)
1/20/2024
01:15
1/20/2024
06:30
5.25 COMPZN, RPCOMP SLKL T Perform 3.83" slick line drift run. Not
able to drift though lower KBMG GLM @
2107' MD. POOH with slick line and
reconfigure tools with roller stem
assembly. Drift to 2005' MD
(unsuccessful) POOH with slick line and
reconfigure tools with 3.83" OD
centralizer. Drift to 2107' MD
(unsuccessful). POOH with slick line
tools and L/D 3.83" gauge assembly.
M/U 3.82" swedge 3' short body
assembly and RIH. Drift through lower
GLM to 2300' MD. POOH and L/D
swedge assembly. Discuss plan forward
options with town. Look at well path and
lower GLM is sitting in poor geometry
due to high dog legs while drilling
surface. Decision made to RIH and get
below dog legs.
4,115.0 4,115.0
1/20/2024
06:30
1/20/2024
07:00
0.50 COMPZN, RPCOMP PUTB P RIH with 4-1/2" 12.6# L-80 Hyd 563
tubing from 4115' to 4487' MD Monitor
displacement on pit #1, S/O 80 k. (103
joints in the hole)
4,115.0 4,487.0
1/20/2024
07:00
1/20/2024
08:30
1.50 COMPZN, RPCOMP SLKL T Perform 3.83" slick line drift run. Not
able to drift though lower KBMG GLM @
2300'. Look at well path again and
lower GLM is sitting in poor geometry
due to high dog legs while drilling
surface. Decision made to RIH and get
completely below all dog legs. POOH
with slick line drift assembly.
4,487.0 4,487.0
1/20/2024
08:30
1/20/2024
09:00
0.50 COMPZN, RPCOMP PUTB P M/U upper KBMG GLM with SOV and
RIH with 4-1/2" 12.6# L-80 Hyd 563
tubing from 4487' MD to 4797'. Monitor
displacement on pit #1, S/O 85 k. (130
joints in the hole)
4,487.0 4,797.0
1/20/2024
09:00
1/20/2024
13:00
4.00 COMPZN, RPCOMP SLKL T Perform 3.83" slick line drift run. Not
able to drift though lower KBMG GLM @
2678'. POOH with slick line and discuss
plan forward options with town. Mobilize
a bull nose centralizer with guide prong
from wire line shop. M/U new 18' long
ESP drift assembly with 3.83" OD
centralizer. Perform drift run and RIH
through upper and lower GLM's to
3000'. Successful drift. POOH and stand
back drift assembly. Decision made to
continue with running upper completion.
Perform ESP connectivity test. (A-
leg/10G, B-leg/12G, C-leg/18G) Perform
HES downhole gauge check (Tubing
1625 Psi, IA 1592 Psi, 82*F)
4,797.0 4,797.0
1/20/2024
13:00
1/20/2024
16:00
3.00 COMPZN, RPCOMP PUTB P RIH with 4-1/2" 12.6# L-80 Hyd 563
tubing from 4797' to 6550' Monitor
displacement on pit #1, S/O 83 k. (153
joints in the hole)
4,797.0 6,550.0
1/20/2024
16:00
1/20/2024
19:00
3.00 COMPZN, RPCOMP SLKL P Perform final 3.83" slick line drift run
from surface through all jewelry and
nogo at 6,120' MD. Perform final ESP
connectivity test. (A-leg/11G, B-leg/12G,
C-leg/6G) Perform final HES downhole
gauge check (Tubing 2114 Psi, IA 2107
Psi, 107*F). POOH and R/D slick line
tools and equipment. SIMOPS - Prep for
testing IA and tubing.
6,550.0 6,550.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 38/41
3S-624
Report Printed: 2/12/2024
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)
1/20/2024
19:00
1/20/2024
23:00
4.00 COMPZN, RPCOMP THGR P RIH with 4-1/2" 12.6# L-80 Hyd 563
tubing from 6550' to 6609' MD and
space out to NOGO with joints #154,
#155 and tag top of liner at 6603' P/U
111k, S/O 89k,Tag top liner with 20k,
S/O 89k, Tag twice to confirm. Did not
witness locator pins sheer. POOH to
6569' MD drift and make up space out
pup joints to stand #153, Drift hanger
3.83". P/U landing joint and hanger
assy. Orientation was out of time.
6,550.0 6,569.0
1/20/2024
23:00
1/21/2024
00:00
1.00 COMPZN, RPCOMP THGR P Prep ESP and DHG cables to terminate,
Locate to rig time collar, change out
collar, make up hanger orientate
hanger180 degrees to ESP and DHG
cables. Terminate ESP and DHG cable,
Feed ESP and DHG cable through
hanger and splice back. Reading before
termination, ESP cable A-leg 2G, B-leg
6G, C-leg 8G, Tec cable, Tubing 2121
PSI, Annular 2096 PSI, Temperature
108*F.
6,569.0 6,569.0
1/21/2024
00:00
1/21/2024
03:15
3.25 COMPZN, RPCOMP THGR P Continue to splice ESP cable to TriBore
penetrator. Terminate lines through
tubing hanger. Test ESP cable (A-
leg/4.4G, B-leg/6.8G, C-leg/1.8G). Test
penetration voids to 5000 psi (good).
6,569.0 6,569.0
1/21/2024
03:15
1/21/2024
08:15
5.00 COMPZN, RPCOMP THGR T Attempt to RIH and land out and
observe excess slack in ESP cable.
Discuss plan forward options with town
and determine best course of action to
cut and re-splice and remove excess
slack. Remove TriBore penetrator and
cut out splice. Re-splice ESP cable and
M/U new TriBore penetrator. Terminate
lines through tubing hanger. Test ESP
cable (A-leg/4.4G, B-leg/6.8G, C-
leg/1.8G). Test penetration voids to
5000 psi (good). SIMOPS - Drain stack
and prep to land on hanger. Prep for
tubing and IA test.
6,569.0 6,569.0
1/21/2024
08:15
1/21/2024
09:15
1.00 COMPZN, RPCOMP THGR P RIH and land on hanger at 6,609' MD
(1.5' from fully located. P/U 113k, S/O
89k. RILDS and pressure test hanger
seals to 5000 Psi for 15 min (good).
6,569.0 6,609.0
1/21/2024
09:15
1/21/2024
10:00
0.75 COMPZN, RPCOMP RURD P R/U for high pressure testing. R/U
casing swedge and TIW valve with head
pin and cement hose to pump down
tubing. R/U to pump down IA. Pressure
test tubing lines to 4600 Psi and
pressure test IA lines to 4000 Psi.
6,609.0 6,609.0
1/21/2024
10:00
1/21/2024
13:00
3.00 COMPZN, RPCOMP PRTS P Pressure up on tubing to 4,550 Psi to
set TNT packer and hold for 15 min.
(good) Bleed tubing to 2200 Psi and
shut in. Pressure up on IA and test to
3850 Psi for 30 min (good). Bleed off IA
and bleed off tubing. Pressure test
tubing to 4550 psi for 30 min (good).
Bleed off tubing and confirm results with
town. All test were charted on Totco.
Pressure up tubing to 2200 Psi and
Pressure up IA to 3000 Psi. Dump
pressure on tubing and shear SOV.
Successful shear.
6,609.0 6,609.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 39/41
3S-624
Report Printed: 2/12/2024
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)
1/21/2024
13:00
1/21/2024
13:30
0.50 COMPZN, RPCOMP OWFF P OWFF for 30 min (static). SIMOPS -
R/D all upper completion tools and
equipment. R/D hooch and ESP/HES
spools. Remove all upper completion
tubing from pipe shed.
0.0 0.0
1/21/2024
13:30
1/21/2024
14:15
0.75 COMPZN, WHDBOP RURD P R/D testing equipment and blow down
lines. Back out landing joint and L/D to
pipe shed.R/U to set BPV. SIMOPS -
R/D all upper completion tools and
equipment. R/D hooch and ESP/HES
spools. Remove all upper completion
tubing from pipe shed.
0.0 0.0
1/21/2024
14:15
1/21/2024
15:00
0.75 COMPZN, WHDBOP MPSP P Cameron set HP-BPV. Pump thru IA and
pressure test in direction of flow to 2500
Psi for 10 min. Confirm all barriers are in
place for N/D BOPE's.
0.0 0.0
1/21/2024
15:00
1/21/2024
17:00
2.00 COMPZN, WHDBOP CLEN P Clean and clear rig floor excess tools
and equip., lay down mousehole to
shed, pull bushings and ready to lay
down trip nipple.
0.0 0.0
1/21/2024
17:00
1/21/2024
19:30
2.50 COMPZN, WHDBOP MPDA P PJSM pull trip nipple and install drip
nipple. Nipple down Beyond MPD
equipment, Orbit valve and high
pressure lines. Set back in BOPE deck.
0.0 0.0
1/21/2024
19:30
1/22/2024
00:00
4.50 COMPZN, WHDBOP NUND P PJSM, remove BOPE yoke from annular
and install between top pipe rams /
blinds. Rig down accumulator hydraulic
lines, drain hydraulic oil from annular,
top pipe rams, blinds rams. mobilize
annular cap removal tool with 6’ pup
joint to rig floor to be torqued, lower
assembly to ground. Use bops bridge
cranes to lift to bope deck. Run rig floor
tugger through rotary table pick up
annular cap breaker tool lift through
table set slips torque to single of 5''
Hwdp. Bolt to top of annular use rig
tongs to brake cap. Rig down annular
cap breaker assembly.(SIMOPS clean
pits, rockwasher. Rig down mud pump
interconnect lines) Off high line power
@ 14:25 hrs
0.0 0.0
1/22/2024
00:00
1/22/2024
02:00
2.00 COMPZN, WHDBOP NUND P R/U over head crane lines to annular.
P/U annular to BOPE deck and position
on trolley. Remove annular from BOPE
deck. (Annular element will be replaced
during rig move)
0.0 0.0
1/22/2024
02:00
1/22/2024
08:00
6.00 COMPZN, WHDBOP NUND P N/D choke and kill lines. Break choke,
kill and cement lines from sub
interconnects. N/D and rack back
remaining BOPE components on
pedalstal. Secure in place for rig move
N/D adaptor spools and stage in BOPE
deck. SIMOPS - Prep tubing adaptor
and well head.
0.0 0.0
1/22/2024
08:00
1/22/2024
12:00
4.00 COMPZN, WHDBOP NUND P N/U tubing adaptor spool and pressure
test to 5000 psi for 15 min (good)
Terminate HES tech wire and ESP
cables through adaptor flange. Perform
final HES downhole gauge check
(Tubing 2132 Psi, IA 2121 Psi, 206*F).
Perform final ESP connectivity test. (A-
leg/6G, B-leg/2G, C-leg/7G) SIMOPS -
Slip and cut 144' drill line
0.0 0.0
1/22/2024
12:00
1/22/2024
13:30
1.50 COMPZN, WHDBOP NUND P N/U 10k frac tree and orient 1502 inlet
towards mouse hole. Tighten all flanges
and ready for pressure test.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 40/41
3S-624
Report Printed: 2/12/2024
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)
1/22/2024
13:30
1/22/2024
15:00
1.50 COMPZN, WHDBOP PRTS P Fill tree with diesel and purge air. R/U
rigs test pump. Rig test tree to 250 Psi
for 5 min and 5000 Psi 15 min and chart
on Totco BOP Test channel. (good)
0.0 0.0
1/22/2024
15:00
1/22/2024
20:00
5.00 COMPZN, WHDBOP RURD P R/D rigs testing equipment. Spot in
place LRS. Thaw 10k hard lines. Liners
were completely packed off with ice and
snow on transport trailer. Thaw and
inspec 10k lines verified lines were
clear.
0.0 0.0
1/22/2024
20:00
1/22/2024
23:00
3.00 COMPZN, WHDBOP PRTS P R/U lines to LRS and 10k frac tree, flood
lines pressure test lines to 10k good
test, Pressure test 4 1/16" frac tree to
10k for 5 minutes visual test no leaks.
R/D testing equipment.
0.0 0.0
1/22/2024
23:00
1/23/2024
00:00
1.00 COMPZN, WHDBOP BOPE T R/U to pull Cameron Dart and HP/ BPV,
RIH with dry rods found Hydraulic valve
on frac tree was in closed position.
Talked with WSC group and discussed
plan forward in opening hydraulic valve
and check and bleed any trapped
pressure. Plan forward to R/U and re-
test 4 1/16" frac to 5000 Psi on chart
0.0 0.0
1/23/2024
00:00
1/23/2024
00:30
0.50 COMPZN, WHDBOP RURD P Rig down Cameron T-bar and BPV
handling equipment.
0.0 0.0
1/23/2024
00:30
1/23/2024
02:00
1.50 COMPZN, WHDBOP RURD P Rig up Test pump equipment to tree and
pressure to 5k to equalize above and
below SSV. Unable to open SSV. Bleed
pressure off. Rig down testing
equipment, Began to rig up LRS on
hardlines. While troubleshooting SSV
valve with Cameron Reps in town, it was
confirmed that valve lock out on SSV
was engaged to prevent valve from
opening.
0.0 0.0
1/23/2024
02:00
1/23/2024
08:00
6.00 COMPZN, WHDBOP WAIT T Phase 3 weather conditions, Monitor rig.
Phase 2 weather conditions 08:00 hrs
0.0 0.0
1/23/2024
08:00
1/23/2024
11:30
3.50 COMPZN, WHDBOP PRTS T PJSM rig up to test 4 1/16" frac tree.
Flood tree and lines with diesel and
purge lines free of air. Pressure up and
inspect for leaks. Pressure test tree to
250 Psi low and 5000 Psi for 15 min via
rig test pump.
Work to remobalize LRS back to the rig
for test and freeze protect.
0.0 0.0
1/23/2024
11:30
1/23/2024
12:00
0.50 COMPZN, WHDBOP RURD T Rig up LRS and hard line to the tree.
Flood lines and attempt to pressure test
hardline.
0.0 0.0
1/23/2024
12:00
1/23/2024
15:15
3.25 COMPZN, WHDBOP SEQP T Work through the hard line and address
leaking unions as needed. Pressure test
hard line to 10,000 Psi. (Good Test).
0.0 0.0
1/23/2024
15:15
1/23/2024
16:15
1.00 COMPZN, WHDBOP PRTS T Pressure test Frac tree with LRS to
10,000 psi for 5 min. 200 psi total
pressure loss for the test. 160 psi in the
first half, 40 psi in the second half.
0.0 0.0
1/23/2024
16:15
1/23/2024
17:00
0.75 COMPZN, WHDBOP RURD P Evacuate diesel from lines and rig down
hard line. Pull BPV and rig up to freeze
protect tubing and IA. SIMOPS - Break
down test and hardline equipment. Load
out on transport trailer and secure.
0.0 0.0
1/23/2024
17:00
1/23/2024
20:00
3.00 COMPZN, WHDBOP FRZP P Freeze protect IA and tubing with LRS.
Pump 92 bbls diesel down IA taking
returns through tubing to cellar box.
Pump 1BPM @ 621 PSI, for 92 bbls
total pumped.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
Page 41/41
3S-624
Report Printed: 2/12/2024
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)
1/23/2024
20:00
1/23/2024
21:00
1.00 COMPZN, WHDBOP THGR P Rig down LRS lines and install H/BPV
into wellhead as per Cameron Rep.
Secure 4 1/16" frac tree, All tree valves
are in close position. Secure IA flange
install pressure gauges. Take all final
IA,OA,Tubing pressure readings. IA 26
Psi, OA 185 Psi, Tubing 0 Psi.
0.0 0.0
1/23/2024
21:00
1/24/2024
00:00
3.00 DEMOB, MOVE DMOB P Rig down upper skate section from
derrick. Work through rig move
checklist. Remove Geronimo line. Rig
down bridge crane hydraulics. Ready
pipe shed cattle chute. Pin up beaver
slide. Secure rig floor. Disconnect all
module service lines. Ready cellar to
pull sub off well. Release rig from 3S-
624 @ 00:00 hrs on 1-24-24. Note
Doyon electrician and mechanic work
and troubleshoot sub module cold start.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 1/24/2024
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Page 1/1
3S-624
Report Printed: 2/12/2024
Cement
Cement Details
Description
Surface String Cement
Cementing Start Date
12/16/2023 14:39
Cementing End Date
12/16/2023 17:54
Wellbore Name
3S-624
Comment
full return during job, observe no sag
Cement Stages
Stage # 1
Description
Surface String Cement
Objective Top Depth (ftKB)
39.7
Bottom Depth (ftKB)
3,048.5
Full Return?
Yes
Vol Cement …
260.0
Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
286
Q Pump Final (bbl/…
2
Q Pump Avg (bbl/…
6
P Pump Final (psi)
586.0
P Plug Bump (psi)
1,114.0
Recip?
No
Stroke (ft) Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
Cement Fluids & Additives
Fluid
Fluid Type
Lead Cement
Fluid Description Estimated Top (ftKB)
39.7
Est Btm (ftKB)
2,548.0
Amount (sacks)
919
Class
*NOT IN LIBRARY
Volume Pumped (bbl)
477.0
Yield (ft³/sack)
2.92
Mix H20 Ratio (gal/sack)
14.90
Free Water (%) Density (lb/gal)
10.70
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)
2,548.0
Est Btm (ftKB)
3,048.5
Amount (sacks)
275
Class
G
Volume Pumped (bbl)
56.0
Yield (ft³/sack)
1.16
Mix H20 Ratio (gal/sack)
5.02
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-624
Report Printed: 2/12/2024
Cement
Cement Details
Description
Intermediate String 1 Cement
Cementing Start Date
12/23/2023 20:45
Cementing End Date
12/23/2023 23:30
Wellbore Name
3S-624
Comment
Cement in place at 2300 hrs
Cement Stages
Stage # 1
Description
Intermediate String 1
Cement
Objective Top Depth (ftKB)
3,555.0
Bottom Depth (ftKB)
7,581.3
Full Return?
No
Vol Cement …
0.0
Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
6
Q Pump Final (bbl/…
3
Q Pump Avg (bbl/…
6
P Pump Final (psi)
1,230.0
P Plug Bump (psi)
1,814.0
Recip?
Yes
Stroke (ft)
12.00
Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
Cement Fluids & Additives
Fluid
Fluid Type
Primary Cement
Fluid Description Estimated Top (ftKB)
3,555.0
Est Btm (ftKB)
7,581.3
Amount (sacks)
664
Class
G
Volume Pumped (bbl)
222.0
Yield (ft³/sack)
1.25
Mix H20 Ratio (gal/sack)
5.57
Free Water (%) Density (lb/gal)
15.30
Plastic Viscosity (cP)
16.0
Thickening Time (hr)
5.60
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-624
Yes No
9. Property Designation (Lease Number): 10. Field:
Torok Oil Pool
11.
Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
20485 5156 19685 5158 2339 None None
Casing Collapse
Structural
Conductor
Surface 2470
Intermediate 4790
Intermediate 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
Manabu Nozaki 2/2/2024 Contact Email:Manabu.Nozaki@cop.com
Contact Phone: 907-265-6519
Authorized Title:Staff Completions Engineer
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other 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
Length
AOGCC USE ONLY
11590
Tubing Grade:Tubing MD (ft):
TNT Packer: 6368' MD/ 4521' TVD
SLZXP: 6603' MD / 4661' TVD
Subsequent Form Required:
Suspension Expiration Date:
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:
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL380107 / ADL380106 / ADL0255528 / ADL393883
223-104
P.O. Box 100360, Anchorage, Alaska 99510-0360 50-103-20868-00-00
ConocoPhillips Alaska Inc.
Kuparuk Field
Will perfs require a spacing exception due to property boundaries?
Current Pools:
Size
Proposed Pools:
TVD Burst
MPSP (psi):Plugs (MD):
MD
PRESENT WELL CONDITION SUMMARY
6890
5210
155
2554.7
5217.6
155
3048.5
51307-5/8"
20"
10-3/4"
115.3
7-5/8"6824.9
3008.8
7581.3
6862
592
4-1/2"
2/10/2024
1968513081.7
4-1/2"
5157.6
Halliburton TNT Prod Packer
Baker SLZXP, No SSSV
L-80
10860
Perforation Depth TVD (ft):Perforation Depth MD (ft):
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
324-048
By Kayla Junke at 4:18 pm, Feb 02, 2024
A.Dewhurst 08FEB24
CDW 02/08/2024
10-404X
VTL 02/08/2024JLC 2/8/2024
2/8/24Brett W. Huber, Sr.Digitally signed by Brett W. Huber,
Sr.
Date: 2024.02.08 19:03:59 -05'00'
RBDMS JSB 021324
Section 1 - Affidavit 10 AAC 25.283 (a)(1)
Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators
within one-half mile radius of the current or proposed wellbore trajectory have been provided
notice of operations in compliance with 20 AAC 25.283(a)(1).
Section 2 – Plat 20 AAC 25.283 (2)(A)
Plat 1: Wells within 1/2 mile
Table 1: Wells within 1/2 miles (2)(C)
3S-624 Frac Sundry Well Intersect Tract Buffer
Business Unit ID Business Area ID API * Well Name Status Symbology
KUP KRU 501032045800 3S-03 SUSP Suspended
KUP KRU 501032045400 3S-06 PA Plugged and Abandoned
KUP KRU 501032045401 3S-06A PA Plugged and Abandoned
KUP KRU 501032043000 3S-07 ACTIVE Oil
KUP KRU 501032045000 3S-08 PA Plugged and Abandoned
KUP KRU 501032045001 3S-08A PA Plugged and Abandoned
KUP KRU 501032045002 3S-08B PA Plugged and Abandoned
KUP KRU 501032045003 3S-08C ACTIVE Oil
KUP KRU 501032045060 3S-08CL1 ACTIVE Oil
KUP KRU 501032045070 3S-08CL1PB1 PA Plugged and Abandoned
KUP KRU 501032043200 3S-09 ACTIVE Injector Miscible Water Alternating Gas
KUP KRU 501032044000 3S-10 PA Plugged and Abandoned
KUP KRU 501032043900 3S-14 SUSP Suspended
KUP KRU 501032044400 3S-15 PA Plugged and Abandoned
KUP KRU 501032044500 3S-16 ACTIVE Injector Miscible Water Alternating Gas
KUP KRU 501032044800 3S-17 PA Plugged and Abandoned
KUP KRU 501032044801 3S-17A PA Plugged and Abandoned
KUP KRU 501032043300 3S-18 SUSP Suspended
KUP KRU 501032046000 3S-19 SUSP Suspended
KUP KRU 501032045200 3S-21 PA Plugged and Abandoned
KUP KRU 501032044600 3S-22 SUSP Suspended
KUP KRU 501032045300 3S-23 PA Plugged and Abandoned
KUP KRU 501032045301 3S-23A SUSP Suspended
KUP KRU 501032045600 3S-24 PA Plugged and Abandoned
KUP KRU 501032045601 3S-24A PA Plugged and Abandoned
KUP COYOTR01 501032045602 3S-24B PA Plugged and Abandoned
KUP KRU 501032036101 3S-26 PA Plugged and Abandoned
KUP MORTR04 501032077400 3S-611 ACTIVE Oil
KUP MORTR04 501032077470 3S-611PB1 PA Plugged and Abandoned
KUP MORTR04 501032077700 3S-612 ACTIVE Injector Miscible Water Alternating Gas
KUP MORTR03 501032073500 3S-613 ACTIVE Injector Produced Water
KUP MORTR05 501032084400 3S-615 ACTIVE Oil
KUP MORTR02 501032069500 3S-620 ACTIVE Oil
KUP MORTR05 501032084200 3S-625 ACTIVE Injector Produced Water
KUP COYOTR02 501032084700 3S-701 PA Plugged and Abandoned
KUP COYOTR02 501032084701 3S-701A ACTIVE Injector Produced Water
KUP COYOTR03 501032084800 3S-704 ACTIVE Oil
KUP KRU 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 @ 5649' MD / 4092' TVD
3S-624 Wellbore Schematic
Grassroots Horizontal Moraine Producer
10-¾" 45.5# L-80 H563 @ 3,049’ MD / 2,555' TVD, 55° Inc
Conductor @ 155'
4-½" 12.6# P110S H563 @19,685' MD / 5,158' TVD
4-½”12.6# L80 H563-MS
9-и" Intermediate Hole
6-1/2" Production Hole
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7-з" 29.7# L-80 H563 @ 7,581' MD / 5,128' TVD, 73° Inc
1/24/2024
6" OD Swell Packer Frac sleeve
FW
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5-½” x 7-5/8" SLZXP Packer @6,603' MD / 4,661' TVD
TOC @ 3,435' MD / 2,778' TVD
Gauge Mandrel, Dual Opsis 5961' MD/4278' TVD 53° Inc
Top Torok (Moraine) @ 7690' MD / 5157' TVD
Rigless ESP, ACP 6170' MD/4403' TVD 53° Inc
Sliding sleeve (3.813" ID) 6263' MD/4458' TVD 53° Inc
Gas Lift Mandrel, 4-½” x 1” (DV installed) 4491' MD/3400' TVD 53° Inc
Gas Lift Mandrel, 4-½” x 1” (SOV sheard) 2105' MD/1975' TVD 41° Inc
Alpha Sleeve (close)
WIV (open)
6-½" TD @ 20,485' MD / 5,156' TVD, 90° INC
4-½” x 7-5/8" Production Packer @6368' MD/4521' TVD
Swell Packer #24 @6,965' MD
Swell Packer #23 @7,458' MD
7-з" 29.7# L80 H563 to 6,862' MD
7-з" 33.7# P-110S H563 from 6,862' to 7,453' MD (heavy heel)
Diesel Freeze Protect
9.5# Corrosion Inhibited Brine
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 on12/16/2023 shows that the original job pumped as
designed. The cement job was pumped with 477 barrels of 10.7 ppg lead cement and 56 barrels
of 15.8ppg tail cement, displaced with 9.8ppg mud. The plug was bumped and the floats held.
260 barrels of 10.7ppg cement came to surface. No losses during cement job.
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).
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 12/18/2023 the 10-3/4” casing was pressure tested to 3,000 psi for 30 minutes
On 12/24/2023 the 7-5/8” casing was pressure tested to 4,000 psi for 30 minutes.
On 1/21/2024 the 4-1/2” tubing was pressure tested to 4,550 psi. Good Test
On 1/21/2024 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) 7,000
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 4,000
Electronic PRV 8,000
Highest pump trip 7,500
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 2,474
7-5/8” 29.7 L-80 6,885 4,789
7-5/8” 33.7 P-110S 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 250 ft
TVD over the course of the lateral section of well 3S-624, from where it intersects the top
formation at 7,690’ 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 820’ TVD. The top of the Torok confining
intervals starts at 4,511’ TVDSS (6457’ MD). The estimated fracture gradient of the
overlying Torok formation is approximately 0.82 psi/ft.
The underlying confining zone 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 top of the HRZ is estimated to be at
5,525 ft TVDSS at the heel, and 5,465’ 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)
The plat shows the location and orientation of each well that transects the confining zone.
ConocoPhillips has formed the opinion, based on following assessments for each well and
seismic, well, and other subsurface information currently available that none of these wells will
interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the
proposed wellbore trajectory.
Casing & Cement assessments for all wells that transect the confining zone:
3S-15: 7” casing cement pump report on 1/24/2003 shows that job was pumped as designed.
The cement job was pumped with 30 barrels of 12.8 ppg mudpush XI and 59 barrels of Class G
cement displaced with 8.5ppg seawater. The plug bumped at 750psi, and the floats were
checked and they held.
3S-17: 7” casing cement pump report on 5/2/2003 shows that job was pumped as designed.
The cement job was pumped with 50 barrels of 12.5 ppg mudpush XI and 62 barrels of 15.8ppg
Class G cement displaced with 8.5ppg seawater. The plug bumped at 2,150psi, and the floats
were checked and they held.
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-624 wellbore trajectory. While the fault doesn’t intersect the 3S-624 or any
other nearby well trajectories, it is interpreted to have offset the toe section of the adjacent 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. 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-624 was completed in 2024 as a horizontal producer in the Torok formation. The well was
completed with a 4-1/2” tubing upper completion and a 4-1/2” liner with a frac 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. At Stage 22, the collet with ball is dropped to
open the specific frac sleeve which is different from the Stage 2-21 frac sleeves.
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 all Pre-frac Well work has been completed and confirm the tubing and annulus
are filled with a freeze protect fluid to 1,975’ TVD.
3. Pressure test the rig installed frac tree to 10,000 psi.
4. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC.
5. MIRU 30 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a
single tank volume plus 10%. Load tanks with 100º F seawater are required for each
stage with breakdown, maximum pad and pumping down the next ball or collet. (450
bbls usable volume per tank).
6. MIRU HES Frac Equipment.
7. PT Surface lines to 10,000 psi using a Pressure test fluid.
8. Test IA Pop off system to ensure lines are clear and all components are functioning
properly.
9. Bring up pumps and increase annulus pressure from 2,500 psi to 3,500 psi as the
tubing pressures up.
10. Pump the 450 bbl breakdown stage (30# Hybor G) according to the attached excel
HES pump schedule during Stage 2. Bring pumps up to maximum rate of 37 BPM as
quick as possible, pressure permitting. Ensure sufficient volume is pumped to load the
well with Frac fluid, prior to shut down.
11. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates.
12. Pump the 22 stage Frac job by following attached HES schedule @ ~37bpm with a
maximum expected treating pressure of 7,000 psi.
13. RDMO HES Equipment. Freeze Protect the tubing and wellhead if not able to
complete following the flush.
14. Well is ready for Post Frac well prep/production tree installation, coiled tubing cleanout
and flowback (Slickline and possibly CTU).
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:
Oil Search
Well Name and Number:3S-624
API Number:
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From:Brooks, Phoebe L (OGC)
To:Rig 142
Cc:Regg, James B (OGC)
Subject:RE: Emailing: 3S-624 12-18-23.xlsx
Date:Tuesday, January 30, 2024 1:49:00 PM
Attachments:Doyon 142 12-18-23.xlsx
Frank,
Only one test type can be included, so I've attached a revised report to just include Initial since it's the first report for
KRU 3S-624. Please update your copy.
Thank you,
Phoebe
Phoebe Brooks
Research Analyst
Alaska Oil and Gas Conservation Commission
Phone: 907-793-1242
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the
Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended
recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of
such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,
without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact
Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov.
-----Original Message-----
From: Rig 142 <rig142@doyondrilling.com>
Sent: Monday, December 18, 2023 4:45 PM
To: Regg, James B (OGC) <jim.regg@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; DOA
AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>
Cc: Doyon 142 Company Man <d142cm@conocophillips.com>
Subject: Emailing: 3S-624 12-18-23.xlsx
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open
attachments unless you recognize the sender and know the content is safe.
Doyon Rig142, 12.18.23 BOP test attached, Frank Your message is ready to be sent with the following file or link
attachments:
3S-624 12-18-23.xlsx
Note: To protect against computer viruses, e-mail programs may prevent sending or receiving certain types of file
attachments. Check your e-mail security settings to determine how attachments are handled.
.XSDUXN5LYHU8QLW6
37'
revised report first report
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
SSub m it to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner: Rig No.:142 DATE: 12/18/23
Rig Rep.: Rig Email:
Operator:
Operator Rep.: Op. Rep Email:
Well Name:PTD #22231040 Sundry #
Operation: Drilling: X Workover: Explor.:
Test: Initial: X Weekly: Bi-Weekly: Other:
Rams:250/5000 Annular:250/3500 Valves:250/5000 MASP:1789
MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 1P
Permit On Location P Hazard Sec.P Lower Kelly 1P
Standing Order Posted P Misc.NA Ball Type 2P
Test Fluid Water Inside BOP 1P
FSV Misc 0NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0NATrip Tank PP
Annular Preventer 1 13-5/8" 5M P Pit Level Indicators PP
#1 Rams 1 3-1/2" x 6" VBR P Flow Indicator PP
#2 Rams 1 Blind/ Shear P Meth Gas Detector PP
#3 Rams 1 3-1/2" x 6" VBR P H2S Gas Detector PP
#4 Rams 0NAMS Misc 0NA
#5 Rams 0NA
#6 Rams 0NAACCUMULATOR SYSTEM:
Choke Ln. Valves 1 3-1/8" 5M P Time/Pressure Test Result
HCR Valves 2 3-1/8" 5M P System Pressure (psi)3000 P
Kill Line Valves 3 3-1/8" 5M P Pressure After Closure (psi)1850 P
Check Valve 0NA200 psi Attained (sec)11 P
BOP Misc 0NAFull Pressure Attained (sec)54 P
Blind Switch Covers: All stations Yes
CHOKE MANIFOLD:Bottle Precharge:P
Quantity Test Result Nitgn. Bottles # & psi (Avg.): 6 at 1967psi P
No. Valves 14 P ACC Misc 0NA
Manual Chokes 1P
Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result
CH Misc 0NA Annular Preventer 18 P
#1 Rams 7 P
Coiled Tubing Only:#2 Rams 7 P
Inside Reel valves 0NA #3 Rams 7 P
#4 Rams 0 NA
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:0 Test Time:5.0 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 12/16/23 09:00
Waived By
Test Start Date/Time:12/17/2023 22:00
(date) (time)Witness
Test Finish Date/Time:12/18/2023 3:00
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Brian Bixby
Doyon
F. Carlo/H. Huntington
Conoco
Mike Tucker/Mickey Arthur
KRU 3S-624
Test Pressure (psi):
rig142@doyondrilling.com
d142cm@conocophillips.com
Test Annular w/ 5" test jt 250/3500psi, Test upper & 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, 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 is on 3-
week test cycle.
Form 10-424 (Revised 08/2022) 2023-1218_BOP_Doyon142_KRU_3S-624
9 9
9
9
9999
9
9
-5HJJ
From:Rig 142
To:Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay
Subject:Emailing: 3S-624 1-12-24 AOGCC Form.xlsx
Date:Sunday, January 14, 2024 7:37:04 AM
Attachments:3S-624 1-12-24 AOGCC Form.xlsx
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open
attachments unless you recognize the sender and know the content is safe.
Rig142 BOP test form attached,
Frank
Your message is ready to be sent with the following file or link attachments:
3S-624 1-12-24 AOGCC Form.xlsx
Note: To protect against computer viruses, e-mail programs may prevent sending or receiving certain types of file
attachments. Check your e-mail security settings to determine how attachments are handled.
.586
37'
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
SSu bmit to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner: Rig No.:142 DATE: 1/12/24
Rig Rep.: Rig Email:
Operator:
Operator Rep.: Op. Rep Email:
Well Name:PTD #2231040 Sundry #
Operation: Drilling: X Workover: Explor.:
Test: Initial: Weekly: Bi-Weekly: Other: X
Rams:250/4000 Annular:250/3500 Valves:250/4000 MASP:1789
MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 1P
Permit On Location P Hazard Sec.P Lower Kelly 1P
Standing Order Posted P Misc.NA Ball Type 2P
Test Fluid Water Inside BOP 1P
FSV Misc 0NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0NATrip Tank PP
Annular Preventer 1 13-5/8" 5M P Pit Level Indicators PP
#1 Rams 1 3-1/2" x 6" VBR P Flow Indicator PP
#2 Rams 1 Blind/ Shear P Meth Gas Detector PP
#3 Rams 1 3-1/2" x 6" VBR P H2S Gas Detector PP
#4 Rams 0NAMS Misc 0NA
#5 Rams 0NA
#6 Rams 0NAACCUMULATOR SYSTEM:
Choke Ln. Valves 1 3-1/8" 5M P Time/Pressure Test Result
HCR Valves 2 3-1/8" 5M P System Pressure (psi)3000 P
Kill Line Valves 3 3-1/8" 5M P Pressure After Closure (psi)1850 P
Check Valve 0NA200 psi Attained (sec)4 P
BOP Misc 0NAFull Pressure Attained (sec)46 P
Blind Switch Covers: All stations Yes
CHOKE MANIFOLD:Bottle Precharge:P
Quantity Test Result Nitgn. Bottles # & psi (Avg.): 6 @ 2000psi P
No. Valves 14 P ACC Misc 0NA
Manual Chokes 1P
Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result
CH Misc 0NA Annular Preventer 23 P
#1 Rams 18 P
Coiled Tubing Only:#2 Rams 16 P
Inside Reel valves 0NA #3 Rams 16 P
#4 Rams 0 NA
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:0 Test Time:8.5 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 01/12/24 19:15
Waived By
Test Start Date/Time:1/12/2024 13:30
(date) (time)Witness
Test Finish Date/Time:1/12/2024 22:00
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Austin McLeod
Doyon
F. Carlo/H. Huntington
Conoco
Adam Dorr/Byron Marmon
KRU 3S-624
Test Pressure (psi):
rig142@doyondrilling.com
d142cm@conocophillips.com
Test Annular w/ 4", 4 1/2" test jt 250/3500psi, Test upper & lower 3-1/2" x 6"VBR 250/4000psi w/ 4", 4 1/2" test jt. Test 2ea-
4"FOSV/ 1ea-4" Dart 250/4000psi Test manual & hydraulic choke to 2,000 psi, Choke valves 1-14, Choke & Kill Manuals & HCR,
4"Demco valve on Kill, Upper & Lower IBOP, 250/4000psi, test H2S, LEL, PVT & flow alarms/both audible and visual. All rams
functioned from both primary and remote controls. Drawdown conducted w/ 2 air, and 2 elec pumps. Rig is on 3-week test cycle.
Form 10-424 (Revised 08/2022) 2024-0112_BOP_Doyon142_KRU_3S-624
99
9
9
9999
9
9
-5HJJ
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________KUPARUK RIV UNIT 3S-624
JBR 03/01/2024
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
Good test
Test Results
TEST DATA
Rig Rep:Sam / HuntingtonOperator:ConocoPhillips Alaska, Inc.Operator Rep:Tucker / Arthur
Rig Owner/Rig No.:Doyon 142 PTD#:2231040 DATE:12/24/2023
Type Operation:DRILL Annular:
250/2500Type Test:OTH
Valves:
250/4000
Rams:
250/4000
Test Pressures:Inspection No:bopAGE231227064804
Inspector Adam Earl
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time
MASP:
1789
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 P2950
Pressure After Closure P1850
200 PSI Attained P10
Full Pressure Attained P50
Blind Switch Covers:PAll Stations
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 P15
#1 Rams P7
#2 Rams P7
#3 Rams P7
#4 Rams NA0
#5 Rams NA0
#6 Rams NA0
HCR Choke P2
HCR Kill P2
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-624
Conoco Phillips Alaska, Inc.
Permit to Drill Number: 223-104
Surface Location: 2717' FSL, 1,262' FEL, NENE S18 T12N R8E
Bottomhole Location: 4167' FWL, 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 ___ day of November 2023.
Brett W. Huber,
Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.11.20 12:42:03 -09'00'
20
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: 20314 TVD: 5153
4a. Location of Well (Governmental Section):7. Property Designation:
Surface:
Top of Productive Horizon:8.DNR Approval Number:13. Approximate Spud Date:
11/26/2023
Total Depth:9. Acres in Property:14. Distance to Nearest Property:
3199' to ADL025528
4b. Location of Well (State Base Plane Coordinates - NAD 27): 10.KB Elevation above MSL (ft): 63.3 15. Distance to Nearest Well Open
Surface: x-475998 y- 5993853 Zone- 4 24.3 to Same Pool: 3840' to 3S-611
16. Deviated wells:Kickoff depth: 300 feet 17.Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 91 degrees Downhole:Surface:
Hole Casing Weight Grade Coupling Length MD TVD MD TVD
42" 20"154 H-40 Welded 81 39 39 120 120
13.5" 10.75"45.5 L-80 Hyd563 3013 39 39 3052 2551
9.875" 7.625"29.7 L80 Hyd563 7169 39 39 7208 4997
9.875" 7.625"33.7 P110S Hyd563 500 7208 4997 7708 5167
6.5" 4.5"12.6 P110S Hyd563 12756 7558 5126 20314 5153
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: Shane McCracken
Chris Brillon Contact Email:shane.m.mccracken@cop.com
Wells Engineering Manager Contact Phone:907-265-6926
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
10 yds
P.O. Box 100360 Anchorage, Alaska, 99510-0360 Kuparuk River Field
Torok Oil Pool
2717' FSL, 4018' FWL, NENE S18 T12N R8E ADL380107 / ADL380106 / ADL025528 / ADL393883
(including stage data)
1645' FSL, 914' FWL, NWSW S7 T12N R8E LONS 01-013
3199' FSL, 4167' FWL, NENE S35 T13N R7E 2448 / 2437 / 2560 / 5760
GL / BF Elevation above MSL (ft):
2339 1789
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 KRU 3S-624
930sks 10.7ppg, 280sks 15.8ppg
650sks 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.
Stratigraphic Test
Nooo Mud log req'd: Yes No o
No Directional svy req'd: Yes Nooo
Seabed ReportDrilling Fluid Program 20 AAC 25.050 requirements
BOP SketchDrillingProgram Time v. Depth PlotShallow HazardAnalysis
Single Well
GasHydrates
Noooo Inclination-only svy req'd: Yes No ooo
Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal
Noooo
sNo
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 7:59 am, Oct 30, 2023
50-103-20868-00-00
A.Dewhurst 13NOV23
-A.Dewhurst 13NOV23
Initial BOP test to 5000 psig; subsequent BOP test to 3500 psig
Annular preventer test to 2500 psig
Waiver for CPAI Rotary 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
Diverter variance request granted per 20 AAC 20.035(h)(2), based on CPAI
offset analysis of 3S-611, 3S-611PB1, 3S-612, and 3S-17 -A.Dewhurst 13NOV23
1,262' FEL
DSR-11/2/23
223-104
VTL 11/20/2023
X
JLC 11/20/2023
Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr.
Date: 2023.11.20 12:43:00 -09'00'11/20/23
11/20/23
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'
<Zhϯ^ͲϲϮϰ
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.
ConocoPhillips Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907-276-1215
October 25, 2023
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
Re: Application for Permit to Drill 3S-624
Dear Sir or Madam:
ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Moraine producer well from the 3S drilling pad.
The intended spud date for this well is 11/26/2023. It is intended that Doyon 142 be used to drill the well.
3S-624 will utilize a 13 1/2” surface hole drilled to TD and 10 3/4” casing will be set and cemented to surface. 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 producer with 4 1/2” liner, frac sleeves and swell
packers. The upper completion will include a production packer with GLM’s and an ESP. It will be 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-624. 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 Shane McCracken at 907-265-6926
(shane.m.mccracken@conocophillips.com) or Chris Brillon at 907-265-6120.
Sincerely, cc:
3S-624 Well File / Jenna Taylor ATO 1560
David Lee ATO 1552
Shane McCracken Chris Brillon ATO 1548
Drilling Engineer Roland Kirschner ATO 636
a variance of the diverter requirement u
Application for Permit to Drill, 3S-624
Saved: 25-Oct-23
3S-624 PTD
Page 1 of 9
Printed: 25-Oct-23
3S-624
Application for Permit to Drill Document
Table of Contents
1. Well Name (Requirements of 20 AAC 25.005 (f)) ........................................................................................................ 2
2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) ......................................................................................... 2
3. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) ........................................................................ 3
4. Blowout Prevention Equipment (Requirements of 20 AAC 25.005(c)(3)) ............................................................. 4
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 ..................................................................................................................... 10
1. Well Name (Requirements of 20 AAC 25.005 (f))
The well for which this application is submitted will be designated as 3S-624
2. Location Summary (Requirements of 20 AAC 25.005(c)(2))
Location at Surface 2717‘ FSL, 4018‘ FWL, NENE S18 T12N R8E, UM
NAD 1927
Northings: 5993853
Eastings: 475998
RKB Elevation 63.3’AMSL
Pad Elevation 24.3’AMSL
Top of Productive Horizon
(Heel) 1645‘ FSL, 914‘ FWL, NWSW S7 T12N R8E, UM
NAD 1927
Northings: 5998071
Eastings: 472891
Measured Depth, RKB: 7,800’
Total Vertical Depth, RKB: 5,186’
Total Vertical Depth, SS: 5,123’
Total Depth (Toe) 3199‘ FSL, 4167‘ FWL, NENE S35 T13N R7E, UM
NAD 1927
Northings: 6010197
Eastings: 469819
Measured Depth, RKB: 20,314 ’
Total Vertical Depth, RKB: 5,153’
Total Vertical Depth, SS: 5,089’
Pad Layout
1,262' FEL
3. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13))
The proposed drilling program is listed below. Please refer to Section 16: Completion Schematic.
1. MIRU Doyon 142 onto 3S-624.
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 16 ppg. Minimum LOT required to drill ahead is 11.5
ppg EMW.
10. Drill 9 7/8” hole to section TD, setting pipe ~20’ TVD above the Moraine Reservoir. (LWD Program: GR/RES).
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). Chart casing pressure test on plug bump to 4,000 psi for 30 minutes.
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. 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.
15. Drill 6 1/2” hole to section TD (LWD Program: GR/RES/Den/Neu).
16. Pull out of hole with drilling BHA. Review cement job details and sonic log TOC.
17. Run 4 1/2” liner with toe-valve, frac sleeves and swell packers and liner hanger to TD.
18. Run 4 1/2” upper completion with glass plug, production packer, sliding sleeve, electric submersible pump, downhole
gauge, and gas lift mandrels. Space out and land tubing hanger with pre-installed and pre-tested BPV.
19. Pressure test hanger seals to 3,850 psi.
20. Pressure against the glass plug to set production packer, test tubing to 3,850 psi, chart test.
21. Bleed tubing pressure to 2200 psi and test IA to 3,850 psi, chart test.
22. Install HP-BPV and test to 2500 psi.
23. Nipple down BOP.
24. Install tubing head adapter assembly. N/U tree and test to 5000 psi/10 minutes.
25. Freeze protect down tubing and annulus.
26. 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.
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 4 previously drilled wells
(3S-611, 3S-611PB1, 3S-612, and 3S-17) within 500’ of the proposed 3S-624 surface shoe. 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)
20 120 / 120 10.9 54 56
10 3/4 3,052 / 2,551 12.5 1141 1403
7 5/8 7,708 / 5,167 13.5 2310 1789
4 1/2 20,314 / 5,153 13.0 2304 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 120 = 56 psi
OR
ASP = FPP – (0.1 x D)
= 1141 – (0.1 x 2,551) = 886 psi
2. Drilling below 10-3/4” surface casing
ASP = [(FG x 0.052) – 0.1] D
= [(12.5 x 0.052) – 0.1] x 2,551 = 1403 psi
OR
ASP = FPP – (0.1 x D)
= 2310 – (0.1 x 5,167) = 1793 psi
3. Drilling below 10-3/4” intermediate casing
ASP = [(FG x 0.052) – 0.1] D
= [(13.5 x 0.052) – 0.1] x 5,167 = 2748 psi
OR
ASP = FPP – (0.1 x D)
= 2304– (0.1 x 5,153 )= 1789 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 42 154 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
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 Un-cemented liner with frac sleeves and swell packers
Cementing Calculations
10 3/4” Surface Casing run to 3,052 ’ MD / 2,551 ’ TVD
Cement from 3,052’ MD to 2,552' (500’ of tail) with Class G + Add's @ 15.8 PPG, and from 2,552' to surface with 10.7
ppg Arctic Lite Crete. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost, zero
excess in 20” conductor.
Lead slurry from 2,552’ MD to surface with Arctic Lite Crete @ 10.7 ppg
Total Volume = 2,687 ft3 => 930 sx of 10.7 ppg Class G + Add's @ 2.92 ft3 /sk
Tail slurry from 3,052 ’ MD to 2,552’ MD with 15.8 ppg Class G + Add's
Total Volume = 316 ft3 => 280 sx of 15.8 ppg Class G + Add's @ 1.16 ft3/sk
7 5/8” Intermediate Casing run to 7,708’ MD / 5,167’ TVD
Top of slurry is designed to be at 5,134 ’ MD, which is 500’MD or 250’ TVD above the prognosed 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 7,708’ MD to 5,134’ MD with 15.3 ppg Class G + Add's
Total Volume = 796 ft3 => 647 sx of 15.3 ppg Class G + Add’s @ 1.23 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 10.5 ppg by use of solids control system and dilutions
where necessary.
Intermediate:
Arctic Lite Crete
Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular
velocity. Maintain mud weight at or below 9.8 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 9.8 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 9.0 – 10.0
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, LCM on location
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, containing an original 26 wells. 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 production and injection has the potential to increase or decrease reservoir pressure above or below
normally pressured. 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.
H2S on 3S pad – There have been elevated H2S levels noted on the 3S pad post drilling. Below table is readings for wells with
the highest concentrations. The rig will have H2S sensors which will be tested, escape packs staged around the rig, and personal
monitors will be worn by the core crew members. A detailed emergency operating procedure will be communicated to all
personnel, in the event H2S is encountered.
Well Name H2S Date Reading (ppm)
3S-704 05/13/2023 100
3S-615 03/10/2023 160
3S-625 01/01/2023 200
3S-620 04/23/2022 110
3S-19 01/02/2022 154
3S-18 08/03/2020 128
3S-10 10/01/2019 100
3S-19 12/06/2022 96
16. Proposed Completion Schematic
Top Coyote@ 5,634' MD / 4,091' TVD
3S-624 Planned Wellbore Schematic
Grassroots Horizontal Moraine Producer
Surface Casing: 10-¾" 45.5#, L-80, Hydril 563 @
3,052’ MD / 2,551' TVD, 53° INC
Conductor: 20" driven to +/-120'
Production Liner: 4-½" 12.6#, L-80, Hydril 563
@ 20,314' MD / 5,153' TVD, 90° INC
Tubing: 4-½”12.6#, L-80, Hydril 5639-и" Intermediate Hole
6-1/2" Production Hole
Kl
a
S
h
i
e
l
d
W
B
M
13-½" Surface Hole
Intermediate Casing: 7-з" 29.7#, L80, Hydril 563 /
500' 33.7#, P110S, Hyd563 Heavy Heel @ 7,708'
MD / 5,167' TVD, 77° Inc
Updated: 10/25/2023
6-1/8" OD Swell Packer Frac sleeve
FW
P
Sp
u
d
M
u
d
5-½” x 7-5/8" Liner Top Packer
4-½” x 7-5/8" Production Packer
TOC
(500' MD / 250' TVD above Top Coyote)
Downhole Dual Gauge
TOC @ Surface
3S-624 wp07.1
Planned Depths
Top Torok Oil Pool (Moraine) @ 7,800' MD / 5,186' TVD
Rigless ESP (wireline retrievable pump/motor) @ 6,500' MD
Sliding sleeve (3.813" ID)
Gas Lift Mandrel, 4-½” x 1-½”
Gas Lift Mandrel, 4-½” x 1-½”
WIV/Alpha Sleeve
39 258
258 448
448 648
648 838
838 1028
1028 1228
1228 1418
1418 1608
1608 2398
2398 3188
3188 3968
3968 4758
4758 5548
5548 6328
6328 7118
7118 7908
7908 9468
9468 11018
11018 12578
12578 14128
14128 15688
15688 17248
17248 18798
18798 20359
3S-624 wp07.1 Plan Summary
0
3
Do
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S
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v
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i
t
y
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]
1245129513441393144214911540158916363S-17
1245129513441393144214911540158916363S-17A
847896945
993
1041
1090
1138
1186
1234
1281
1329
13763S-18
653702751800849898
947
995
1043
1091
1138
1186
12323S-19
56106156206256306
355
404
453
501
549
3S-21
56106156206256306356406456505555604
653
702
751
799
848
896
944
9923S-22
58
108
158208258308358408458508558608658708
758808857907956
10063S-23 56
106
156206256306356405455505555605655705
755805855905954
10033S-23A 57107157
207257307357
407
456
505
553
601
3S-24
57107157
207257307357
407
456
505
553
601
3S-24A
58108158
208258307357
407
456
505
554
602
3S-24B
53103153203253303353403453503553603652
701
750
799
847
8943S-26
53103153203253303353403453503553603652
701
750
799
847
894PALM 1
3953103153203253303353403453502
552
601
650
698
746
3S-625
4797147197247297347397447497547598648698747
797
847
3S-626 wp04
885
933
981
1029
1076
1124
1171
12183S-719 wp03
4797147197247297346396445495544594643692741
790
838
887
935
984
10323S-721 wp03
4797147197247297346396446495544
593
6413S-722 wp04
0
2750
Tr
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0 2500 5000 7500 10000 12500 15000 17500
Vertical Section at 339.10°
10-3/4" Surface Casing
7-5/8" Intermediate Casing 4-1/2" Production Liner
0
18
35
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0 400 800 1200 1600 2000 2400 2800
Measured Depth
Equivalent Magnetic Distance
DDI
7.098
SURVEY PROGRAM
Date: 2021-02-19T00:00:00 Validated: Yes Version:
Depth From Depth To Survey/Plan Tool
39.00 1600.00 3S-624 wp07.1 (3S-624) SDI_URSA1_I4
1600.00 3050.00 3S-624 wp07.1 (3S-624) MWD+IFR2+SAG+MS
3050.00 7700.00 3S-624 wp07.1 (3S-624) MWD+IFR2+SAG+MS
7700.00 20314.28 3S-624 wp07.1 (3S-624) MWD+IFR2+SAG+MS
Ground / 24.30
CASING DETAILS
TVD MD Name
2551.30 3052.08 10-3/4" Surface Casing
5166.60 7708.00 7-5/8" Intermediate Casing
5152.70 20313.44 4-1/2" Production Liner
Mag Model & Date: BGGM2023 20-Dec-23
Magnetic North is 14.42° East of True North (Magnetic Declinatio
Mag Dip & Field Strength: 80.64° 57225.67nT
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
3 450.00 2.25 324.00 449.96 2.38 -1.73 1.50 324.00 2.84
4 600.00 5.25 324.00 599.62 10.32 -7.50 2.00 0.00 12.31
5 1551.47 29.04 324.00 1502.30 235.59 -171.16 2.50 0.00 281.14 Start 114.48 hold at 1555.36 MD
6 1665.84 29.04 324.00 1602.30 280.50 -203.79 0.00 0.00 334.74 Start DLS 3.00 TFO -5.23
7 2479.67 53.39 321.32 2209.95 701.68 -528.95 3.00 -5.21 844.20
8 6776.37 53.39 321.32 4772.22 3394.30 -2684.45 0.00 0.00 4128.56
9 8037.38 85.00 344.00 5219.53 4431.14 -3192.47 3.00 38.77 5278.40 Start Build 2.00
10 8237.38 89.00 344.00 5230.00 4623.09 -3247.51 2.00 0.00 5477.36 3S-624 [Chenega] T01 062923 Start 20.00 hold at 8239.94 MD
11 8257.38 89.00 344.00 5230.35 4642.31 -3253.02 0.00 0.00 5497.29 Start DLS 1.50 TFO 53.98
12 8400.72 90.26 345.74 5231.27 4780.67 -3290.43 1.50 53.98 5639.89 Start 3689.44 hold at 8403.28 MD
1312090.17 90.26 345.74 5214.21 8356.38 -4199.29 0.00 0.00 9304.58 Start DLS 1.00 TFO 10.46
14 12129.33 90.65 345.81 5213.90 8394.34 -4208.91 1.00 10.46 9343.47 3S-624 [Chenega] T02 062923 Start DLS 1.00 TFO 11.97
15 12173.74 91.08 345.90 5213.23 8437.41 -4219.76 1.00 11.97 9387.58 Start 2392.46 hold at 12176.31 MD
16 14566.20 91.08 345.90 5167.95 10757.39 -4802.41 0.00 0.0011762.78 Start DLS 1.00 TFO -162.57
17 14616.98 90.60 345.75 5167.20 10806.62 -4814.84 1.00 -162.5711813.20 3S-624 [Chenega] T03 062923 Start DLS 1.00 TFO -160.21
1814665.46 90.14 345.59 5166.89 10853.59 -4826.84 1.00 -160.2111861.36 Start 5648.82 hold at 14668.02 MD
19 20314.28 90.14 345.59 5152.70 16324.57 -6232.99 0.00 0.0017474.03 3S-624 [Chenega] T04 062923 TD at 20316.84
FORMATION TOP DETAILS
TVDPath Formation
1365.30 Top Ugnu C
1632.30 Top Ugnu B
1700.30 Base Permafrost
1740.30 Top Ugnu A
2023.30 Top West Sak
2518.30 Base West Sak
2601.30 C-80
3432.30 C-50
3886.30 C-35
4091.30Top Coyote (Nanushuk), K3
4575.30 Base Coyote (Nanushuk)
5186.30 Top Torok (Top Moraine)
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: 24.3+39 @ 63.30usft (D142)
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Ce
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t
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C
e
n
t
r
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S
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p
a
r
a
t
i
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0 450 900 1350 1800 2250
Partial Measured Depth
3S
-
1
7
3S
-
1
7
A
3S
-
1
8
3S
-19
3S
-
2
1
3S
-
2
2
3S
-
2
3
3S
-
2
3
A
3S-2
4
3S-2
4
A
3S-2
4
B
3S
-
2
6
PA
L
M
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3S
-
6
2
5
3S-
62
6
w
p
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4
3S
-
7
1
9
w
p
0
3
3S
-
7
2
1
w
p
0
3
3S
-
7
2
2
w
p
0
4
Equivalent Magnetic Distance
3S-624 wp07.1 Ladder View
0
150
300
Ce
n
t
r
e
t
o
C
e
n
t
r
e
S
e
p
a
r
a
t
i
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n
0 3000 6000 9000 12000 15000 18000
Measured Depth
3S
-
1
4
3S
-
1
5
3S
-
1
6
3S
-
1
7
3S
-
1
7
A
3S
-
1
8
3S
-19
3S
-
2
1
3S
-2
2
3S
-
2
3
3S
-
2
3
A
3S
-
24
3S
-
24
A
3S
-
2
4
B
3S
-
2
6
PA
L
M
1
3S
-6
1
1
3S
-
6
1
1
PB
1
3S
-
6
1
1
A
w
p
0
4
3S
-
61
2
3S
-
6
1
3
3S
-
6
1
5
3S
-
61
7
w
p
0
7
3S
-
6
2
0
3S
-
6
2
5
3S
-
6
1
0
w
p
0
5
3S
-62
6
w
p
0
4
3S
-
7
1
4
w
p
0
3
3S
-
7
1
8
w
p
0
4
3S
-71
9
w
p
0
3
3S
-
7
2
1
w
p
0
3
3S
-
7
2
2
wp
0
4
3S
-
72
3
w
p
0
2
Equivalent Magnetic Distance
SURVEY PROGRAM
Depth From Depth To Survey/Plan Tool
39.00 1600.00 3S-624 wp07.1 (3S-624) SDI_URSA1_I4
1600.00 3050.00 3S-624 wp07.1 (3S-624) MWD+IFR2+SAG+MS
3050.00 7700.00 3S-624 wp07.1 (3S-624) MWD+IFR2+SAG+MS
7700.00 20314.28 3S-624 wp07.1 (3S-624) MWD+IFR2+SAG+MS
12:38, October 18 2023
CASING DETAILS
TVD MD Name
2551.30 3052.08 10-3/4" Surface Casing
5166.60 7708.00 7-5/8" Intermediate Casing
5152.70 20313.44 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 15000
15000 20315
3S-624 wp07.1 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]
57107157207257306356405454503552601650699748797
3S-15
57107157207
257307356405454503551600648696743
791
3S-16
57107157207257307356405455504553603652702751800850
8999499981048109711471196124512951344139314421491154015891636168517351785183518861937198820392090
3S-17 57107157207257307356405455504553603652702751800850
8999499981048109711471196124512951344139314421491154015891636168517351785183518861937198820392090
57107157207257
307356
406455504554603652701750799847896945993
1041
1090
1138
1186
1234
1281
1329
1376
1423
1470
1516
1563
1610
1657
1703
3S-18
57107157
207257307357406456505
555604653702751800849898947
995
1043
1091
1138
1186
1232
1279
1325
1370
1416
1461
3S-19
56106156206256306355
404
453
501
549
596
643
688
733
776
819
861
3S-21
56106156206256306356406456505555604653
702
751
799
848
896
944
992
1040
1087
1134
1181
1227
1272
1317
1362
1405
3S-22
58
108
158208258308358408458508558608658708
7588088579079561006
1054
1102
1150
1197
1244
1289
3S-23
56
106
156206256306356405455505555605655705
7558058559059541003
1052
1100
1148
1195
1241
1287
57107157
207257307357407
456
505
553
601
648
693
737
780
822
3S-24
57107157
207257307357407
456
505
553
601
648
693
737
780
822
58108158
208258307357407
456
505
554
602
648
694
738
780
822
53103153203253303353403453503553603652701
750
799
847
894
941
988
1034
1080
1125
1169
1213
3S-26
53103153203253303353403453503553603652701
750
799
847
894
941
988
1034
1080
1125
1169
1213
PALM 1
2673272227712820286929172966
3015306331113159320632533300
3346
3392
3437
3483
3528
357336183663
3S-611 2338
2384
2429
2475
2523
257226222671272027692818286729003S-611PB1
2673272227712820286929182966
3015306331113159
32083256330433533401
34503498354735953643
3S-611A wp04
15931643169017361782182818741920
1966
201220582104
2150
2196
2242
2287
2333
2378
2424
2469
2516
2565
3S-612
400449497
5453S-615
501001502002503003493994484975465956436927407898378859339821030107711251173122012681315136214101456
1503
1550
3S-617 wp07
61
111161
211261311360410459508557606654703751800
848
895
943
991
1038
1085
1131
1177
1223
1269
1314
1358
3S-620
3953103153203253303353403453502
552
601
650
698
746
793
839
885
930
974
1018
3S-625
4797147197247297347397447497547598648698747797
847
896
945
994
1043
1091
1139
1187
1235
1282
1329
3S-626 wp04
4797147197247297346395445493542590
638
684
730
7753S-718 wp04
4797147197247297346395445494543593642690739788836
885
933
981
1029
1076
1124
1171
1218
1265
1311
1357
1403
1449
1494
1539
1585
3S-719 wp03
4797147197247297346396445495544594643692741790838
887
935
984
1032
1080
1127
1175
1222
1269
1316
1363
1409
1456
1502
1548
1595
1643
3S-721 wp03
4797147197247297346396446495544593
641
688
735
781
825
869
912
3S-722 wp04
SURVEY PROGRAM
Date: 2021-02-19T00:00:00 Validated: Yes Version:
From To Tool
39.00 1600.00 SDI_URSA1_I4
1600.00 3050.00 MWD+IFR2+SAG+MS
3050.00 7700.00 MWD+IFR2+SAG+MS
7700.00 20314.28 MWD+IFR2+SAG+MS
CASING DETAILS
TVD MD Name
2551.30 3052.08 10-3/4" Surface Casing5166.60 7708.00 7-5/8" Intermediate Casing
5152.70 20313.44 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
3 450.00 2.25 324.00 449.96 2.38 -1.73 1.50 324.00 2.84
4 600.00 5.25 324.00 599.62 10.32 -7.50 2.00 0.00 12.31
5 1551.47 29.04 324.00 1502.30 235.59 -171.16 2.50 0.00 281.14 Start 114.48 hold at 1555.36 MD
6 1665.84 29.04 324.00 1602.30 280.50 -203.79 0.00 0.00 334.74 Start DLS 3.00 TFO -5.23
7 2479.67 53.39 321.32 2209.95 701.68 -528.95 3.00 -5.21 844.20
8 6776.37 53.39 321.32 4772.22 3394.30 -2684.45 0.00 0.00 4128.56
9 8037.38 85.00 344.00 5219.53 4431.14 -3192.47 3.00 38.77 5278.40 Start Build 2.00
10 8237.38 89.00 344.00 5230.00 4623.09 -3247.51 2.00 0.00 5477.36 3S-624 [Chenega] T01 062923 Start 20.00 hold at 8239.94 MD
11 8257.38 89.00 344.00 5230.35 4642.31 -3253.02 0.00 0.00 5497.29 Start DLS 1.50 TFO 53.98
12 8400.72 90.26 345.74 5231.27 4780.67 -3290.43 1.50 53.98 5639.89 Start 3689.44 hold at 8403.28 MD
1312090.17 90.26 345.74 5214.21 8356.38 -4199.29 0.00 0.00 9304.58 Start DLS 1.00 TFO 10.46
1412129.33 90.65 345.81 5213.90 8394.34 -4208.91 1.00 10.46 9343.47 3S-624 [Chenega] T02 062923 Start DLS 1.00 TFO 11.97
1512173.74 91.08 345.90 5213.23 8437.41 -4219.76 1.00 11.97 9387.58 Start 2392.46 hold at 12176.31 MD
1614566.20 91.08 345.90 5167.95 10757.39 -4802.41 0.00 0.0011762.78 Start DLS 1.00 TFO -162.57
1714616.98 90.60 345.75 5167.20 10806.62 -4814.84 1.00 -162.5711813.20 3S-624 [Chenega] T03 062923 Start DLS 1.00 TFO -160.21
1814665.46 90.14 345.59 5166.89 10853.59 -4826.84 1.00 -160.2111861.36 Start 5648.82 hold at 14668.02 MD
19 20314.28 90.14 345.59 5152.70 16324.57 -6232.99 0.00 0.0017474.03 3S-624 [Chenega] T04 062923 TD at 20316.84
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39
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3S-624wp07.1 Intermediate Csg
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3S-624wp07.1 Top Torok
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3S-624wp07.1 TD
3S-624wp07.1 TD
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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.
KUPARUK RIVER
TOROK OIL POOL
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KRU 3S-624
223-104
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14
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15
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16
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17
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18
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20
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No
21
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22
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23
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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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P
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30
BO
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p
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Ye
s
31
Ch
o
k
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s
32
Wo
r
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w
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Ye
s
33
Is
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2
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s
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b
a
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e
NA
34
Me
c
h
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35
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e
n
s
u
l
f
i
d
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m
e
a
s
u
r
e
s
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s
Re
s
e
r
v
o
i
r
p
o
r
e
p
r
e
s
s
u
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a
n
t
i
c
i
p
a
t
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d
t
o
b
e
8
.
6
p
p
g
E
M
W
.
M
a
y
v
a
r
y
d
u
e
t
o
o
f
f
s
e
t
p
r
o
d
u
c
t
i
o
n
a
n
d
i
n
j
e
c
t
i
o
n
36
Da
t
a
p
r
e
s
e
n
t
e
d
o
n
p
o
t
e
n
t
i
a
l
o
v
e
r
p
r
e
s
s
u
r
e
z
o
n
e
s
NA
37
Se
i
s
m
i
c
a
n
a
l
y
s
i
s
o
f
s
h
a
l
l
o
w
g
a
s
z
o
n
e
s
NA
38
Se
a
b
e
d
c
o
n
d
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t
i
o
n
s
u
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v
e
y
(
i
f
o
f
f
-
s
h
o
r
e
)
NA
39
Co
n
t
a
c
t
n
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m
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p
h
o
n
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f
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r
w
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k
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g
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s
s
r
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p
o
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s
[
e
x
p
l
o
r
a
t
o
r
y
o
n
l
y
]
Ap
p
r
AD
D
Da
t
e
11
/
1
3
/
2
0
2
3
Ap
p
r
VT
L
Da
t
e
11
/
2
0
/
2
0
2
3
Ap
p
r
AD
D
Da
t
e
11
/
1
3
/
2
0
2
3
Ad
m
i
n
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s
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r
a
t
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En
g
i
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e
e
r
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g
Ge
o
l
o
g
y
Ge
o
l
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c
Co
m
m
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s
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r
:
Da
t
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:
En
g
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m
m
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s
s
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r
:
Da
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Pu
b
l
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m
m
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s
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r
Da
t
e
JL
C
1
1
/
2
0
/
2
0
2
3
