Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout222-1011. 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):
23770' 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
(907) 263-4529
CTD/RWO Engineer
KRU 3S-615
5201' 23770' 5201' 1417 None
N/A
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
AOGCC USE ONLY
Tubing Grade: Tubing MD (ft):
11271' MD and 4991' TVD
11531'MD and 5075' TVD
N/A
Adam Klem
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0025528, ADL0025544, ADL0380107
222-101
P.O. Box 100360, Anchorage, AK 99510 50-103-20844-00-00
Kuparuk River Field Torok Oil Pool
ConocoPhillips Alaska, Inc.
Length Size
Proposed Pools:
PRESENT WELL CONDITION SUMMARY
Torok Oil Pool
TVD Burst
11537' MD
MD
114'
2543'
5130'
114'
3069'
20"
10-3/4"
78'
7-5/8"11671'
3032'
11706'
None
4-1/2"
None
Perforation Depth TVD (ft):
1/15/2026
23756'12225'
4-1/2"
5201'
Packer: HAL TNT Production Packer
ZXP Liner Top Packer
SSSV: None
Perforation Depth MD (ft):
L-80
m
n
P
s
66
t
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
oregoing is true and the
325-752
By Grace Christianson at 8:19 am, Dec 11, 2025
AOGCC witnessed BOP and Annular test to 2500 psi.
Ensure packer is set below production casing TOC.
J.Lau 12/30/25
10-404
DSR-12/11/25
X
TS 12/15/25
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-615 (PTD#
222-101).
Well 3S-615 was spudded in October of 2022 and completed in December of 2022. The well was initially brought
online with the ESP. However, due to several factors, it was needed to be converted to gas lift. While attempting
to pull the pumps and motor, issues were encountered. After several fishing attempts, they were able to be
retrieved but drift issues were discovered as the culprit.
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-615 Moraine Producer Pull and Replace ESP Completion PTD: 222-101
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. Set plug in 3.562 DB nipple at 11,345
5. PT tbg and IA to 2,500 psi for 30 minutes.
6. Shift sliding sleeve or pull valve from GLM for circulation point.
7. Cut tubing at ~11,250 MD
8. Prepare well for rig arrival.
Rig Work
MIRU
1. MIRU Nabors 7ES on 3S-615. 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 ~11,250 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.
Post-Rig Work
1. Pull SOV. Install new DMY.
3S-615 Moraine Producer Pull and Replace ESP Completion PTD: 222-101
Page 2 of 2
2. Pull ball and rod, RHC plug
3. Pull pre rig set plug
4. Install retrievable AccessESP assembly.
General Well Information:
Estimated Start Date:
Current Operations:
Well Type:
Wellhead Type:
1/15/2
Flowing on gas lift
Producer
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
IC POT & PPPOT: Passed when installed
Static BHP: 1,878 psi / 4,613 TVD measured on 3/5/24
MPSP: 1417 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@ 8,325' MD / 4,113' TVD
3S-615 Wellbore Schematic
Grassroots Horizontal Moraine Producer
Surface Casing: 10-¾" 45.5#, L-80, Hydril 563 @
3,069 MD / 2,543' TVD, 63° INC
Conductor: 20" driven to +/-119'
Production Liner: 4-½" 12.6#, L-80, Hydril 563
@ 23,756' MD / 5,201' TVD, 90° INC
Tubing: 4-½12.6#, L-80, Hydril 5639-" Intermediate Hole
6-1/2" Production Hole
13-½" Surface Hole
Intermediate Casing: 7-" 29.7#, L80, Hydril 563 /
500' 33.7#, P110S, Hyd563 Heavy Heel @ 11,707'
MD / 5,130' TVD, 72° Inc
Updated: 12/18/2022
by K. Herring
4-½ x 6" OD Swell Packer Frac sleeve (ball drop)
3.562" DB Landing Nipple @ 11,345' MD
5-½ x 7-5/8" ZXP Packer @ 11,531' MD
5-½ x 7-5/8" Flexlock Hanger @ 11,553' MD
4-½ x 7-" Halliburton TNT @ 11,270' MD
TOC 5,620' / 3,340' TVD
(773' TVD above hydrocarbon bearing zone)
Downhole Gauge @ 10,085' MD
TOC @ Surface
As Drilled
Top Torok Oil Pool (Moraine) @ 11,740' MD / 5141' TVD
Rigless ESP (wireline retrievable pump/motor) @ 10,225' MD
Sliding sleeve w/3.813" X profile @ 10458' MD
Gas Lift Mandrel, 4-½ x 1-½ @ 6,417' MD
Gas Lift Mandrel, 4-½ x 1-½ @ 2,951' MD
WIV/Alpha Sleeve
Top Coyote@ 8,325' MD / 4,113' TVD
3S-615 Wellbore Schematic
Grassroots Horizontal Moraine Producer
Surface Casing: 10-¾" 45.5#, L-80, Hydril 563 @
3,069 MD / 2,543' TVD, 63° INC
Conductor: 20" driven to +/-119'
Production Liner: 4-½" 12.6#, L-80, Hydril 563
@ 23,756' MD / 5,201' TVD, 90° INC
Tubing: 4-½12.6#, L-80, Hydril 5639-" Intermediate Hole
6-1/2" Production Hole
KlaShield WBM13-½" Surface Hole
Intermediate Casing: 7-" 29.7#, L80, Hydril 563 /
500' 33.7#, P110S, Hyd563 Heavy Heel @ 11,707'
MD / 5,130' TVD, 72° Inc
Updated: 9/3/25 by
Adam Klem
4-½ x 6" OD Swell Packer Frac sleeve (ball drop)LSNDSpud Mud3.562" DB Landing Nipple @ 11,345' MD
5-½ x 7-5/8" ZXP Packer @ 11,531' MD
5-½ x 7-5/8" Flexlock Hanger @ 11,553' MD
4-½ x 7-" Halliburton TNT @ 11,270' MD
TOC 5,620' / 3,340' TVD
(773' TVD above hydrocarbon bearing zone)
Downhole Gauge
TOC @ Surface
Proposed
Top Torok Oil Pool (Moraine) @ 11,740' MD / 5141' TVD
Rigless ESP (wireline retrievable pump/motor) @ ~10,225' MD
Sliding sleeve w/3.813" X profile
Gas Lift Mandrel, 4-½ x 1-½
Gas Lift Mandrel, 4-½ x 1-½
WIV/Alpha Sleeve
3.813" X nipple
4-½ x 7-" Packer w/ seals
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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:Convert ESP to GL
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 23770'feet None feet
true vertical 5201' feet None feet
Effective Depth measured 23770'feet 11271', 11531'feet
true vertical 5201' feet 4990', 5075' feet
Perforation depth Measured depth
True Vertical depth
Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 11537' MD
Packers and SSSV (type, measured and true vertical depth) 11271' MD
11531' MD
N/A
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure: N/A
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: Contact Name:
Contact Email:
Authorized Title:Contact Phone:
3069' 2543'
Burst Collapse
Production
Liner
11671'
12225'
Casing
5130'
4-1/2"
11706'
23756' 5201'
3032'
114'Conductor
Surface
Intermediate
20"
10-3/4"
77'
measured
TVD
7-5/8"
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
222-101
50-103-20844-00-0
P.O. Box 100360
Anchorage, AK 99510
3. Address:
ConocoPhillips Alaska, Inc.
N/A
5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work:
ADL0025528, ADL0025544, ADL0380107
Kuparuk River Field/ Torok Oil Pool
KRU 3S-615
Plugs
Junk measured
Length
measured
true vertical
Packer
Representative Daily Average Production or Injection Data
Casing Pressure Tubing Pressure
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
1250
Gas-Mcf
MD
220
Size
114'
2050 1330775
1300 1954300
300
324-086
Sr Pet Eng: Sr Pet Geo: Sr Res Eng:
WINJ WAG
1800
Water-BblOil-Bbl
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
N/A
Packer: HAL TNT Prod Packer
Packer: ZXP Packer
SSSV: None
Sydney Autry
sydney.autry@conocophillips.com
265-6813Senior Production Engineer
Frac Sleeves: 11965-23594'
Frac Sleeves: 5202-5201'
Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
5076' TVD
4990' TVD
5075' TVD
N/A
Sydney Autry Digitally signed by Sydney Autry
Date: 2025.01.16 11:24:37 -09'00'
By Grace Christianson at 1:54 pm, Jan 16, 2025
RBDMS JSB 012825
JJL 2/7/25 DSR-1/16/25SFD 2/10/2025
DTTMSTART JOBTYP SUMMARYOPS
1/31/2024 OPTIMIZE WELL PULLED 4 1/2" SLIP STOP @ 10,182' RKB & ATTEMPT TO LATCH PACKOFF @ 10,184' RKB (CURRENTLY
POOH).
1/31/2024 OPTIMIZE WELL *****ASSIST COIL*********
RECOVERED 4 1/2 ESP PUMP @ 4100', COIL JARRED ON MOTOR FOR 50 LICKS UNABLE TO RECOVER.
SLICKLINE ASSISTANCE NO LONGER REQUIRED AT THIS TIME. JOB POSTPONED.
2/1/2024 OPTIMIZE WELL CHANGE PACKOFFS & PERFORM CHAIN INSPECTION; PULLED 4.5" D&D PACKOFF ASSEMBLY @
10,184' RKB. (MISSING ELEMENT); RUN VENTURI DOWN TO TOP OF ESP @ 10,187' RKB (RECOVERED
3/4 OF ELEMENT). PULLED PUMP FROM 10,187' RKB TO SURFACE & RBIH TO PUMP OFF @ 2500'
CTMD.
2/2/2024 OPTIMIZE WELL PUMP OFF ESP @ 2500' CTMD (STANDBY FOR SLICKLINE TO RECOVER 48' ESP). MAKE 2 ATTEMPTS
TO PULL MOTOR @ 10,235' RKB.
2/3/2024 OPTIMIZE WELL LATCH ACCESS MOTOR @ 10,235' RKB & JARRED UP FOR 50 CYCLES (44-55K) W/ NO MOVEMENT.
TRIM PIPE, CHANGE PACKOFFS, & PERFORM CHAIN INSPECTION. ATTEMPT TO FISH WITH
TEMPRESS IN TOOLSTRING & UNABLE TO LATCH MOTOR; REMOVE TEMPRESS & JARRED UP ON
MOTOR FOR 16 CYCLES BEFORE JARS FAILED. IN PROGRESS.
2/4/2024 OPTIMIZE WELL JAR ON ESP MOTOR @ 10,235' RKB (HIT 50 JAR HITS ALTERNATING WITH VIBRATING ON FISH);
TRIM PIPE, ACCELERATOR,& WT BARS. DISPLACE TBG W/ DIESEL (776) JAR ON ESP MOTOR @
10,235' RKB (50 CYCLES UP, TEMPRESSED DOWN FOR 10 MIN, & UP FOR A TOTAL OF 60 MIN W/ NO
MOVEMENT). IN PROGRESS.
2/5/2024 OPTIMIZE WELL TRIM 100' OF PIPE & SWITCHED TO 2.88" OD TOOLSTRING. PINHOLED PIPE WHILE RIH @ 6,845'.
PULLED OUT OF HOLE & BEGIN CUTTING 6900' OF COIL TUBING (4150' CUT SO FAR).
2/6/2024 OPTIMIZE WELL FINISH CUTTING 2818' OF COIL TBG (CUT 6968' TOTAL). RIH WITH 4" JPP SPEAR AND 2.88" FISHING
STRING. JAR 4 HITS AND POPS FREE. POOH AND RECOVER 9.5' OF PUMP ASSEMBLY. ACCESS TO
DETERMINE IF REMAINING ESP MOTOR ASSEMBLY IS FISHABLE.
2/18/2024 OPTIMIZE WELL IMPRESSION BLOCK PICTURE SHOWS WHAT SEEMS TO BE SHAFT COUPLER LAYING ACROSS PUMP
SEAL SECTION / SHAFT, SET SS CATCHER 6464' RKB, INSTALLED 1'' 1/4 PORT OV w/ BK LATCH ST#2
6417' RKB.... IN PROGRESS
2/19/2024 OPTIMIZE WELL INSTALLED 3/16'' GLV ST#1, 2959' RKB, SET/PULLED SLIP STOP HOLE FINDER BELOW ST#2 6417' RKB,
TESTED TO 1000 PSI, GOOD TEST, ATTEMPT TO FISH CUPLING OFF TOP OFF PUMP... IN PROGRESS
2/20/2024 OPTIMIZE WELL FISHED 1.50'' x 3.75'' SPLINED PUMP SHAFT COUPLER @ 10,240' RKB,.ATTEMPT TO FISH PUMP SHAFT
10,240' RKB, NO SUCCESS. IN PROGRESS
2/23/2024 OPTIMIZE WELL PULLED 8' ACCESS MOTOR SHAFT @ 10245' RKB. READY FOR DHD.
2/24/2024 ACQUIRE DATA (AC EVAL) GAS MIT-IA (IN PROGRESS)
2/25/2024 ACQUIRE DATA (AC EVAL) GAS MITIA (PASS)
2/28/2024 OPTIMIZE WELL STANDBY FOR VALVE CREW, SLICKLINE, & FRAC EQUIPMENT TO GET MOVED; MIRU CTU W/ 2" CT &
MAKE UP BHA. IN PROGRESS.
2/29/2024 OPTIMIZE WELL ATTEMPT TO PULL ACCESS MOTOR (FISH) @ 10,225' CTMD (ABLE TO GET FRICTION BITE & CONFIRM
LIMAR SPEAR WAS GETTING INTO FISH 1/2" ON FIRST ATTEMPT). 2nd ATTEMPT OBTAIN FRICTION
BITE ON FISH AND CURRENTLY TEMPERESSING DOWN TRYING TO DRIVE SPEAR DEEPER.
3/1/2024 OPTIMIZE WELL ON 2nd ATTEMPT TO PULL FISH, HIT 6 JAR LICKS BEFORE POPPING FREE OFF OF FISH (UNABLE TO
GET LATCH BACK UP AFTERWARDS / MARKS ON BOTTOM OF CORE & MARKS ON GRAPPLE
INDICATE SPEAR WAS FULLY BURIED).
RAN UP SIZED GRAPPLE ON LIMAR SPEAR (2.125-2.25") RECOVERED ESP FISH FROM 10,229 CTMD;
LEFT TRAPPED IN PANCAKE FLANGE W/ UPPER CROWN VALVE CLOSED. READY FOR SLICKLINE TO
RECOVER.
3/2/2024 OPTIMIZE WELL MOBILIZE RIG TO 3G, STAND BY FOR SLICK LINE. MOBILIZE TO 3S, SPOT UP RIG UP. - JOB IN
PROGRESS.
3/2/2024 OPTIMIZE WELL LATCH FISH IN PANCAKE FLANGE UNABLE TO MOVE FISH UP. READY FOR COIL TO RECOVER.
3/3/2024 OPTIMIZE WELL CONTINUE TO RIG UP. FISH MOTOR FROM PANCAKE FLANGE. RECOVERED ALL OF THE SEAL
HOUSING, PART OF THE EXTERNAL MOTOR HEAD AND ALL OF THE INTERNALS OF THE MOTOR.
EXTERNAL MOTOR HOUSING, SENSOR AND REMAINING MOTOR ARE STILL IN HOLE, (APPROX. 31.97')
MADE ONE ATTEMPT TO FISH WITH 3.5" ITCO SPEAR. DID NOT LATCH UP. OOH RDMO FOR PLAN
FORWARD.
3/12/2024 MAINTAIN WELL PUMP 66 BBLS HOT DSL DOWN TBG. PUMP METH ON FLOWLINE TO REMOVE ICE PLUG.
JOB COMPLETE
4/9/2024 MAINTAIN WELL PUMP 10 BBL METH SPEAR DOWN IA
3S-615 Convert ESP to GL
Summary of Operations
5/26/2024 OPTIMIZE WELL TRAVEL FROM 1J PAD. SPOT UP RIG UP. RIH PUMP 60 BBLS SLICK SEA WATER AND 24 BBLS 15%
HCL AROUND STUCK ESP FISH. POOH, RECONFIGURE BHA TO FISH ESP. WAIT 12 HRS FOR ACID TO
SOAK. - JOB IN PROGRESS.
5/27/2024 OPTIMIZE WELL WAIT ON ACID TO SOAK; ENGAGED FISH @ 10,229' CTMD, HIT 34 JAR LICKS & RECOVERED ENTIRE
ESP MOTOR ASSEMBLY;
RAN 2.88 VENTURI W/ 3.69 MULE SHOE & RECIPROCATED ACROSS SLIDING SLEEVE @ 10,458,
10,225', & ACP @ 10,282' RKB (RECOVERED 1/2 CUP OF MATERIAL).
CLOSED CMU @ 10,458' RKB.
5/28/2024 OPTIMIZE WELL ATTEMPT TO RUN ACP ISO SLEEVE TO 10,282 RKB. DEBRIS IN HOLE UNABLE TO PASS BELOW 945'.
POOH, RUN VENTURI FROM 850'-4,000' ACROSS GLM #2 @ 6417 FROM 10,085' - 10,282' SMALL
AMOUNT OF DEBRIS RETURNED. REATTEMPT TO RUN ACP ISO SLEEVE SET DOWN AT 1,273'
STICKY PICK UP, POOH AND PICK UP MOTOR WITH 3.81 JUNK MILL. RUN JUNK MILL TO 10,244'. RUN
ISO SLEEVE DRIFT TO 10,200' WITH NO ISSUES. RIH WITH SHIFTING TOOL AND SHIFTED SLEEVE
CLOSED AT 10,225'
5/29/2024 OPTIMIZE WELL AT 2500' CONTINUE PULLING OOH RDMO
6/4/2024 OPTIMIZE WELL DRIFT CLEAN TO 10,228' CTMD WITH 3.80" MILL. PUMP 150 BBL S. DIESEL DOWN CT X TUBING
ANNULUS AT 3.0 BPM. JOB IN PROGRESS.
6/5/2024 OPTIMIZE WELL SET ACCESS ACP ISO SLEEVE AT 10,282' RKB. IA DRAWDOWN TEST - PASS. JOB COMPLETE
6/9/2024 ACQUIRE DATA (AC EVAL) TIFL (PASSED)
12/8/2024 MAINTAIN WELL PUMP 10 BBLS METH SPEAR DOWN IA
JOB COMPLETE
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Set AccessESP IsoSleeve 3S-615 6/5/2024 famaj
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread
CONDUCTOR 20 18.50 36.3 113.8 120.00 H160
SURFACE 10 3/4 9.95 36.6 3,069.0 2,543.0 45.50 L80 H563
INTERMEDIATE 7 5/8 6.88 34.5 11,706.0 5,129.9 29.70 L-80 Hyd 563
LINER 4 1/2 3.96 11,531.4 23,756.0 5,200.7 12.60 L80 HYD 563
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
33.2
Set Depth …
11,537.0
Set Depth …
5,076.4
String Max No…
4 1/2
Tubing Description
Tubing – Completion Upper
Wt (lb/ft)
12.60
Grade
L80
Top Connection
H563
ID (in)
3.96
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
33.2 33.2 0.00 HANGER 10.850 Cameron 4-1/2" Tubing Hanger,
H563
Camero
n
C-SRL-
CL
3.958
2,951.9 2,489.8 61.59 Mandrel – GAS
LIFT
4.500 4-1/2" Camco KBMG GLM Schlumb
erger
KBMG 3.900
6,417.3 3,567.2 73.51 Mandrel – GAS
LIFT
4.500 4-1/2" Camco KBMG GLM Schlumb
erger
KBMG 3.900
10,085.7 4,612.9 72.99 Sensor -
Discharge
Gauge
4.500 HAL ROC Discharge DHG +
Mandrel, 4-1/2" 12.6# L-80 Hyd 563
Halliburt
on
Opsis
Single
Ended
Gauge
Carrier
3.921
10,224.2 4,653.7 72.78 XO 4.500 Pup joint, X-over, 4-1/2" Hyd 563
box x VAM top pin
Access
ESP
3.958
10,225.3 4,654.1 72.78 Sleeve - Sliding 5.500 CMD Gas Venting Sliding Sleeve
(CLOSED position 5/28/24), 4-1/2"
Vam top box x 5-1/2" VAM FJL box
Access
ESP
3.910
10,230.2 4,655.5 72.74 Motor 5.500 Motor Shroud 8, 5.5" 23# VAM FJL
Pin x 5.5" 23# VAM FJL Pin
Access
ESP
4.548
10,235.0 4,656.9 72.71 Centralizer 5.500 Motor Centralizer 7, 5.5" 23# VAM
FJL BOX x 5.5" VAM FJL BOX
Access
ESP
3.893
10,236.8 4,657.5 72.70 Motor 5.500 Motor Shroud 7, 5.5" 23# VAM FJL
Pin x 5.5" 23# VAM FJL Pin
Access
ESP
4.548
10,241.6 4,658.9 72.67 Centralizer 5.500 Motor Centralizer 6, 5.5" 23# VAM
FJL BOX x 5.5" VAM FJL BOX
Access
ESP
3.893
10,243.3 4,659.4 72.66 Motor 5.500 Motor Shroud 6, 5.5" 23# VAM FJL
Pin x 5.5" 23# VAM FJL Pin
Access
ESP
4.548
10,248.1 4,660.8 72.63 Centralizer 5.500 Motor Centralizer 5, 5.5" 23# VAM
FJL BOX x 5.5" VAM FJL BOX
Access
ESP
3.893
10,249.9 4,661.4 72.62 Motor 5.500 Motor Shroud 5, 5.5" 23# VAM FJL
Pin x 5.5" 23# VAM FJL Pin
Access
ESP
4.548
10,254.7 4,662.8 72.59 Centralizer 5.500 Motor Centralizer 4, 5.5" 23# VAM
FJL BOX x 5.5" VAM FJL BOX
Access
ESP
3.893
10,256.4 4,663.3 72.57 Motor 5.500 Motor Shroud 4, 5.5" 23# VAM FJL
Pin x 5.5" 23# VAM FJL Pin
Access
ESP
4.548
10,261.2 4,664.8 72.54 Centralizer 5.500 Motor Centralizer 3, 5.5" 23# VAM
FJL BOX x 5.5" VAM FJL BOX
Access
ESP
3.893
10,263.0 4,665.3 72.53 Motor 5.500 Motor Shroud 3, 5.5" 23# VAM FJL
Pin x 5.5" 23# VAM FJL Pin
Access
ESP
4.548
10,267.8 4,666.7 72.50 Centralizer 5.500 Motor Centralizer 2, 5.5" 23# VAM
FJL BOX x 5.5" VAM FJL BOX
Access
ESP
3.893
10,269.5 4,667.3 72.49 Motor 5.500 Motor Shroud 2, 5.5" 23# VAM FJL
Pin x 5.5" 23# VAM FJL Pin
Access
ESP
4.548
10,274.3 4,668.7 72.46 Centralizer 5.500 Motor Centralizer 1, 5.5" 23# VAM
FJL BOX x 5.5" VAM FJL BOX
Access
ESP
3.893
10,276.1 4,669.2 72.45 Motor 5.500 Motor Shroud 1, 5.5" 23# VAM FJL
Pin x 5.5" 23# VAM FJL Pin
Access
ESP
4.548
10,282.4 4,671.1 72.41 Annular
Connection
Port (ACP)
5.950 5" VAM FJL Box x 4-1/2" VAM top
Box, Annular Connection Port (ACP)
Access
ESP
3.860
10,306.0 4,678.3 72.25 B Profile
Assembly
4.967 B-profile, 4.5" 12.6# VAM Top Box x
4.5" 12.6# VAM Top Box
Access
ESP
3.913
10,319.5 4,682.4 72.18 Nipple - No Go 5.220 No-GO, 4.5" 12.6# VAM Top Box x
4.5" VAM Top Box
Access
ESP
3.813
10,458.8 4,725.8 71.57 Sleeve - Sliding 4.500 CMU SLB Sliding Sleeve (CLOSED
position 5/27/24), 4-1/2" 12.6# L-80
Hyd 563, 3.813" X
Slumber
ger
NEXA-2 3.813
11,270.6 4,990.5 70.79 Packer 7.625 HAL TNT Production Packer
4.5"x7.63"
Halliburt
on
TNT 3.810
11,345.0 5,014.7 71.30 Nipple - DB 4.500 NIPPLE,LANDING,4 1/2", DB,
3.562"
Slumber
ger
DB
Nipple
3.562
11,397.9 5,031.6 71.29 Sub - Shear
Out - SOS
5500psi
4.500 Arsenal Glass Plug - 5500 psi shear
*SHEARED*
Arsenal 11937-
01-01
3.890
11,528.1 5,073.6 71.16 Locator 6.400 Baker Shear Type Locator sub -
above locating shoulder
Baker 3.860
11,528.7 5,073.8 71.16 Locator 5.640 Baker Shear Type Locator - to
locating shoulder (Shear pins 1'
below shoulder)
Baker 3.860
11,533.8 5,075.4 71.15 Shoe - Mule 4.500 Halliburton Ratcheting Muleshoe Halliburt
on
Ratcheti
ng
3.900
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
10,282.0 4,671.0 72.41 ISO-SLEEVE ACP iso sleeve (OAL = 11.28') AccessE
SP
6/5/2024
HORIZONTAL, 3S-615, 1/16/2025 8:48:49 AM
Vertical schematic (actual)
LINER; 11,531.4-23,756.0
Hydraulic fracture; 23,590.0
Hydraulic fracture; 23,060.0
Hydraulic fracture; 22,545.0
Hydraulic fracture; 22,026.0
Hydraulic fracture; 21,509.0
Hydraulic fracture; 20,988.0
Hydraulic fracture; 20,468.0
Hydraulic fracture; 19,947.0
Hydraulic fracture; 19,425.0
Hydraulic fracture; 18,906.0
Hydraulic fracture; 17,868.0
Hydraulic fracture; 17,310.0
Hydraulic fracture; 16,789.0
Hydraulic fracture; 16,268.0
Hydraulic fracture; 15,790.0
Hydraulic fracture; 15,310.0
Hydraulic fracture; 14,831.0
Hydraulic fracture; 14,352.0
Hydraulic fracture; 13,876.0
Hydraulic fracture; 13,399.0
Hydraulic fracture; 12,922.0
Hydraulic fracture; 12,485.0
Hydraulic fracture; 11,965.0
INTERMEDIATE; 34.5-11,706.0
Nipple - DB; 11,345.0
Sleeve - Sliding; 10,458.8
ISO-SLEEVE; 10,282.0
Mandrel – GAS LIFT; 6,417.3
SURFACE; 36.6-3,069.0
Mandrel – GAS LIFT; 2,951.9
HANGER; 33.2
KUP PROD
KB-Grd (ft)
36.25
RR Date
12/17/202
2
Other Elev…
3S-615
...
TD
Act Btm (ftKB)
23,770.0
Well Attributes
Field Name
TRACT OPERATION MORTR05
Wellbore API/UWI
501032084400
Wellbore Status
PROD
Max Angle & MD
Incl (°)
91.14
MD (ftKB)
20,303.77
WELLNAME WELLBORE3S-615
Annotation End DateH2S (ppm)
160
Date
3/10/2023
Comment
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi) Run Date Com Make Model
Port
Size (in)
2,951.9 2,489.8 61.59 1 ESP GLV BK 1 1,380.0 2/19/2024 0.188
6,417.3 3,567.2 73.51 2 ESP OV BK 1 0.0 2/18/2024 0.250
Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal ID
(in)
11,531.4 5,074.6 71.16 PACKER 6.530 5.5" X 7-5/8" ZXP Packer w/
11.29' x 5.75" ID TieBK Sleeve
~ 175' lap
ZXP LTP H29645026
5-COI
4.820
11,551.0 5,081.0 71.23 Nipple - RS 6.020 RS Packoff Seal Nipple R/S
Nipple
10553458-
COI
4.240
11,562.7 5,084.7 71.30 XO Reducing 6.060 5.5" Hyd 563 box X pin 4.5" Hyd
563 cross over
3.880
11,736.0 5,139.4 71.57 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #24
Water
Swell
H30415XM
OD
3.930
11,964.5 5,202.4 76.73 Sleeve - Frac #24 5.000 BAKER Frac Sleeve (2.895" ball)
#23, HYD563
Frac
sleeve
H80908026
4
2.855
12,174.2 5,241.2 82.11 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #23
Water
Swell
H30415XM
OD
3.900
12,485.3 5,262.8 89.96 Sleeve - Frac #23 5.000 BAKER Frac Sleeve (2.845" ball)
#22, HYD563
Frac
sleeve
H80908072
8
2.805
12,695.0 5,262.0 90.16 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #22
Water
Swell
H30415XM
OD
3.860
12,921.8 5,262.5 90.11 Sleeve - Frac #22 5.000 BAKER Frac Sleeve (2.795" ball)
#21, HYD563
Frac
sleeve
H80908039
8
2.755
13,171.1 5,262.0 90.18 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #21
Water
Swell
H30415XM
OD
3.920
13,399.2 5,261.4 90.13 Sleeve - Frac #21 5.000 BAKER Frac Sleeve (2.745" ball)
#20, HYD563
Frac
sleeve
H80908039
7
2.705
13,691.2 5,260.6 90.05 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #20
Water
Swell
H30415XM
OD
3.940
13,876.3 5,260.5 90.07 Sleeve - Frac #20 5.000 BAKER Frac Sleeve (2.695" ball)
#19, HYD563
Frac
sleeve
H80908039
6
2.655
14,125.1 5,259.1 90.40 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #19
Water
Swell
H30415XM
OD
3.830
14,351.6 5,258.9 90.10 Sleeve - Frac #19 5.000 BAKER Frac Sleeve (2.645" ball)
#18, HYD563
Frac
sleeve
H80908039
5
2.605
14,561.3 5,258.2 90.05 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #18
Water
Swell
H30415XM
OD
3.890
14,830.7 5,257.5 90.06 Sleeve - Frac #18 5.000 BAKER Frac Sleeve (2.595" ball)
#17, HYD563
Frac
sleeve
H80908039
4
2.555
15,080.4 5,256.4 90.46 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #17
Water
Swell
H30415XM
OD
3.910
15,309.9 5,255.2 90.34 Sleeve - Frac #17 5.000 BAKER Frac Sleeve (2.545" ball)
#16, HYD563
Frac
sleeve
H80908039
3
2.505
15,561.1 5,253.8 90.35 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #16
Water
Swell
H30415XM
OD
3.890
15,789.5 5,252.1 90.45 Sleeve - Frac #16 5.000 BAKER Frac Sleeve (2.495" ball)
#15, HYD563
Frac
sleeve
H80908039
2
2.465
16,081.2 5,250.6 90.20 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #15
Water
Swell
H30415XM
OD
3.880
16,268.1 5,249.9 90.35 Sleeve - Frac #15 5.000 BAKER Frac Sleeve (2.455" ball)
#14, HYD563
Frac
sleeve
H80908039
1
2.425
16,519.0 5,248.7 90.30 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #14
Water
Swell
H30415XM
OD
3.920
16,788.8 5,246.5 90.55 Sleeve - Frac #14 5.000 BAKER Frac Sleeve (2.415" ball)
#13, HYD563
Frac
sleeve
H80908039
0
2.385
17,081.3 5,244.0 90.47 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #13
Water
Swell
H30415XM
OD
3.910
17,309.9 5,241.9 90.50 Sleeve - Frac #13 5.000 BAKER Frac Sleeve (2.375" ball)
#12, HYD563
Frac
sleeve
H80908039
0
2.345
17,600.2 5,239.2 90.61 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #12
Water
Swell
H30415XM
OD
3.910
17,868.3 5,236.7 90.38 Sleeve - Frac #12 5.000 BAKER Frac Sleeve (2.335" ball)
#11, HYD563
Frac
sleeve
H80908038
8
2.305
18,117.4 5,234.7 90.49 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #11
Water
Swell
H30415XM
OD
3.890
18,387.2 5,232.2 90.54 Sleeve - Frac #11 5.000 BAKER Frac Sleeve (2.295" ball)
#10, HYD563
Frac
sleeve
H80908038
7
2.265
18,638.2 5,230.1 90.40 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #10
Water
Swell
H30415XM
OD
3.910
18,906.0 5,228.1 90.42 Sleeve - Frac #10 5.000 BAKER Frac Sleeve (2.255" ball)
#9, HYD563
Frac
sleeve
H80908038
6
2.225
19,114.0 5,226.4 90.53 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #9
Water
Swell
H30415XM
OD
3.890
19,425.4 5,223.1 90.47 Sleeve - Frac #9 5.000 BAKER Frac Sleeve (2.215" ball)
#8, HYD563
Frac
sleeve
H80908038
5
2.185
19,676.7 5,221.8 90.16 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #8
Water
Swell
H30415XM
OD
3.910
19,946.6 5,220.6 90.57 Sleeve - Frac #8 5.000 BAKER Frac Sleeve (2.175" ball)
#7, HYD563
Frac
sleeve
H80908038
4
2.145
20,197.7 5,217.2 90.93 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #7
Water
Swell
H30415XM
OD
3.930
20,467.7 5,213.2 90.63 Sleeve - Frac #7 5.000 BAKER Frac Sleeve (2.135" ball)
#6, HYD563
Frac
sleeve
H80908038
3
2.105
20,718.8 5,211.0 90.00 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #6
Water
Swell
H30415XM
OD
3.810
20,988.1 5,211.7 89.90 Sleeve - Frac #6 5.000 BAKER Frac Sleeve (2.095" ball)
#5, HYD563
Frac
sleeve
H80908038
2
2.065
21,239.3 5,211.3 90.54 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #5
Water
Swell
H30415XM
OD
3.930
21,509.0 5,209.1 90.51 Sleeve - Frac #5 5.000 BAKER Frac Sleeve (2.055" ball)
#4, HYD563
Frac
sleeve
H80908038
1
2.025
21,756.6 5,206.7 90.58 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #4
Water
Swell
H30415XM
OD
3.910
HORIZONTAL, 3S-615, 1/16/2025 8:48:50 AM
Vertical schematic (actual)
LINER; 11,531.4-23,756.0
Hydraulic fracture; 23,590.0
Hydraulic fracture; 23,060.0
Hydraulic fracture; 22,545.0
Hydraulic fracture; 22,026.0
Hydraulic fracture; 21,509.0
Hydraulic fracture; 20,988.0
Hydraulic fracture; 20,468.0
Hydraulic fracture; 19,947.0
Hydraulic fracture; 19,425.0
Hydraulic fracture; 18,906.0
Hydraulic fracture; 17,868.0
Hydraulic fracture; 17,310.0
Hydraulic fracture; 16,789.0
Hydraulic fracture; 16,268.0
Hydraulic fracture; 15,790.0
Hydraulic fracture; 15,310.0
Hydraulic fracture; 14,831.0
Hydraulic fracture; 14,352.0
Hydraulic fracture; 13,876.0
Hydraulic fracture; 13,399.0
Hydraulic fracture; 12,922.0
Hydraulic fracture; 12,485.0
Hydraulic fracture; 11,965.0
INTERMEDIATE; 34.5-11,706.0
Nipple - DB; 11,345.0
Sleeve - Sliding; 10,458.8
ISO-SLEEVE; 10,282.0
Mandrel – GAS LIFT; 6,417.3
SURFACE; 36.6-3,069.0
Mandrel – GAS LIFT; 2,951.9
HANGER; 33.2
KUP PROD 3S-615
...
WELLNAME WELLBORE3S-615
Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal ID
(in)
22,026.3 5,204.5 90.46 Sleeve - Frac #4 5.000 BAKER Frac Sleeve (2.015" ball)
#3, HYD563
Frac
sleeve
H80908072
6
1.985
22,275.3 5,202.2 90.62 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #3
Water
Swell
H30415XM
OD
3.880
22,545.1 5,200.2 90.63 Sleeve - Frac #3 5.000 BAKER Frac Sleeve (1.975" ball)
#2, HYD563
Frac
sleeve
H80908072
5
1.945
22,790.0 5,197.6 90.71 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #2
Water
Swell
H30415XM
OD
3.950
23,059.7 5,196.1 90.15 Sleeve - Frac #2 5.000 BAKER Frac Sleeve (1.935" ball)
#1, HYD563
Frac
sleeve
H80908072
4
1.905
23,352.1 5,197.2 89.07 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #1
Water
Swell
H30415XM
OD
3.910
23,589.9 5,200.6 89.50 Sleeve - Frac #1 5.620 Alpha Pressure Sleeve, 4 1/2",
13.5#, Q125
Alpha
Sleeve
H81047006
8
3.000
23,593.6 5,200.7 89.53 Sleeve - Frac 5.660 Wellbore Isolation Valve, 4 1/2",
13.5#, P110
WIV H80914004
2
1.250
Stimulation Intervals
Top (ftKB) Btm (ftKB)
Inter
val
Num
ber Type Subtype Start Date
Proppant
Designed (lb)
Proppant
Total (lb)
Vol Clean
Total (bbl)
Vol Slurry
Total (bbl)
23,590.0 23,594.0 1 Hydraulic
fracture
1/6/2023 207,200.0 207,911.0 5,136.00 5,360.00
23,060.0 23,062.0 2 Hydraulic
fracture
1/7/2023 207,200.0 206,714.0 3,398.00 3,621.00
22,545.0 22,548.0 3 Hydraulic
fracture
1/7/2023 207,200.0 0.0 1,027.00 1,027.00
22,026.0 22,029.0 4 Hydraulic
fracture
1/8/2023 207,200.0 208,437.0 3,251.00 3,476.00
21,509.0 21,511.0 5 Hydraulic
fracture
1/8/2023 207,200.0 206,325.0 2,949.00 3,172.00
20,988.0 20,991.0 6 Hydraulic
fracture
1/9/2023 207,200.0 203,967.0 2,766.00 2,986.00
20,468.0 20,470.0 7 Hydraulic
fracture
1/9/2023 207,200.0 206,751.0 2,833.00 3,057.00
19,947.0 19,949.0 8 Hydraulic
fracture
1/18/2023 207,200.0 206,940.0 2,708.00 2,931.00
19,425.0 19,428.0 9 Hydraulic
fracture
1/18/2023 207,200.0 203,938.0 2,447.00 2,667.00
18,906.0 18,908.0 10 Hydraulic
fracture
1/18/2023 207,200.0 196,230.0 2,671.00 2,883.00
17,868.0 17,871.0 12 Hydraulic
fracture
1/26/2023 207,200.0 208,803.0 2,873.00 3,099.00
17,310.0 17,312.0 13 Hydraulic
fracture
1/26/2023 207,200.0 203,292.0 2,503.00 2,722.00
16,789.0 16,791.0 14 Hydraulic
fracture
1/26/2023 207,200.0 201,030.0 2,755.00 2,972.00
16,268.0 16,271.0 15 Hydraulic
fracture
1/28/2023 207,200.0 196,477.0 2,805.00 3,017.00
15,790.0 15,792.0 16 Hydraulic
fracture
1/28/2023 207,200.0 203,209.0 2,728.00 2,947.00
15,310.0 15,312.0 17 Hydraulic
fracture
1/29/2023 207,200.0 200,687.0 2,641.00 2,858.00
14,831.0 14,833.0 18 Hydraulic
fracture
1/29/2023 207,200.0 202,142.0 2,453.00 2,671.00
14,352.0 14,354.0 19 Hydraulic
fracture
1/29/2023 207,200.0 206,465.0 3,043.00 3,266.00
13,876.0 13,879.0 20 Hydraulic
fracture
1/31/2023 207,200.0 210,380.0 2,871.00 3,098.00
13,399.0 13,402.0 21 Hydraulic
fracture
1/31/2023 207,200.0 208,214.0 2,502.00 2,727.00
12,922.0 12,924.0 22 Hydraulic
fracture
1/31/2023 207,200.0 203,930.0 2,886.00 3,106.00
12,485.0 12,488.0 23 Hydraulic
fracture
2/1/2023 207,200.0 206,512.0 2,602.00 2,825.00
11,965.0 11,967.0 24 Hydraulic
fracture
2/2/2023 207,200.0 206,404.0 2,837.00 3,059.00
HORIZONTAL, 3S-615, 1/16/2025 8:48:51 AM
Vertical schematic (actual)
LINER; 11,531.4-23,756.0
Hydraulic fracture; 23,590.0
Hydraulic fracture; 23,060.0
Hydraulic fracture; 22,545.0
Hydraulic fracture; 22,026.0
Hydraulic fracture; 21,509.0
Hydraulic fracture; 20,988.0
Hydraulic fracture; 20,468.0
Hydraulic fracture; 19,947.0
Hydraulic fracture; 19,425.0
Hydraulic fracture; 18,906.0
Hydraulic fracture; 17,868.0
Hydraulic fracture; 17,310.0
Hydraulic fracture; 16,789.0
Hydraulic fracture; 16,268.0
Hydraulic fracture; 15,790.0
Hydraulic fracture; 15,310.0
Hydraulic fracture; 14,831.0
Hydraulic fracture; 14,352.0
Hydraulic fracture; 13,876.0
Hydraulic fracture; 13,399.0
Hydraulic fracture; 12,922.0
Hydraulic fracture; 12,485.0
Hydraulic fracture; 11,965.0
INTERMEDIATE; 34.5-11,706.0
Nipple - DB; 11,345.0
Sleeve - Sliding; 10,458.8
ISO-SLEEVE; 10,282.0
Mandrel – GAS LIFT; 6,417.3
SURFACE; 36.6-3,069.0
Mandrel – GAS LIFT; 2,951.9
HANGER; 33.2
KUP PROD 3S-615
...
WELLNAME WELLBORE3S-615
Operations shutdownRepair WellFracture StimulatePlug PerforationsAbandon1. Type of Request:
Change Approved ProgramPull TubingOther StimulatePerforateSuspend
Other: Convert ESP to GLAlter CasingPerforate New Pool Re-enter Susp WellPlug for Redrill
5. Permit to Drill Number:4. Current Well Class:2. Operator Name:
DevelopmentExploratory
3. Address:ServiceStratigraphic 6. API Number:
8. Well Name and Number:7. If perforating:
What Regulation or Conservation Order governs well spacing in this pool?
NoYes
10. Field:9. Property Designation (Lease Number):
11.
Junk (MD):Effective Depth TVD:Effective Depth MD:Total Depth TVD (ft):Total Depth MD (ft):
10226'23770'
CollapseCasing
Structural
Conductor
Surface
Intermediate
Production
Liner
Packers and SSSV MD (ft) and TVD (ft):Packers and SSSV Type:
13. Well Class after proposed work:12. Attachments: Proposal Summary Wellbore schematic
ServiceDevelopmentExploratory StratigraphicDetailed Operations Program BOP Sketch
15. Well Status after proposed work:14. Estimated Date for
WDSPLOIL WINJCommencing Operations:Suspended
SPLUGGSTORWAGGASDate:16. Verbal Approval:
AOGCC Representative: GINJ AbandonedOp Shutdown
Contact Name:
Authorized Title:
Sundry Number:Conditions of approval: Notify AOGCC so that a representative may witness
Location ClearancePlug Integrity BOP Test Mechanical Integrity Test
Other Conditions of Approval:
Post Initial Injection MIT Req'd? NoYes
APPROVED BY
Date:THE AOGCCCOMMISSIONERApproved by:
Sr Res EngSr Pet GeoSr Pet EngComm.Comm.
2/26/2024
23756'12225'
4-1/2"
5201'
Packer: HLB Prod Packer
Packer: ZXP LTP Packer
SSSV: None
Perforation Depth MD (ft):
L-80
11671'
3032'
11706'
Frac Sleeves: 11964-23594'
4-1/2"
Frac Sleves: 5202-5201'
Perforation Depth TVD (ft):
114'
3069'
20"
10-3/4"
77'
7-5/8"
11537'
MD
114'
2543'
5130'
ConocoPhillips Alaska, Inc.
SizeLength
PRESENT WELL CONDITION SUMMARY
BurstTVD
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0025528, ADL0025544, ADL0380107
222-101
P.O. Box 100360, Anchorage, AK 99510 50-103-20844-00-00
Kuparuk River Field
AOGCC USE ONLY
Tubing MD (ft):Tubing Grade:
11271' MD and 4990' TVD
11531' MD and 5075' TVD
N/A
Brian Lewis
Subsequent Form Required:
Suspension Expiration Date:
Will perfs require a spacing exception due to property boundaries?
Plugs (MD):MPSP (psi):
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:
Senior Production Engineer
KRU 3S-615
None5201'23770'5201'
N/A
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
Current Pools:
Torok Oil Pool
Proposed Pools:
Torok Oil Pool
Contact Email: brian.m.lewis@conocophillips.com
Contact Phone:(907) 659-7871
By Kayla Junke at 2:17 pm, Feb 15, 2024
324-086
Brian Lewis Digitally signed by Brian Lewis
Date: 2024.02.14 16:42:29 -09'00'
VTL 02/21/2024
10-404
DSR-2/15/24SFD 2/15/2024
X
*&:JLC 2/21/2024
Brett W. Huber,
Sr.
Digitally signed by Brett W. Huber,
Sr.
Date: 2024.02.21 15:24:24 -09'00'02/21/24
RBDMS JSB 022324
3S-615 DESCRIPTION SUMMARY OF PROPOSAL
CONVERT FROM ESP TO GASLIFT
CPAI is seeking approval to convert the arcial li method in well 3S-615 from Electric Submersible
Pump (ESP) to Gas Lied producon as the ESP motor has become non-retrievable during a recent well
intervenon on 02/06/2024.
3S-615 is a single-lateral producer that was completed in the Torok formaon in February 2023. The well
was originally produced in Gas Li service from February to June 2023, at which point a thru-tubing
retrievable ESP was installed and the well was converted to ESP service. The decision was made to pull
the ESP in January 2024 due to e3ciency losses from pump wear; however, while pulling the ESP the
connecon between the upper and lower seals parted, leaving the motor non-retrievable at this me.
Converng the arcial li method to gasli will restore producon unl such me as a rig workover
can be performed.
The well is congured with 4-1/2” tubing and equipped with 1” side pocket gasli mandrels located at
2,490’ TVD and 3,567’ TVD. The gas li design will consist of an unloading valve in the rst mandrel and
an orice valve in the second mandrel. This conguraon will allow the well to be operated at ~1.5
MMCFD with a stabilized operang annulus casing pressure of ~1,200psi.
Applying the well integrity guidelines established for West Sak packerless ESP compleons, a gas
mechanical integrity test (GMIT) of the producon casing will be performed. This GMIT will consist of
tesng the producon casing with gas up to 1400psi while monitoring IA and OA Auid levels for a 12-
hour period to verify gas-ght construcon prior to the well being placed in gaslied service.
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Pulled Slipstop, Packoff, ESP Pump, left ESP Motor Fish 3S-615 2/6/2024 famaj
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread
CONDUCTOR 20 18.50 36.3 113.8 120.00 H160
SURFACE 10 3/4 9.95 36.6 3,069.0 2,543.0 45.50 L80 H563
INTERMEDIATE 7 5/8 6.88 34.5 11,706.0 5,129.9 29.70 L-80 Hyd 563
LINER 4 1/2 3.96 11,531.4 23,756.0 5,200.7 12.60 L80 HYD 563
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
33.2
Set Depth …
11,537.0
Set Depth …
5,076.4
String Max No…
4 1/2
Tubing Description
Tubing – Completion Upper
Wt (lb/ft)
12.60
Grade
L80
Top Connection
H563
ID (in)
3.96
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
33.2 33.2 0.00 HANGER 10.850 Cameron 4-1/2" Tubing Hanger,
H563
Camero
n
C-SRL-
CL
3.958
2,951.9 2,489.8 61.59 Mandrel – GAS
LIFT
4.500 4-1/2" Camco KBMG GLM Schlumb
erger
KBMG 3.900
6,417.3 3,567.2 73.51 Mandrel – GAS
LIFT
4.500 4-1/2" Camco KBMG GLM Schlumb
erger
KBMG 3.900
10,085.7 4,612.9 72.99 Sensor -
Discharge
Gauge
4.500 HAL ROC Discharge DHG +
Mandrel, 4-1/2" 12.6# L-80 Hyd 563
Halliburt
on
Opsis
Single
Ended
Gauge
Carrier
3.921
10,224.2 4,653.7 72.78 XO 4.500 Pup joint, X-over, 4-1/2" Hyd 563
box x VAM top pin
Access
ESP
3.958
10,225.3 4,654.1 72.78 Sleeve - Sliding 5.500 CMD Gas Venting Sliding Sleeve
(OPEN position 6/16/2023), 4-1/2"
Vam top box x 5-1/2" VAM FJL box
Access
ESP
3.910
10,230.2 4,655.5 72.74 Motor 5.500 Motor Shroud 8, 5.5" 23# VAM FJL
Pin x 5.5" 23# VAM FJL Pin
Access
ESP
4.548
10,235.0 4,656.9 72.71 Centralizer 5.500 Motor Centralizer 7, 5.5" 23# VAM
FJL BOX x 5.5" VAM FJL BOX
Access
ESP
3.893
10,236.8 4,657.5 72.70 Motor 5.500 Motor Shroud 7, 5.5" 23# VAM FJL
Pin x 5.5" 23# VAM FJL Pin
Access
ESP
4.548
10,241.6 4,658.9 72.67 Centralizer 5.500 Motor Centralizer 6, 5.5" 23# VAM
FJL BOX x 5.5" VAM FJL BOX
Access
ESP
3.893
10,243.3 4,659.4 72.66 Motor 5.500 Motor Shroud 6, 5.5" 23# VAM FJL
Pin x 5.5" 23# VAM FJL Pin
Access
ESP
4.548
10,248.1 4,660.8 72.63 Centralizer 5.500 Motor Centralizer 5, 5.5" 23# VAM
FJL BOX x 5.5" VAM FJL BOX
Access
ESP
3.893
10,249.9 4,661.4 72.62 Motor 5.500 Motor Shroud 5, 5.5" 23# VAM FJL
Pin x 5.5" 23# VAM FJL Pin
Access
ESP
4.548
10,254.7 4,662.8 72.59 Centralizer 5.500 Motor Centralizer 4, 5.5" 23# VAM
FJL BOX x 5.5" VAM FJL BOX
Access
ESP
3.893
10,256.4 4,663.3 72.57 Motor 5.500 Motor Shroud 4, 5.5" 23# VAM FJL
Pin x 5.5" 23# VAM FJL Pin
Access
ESP
4.548
10,261.2 4,664.8 72.54 Centralizer 5.500 Motor Centralizer 3, 5.5" 23# VAM
FJL BOX x 5.5" VAM FJL BOX
Access
ESP
3.893
10,263.0 4,665.3 72.53 Motor 5.500 Motor Shroud 3, 5.5" 23# VAM FJL
Pin x 5.5" 23# VAM FJL Pin
Access
ESP
4.548
10,267.8 4,666.7 72.50 Centralizer 5.500 Motor Centralizer 2, 5.5" 23# VAM
FJL BOX x 5.5" VAM FJL BOX
Access
ESP
3.893
10,269.5 4,667.3 72.49 Motor 5.500 Motor Shroud 2, 5.5" 23# VAM FJL
Pin x 5.5" 23# VAM FJL Pin
Access
ESP
4.548
10,274.3 4,668.7 72.46 Centralizer 5.500 Motor Centralizer 1, 5.5" 23# VAM
FJL BOX x 5.5" VAM FJL BOX
Access
ESP
3.893
10,276.1 4,669.2 72.45 Motor 5.500 Motor Shroud 1, 5.5" 23# VAM FJL
Pin x 5.5" 23# VAM FJL Pin
Access
ESP
4.548
10,282.4 4,671.1 72.41 Annular
Connection
Port (ACP)
5.950 5" VAM FJL Box x 4-1/2" VAM top
Box, Annular Connection Port (ACP)
Access
ESP
3.860
10,306.0 4,678.3 72.25 B Profile
Assembly
4.967 B-profile, 4.5" 12.6# VAM Top Box x
4.5" 12.6# VAM Top Box
Access
ESP
3.913
10,319.5 4,682.4 72.18 Nipple - No Go 5.220 No-GO, 4.5" 12.6# VAM Top Box x
4.5" VAM Top Box
Access
ESP
3.813
10,458.8 4,725.8 71.57 Sleeve - Sliding 4.500 CMU SLB Sliding Sleeve (OPEN
position 6/17/2023), 4-1/2" 12.6# L-
80 Hyd 563, 3.813" X
Slumber
ger
NEXA-2 3.813
11,270.6 4,990.5 70.79 Packer 7.625 HAL TNT Production Packer
4.5"x7.63"
Halliburt
on
TNT 3.810
11,345.0 5,014.7 71.30 Nipple - DB 4.500 NIPPLE,LANDING,4 1/2", DB,
3.562"
Slumber
ger
DB
Nipple
3.562
11,397.9 5,031.6 71.29 Sub - Shear
Out - SOS
5500psi
4.500 Arsenal Glass Plug - 5500 psi shear Arsenal 11937-
01-01
3.890
11,528.1 5,073.6 71.16 Locator 6.400 Baker Shear Type Locator sub -
above locating shoulder
Baker 3.860
11,528.7 5,073.8 71.16 Locator 5.640 Baker Shear Type Locator - to
locating shoulder (Shear pins 1'
below shoulder)
Baker 3.860
11,533.8 5,075.4 71.15 Shoe - Mule 4.500 Halliburton Ratcheting Muleshoe Halliburt
on
Ratcheti
ng
3.900
HORIZONTAL, 3S-615, 2/12/2024 10:32:03 AM
Vertical schematic (actual)
LINER; 11,531.4-23,756.0
Hydraulic fracture; 23,590.0
Hydraulic fracture; 23,060.0
Hydraulic fracture; 22,545.0
Hydraulic fracture; 22,026.0
Hydraulic fracture; 21,509.0
Hydraulic fracture; 20,988.0
Hydraulic fracture; 20,468.0
Hydraulic fracture; 19,947.0
Hydraulic fracture; 19,425.0
Hydraulic fracture; 18,906.0
Hydraulic fracture; 17,868.0
Hydraulic fracture; 17,310.0
Hydraulic fracture; 16,789.0
Hydraulic fracture; 16,268.0
Hydraulic fracture; 15,790.0
Hydraulic fracture; 15,310.0
Hydraulic fracture; 14,831.0
Hydraulic fracture; 14,352.0
Hydraulic fracture; 13,876.0
Hydraulic fracture; 13,399.0
Hydraulic fracture; 12,922.0
Hydraulic fracture; 12,485.0
Hydraulic fracture; 11,965.0
INTERMEDIATE; 34.5-11,706.0
Nipple - DB; 11,345.0
Sleeve - Sliding; 10,458.8
FISH; 10,226.0
Mandrel – GAS LIFT; 6,417.3
SURFACE; 36.6-3,069.0
Mandrel – GAS LIFT; 2,951.9
HANGER; 33.2
KUP PROD
KB-Grd (ft)
36.25
RR Date
12/17/202
2
Other Elev…
3S-615
...
TD
Act Btm (ftKB)
23,770.0
Well Attributes
Field Name
TRACT OPERATION MORTR05
Wellbore API/UWI
501032084400
Wellbore Status
PROD
Max Angle & MD
Incl (°)
91.14
MD (ftKB)
20,303.77
WELLNAME WELLBORE3S-615
Annotation End DateH2S (ppm)
160
Date
3/10/2023
Comment
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
10,226.0 4,654.3 72.77 FISH 2/6/24: Attempt to pull motor
and retrieved upper 9.50' of
motor leaving lower 45' of
motor in the hole.
AccessE
SP
6/18/2023 0.000
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi) Run Date Com Make Model
Port
Size (in)
2,951.9 2,489.8 61.59 1 ESP DMY BK 1 0.0 2/8/2023 0.000
6,417.3 3,567.2 73.51 2 ESP SOV BK 1 0.0 8/7/2023 2000
PSI
TBG
Shear
0.000
Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal ID
(in)
11,531.4 5,074.6 71.16 PACKER 6.530 5.5" X 7-5/8" ZXP Packer w/
11.29' x 5.75" ID TieBK Sleeve
~ 175' lap
ZXP LTP H29645026
5-COI
4.820
11,551.0 5,081.0 71.23 Nipple - RS 6.020 RS Packoff Seal Nipple R/S
Nipple
10553458-
COI
4.240
11,562.7 5,084.7 71.30 XO Reducing 6.060 5.5" Hyd 563 box X pin 4.5" Hyd
563 cross over
3.880
11,736.0 5,139.4 71.57 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #24
Water
Swell
H30415XM
OD
3.930
11,964.5 5,202.4 76.73 Sleeve - Frac #24 5.000 BAKER Frac Sleeve (2.895" ball)
#23, HYD563
Frac
sleeve
H80908026
4
2.855
12,174.2 5,241.2 82.11 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #23
Water
Swell
H30415XM
OD
3.900
12,485.3 5,262.8 89.96 Sleeve - Frac #23 5.000 BAKER Frac Sleeve (2.845" ball)
#22, HYD563
Frac
sleeve
H80908072
8
2.805
12,695.0 5,262.0 90.16 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #22
Water
Swell
H30415XM
OD
3.860
12,921.8 5,262.5 90.11 Sleeve - Frac #22 5.000 BAKER Frac Sleeve (2.795" ball)
#21, HYD563
Frac
sleeve
H80908039
8
2.755
13,171.1 5,262.0 90.18 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #21
Water
Swell
H30415XM
OD
3.920
13,399.2 5,261.4 90.13 Sleeve - Frac #21 5.000 BAKER Frac Sleeve (2.745" ball)
#20, HYD563
Frac
sleeve
H80908039
7
2.705
13,691.2 5,260.6 90.05 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #20
Water
Swell
H30415XM
OD
3.940
13,876.3 5,260.5 90.07 Sleeve - Frac #20 5.000 BAKER Frac Sleeve (2.695" ball)
#19, HYD563
Frac
sleeve
H80908039
6
2.655
14,125.1 5,259.1 90.40 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #19
Water
Swell
H30415XM
OD
3.830
14,351.6 5,258.9 90.10 Sleeve - Frac #19 5.000 BAKER Frac Sleeve (2.645" ball)
#18, HYD563
Frac
sleeve
H80908039
5
2.605
14,561.3 5,258.2 90.05 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #18
Water
Swell
H30415XM
OD
3.890
14,830.7 5,257.5 90.06 Sleeve - Frac #18 5.000 BAKER Frac Sleeve (2.595" ball)
#17, HYD563
Frac
sleeve
H80908039
4
2.555
15,080.4 5,256.4 90.46 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #17
Water
Swell
H30415XM
OD
3.910
15,309.9 5,255.2 90.34 Sleeve - Frac #17 5.000 BAKER Frac Sleeve (2.545" ball)
#16, HYD563
Frac
sleeve
H80908039
3
2.505
15,561.1 5,253.8 90.35 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #16
Water
Swell
H30415XM
OD
3.890
15,789.5 5,252.1 90.45 Sleeve - Frac #16 5.000 BAKER Frac Sleeve (2.495" ball)
#15, HYD563
Frac
sleeve
H80908039
2
2.465
16,081.2 5,250.6 90.20 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #15
Water
Swell
H30415XM
OD
3.880
16,268.1 5,249.9 90.35 Sleeve - Frac #15 5.000 BAKER Frac Sleeve (2.455" ball)
#14, HYD563
Frac
sleeve
H80908039
1
2.425
16,519.0 5,248.7 90.30 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #14
Water
Swell
H30415XM
OD
3.920
16,788.8 5,246.5 90.55 Sleeve - Frac #14 5.000 BAKER Frac Sleeve (2.415" ball)
#13, HYD563
Frac
sleeve
H80908039
0
2.385
17,081.3 5,244.0 90.47 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #13
Water
Swell
H30415XM
OD
3.910
17,309.9 5,241.9 90.50 Sleeve - Frac #13 5.000 BAKER Frac Sleeve (2.375" ball)
#12, HYD563
Frac
sleeve
H80908039
0
2.345
17,600.2 5,239.2 90.61 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #12
Water
Swell
H30415XM
OD
3.910
17,868.3 5,236.7 90.38 Sleeve - Frac #12 5.000 BAKER Frac Sleeve (2.335" ball)
#11, HYD563
Frac
sleeve
H80908038
8
2.305
18,117.4 5,234.7 90.49 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #11
Water
Swell
H30415XM
OD
3.890
18,387.2 5,232.2 90.54 Sleeve - Frac #11 5.000 BAKER Frac Sleeve (2.295" ball)
#10, HYD563
Frac
sleeve
H80908038
7
2.265
18,638.2 5,230.1 90.40 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #10
Water
Swell
H30415XM
OD
3.910
18,906.0 5,228.1 90.42 Sleeve - Frac #10 5.000 BAKER Frac Sleeve (2.255" ball)
#9, HYD563
Frac
sleeve
H80908038
6
2.225
19,114.0 5,226.4 90.53 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #9
Water
Swell
H30415XM
OD
3.890
19,425.4 5,223.1 90.47 Sleeve - Frac #9 5.000 BAKER Frac Sleeve (2.215" ball)
#8, HYD563
Frac
sleeve
H80908038
5
2.185
19,676.7 5,221.8 90.16 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #8
Water
Swell
H30415XM
OD
3.910
19,946.6 5,220.6 90.57 Sleeve - Frac #8 5.000 BAKER Frac Sleeve (2.175" ball)
#7, HYD563
Frac
sleeve
H80908038
4
2.145
20,197.7 5,217.2 90.93 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #7
Water
Swell
H30415XM
OD
3.930
20,467.7 5,213.2 90.63 Sleeve - Frac #7 5.000 BAKER Frac Sleeve (2.135" ball)
#6, HYD563
Frac
sleeve
H80908038
3
2.105
HORIZONTAL, 3S-615, 2/12/2024 10:32:04 AM
Vertical schematic (actual)
LINER; 11,531.4-23,756.0
Hydraulic fracture; 23,590.0
Hydraulic fracture; 23,060.0
Hydraulic fracture; 22,545.0
Hydraulic fracture; 22,026.0
Hydraulic fracture; 21,509.0
Hydraulic fracture; 20,988.0
Hydraulic fracture; 20,468.0
Hydraulic fracture; 19,947.0
Hydraulic fracture; 19,425.0
Hydraulic fracture; 18,906.0
Hydraulic fracture; 17,868.0
Hydraulic fracture; 17,310.0
Hydraulic fracture; 16,789.0
Hydraulic fracture; 16,268.0
Hydraulic fracture; 15,790.0
Hydraulic fracture; 15,310.0
Hydraulic fracture; 14,831.0
Hydraulic fracture; 14,352.0
Hydraulic fracture; 13,876.0
Hydraulic fracture; 13,399.0
Hydraulic fracture; 12,922.0
Hydraulic fracture; 12,485.0
Hydraulic fracture; 11,965.0
INTERMEDIATE; 34.5-11,706.0
Nipple - DB; 11,345.0
Sleeve - Sliding; 10,458.8
FISH; 10,226.0
Mandrel – GAS LIFT; 6,417.3
SURFACE; 36.6-3,069.0
Mandrel – GAS LIFT; 2,951.9
HANGER; 33.2
KUP PROD 3S-615
...
WELLNAME WELLBORE3S-615
Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal ID
(in)
20,718.8 5,211.0 90.00 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #6
Water
Swell
H30415XM
OD
3.810
20,988.1 5,211.7 89.90 Sleeve - Frac #6 5.000 BAKER Frac Sleeve (2.095" ball)
#5, HYD563
Frac
sleeve
H80908038
2
2.065
21,239.3 5,211.3 90.54 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #5
Water
Swell
H30415XM
OD
3.930
21,509.0 5,209.1 90.51 Sleeve - Frac #5 5.000 BAKER Frac Sleeve (2.055" ball)
#4, HYD563
Frac
sleeve
H80908038
1
2.025
21,756.6 5,206.7 90.58 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #4
Water
Swell
H30415XM
OD
3.910
22,026.3 5,204.5 90.46 Sleeve - Frac #4 5.000 BAKER Frac Sleeve (2.015" ball)
#3, HYD563
Frac
sleeve
H80908072
6
1.985
22,275.3 5,202.2 90.62 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #3
Water
Swell
H30415XM
OD
3.880
22,545.1 5,200.2 90.63 Sleeve - Frac #3 5.000 BAKER Frac Sleeve (1.975" ball)
#2, HYD563
Frac
sleeve
H80908072
5
1.945
22,790.0 5,197.6 90.71 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #2
Water
Swell
H30415XM
OD
3.950
23,059.7 5,196.1 90.15 Sleeve - Frac #2 5.000 BAKER Frac Sleeve (1.935" ball)
#1, HYD563
Frac
sleeve
H80908072
4
1.905
23,352.1 5,197.2 89.07 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #1
Water
Swell
H30415XM
OD
3.910
23,589.9 5,200.6 89.50 Sleeve - Frac #1 5.620 Alpha Pressure Sleeve, 4 1/2",
13.5#, Q125
Alpha
Sleeve
H81047006
8
3.000
23,593.6 5,200.7 89.53 Sleeve - Frac 5.660 Wellbore Isolation Valve, 4 1/2",
13.5#, P110
WIV H80914004
2
1.250
Stimulation Intervals
Top (ftKB) Btm (ftKB)
Inter
val
Num
ber Type Subtype Start Date
Proppant
Designed (lb)
Proppant
Total (lb)
Vol Clean
Total (bbl)
Vol Slurry
Total (bbl)
23,590.0 23,594.0 1 Hydraulic
fracture
1/6/2023 207,200.0 207,911.0 5,136.00 5,360.00
23,060.0 23,062.0 2 Hydraulic
fracture
1/7/2023 207,200.0 206,714.0 3,398.00 3,621.00
22,545.0 22,548.0 3 Hydraulic
fracture
1/7/2023 207,200.0 0.0 1,027.00 1,027.00
22,026.0 22,029.0 4 Hydraulic
fracture
1/8/2023 207,200.0 208,437.0 3,251.00 3,476.00
21,509.0 21,511.0 5 Hydraulic
fracture
1/8/2023 207,200.0 206,325.0 2,949.00 3,172.00
20,988.0 20,991.0 6 Hydraulic
fracture
1/9/2023 207,200.0 203,967.0 2,766.00 2,986.00
20,468.0 20,470.0 7 Hydraulic
fracture
1/9/2023 207,200.0 206,751.0 2,833.00 3,057.00
19,947.0 19,949.0 8 Hydraulic
fracture
1/18/2023 207,200.0 206,940.0 2,708.00 2,931.00
19,425.0 19,428.0 9 Hydraulic
fracture
1/18/2023 207,200.0 203,938.0 2,447.00 2,667.00
18,906.0 18,908.0 10 Hydraulic
fracture
1/18/2023 207,200.0 196,230.0 2,671.00 2,883.00
17,868.0 17,871.0 12 Hydraulic
fracture
1/26/2023 207,200.0 208,803.0 2,873.00 3,099.00
17,310.0 17,312.0 13 Hydraulic
fracture
1/26/2023 207,200.0 203,292.0 2,503.00 2,722.00
16,789.0 16,791.0 14 Hydraulic
fracture
1/26/2023 207,200.0 201,030.0 2,755.00 2,972.00
16,268.0 16,271.0 15 Hydraulic
fracture
1/28/2023 207,200.0 196,477.0 2,805.00 3,017.00
15,790.0 15,792.0 16 Hydraulic
fracture
1/28/2023 207,200.0 203,209.0 2,728.00 2,947.00
15,310.0 15,312.0 17 Hydraulic
fracture
1/29/2023 207,200.0 200,687.0 2,641.00 2,858.00
14,831.0 14,833.0 18 Hydraulic
fracture
1/29/2023 207,200.0 202,142.0 2,453.00 2,671.00
14,352.0 14,354.0 19 Hydraulic
fracture
1/29/2023 207,200.0 206,465.0 3,043.00 3,266.00
13,876.0 13,879.0 20 Hydraulic
fracture
1/31/2023 207,200.0 210,380.0 2,871.00 3,098.00
13,399.0 13,402.0 21 Hydraulic
fracture
1/31/2023 207,200.0 208,214.0 2,502.00 2,727.00
12,922.0 12,924.0 22 Hydraulic
fracture
1/31/2023 207,200.0 203,930.0 2,886.00 3,106.00
12,485.0 12,488.0 23 Hydraulic
fracture
2/1/2023 207,200.0 206,512.0 2,602.00 2,825.00
11,965.0 11,967.0 24 Hydraulic
fracture
2/2/2023 207,200.0 206,404.0 2,837.00 3,059.00
HORIZONTAL, 3S-615, 2/12/2024 10:32:05 AM
Vertical schematic (actual)
LINER; 11,531.4-23,756.0
Hydraulic fracture; 23,590.0
Hydraulic fracture; 23,060.0
Hydraulic fracture; 22,545.0
Hydraulic fracture; 22,026.0
Hydraulic fracture; 21,509.0
Hydraulic fracture; 20,988.0
Hydraulic fracture; 20,468.0
Hydraulic fracture; 19,947.0
Hydraulic fracture; 19,425.0
Hydraulic fracture; 18,906.0
Hydraulic fracture; 17,868.0
Hydraulic fracture; 17,310.0
Hydraulic fracture; 16,789.0
Hydraulic fracture; 16,268.0
Hydraulic fracture; 15,790.0
Hydraulic fracture; 15,310.0
Hydraulic fracture; 14,831.0
Hydraulic fracture; 14,352.0
Hydraulic fracture; 13,876.0
Hydraulic fracture; 13,399.0
Hydraulic fracture; 12,922.0
Hydraulic fracture; 12,485.0
Hydraulic fracture; 11,965.0
INTERMEDIATE; 34.5-11,706.0
Nipple - DB; 11,345.0
Sleeve - Sliding; 10,458.8
FISH; 10,226.0
Mandrel – GAS LIFT; 6,417.3
SURFACE; 36.6-3,069.0
Mandrel – GAS LIFT; 2,951.9
HANGER; 33.2
KUP PROD 3S-615
...
WELLNAME WELLBORE3S-615
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PTD: 222-101
T38008
Kayla Junke 9/22/2023
Kayla
Junke
Digitally signed
by Kayla Junke
Date: 2023.09.22
11:57:58 -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: Convert GL to ESP
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 23770'feet None feet
true vertical 5201' feet None feet
Effective Depth measured 23770'feet 11271', 11531'feet
true vertical 5201' feet 4990', 5075' feet
Perforation depth Measured depth
True Vertical depth
Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 11537' MD 5076' TVD
Packers and SSSV (type, measured and true vertical depth) 11271' MD
11531' MD
N/A
4990' TVD
5075' TVD
N/A
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure: N/A
13a.
Prior to well operation:
Subsequent to operation:
13b. Pools active after work:
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: Contact Name:
Contact Email:
Authorized Title: Contact Phone:
3069' 2543'
Burst Collapse
Production
Liner
11671'
12225'
Casing
5130'
4-1/2"
11706'
23756' 5201'
3032'
114'Conductor
Surface
Intermediate
20"
10-3/4"
77'
measured
TVD
7-5/8"
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
222-101
50-103-20844-00-00
P.O. Box 100360
Anchorage, AK 99510
3. Address:
ConocoPhillips Alaska, Inc.
N/A
5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work:
ADL0025528, ADL0025544, ADL0380107
Kuparuk Field/Torok Oil Pool
KRU 3S-615
Plugs
Junk measured
Length
measured
true vertical
Packer
Representative Daily Average Production or Injection Data
Casing Pressure Tubing Pressure
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
1235
Gas-Mcf
MD
975
Size
114'
6390 2202223
1354 2406380
195
N/A
Sr Pet Eng: Sr Pet Geo: Sr Res Eng:
WINJ WAG
2140
Water-BblOil-Bbl
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
N/A
Packer: HAL TNT Prod Packer
Packer: ZXP Packer
SSSV: None
Brian Lewis
brian.m.lewis@conocophillips.com
(907) 263-4535Senior Production Engineer
None
None
Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
Torok Oil Pool
By Grace Christianson at 9:17 am, Jul 31, 2023
DTTMSTART JOBTYP SUMMARYOPS
6/14/2023 ACQUIRE DATA MIRU, PERFORM WEEKLY BOP TEST, DRY TAG AT 10274' CTMD, FLUFF-N-STUFF DOWN TO
19620'. JOB IN PROGRESS.
6/15/2023 ACQUIRE DATA FLUFF-N-STUFF DOWN TO 19620' CTMD. RUN SPECTRASCAN GAMMA RAY LOGGING TOOLS
DOWN TO 11,500' LOG DOWN @30FPM TO LOCK UP AT 19400', LOG UP FROM 19400 TO
11,500' @ 30FPM. DOWNLOAD DATA. GOOD DATA. MAKE UP FISHING BHA. JOB IN
PROGRESS.
6/16/2023 ACQUIRE DATA LATCH ISO SLEEVE @ 10282', SHIFT SLIDING SLEEVE OPEN AT 10225', UNABLE TO LATCH X
ISO SLEEVE @ 10459', STAND BACK FOR SLICKLINE TO TRY AND PULL X ISO SLEEVE.
6/16/2023 ACQUIRE DATA ***ASSIST COIL***
PULLED 3.13" ISO SLEEVE FROM CMU @ 10459' RKB & SHIFTED TO OPEN POSITION, IN
PROGRESS
6/17/2023 ACQUIRE DATA PUSH MOTOR TO BOTTOM, TAG AT 10273' CTMD, WE HAD A FAILED SET ATTEMPT, PUH TO
2500' CTMD AND PUMP OFF OF THE MOTOR, REDRESS MOTOR ARM, SLICKLINE DEPLOY IN
THE WELL. COIL PUSH MOTOR TO BOTTOM, TAG @ 10273' CTMD, HAD ANOTHER FAILED
SET ATTEMPT. DROP MOTOR FOR SLICKLINE TO RECOVER FROM THE WELL. INSPECT
MOTOR, FOUND ONE BROKE ROD ON THE ARM. MAKE UP FCO BHA, SEND ACCESS TO
CAMP TO GET SOME SLEEP. JOB IN PROGRESS.
6/17/2023 ACQUIRE DATA ***ASSIST COIL***
DEPLOYED ACCESS MOTOR FOR COIL @ 2150' SLM, COIL UNABLE TO SET MOTOR, PULL
MOTOR FROM 2850' SLM, ACCESS RE-DRESS MOTOR, DEPLOYED MOTOR AGAIN FOR COIL
@ 2400' SLM, COIL STILL UNABLE TO SET MOTOR, PULLED MOTOR, ACCESS RE-DRESS
MOTOR AGAIN, IN PROGRESS
6/18/2023 ACQUIRE DATA WASH ACROSS ACP, B PROFILE AND NO-GO, (10282'-10340') 4 TIMES. OOH WAIT FOR
ACCESS ESP TO REST AND GET NEW ARM FROM DEADHORSE. SET MOTOR AT 10248'
CTMD, GOT GOOD CONNECTION. SLICKLINE DEPLOY SUMMIT PUMP, COIL SET PUMP AT
10195' CTMD. JOB IN PROGRESS.
6/18/2023 ACQUIRE DATA ***ASSIST COIL***
DEPLOYED MOTOR FOR COIL @ 2400' SLM. STANDBY FOR COIL TO SET MOTOR. DEPLOYED
PUMP FOR COIL @ 2400' SLM. JOB COMPLETE
6/19/2023 ACQUIRE DATA SET PACK-OFF @ 10,200' CTMD, TEST PACKOFF TO 2500 PSI (NO SHEAR OUT VAVLE).
GOOD TEST. SET SLIP-STOP @ 10,197' CTMD, F/P TBG WITH 50 BBLS SLICK DIESEL, RDMO
CTU, READY FOR SLICKLINE, JOB IN PROGRESS.
6/19/2023 ACQUIRE DATA STANDBY FOR COIL TO DEMOB. SET 4.5" SLIP STOP CATCHER @ 6561' RKB. IN PROGRESS.
6/20/2023 ACQUIRE DATA PULLED OV @ 6417' RKB & REPLACED W/ 2000# SOV, TESTED TBG TO 1000 PSI, PULLED
SLIP STOP CATCHER @ 6561' RKB. JOB COMPLETE.
3S-615 Convert GL to ESP
Summary of Operations
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Pulled OV, Set SOV 3S-615 6/20/2023 rogerba
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread
CONDUCTOR 20 18.50 36.3 113.8 120.00 H160
SURFACE 10 3/4 9.95 36.6 3,069.0 2,543.0 45.50 L80 H563
INTERMEDIATE 7 5/8 6.88 34.5 11,706.0 5,129.9 29.70 L-80 Hyd 563
LINER 4 1/2 3.96 11,531.4 23,756.0 5,200.7 12.60 L80 HYD 563
Tubing Strings: string max indicates LONGEST segment of string
Top (ftKB)
33.2
Set Depth
11,537.0
Set Depth
5,076.4
String Ma
4 1/2
Tubing Description
Tubing Completion Upper
Wt (lb/ft)
12.60
Grade
L80
Top Connection
H563
ID (in)
3.96
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
33.2 33.2 0.00 HANGER 10.850 Cameron 4-1/2" Tubing Hanger,
H563
Camero
n
C-SRL-
CL
3.958
2,951.9 2,489.8 61.59 Mandrel GAS
LIFT
4.500 4-1/2" Camco KBMG GLM Schlumb
erger
KBMG 3.900
6,417.3 3,567.2 73.51 Mandrel GAS
LIFT
4.500 4-1/2" Camco KBMG GLM Schlumb
erger
KBMG 3.900
10,085.7 4,612.9 72.99 Sensor -
Discharge
Gauge
4.500 HAL ROC Discharge DHG +
Mandrel, 4-1/2" 12.6# L-80 Hyd 563
Halliburt
on
Opsis
Single
Ended
Gauge
Carrier
3.921
10,224.2 4,653.7 72.78 XO 4.500 Pup joint, X-over, 4-1/2" Hyd 563
box x VAM top pin
Access
ESP
3.958
10,225.3 4,654.1 72.78 Sleeve - Sliding 5.500 CMD Gas Venting Sliding Sleeve
(OPEN position 6/16/2023), 4-1/2"
Vam top box x 5-1/2" VAM FJL box
Access
ESP
3.910
10,230.2 4,655.5 72.74 Motor 5.500 Motor Shroud 8, 5.5" 23# VAM FJL
Pin x 5.5" 23# VAM FJL Pin
Access
ESP
4.548
10,235.0 4,656.9 72.71 Centralizer 5.500 Motor Centralizer 7, 5.5" 23# VAM
FJL BOX x 5.5" VAM FJL BOX
Access
ESP
3.893
10,236.8 4,657.5 72.70 Motor 5.500 Motor Shroud 7, 5.5" 23# VAM FJL
Pin x 5.5" 23# VAM FJL Pin
Access
ESP
4.548
10,241.6 4,658.9 72.67 Centralizer 5.500 Motor Centralizer 6, 5.5" 23# VAM
FJL BOX x 5.5" VAM FJL BOX
Access
ESP
3.893
10,243.3 4,659.4 72.66 Motor 5.500 Motor Shroud 6, 5.5" 23# VAM FJL
Pin x 5.5" 23# VAM FJL Pin
Access
ESP
4.548
10,248.1 4,660.8 72.63 Centralizer 5.500 Motor Centralizer 5, 5.5" 23# VAM
FJL BOX x 5.5" VAM FJL BOX
Access
ESP
3.893
10,249.9 4,661.4 72.62 Motor 5.500 Motor Shroud 5, 5.5" 23# VAM FJL
Pin x 5.5" 23# VAM FJL Pin
Access
ESP
4.548
10,254.7 4,662.8 72.59 Centralizer 5.500 Motor Centralizer 4, 5.5" 23# VAM
FJL BOX x 5.5" VAM FJL BOX
Access
ESP
3.893
10,256.4 4,663.3 72.57 Motor 5.500 Motor Shroud 4, 5.5" 23# VAM FJL
Pin x 5.5" 23# VAM FJL Pin
Access
ESP
4.548
10,261.2 4,664.8 72.54 Centralizer 5.500 Motor Centralizer 3, 5.5" 23# VAM
FJL BOX x 5.5" VAM FJL BOX
Access
ESP
3.893
10,263.0 4,665.3 72.53 Motor 5.500 Motor Shroud 3, 5.5" 23# VAM FJL
Pin x 5.5" 23# VAM FJL Pin
Access
ESP
4.548
10,267.8 4,666.7 72.50 Centralizer 5.500 Motor Centralizer 2, 5.5" 23# VAM
FJL BOX x 5.5" VAM FJL BOX
Access
ESP
3.893
10,269.5 4,667.3 72.49 Motor 5.500 Motor Shroud 2, 5.5" 23# VAM FJL
Pin x 5.5" 23# VAM FJL Pin
Access
ESP
4.548
10,274.3 4,668.7 72.46 Centralizer 5.500 Motor Centralizer 1, 5.5" 23# VAM
FJL BOX x 5.5" VAM FJL BOX
Access
ESP
3.893
10,276.1 4,669.2 72.45 Motor 5.500 Motor Shroud 1, 5.5" 23# VAM FJL
Pin x 5.5" 23# VAM FJL Pin
Access
ESP
4.548
10,282.4 4,671.1 72.41 Annular
Connection
Port (ACP)
5.950 5" VAM FJL Box x 4-1/2" VAM top
Box, Annular Connection Port (ACP)
Access
ESP
3.860
10,306.0 4,678.3 72.25 B Profile
Assembly
4.967 B-profile, 4.5" 12.6# VAM Top Box x
4.5" 12.6# VAM Top Box
Access
ESP
3.913
10,319.5 4,682.4 72.18 Nipple - No Go 5.220 No-GO, 4.5" 12.6# VAM Top Box x
4.5" VAM Top Box
Access
ESP
3.813
10,458.8 4,725.8 71.57 Sleeve - Sliding 4.500 CMU SLB Sliding Sleeve (OPEN
position 6/17/2023), 4-1/2" 12.6# L-
80 Hyd 563, 3.813" X
Slumber
ger
NEXA-2 3.813
11,270.6 4,990.5 70.79 Packer 7.625 HAL TNT Production Packer
4.5"x7.63"
Halliburt
on
TNT 3.810
11,345.0 5,014.7 71.30 Nipple - DB 4.500 NIPPLE,LANDING,4 1/2", DB,
3.562"
Slumber
ger
DB
Nipple
3.562
11,397.9 5,031.6 71.29 Sub - Shear
Out - SOS
5500psi
4.500 Arsenal Glass Plug - 5500 psi shear Arsenal 11937-
01-01
3.890
11,528.1 5,073.6 71.16 Locator 6.400 Baker Shear Type Locator sub -
above locating shoulder
Baker 3.860
11,528.7 5,073.8 71.16 Locator 5.640 Baker Shear Type Locator - to
locating shoulder (Shear pins 1'
below shoulder)
Baker 3.860
11,533.8 5,075.4 71.15 Shoe - Mule 4.500 Halliburton Ratcheting Muleshoe Halliburt
on
Ratcheti
ng
3.900
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
10,182.6 4,641.5 72.84 SLIP STOP Set Slipstop 6/20/2023 2.250
HORIZONTAL, 3S-615, 7/27/2023 11:07:09 AM
Vertical schematic (actual)
LINER; 11,531.4-23,756.0
INTERMEDIATE; 34.5-11,706.0
Nipple - DB; 11,345.0
Sleeve - Sliding; 10,458.8
ESP MOTOR; 10,235.5
ESP; 10,187.5
PACKOFF; 10,184.4
SLIP STOP; 10,182.6
Mandrel GAS LIFT; 6,417.3
SURFACE; 36.6-3,069.0
Mandrel GAS LIFT; 2,951.9
HANGER; 33.2
KUP PROD
KB-Grd (ft)
36.25
RR Date
12/17/202
2
Other Elev
3S-615
...
TD
Act Btm (ftKB)
23,770.0
Well Attributes
Field Name
TRACT OPERATION MORTR05
Wellbore API/UWI
501032084400
Wellbore Status
PROD
Max Angle & MD
Incl (°)
91.14
MD (ftKB)
20,303.77
WELLNAME WELLBORE3S-615
Annotation End DateH2S (ppm) DateComment
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
10,184.4 4,642.0 72.85 PACKOFF Set Packoff 6/20/2023 1.000
10,187.5 4,642.9 72.85 ESP Set Summit ESP (OAL = 48') Summit
ESP
6/18/2023 0.000
10,235.5 4,657.1 72.71 ESP MOTOR Set Access ESP Motor (OAL =
55')
Access
ESP
6/18/2023 0.000
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi) Run Date Com Make Model
Port
Size (in)
2,951.9 2,489.8 61.59 1 ESP DMY BK 1 0.0 2/8/2023 0.000
6,417.3 3,567.2 73.51 2 ESP SOV BK 1 0.0 6/20/2023 2000
PSI
TBG
Shear
0.000
Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal ID
(in)
11,531.4 5,074.6 71.16 PACKER 6.530 5.5" X 7-5/8" ZXP Packer w/
11.29' x 5.75" ID TieBK Sleeve
~ 175' lap
ZXP LTP H29645026
5-COI
4.820
11,551.0 5,081.0 71.23 Nipple - RS 6.020 RS Packoff Seal Nipple R/S
Nipple
10553458-
COI
4.240
11,562.7 5,084.7 71.30 XO Reducing 6.060 5.5" Hyd 563 box X pin 4.5" Hyd
563 cross over
3.880
11,736.0 5,139.4 71.57 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #24
Water
Swell
H30415XM
OD
3.930
11,964.5 5,202.4 76.73 Sleeve - Frac #24 5.000 BAKER Frac Sleeve (2.895" ball)
#23, HYD563
Frac
sleeve
H80908026
4
2.855
12,174.2 5,241.2 82.11 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #23
Water
Swell
H30415XM
OD
3.900
12,485.3 5,262.8 89.96 Sleeve - Frac #23 5.000 BAKER Frac Sleeve (2.845" ball)
#22, HYD563
Frac
sleeve
H80908072
8
2.805
12,695.0 5,262.0 90.16 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #22
Water
Swell
H30415XM
OD
3.860
12,921.8 5,262.5 90.11 Sleeve - Frac #22 5.000 BAKER Frac Sleeve (2.795" ball)
#21, HYD563
Frac
sleeve
H80908039
8
2.755
13,171.1 5,262.0 90.18 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #21
Water
Swell
H30415XM
OD
3.920
13,399.2 5,261.4 90.13 Sleeve - Frac #21 5.000 BAKER Frac Sleeve (2.745" ball)
#20, HYD563
Frac
sleeve
H80908039
7
2.705
13,691.2 5,260.6 90.05 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #20
Water
Swell
H30415XM
OD
3.940
13,876.3 5,260.5 90.07 Sleeve - Frac #20 5.000 BAKER Frac Sleeve (2.695" ball)
#19, HYD563
Frac
sleeve
H80908039
6
2.655
14,125.1 5,259.1 90.40 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #19
Water
Swell
H30415XM
OD
3.830
14,351.6 5,258.9 90.10 Sleeve - Frac #19 5.000 BAKER Frac Sleeve (2.645" ball)
#18, HYD563
Frac
sleeve
H80908039
5
2.605
14,561.3 5,258.2 90.05 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #18
Water
Swell
H30415XM
OD
3.890
14,830.7 5,257.5 90.06 Sleeve - Frac #18 5.000 BAKER Frac Sleeve (2.595" ball)
#17, HYD563
Frac
sleeve
H80908039
4
2.555
15,080.4 5,256.4 90.46 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #17
Water
Swell
H30415XM
OD
3.910
15,309.9 5,255.2 90.34 Sleeve - Frac #17 5.000 BAKER Frac Sleeve (2.545" ball)
#16, HYD563
Frac
sleeve
H80908039
3
2.505
15,561.1 5,253.8 90.35 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #16
Water
Swell
H30415XM
OD
3.890
15,789.5 5,252.1 90.45 Sleeve - Frac #16 5.000 BAKER Frac Sleeve (2.495" ball)
#15, HYD563
Frac
sleeve
H80908039
2
2.465
16,081.2 5,250.6 90.20 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #15
Water
Swell
H30415XM
OD
3.880
16,268.1 5,249.9 90.35 Sleeve - Frac #15 5.000 BAKER Frac Sleeve (2.455" ball)
#14, HYD563
Frac
sleeve
H80908039
1
2.425
16,519.0 5,248.7 90.30 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #14
Water
Swell
H30415XM
OD
3.920
16,788.8 5,246.5 90.55 Sleeve - Frac #14 5.000 BAKER Frac Sleeve (2.415" ball)
#13, HYD563
Frac
sleeve
H80908039
0
2.385
17,081.3 5,244.0 90.47 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #13
Water
Swell
H30415XM
OD
3.910
17,309.9 5,241.9 90.50 Sleeve - Frac #13 5.000 BAKER Frac Sleeve (2.375" ball)
#12, HYD563
Frac
sleeve
H80908039
0
2.345
17,600.2 5,239.2 90.61 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #12
Water
Swell
H30415XM
OD
3.910
17,868.3 5,236.7 90.38 Sleeve - Frac #12 5.000 BAKER Frac Sleeve (2.335" ball)
#11, HYD563
Frac
sleeve
H80908038
8
2.305
18,117.4 5,234.7 90.49 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #11
Water
Swell
H30415XM
OD
3.890
18,387.2 5,232.2 90.54 Sleeve - Frac #11 5.000 BAKER Frac Sleeve (2.295" ball)
#10, HYD563
Frac
sleeve
H80908038
7
2.265
18,638.2 5,230.1 90.40 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #10
Water
Swell
H30415XM
OD
3.910
18,906.0 5,228.1 90.42 Sleeve - Frac #10 5.000 BAKER Frac Sleeve (2.255" ball)
#9, HYD563
Frac
sleeve
H80908038
6
2.225
19,114.0 5,226.4 90.53 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #9
Water
Swell
H30415XM
OD
3.890
19,425.4 5,223.1 90.47 Sleeve - Frac #9 5.000 BAKER Frac Sleeve (2.215" ball)
#8, HYD563
Frac
sleeve
H80908038
5
2.185
19,676.7 5,221.8 90.16 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #8
Water
Swell
H30415XM
OD
3.910
19,946.6 5,220.6 90.57 Sleeve - Frac #8 5.000 BAKER Frac Sleeve (2.175" ball)
#7, HYD563
Frac
sleeve
H80908038
4
2.145
20,197.7 5,217.2 90.93 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #7
Water
Swell
H30415XM
OD
3.930
HORIZONTAL, 3S-615, 7/27/2023 11:07:09 AM
Vertical schematic (actual)
LINER; 11,531.4-23,756.0
INTERMEDIATE; 34.5-11,706.0
Nipple - DB; 11,345.0
Sleeve - Sliding; 10,458.8
ESP MOTOR; 10,235.5
ESP; 10,187.5
PACKOFF; 10,184.4
SLIP STOP; 10,182.6
Mandrel GAS LIFT; 6,417.3
SURFACE; 36.6-3,069.0
Mandrel GAS LIFT; 2,951.9
HANGER; 33.2
KUP PROD 3S-615
...
WELLNAME WELLBORE3S-615
Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal ID
(in)
20,467.7 5,213.2 90.63 Sleeve - Frac #7 5.000 BAKER Frac Sleeve (2.135" ball)
#6, HYD563
Frac
sleeve
H80908038
3
2.105
20,718.8 5,211.0 90.00 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #6
Water
Swell
H30415XM
OD
3.810
20,988.1 5,211.7 89.90 Sleeve - Frac #6 5.000 BAKER Frac Sleeve (2.095" ball)
#5, HYD563
Frac
sleeve
H80908038
2
2.065
21,239.3 5,211.3 90.54 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #5
Water
Swell
H30415XM
OD
3.930
21,509.0 5,209.1 90.51 Sleeve - Frac #5 5.000 BAKER Frac Sleeve (2.055" ball)
#4, HYD563
Frac
sleeve
H80908038
1
2.025
21,756.6 5,206.7 90.58 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #4
Water
Swell
H30415XM
OD
3.910
22,026.3 5,204.5 90.46 Sleeve - Frac #4 5.000 BAKER Frac Sleeve (2.015" ball)
#3, HYD563
Frac
sleeve
H80908072
6
1.985
22,275.3 5,202.2 90.62 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #3
Water
Swell
H30415XM
OD
3.880
22,545.1 5,200.2 90.63 Sleeve - Frac #3 5.000 BAKER Frac Sleeve (1.975" ball)
#2, HYD563
Frac
sleeve
H80908072
5
1.945
22,790.0 5,197.6 90.71 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #2
Water
Swell
H30415XM
OD
3.950
23,059.7 5,196.1 90.15 Sleeve - Frac #2 5.000 BAKER Frac Sleeve (1.935" ball)
#1, HYD563
Frac
sleeve
H80908072
4
1.905
23,352.1 5,197.2 89.07 Packer - Swell 4.500 PACKER,SWELL, 6.0", BAKER,
HYD563 #1
Water
Swell
H30415XM
OD
3.910
23,589.9 5,200.6 89.50 Sleeve - Frac #1 5.620 Alpha Pressure Sleeve, 4 1/2",
13.5#, Q125
Alpha
Sleeve
H81047006
8
3.000
23,593.6 5,200.7 89.53 Sleeve - Frac 5.660 Wellbore Isolation Valve, 4 1/2",
13.5#, P110
WIV H80914004
2
1.250
HORIZONTAL, 3S-615, 7/27/2023 11:07:09 AM
Vertical schematic (actual)
LINER; 11,531.4-23,756.0
INTERMEDIATE; 34.5-11,706.0
Nipple - DB; 11,345.0
Sleeve - Sliding; 10,458.8
ESP MOTOR; 10,235.5
ESP; 10,187.5
PACKOFF; 10,184.4
SLIP STOP; 10,182.6
Mandrel GAS LIFT; 6,417.3
SURFACE; 36.6-3,069.0
Mandrel GAS LIFT; 2,951.9
HANGER; 33.2
KUP PROD 3S-615
...
WELLNAME WELLBORE3S-615
STATE OF ALASKA ID
ALASKA OIL AND GAS CONSERVATION COMMISSION �BRyEKCaEy1aVJEunke at 11:15 am, Mar 29, 2023
REPORT OF SUNDRY WELL OPERATIONS
1. Operations Susp Well Insp❑ Plug Perforations ❑ Fracture Stimulate Q 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: ❑
2. Operator Name
4. Well Class Before Work:
5. Permit to Drill Number:
Conocophillips Alaska, Inc
Development ❑ Exploratory ❑
Stratigraphic ❑ Service ❑✓
222-101
3. Address: P.O. Box 100360, Anchorage, AK 99510
6. API Number:
50-103-20844-00-00
7. Property Designation (Lease Number):
8. Well Name and Number:
ADL 025528, ADL 025544, ADL 380107
KRU 3S-615
9. Logs (List logs and submit electronic data per 20AAC25.071): 8ft8Clled
10. Field/Pool(s):
Ku aruk River Unit / Torok Oil Pool
11. Present Well Condition Summary:
Total Depth measured 23770 feet Plugs measured None feet
true vertical 5200.7 feet Junk measured None feet
Effective Depth measured 23593.6 feet Packer measured 11270.6 feet
true vertical 5200.7 feet true vertical 4990.5 feet
Casing
Length
Size
MD
TVD
Burst
Collapse
Structural
Conductor
94
20
113
131
Surface
3032.3
10.75
3069
2543
5210
2470
Intermediate
11107.9
7.625
11143
4948
6890
4790
Intermediate
563
7.625
11706
5130
10860
7850
Liner
11063.6
4.5
23756
5201
8430
7500
see below
Perforation depth Measured depth feet Frac Sleeves attached below (page 11 of Post Job Reort)
True Vertical depth see below feet attached below (page 11 of Post Job Reort)
Tubing (size, grade, measured and true vertical depth) 4.5 L-80 (12.6 ppf) 11537 5076.4
no SSSV
Packers and SSSV (type, measured and true vertical depth) HAL TNT Prod Packer 11270.6 4990.5
12. Stimulation or cement squeeze summary: Stimulation details attached below
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure: volumes and pressures attached below
13a. Representative Daily Average Production or Injection Data
Oil-BbI Gas-Mcf I Water-BbI Casing Pressure Tubing Pressure
Prior to well operation: 10 10 10 10 11120
Subsequent to operation: 10 10 164,240 1700 11245
131b. Pools active after work: Kuparuk River Unit / Torok Oil Pool
14. Attachments (required per 20 AAC 25.070, 25.071, a 25.283)
15. Well Class after work:
Daily Report of Well Operations 0
Exploratory ❑ Development[_] Service Q Stratigraphic ❑
Copies of Logs and Surveys Run ❑
16. Well Status after work: Oil Gas WDSPL
Electronic Fracture Stimulation Data 0
GSTOR WINJ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑
17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt:
by:
-r,Do�/eueig�In/,eAd
I
Authorized Name and %r\<^yl�klYo�nl Mar-29-2023
Digital Signature with Date: Contact Name:
Contact Email:
Authorized Title: Contact Phone:
Sr Pet Eng: ISr Pet Geo: I ISr Res Eng: DSR-3/31/23
RBDMS JSB 033023
Form 10-404 Revised 1012022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
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HALLI S U RTO N Sales Order# 0908328056
Conoco Phillips
3S-615
Intervals 1-24 Kuparuk
A -Sand Formation
Harrison Bay County, AK
API: 50-103-20844
Prepared for: Dustin Morrow
February 2, 2023
Stimulation Treatment
Post Job Report
30# Hybor G
Prepared By:
Keegan Lambe
Daniel Faur
Nannook Crew
Notice: Although the information contained in this report is based on sound engineering practices, the
copyright owner(s) does (do) not accept any responsibility whatsoever, in negligence or otherwise, for any
loss or damage arising from the possession or use of the report whether in terms of correctness or
otherwise. The application, therefore, by the user of this report or any part thereof, is solely at the user's
own risk.
Table of Contents
Section
Page(s)
Executive Summary
3
Actual Design
4-9
Wellbore Information
10
Interval Summary
11-47
Fluid System-Proppant Summary
48
Interval 1 Plots
49 - 61
Interval 2 Plots
62 - 68
Interval 3 Plots
69 - 72
Interval 4 Plots
73 - 79
Interval 5 Plots
80 - 83
Interval 6 Plots
84 - 90
Interval 7 Plots
91- 94
Interval 8 Plots
95 -101
Interval 9 Plots
102 -105
Interval 10 Plots
106. ID9
Interval 11 Plots
110 -112
Interval 12 Plots
123 -116
Interval 13 Plots
117 -120
Interval 14 Plots
121-124
Interval 15 Plots
125 -132
Interval 16 Plots
132 -135
Interval 17 Plots
136 -142
Interval 18 Plots
143 -146
Interval 19 Plots
147 -150
Interval 20 Plots
151-157
Interval 21 Plots
158 -162
Interval 22 Plots
162 -168
Interval 23 Plots
169 -172
Interval 24 Plots
173 -178
Appendix
179
Well Summary
180
Chemical Summary
181
Planned Design
182 -189
Real -Time QC
190 -191
Water Analysis Jan 3
192
Water Analysis Jan 4
193
Water Analysis Jan 6
194
Water Analysis Jan 7
195
Water Analysis Jan 8
196
Water Analysis Jan 12
197
Water Analysis Jan 17
198
Water Analysis Jan 18
199
Water Analysis Jan 25
200
Water Analysis Jan 28
201
Water Analysis Jan 29
202
Water Analysis Jan 30
203
Water Analysis Feb 1
204
Water Analysis Feb 2
205
Water Straps Jan 4
206
Water Straps Jan 6
207
Water Straps Jan 7
208
Water Straps Jan 8
209
Water Straps Jan 9
220
Water Straps Jan 17
211
Water Straps Jan 18
212
Water Straps Jan 26
223
Water Straps Jan 28
214
Water Straps Jan 29
215
Water Straps Jan 31
226
Water Straps Feb 1
217
Water Straps Feb 2
218
Prejob Break Test Day 1
229
Farm Test Interval
220
Farm Test Interval
221
Farm Test Interval
222
Farm Test Interval
223
Farm Test Interval
224
Farm Test Interval
225
Farm Test Interval?
226
Farm Test Interval
227
Farm Test Interval
228
Farm Test Interval 30
229
Conoco Phillips-35-615 TOC
Fann Test Interval 11
230
Fann Test Interval 12
231
Fann Test lnterva113
232
Fann Test Interval 14
233
Fann Test Interval 15
234
Fann Test lnteml 16
235
Fann Test Interval 17
236
Fann Test lnteml18
237
Fann Test lnterva119
238
Fann Test lnteml 20
239
Fann Test Interval 21
240
Fann Test lnterva122
241
Fann Test Interval 23
242
Fann Test Interval 24
243
Event Log Interval 01
244
Event Log Interval 2-3
246
Event Log Interval 4-5
247
Event Log Interval 6-7
248
Event Log Interval 8-10
249
Event Log Interval 11-14
250
Event Log Interval 15-16
251
Even[Log Interval l7-19
252
Event Log lnterva1 Nil
253
Event Log Interval 22-23
254
Event Log Interval 24
256
Conoco Phillips-35-615 TOC
Engineering Executive Summary
On January 03, 2023 a stimulation treatment was performed in the ASand formation on the 35-615 well in Harrison Bay
County, AK. The 35-615 was a 24 stage Horizontal Sleeve Design. The proposed treatment consisted of:
2,562,938 gallons of 30# Hybor G
150,995 gallons of 30# Linear
1,340 gallons of Seawater
12,000 gallons of Freeze Protect
20,000 gallons of Potassium Formate
4,657,600 pounds of Wanli 16/20 Ceramic
108,000 pounds of 100M
The actual treatment fully completed 22 of 24 stages. 2 stages were skipped, 0 stage screened out and 0 stages were cut short
of design. The actual treatment consisted of:
2,506,059 gallons of 30# Hybor G
190,247 gallons of 30# Linear
1,780 gallons of Seawater
9,686 gallons of Freeze Protect
8,967 gallons of Potassium Formate
4,440,921 pounds of Wanli 16/20 Ceramic
63,837 pounds of 100M
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 3 was skipped due to no ball seat being observed. The ball for Interval 12 was dropped in place of the ball for interval 11
leading to interval 11 being skipped.
The large gaps in treatement days were due to changing of a sleeve in the well, weather delays and completing work in Alpine.
Due to shortages of 100M, 16120 was pumped in place.
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.
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.
Thank you,
Keegan Lambe
Senior Technical Professional
Halliburton Energy Services
Pablo Hernandez Gonzalez
Senior Technical Professional
Halliburton Energy Services
Conoco Phillips - 35-615 Executive Summary
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Interval Summary
3a-O I a - nuparuK - /nfervel 7
Interval Summary
Start Date/Time:
1/6/23 11:40
End Date/Time:
1/6/23 14:05
Pump Time:
145 min
Initial Rate (Breakdown):
NA
bpm
Initial Surface Pressure (Breakdown):
NA
psi
Initial BH Pressure (Breakdown):
NA
psi
Ball Seat (Early):
NA
bbl
Max Rate:
30.3
bpm
Max Surface Pressure:
4,534
psi
Max BH Pressure:
5,891
psi
Average Rate:
26.6
bpm
Average Missile Pressure:
3,645
psi
Average Surface Pressure:
3,664
psi
Average BH Pressure:
5,121
psi
Average Missile HHP:
2,380
hhp
Initial CA Pressure:
317
psi
Max CA Pressure:
663
psi
Max Proppant Concentration:
5.12
PPg
Average Visc:
32
cP
Average Temp:
75.8
F
Average pH:
9.1
ISDP:
3399
psi
Final Fracture Gradient:
0.654
psi/ft
Final 5 min:
3263
psi
Final 10 min:
3256
psi
Final 15 min:
3247
psi
Proppant Summary
Wanli 16/20 Ceramic Pumped:
201,967
Ibs
100M Pumped:
5,944
Ibs
Total Proppant Pumped' :
207,911
Ibs
Proppant in Formation:
207,911
Ibs
Fluid Summary (by fluid description)
30# Hybor G Volume:
174,613
gal
4,157
bbls
30# Linear Volume:
36,467
gal
868
bbls
Seawater Volume:
1,780
gal
42
bbls
Freeze Protect Volume:
2,840
gal
68
bbls
Potassium Formate Volume:
0
gal
0
bbls
Conoco Phillips - 35-615 Interval Summary 12
Fluid Summary (by stage description)
Pad Volume.
25,187
gal
Conditioning Pad Volume:
28,897
gal
Proppant Laden Fluid Volume:
74,571
gal
Displacement Volume:
15,102
gal
Flush Volume:
30,799
gal
Freeze Protect Volume:
2,000
gal
Step Rate Test Volume:
5,533
gal
Establish Stable Fluid Volume:
18,336
gal
Minifrac Volume:
12,655
gal
Alpha Sleeve Volume:
949
gal
Spacer and Ball Drop Volume:
0
gal
DFIT Volume:
831
gal
Interval Status: Completed
600 bbls
688 bbls
1,776 bbls
360 bbls
733 bbls
48 bbls
132 bbls
437 bbls
301 bbls
23 bbls
0 bbls
20 bbls
Some cnem lines frozen oetore start treatment tngmeer Pablo Hernandez
Treater. Greg Koester
Supervisor: Greg Koester
'Values for proppant are taken from software calculations based on multiple variables. Customer Engineer:
Proppant is billed off of weight ticket volumes and may vary slightly from this number. Customer Rep: Greg Clayton
Conoco Phillips - 3S-615 Interval Summary 13
Start Date/Time: 1/7/23 11:23
End Date/Time: 1/7/23 12:57
Pump Time: 94 min
Initial Rate (Breakdown):
10.0
bpm
Initial Surface Pressure (Breakdown):
4,491
psi
Initial BH Pressure (Breakdown):
5,158
psi
Ball Seat (Early):
Ge
bbl
Max Rate:
29.9
bpm
Max Surface Pressure:
4,542
psi
Max BH Pressure:
6,064
psi
Average Rate:
24.6
bpm
Average Missile Pressure:
3,530
psi
Average Surface Pressure:
3,460
psi
Average BH Pressure:
4,927
psi
Average Missile HHP:
2,124
hhp
Initial CA Pressure:
322
psi
Max CA Pressure:
522
psi
Max Proppant Concentration:
5.03
Ppg
Average Vise:
29.5
cP
Average Temp:
61.6
F
Average pH:
9.06
Proppant Summary
Wanli 16/20 Ceramic Pumped:
200,232
Ibs
100M Pumped:
6,482
Ibs
Total Proppant Pumped` :
206,714
Ibs
Proppant in Formation:
206,714
Ibs
Fluid Summary (by fluid description)
30# Hybor G Volume:
141,429
gal
3,367
bbls
30# Linear Volume:
1,267
gal
30
bbls
Seawater Volume:
0
gal
0
bbls
Freeze Protect Volume:
0
gal
0
bbls
Potassium Formate Volume:
0
gal
0
bbls
Fluid Summary (by stage description)
Pad Volume:
24,991
gal
595
bbls
Conditioning Pad Volume:
28,886
gal
688
bb/s
Proppant Laden Fluid Volume:
72,850
gal
1,735
bb/s
Establish Stable Fluid Volume:
12,480
gal
297
bb/s
Spacer and Ball Drop Volume:
3,489
gal
83
bbls
Interval Status:
Completed
Conoco Phillips - 35-615 Interval Summary 14
for proppant are taken from software calculations based on multiple variables.
it is billed off of weight ticket volumes and may vary slightly from this number.
Treater: Greg Koester
Supervisor: Greg Koester
Customer Engineer.
Customer Rep: Greq Clavton
Conoco Phillips - 3S-615 Interval Summary 15
35-615 - Kuparuk - Interval 3
Interval Summary
Start Date/Time: 1/7/23 12:57
End Date/Time: 1/7/23 13:48
Pump Time: 51 min
Initial Rate (Breakdown):
0.0
bpm
Initial Surface Pressure (Breakdown):
0
psi
Initial BH Pressure (Breakdown):
0
psi
Ball Seat (Early):
NA
bbl
Max Rate:
30.4
bpm
Max Surface Pressure:
4,657
psi
Max BH Pressure:
5,986
psi
Average Rate:
17.4
bpm
Average Missile Pressure:
2,938
psi
Average Surface Pressure:
3,022
psi
Average BH Pressure:
4,488
psi
Average Missile HHP:
1,251
hhp
Initial CA Pressure:
498
psi
Max CA Pressure:
541
psi
Max Proppant Concentration:
ppg
Average Viso:
29.5
cP
Average Temp:
61.6
F
Average pH:
9.06
ISDP:
3395
psi
Final Fracture Gradient:
0.653
psi/ft
Final 5 min:
3284
psi
Final 10 min:
3271
psi
Final 15 min:
3265
psi
Proppant Summary
Wanli 16/20 Ceramic Pumped:
0
Ibs
100M Pumped:
0
Ibs
Total Proppant Pumped* :
0
Ibs
Proppant in Formation:
0
Ibs
Fluid Summary (by fluid description)
30# Hybor G Volume:
21,047
gal
30# Linear Volume:
19,977
gal
Seawater Volume:
0
gal
Freeze Protect Volume:
2,100
gal
Potassium Formate Volume:
0
gal
501 bbls
476 bbls
0 bbls
50 bbls
0 bbls
Fluid Summary (by stage description)
Pad Volume:
21,047
gal
501
bbls
Conditioning Pad Volume:
0
gal
0
bbls
Proppant Laden Fluid Volume:
0
gal
0
bbls
Displacement Volume:
0
gal
0
bbls
Flush Volume:
19,977
gal
476
bbls
Freeze Protect Volume:
2,100
gal
50
bbls
Interval Status:
Skipped
Conoco Phillips - 35-615 Interval Summary 16
for proppant are taken from software calculations based on multiple variables.
it is billed off of weight ticket volumes and may vary slightly from this number.
Treater: Greg Koester
Supervisor: Greg Koester
Customer Engineer.
Customer Rep: Greq Clavton
Conoco Phillips - 3S-615 Interval Summary 17
3S-615 - Kuparuk - Interval 4
Interval Summary
Start Date/Time: 1/8/23 12:45
End Date/Time: 1/8/23 14:54
Pump Time: 128 min
Initial Rate (Breakdown):
10.0
bpm
Initial Surface Pressure (Breakdown):
5,230
psi
Initial BH Pressure (Breakdown):
6,912
psi
Ball Seat (Early):
16
bbl
Max Rate:
30.6
bpm
Max Surface Pressure:
5,241
psi
Max BH Pressure:
6,914
psi
Average Rate:
26.2
bpm
Average Missile Pressure:
3,704
psi
Average Surface Pressure:
3,675
psi
Average BH Pressure:
5,083
psi
Average Missile HHP:
2,380
hhp
Initial CA Pressure:
359
psi
Max CA Pressure:
552
psi
Max Proppant Concentration:
6.30
Ppg
Average Viso:
32
cP
Average Temp:
67
F
Average pH:
9.1
Proppant Summary
Wanli 16/20 Ceramic Pumped:
201,804
/bs
100M Pumped:
6,633
/bs
Total Proppant Pumped* :
208,437
/bs
Proppant in Formation:
208,437
/bs
Fluid Summary (by fluid description)
30# Hybor G Volume:
133,492
gal
3,178
bbls
30# Linear Volume:
2,017
gal
48
bbls
Seawater Volume:
0
gal
0
bbls
Freeze Protect Volume:
1,050
gal
25
bbls
Potassium Formate Volume:
0
gal
0
bbls
Fluid Summary (by stage description)
Pad Volume:
25,025
gal
596
bbls
Conditioning Pad Volume:
30,056
gal
716
bbls
Proppant Laden Fluid Volume:
67,473
gal
1,607
bbls
Establish Stable Fluid Volume:
10,377
gal
247
bbls
Spacer and Ball Drop Volume:
2,578
gal
61
bbls
Interval Status:
Completed
No Issues tngrneer. Pablo Hernandez
Treater. Greg Koester
Supervisor: Greg Koester
*Values for proppant are taken from software calculations based on multiple variables. Customer Engineer:
Pnoppant is billed off of weight ticket volumes and may vary slightly from this number. Customer Rep: Greg Clayton
Conoco Phillips - 35-615 Interval Summary 18
Start Date/Time: 1/8/23 14:54
End Date/Time: 1/8/23 16:40
Pump Time: 106 min
Initial Rate (Breakdown):
9.1
bpm
Initial Surface Pressure (Breakdown):
5,250
psi
Initial BH Pressure (Breakdown):
6,998
psi
Ball Seat (Early):
39
bbl
Max Rate:
31.1
bpm
Max Surface Pressure:
5,264
psi
Max BH Pressure:
7,006
psi
Average Rate:
29.4
bpm
Average Missile Pressure:
3,846
psi
Average Surface Pressure:
3,789
psi
Average BH Pressure:
5,143
psi
Average Missile HHP:
2,771
hhp
Initial CA Pressure:
533
psi
Max CA Pressure:
593
psi
Max Proppant Concentration:
6.60
Ppg
Average Viso:
31
cp
Average Temp:
70.8
F
Average pH:
9.2
ISDP:
3394
psi
Final Fracture Gradient:
0.652
psi/ft
Final 5 min:
3299
psi
Final 10 min:
3289
psi
Final 15 min:
3261
psi
Proppant Summary
Wanli 16/20 Ceramic Pumped:
199,703
Ibs
100M Pumped:
6,622
Ibs
Total Proppant Pumped' :
206,325
Ibs
Proppant in Formation:
206,325
Ibs
Fluid Summary (by fluid description)
30# Hybor G Volume:
109,490
gal
2,607
bbls
30# Linear Volume:
14,384
gal
342
bbls
Seawater Volume:
0
gal
0
bbls
Freeze Protect Volume:
0
gal
0
bbls
Potassium Formate Volume:
0
gal
0
bbls
Fluid Summary (by stage description)
Pad Volume:
24,989
gal
595
bbls
Conditioning Pad Volume:
28,832
gal
686
bbls
Proppant Laden Fluid Volume:
55,669
gal
1,325
bbls
Flush Volume:
14,384
gal
342
bbls
Interval Status:
Completed
Conoco Phillips - 35-615 Interval Summary 19
for proppant are taken from software calculations based on multiple variables.
it is billed off of weight ticket volumes and may vary slightly from this number.
Treater: Greg Koester
Supervisor: Greg Koester
Customer Engineer.
Customer Rep: Greq Clavton
Conoco Phillips - 3S-615 Interval Summary 20
3S-615 - Kuparuk - Interval 6
Interval Summary
Start Date/Time:
1/9/23 14:38
End Date/Time:
1/9/23 16:27
Pump Time:
109 min
Initial Rate (Breakdown):
10.7
bpm
Initial Surface Pressure (Breakdown):
5,395
psi
Initial BH Pressure (Breakdown):
6,998
psi
Ball Seat (Early):
6
bbl
Max Rate:
32.6
bpm
Max Surface Pressure:
5,395
psi
Max BH Pressure:
7,002
psi
Average Rate:
27.1
bpm
Average Missile Pressure:
3,828
psi
Average Surface Pressure:
3,758
psi
Average BH Pressure:
5,221
psi
Average Missile HHP:
2,542
hhp
Initial CA Pressure:
368
psi
Max CA Pressure:
652
psi
Max Proppant Concentration:
7.02
PPg
Average Viso:
31
cP
Average Temp:
83.2
F
Average pH:
9
Proppant Summary
Wanli 16/20 Ceramic Pumped:
197,519
Ibs
100M Pumped:
6,448
Ibs
Total Proppant Pumped` :
203,967
Ibs
Proppant in Formation:
203,967
Ibs
Fluid Summary (by fluid description)
30# Hybor G Volume:
112,640
gal
2,682
bbls
30# Linear Volume:
3,513
gal
84
bbls
Seawater Volume:
0
gal
0
bbls
Freeze Protect Volume:
0
gal
0
bbls
Potassium Formate Volume:
0
gal
0
bbls
Fluid Summary (by stage description)
Pad Volume:
24,296
gal
578
bbls
Conditioning Pad Volume:
28,783
gal
685
bbls
Proppant Laden Fluid Volume:
50,316
gal
1,198
bbls
Establish Stable Fluid Volume:
7,788
gal
185
bbls
Spacer and Ball Drop Volume:
3,520
gal
84
bbls
Interval Status:
Completed
Waited on UPS for TCC before start treatment, pumps pre -loads issue (twice) Engineer: Pablo Hernandez
Treater: Greg Koester
Supervisor: Greg Koester
'Values for proppant are taken from software calculations based on multiple variables. Customer Engineer:
Proppant is billed off of weight ticket volumes and may vary slightly from this number. Customer Rep: Greg Clayton
Conoco Phillips - 35-615 Interval Summary 21
Start Date/Time: 119/23 16:27
End Date/Time: 1/9/23 18:22
Pump Time: 115 min
Initial Rate (Breakdown):
9.2
bpm
Initial Surface Pressure (Breakdown):
5,431
psi
Initial BH Pressure (Breakdown):
7,171
psi
Ball Seat (Early):
40
bbl
Max Rate:
30.8
bpm
Max Surface Pressure:
5,440
psi
Max BH Pressure:
7,172
psi
Average Rate:
29.4
bpm
Average Missile Pressure:
4,154
psi
Average Surface Pressure:
4,100
psi
Average BH Pressure:
5,545
psi
Average Missile HHP:
2,990
hhp
Initial CA Pressure:
631
psi
Max CA Pressure:
702
psi
Max Proppant Concentration:
7.01
Ppg
Average Viso:
30
cp
Average Temp:
82.5
F
Average pH:
9
ISDP:
3479
psi
Final Fracture Gradient:
0.667
psi/ft
Final 5 min:
3342
psi
Final 10 min:
3299
psi
Final 15 min:
3274
psi
Proppant Summary
Wanli 16/20 Ceramic Pumped:
199,980
Ibs
100M Pumped:
6,771
Ibs
Total Proppant Pumped' :
206,751
Ibs
Proppant in Formation:
206,751
Ibs
Fluid Summary (by fluid description)
30# Hybor G Volume:
105,246
gal
2,506
bbls
30# Linear Volume:
13,760
gal
328
bbls
Seawater Volume:
0
gal
0
bbls
Freeze Protect Volume:
0
gal
0
bbls
Potassium Formate Volume:
0
gal
0
bbls
Fluid Summary (by stage description)
Pad Volume:
25,078
gal
597
bbls
Conditioning Pad Volume:
28,910
gal
688
bbls
Proppant Laden Fluid Volume:
51,258
gal
1,220
bbls
Flush Volume:
13,760
gal
328
bbls
Interval Status:
Completed
Conoco Phillips - 35-615 Interval Summary 22
for proppant are taken from software calculations based on multiple variables.
it is billed off of weight ticket volumes and may vary slightly from this number.
Treater: Greg Koester
Supervisor: Greg Koester
Customer Engineer.
Customer Rep: Greq Clavton
Conoco Phillips - 3S-615 Interval Summary 23
3S-615 - Kuparuk - Interval 8
Interval Summary
Start Date/Time:
1/18/23 11:41
End Date/Time:
1/18/2313:22
Pump Time:
102 min
Initial Rate (Breakdown):
15.2
bpm
Initial Surface Pressure (Breakdown):
5,413
psi
Initial BH Pressure (Breakdown):
7,043
psi
Ball Seat (Early):
18
bbl
Max Rate:
32.0
bpm
Max Surface Pressure:
6,702
psi
Max BH Pressure:
7,051
psi
Average Rate:
28.5
bpm
Average Missile Pressure:
3,490
psi
Average Surface Pressure:
3,472
psi
Average BH Pressure:
4,852
psi
Average Missile HHP:
2,441
hhp
Initial CA Pressure:
187
psi
Max CA Pressure:
528
psi
Max Proppant Concentration:
7.70
pPg
Average Visc:
30
cp
Average Temp:
74.5
F
Average pH:
9.2
Proppant Summary
Wanli 16/20 Ceramic Pumped:
200,500
Ibs
100M Pumped:
6,440
Ibs
Total Proppant Pumped` :
206,940
Ibs
Proppant in Formation:
206,940
Ibs
Fluid Summary (by Fluid description)
30# Hybor G Volume:
110,094
gal
2,621
bbls
30# Linear Volume:
2,181
gal
52
bbls
Seawater Volume:
0
gal
0
bbls
Freeze Protect Volume:
1,470
gal
35
bbls
Potassium Formate Volume:
0
gal
0
bbls
Fluid Summary (by stage description)
Pad Volume:
24,406
gal
581
bbls
Conditioning Pad Volume:
28,776
gal
685
bbls
Proppant Laden Fluid Volume:
50,691
gal
1,207
bbls
Establish Stable Fluid Volume:
6,221
gal
148
bbls
Spacer and Ball Drop Volume:
2,181
gal
52
bbls
Interval Status: Completed
before start
for proppant are taken from software calculations based on multiple variables.
it is billed off of weight ticket volumes and may vary slightly from this number.
Treater: Greg Koester
Supervisor: Greg Koester
Customer Engineer.
Customer Rep: Greg Clayton
Conoco Phillips - 35-615 Interval Summary 24
35-615 - Kuparuk - Interval 9
Interval Summary
Start Date/Time: 1/18/23 13:22
End Date/Time: 1/18/23 14:51
Pump Time: 89 min
Initial Rate (Breakdown):
15.0
bpm
Initial Surface Pressure (Breakdown):
5,193
psi
Initial BH Pressure (Breakdown):
6,917
psi
Ball Seat (Early):
15
bbl
Max Rate:
32.1
bpm
Max Surface Pressure:
52
psi
Max BH Pressure:
6,955
psi
Average Rate:
30.1
bpm
Average Missile Pressure:
3,314
psi
Average Surface Pressure:
3,291
psi
Average BH Pressure:
4,695
psi
Average Missile HHP:
2,447
hhp
Initial CA Pressure:
511
psi
Max CA Pressure:
574
psi
Max Proppant Concentration:
7.40
Ppg
Average Viso:
30
cp
Average Temp:
71.4
F
Average pH:
9.3
Proppant Summary
Wanli 16/20 Ceramic Pumped:
196,535
/bs
100M Pumped:
7,403
/bs
Total Proppant Pumped* :
203,938
/bs
Proppant in Formation:
203,938
/bs
Fluid Summary (by fluid description)
30# Hybor G Volume:
102,756
gal
2,447
bbls
30# Linear Volume:
0
gal
0
bbls
Seawater Volume:
0
gal
0
bbls
Freeze Protect Volume:
0
gal
0
bbls
Potassium Formate Volume:
0
gal
0
bbls
Fluid Summary (by stage description)
Pad Volume:
24,199
gal
576
bbls
Conditioning Pad Volume:
27,444
gal
653
bbls
Proppant Laden Fluid Volume:
50,541
gal
1,203
bbls
Spacer and Ball Drop Volume:
572
gal
14
bbls
Interval Status: Completed
No Issues Engineer. Pablo Hernandez
Treater. Greg Koester
Supervisor: Greg Koester
*Values for proppant are taken from software calculations based on multiple variables. Customer Engineer:
Proppant is billed off of weight ticket volumes and may vary slightly from this number. Customer Rep: Greg Clayton
Conoco Phillips - 35-615 Interval Summary 25
Start Date/Time: 1/18123 14:51
End Date/Time: 1/18/23 16:24
Pump Time: 93 min
Initial Rate (Breakdown):
14.3
bpm
Initial Surface Pressure (Breakdown):
5,197
psi
Initial BH Pressure (Breakdown):
6,867
psi
Ball Seat (Early):
23
bbl
Max Rate:
31.8
bpm
Max Surface Pressure:
5,235
psi
Max BH Pressure:
6,875
psi
Average Rate:
30.6
bpm
Average Missile Pressure:
3,282
psi
Average Surface Pressure:
3,263
psi
Average BH Pressure:
4,651
psi
Average Missile HHP:
2,462
hhp
Initial CA Pressure:
553
psi
Max CA Pressure:
627
psi
Max Proppant Concentration:
7.60
Ppg
Average Viso:
29
cp
Average Temp:
71.8
F
Average pH:
9.2
ISDP:
3428
psi
Final Fracture Gradient:
0.656
psi/ft
Final 5 min:
3344
psi
Final 10 min:
3329
psi
Final 15 min:
3317
psi
Proppant Summary
Wanli 16/20 Ceramic Pumped:
191,286
Ibs
100M Pumped:
4,944
Ibs
Total Proppant Pumped' :
196,230
Ibs
Proppant in Formation:
196,230
Ibs
Fluid Summary (by fluid description)
30# Hybor G Volume:
98,421
gal
2,343
bbls
30# Linear Volume:
12,716
gal
303
bbls
Seawater Volume:
0
gal
0
bbls
Freeze Protect Volume:
0
gal
0
bbls
Potassium Formate Volume:
1,050
gal
25
bbls
Fluid Summary (by stage description)
Pad Volume:
24,277
gal
578
bbls
Conditioning Pad Volume:
24,058
gal
573
bbls
Proppant Laden Fluid Volume:
50,086
gal
1,193
bbls
Flush Volume:
12,716
gal
303
bbls
Freeze Protect Volume:
1,050
gal
25
bbls
Interval Status: Completed
Conoco Phillips - 35-615 Interval Summary 26
for proppant are taken from software calculations based on multiple variables.
it is billed off of weight ticket volumes and may vary slightly from this number.
Treater: Greg Koester
Supervisor: Greg Koester
Customer Engineer.
Customer Rep: Greq Clavton
Conoco Phillips - 3S-615 Interval Summary 27
3S-615 - Kuparuk - Interval 11
Interval Summary
Ball was not dropped for Interval 11 resulting in the stage being skipped
Engineer: Keegan Lambe
Treater Craig Karpinski
Supervisor: Michael Johnson
'Values for proppant are taken from software calculations based on multiple variables.
Customer Engineer:
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Customer Rep: Chad Burkett
Conoco Phillips - 3S-615 Interval Summary 28
35-615 - Kuparuk - Interval 12
Interval Summary
Start Date/Time:
1/26/23 11:49
End Date/Time:
1/2612314:00
Pump Time:
131 min
Initial Rate (Breakdown):
10.8
bpm
Initial Surface Pressure (Breakdown):
4,929
psi
Initial BH Pressure (Breakdown):
6,838
psi
Ball Seat (Early):
27
bbl
Max Rate:
32.6
bpm
Max Surface Pressure:
3,824
psi
Max BH Pressure:
4,965
psi
Average Rate:
30.2
bpm
Average Missile Pressure:
2,951
psi
Average Surface Pressure:
2,919
psi
Average BH Pressure:
4,324
psi
Average Missile HHP:
2,181
hhp
Initial CA Pressure:
162
psi
Max CA Pressure:
573
psi
Max Proppant Concentration:
7.57
PPg
Average Visc:
31
cp
Average Temp:
77.1
F
Average pH:
9
Proppant Summary
Wanli 16/20 Ceramic Pumped:
202,653
Ibs
100M Pumped:
6,150
Ibs
Total Proppant Pumped` :
208,803
Ibs
Proppant in Formation:
208,803
Ibs
Fluid Summary (by fluid description)
30# Hybor G Volume:
114,189
gal
2,719
bbls
30# Linear Volume:
4,388
gal
104
bbls
Seawater Volume:
0
gal
0
bbls
Freeze Protect Volume:
0
gal
0
bbls
Potassium Formate Volume:
2,100
gal
50
bbls
Fluid Summary (by stage description)
Pad Volume:
24,199
gal
576
bbls
Conditioning Pad Volume:
28,784
gal
685
bbls
Proppant Laden Fluid Volume:
50,631
gal
1,206
bbls
Establish Stable Fluid Volume:
9,220
gal
220
bbls
Spacer and Ball Drop Volume:
5,743
gal
137
bbls
DFIT Volume:
0
gal
0
bbls
Interval Status: Completed
ad opened at 11:49 to 764psi on surface. After establishing injection had issues with the
and ACE on the blender. Came offline to restart ace on the blender. Ball seat observed.
for proppant are taken from software calculations based on multiple variables.
it is billed off of weight ticket volumes and may vary slightly from this number.
Treater: Craig Karpinski
Supervisor: Michael Johnson
Customer Engineer.
Customer Rep: Chad Burkett
Conoco Phillips - 35-615 Interval Summary 29
35-675 - Kuparuk - Interval 73
Interval Summary
Start Date/Time: 1/26/23 14:00
End Date/Time: 1/26/23 15:33
Pump Time: 93 min
Initial Rate (Breakdown):
10.0
bpm
Initial Surface Pressure (Breakdown):
4,995
psi
Initial BH Pressure (Breakdown):
6,892
psi
Ball Seat (Early):
28
bbl
Max Rate:
32.1
bpm
Max Surface Pressure:
3,667
psi
Max BH Pressure:
4,760
psi
Average Rate:
29.3
bpm
Average Missile Pressure:
2,703
psi
Average Surface Pressure:
2,663
psi
Average BH Pressure:
4,121
psi
Average Missile HHP:
1,939
hhp
Initial CA Pressure:
573
psi
Max CA Pressure:
663
psi
Max Proppant Concentration:
7.76
Ppg
Average Viso:
29
cp
Average Temp:
78.5
F
Average pH:
8.9
Proppant Summary
Wanli 16/20 Ceramic Pumped:
203,292
/bs
100M Pumped:
0
/bs
Total Proppant Pumped* :
203,292
/bs
Proppant in Formation:
203,292
/bs
Fluid Summary (by fluid description)
30# Hybor G Volume:
105,123
gal
2,503
bbls
30# Linear Volume:
0
gal
0
bbls
Seawater Volume:
0
gal
0
bbls
Freeze Protect Volume:
0
gal
0
bbls
Potassium Formate Volume:
0
gal
0
bbls
Fluid Summary (by stage description)
Pad Volume:
24,963
gal
594
bbls
Conditioning Pad Volume:
28,763
gal
685
bbls
Proppant Laden Fluid Volume:
50,167
gal
1,194
bbls
Spacer and Ball Drop Volume:
1,230
gal
29
bbls
Interval Status: Completed
Ban Seat observed. Alter attempting to load the loom, very little came out of the castle. Switched
Engineer. Keegan Lambe
up to 16/20 in place of the 100M. Blender suction struggled during the interval.
Treater. Craig Karpinski
Supervisor: Michael Johnson
*Values for proppant are taken from software calculations based on multiple variables.
Customer Engineer:
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Customer Rep: Chad Burkett
Conoco Phillips - 35-615 Interval Summary 30
Start Date/Time: 1/26123 15:33
End Date/Time: 1/26/23 17:06
Pump Time: 93 min
Initial Rate (Breakdown):
9.9
bpm
Initial Surface Pressure (Breakdown):
5,044
psi
Initial BH Pressure (Breakdown):
6,621
psi
Ball Seat (Early):
31
bbl
Max Rate:
31.6
bpm
Max Surface Pressure:
2,880
psi
Max BH Pressure:
4,445
psi
Average Rate:
29.6
bpm
Average Missile Pressure:
2,577
psi
Average Surface Pressure:
2,553
psi
Average BH Pressure:
4,008
psi
Average Missile HHP:
1,868
hhp
Initial CA Pressure:
638
psi
Max CA Pressure:
719
psi
Max Proppant Concentration:
7.58
Ppg
Average Viso:
29
cp
Average Temp:
79.3
F
Average pH:
9
ISDP:
3218
psi
Final Fracture Gradient:
0.614
psi/ft
Final 5 min:
3144
psi
Final 10 min:
3133
psi
Final 15 min:
3124
psi
Proppant Summary
Wanli 16/20 Ceramic Pumped:
201,030
Ibs
100M Pumped:
0
Ibs
Total Proppant Pumped' :
201,030
Ibs
Proppant in Formation:
201,030
Ibs
Fluid Summary (by fluid description)
30# Hybor G Volume:
103,987
gal
2,476
bbls
30# Linear Volume:
11,720
gal
279
bbls
Seawater Volume:
0
gal
0
bbls
Freeze Protect Volume:
0
gal
0
bbls
Potassium Formate Volume:
0
gal
0
bbls
Fluid Summary (by stage description)
Pad Volume:
24,212
gal
576
bbls
Conditioning Pad Volume:
28,769
gal
685
bbls
Proppant Laden Fluid Volume:
51,006
gal
1,214
bbls
Flush Volume:
11,720
gal
279
bbls
Interval Status:
Completed
Conoco Phillips - 35-615 Interval Summary 31
hit observed.
for proppant are taken from software calculations based on multiple variables.
it is billed off of weight ticket volumes and may vary slightly from this number.
Treater: Craig Karpinski
Supervisor: Michael Johnson
Customer Engineer.
Customer Rep: Chad Burkett
Conoco Phillips - 3S-615 Interval Summary 32
3S-615 - Kuparuk - Interval 15
Interval Summary
Start Daterl ime: 1/28/23 11:29
End Daterl ime: 1/28/23 13:29
Pump Time: 120 min
Initial Rate (Breakdown):
9.2
bpm
Initial Surface Pressure (Breakdown):
4,470
psi
Initial BH Pressure (Breakdown):
6,460
psi
Ball Seat (Early):
31
bbl
Max Rate:
33.3
bpm
Max Surface Pressure:
3,139
psi
Max BH Pressure:
4,434
psi
Average Rate:
29.4
bpm
Average Missile Pressure:
2,443
psi
Average Surface Pressure:
2,446
psi
Average BH Pressure:
3,888
psi
Average Missile HHP:
1,762
hhp
Initial CA Pressure:
373
psi
Max CA Pressure:
624
psi
Max Proppant Concentration:
7.29
PPg
Average Viso:
29
cP
Average Temp:
76
F
Average pH:
9.1
Proppant Summary
Wanli 16/20 Ceramic Pumped:
196,477
Ibs
100M Pumped:
0
Ibs
Total Proppant Pumped* :
196,477
Ibs
Proppant in Formation:
196,477
Ibs
Fluid Summary (by fluid description)
30# Hybor G Volume:
114,777
gal
2,733
bbls
30# Linear Volume:
1,723
gal
41
bbls
Seawater Volume:
0
gal
0
bbls
Freeze Protect Volume:
0
gal
0
bbls
Potassium Formate Volume:
1,302
gal
31
bbls
Fluid Summary (by stage description)
Pad Volume:
24,206
gal
576
bbls
Conditioning Pad Volume:
28,767
gal
685
bbls
Proppant Laden Fluid Volume:
42,650
gal
1,015
bbls
Establish Stable Fluid Volume:
17,578
gal
419
bbls
Spacer and Ball Drop Volume:
3,299
gal
79
bbls
Interval Status:
Completed
Wellhead opened at 11:29 and 887psi. 100M was replaced by 16/20 due to lack of 100M on
Engineer: Keegan Lambe
available. Ball seat observed.
Treater. Craig Karpinski
Supervisor: Michael Johnson
*Values for proppant are taken from software calculations based on multiple variables.
Customer Engineer:
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Customer Rep: Chad Burkett
Conoco Phillips - 35-615 Interval Summary 33
35-615 - Kuparuk - Interval 16
Interval Summary
Start Daterrime:
1/28123 13:29
End Daterrime:
1/28123 15:00
Pump Time:
91 min
Initial Rate (Breakdown):
10.1
bpm
Initial Surface Pressure (Breakdown):
4,785
psi
Initial BH Pressure (Breakdown):
6,477
psi
Ball Seat (Early):
31
bbl
Max Rate:
33.2
bpm
Max Surface Pressure:
2,863
psi
Max BH Pressure:
4,138
psi
Average Rate:
30.1
bpm
Average Missile Pressure:
2,444
psi
Average Surface Pressure:
2,430
psi
Average BH Pressure:
3,862
psi
Average Missile HHP:
1,805
hhp
Initial CA Pressure:
624
psi
Max CA Pressure:
735
psi
Max Proppant Concentration:
7.60
Ppg
Average Visc:
29
cP
Average Temp:
89
F
Average pH:
9
ISDP:
3390
psi
Final Fracture Gradient:
0.646
psi/ft
Final 5 min:
3156
psi
Final 10 min:
3143
psi
Final 15 min:
3136
psi
Proppant Summary
Wanli 16/20 Ceramic Pumped:
203,209
Ibs
100M Pumped:
0
Ibs
Total Proppant Pumped` :
203,209
Ibs
Proppant in Formation:
203,209
Ibs
Fluid Summary (by fluid description)
30# Hybor G Volume:
114,559
gal
2,728
bbls
30# Linear Volume:
0
gal
0
bbls
Seawater Volume:
0
gal
0
bbls
Freeze Protect Volume:
0
gal
0
bbls
Potassium Formate Volume:
0
gal
0
bbls
Fluid Summary (by stage description)
Pad Volume:
24,216
gal
577
bbls
Conditioning Pad Volume:
28,808
gal
686
bbls
Proppant Laden Fluid Volume:
50,351
gal
1,199
bbls
Flush Volume:
11,184
gal
266
bbls
Interval Status: Completed
Conoco Phillips - 35-615 Interval Summary 34
for proppant are taken from software calculations based on multiple variables.
it is billed off of weight ticket volumes and may vary slightly from this number.
Treater: Craig Karpinski
Supervisor: Michael Johnson
Customer Engineer.
Customer Rep: Chad Burkett
Conoco Phillips - 3S-615 Interval Summary 35
35-615 - Kuparuk - Interval 17
Interval Summary
Start Date/Time:
1/29/23 10:14
End Date/Time:
1/2912312:09
Pump Time:
115 min
Initial Rate (Breakdown):
10.1
bpm
Initial Surface Pressure (Breakdown):
4,916
psi
Initial BH Pressure (Breakdown):
6,372
psi
Ball Seat (Early):
28
bbl
Max Rate:
30.4
bpm
Max Surface Pressure:
3,074
psi
Max BH Pressure:
4,574
psi
Average Rate:
29.3
bpm
Average Missile Pressure:
2,691
psi
Average Surface Pressure:
2,692
psi
Average BH Pressure:
4,144
psi
Average Missile HHP:
1,931
hhp
Initial CA Pressure:
393
psi
Max CA Pressure:
721
psi
Max Proppant Concentration:
7.06
PPg
Average Visc:
29
cP
Average Temp:
87
F
Average pH:
8.9
Proppant Summary
Wanli 16/20 Ceramic Pumped:
200,687
Ibs
100M Pumped:
0
Ibs
Total Proppant Pumped` :
200,687
Ibs
Proppant in Formation:
200,687
Ibs
Fluid Summary (by fluid description)
30# Hybor G Volume:
108,696
gal
2,588
bbls
30# Linear Volume:
1,476
gal
35
bbls
Seawater Volume:
0
gal
0
bbls
Freeze Protect Volume:
756
gal
18
bbls
Potassium Formate Volume:
0
gal
0
bbls
Fluid Summary (by stage description)
Pad Volume:
24,223
gal
577
bbls
Conditioning Pad Volume:
28,784
gal
685
bbls
Proppant Laden Fluid Volume:
49,527
gal
1,179
bbls
Establish Stable Fluid Volume:
4,611
gal
110
bbls
Spacer and Ball Drop Volume:
3,027
gal
72
bbls
Interval Status:
Completed
Well opened at 794psi. Ball hit observed. Interval pumped to design. Pumped 16/20 in place of
Engineer: Keegan Lambe
loom.
Treater: Craig Karpinski
Supervisor: Michael Johnson
'Values for proppant are taken from software calculations based on multiple variables.
Customer Engineer:
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Customer Rep: Chad Burkett
Conoco Phillips - 35-615 Interval Summary 36
35-675 - Kuparuk - Interval 18
Interval Summary
Start Date/Time: 1/29/23 12:09
End Date/Time: 1/29/23 13:53
Pump Time: 104 min
Initial Rate (Breakdown):
10.1
bpm
Initial Surface Pressure (Breakdown):
5,351
psi
Initial BH Pressure (Breakdown):
6,948
psi
Ball Seat (Early):
30
bbl
Max Rate:
31.0
bpm
Max Surface Pressure:
2,793
psi
Max BH Pressure:
4,004
psi
Average Rate:
25.9
bpm
Average Missile Pressure:
2,194
psi
Average Surface Pressure:
2,193
psi
Average BH Pressure:
3,706
psi
Average Missile HHP:
1,392
hhp
Initial CA Pressure:
723
psi
Max CA Pressure:
723
psi
Max Proppant Concentration:
7.63
Ppg
Average Viso:
28
cp
Average Temp:
87
F
Average pH:
8.8
Proppant Summary
Wanli 16/20 Ceramic Pumped:
202,142
/bs
100M Pumped:
0
/bs
Total Proppant Pumped* :
202,142
/bs
Proppant in Formation:
202,142
/bs
Fluid Summary (by fluid description)
30# Hybor G Volume:
103,016
gal
2,453
bbls
30# Linear Volume:
0
gal
0
bbls
Seawater Volume:
0
gal
0
bbls
Freeze Protect Volume:
0
gal
0
bbls
Potassium Formate Volume:
0
gal
0
bbls
Fluid Summary (by stage description)
Pad Volume:
22,299
gal
531
bbls
Conditioning Pad Volume:
28,793
gal
686
bbls
Proppant Laden Fluid Volume:
50,215
gal
1,196
bbls
Spacer and Ball Drop Volume:
1,709
gal
41
bbls
Interval Status: Completed
Ball hit observed. Pumped 16120 In place of the 100M Engineer Keegan Lambe
Treater. Craig Karpinski
Supervisor: Michael Johnson
*Values for proppant are taken from software calculations based on multiple variables. Customer Engineer:
Proppant is billed off of weight ticket volumes and may vary slightly from this number. Customer Rep: Chad Burkett
Conoco Phillips - 35-615 Interval Summary 37
Start Date/Time: 1/29/23 13:53
End Date/Time: 1/29/23 16:31
Pump Time: 158 min
Initial Rate (Breakdown):
15.6
bpm
Initial Surface Pressure (Breakdown):
5,084
psi
Initial BH Pressure (Breakdown):
6,588
psi
Ball Seat (Early):
29
bbl
Max Rate:
31.2
bpm
Max Surface Pressure:
2,778
psi
Max BH Pressure:
4,035
psi
Average Rate:
28.9
bpm
Average Missile Pressure:
2,157
psi
Average Surface Pressure:
2,170
psi
Average BH Pressure:
3,618
psi
Average Missile HHP:
1,526
hhp
Initial CA Pressure:
700
psi
Max CA Pressure:
700
psi
Max Proppant Concentration:
7.60
Ppg
Average Viso:
29
cP
Average Temp:
87.6
F
Average pH:
9
ISDP:
3207
psi
Final Fracture Gradient:
0.610
psi/ft
Final 5 min:
3072
psi
Final 10 min:
3082
psi
Final 15 min:
3086
psi
Proppant Summary
Wanli 16/20 Ceramic Pumped:
206,465
Ibs
100M Pumped:
0
Ibs
Total Proppant Pumped* :
206,465
Ibs
Proppant in Formation:
206,465
Ibs
Fluid Summary (by fluid description)
30# Hybor G Volume:
102,173
gal
2,433
bbls
30# Linear Volume:
25,653
gal
611
bbls
Seawater Volume:
0
gal
0
bbls
Freeze Protect Volume:
0
gal
0
bbls
Potassium Formate Volume:
0
gal
0
bbls
Fluid Summary (by stage description)
Pad Volume:
22,126
gal
527
bbls
Conditioning Pad Volume:
28,764
gal
685
bbls
Proppant Laden Fluid Volume:
51,283
gal
1,221
bbls
Displacement Volume:
15,326
gal
365
bbls
Flush Volume:
10,327
gal
246
bbls
Interval Status: Completed
Conoco Phillips-35-615
Interval Summary
38
After dropping the ball for interval 18, a leak on the blender discharge occurred. Isolation was shut,
Engineer: Keegan Lambe
which resulted in loss of rate. After hoses were swapped rate was stepped back to displace
Treater Craig Karpinski
proppant in wellbore along with the ball. After resuming interval pumped to design.
Supervisor: Michael Johnson
'Values for proppant are taken from software calculations based on multiple variables.
Customer Engineer:
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Customer Rep: Chad Burkett
Conoco Phillips - 3S-615 Interval Summary 39
3S-615 - Kuparuk - Interval 20
Interval Summary
Start Date/Time:
1/31/23 11:43
End Date/Time:
1/31/2316:23
Pump Time:
280 min
Initial Rate (Breakdown):
10.5
bpm
Initial Surface Pressure (Breakdown):
4,851
psi
Initial BH Pressure (Breakdown):
6,588
psi
Ball Seat (Early):
26
bbl
Max Rate:
32.6
bpm
Max Surface Pressure:
3,028
psi
Max BH Pressure:
3,994
psi
Average Rate:
31.0
bpm
Average Missile Pressure:
2,322
psi
Average Surface Pressure:
2,319
psi
Average BH Pressure:
3,660
psi
Average Missile HHP:
1,765
hhp
Initial CA Pressure:
251
psi
Max CA Pressure:
593
psi
Max Proppant Concentration:
9.19
PPg
Average Viso:
32
cP
Average Temp:
85.9
F
Average pH:
8.8
Proppant Summary
Wanli 16/20 Ceramic Pumped:
210,380
Ibs
100M Pumped:
0
Ibs
Total Proppant Pumped` :
210,380
Ibs
Proppant in Formation:
210,380
Ibs
Fluid Summary (by fluid description)
30# Hybor G Volume:
105,884
gal
2,521
bbls
30# Linear Volume:
13,011
gal
310
bbls
Seawater Volume:
0
gal
0
bbls
Freeze Protect Volume:
0
gal
0
bbls
Potassium Formate Volume:
1,680
gal
40
bbls
Fluid Summary (by stage description)
Pad Volume:
21,381
gal
509
bbls
Conditioning Pad Volume:
28,949
gal
689
bbls
Proppant Laden Fluid Volume:
48,621
gal
1,158
bbls
Establish Stable Fluid Volume:
5,457
gal
130
bbls
Spacer and Ball Drop Volume:
14,487
gal
345
bbls
Interval Status: Completed
Wellhead opened at 11:43 to 659psi. After establishing injection there were issues with the
Engineer: Keegan Lambe
blender and ADP suction. After resolving the issue an issue with the CI-28M transfer pump was
Treater: Greg Koester
found. Once resolved, interval proppant pumped to design. The blender densometer tracked
proppant runninq at hiqher concentrations than tarqeted desiqn.
Supervisor: Greg Koester
'Values for proppant are taken from software calculations based on multiple variables.
Customer Engineer:
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Customer Rep: Chad Burkett
Conoco Phillips - 3S-615 Interval Summary 40
Start Date/Time. 1/31/2316:23
End Dateffime. 1/31/2317:44
Pump Time: 81 min
Initial Rate (Breakdown):
10.4
bpm
Initial Surface Pressure (Breakdown):
4,935
psi
Initial BH Pressure (Breakdown):
6,420
psi
Ball Seat (Early):
23
bbl
Max Rate:
32.6
bpm
Max Surface Pressure:
2,948
psi
Max BH Pressure:
4,075
psi
Average Rate:
31.3
bpm
Average Missile Pressure:
2,323
psi
Average Surface Pressure:
2,330
psi
Average BH Pressure:
3,696
psi
Average Missile HHP:
1,780
hhp
Initial CA Pressure:
593
psi
Max CA Pressure:
718
psi
Max Proppant Concentration:
7.44
ppg
Average Viso:
32
cP
Average Temp:
92.5
F
Average pH:
8.8
Proppant Summary
Wanli 16/20 Ceramic Pumped:
208,214
Ibs
100M Pumped:
0
Ibs
Total Proppant Pumped' :
208,214
Ibs
Proppant in Formation:
208,214
Ibs
Fluid Summary (by fluid description)
30# Hybor G Volume:
105,091
gal
2,502
bbls
30# Linear Volume:
0
gal
0
bbls
Seawater Volume:
0
gal
0
bbls
Freeze Protect Volume:
0
gal
0
bbls
Potassium Formate Volume:
0
gal
0
bbls
Fluid Summary (by stage description)
Pad Volume:
21,258
gal
506
bbls
Conditioning Pad Volume:
28,839
gal
687
bbls
Proppant Laden Fluid Volume:
53,298
gal
1,269
bbls
Spacer and Ball Drop Volume:
1,696
gal
40
bbls
Interval Status:
Completed
Conoco Phillips - 35-615 Interval Summary 41
hit observed.
for proppant are taken from software calculations based on multiple variables.
it is billed off of weight ticket volumes and may vary slightly from this number.
Treater: Greg Koester
Supervisor: Greg Koester
Customer Engineer.
Customer Rep: Chad Burkett
Conoco Phillips - 3S-615 Interval Summary 42
Start Date/Time: 1/31/23 17:44
End Date/Time: 2/1/23 16:02
Pump Time: NA min
Initial Rate (Breakdown):
10.5
bpm
Initial Surface Pressure (Breakdown):
4,753
psi
Initial BH Pressure (Breakdown):
6,673
psi
Ball Seat (Early):
21
bbl
Max Rate:
32.2
bpm
Max Surface Pressure:
2,711
psi
Max BH Pressure:
3,736
psi
Average Rate:
31.0
bpm
Average Missile Pressure:
2,195
psi
Average Surface Pressure:
2,188
psi
Average BH Pressure:
3,535
psi
Average Missile HHP:
1,667
hhp
Initial CA Pressure:
462
psi
Max CA Pressure:
650
psi
Max Proppant Concentration:
8.13
Ppg
Average Viso:
28
cp
Average Temp:
86
F
Average pH:
9.1
Proppant Summary
Wanli 16/20 Ceramic Pumped:
203,930
Ibs
100M Pumped:
0
Ibs
Total Proppant Pumped' :
203,930
Ibs
Proppant in Formation:
203,930
Ibs
Fluid Summary (by fluid description)
30# Hybor G Volume:
112,965
gal
2,690
bbls
30# Linear Volume:
5,195
gal
124
bbls
Seawater Volume:
0
gal
0
bbls
Freeze Protect Volume:
1,470
gal
35
bbls
Potassium Formate Volume:
1,575
gal
38
bbls
Fluid Summary (by stage description)
Pad Volume:
31,898
gal
759
bb/s
Conditioning Pad Volume:
28,819
gal
686
bbls
Proppant Laden Fluid Volume:
49,577
gal
1,180
bbls
Freeze Protect Volume:
1,470
gal
35
bbls
Establish Stable Fluid Volume:
2,671
gal
64
bbls
Spacer and Ball Drop Volume:
5,195
gal
124
bbls
Interval Status:
Completed
Conoco Phillips - 35-615 Interval Summary 43
Ball seat observed on 1/31. While pumping pad volume on 1131 a chikson on the main treating
Engineer: Keegan Lambe
line started to leak. Shut down at 17:55 on 1/31 to replace the chickson. Freeze protected well and
Treater: Nathan Brzezinski
shut down for night. Reopened the well at 14:11 to resume the frac. Dropped the backup ball. Ball
launched at 14:20 and 68bbl isv. Displaced the ball at 15bpm. No secondary ball observed.
Supervisor: Greg Koester
'Values for proppant are taken from software calculations based on multiple variables.
Customer Engineer:
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Customer Rep: Chad Burkett
Conoco Phillips - 3S-615 Interval Summary 44
Start Date/Time: 2/1/23 16:02
End Date/Time: 2/1/23 17:27
Pump Time: 85 min
Initial Rate (Breakdown):
11.9
bpm
Initial Surface Pressure (Breakdown):
5,063
psi
Initial BH Pressure (Breakdown):
6,541
psi
Ball Seat (Early):
24
bbl
Max Rate:
32.3
bpm
Max Surface Pressure:
2,424
psi
Max BH Pressure:
3,653
psi
Average Rate:
31.4
bpm
Average Missile Pressure:
2,115
psi
Average Surface Pressure:
2,103
psi
Average BH Pressure:
3,441
psi
Average Missile HHP:
1,626
hhp
Initial CA Pressure:
650
psi
Max CA Pressure:
717
psi
Max Proppant Concentration:
8.20
PPg
Average Viso:
31
cP
Average Temp:
100
F
Average pH:
9
ISDP:
3224
psi
Final Fracture Gradient:
0.613
psi/ft
Final 5 min:
3137
psi
Final 10 min:
3116
psi
Final 15 min:
3098
psi
Proppant Summary
Wanli 16/20 Ceramic Pumped:
206,512
Ibs
100M Pumped:
0
Ibs
Total Proppant Pumped' :
206,512
Ibs
Proppant in Formation:
206,512
Ibs
Fluid Summary (by fluid description)
30# Hybor G Volume:
100,278
gal
2,388
bbls
30# Linear Volume:
9,012
gal
215
bbls
Seawater Volume:
0
gal
0
bbls
Freeze Protect Volume:
0
gal
0
bbls
Potassium Formate Volume:
0
gal
0
bbls
Fluid Summary (by stage description)
Pad Volume:
21,538
gal
513
bbls
Conditioning Pad Volume:
28,823
gal
686
bbls
Proppant Laden Fluid Volume:
49,917
gal
1,189
bbls
Flush Volume:
9,012
gal
215
bbls
Interval Status: Completed
Conoco Phillips - 35-615 Interval Summary 45
hit
for proppant are taken from software calculations based on multiple variables.
it is billed off of weight ticket volumes and may vary slightly from this number.
Treater: Nathan Brzezinski
Supervisor: Greg Koester
Customer Engineer.
Customer Rep: Chad Burkett
Conoco Phillips - 3S-615 Interval Summary 46
35-615 - Kuparuk - Interval 24
Interval Summary
Start Date/Time: 2/2/23 11:26
End Date/Time: 2/2/23 13:14
Pump Time: 108 min
Initial Rate (Breakdown):
10.4
bpm
Initial Surface Pressure (Breakdown):
4,873
psi
Initial BH Pressure (Breakdown):
6,032
psi
Ball Seat (Early):
19
bbl
Max Rate:
32.4
bpm
Max Surface Pressure:
2,797
psi
Max BH Pressure:
3,723
psi
Average Rate:
31.1
bpm
Average Missile Pressure:
2,072
psi
Average Surface Pressure:
2,082
psi
Average BH Pressure:
3,355
psi
Average Missile HHP:
1,581
hhp
Initial CA Pressure:
227
psi
Max CA Pressure:
581
psi
Max Proppant Concentration:
8.10
Ppg
Average Viso:
28
cP
Average Temp:
88.3
F
Average pH:
9.1
ISDP:
3238
psi
Final Fracture Gradient:
0.622
psi/ft
Final 5 min:
3136
psi
Final 10 min:
3132
psi
Final 15 min:
3122
psi
Proppant Summary
Wanli 16/20 Ceramic Pumped:
206,404
Ibs
100M Pumped:
0
Ibs
Total Proppant Pumped* :
206,404
Ibs
Proppant in Formation:
206,404
Ibs
Fluid Summary (by fluid description)
30# Hybor G Volume:
106,093
gal
30# Linear Volume:
11,787
gal
Seawater Volume:
0
gal
Freeze Protect Volume:
0
gal
Potassium Formate Volume:
1,260
gal
2,526 bbls
281 bbls
0 bbls
0 bbls
30 bbls
Fluid Summary (by stage description)
Pad Volume:
21,337
gal
508
bbls
Conditioning Pad Volume:
28,849
gal
687
bbls
Proppant Laden Fluid Volume:
50,214
gal
1,196
bbls
Flush Volume:
8,491
gal
202
bbls
Establish Stable Fluid Volume:
5,693
gal
136
bbls
Spacer and Ball Drop Volume:
3,296
gal
78
bbls
DFIT Volume:
0
gal
0
bbls
Interval Status: Completed
Conoco Phillips - 35-615 Interval Summary 47
for proppant are taken from software calculations based on multiple variables.
it is billed off of weight ticket volumes and may vary slightly from this number.
tngmeer. Keegan Lambe
Treater. Nathan Brzezinski
Supervisor: Greg Koester
Customer Engineer.
Customer Rep: Chad Burkett
Conoco Phillips - 3S-615 Interval Summary 48
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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: 24.7 BF:
Total Depth: 682' FNL, 3009 FEL, Sec 2, T12N, R7E 10. Plug Back Depth MD/TVD: 18. Property Designation:
4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number:
Surface: x- y- Zone- 4
TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD:
Total Depth: x- y- Zone- 4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 N/A (ft MSL)
22. Logs Obtained:
23.
BOTTOM
20" H-160 114'
10 3/4" L-80 2,543'
7 5/8" L-80 5,130'
7 5/8" P110S 5,030'
4 1/2" L-80 5,201
24. Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr):
Press. 24-Hour Rate
Sr Res EngSr Pet GeoSr Pet Eng
N/A
Oil-Bbl: Water-Bbl:
11,270'MD/4,990' TVD
11,531'MD/5,075' TVD
GR, RES, PWD, DIR, AZI, DEN, NEU, CALIPER, POR, SONIC
Water-Bbl:
PRODUCTION TEST
N/A
Date of Test: Oil-Bbl:
33.7 12,342'
Flow Tubing
Liner @ 11,531'MD/5,074'TVD to 23,756'MD/5,201'TVD
Gas-Oil Ratio:Choke Size:
Per 20 AAC 25.283 (i)(2) attach electronic information
29.7
23,756'
40'
5,074'
120
45.5
114'
40' 11,706'
SIZE DEPTH SET (MD) PACKER SET (MD/TVD)
42"
13.5"
10 yards
40'Lead: 396 bbls of 10.7 ppg
Arctic
Tail: 58 bbls of 15.8ppg Class G
12.6
12,842' 5,025'
5994699
1,631'MD/1,572'TVD
SETTING DEPTH TVD
6006340
TOP HOLE SIZE AMOUNT
PULLED
467144
464211
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
50-103-20844-00-00
KRU 3S-615
ADL 380107, ADL 025544. ADL 025528
LONS 01-01103
10/29/2022
23,770' MD/5,201'TVD
N/A
60.8
P.O. Box 100360 Anchorage, AK 99510-0360
476174 5993893
1751 FNL, 33FEL, Sec 14, T12N, R7E
12/5/20222523' FNL, 1086' FEL, Sec 18, T12N, R8E
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
ConocoPhillips Alaska, Inc.
WAG
Gas
12/17/2022 222-101
40'
11,531'
3,069'
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date perf'd or liner run):
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
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,
6.5"
TUBING RECORD
233 bbls of 15.3 ppg Class G
277 Sacks 15.8 Class G
9.875"
11,537'4.5"
CASING WT. PER
FT.GRADE CEMENTING RECORD
40'
40'
9.875"
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
By James Brooks at 9:05 am, Jan 17, 2023
Completed
12/17/2022
JSB
RBDMS JSB 012523
GDSR-2/1/23
Conventional Core(s): Yes No Sidewall Cores:
N/A
30.
MD TVD
Surface Surface
1631 1572
1697 1628
1853 1758
2193 2017
C-80 3205 2601
5565 3325
8324 4112
Torok Shales 9157 4348
Top of Productive Interval 11740 5141
(Torok):
Formation at total depth 23770 5201
(TD): Torok
31. List of Attachments:
Cement Report, Directional Survey, Well Schematic, Operations Summary
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Abby Warren
Contact Email:abby.warren@conocophillips.com
Authorized Contact Phone:907-240-9293
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:
Coyote/K3
The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram
with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical
reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted.
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis,
paleontological report, production or well test results, per 20 AAC 25.070.
Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
TPI (Top of Producing Interval).
Signature w/Date:
Abby Warren
Drilling Engineer
Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
FORMATION TESTS
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment, whichever occurs first.
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
C-50
Ugnu A
INSTRUCTIONS
Authorized Name:
Ugnu B
Authorized Title:
West Sak
If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form,
if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071.
Yes No
Well tested? Yes No
28. CORE DATA
If yes, list intervals and formations tested, briefly summarizing test results. Attach
separate pages to this form, if needed, and submit detailed test information,
including reports, per 20 AAC 25.071.
NAME
Permafrost - Top
Permafrost - Base
29. GEOLOGIC MARKERS (List all formations and markers encountered):
Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment
/Moraine
Top Coyote@ 8,325' MD / 4,113' TVD
3S-615 Wellbore Schematic
Grassroots Horizontal Moraine Producer
Surface Casing: 10-¾" 45.5#, L-80, Hydril 563 @
3,069’ MD / 2,543' TVD, 63° INC
Conductor: 20" driven to +/-119'
Production Liner: 4-½" 12.6#, L-80, Hydril 563
@ 23,756' MD / 5,201' 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 @ 11,707'
MD / 5,130' TVD, 72° Inc
Updated: 12/18/2022
by K. Herring
4-½” x 6" OD Swell Packer Frac sleeve (ball drop)
LS
N
D
Sp
u
d
M
u
d
3.562" DB Landing Nipple @ 11,345' MD
5-½” x 7-5/8" ZXP Packer @ 11,531' MD
5-½” x 7-5/8" Flexlock Hanger @ 11,553' MD
4-½” x 7-з" Halliburton TNT @ 11,270' MD
TOC 5,620' / 3,340' TVD
(773' TVD above hydrocarbon bearing zone)
Downhole Gauge @ 10,085' MD
TOC @ Surface
As Drilled
Top Torok Oil Pool (Moraine) @ 11,740' MD / 5141' TVD
Rigless ESP (wireline retrievable pump/motor) @ 10,225' MD
Sliding sleeve w/3.813" X profile @ 10458' MD
Gas Lift Mandrel, 4-½” x 1-½” @ 6,417' MD
Gas Lift Mandrel, 4-½” x 1-½” @ 2,951' MD
WIV/Alpha Sleeve
Page 1/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/27/2022
00:00
10/27/2022
05:00
5.00 MIRU, MOVE RURD P Clean cellar box and tree. Remove
annular adapters, tighten tree cap
adapter. R/D pits interconnects, secure
pipe shed tools, prepare pad and mats
for move.
0.0 0.0
10/27/2022
05:00
10/27/2022
10:00
5.00 MIRU, MOVE RURD P Blow down steam and water lines.
Disconnect electrical plugs for pits, sub
and top drive. Pull pipe shed out of way.
Prepare to move pits and motor
complexes. Swab sub to generator
power. Back up pits and motor
complexes. Skid rig floor to move
position.
0.0 0.0
10/27/2022
10:00
10/27/2022
12:00
2.00 MIRU, MOVE MOB P Pull off well with sub and crab over to
mats at 615 well.
0.0 0.0
10/27/2022
12:00
10/27/2022
15:30
3.50 MIRU, MOVE MOB P Align sub to spot over 3S-615 well.
Remove lower rear drillers side wind
wall from cellar, spot rig over
well.Shimmed sub to plum and level.
Lower stompers and set pressures.
Lower rear cellar wind walls. Continue
setting mat layout for pits and motor
complexes.
0.0 0.0
10/27/2022
15:30
10/27/2022
16:30
1.00 MIRU, MOVE MOB P Skid rig floor to drilling position while
preparing pit and motor complex's to
spot onto sub.
0.0 0.0
10/27/2022
16:30
10/28/2022
00:00
7.50 MIRU, MOVE MOB P Move and position pits and motor
complexes to sub for drilling position.
Shim pits as required. Connect all
service lines for pits to sub. Connect all
services lines for sub to rig floor. Spot
MPD connex and herculite and berm
around connex. Spot pipe shed to sub.
Connect electrical lines to top drive,
VFD, SCR's to pits tie in's. Spot
rockwasher and pipe shed heater. Lay
out rig mats for cuttings tank and
Magtec equipment. Install drilling bails
on top drive and 5" elevators. Working
on acceptance check list.
0.0 0.0
10/28/2022
00:00
10/28/2022
08:00
8.00 MIRU, MOVE RURD P Continue working on rig acceptance
checklist. Install herculite wind wall in
cellar on drillers side. Plug hole is cellar
walls. Install cellar pump, welding in pits
and product line in pump room.
113.8 113.8
10/28/2022
08:00
10/28/2022
12:00
4.00 MIRU, MOVE RURD P Rig accepted at 08:00 hrs. Take on 9.0
ppg spud mud to pits. N/U riser and flow
line. Install turn buckles on riser. P/U lift
subs and stab's to floor. Cameron tech
tested wellhead seals to 500 psi for 30
minutes - good test and set wellhead
slips.
113.8 113.8
10/28/2022
12:00
10/28/2022
18:00
6.00 MIRU, MOVE RURD P Continue N/U riser. Stage BHA on rig
floor, load 66 joints 5" drill pipe and 17
joints 5" HWDP to shed.
113.8 113.8
10/28/2022
18:00
10/28/2022
20:00
2.00 MIRU, MOVE RURD P Strap and tally 5" drill pipe and 5"
HWDP in pipe shed.
113.8 113.8
10/28/2022
20:00
10/29/2022
00:00
4.00 MIRU, MOVE PULD P PJSM. Pick up and stand back 22
stands of 5" drill pipe. Drift to 2.5".
113.8 113.8
10/29/2022
00:00
10/29/2022
02:30
2.50 MIRU, MOVE PULD P Pick up and stand back 6 stands 5"
HWDP + Jars.
113.0 113.0
10/29/2022
02:30
10/29/2022
04:15
1.75 MIRU, MOVE BHAH P P/U 13-1/2" clean out BHA. TIH tag ice
at 68'.
113.0 113.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 2/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/29/2022
04:15
10/29/2022
04:30
0.25 MIRU, MOVE SFTY P Pre-spud meeting with rig crew. 113.0 113.0
10/29/2022
04:30
10/29/2022
04:45
0.25 MIRU, MOVE PRTS P Fill conductor with 8.8 ppg spud mud
and confirm no leaks. Pressure test
surface lines to 4,000 psi.
113.0 113.0
10/29/2022
04:45
10/29/2022
05:30
0.75 SURFAC, DRILL REAM P Clean out conductor F/68' to 113' at
shoe.
350 GPM
380 PSI
30 RPM
2K TQ
113.0 113.0
10/29/2022
05:30
10/29/2022
06:30
1.00 SURFAC, DRILL DDRL P Drill 13-1/2" directional surface hole
F/113' to 223'.
Spud well @ 05:30 hrs 10-29-2022
350 GPM
380 PSI
30 RPM
2K TQ
5-10K WOB
75K P/U
70K S/O
73K ROT
113.0 223.0
10/29/2022
06:30
10/29/2022
07:00
0.50 SURFAC, DRILL CIRC P Circulate hole clean with 8.8 ppg spud
mud.
350 GPM
370 PSI
30 RPM
3K TQ
5-10K WOB
75K P/U
70K S/O
73K ROT
223.0 223.0
10/29/2022
07:00
10/29/2022
07:15
0.25 SURFAC, DRILL OWFF P OWFF - static. 223.0 223.0
10/29/2022
07:15
10/29/2022
08:00
0.75 SURFAC, DRILL TRIP P POOH pumping 110 gpm with 130 psi.
75K P/U
71K S/O
223.0 223.0
10/29/2022
08:00
10/29/2022
10:15
2.25 SURFAC, DRILL BHAH P PJSM. M/U BHA #2 as per SLB rep
F/41' to 79'.
Started taking weight at 77'.
223.0 223.0
10/29/2022
10:15
10/29/2022
10:30
0.25 SURFAC, DRILL BHAH P Orientate BHA 90° and work pipe, still
taking weight F/75' to 79'.
223.0 223.0
10/29/2022
10:30
10/29/2022
10:45
0.25 SURFAC, DRILL OWFF P OWFF - static while calling town. 223.0 223.0
10/29/2022
10:45
10/29/2022
12:00
1.25 SURFAC, DRILL BHAH P Continue M/U BHA #2 F/ 79' to 125' as
per SLB rep.
223.0 223.0
10/29/2022
12:00
10/29/2022
12:30
0.50 SURFAC, DRILL OTHR P Swap rig to Hi-Line power. 223.0 223.0
10/29/2022
12:30
10/29/2022
13:30
1.00 SURFAC, DRILL BHAH P Continue M/U BHA #2 as per SLB rep.
Taking weight at 123'. L/D flex collar and
kelly up. Stage pump up to 375 gpm,
420 psi.
223.0 223.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 3/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/29/2022
13:30
10/29/2022
15:00
1.50 SURFAC, DRILL REAM P M/U stand HWDP and ream F/156' to
223'. Rack back HWDP stand, M/U
remaining flex collar and stand HWDP.
400 GPM
550 PSI
30 RPM
1K TQ
0K WOB
223.0 223.0
10/29/2022
15:00
10/29/2022
17:00
2.00 SURFAC, DRILL DDRL P Drill 13-1/2" surface directional hole
F/223' to 404'.
350 GPM
370 PSI
30 RPM
3K TQ
5-10K WOB
75K P/U
70K S/O
73K ROT
4.23 BIT HRS
1.73 ADT
223.0 404.0
10/29/2022
17:00
10/29/2022
21:00
4.00 SURFAC, DRILL CIRC T Packed off at surface in riser with clay.
Staging flow rates while reciprocating
pipe breaking up clay to go down flow
line.
404.0 404.0
10/29/2022
21:00
10/29/2022
23:30
2.50 SURFAC, DRILL DDRL P Drill 13-1/2" surface directional hole
F/404' to T/610' MD / 610'TVD.
500 GPM
900 PSI
40 RPM
2K TQ
4K WOB
87K P/U
87K S/O
88K ROT
6.13 BIT HRS
1.9 HRS ADT
404.0 610.0
10/29/2022
23:30
10/30/2022
00:00
0.50 SURFAC, DRILL CIRC T Packed off at surface in riser with clay.
Staging flow rates while reciprocating
pipe breaking up clay to go down flow
line.
610.0 610.0
10/30/2022
00:00
10/30/2022
06:00
6.00 SURFAC, DRILL DDRL P Drill 13-1/2" surface directional hole
F/610' to T/1,075' MD / 1,066' TVD.
450-600 GPM
780-1100 PSI
40 RPM
3K TQ
4-20K WOB
120K P/U
100K S/O
115K ROT
10.5 BIT HRS
6.04 HRS ADT
610.0 1,075.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 4/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/30/2022
06:00
10/30/2022
07:00
1.00 SURFAC, DRILL DDRL P Drill 13-1/2" surface directional hole
F/1,075' to T/1,182' MD / 1,066' TVD.
550 GPM
1480 PSI
40 RPM
6K TQ
5-10K WOB
120K P/U
110K S/O
115K ROT
1,075.0 1,182.0
10/30/2022
07:00
10/30/2022
07:45
0.75 SURFAC, DRILL CIRC T Started taking losses at 200 bph.
Pumped 61 bbls 8.8 ppg LCM pill at 40
ppb and displaced. Losses decreased to
20 bph once LCM in open hole.
1,182.0 1,182.0
10/30/2022
07:45
10/30/2022
12:00
4.25 SURFAC, DRILL DDRL P Drill 13-1/2" surface directional hole
F/1,182' to T/1,586' MD / 1,535' TVD.
550 GPM
1450 PSI
40 RPM
3K TQ
5-10K WOB
126K P/U
117K S/O
120K ROT
14.04 BIT HRS
3.54 HRS ADT
1,182.0 1,586.0
10/30/2022
12:00
10/30/2022
18:00
6.00 SURFAC, DRILL DDRL P Drill 13-1/2" surface directional hole
F/1,586' to T/2,025' MD / 1,920' TVD.
550 GPM
1400 PSI
40 RPM
5K TQ
5-10K WOB
129K P/U
112K S/O
122K ROT
19.1 BIT HRS
5.13 HRS ADT
1,586.0 2,025.0
10/30/2022
18:00
10/30/2022
21:30
3.50 SURFAC, DRILL DDRL P Drill 13-1/2" surface directional hole
F/2,025' to T/2,266' MD / 2,005' TVD.
550 GPM
1400 PSI
40 RPM
5K TQ
5-10K WOB
129K P/U
112K S/O
122K ROT
19.1 BIT HRS
5.13 HRS ADT
2,025.0 2,266.0
10/30/2022
21:30
10/30/2022
23:00
1.50 SURFAC, DRILL RGRP T Mud Pump #1 changed #1 swab and
liner while circulating at 420 gpm and
reciprocating pipe.
2,266.0 2,266.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 5/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/30/2022
23:00
10/31/2022
00:00
1.00 SURFAC, DRILL DDRL P Drill 13-1/2" surface directional hole
F/2,266' to T/2,344' MD / 2,129 TVD.
600 GPM
1700 PSI
60 RPM
5K TQ
5-10K WOB
135K P/U
114K S/O
125K ROT
20.09 BIT HRS
3.41 HRS ADT
2,266.0 2,344.0
10/31/2022
00:00
10/31/2022
06:00
6.00 SURFAC, DRILL DDRL P Drill 13-1/2" surface directional hole
2,344' to 2,956' MD / 2,492' TVD.
500-600 GPM
1440-1780 PSI
60-80 RPM
6-8K TQ
10-20K WOB
136K P/U
117K S/O
124K ROT
25.19 BIT HRS
5.1 HRS ADT
2,344.0 2,956.0
10/31/2022
06:00
10/31/2022
07:45
1.75 SURFAC, DRILL DDRL P Drill 13-1/2" surface directional hole
2,956' to 3,080' MD / 2,547' TVD at
section TD.
550 GPM
1600 PSI
60 RPM
7K TQ
5-12K WOB
134K P/U
117K S/O
124K ROT
26.3 BIT HRS
1.2 HRS ADT
2,956.0 3,080.0
10/31/2022
07:45
10/31/2022
10:00
2.25 SURFAC, TRIPCAS CIRC P Pump 40 bbls 40 ppb LCM sweep and
circulate 2 x bottoms up with 9.8 ppg
mud. Moderate increase in cuttings
when sweep at surface.
650 GPM
2000 PSI
80 RPM
5K TQ
3,080.0 3,080.0
10/31/2022
10:00
10/31/2022
10:30
0.50 SURFAC, TRIPCAS OWFF P OWFF - slight drop. SIMOPS: B/D top
drive and prepare to POOH.
3,080.0 3,004.0
10/31/2022
10:30
10/31/2022
12:00
1.50 SURFAC, TRIPCAS BKRM P BROOH 3,004 to 2,650'.
675 GPM
2110 PSI
80 RPM
6K TQ
3,004.0 2,650.0
10/31/2022
12:00
10/31/2022
18:00
6.00 SURFAC, TRIPCAS BKRM P BROOH 2,650 to 1,683'. While
backreaming 1,967' to 1,683' pumped 1
bottoms up per stand.
675 GPM
2110 PSI
80 RPM
6K TQ
2,650.0 1,683.0
10/31/2022
18:00
10/31/2022
19:00
1.00 SURFAC, TRIPCAS TRIP P B/D top drive. POOH on elevators
1,683' to 1,204' with normal drag.
1,683.0 1,204.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 6/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/31/2022
19:00
10/31/2022
20:00
1.00 SURFAC, TRIPCAS RGRP T Troubleshoot trip tank pumps. TT #2
pump tripped off due to overheating and
TT#1 pump will not pump sufficent
volume to fill hole. Lined up 2 mixing
pumps to fill hole.
1,204.0 1,204.0
10/31/2022
20:00
10/31/2022
20:45
0.75 SURFAC, TRIPCAS TRIP P POOH on elevators 1,204' to 725' at
BHA with normal drag.
1,204.0 725.0
10/31/2022
20:45
10/31/2022
21:15
0.50 SURFAC, TRIPCAS OWFF P OWFF - static. SIMOPS: PJSM for BHA. 725.0 725.0
10/31/2022
21:15
11/1/2022
00:00
2.75 SURFAC, TRIPCAS BHAH P Rack back HWDP + Jars. L/D BHA #2
tools as per SLB DD.
725.0 90.0
11/1/2022
00:00
11/1/2022
01:45
1.75 SURFAC, TRIPCAS BHAH P PJSM. Finish L/D BHA #2 tools as per
SLB DD. Note: String stabilizer worn
down ~1" in length and 1/2" down on
gauge OD on top of all the blades and
similar wear found on 2 of the 4 blades
on motor sleeve stab. Bit shanks had
wear similar to these and a couple of
chipped PDC's.
90.0 0.0
11/1/2022
01:45
11/1/2022
04:00
2.25 SURFAC, TRIPCAS CLEN P Clear and clean BHA tools off rig floor
while monitoring well - static.
0.0 0.0
11/1/2022
04:00
11/1/2022
05:15
1.25 SURFAC, CASING RURD P R/U and make dummy run with
Cameron Casing Hanger. Landed @
36.6', drifted to 9.88".
0.0 0.0
11/1/2022
05:15
11/1/2022
07:30
2.25 SURFAC, CASING PUTB P R/U to run 10-3/4" casing. M/U CRT,
replaced bails, elevators and spider
while monitoring well - static.
0.0 0.0
11/1/2022
07:30
11/1/2022
12:00
4.50 SURFAC, CASING PUTB P PJSM. M/U 10-3/4" 45.5# L-80 HYD 563
shoe track joints with centralizers
installed as per plan and baker loc each
to 4th connection. Double bumped each
connection. Pumped through shoe track
floats - ok. Run casing installing
centralizers as per plan top filling each
joint with 9.8 ppg mud and top up every
10 joints from 128' to 1,121'.
0.0 1,121.0
11/1/2022
12:00
11/1/2022
15:30
3.50 SURFAC, CASING PUTB P Run 10-3/4" casing installing
centralizers as per plan top filling each
joint with 9.8 ppg mud and top up every
10 joints from 1,121' to 1,665' at base
permafrost.
1,121.0 1,665.0
11/1/2022
15:30
11/1/2022
18:30
3.00 SURFAC, CASING CIRC P Circulate staging pump up in 1/2 bbl
increments to 8 bpm while reciprocate
pipe and circulate bottoms up at 8 bpm
with no losses.
ICP: 0.5 bpm at 190 psi, FCP: 8 bpm at
250 psi.
1,665.0 1,665.0
11/1/2022
18:30
11/1/2022
22:15
3.75 SURFAC, CASING PUTB P Run 10-3/4" casing installing
centralizers as per plan top filling each
joint with 9.8 ppg mud and top up every
10 joints from 1,665' to 2,576'.
Note: Tagged at 1,815' and worked and
pumped at 1-2 bpm down to1,830' then
continued running casing.
1,665.0 2,576.0
11/1/2022
22:15
11/2/2022
00:00
1.75 SURFAC, CASING RGRP T Top Drive would not function. Worked
pipe and staage pump up to 3 bpm
while troubleshooting.
2,576.0 2,576.0
11/2/2022
00:00
11/2/2022
01:30
1.50 SURFAC, CASING RGRP T Top Drive would not function. Worked
pipe and stage pump up to 4 bpm while
troubleshooting. Found hydraulic relay
switch tripped.
2,576.0 2,576.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 7/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/2/2022
01:30
11/2/2022
02:45
1.25 SURFAC, CASING PUTB P Run 10-3/4" casing installing
centralizers as per plan top filling each
joint with 9.8 ppg mud and top up every
10 joints from 2,576' to 3,029'.
S/O 115K
2,576.0 3,029.0
11/2/2022
02:45
11/2/2022
03:15
0.50 SURFAC, CASING PUTB P M/U Cameron 10-3/4"x 13-1/2" Mandrel
Hanger with pup joint to landing joint.
Run in hole washing down at 1/2 bpm
and land out on landing ring.
Shoe @ 3,069'.
P/U 178K
S/O 121K
21 GPM
190 PSI
3,029.0 3,069.0
11/2/2022
03:15
11/2/2022
06:30
3.25 SURFAC, CEMENT CIRC P Establish circulation with 9.8 ppg mud
while reciprocating staging up to 5 bpm.
Circulated at 5 bpm.
SIMOPS: R/U Halliburton cementers
and PJSM.
P/U 188K
S/O 128K
3,069.0 3,069.0
11/2/2022
06:30
11/2/2022
12:00
5.50 SURFAC, CEMENT CMNT P Perform surface cement job as per HES.
Pump 60 bbl's 10.2 ppg tuned prime
spacer with LCM and #4 red dye @ 4.3
bpm while reciprocating, PUW 180K,
SOW 130K.
Drop bottom wiper plug and follow with
10.7 ppg Arctic Cem Lead Cement,
pump at average 5.3 bpm.
Land hanger while interface exiting
casing shoe at total volume pumped 295
bbl's, pick up and reciprocate after
interface clears shoe track at total of
350 bbl's pumped. Finish lead cement
for a total of 501 bbl's 10.7 ppg lead
cement pumped.
Follow with 58 bbl's 15.8 ppg tail cement
at 2 bpm (Cement to surface 17 bbls
into Tail slurry).
Drop top wiper plug and chase with 20
bbl's @ 5.8 bpm fresh water from HES
cement unit.
Displace 262 bbl's 9.8 Spud mud with
rig pumps ICP at 6.2 BPM 226 PSI, at
256 bbls pumped reduce rate to 3 bpm
385 psi FCP.
Bump plug at 2604 strokes and build
pressure to 931 psi and held for 5
minutes. Bleed pressure off and check
floats, floats holding. Note: Landed
hanger 2,000 stks into displacement,
CIP @ 11:57 hrs.
Note: Full returns during job, spacer,
306 bbls cement and interface back to
surface with 46 bbls 10.6 ppg cement.
S/O 105K prior to landing
3,069.0 3,069.0
11/2/2022
12:00
11/2/2022
17:00
5.00 SURFAC, CEMENT RURD P Flush staring head with black water, L/D
Volant tool, casing running equipment
and landing joint. B/D cement line, clean
possum belly and ditch in pits, pull
mouse hole, clean cement line valves
and flush riser with BOP wash tool.
0.0 0.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 8/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/2/2022
17:00
11/2/2022
20:00
3.00 SURFAC, WHDBOP NUND P PJSM. N/D flowline adapter, surface
risers and remove Cameron adapter
and starting head. Continue cleaning
pits.
0.0 0.0
11/2/2022
20:00
11/2/2022
21:00
1.00 SURFAC, WHDBOP WWSP P Prepare Cameron wellhead and N/U on
casing hanger. Orientation confirmed by
3S Pad Operator. Elevation
measurements to ULDS = 32.96', LLDS
= 33.86'. No change in cement height at
24" in annulus.
0.0 0.0
11/2/2022
21:00
11/2/2022
22:00
1.00 SURFAC, WHDBOP WWSP P Tested wellhead seals to 5,000 psi for
15 minutes - good test. Torque lock
down pins and restest seals - good test.
Test witnessed by CPA rep.
0.0 0.0
11/2/2022
22:00
11/3/2022
00:00
2.00 SURFAC, WHDBOP NUND P M/U adapter flange, spacer spool and
spot BOP over well.
0.0 0.0
11/3/2022
00:00
11/3/2022
09:00
9.00 SURFAC, WHDBOP NUND P N/U BOP on wellhead, Install MPD
manifold on stack, Perform BWM, Install
flow box, orbit valve, MPD lines, drip
pan, tighten choke line, and install turn
buckles.
0.0 0.0
11/3/2022
09:00
11/3/2022
12:00
3.00 SURFAC, WHDBOP BOPE P Test run trip nipple - sent to shop for
length modification. P/U 5" test joint and
Cameron test plug. SIMOPS: Cleaning
pits, pumps and blow through pop offs.
0.0 0.0
11/3/2022
12:00
11/3/2022
14:30
2.50 SURFAC, WHDBOP BOPE P Set test plug, R/U BOP test equipment
and fill surface equipment with water.
0.0 0.0
11/3/2022
14:30
11/3/2022
15:00
0.50 SURFAC, WHDBOP BOPE P Purge air and shell test BOP. Tested all
gas alarms, PVT gain / loss, TT gain /
loss, flow out indicators.
0.0 0.0
11/3/2022
15:00
11/3/2022
19:30
4.50 SURFAC, WHDBOP BOPE P All test BOPE 250 PSI low 4000 PSI for
5 minutes each test charted. Test
annular Preventer to 250 psi low and
2500 psi high for 5 minutes each.
Test the following 4" Demco kill, choke
valves 1,12,13,14, 3.5" x 6" VBR top
rams, auto IBOP, HCR kill valve, manual
choke valve 9 and 11, IBOP, needle
valve above #1 to 250 psi low and 4000
psi high for 5 minutes each. Remote and
hydraulic chokes tested to 2,000 psi and
observed pressure drop when opening.
F&P Upper IBOP - functioned then
good.
Witnessed by AOGCC Rep Kam
StJohn.
Accumulator drawdown:
ISP = 3,050
PSI after function = 1,450, 4 bottles N2
avg = 2,300 psi
Closing time: Annular = 14 sec, UPPR's:
8 sec, Blinds: 8 sec, LPPR's: 8 sec,
HCR Kill: 2 sec, HCR Choke: 2 sec.
0.0 0.0
11/3/2022
19:30
11/3/2022
21:00
1.50 SURFAC, WHDBOP MPDA P Shell test MPD 250 psi / 1,250 psi 5 min
each as per Beyond rep.
0.0 0.0
11/3/2022
21:00
11/3/2022
21:30
0.50 SURFAC, WHDBOP BOPE P Pull test plug and set Cameron wear
bushing (10" ID - 2.57' long) as per
Cameron rep.
0.0 0.0
11/3/2022
21:30
11/3/2022
22:00
0.50 SURFAC, WHDBOP NUND P L/D test joint, bring trip nipple and bha
components to floor.
0.0 0.0
11/3/2022
22:00
11/4/2022
00:00
2.00 SURFAC, WHDBOP NUND P R/U trip nipple, hole fill, bleeder, jet line,
mud bucket drain and flow line
extension.
0.0 0.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 9/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/4/2022
00:00
11/4/2022
01:30
1.50 SURFAC, DRILLOUT PULD P L/D 4 stands 5" HWDP from mast.
SIMOPS: shuffle 5" DP in shed for
drilling.
0.0 0.0
11/4/2022
01:30
11/4/2022
03:30
2.00 SURFAC, DRILLOUT BHAH P Pick up and make up BHA #3 - 9-7/8"
intermediate drilling BHA T/332' as per
directional driller. Note: Corrosion
coupon ran in top 1st stand HWDP box.
0.0 332.0
11/4/2022
03:30
11/4/2022
05:30
2.00 SURFAC, DRILLOUT TRIP P RIH with BHA #3 F/332' T/2,698'. 332.0 2,698.0
11/4/2022
05:30
11/4/2022
05:45
0.25 SURFAC, DRILLOUT PULD P Single in 5" DP from pipe shed F/2,698'
T/2,883' (6 jts).
2,698.0 2,883.0
11/4/2022
05:45
11/4/2022
06:30
0.75 SURFAC, DRILLOUT CIRC P Shallow hole test MWD tools pumping
550 gpm, 1,100 psi - good test.
2,883.0 2,883.0
11/4/2022
06:30
11/4/2022
08:30
2.00 SURFAC, DRILLOUT SLPC P PJSM. Slip and cut 63' drill line.
SIMOPS: Circulate and condition mud
for casing test pumping 100 gpm at 80
psi.
2,883.0 2,883.0
11/4/2022
08:30
11/4/2022
09:00
0.50 SURFAC, DRILLOUT SVRG P Service rig and top drive. SIMOPS:
Circulate and condition mud for casing
test pumping 100 gpm with 80 psi.
2,883.0 2,883.0
11/4/2022
09:00
11/4/2022
09:30
0.50 SURFAC, DRILLOUT CIRC P Circulate bottoms up pumping 500 gpm
with 900 psi.
2,883.0 2,883.0
11/4/2022
09:30
11/4/2022
10:00
0.50 SURFAC, DRILLOUT RURD P B/D top drive and R/U to test casing. 2,883.0 2,883.0
11/4/2022
10:00
11/4/2022
12:00
2.00 SURFAC, DRILLOUT PRTS P Pressure test 10-3/4" casing to 3000 psi
for 30 minutes with 9.8 ppg mud,
charted.
Total pumped 41 strokes 4.1 Bbl's
Pressure loss over 30 minutes 24 PSI,
casing held 99.2%
Total bled back 4.1Bbl's. R/D and B/D
test equipment.
2,883.0 2,883.0
11/4/2022
12:00
11/4/2022
12:30
0.50 SURFAC, DRILLOUT DRLG P Wash/ream down F/2,883' T/2,975'.
450 GPM
750 PSI
40 RPM
4k TQ
2k WOB
125K P/U
105K S/O
120K ROT
2,883.0 2,975.0
11/4/2022
12:30
11/4/2022
13:15
0.75 SURFAC, DRILLOUT CIRC P Reduce flow rate to handle green
cement at shakers, stage pumps back
up as shakers cleaned up.
2,975.0 2,975.0
11/4/2022
13:15
11/4/2022
14:30
1.25 SURFAC, DRILLOUT DRLG P Wash/ream down drilling out shoe track
F/2,975' T/3,060'.
450 GPM
750 PSI
40 RPM
4k TQ
2k WOB
125K P/U
105K S/O
120K ROT
2,975.0 3,060.0
11/4/2022
14:30
11/4/2022
16:30
2.00 SURFAC, DRILLOUT CIRC T While drilling cement lost
communications with ARC & Xceed
tools below MWD. Attempted to
troubleshoot without success. Decision
made to POOH to replace tools.
3,060.0 3,060.0
11/4/2022
16:30
11/4/2022
18:45
2.25 SURFAC, DRILLOUT TRIP T B/D top drive, TOH F/3,060' T/332'
monitoring displacement on TT #2.
3,060.0 332.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 10/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/4/2022
18:45
11/4/2022
19:00
0.25 SURFAC, DRILLOUT OWFF T OWFF - static. 332.0 332.0
11/4/2022
19:00
11/4/2022
20:30
1.50 SURFAC, DRILLOUT BHAH T Rack back jars, HWDP, flex collars and
L/D BHA and bit.
332.0 0.0
11/4/2022
20:30
11/4/2022
22:30
2.00 SURFAC, DRILLOUT BHAH T Program replacement Ecoscope tool in
pipe shed. Note Ecoscope received on
location at 20:00 hrs.
0.0 0.0
11/4/2022
22:30
11/5/2022
00:00
1.50 SURFAC, DRILLOUT BHAH T P/U Xceed and M/U RR bit. While M/U
bit the EcoScope tool was on the skate
at the floor and the skate stop released
allowing the tool to descended down the
skate ~50' contacting the stop.
Contacted town and decision made to
run the PeriScope tool. Reprogram
TeleScope tool for PeriScope tool.
0.0 25.0
11/5/2022
00:00
11/5/2022
02:30
2.50 SURFAC, DRILLOUT BHAH T Reprogram TeleScope tool due to
running PeriScope tool (it was
previously programmed for EcoScope).
M/U PeriScope and Telescope tools.
RIH with BHA T/332'.
25.0 332.0
11/5/2022
02:30
11/5/2022
04:45
2.25 SURFAC, DRILLOUT TRIP T RIH with BHA # 3 F/332' T/2,888'.
P/U 130K
S/O 105K
332.0 2,888.0
11/5/2022
04:45
11/5/2022
05:30
0.75 SURFAC, DRILLOUT WASH T Shallow hole test tools - good. Wash
down to 3,060'.
2,888.0 3,060.0
11/5/2022
05:30
11/5/2022
08:15
2.75 SURFAC, DRILLOUT REAM P Wash/ream down drilling out shoe track
F/3,060' T/3,069 at shoe. Float
equipment on depth. Clean out rat hole
to 3,080'.
550 GPM
1000 PSI
40-80 RPM
8K TQ
5-7k WOB
130K P/U
105K S/O
120K ROT
3,060.0 3,080.0
11/5/2022
08:15
11/5/2022
08:45
0.50 SURFAC, DRILLOUT REAM P Clean up shoe with 3 passes F/3,067
T/3,080'.
550 GPM
1000 PSI
60 RPM
8K TQ
130K P/U
105K S/O
120K ROT
3,080.0 3,080.0
11/5/2022
08:45
11/5/2022
09:15
0.50 SURFAC, DRILLOUT DDRL P Drill 20' new formation for FIT/LOT test
F/3.080' MD T/3,100' MD
550 GPM
1010 PSI
60 RPM
8K TQ
5-7k WOB
130K P/U
105K S/O
120K ROT
3,080.0 3,100.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 11/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/5/2022
09:15
11/5/2022
09:30
0.25 SURFAC, DRILLOUT CIRC P Circulate bottoms up while back
reaming to shoe.
550 GPM
990 PSI
40 RPM
5K TQ
130K P/U
105K S/O
120K ROT
3,100.0 2,982.0
11/5/2022
09:30
11/5/2022
09:45
0.25 SURFAC, DRILLOUT OWFF P OWFF - static SIMOPS: B/D top drive 2,982.0 2,982.0
11/5/2022
09:45
11/5/2022
12:30
2.75 SURFAC, DRILLOUT FIT P R/U FIT/LOT testing equipment,
circulate through lines to purge air, close
UPR rams Perform FIT test as per
procedure. Pumped 3.0 bbls in 1/2 bbl
increments with rig pump to test
pressure and observed leak at OA plug
valve. Bled to zero and repaired same.
Pumped 2nd time to 615 psi when leak
off observed.
615 PSI, 14.4 PPG EMW.
1.8 bbls pumped
Shut in for 10 minutes and pressure
bled down to 298 PSI for 312 PSI loss
over 10 minutes.
Bled off and record 1.3 bbls back.
Monitor OA pressure and discussed
LOT with town.
2,982.0 2,982.0
11/5/2022
12:30
11/5/2022
13:00
0.50 INTRM1, DRILL OWFF P OWFF - static SIMOPS: R/D and B/D
test equipment.
2,982.0 2,982.0
11/5/2022
13:00
11/5/2022
14:00
1.00 INTRM1, DRILL REAM P Wash / ream F/2,982' T/3,100' while
pumping spacer and displacing to 9.0
ppg LSND mud.
550 GPM
980 PSI
40 RPM
6K TQ
130K P/U
105K S/O
120K ROT
2,982.0 3,100.0
11/5/2022
14:00
11/5/2022
18:00
4.00 INTRM1, DRILL DDRL P Drill 9-7/8" Intermediate hole as per DD
F/3,100' T/3,358' - 2,662' TVD.
550 GPM
850 PSI
120 RPM
5-6K WOB
125K P/U
117K S/O
120K ROT
10.0 ECD
ADT= 2.58
Bit HRS= 5.68
3,100.0 3,358.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 12/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/5/2022
18:00
11/6/2022
00:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8" Intermediate hole as per DD
F/3,358' T/3,966' - 2,867' TVD. Pumped
30 bbls Hi-Vis sweep at 3,638'. Shakers
had 50% increase when pill at surface.
750 GPM
1400 PSI
150-160 RPM
8K WOB
130K P/U
117K S/O
120K ROT
10.3 ECD
ADT= 4.46
Bit HRS= 10.14
3,358.0 3,966.0
11/6/2022
00:00
11/6/2022
06:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8" Intermediate hole as per DD
F/3,966' T/4,781' - 3,102' TVD. Pumped
30 bbls Hi-Vis sweeps at 4,118' = 25%
increase, at 4,618' = 30% increase
when pills at surface.
Note: Daylight Savings 1 hr Time
Change.
740 GPM
1480 PSI
160 RPM
5.5K TQ
5-10K WOB
135K P/U
120K S/O
125K ROT
11.06 ECD
ADT= 5.02
Bit HRS= 15.16
3,966.0 4,781.0
11/6/2022
06:00
11/6/2022
12:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8" Intermediate hole as per DD
F/4,781' T/5,388' - 3,275' TVD. Pumped
25 bbls Hi-Vis sweeps at 5,063' = 30%
increase when pills at surface.
730 GPM
1590 PSI
160 RPM
7K TQ
6K WOB
143K P/U
120K S/O
130K ROT
11.09 ECD
ADT= 4.64
Bit HRS= 19.8
4,781.0 5,388.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 13/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/6/2022
12:00
11/6/2022
18:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8" Intermediate hole as per DD
F/5,388' T/6,013' - 3,453' TVD. Pumped
30 bbls Hi-Vis sweeps at 5,537' = 20%
increase, at 6,013' = 30% increase
when sweeps at surface.
730 GPM
1750 PSI
160 RPM
9K TQ
12K WOB
155K P/U
120K S/O
128K ROT
11.28 ECD
ADT= 4.48
Bit HRS= 24.28
5,388.0 6,013.0
11/6/2022
18:00
11/7/2022
00:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8" Intermediate hole as per DD
F/6,013' T/6,581' - 3,614' TVD.
Pumped 180 bbl 9.0 ppg LSND dilution
at 6,425'.
730 GPM
1900 PSI
160 RPM
9K TQ
12K WOB
155K P/U
120K S/O
135K ROT
11.5 ECD
ADT= 4.55
Bit HRS= 28.83
6,013.0 6,581.0
11/7/2022
00:00
11/7/2022
06:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8" Intermediate hole as per DD
F/6,581' T/7,242' - 3,891' TVD.
Pumped 30 bbls Hi-Vis sweep at 6,598'
= 35% increase when sweep at surface.
730 GPM
1900 PSI
175 RPM
7K TQ
5-10K WOB
185K P/U
130K S/O
143K ROT
11.46 ECD
ADT= 4.69
Bit HRS= 33.52
6,581.0 7,242.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 14/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/7/2022
06:00
11/7/2022
12:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8" Intermediate hole as per DD
F/7,242' T/7,741' - 3,945' TVD.
Pumped 30 bbls Hi-Vis sweeps at 7,057'
= 35% increase, 7,429' = 45% increase
when sweeps at surface.
723 GPM
1960 PSI
175 RPM
9K TQ
12K WOB
165K P/U
130K S/O
143K ROT
11.5 ECD
ADT= 3.81
Bit HRS= 37.33
7,242.0 7,741.0
11/7/2022
12:00
11/7/2022
18:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8" Intermediate hole as per DD
F/7,741' T/8,282' - 4,100' TVD.
Pumped 30 bbls Hi-Vis sweep at 7,904'
= 25% increase when sweep at surface.
720 GPM
1990 PSI
175 RPM
9K TQ
12K WOB
168K P/U
130K S/O
145K ROT
11.36 ECD
ADT= 4.99
Bit HRS= 42.32
7,741.0 8,282.0
11/7/2022
18:00
11/8/2022
00:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8" Intermediate hole as per DD
F/8,282' T/8,800' - 4,247' TVD.
Pumped 30 bbls Hi-Vis sweep at 8,378'
= 35% increase when sweep at surface.
720 GPM
1990 PSI
175 RPM
9K TQ
12K WOB
168K P/U
137K S/O
148K ROT
11.36 ECD
ADT= 4.48
Bit HRS= 46.8
8,282.0 8,800.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 15/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/8/2022
00:00
11/8/2022
06:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8" Intermediate hole as per DD
F/8,800' T/9,320' - 4,395' TVD.
Pumped 30 bbls Hi-Vis sweeps at 8,855'
= 20% and 9,323' = 10% increase when
sweeps at surface.
720 GPM
2100 PSI
175 RPM
9K TQ
9K WOB
170K P/U
140K S/O
153K ROT
11.34 ECD
ADT= 4.6
Bit HRS= 51.4
8,800.0 9,320.0
11/8/2022
06:00
11/8/2022
12:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8" Intermediate hole as per DD
F/9,320' T/9,860' - 4,550' TVD.
Pumped 30 bbls Bit Ball sweep at 9,845'
= 15% increase when sweep at surface.
720 GPM
2120 PSI
175 RPM
10K TQ
9K WOB
174K P/U
144K S/O
156K ROT
11.35 ECD
ADT= 4.6
Bit HRS= 56.0
9,320.0 9,860.0
11/8/2022
12:00
11/8/2022
18:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8" Intermediate hole as per DD
F/9,860' T/10,434' - 4,719' TVD.
Pumped 30 bbls Bit Ball sweep at
10,270' = 10% increase when sweep at
surface.
720 GPM
2160 PSI
175 RPM
12K TQ
11K WOB
185K P/U
145K S/O
158K ROT
11.37 ECD
ADT= 4.91
Bit HRS= 60.91
9,860.0 10,434.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 16/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/8/2022
18:00
11/9/2022
00:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8" Intermediate hole as per DD
F/10,434' T/10,960' - 4,780' TVD.
Pumped 30 bbls weighted sweep (11.4
ppg) at 10,841' = 10% increase when
sweep at surface.
723 GPM
2270 PSI
175 RPM
13K TQ
12K WOB
192K P/U
145K S/O
160K ROT
11.51 ECD
ADT= 4.64
Bit HRS= 65.55
10,434.0 10,960.0
11/9/2022
00:00
11/9/2022
00:30
0.50 INTRM1, DRILL DDRL P Drill 9-7/8" Intermediate hole as per DD
F/10,960' T/11,024'.
Note: No additional sweeps pumped
due to minimal results.
720 GPM
2270 PSI
175 RPM
13K TQ
12K WOB
192K P/U
145K S/O
160K ROT
11.51 ECD
10,960.0 11,024.0
11/9/2022
00:30
11/9/2022
01:30
1.00 INTRM1, DRILL CIRC T Communications went down, lost Totco
PVT and internet. Kuparuk
Communications were contacted by
radio and reported a problem in the 3S
control room, Communications came
back on.
11,024.0 11,024.0
11/9/2022
01:30
11/9/2022
06:00
4.50 INTRM1, DRILL DDRL P Drill 9-7/8" Intermediate hole as per DD
F/11,024' T/11,340' - 5,007' TVD.
720 GPM
2250 PSI
175 RPM
13K TQ
12K WOB
194K P/U
144K S/O
160K ROT
11.35 ECD
ADT= 3.24
Bit HRS= 68.79
11,024.0 11,340.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 17/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/9/2022
06:00
11/9/2022
10:15
4.25 INTRM1, DRILL DDRL P Drill 9-7/8" Intermediate hole as per DD
F/11,340' T/11,717' - 5,133' TVD at
section TD.
720 GPM
2310 PSI
175 RPM
13K TQ
12K WOB
198K P/U
148K S/O
168K ROT
11.35 ECD
ADT= 3.25
Bit HRS= 72.04
11,340.0 11,717.0
11/9/2022
10:15
11/9/2022
10:45
0.50 INTRM1, TRIPCAS CIRC P Obtaing final T&D numbers, section TD
survey and SPR's.
11,717.0 11,717.0
11/9/2022
10:45
11/9/2022
12:00
1.25 INTRM1, TRIPCAS CIRC P Circulate and condition mud while
preparing for dilution.
720 GPM
2250 PSI
175 RPM
9.5K TQ
198K P/U
148K S/O
168K ROT
11.31 ECD
11,717.0 11,717.0
11/9/2022
12:00
11/9/2022
12:30
0.50 INTRM1, TRIPCAS CIRC P Continue circulating and conditioning
mud while preparing for dilution.
720 GPM
2250 PSI
175 RPM
9.5K TQ
198K P/U
148K S/O
168K ROT
11.31 ECD
11,717.0 11,717.0
11/9/2022
12:30
11/9/2022
14:00
1.50 INTRM1, TRIPCAS CIRC P Displace with 580 bbls clean 9.6 ppg
mud staging up to 550 gpm at 1500 psi.
11,717.0 11,717.0
11/9/2022
14:00
11/9/2022
15:00
1.00 INTRM1, TRIPCAS CIRC P Take SPR's while reciprocating string,
screening down to 120's on shakers.
11,717.0 11,717.0
11/9/2022
15:00
11/9/2022
16:00
1.00 INTRM1, TRIPCAS BKRM P Circulate bottoms up staging pumps to
550 gpm and lay down 1st stand in
mousehole.
550 GPM
1500 PSI
150 RPM
9K TQ
198K P/U
148K S/O
168K ROT
10.43 ECD
11,717.0 11,598.0
11/9/2022
16:00
11/9/2022
18:00
2.00 INTRM1, TRIPCAS BKRM P OWFF 10 min - static. BROOH
F/11,598' T/11,312' laying down stands
5" drill pipe out of mousehole.
710 GPM
2150 PSI
150 RPM
8K TQ
150K ROT
11.1 ECD
11,598.0 11,312.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 18/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/9/2022
18:00
11/10/2022
00:00
6.00 INTRM1, TRIPCAS BKRM P BROOH F/11,312' T/9,234' laying down
stands 5" drill pipe out of mousehole.
Shakers have had a light steady load
and no unloading events experienced.
710 GPM
2150 PSI
150 RPM
8K TQ
150K ROT
11.1 ECD
11,312.0 9,234.0
11/10/2022
00:00
11/10/2022
06:00
6.00 INTRM1, TRIPCAS BKRM P BROOH F/9,234' T/6,870' laying down
stands 5" drill pipe out of mousehole.
Shakers have had a light steady load
and no unloading events experienced.
720 GPM
1640 PSI
150 RPM
7K TQ
133K ROT
10.97 ECD
9,234.0 6,870.0
11/10/2022
06:00
11/10/2022
12:00
6.00 INTRM1, TRIPCAS BKRM P BROOH F/6,870' T/4,960' laying down
stands 5" drill pipe out of mousehole.
Shakers have had a light steady load
and no unloading events experienced.
710 GPM
1440 PSI
139K UP
112K DN
150 RPM
5K TQ
124K ROT
10.64 ECD
6,870.0 4,960.0
11/10/2022
12:00
11/10/2022
17:30
5.50 INTRM1, TRIPCAS BKRM P BROOH F/4,960' T/3,172' laying down
stands 5" drill pipe out of mousehole.
Shakers have had a light steady load
and no unloading events experienced.
710 GPM
1280 PSI
120K UP
115K DN
150 RPM
4K TQ
115K ROT
10.2 ECD
4,960.0 3,172.0
11/10/2022
17:30
11/10/2022
18:00
0.50 INTRM1, TRIPCAS BKRM P BROOH with 60 RPM 710 GPM 1280
PSI pulling BHA into shoe , didn't see
any over pull , TQ or pump PSI increase
while pulling into shoe
3,172.0 3,070.0
11/10/2022
18:00
11/10/2022
19:30
1.50 INTRM1, TRIPCAS CIRC P Pump 40 BBL nut plug sweep , Circ until
shakers clean up @ 720 GPM 1200
PSI , Circ 14,000 STKS ECD from
10.20 at start to 10.02
Cuttings from light to minimal going form
clay to 50% silty shale to 50% clay - See
larger chunks of clay and Torok Shale
come back
3,070.0 2,982.0
11/10/2022
19:30
11/10/2022
19:45
0.25 INTRM1, TRIPCAS OWFF P Flow check - Static 2,982.0 2,982.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 19/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/10/2022
19:45
11/10/2022
23:00
3.25 INTRM1, TRIPCAS BKRM P BROOH F/2,982' T/1,842'
710 GPM
1060 PSI
60 RPM
2K TQ
108K UP
103K DN
103K ROT
Getting larger chunks clay and Torok
Shale back
2,982.0 1,842.0
11/10/2022
23:00
11/10/2022
23:30
0.50 INTRM1, TRIPCAS SVRG P Service rig 1,842.0 1,842.0
11/10/2022
23:30
11/11/2022
00:00
0.50 INTRM1, TRIPCAS RGRP T Change out wash pipe - monitor well on
TT
1,842.0 1,842.0
11/11/2022
00:00
11/11/2022
05:30
5.50 INTRM1, TRIPCAS BKRM P BROOH F/1,842' T/427'
710 GPM
800 PSI
60 RPM
2K TQ
Getting larger chunks clay and Torok
Shale back
1,842.0 427.0
11/11/2022
05:30
11/11/2022
06:30
1.00 INTRM1, TRIPCAS OWFF P Blow DN top drive - Flow check - Static
Sim Ops PJSM L/D 5" HWDP
427.0 427.0
11/11/2022
06:30
11/11/2022
08:45
2.25 INTRM1, TRIPCAS BHAH P POOH laying down 5" HWDP T/139'
Lay down BHA as per SLBG DD
Clean clear rig floor
427.0 0.0
11/11/2022
08:45
11/11/2022
09:45
1.00 INTRM1, CASING WWWH P Make up stack washer flush stack
700 GPM 350 PSI
0.0 0.0
11/11/2022
09:45
11/11/2022
11:30
1.75 INTRM1, CASING BOPE P Pull wear busghing and set test plug as
per Cameron Rep.
0.0 0.0
11/11/2022
11:30
11/11/2022
12:30
1.00 INTRM1, CASING BOPE P Change out upper VBR rams to 7 5/8"
soild body rams
0.0 0.0
11/11/2022
12:30
11/11/2022
13:00
0.50 INTRM1, CASING BOPE P Rig up test JT and test equipment 0.0 0.0
11/11/2022
13:00
11/11/2022
14:00
1.00 INTRM1, CASING BOPE P Test 7 5/8" rams to 250/4000 PSI 5 min
each
Test witnessed waived by AOGCC
Adam Earl on 11-9-22 @ 9:28 AM
0.0 0.0
11/11/2022
14:00
11/11/2022
14:30
0.50 INTRM1, CASING OTHR P Clean clear rig floor for casing run - Sim
Ops suck out water in 90' mouse hole
0.0 0.0
11/11/2022
14:30
11/11/2022
17:30
3.00 INTRM1, CASING RURD P Rig up to run 7 5/8" casing - Perform
dummy run with hanger and landing JT
0.0 0.0
11/11/2022
17:30
11/11/2022
18:00
0.50 INTRM1, CASING SFTY P PJSM - Run 7 5/8" casing 0.0 0.0
11/11/2022
18:00
11/11/2022
18:45
0.75 INTRM1, CASING PUTB P Pick up 7 5/8" P-110 33.7# shoe track to
JT #4 - Baker loc to pin end of JT#4 -
Make TQ 12,100 FT/LBS T/171'
0.0 171.0
11/11/2022
18:45
11/11/2022
19:00
0.25 INTRM1, CASING CIRC P Break Circ @ 3 BPM
Pick up check floats - floats holding
171.0 171.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 20/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/11/2022
19:00
11/11/2022
23:45
4.75 INTRM1, CASING PUTB P Run 7 5/8" casing as per detail F/171'
T/3,069'
131K UP
124K DN
33.7# TQ to 12,100 FT/LBS
29.7# TQ to 10,300 FT/LBS
171.0 3,069.0
11/11/2022
23:45
11/12/2022
00:00
0.25 INTRM1, CASING CIRC P Circ cond mud for 9.6 PPG in and out
stage pumps up to 6.5 BPM 200 PSI
3,069.0 3,069.0
11/12/2022
00:00
11/12/2022
01:00
1.00 INTRM1, CASING CIRC P Circ cond mud stage pumps up to 6.5
BPM 200 PSI
After Circ
133K UP
127K DN
3,069.0 3,069.0
11/12/2022
01:00
11/12/2022
06:00
5.00 INTRM1, CASING PUTB P Run 7 5/8" casing as per detail F/3,069'
T/5,987'
160K UP
133K DN
29.7# TQ to 10,300 FT/LBS
3,069.0 5,987.0
11/12/2022
06:00
11/12/2022
07:45
1.75 INTRM1, CASING CIRC P Circ cond mud for 9.6 PPG in and out
Stage up to 6 BPM 330 PSI
160K UP
130K DN
5,987.0 5,987.0
11/12/2022
07:45
11/12/2022
14:30
6.75 INTRM1, CASING PUTB P Run 7 5/8" casing as per detail F/5,987'
T/9,157'
204K UP
133K DN
29.7# TQ to 10,300 FT/LBS
5,987.0 9,157.0
11/12/2022
14:30
11/12/2022
16:30
2.00 INTRM1, CASING CIRC P Circ cond mud for 9.6 PPG in and out
Stage up to 6 BPM 430 PSI
183K UP
135K DN
9,157.0 9,157.0
11/12/2022
16:30
11/12/2022
22:15
5.75 INTRM1, CASING PUTB P Run 7 5/8" casing as per detail F/9,157'
T/11,587'
138K DN
29.7# TQ to 10,300 FT/LBS
9,157.0 11,587.0
11/12/2022
22:15
11/12/2022
22:45
0.50 INTRM1, CASING PUTB P Wash down F/11,587' T/11,668'
2 BPM 590 PSI
11,587.0 11,668.0
11/12/2022
22:45
11/12/2022
23:15
0.50 INTRM1, CASING PUTB P Make up hanger and landing joint
Wash down F/11668' T/11706' @ 2 BPM
590 PSI
237K UP
135K DN
Land hanger on depth
11,668.0 11,706.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 21/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/12/2022
23:15
11/13/2022
00:00
0.75 INTRM1, CEMENT CIRC P Circ condtion mud for cement job ,
staging pumps up to 8 BPM
Work pipe 18' - 20' strokes
220K UP
136K DN
2 BPM 510 PSI
2.5 BPM 610 PSI
3 BPM 580 PSI
3.5 BPM 600 PSI
11,704.0 11,704.0
11/13/2022
00:00
11/13/2022
01:00
1.00 INTRM1, CEMENT CIRC P Circ condtion mud for cement job ,
staging pumps up to 8 BPM
Work pipe 18' - 20' strokes
220K UP
136K DN
3.5 BPM 600 PSI
4 BPM 570 PSI
4.5 BPM 615 PSI
5 BPM 580 PSI
6 BPM 590 PSI
Sim Ops load pipe shed with 4" DP -
Spot cement unit
11,704.0 11,704.0
11/13/2022
01:00
11/13/2022
02:30
1.50 INTRM1, CEMENT CIRC P Attempt to land out casing in well head
230K UP 150K DN
Set DN 25K at 11704' - 2' off landed
Cont working pipe trying to land work
pumps up to 8 BPM
7 BPM 650 PSI
7.5 BPM 650 PSI
8 BPM 700 PSI
11,704.0 11,704.0
11/13/2022
02:30
11/13/2022
04:00
1.50 INTRM1, CEMENT CIRC T Cont to attempt to work casing down to
landing depth
225K UP 145K DN
Attempt to pull hanger to floor , at 13'' in
on landing JT pull 25K over to 250K on
hook , thinking hanger hanging up in
RCD , drain stack center string in hole
with tugger , pull 25K over again , drain
stack to see down to well head nothing
seen in BOP's
Work pipe with 3.5 BPM 430 PSI , set
DN 45K to 100K on hook slowly get
weight back and land out casing
11,704.0 11,704.0
11/13/2022
04:00
11/13/2022
04:30
0.50 INTRM1, CEMENT CIRC P Work pipe from 11,706' to 11,685' , pull
25K over at 11,685'
Slack off make sure can land out again ,
repeat 3 times only pulling up to 11,685'
once
11,706.0 11,706.0
11/13/2022
04:30
11/13/2022
06:00
1.50 INTRM1, CEMENT RURD P Land out casing on hanger , blow down
top drive rig up cement line to volant tool
Break circ , test lines to 4200 PSI for
CSG test
Circ while rigging up cement lines and
PJSM with cementers
11,706.0 11,706.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 22/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/13/2022
06:00
11/13/2022
11:00
5.00 INTRM1, CEMENT CMNT P Cement 7 5/8" casing as per Halliburton
program
Shut down rig pumps turn over to
Halliburton , flood lines test trips and
test lines to 4000 PSI
Drop 1st bottom wiper plug , pump 57.2
BBLS 12.5 PPG spacer with BMII @ 3
BPM 320 PSI while working pipe 245K
UP 159K DN
Drop 2nd bottom wiper plug , pump 200
BBLS 15.3 PPG cement with BMII
followed by 37 BBLS 15.3 PPG cement
at 3.7 BPM 325 PSI while working pipe
240K UP 165K DN
Drop top plug Halliburton pump 10
BBLS water
Chase with rig pumps , displace with
524 BBLS 9.6 PPG mud at 8 BPM ICP
270 PSI , FCP 1322 PSI , slowing to 3
BPM last 10 BBLS. Bump plugs @ 5204
STKS pressure up from 1322 PSI to
1800 PSI , hold for 5 min. bleed off
check floats good , CIP @ 10:02 AM 11-
13-22
Note: Casing was worked until 380
BBLS into displacement , 80 BBLS of
cement turned corner and loss of down
weight seen , 200K UP 90K DN
Shoe @ 11,706.50' , float collar @
11,615.22'
11,706.0 11,716.0
11/13/2022
11:00
11/13/2022
13:15
2.25 INTRM1, WHDBOP WWSP P Set 7 5/8" pack off as per Cameron
Rep , test to 5000 PSI F/15 min , good
test
0.0 0.0
11/13/2022
13:15
11/13/2022
14:15
1.00 INTRM1, WHDBOP CLEN P Lay down landing joint
Clean clear rig floor of casing running
equipment
0.0 0.0
11/13/2022
14:15
11/13/2022
16:45
2.50 INTRM1, WHDBOP BOPE P Change out upper rams from 7 5/8" to 3
1/2" x 6" VBR
Sim Ops - change saver sub to XT39 ,
off load and clean pits , P/U 4" handling
equipment
0.0 0.0
11/13/2022
16:45
11/13/2022
17:30
0.75 INTRM1, WHDBOP BHAH T Pick up sonic tool , soft break
connection to install batteries and
software down load , lay down to pipe
shed
0.0 0.0
11/13/2022
17:30
11/13/2022
19:00
1.50 INTRM1, WHDBOP BOPE P Make up and set test plug as per
Cameron , fill stack , choke manifold ,
lines with water. Rig up testing
equipment , pump air our of system
Shell test BOP , good
0.0 0.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 23/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/13/2022
19:00
11/13/2022
23:30
4.50 INTRM1, WHDBOP BOPE P All test BOPE with 4" test joint to
250/4,000 PSI for 5 minutes each test
charted. Test annular preventer with 4"
test joint to 250/2,500 psi for 5 minutes
each.
Test 4" Demco kill, choke valves 1 to 14,
3.5" x 6" VBR top and bottom rams,
blind rams, auto IBOP, HCR kill valve,
manual choke valve, IBOP, FOSV to
250 psi low and 4,000 psi high for 5
minutes each. Test remote and hydraulic
chokes to 2,000 psi and observed
pressure drop when opening.
Accumulator drawdown:
ISP = 3000 psi
PSI after functioning = 1500 psi
200 psi rec = 31 seconds
Full system recovery = 152 seconds
4 bottles back up average = 2300 psi
Bottle pre-charge average = 11 @ 1000
psi
Closing times: Annular = 16 seconds,
UPR = 7 seconds, Blind rams = 16
seconds, LPR = 7 seconds, Choke HCR
= 1 seconds, Kill HCR = 1 seconds
Test all gas alarms, PVT gain/loss, Flow
paddle
Witness waived by Guy Cook 11-12-22
@ 17:06 HRS
0.0 0.0
11/13/2022
23:30
11/14/2022
00:00
0.50 INTRM1, WHDBOP BOPE P Rig down BOP test equipment , blow
down lines
0.0 0.0
11/14/2022
00:00
11/14/2022
00:30
0.50 INTRM1, WHDBOP BOPE P Install wear ring as per Cameron 0.0 0.0
11/14/2022
00:30
11/14/2022
02:00
1.50 INTRM1, DRILLOUT PULD P Pick up stand back 7 stands 4" DP via
mousehole , stand back in derrick for
drilling out
0.0 0.0
11/14/2022
02:00
11/14/2022
02:45
0.75 INTRM1, DRILLOUT BHAH P Mobilize BHA components to rig floor ,
get pipe shed ready to pick up BHA
0.0 0.0
11/14/2022
02:45
11/14/2022
06:30
3.75 INTRM1, DRILLOUT BHAH P PJSM - Make up BHA #5 as per SLBG
DD T/377'
0.0 377.0
11/14/2022
06:30
11/14/2022
11:00
4.50 INTRM1, DRILLOUT TRIP P RIH F/377' T/3,490'
Single in the hole with 4" DP from pipe
shed
Filling pipe every 10 STDS
377.0 3,490.0
11/14/2022
11:00
11/14/2022
12:00
1.00 INTRM1, DRILLOUT CIRC P Shallow test MWD tools good test ,
down link turn on Sonicscope for logging
3,490.0 3,490.0
11/14/2022
12:00
11/15/2022
00:00
12.00 INTRM1, DRILLOUT TRIP P RIH F/3,490' T/9,390'
101K DN
Single in the hole with 4" DP from pipe
shed
Filling pipe every 10 STDS
Logging with Sonicscope obtain free
ring pipe @ 1800 FPH max - AVG 491
FPH
3,490.0 9,390.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 24/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/15/2022
00:00
11/15/2022
04:15
4.25 INTRM1, DRILLOUT TRIP P RIH F/9,390' T/11,425'
105K DN
Single in the hole with 4" DP from pipe
shed
Filling pipe every 10 STDS
Logging with Sonicscope @ 1800 FPH
max - AVG 478 FPH
SimOps - prep to load pipe shed with 4"
DP on short side
9,390.0 11,425.0
11/15/2022
04:15
11/15/2022
05:00
0.75 INTRM1, DRILLOUT CIRC P Down link to turn SonicScope off 250
GPM 2400 PSI - blow down top drive
Rig up for casing test , fill lines
11,425.0 11,425.0
11/15/2022
05:00
11/15/2022
06:30
1.50 INTRM1, DRILLOUT PRTS P Test 7 5/8"casing to 4000 PSI
Pump 7.4 BBLS
Bleed Back 7.4 BBLS
Rig down test eqipment - blow down
lines
11,425.0 11,425.0
11/15/2022
06:30
11/15/2022
08:30
2.00 INTRM1, DRILLOUT SLPC P Slip and cut 8 wraps drilling line 11,425.0 11,425.0
11/15/2022
08:30
11/15/2022
09:00
0.50 INTRM1, DRILLOUT SVRG P Service rig 11,425.0 11,425.0
11/15/2022
09:00
11/15/2022
10:15
1.25 INTRM1, DRILLOUT MPDA P Remove trip nipple , install MPD bearing
as per MPD advisor
11,425.0 11,425.0
11/15/2022
10:15
11/15/2022
12:00
1.75 INTRM1, DRILLOUT MPDA P Calibrate MPD system as per MPD
advisor
11,425.0 11,425.0
11/15/2022
12:00
11/15/2022
13:30
1.50 INTRM1, DRILLOUT MPDA P Blow down top drive and MPD system ,
remove MPD bearing , install trip
nipple , hook up lines , fill stack with
mud check for leaks
175K UP
114K DN
11,425.0 11,425.0
11/15/2022
13:30
11/15/2022
14:30
1.00 INTRM1, DRILLOUT TRIP P Circulate and rotate F/11,425' T/11,615'
250 GPM 2330 PSI
40 RPM 8K TQ
125K Rot Wt
Tag cement stringer @ 11,608'
11,425.0 11,615.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 25/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/15/2022
14:30
11/15/2022
16:45
2.25 INTRM1, DRILLOUT DRLG P Drill out cement plugs and float collar ,
clean out cement to shoe , drill out
shoe , clean out rat hole F/11,615'
T/11,717'
250 GPM 2320 PSI
40-80 RPM 8-10.8K TQ
128K Rot Wt
Tag float collar @ 11,615'
Tag shoe @ 11,706'
SimOps @ 15:20 HRS - attempt to
freeze protect the OA , pressure up to
636 PSI , shut DN bleed to 486 PSI in
14 min , pressure up to 610 PSI shut
dowm , bleed to 538 PSI 9 min ,
pressure up to 622 PSI , bleed to 575
PSI in 4 min , pressure up to 671 PSI ,
bleed to 602 in 9 min , pressure up to
690 PSI , bleed to 613 PSI in 15 min ,
bleed off at surface to 100 PSI ,
pressure up to 650 PSI , bleed to 574
PSI in 7 min , pressure up to 647 PSI ,
bleed to 599 PSI in 10 min , pressure up
to 667 PSI , bleed to 629 PSI in 6 min ,
pressure up to 675 PSI keep PSI
bumped up ~670 PSI over 30 min time
frame , pump 3.6 BBLS total - bleed off
OA to ~100 PSI , bleed 1.7 BBLS back ,
pump 1.9 BBLS in OA 18:00 HRS shut
dn rig down for the night
11,615.0 11,717.0
11/15/2022
16:45
11/15/2022
17:15
0.50 INTRM1, DRILLOUT DRLG P Drill 20' new hole F/11,717' T/11,737'
250 GPM 2330 PSI
60 RPM 8-10K TQ
126K Rot Wt
ADT = 3.8 - cement and 20' new hole
11,717.0 11,737.0
11/15/2022
17:15
11/15/2022
18:30
1.25 INTRM1, DRILLOUT CIRC P Circulate and cond mud for FIT/LOT test
250 GPM 2350 PSI
60 RPM 9K TQ
126K Rot Wt
11,737.0 11,737.0
11/15/2022
18:30
11/15/2022
19:00
0.50 INTRM1, DRILLOUT TRIP P Stand 1 Stand back in dewrrick , lay
down single 4" DP F/11,737' T/11,677'
Blow down top drive , flow check static
11,737.0 11,677.0
11/15/2022
19:00
11/15/2022
19:30
0.50 INTRM1, DRILLOUT LOT P Rig up , fill lines for LOT test 11,677.0 11,677.0
11/15/2022
19:30
11/15/2022
20:15
0.75 INTRM1, DRILLOUT LOT P Close rams perform LOT test. Pumped
2.9 BBLS in 1/2 bbl increments with rig
pump to 1560 PSI , noticed sharp
decline in pump PSI , pump .6 more
barrels for 3.5 BBLS total , PSI F/1560
T/1220 while pumping
1560 PSI = 15.4 PPG EMW.
3.5 BBLS pumped
Shut in for 10 minutes and pressure
bled down F/1220 PSI T/920 PSI
Bled off 2.1 BBLS back.
11,677.0 11,677.0
11/15/2022
20:15
11/15/2022
20:45
0.50 INTRM1, DRILLOUT OWFF P Bleed off PSI , open rams
Flow check static
Sim Ops PJSM for displacement
11,677.0 11,677.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 26/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/15/2022
20:45
11/15/2022
21:15
0.50 INTRM1, DRILLOUT LOT P Blow down and rig down lines and test
equipment
11,677.0 11,677.0
11/15/2022
21:15
11/15/2022
23:15
2.00 PROD1, DRILL CIRC P Pick up two singles break circulation
250 GPM 2320 PSI
40 RPM 11K TQ
Perform displacement from 9.6 PPG
LSND T/9.5 PPG Kla-Shield
Pump 35 BBLS high vis spacer followed
by 500 BBLS 9.5 PPG Kla Shield mud
250 GPM 2080 PSI
40 RPM 7K TQ
Work pipe F/11,677' T/11,737' while
displacing until new mud come out bit
then pull up into shoe
11,677.0 11,706.0
11/15/2022
23:15
11/15/2022
23:45
0.50 PROD1, DRILL OWFF P Flow check - static
Sim Ops PJSM pull trip nipple
11,706.0 11,706.0
11/15/2022
23:45
11/16/2022
00:00
0.25 PROD1, DRILL MPDA P Pull up to 11,613' , space out for pulling
trip nipple
11,706.0 11,613.0
11/16/2022
00:00
11/16/2022
01:00
1.00 PROD1, DRILL MPDA P Pull trip nipple , install MPD bearing , fill
lines and circ thru them to check for
leaks
11,613.0 11,613.0
11/16/2022
01:00
11/16/2022
02:00
1.00 PROD1, DRILL TRIP P Wash down F/11613' T/11,737'
250 GPM 2060 PSI
60 RPM 9.5K TQ
Obtain TQ/Drag and SPR before going
into open hole
165K UP
102K DN
126K Rot @ 20 RPM
2 BPM 700 PSI
11,613.0 11,737.0
11/16/2022
02:00
11/16/2022
06:00
4.00 PROD1, DRILL DDRL P Drill 6-1/2" hole F/11,737' T/12,060'
while maintaining 11 PPG EMW on
connections at the 7 5/8" shoe with
MPD.
Control drill at 100 FPH until BHA clear
of shoe
250 GPM
2110 PSI
100 RPM
9K TQ on 7K off
10K WOB
10.88 ECD
P/U - 173K
S/O - 100K
ROT- 131K
350 Units MAX GAS
ADT= 3.13
Bit HRS= 6.93
11,737.0 12,060.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 27/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/16/2022
06:00
11/16/2022
12:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2" hole F/12,060' T/12,462'
while maintaining 11 PPG EMW on
connections at the 7 5/8" shoe with
MPD.
266 GPM
2350 PSI
150 RPM
9K TQ on 6.5K off
10K WOB
10.98 ECD
P/U - 170K
S/O - 95K
ROT- 133K
1019 Units MAX GAS
ADT= 4.27
Bit HRS= 11.2
12,060.0 12,462.0
11/16/2022
12:00
11/16/2022
13:00
1.00 PROD1, DRILL DDRL P Drill 6-1/2" hole F/12,462' T/12,560'
while maintaining 11 PPG EMW on
connections at the 7 5/8" shoe with
MPD.
266 GPM
2380 PSI
150 RPM
8K TQ on 6.5K off
10K WOB
10.99 ECD
P/U - 171K
S/O - 98K
ROT- 133K
512 Units MAX GAS
ADT= 0.63
Bit HRS= 11.83
12,462.0 12,560.0
11/16/2022
13:00
11/16/2022
14:30
1.50 PROD1, DRILL CIRC P Circulate bottoms up for no flow test
265 GPM 2380 PSI
150 RPM 8K TQ
Rot WT 128K
12,560.0 12,560.0
11/16/2022
14:30
11/16/2022
15:00
0.50 PROD1, DRILL OWFF P Perform no flow test with MPD
Trap 350 PSI with MPD Bleed to 310
PSI in 6 MIN
Open chokes 25% bleed to 250 PSI -
close choke no PSI increase
Open choke 25% bleed to 200 PSI -
close choke no PSI increase
Open chokes 25% bleed to 170 PSI -
close choke no PSI increase
Open choke 50% bleed to 25 PSI -
close choke no PSI increase - repeat
again
Open choke 100% observe for flow -
slight flow and drop off to min - flow
check good
12,560.0 12,560.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 28/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/16/2022
15:00
11/17/2022
00:00
9.00 PROD1, DRILL DDRL P Drill 6-1/2" hole F/12,560' T/13,242'
while maintaining 11 PPG EMW on
connections at the 7 5/8" shoe with
MPD.
265 GPM
2440 PSI
150 RPM
8K TQ on 7K off
5-8K WOB
11.30 ECD
P/U - 166K
S/O - 95K
ROT- 128K
512 Units Max Gas
AVG = 76 FPH W/connections
ADT= 7.14
Bit HRS= 19.87
SimOps Freeze protect 10 3/4" x 7 5/8
annulus
Start pumping .25-.5 bpm
Took fluid at 951 PSI @ 1/2 BPM
ICP 1009 PSI @ 1 BPM - FCP @ 1.5
BPM 1234 PSI
Pump 74 bbls (Plus 1.9 bbls from
previous day) = 75.9 BBLS diesel
Montor 20 Min PSI drop F/1143 T/769
Bleed back 1/2 BBL shut in OA with 730
PSI
Total volume diesel left in OA = 75.4
BBLS
12,560.0 13,242.0
11/17/2022
00:00
11/17/2022
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2" hole F/13,242' T/13,884'
while maintaining 11 PPG EMW on
connections at the 7 5/8" shoe with
MPD.
275 GPM
2670 PSI
150 RPM
9K TQ on 7K off
5-8K WOB
11.43 ECD
P/U - 167K
S/O - 93K
ROT- 130K
457 Units Max Gas
AVG = 107 FPH W/connections
ADT= 4.62
Bit HRS= 23.56
13,242.0 13,884.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 29/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/17/2022
06:00
11/17/2022
12:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2" hole F/13,884' T/14,540'
while maintaining 11 PPG EMW on
connections at the 7 5/8" shoe with
MPD.
275 GPM
2730 PSI
150 RPM
9K TQ on 7K off
5-8K WOB
11.50 ECD
P/U - 170K
S/O - 85K
ROT- 130K
545 Units Max Gas
AVG = 109 FPH W/connections
ADT= 4.92
Bit HRS= 28.48
13,884.0 14,540.0
11/17/2022
12:00
11/17/2022
18:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2" hole F/14,540' T/15,146'
while maintaining 11 PPG EMW on
connections at the 7 5/8" shoe with
MPD.
275 GPM
2810 PSI
150 RPM
9K TQ on 7K off
5-7K WOB
11.70 ECD
P/U - 175K
S/O - 85K
ROT- 129K
588 Units Max Gas
AVG = 101 FPH W/connections
ADT= 4.56
Bit HRS= 33.04
14,540.0 15,146.0
11/17/2022
18:00
11/18/2022
00:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2" hole F/15,146' T/15,645'
while maintaining 11 PPG EMW on
connections at the 7 5/8" shoe with
MPD.
275 GPM
2810 PSI
150 RPM
TQ 10K on 8K off
7-8K WOB
11.67 ECD
P/U - 179K
S/O - 87K
ROT- 130K
588 Units Max Gas
AVG = 83 FPH W/connections
ADT= 4.20
Bit HRS= 37.24
15,146.0 15,645.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 30/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/18/2022
00:00
11/18/2022
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2" hole F/15,645' T/16,134'
while maintaining 11 PPG EMW on
connections at the 7 5/8" shoe with
MPD.
275 GPM
2920 PSI
150 RPM
TQ 10.5K on 8K off
7-8K WOB
11.81 ECD
P/U - 185K
S/O - 85K
ROT- 130K
443 Units Max Gas
AVG = 81.5 FPH W/connections
ADT= 4.24
Bit HRS= 41.83
15,645.0 16,074.0
11/18/2022
06:00
11/18/2022
12:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2" hole F/16,134' T/16,619'
while maintaining 11 PPG EMW on
connections at the 7 5/8" shoe with
MPD.
275 GPM
2920 PSI
150 RPM
TQ 10.5K on 8K off
7-8K WOB
11.78 ECD
P/U - 182K
S/O - 79K
ROT- 130K
485 Units Max Gas
AVG = 80.8 FPH W/connections
ADT= 4.08
Bit HRS= 45.91
16,074.0 16,619.0
11/18/2022
12:00
11/18/2022
16:00
4.00 PROD1, DRILL DDRL P Drill 6-1/2" hole F/16,619 T/16,952'
while maintaining 11 PPG EMW on
connections at the 7 5/8" shoe with
MPD. Slowed ROP to 120 FPH to help
recover from deflections
275 GPM
2930 PSI
150 RPM
TQ 11K on 8K off
8-10K WOB
11.78 ECD
P/U - 190K
S/O - N/A
ROT- 126K
503 Units Max Gas
AVG = 83.25 FPH W/connections
ADT= 3.06
Bit HRS= 48.97
16,619.0 16,952.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 31/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/18/2022
16:00
11/18/2022
16:30
0.50 PROD1, DRILL SVRG P Service rig 16,952.0 16,952.0
11/18/2022
16:30
11/18/2022
19:15
2.75 PROD1, DRILL RGRP T Shakers went down , when #2 was
started back up all 3 went down , got #1
and #3 running , trouble shoot #2 shaker
Circ and rotate F/16,952' T/16,827'
150 - 250 GPM 1380/2570 PSI
80-120 RPM 8.5K TQ
ROT - 121K
11.44 ECD
Circ thru degasser while hot work in pits
Decide to drill with 2 shakers while
looking for parts
16,952.0 16,952.0
11/18/2022
19:15
11/18/2022
19:45
0.50 PROD1, DRILL WASH P Wash and ream F/16,827' T/16,952'
275 GPM 2950 PSI
100 RPM 8K TQ
11.65 ECD
16,952.0 16,952.0
11/18/2022
19:45
11/18/2022
22:30
2.75 PROD1, DRILL DDRL P Drill 6-1/2" hole F/16,952' T/17,188'
while maintaining 11 PPG EMW on
connections at the 7 5/8" shoe with
MPD. Slowed ROP to 120 FPH to help
recover from deflections
275 GPM
2992 PSI
150 RPM
TQ 11.5K on 8K off
8-10K WOB
11.83 ECD
P/U - 190K
S/O - N/A
ROT- 126K
306 Units Max Gas
AVG = 85.8 FPH W/connections
ADT= 2.15
Bit HRS= 51.12
16,952.0 17,188.0
11/18/2022
22:30
11/18/2022
23:30
1.00 PROD1, DRILL RGRP T Work pipe F/17,188' T/17,091'
while installing shaker overload switch
275 GPM 2990 PSI
80 RPM 8.5 TQ
Circ thru degasser while hot work in pits
17,188.0 17,188.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 32/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/18/2022
23:30
11/19/2022
00:00
0.50 PROD1, DRILL DDRL P Drill 6-1/2" hole F/17,188' T/17,232'
while maintaining 11 PPG EMW on
connections at the 7 5/8" shoe with
MPD. Slowed ROP to 120 FPH to help
recover from deflections
275 GPM
2980 PSI
150 RPM
TQ 11K on 9K off
8-10K WOB
11.84 ECD
P/U - 190K
S/O - N/A
ROT- 127K
360 Units Max Gas
ADT= .32
Bit HRS= 51.44
17,188.0 17,232.0
11/19/2022
00:00
11/19/2022
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2" hole F/17,232' T/17,758'
while maintaining 11 PPG EMW on
connections at the 7 5/8" shoe with
MPD. Slowed ROP to 120 FPH to help
recover from deflections
275 GPM
3050 PSI
150 RPM
TQ 11K on 9K off
8-10K WOB
11.83 ECD
P/U - 195K
S/O - N/A
ROT- 130K
429 Units Max Gas
AVG = 87.6 FPH W/connections
ADT= 4.86
Bit HRS= 56.30
17,232.0 17,758.0
11/19/2022
06:00
11/19/2022
12:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2" hole F/17,758' T/18,318'
while maintaining 11 PPG EMW on
connections at the 7 5/8" shoe with
MPD. Slowed ROP to 120 FPH to help
recover from deflections
275 GPM
3080 PSI
150 RPM
TQ 11.5K on 9K off
8-10K WOB
11.92 ECD
P/U - 190K
S/O - N/A
ROT- 128K
489 Units Max Gas
AVG = 93.3 FPH W/connections
ADT= 4.77
Bit HRS= 61.07
17,758.0 18,318.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 33/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/19/2022
12:00
11/19/2022
18:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2" hole F/18,318' T/18,888'
while maintaining 11 PPG EMW on
connections at the 7 5/8" shoe with
MPD. Slowed ROP to 120 FPH to help
recover from deflections
275 GPM
3010 PSI
150 RPM
TQ 12K on 10K off
8-10K WOB
11.98 ECD
P/U - 192K
S/O - N/A
ROT- 130K
1285 Units Max Gas
AVG = 95 FPH W/connections
ADT= 4.84
Bit HRS= 65.91
18,318.0 18,888.0
11/19/2022
18:00
11/19/2022
21:00
3.00 PROD1, DRILL DDRL P Drill 6-1/2" hole F/18,888' T/19,148'
while maintaining 11 PPG EMW on
connections at the 7 5/8" shoe with
MPD. Slowed ROP to 120 FPH to help
recover from deflections
275 GPM
3170 PSI
150 RPM
TQ 12.5K on 10K off
8-10K WOB
11.83 ECD
P/U - 199K
S/O - N/A
ROT- 128K
1172 Units Max Gas
AVG = 86.6 FPH W/connections
ADT= 2.19
Bit HRS= 68.10
18,888.0 19,148.0
11/19/2022
21:00
11/20/2022
00:00
3.00 PROD1, DRILL DDRL T Lose comms with power drive , trouble
shoot , follow anti jamming procedure
Rotate at different RPM's 100 - 150
Pump @ 275/290 GPM 2910/3150 PSI
Pump 42 BBL low vis sweep followed by
43 BBL Hi Vis sweep , no indication of
power drive un jamming or comms with
tool
Decide to drill ahead watching MWD
INC to see if power drive is holding INC
19,148.0 19,148.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 34/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/20/2022
00:00
11/20/2022
02:30
2.50 PROD1, DRILL DDRL P Drill 6-1/2" hole F/19,148' T/19,267'
while maintaining 11 PPG EMW on
connections at the 7 5/8" shoe with
MPD. Slowed ROP to 120 FPH to help
recover from deflections watching MWD
INC to see if power drive was holding
INC
275 GPM
3190 PSI
150 RPM
TQ 12.5K on 10K off
5-8K WOB
11.93 ECD
P/U - 199K
S/O - N/A
ROT- 128K
467 Units Max Gas
ADT= 1.74
Bit HRS= 69.84
19,148.0 19,267.0
11/20/2022
02:30
11/20/2022
04:00
1.50 PROD1, DRILL CIRC T CBU at 275 GPM 2940 PSI , 100 RPM
9.8K TQ ECD F/11.92 T/11.81
Stand a stand back to 19,172'
19,267.0 19,172.0
11/20/2022
04:00
11/20/2022
05:45
1.75 PROD1, DRILL OWFF T Blow DN top drive , perform no flow test
with MPD
380 PSI ISIP
Open choke 50% F/15 seconds monitor
5 min 257 PSI
Open choke 50% F/15 seconds monitor
5 min 224 PSI
Open choke 50% F/30 seconds monitor
5 min 196 PSI
Open choke 50% F/1 min monitor 5 min
174 PSI
Open choke 50% F/2 min monitor 5 min
151 PSI
Open choke 50% F/3 min monitor 5 min
130 PSI
Open choke 50% F/3 min monitor 5 min
126 PSI
Open choke 50% F/5 min monitor 5 min
118 PSI
Leave chokes closed for 15 min total
PSI build to 154 PSI
Open chokes 50% F/5 min monitor 5
min 115 PSI
Pit gain 9 BBLS
19,172.0 19,172.0
11/20/2022
05:45
11/20/2022
08:45
3.00 PROD1, DRILL CIRC T CBU x2 standing one stand back per
B/U F/19,176' T/18,982'
275 GPM 2780 PSI
70 RPM 9.5K TQ
11.61 ECD
19,172.0 18,982.0
11/20/2022
08:45
11/20/2022
12:00
3.25 PROD1, DRILL BKRM T BROOH F/18,982' T/18,321'
275 GPM 2750 PSI
70 RPM
9K TQ
11.58 ECD
18,982.0 19,321.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 35/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/20/2022
12:00
11/20/2022
20:30
8.50 PROD1, DRILL BKRM T BROOH F/18,321' T/15,867'
275 GPM 2830 PSI
70 RPM
8-10K TQ
11.26 ECD
186K UP
71K DN
126K ROT
Checking for slack off weight at 17,570' ,
16,537' , 16,291' , 15,849' regain slack
off weight
19,321.0 15,867.0
11/20/2022
20:30
11/20/2022
21:45
1.25 PROD1, DRILL CIRC T CBU
275 GPM 2840 PSI
70 RPM 8-9K TQ
ECD F/11.23 T/11.21
Stand a stand back T/15,772'
15,867.0 15,772.0
11/20/2022
21:45
11/20/2022
22:45
1.00 PROD1, DRILL SMPD T SOOH F/15,772' T/15,430' , as per
beyond stripping schedule
Pull 25K over at 15,430' , slack off
15,439' make up top drive
185-200K UP
71K DN @ 15,849'
Holding 10.3 PPG EMW at shoe with
MPD
15,772.0 15,430.0
11/20/2022
22:45
11/21/2022
00:00
1.25 PROD1, DRILL CIRC T BROOH F/15,430 T/15,358'
Circ at 275 GPM 2850 PSI 70 RPM 9K
TQ
While circulating 1 1/2 times open hole
volume monitoring ECD's , TQ and
pump PSI
Stand a stand back after 1 1/2 open
hole volumes
Cont BROOH T/15,360' observe PSI ,
TQ and ECD increase T/12.7 PPG ,
slack off to T/15,394' pull slow watching
pump PSI , TQ an d ECD's trends while
CBU to clean up cuttings bed
Lose 12 BBLS to hole
15,430.0 15,358.0
11/21/2022
00:00
11/21/2022
12:00
12.00 PROD1, DRILL BKRM T BROOH F/15,358' T/15,000'
275 GPM 2700 PSI
70 RPM 8-10K TQ
11.27 ECD
315 units gas on bottoms up from
pressure effent @ 15,360'
Work thru tight spot's at 15,355' ,
15,215' , 15,180' , 15,164' as ECD and
pump preusse would allow
15,358.0 15,000.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 36/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/21/2022
12:00
11/22/2022
00:00
12.00 PROD1, DRILL BKRM T BROOH F/15,000' T/14,490'
275 GPM 2710 PSI
70 - 120 RPM 7-10K TQ
11.43 - 11.18 ECD
At 14,896' observe ECD and pressure
event lost 46 BBLS , ECD's climb to
13.55 , drop down T/14,922' regain full
returns , RIH 1 stand T/14,994' stage up
pumps and rotary contuine to BROOH
as hole condtions allow
420 units gas on bottoms up from
pressure effent @ 14,896'
Work thru tight spots @ 14,840' ,
14,712' , 14,690' , 14,675' as ECD's and
pump pressure would allow
15,000.0 14,490.0
11/22/2022
00:00
11/22/2022
09:15
9.25 PROD1, DRILL BKRM T BROOH F/14,490' T/13,751' , as hole
conditions allow
275 GPM 2440 PSI
80 - 120 RPM 6-8K TQ
11.12 ECD
Work thru tight spots as ECD's and
pump pressure would allow
Adjusting RPM's for shocks and vibes
on PeriScope for ECD monitoring
14,490.0 13,751.0
11/22/2022
09:15
11/22/2022
10:30
1.25 PROD1, DRILL CIRC T Drop down from tight spot at 13,751'
T/13,885'
Wash down at 275 GPM 2620 PSI 120
RPM 8K TQ
13,751.0 13,885.0
11/22/2022
10:30
11/22/2022
12:00
1.50 PROD1, DRILL CIRC T CBU 1 1/2 times at
285 GPM 2770 PSI
160 RPM 10.5 K TQ
125K Rot wt
13,885.0 13,885.0
11/22/2022
12:00
11/22/2022
12:15
0.25 PROD1, DRILL CIRC T Cont. to CBU 1 1/2 times at
285 GPM 2770 PSI
160 RPM 10.5 K TQ
125K Rot wt
13,885.0 13,885.0
11/22/2022
12:15
11/23/2022
00:00
11.75 PROD1, DRILL BKRM T BROOH F/13,885' T/13,396' , as hole
conditions allow
275 GPM 2710 PSI
150 RPM 8-10K TQ
11.25 ECD
Work thru tight spots at 13,662' ,
13,628' , 13,610' , 13,581' , 13,440' ,
13,420' , 13,400' as ECD's , pump
pressure and return flow would allow
13,885.0 13,396.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 37/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/23/2022
00:00
11/23/2022
12:00
12.00 PROD1, DRILL BKRM T BROOH F/13,396' T/12,650' , as hole
conditions allow
275 GPM 2550 PSI
150 - 120 RPM 8-10K TQ
11.22 ECD
Work thru tight spots as ECD's , pump
pressure and return flow would allow
13,396.0 12,650.0
11/23/2022
12:00
11/23/2022
22:00
10.00 PROD1, DRILL BKRM T BROOH F/12,650' T/11,895' , as hole
conditions allow
275 GPM 2550 PSI
150 RPM 8-10K TQ
11.17 ECD
Work thru tight spots as ECD's , pump
pressure and return flow would allow
Pull BHA up into casing shoe @ 200
GPM 1640 PSI with MPD PSI at 135 for
11 PPG ECD
165K UP , see 5-10K drag pulling BHA
into shoe
12,650.0 11,706.0
11/23/2022
22:00
11/24/2022
00:00
2.00 PROD1, DRILL CIRC T Work pipe F/11,700' T/11,610' , while
CBU up inside 7 5/8" casing
250 GPM 2180 PSI - MPD 108 PSI
11.1 ECD
Perform DFIT with MPD to 11.51 ECD
for weight up
Step up MPD PSI F/108 T/246 PSI
monitor for 15 min , lose 1 BBL
Open MPD choke stage up rotary to 70
RPM
11,706.0 11,610.0
11/24/2022
00:00
11/24/2022
04:00
4.00 PROD1, DRILL CIRC T Work pipe F/11,700' T/11,614' , weight
up from 9.5 PPG to 10 PPG in two S/S
circulations , circulate a total of 14471
STKS
Circ at 250 GPM 2170 PSI ICP , 2155
PSI FCP @ 249 GPM 11.42 ECD
70 RPM 5-6K TQ
Obtain new slow pump rates
11,700.0 11,614.0
11/24/2022
04:00
11/24/2022
08:00
4.00 PROD1, DRILL OWFF T Blow down top drive
Perform no flow test with MPD
Bleed down in stages of 3 starting at
253 PSI
To 58 PSI final 5 minute monitor
Open up to atmosphere monitor until
static , then for 15 min after
11,614.0 11,614.0
11/24/2022
08:00
11/24/2022
12:00
4.00 PROD1, DRILL SMPD T SOOH F/11,614' T/8,028'
With MPD holding 400 PSI dynamic and
270 PSI static
11,614.0 8,028.0
11/24/2022
12:00
11/24/2022
16:45
4.75 PROD1, DRILL SMPD T SOOH F/8,028' T/2,946'
With MPD holding 400 PSI dynamic and
270 PSI static
8,028.0 2,946.0
11/24/2022
16:45
11/24/2022
17:15
0.50 PROD1, DRILL SVRG T Service drawworks , top drive and iron
roughneck
2,946.0 2,946.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 38/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/24/2022
17:15
11/24/2022
20:00
2.75 PROD1, DRILL SMPD T SOOH F/2,946' T/405'
With MPD holding 400 PSI dynamic and
270 PSI static
Calc hole fill for trip to 405' = 66.7 BBLS
Actual hole fill = 98.4 BBLS
2,946.0 405.0
11/24/2022
20:00
11/25/2022
00:00
4.00 PROD1, DRILL OWFF T Flow check , 265 PSI back PSI , open
MPD choke Beyond flow out to zero in
15 min
Open to 2" drain at mezzaninemonitor
flow out every 15 - 30 min start at 20:45
hrs 4.3 BBL/HR down to 2.5 BBL/HR
405.0 405.0
11/25/2022
00:00
11/25/2022
08:00
8.00 PROD1, DRILL OWFF T Flow check monitoring flow out every 30
min , slowing down
Started at 2.5 BBL/HR slowing to 2
BBL/HR
Bleed back total of 32.1 BBLS
405.0 405.0
11/25/2022
08:00
11/25/2022
12:00
4.00 PROD1, DRILL SMPD T RIH F/405' T/3,681' Holding 140 PSI
staic and 70 PSI dynamic with MPD
405.0 3,681.0
11/25/2022
12:00
11/25/2022
17:00
5.00 PROD1, DRILL OWFF T Conduct no flow test , ICP =119 PSI ,
FSP = 33 PSI , 3.8 BBLS bleed back ,
monitor shut in PSI from 33 to 109 PSI
3,681.0 3,681.0
11/25/2022
17:00
11/25/2022
18:00
1.00 PROD1, DRILL CIRC T From 3,681' T/3,298' , pump and lay in
40 BBL Hi Vis pill while pumping at 2
BPM 397 PSI
100K UP
3,681.0 3,298.0
11/25/2022
18:00
11/25/2022
21:30
3.50 PROD1, DRILL CIRC T Weight up from 10 PPG to 10.8 PPG
200 GPM 910 ICP , 1080 FCP
Pump a total of 8850 STKS
3,298.0 3,298.0
11/25/2022
21:30
11/25/2022
22:45
1.25 PROD1, DRILL OWFF T Shut down pumps , observe beyond
flow out go to zero , flow check in pits
slowing down , open up to 2" on
mezzadene , observe for flow startt out
at .86 BBLS/HR , go static in 20 min ,
montior for 30 min after static
3,298.0 3,298.0
11/25/2022
22:45
11/26/2022
00:00
1.25 PROD1, DRILL SMPD T SOOH F/3,298' T/2,643'
As per Beyond schedule , holding 80 -
60 PSI dynamic and 28 PSI static
3,298.0 2,643.0
11/26/2022
00:00
11/26/2022
03:00
3.00 PROD1, DRILL SMPD T SOOH F/2,643' T/405'
As per Beyond schedule , holding 80 -
45 PSI dynamic and 28 PSI static
Calc fill = 16.8 BBLS
Act fill = 21.1 BBLS
2,643.0 405.0
11/26/2022
03:00
11/26/2022
10:00
7.00 PROD1, DRILL OWFF T Montior for flow , shut down back side
pump , watch beyond flow out go to
zero , monitor in pits for 20 minutes flow
dropping off gain 3.3 BBLS in 10 min
nothing in last 5 min , close MPD choke
monitor PSI F/24 min no gain in 10 min ,
monitor flow out in cellar start out at 1.5
BPH dropping to .74 BPH in 1 HR cont ,
notice slight flow increase to .81 BPH ,
shut in monitor against MPD choke PSI
at 22 build to 39 PSI - Open up bleed off
PSI , monitor flow out , mud weight 10.4
PPG and high vis , 10.8 mud cap
slipping down hole.
405.0 405.0
11/26/2022
10:00
11/26/2022
12:00
2.00 PROD1, DRILL SMPD T Strip in hole as per MPD schedule
adjusting back pressure as needed for
hole fill
F/405' T/1,133'
80K DN
405.0 1,133.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 39/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/26/2022
12:00
11/26/2022
17:30
5.50 PROD1, DRILL SMPD T Strip in hole as per MPD schedule
adjusting back pressure as needed for
hole fill
F/1,133' T/4,048''
90K DN
1,133.0 4,048.0
11/26/2022
17:30
11/26/2022
19:00
1.50 PROD1, DRILL CIRC T Circ to remove hi vis pill and 10.8 PPG
mud with 10 PPG
200 GPM 900 PSI
4,048.0 4,048.0
11/26/2022
19:00
11/27/2022
00:00
5.00 PROD1, DRILL SMPD T Strip in hole as per MPD schedule
adjusting back pressure as needed for
hole fill
F/4,048' T/7,749'
100K DN
4,048.0 7,749.0
11/27/2022
00:00
11/27/2022
05:45
5.75 PROD1, DRILL SMPD T Strip in hole as per MPD schedule
adjusting back pressure as needed for
hole fill
F/7,749' T/11,705'
100K DN
Calc displacment = 67.20 BBLS
Act displacment = 67 BBLS
7,749.0 11,705.0
11/27/2022
05:45
11/27/2022
07:00
1.25 PROD1, DRILL CIRC T CBU @ 200 GPM 1600 PSI 60 RPM
6.5K TQ
11,705.0 11,705.0
11/27/2022
07:00
11/27/2022
14:00
7.00 PROD1, DRILL CIRC T Weight up from 10 PPG to 10.5 PPG in
two stages , slowing pumps as needed
for losses
220 GPM 1670 PSI ICP 60 RPM 6K TQ
85 GPM 1040 PSI FCP 60 RPM 6K TQ
Lost 20 BBLS while weighting up
11,705.0 11,645.0
11/27/2022
14:00
11/27/2022
17:00
3.00 PROD1, DRILL OWFF T Perform no flow test with MPD
Start at 103 PSI open choke , close , pit
gain .4 BBLS , PSI to 44
Open to 2" in mezzanine , flow out start
@ .32 BPH , go static in 1 HR , monitor
for 30 min
11,645.0 11,645.0
11/27/2022
17:00
11/28/2022
00:00
7.00 PROD1, DRILL SMPD T SOOH with MPD as per beyond
stripping schedule holding an 10.5 PPG
EMW at shoe
F/11,645' T/7,981'
135K UP
11,645.0 7,981.0
11/28/2022
00:00
11/28/2022
08:45
8.75 PROD1, DRILL SMPD T SOOH with MPD as per beyond
stripping schedule holding an 10.5 PPG
EMW at shoe
F/7,981' T/471'
75K UP
7,981.0 471.0
11/28/2022
08:45
11/28/2022
09:30
0.75 PROD1, DRILL OWFF T Conduct no flow test with MPD , closed
choke zero PSI build , open to 2" at
RCD head , well static monitor for 30
min
471.0 471.0
11/28/2022
09:30
11/28/2022
10:30
1.00 PROD1, DRILL MPDA T Pull MPD bearing and install trip nipple ,
fill with mud check for leaks , no leaks
471.0 471.0
11/28/2022
10:30
11/28/2022
11:30
1.00 PROD1, DRILL TRIP T POOH F/471' T/377' - stand back
HWDP
Actual fill = 79.2 BBLS
Calc fill = 68.5 BBLS
471.0 377.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 40/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/28/2022
11:30
11/28/2022
15:00
3.50 PROD1, DRILL BHAH T Lay down BHA as per DD 377.0 0.0
11/28/2022
15:00
11/28/2022
16:00
1.00 PROD1, WHDBOP WWWH T Clean clear rig floor , make up stack
washer , flush stack lay down same ,
blow down top drive
0.0 0.0
11/28/2022
16:00
11/28/2022
17:00
1.00 PROD1, WHDBOP BOPE P Drain stack , make up wear ring running
tool , pull wear ring
0.0 0.0
11/28/2022
17:00
11/28/2022
19:15
2.25 PROD1, WHDBOP BOPE P Set test plug , R/U BOP test equipment ,
fill stack , work air out of system , shell
test BOP good
0.0 0.0
11/28/2022
19:15
11/29/2022
00:00
4.75 PROD1, WHDBOP BOPE P Test BOPE with 4" test joint to 250 PSI
low 4,000 PSI for 5 minutes each test
charted. Test annular preventer with 4"
test joint to 250 psi low and 2,500 psi
high for 5 minutes each.
Test 4" Demco kill, choke valves 1,2 , 5-
13 , 3.5" x 6" VBR top rams ,
upper/lower IBOP, HCR kill valve, dart
valve , FOSV to 250 psi low and 4,000
psi high for 5 minutes each.
Witness waived by Brian Bixby 11-28-22
@ 16:44 HRS
0.0 0.0
11/29/2022
00:00
11/29/2022
03:00
3.00 PROD1, WHDBOP BOPE P Test BOPE with 4" and 4-1/2" test joints
all test to 250 PSI low 4,000 PSI for 5
minutes each test charted. Test upper
and lower 3 1/2" x 6" VBR with 4 1/2"
test joint
Test choke valves 3 ,4 and14, 3.5" x 6"
VBR bottom rams, blind rams, HCR/
manual choke valve. Test remote and
hydraulic chokes to 2,000 psi and
observed pressure drop when opening.
Accumulator drawdown:
ISP = 3000 psi
PSI after functioning = 1450 psi
200 psi rec = 24 seconds
Full system recovery = 155 seconds
4 bottles back up average = 2300 psi
Bottle pre-charge average = 11 @ 1000
psi
Closing times: Annular = 14 seconds,
UPR = 9 seconds, Blind rams = 11
seconds, LPR = 8 seconds, Choke HCR
= 1 seconds, Kill HCR = 1 seconds
Test all gas alarms, PVT gain/loss, Flow
paddle
Witness waived by Brian Bixby 11-28-22
@ 16:44 HRS
0.0 0.0
11/29/2022
03:00
11/29/2022
05:30
2.50 PROD1, DRILL BOPE P Rig down BOP test equipment , blow
down lines , pull test plug , install wear
ring
0.0 0.0
11/29/2022
05:30
11/29/2022
08:30
3.00 PROD1, DRILL BHAH T Mobilize BHA components to rig floor -
spot source by beaver slide
PJSM - Make up BHA as per SLBG DD
T/355'
0.0 355.0
11/29/2022
08:30
11/29/2022
11:30
3.00 PROD1, DRILL TRIP T RIH F/355' T/1,710'
90K UP
83K DN
355.0 1,710.0
11/29/2022
11:30
11/29/2022
13:00
1.50 PROD1, DRILL MPDA T Pull trip nipple , install MPD element 1,710.0 1,710.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 41/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/29/2022
13:00
11/29/2022
14:00
1.00 PROD1, DRILL CIRC T Shallow test MWD tools @ 228 GPM
1030 PSI
Blow down top drive
1,710.0 1,710.0
11/29/2022
14:00
11/29/2022
15:30
1.50 PROD1, DRILL SLPC T Slip cut drilling line 9 wraps , service
rig , calibrate block height
1,710.0 1,710.0
11/29/2022
15:30
11/29/2022
21:00
5.50 PROD1, DRILL TRIP T RIH F/1710' T/5,543'
105K UP
93K DN
Fill pipe every 20 stands
1,710.0 5,543.0
11/29/2022
21:00
11/30/2022
00:00
3.00 PROD1, DRILL CIRC T Displace 10.5 PPG mud with 9.5 PPG
mud
Stage pumps up T/250 GPM 1420 PSI
50 RPM 2K TQ
110K Rot Wt
5,543.0 5,543.0
11/30/2022
00:00
11/30/2022
00:45
0.75 PROD1, DRILL CIRC T Finish circ 9.5 mud , line up MPD , blow
down top drive
250 GPM 1430 PSI
50 RPM 2K
5,543.0 5,543.0
11/30/2022
00:45
11/30/2022
09:30
8.75 PROD1, DRILL SMPD T SIH as per beyond schedule F/5,543'
T/11,685' - holding 10.5 EMW with MPD
at shoe
98K DN
Actual displacmentl = 58.1 BBLS
Calc displacment = 67.2 BBLS
Fill pipe every 20 stands
5,543.0 11,685.0
11/30/2022
09:30
11/30/2022
10:15
0.75 PROD1, DRILL CIRC T Displace 10.5 PPG mud with 9.5 PPG
mud
Staging pumps up from 80 GPM 700
PSI to 100 GPM 830 PSI , 60 RPM 5.5K
TQ
Holding 10.5 EMW at shoe with MPD
11,685.0 11,685.0
11/30/2022
10:15
11/30/2022
10:45
0.50 PROD1, DRILL OWFF T Notice 8 BBL gain in pits , notified Co
Man , shut down , closed MPD choke ,
monitor PSI F/181 to 171 PSI , zero gas
at shakers , confirmed aired up mud ,
line up on MGS
11,685.0 11,685.0
11/30/2022
10:45
11/30/2022
15:00
4.25 PROD1, DRILL CIRC T Cont displacing to 9.5 PPG mud ,
holding 10.5 EMW at shoe with MPD
Stage up pumps from
110 GPM 730 PSI
220 GPM 1650 PSI
60 RPM 5.5K TQ
153K UP
102K DN
125K ROT
11,685.0 11,685.0
11/30/2022
15:00
11/30/2022
21:45
6.75 PROD1, DRILL SMPD T SIH F/11,685' T/14,620'
Holding 10.5 EMW at shoe with MPD
Work thru tight spots at 13,142' , 13,195'
@ 2 BPM , 13,216' @ 2 BPM
Attempt to work thru tight spot at 14,620'
at 2 BPM
11,685.0 14,620.0
11/30/2022
21:45
11/30/2022
23:00
1.25 PROD1, DRILL REAM T Wash ream down F/14,620' T/14,777'
Max speed while wash/ream 360 FPH
for logging purposes
Stage up to 220 GPM 1990 PSI , 120
RPM 8K TQ
120K Rot Wt
ECD @ 11.94 at start
14,620.0 14,777.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 42/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/30/2022
23:00
12/1/2022
00:00
1.00 PROD1, DRILL CIRC T Pump pressure increase from 1875 to
2300 PSI , torque stall out at 12K at
14,777' , start losing returns , pick up
establish returns , stage pumps up to
200 GPM 1580 PSI rotary to 120 RPM
7.5K TQ
Circ heavy mud out - max weight seen
out was 10.3 PPG , taking returns thru
MGS
Max gas 403 units
Lost 28 BBLS from pack off
14,777.0 14,777.0
12/1/2022
00:00
12/1/2022
01:00
1.00 PROD1, DRILL CIRC T Cont stage up pumps to 250 GPM 2100
PSI , 140 RPM 8 K TQ
ECD 11.41
Taking returns thru MGS
14,777.0 14,777.0
12/1/2022
01:00
12/1/2022
05:45
4.75 PROD1, DRILL REAM T Cont wash ream F/14,777' T/15,607'
250 GPM 2050 PSI
120 RPM 8K TQ
11.18 ECD
Taking returns thru MGS and back down
flowline at 14,990' @ 02:30 hrs.
436 units gas back on bottoms up after
pack off
Holding 11 PPG EMW at shoe on
connections
Logging at 360 FPH max
14,777.0 15,607.0
12/1/2022
05:45
12/1/2022
09:00
3.25 PROD1, DRILL REAM T Cont wash ream F/15,607' T/15,745'
working through restriction.
250-275 GPM 2050-2390 PSI
120 - 150 RPM 7-9K TQ
11.18 ECD
P/U 177K
S/O 85K
ROT 124K
Holding 11 PPG EMW at shoe on
connections
Logging at 360 FPH max
15,607.0 15,745.0
12/1/2022
09:00
12/1/2022
12:00
3.00 PROD1, DRILL REAM T Cont wash ream F/15,745' T/16,131.
275 GPM 2420 PSI
120 RPM 8K TQ
11.26 ECD
P/U 177K
S/O 85K
ROT 124K
Holding 11 PPG EMW at shoe on
connections
Logging at 360 FPH max
15,745.0 16,131.0
12/1/2022
12:00
12/1/2022
18:00
6.00 PROD1, DRILL REAM T Cont wash ream F/16,131' T/17,259'.
275 GPM 2420 PSI
120 RPM 8K TQ
11.23 ECD
P/U 177K
S/O 85K
ROT 124K
Holding 11 PPG EMW at shoe on
connections
Logging at 360 FPH max
16,131.0 17,259.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 43/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/1/2022
18:00
12/2/2022
00:00
6.00 PROD1, DRILL REAM T Cont wash ream F/17,259' T/18,140'.
Experienced minimal pack offs at
17,989', 18,025', 18,097', 18,140' and
worked through each until good.
275 GPM 2650 PSI
120 RPM 9K TQ
11.27 ECD
P/U 177K
S/O 85K
ROT 124K
Holding 11 PPG EMW at shoe on
connections
Logging at 360 FPH max
17,259.0 18,140.0
12/2/2022
00:00
12/2/2022
02:00
2.00 PROD1, DRILL REAM T Cont wash ream F/18,140' T/18,267'.
Experienced minimal pack off at 18,140'
and worked through until good.
275 GPM 2650 PSI
120 RPM 9K TQ
11.48 ECD
P/U 177K
S/O 85K
ROT 120K
Holding 11 PPG EMW at shoe on
connections
Logging at 360 FPH max
18,140.0 18,267.0
12/2/2022
02:00
12/2/2022
06:00
4.00 PROD1, DRILL REAM T Cont wash ream F/18,267' T/18,600'.
Problem areas at 18,373', 18,405',
18,575-18,600' work through until good.
275 GPM 2650 PSI
120-150 RPM 9-11K TQ
11.56 ECD
P/U 177K
S/O 85K
ROT 124K
Holding 11 PPG EMW at shoe on
connections
Logging at 360 FPH on 1st half stand
(45') and 180 FPH on 2nd half stand
(45').
18,267.0 18,600.0
12/2/2022
06:00
12/2/2022
12:00
6.00 PROD1, DRILL REAM T Cont wash ream F/18,600' T/18,892'.
Problem areas at 18,600 -18,675',
18,800' work through until good.
275 GPM 2720 PSI
120-170 RPM 9-11.5K TQ
11.56 ECD
P/U 192K
ROT 124K
Holding 11 PPG EMW at shoe on
connections
Logging at 360 FPH on 1st half stand
(45') and 180 FPH on 2nd half stand
(45').
18,600.0 18,892.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 44/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/2/2022
12:00
12/2/2022
16:00
4.00 PROD1, DRILL REAM T Cont wash ream F/18,892' T/19,244'.
Work through problem areas at 19,010',
19,053', 19,162', 19,200' work through
until good.
275 GPM 2720 PSI
120-170 RPM 9-11.5K TQ
12.18 ECD
P/U 195K
ROT 124K
Holding 11 PPG EMW at shoe on
connections
Logging at 360 FPH on 1st half stand
(45') and 180 FPH on 2nd half stand
(45').
18,892.0 19,244.0
12/2/2022
16:00
12/2/2022
17:00
1.00 PROD1, DRILL FIT T Perform Dynamic FIT at 19,230' MD /
5,225' TVD, trap psi F/99 to 315 psi,
11.26 ppg - 12.04 ppg ECD. 5 bbls 9.5
ppg mud lost to formation.
19,244.0 19,244.0
12/2/2022
17:00
12/2/2022
18:15
1.25 PROD1, DRILL REAM T Cont wash ream F/19,244' T/19,269' at
bottom.
275 GPM 2720 PSI
120-170 RPM 9-11.5K TQ
12.18 ECD
P/U 195K
ROT 124K
Increased to holding 12.0 PPG EMW at
shoe on connections and dynamic 170
psi.
Logging at 180 FPH on 2nd half stand
(45').
Max Gas 4807 units from problem area
at ~19,200', no mud cut.
19,244.0 19,269.0
12/2/2022
18:15
12/3/2022
00:00
5.75 PROD1, DRILL DDRL P Drill 6-1/2" hole F/19,269' T/19,717'
while maintaining 12 PPG EMW at shoe
on connections and dynamic 170 psi
with MPD. Control ROP to 120 FPH to
help recover from deflections.
275 GPM
2800 PSI
175 RPM
TQ 12K on 9.8K off
11K WOB
12.15 ECD
P/U - 198K
S/O - N/A
ROT- 126K
587 Units Max Gas
AVG = 77.9 FPH W/connections
ADT= 4.14
Bit HRS= 4.14
Jars 73.98 hrs
19,269.0 19,717.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 45/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/3/2022
00:00
12/3/2022
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2" hole F/19,717' T/20,272'
while maintaining 12 PPG EMW at shoe
on connections and dynamic 170 psi
with MPD. Control ROP to 120 FPH to
help recover from deflections.
275 GPM
3010 PSI
170 RPM
TQ 12.5K on 10K off
10K WOB
12.18 ECD
P/U - 200K
S/O - N/A
ROT- 129K
838 Units Max Gas
AVG = 92.5 FPH W/connections
ADT= 4.98
Bit HRS= 9.12
Jars 78.96 hrs
19,717.0 20,272.0
12/3/2022
06:00
12/3/2022
12:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2" hole F/20,272' T/20,783'
while maintaining 12 PPG EMW at shoe
on connections and dynamic 170 psi
with MPD. Control ROP to 120 FPH to
help recover from deflections.
275 GPM
3120 PSI
175 RPM
TQ 12.8K on 10.5K off
10K WOB
12.47 ECD
P/U - 217K
S/O - N/A
ROT- 140K
688 Units Max Gas
AVG = 85.1 FPH W/connections
ADT= 4.51
Bit HRS= 13.3
Jars 83.47 hrs
20,272.0 20,783.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 46/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/3/2022
12:00
12/3/2022
18:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2" hole F/20,783' T/21,331'
while maintaining 12 PPG EMW at shoe
on connections and dynamic 170 psi,
reduced dynamic to 125 psi at 20,950'
with MPD. Control ROP to 120 FPH to
help recover from deflections.
Note: At 12:15 hrs Centrifuge feed pump
went down (front shaft bearing). After
Centrifuge failure reduced dynamic from
170 to 125 psi at 13:45 hrs due to ECD
slowly increasing with increasing MW.
275 GPM
3260 PSI
175 RPM
TQ 12.8K on 10.5K off
10K WOB
12.58 ECD
P/U - 230K
S/O - N/A
ROT- 135K
521 Units Max Gas
AVG = 91.6 FPH W/connections
ADT= 4.71
Bit HRS= 18.3
Jars 88.1 hrs
20,783.0 21,331.0
12/3/2022
18:00
12/4/2022
00:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2" hole F/21,331' T/21,852'
while maintaining 12 PPG EMW at shoe
on connections and dynamic 125 psi
with MPD. Control ROP to 120 FPH to
help recover from deflections.
275 GPM
3230 PSI
175 RPM
TQ 14K on 11K off
10K WOB
12.61 ECD
P/U - 234K
S/O - N/A
ROT- 138K
521 Units Max Gas
AVG = 86.8 FPH W/connections
ADT= 4.35
Bit HRS= 22.69
Jars 92.5 hrs
21,331.0 21,852.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 47/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/4/2022
00:00
12/4/2022
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2" hole F/21,852' T/22,420'
while maintaining 12 PPG EMW at shoe
on connections and dynamic 125 psi
with MPD. Control ROP to 120 FPH to
help recover from deflections. Note: At
21,940' decreased dynamic from 125
psi to 95 psi as per Beyond modeling.
275 GPM
3210 PSI
175 RPM
TQ 14.4K on 12K off
8K WOB
12.37 ECD
P/U - 243K
ROT- 147K
862 Units Max Gas
AVG = 94.6 FPH W/connections
ADT= 4.81
Bit HRS= 27.5
Jars 97.4 hrs
21,852.0 22,420.0
12/4/2022
06:00
12/4/2022
12:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2" hole F/22,420' T/22,967'
while maintaining 12 PPG EMW at shoe
on connections and dynamic 125 psi
with MPD. Control ROP to 120 FPH to
help recover from deflections. Note: At
22,420' increased dynamic from 95 psi
to 115 psi as per Beyond modeling.
275 GPM
3130PSI
175 RPM
TQ 14.8K on 12K off
12K WOB
12.49 ECD
P/U - 255K
S/O - N/A
ROT- 155K
680 Units Max Gas
AVG = 91.1 FPH W/connections
ADT= 4.58
Bit HRS= 32.08
Jars 101.9 hrs
22,420.0 22,967.0
12/4/2022
12:00
12/4/2022
12:15
0.25 PROD1, DRILL DDRL P Drill 6-1/2" hole F/22,967' T/22,990'
while maintaining 12 PPG EMW at shoe
on connections and dynamic 125 psi
with MPD. Control ROP to 120 FPH to
help recover from deflections. Note: At
22,790' increased dynamic from 115 psi
to 125 psi as per Beyond modeling.
275 GPM
3210 PSI
175 RPM
TQ 14.4K on 12K off
8K WOB
12.37 ECD
P/U - 243K
S/O - N/A
ROT- 147K
22,967.0 22,990.0
12/4/2022
12:15
12/4/2022
13:30
1.25 PROD1, DRILL DDRL T Troubleshoot PowerDrive due to loosing
communications. Performed anti-jam
procedure and tools responded.
22,990.0 22,990.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 48/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/4/2022
13:30
12/4/2022
18:00
4.50 PROD1, DRILL DDRL P Drill 6-1/2" hole F/22,990' T/23,326'
while maintaining 12 PPG EMW at shoe
on connections and dynamic 125 psi
with MPD. Control ROP to 120 FPH to
help recover from deflections.
275 GPM
3590 PSI
175 RPM
TQ 14.4K on 12K off
8K WOB
12.37 ECD
P/U - 243K
S/O - N/A
ROT- 153K
862 Units Max Gas
AVG = 74.6 FPH W/connections
ADT= 3.92
Bit HRS= 36
Jars 105.8 hrs
22,990.0 23,326.0
12/4/2022
18:00
12/5/2022
00:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2" hole F/23,326' T/23,770' at
TD while maintaining 12 PPG EMW at
shoe on connections and dynamic 125
psi with MPD. Control ROP to 120 FPH
to help recover from deflections.
275 GPM
3790 PSI
175 RPM
TQ 16K on 12K off
12K WOB
12.93 ECD
P/U - 243K
S/O - N/A
ROT- 153K
584 Units Max Gas
AVG = 74 FPH W/connections
ADT= 4.48
Bit HRS= 40.4
Jars 110.3 hrs
23,326.0 23,770.0
12/5/2022
00:00
12/5/2022
02:00
2.00 PROD1, TRIPCAS CIRC P Circulate bottoms up at TD while
rotating and reciprocating maintaining
12.0 ppg EMW with MPD.
275 GPM
3800 PSI
150 RPM
TQ 13.5K on 12K off
12.95 ECD
P/U - 243K
S/O - N/A
ROT- 153K
292 Units Max Gas
23,770.0 23,770.0
12/5/2022
02:00
12/5/2022
02:15
0.25 PROD1, TRIPCAS OWFF P Blow down top drive and line up on pill
pit #1 for MPD drawdown.
23,770.0 23,770.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 49/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/5/2022
02:15
12/5/2022
04:15
2.00 PROD1, TRIPCAS OWFF P Perform MPD drawdown from 12.0 ppg
to 10.8 ppg EMW at shoe (5,130'TVD)
in 0.2 ppg stages at 5 minutes each
interval while rotating 15 rpm. Pumped
at 200 gpm with most consistent
pressure. Worked pipe in between
intervals.
Note: Changed to pit #1 due to mud
being aerated in pill pit #1 (smaller pit).
12.0 ppg = 680 psi - lost 0.5 bbl
11.8 ppg = 626 psi - lost 0.4 bbl
11.6 ppg = 572 psi - lost 0.3 bbl
11.4 ppg = 518 psi - static
11.2 ppg = 464 psi - gain 0.2 bbl
11.0 ppg = 410 psi - gain 0.5 bbl
10.8 ppg = 356 psi - static
23,770.0 23,770.0
12/5/2022
04:15
12/5/2022
07:30
3.25 PROD1, TRIPCAS CIRC P Circulate bottoms up at TD while
rotating and reciprocating maintaining
12.0 ppg EMW with MPD.
275 GPM
3730 PSI
150 RPM
TQ 13K on 12K off
12.55 ECD
P/U - 243K
S/O - N/A
ROT- 153K
Max Gas 184 units
23,770.0 23,770.0
12/5/2022
07:30
12/5/2022
07:45
0.25 PROD1, TRIPCAS CIRC P Make up 5" FOSV with crossovers,
drop1.75" OD stainless steel ball to
open well commander.
23,770.0 23,770.0
12/5/2022
07:45
12/5/2022
10:00
2.25 PROD1, TRIPCAS CIRC P Open WellCommander as per SLB DD.
ICP = 250 gpm at 3,000 psi, FCP 67
gpm at 1270 psi, 60 rpm, 12k TQ.
Unable to seat ball at these parameters.
Increased to 130 gpm at 1660 psi, 10
rpm for 5 minutes.Observed pressure
increase to 1800 psi. Staged up
pressure in 200 psi increments holding
30 sec each. Observed tool shearing at
2500 psi (normal shear pressure is 1500
psi +/- 25%).
23,770.0 23,680.0
12/5/2022
10:00
12/5/2022
12:00
2.00 PROD1, TRIPCAS CIRC P Circulate 2 bottoms up at 23,680'
pumping though WellCommander at 350
gpm with 3500 psi, 150 rpm, 13K TQ
maintaining 12.0 ppg EMW with MPD.
23,680.0 23,680.0
12/5/2022
12:00
12/5/2022
13:00
1.00 PROD1, TRIPCAS CIRC P Circulate 1 bottoms up at 23,680'
pumping though WellCommander at 350
gpm with 3500 psi, 150 rpm, 13K TQ
maintaining 12.0 ppg EMW with MPD.
23,680.0 23,680.0
12/5/2022
13:00
12/5/2022
14:30
1.50 PROD1, TRIPCAS CIRC P Drop 1.75" OD stainless steel closing
ball, pump down at 250 gpm, 2100 psi,
40 rpm, 12K TQ,ROW 150K. Reduced
to 84 gpm, observed pressure increase
to 2600 psi. Verify tool closed by
increasing to 275 gpm and comparing
pressures and rates, monitored for
MWD signal confirming tool closed.
23,680.0 23,705.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 50/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/5/2022
14:30
12/5/2022
18:00
3.50 PROD1, TRIPCAS BKRM P BROOH F/23,705' T/23,058' maintaining
12.0 ppg EMW with MPD.
275 GPM
3720 PSI
150 RPM
13K TQ
150K ROT
23,705.0 23,058.0
12/5/2022
18:00
12/6/2022
00:00
6.00 PROD1, TRIPCAS BKRM P BROOH F/23,058' T/22,133' maintaining
12.0 ppg EMW with MPD.
275 GPM
3573 PSI
150 RPM
13K TQ
143K ROT
12.45 ECD
23,058.0 22,133.0
12/6/2022
00:00
12/6/2022
08:30
8.50 PROD1, TRIPCAS BKRM P BROOH F/22,133' T/21,020' maintaining
12.0 ppg EMW with MPD. Progress
getting slower due to increasing ECD.
275 GPM
3420 PSI
150 RPM
12.5K TQ
142K ROT
13.09 ECD
22,133.0 21,020.0
12/6/2022
08:30
12/6/2022
09:45
1.25 PROD1, TRIPCAS CIRC P Drop 1.75" SS ball to open Well
Commander as per SLB DD. ICP = 250
gpm at 2,860 psi, FCP 89 gpm at 1380
psi, 40 rpm, 10k TQ. Staged up
pressure in 500 psi increments holding
30 sec each to 3,500 psi. Tool did not
shift open.
21,020.0 21,020.0
12/6/2022
09:45
12/6/2022
11:30
1.75 PROD1, TRIPCAS CIRC T Cycled pumps 13 times bleeding off
pressure at surface between cycles and
staging up from 3,000 psi up to 4,200
psi. Held pressure at 4,200 psi and
reduced MPD dynamic from 680 psi to
300 psi. Observed tool opening and
pressure dropped to 1000 psi and
observed returns to shakers. Note:
Normal shear pressure is 1500 psi +/-
25%.
21,020.0 21,020.0
12/6/2022
11:30
12/6/2022
16:00
4.50 PROD1, TRIPCAS CIRC P Stage pump rate up to 350 gpm and
circulate. Note: Geologist comments -
There was a small increase in cuttings
volume over the shakers consisting of
sandstone and siltstone with minor
elongated or platey cuttings habit. Max
Gas 210 units.
350 GPM
3100 PSI
120 RPM
10K TQ
142K ROT
21,020.0 21,020.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 51/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/6/2022
16:00
12/6/2022
18:30
2.50 PROD1, TRIPCAS CIRC P Stage pump rate up to 436 gpm and
circulate. Note: Geologist comments -
Increase in cuttings, light to moderate
volume then decreased back down to
very minimal amount, increase
observed ~2000+ strokes from
calculated bottoms up from circ at 436
GPM, 80% formation 20% mud product,
no changes in formation still
siltstone/sandstone with ~10-20%
bigger siltstone cuttings and minor
platey-tabular cuttings habit
436 GPM
4090 PSI
120 RPM
10K TQ
129K ROT
21,020.0 21,020.0
12/6/2022
18:30
12/6/2022
20:15
1.75 PROD1, TRIPCAS CIRC T Continue circualting and reciproicating
while taking on 11.3 ppg mud in pits.
275 GPM
2160 PSI
120 RPM
10K TQ
129K ROT
21,020.0 21,020.0
12/6/2022
20:15
12/6/2022
21:00
0.75 PROD1, TRIPCAS CIRC T Displace string down to Well
Commander (161' above bit) with 11.3
ppg mud maintaining 11.2 ppg EMW on
shoe.
275 GPM
2160 PSI
120 RPM
10K TQ
129K ROT
21,020.0 21,020.0
12/6/2022
21:00
12/7/2022
00:00
3.00 PROD1, TRIPCAS SMPD P SOOH F/21,020' T/19,720' holding 11.2
EMW on shoe with MPD racking back
HWDP stands to first stand 4" drill pipe.
Note: Performed weekly BOP function
test using 4" drill pipe on upper and
lower VBR's, Annular, and functioned
HCR's.
21,020.0 19,720.0
12/7/2022
00:00
12/7/2022
06:00
6.00 PROD1, TRIPCAS STRP P SOOH F/19,720' T/15,762' holding 11.2
EMW on shoe with MPD racking back 4"
drill pipe.
19,720.0 15,762.0
12/7/2022
06:00
12/7/2022
12:00
6.00 PROD1, TRIPCAS STRP P SOOH F/15,762' T/11,685' holding 11.2
EMW on shoe with MPD racking back 4"
drill pipe.
15,762.0 11,685.0
12/7/2022
12:00
12/7/2022
14:30
2.50 PROD1, TRIPCAS CIRC P Rig up TIW and XO's, Displace 11.3 ppg
mud out of drill string with 9.5 ppg mud
as per Beyond MPD schedule.
SIMOPS: L/D 11 stands 4" drill pipe in
mousehole.
275 GPM
1320 PSI
10 RPM
6K TQ
117K ROT
11,685.0 11,685.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 52/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/7/2022
14:30
12/7/2022
18:30
4.00 PROD1, TRIPCAS CIRC P Line both pumps on hole. Stage pump
rate up to 475 gpm and circulate.
Minimal cuttings at shakers on bottoms
up. SIMOPS: Preparing pits with 11.3
ppg mud for displacement.
475 GPM
2480 PSI
150 RPM
5K TQ
124K ROT
11,685.0 11,685.0
12/7/2022
18:30
12/8/2022
00:00
5.50 PROD1, TRIPCAS CIRC P Line up #1 pump back on injection line
and #2 pump on hole. Displace 9.5 ppg
with 11.3 ppg mud as per Beyond MPD
rollover schedule.
SIMOPS: L/D 9 stands 4" drill pipe in
mousehole.
275 GPM Initial - 100 GPM Final
1040 PSI Initial - 691 psi Final
20 RPM
5K TQ
123K ROT
11,685.0 11,685.0
12/8/2022
00:00
12/8/2022
01:30
1.50 PROD1, TRIPCAS CIRC P Continue circulating until mud weight
11.3 ppg in/out.
100 GPM - 125 GPM Final
825 PSI Initial - 910 psi Final
150 RPM
6K TQ
126K ROT
11,685.0 11,685.0
12/8/2022
01:30
12/8/2022
02:30
1.00 PROD1, TRIPCAS OWFF P OWFF, Shut in on Beyond choke and
monitored pressure. Pressure increased
to 24 psi in 10 minutes and remained at
24 psi for 20 minutes. Opened choke
and bled off to zero. Monitored for 10
minutes at MPD manifold through open
valve. Returns decreased from initial
pencil flow to a drip.
11,685.0 11,685.0
12/8/2022
02:30
12/8/2022
02:45
0.25 PROD1, TRIPCAS CIRC P Establish circulation and take SPR's
with 11.3 ppg mud. Blow down TDS.
11,685.0 11,685.0
12/8/2022
02:45
12/8/2022
12:00
9.25 PROD1, TRIPCAS STRP P SOOH F/11,685' T/4,982' as per
Beyond MPD schedule racking back 4"
drill pipe.
11,685.0 4,982.0
12/8/2022
12:00
12/8/2022
17:00
5.00 PROD1, TRIPCAS STRP P SOOH F/4,982' T/2,178' as per Beyond
MPD schedule racking back 4" drill pipe.
4,982.0 2,178.0
12/8/2022
17:00
12/8/2022
18:30
1.50 PROD1, TRIPCAS OWFF P OWFF, Perform exhale test. ISP 54 psi,
FSP 27 psi. 0.8 bbl bled back. Monitor
at 2" port at RCD housing - well static.
2,178.0 2,178.0
12/8/2022
18:30
12/8/2022
21:15
2.75 PROD1, TRIPCAS SMPD P SOOH F/2,178' T/455' as per Beyond
MPD schedule racking back 4" drill pipe.
2,178.0 445.0
12/8/2022
21:15
12/8/2022
21:45
0.50 PROD1, TRIPCAS OWFF P OWFF, well static. 445.0 445.0
12/8/2022
21:45
12/8/2022
23:00
1.25 PROD1, TRIPCAS MPDA P Pull MPD bearing and install trip nipple ,
fill with mud check for leaks , no leaks
445.0 445.0
12/8/2022
23:00
12/9/2022
00:00
1.00 PROD1, TRIPCAS BHAH P L/D production BHA to 78' as per
Schlumberger DD.
445.0 78.0
12/9/2022
00:00
12/9/2022
02:00
2.00 PROD1, TRIPCAS BHAH P Complete L/D production BHA as per
Schlumberger DD. Bit Grade: 0-0-NO-A-
X-IN-NO-TD
78.0 0.0
12/9/2022
02:00
12/9/2022
03:15
1.25 PROD1, TRIPCAS CLEN P Clean and clear rig floor excess tools. 0.0 0.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 53/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/9/2022
03:15
12/9/2022
03:45
0.50 PROD1, WHDBOP WWWH P Drain BOP, M/U BOP wash tool and
flush BOP at 375 gpm, 80 psi with
water.
0.0 0.0
12/9/2022
03:45
12/9/2022
05:00
1.25 PROD1, WHDBOP WWWH P B/D top drive, R/D stack wash tool and
retrieve wear bushing as per Cameron
rep. Note: No visable wear observed.
0.0 0.0
12/9/2022
05:00
12/9/2022
07:30
2.50 PROD1, WHDBOP BOPE P Make up and set test plug as per
Cameron, fill BOP with water and
perform shell test to 2,500 psi. Change
out leaking ball valve on test pump.
0.0 36.0
12/9/2022
07:30
12/9/2022
13:30
6.00 PROD1, WHDBOP BOPE P All test BOPE with 4-1/2" & 4" test joints
to 250/4,000 PSI for 5 minutes each test
charted. Test annular preventer with 4-
1/2" & 4" test joints to 250/2,500 psi for
5 minutes each.
Test 4" Demco kill, choke valves 1 to 14,
3.5" x 6" VBR top and bottom rams,
blind rams, auto IBOP, HCR kill & choke
valves and manual valves, IBOP, FOSV
to 250 psi low and 4,000 psi high for 5
minutes each. Test remote and hydraulic
chokes to 1,500 psi and observed
pressure drop when opening.
Accumulator drawdown:
ISP = 2940 psi
PSI after functioning = 1550 psi
200 psi rec = 28 seconds
Full system recovery = 145 seconds
4 bottles back up average = 2400 psi
Bottle pre-charge average = 11 @ 1000
psi
Closing times: Annular = 17 seconds,
UPR = 7 seconds, Blind rams = 16
seconds, LPR = 7 seconds, Choke HCR
= 1 seconds, Kill HCR = 1 seconds
Test all gas alarms, PVT gain/loss, Flow
paddle
Note: FP on Choke HCR valve.
Witness waived by Austin McLeod 12-8-
22 @ 06:56 HRS
36.0 36.0
12/9/2022
13:30
12/9/2022
14:30
1.00 PROD1, WHDBOP WWWH P R/D test equipment, pull test plug, B/D
choke and kill lines and line up choke
manifold.
36.0 0.0
12/9/2022
14:30
12/9/2022
14:45
0.25 PROD1, WHDBOP WWWH P Set wear bushing as per Cameron rep. 0.0 0.0
12/9/2022
14:45
12/9/2022
17:00
2.25 COMPZN, CASING RURD P R/U to run 4-1/2" lower completion. 0.0 0.0
12/9/2022
17:00
12/10/2022
00:00
7.00 COMPZN, CASING PUTB P PJSM - RIH with 4 1/2" HYD 563 floated
lower completion as per detail T/5,013'
70K DN WT
0.0 5,013.0
12/10/2022
00:00
12/10/2022
07:30
7.50 COMPZN, CASING PULD P PJSM - RIH with 4 1/2" HYD 563 floated
lower completion as per detail F/5,013'
T/12,187.
71K DN WT
5,013.0 12,187.0
12/10/2022
07:30
12/10/2022
08:15
0.75 COMPZN, CASING PUTB P Make up Baker Flexlock liner hanger
assy w/ZXP packer, Install RS packoff
seal nipple as per Baker rep F/12,187'
T/12,233' , crossover to 4" drill pipe and
run 1 stand 4" drill pipe.
71K DN WT
12,187.0 12,331.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 54/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/10/2022
08:15
12/10/2022
09:00
0.75 COMPZN, CASING MPDA P Remove trip nipple and install RCD
bearing.
12,331.0 12,394.0
12/10/2022
09:00
12/10/2022
12:00
3.00 COMPZN, CASING RUNL P SIH on 4" drill pipe F/12,394' T/14,219'
as per Beyond surge schedule. Top
filling each stand with 9.7 ppg mud.
81K DN Wt
12,394.0 14,219.0
12/10/2022
12:00
12/10/2022
18:00
6.00 COMPZN, CASING RUNL P SIH on 4" drill pipe F/14,219' T/17,789'
as per Beyond surge schedule. Top
filling each stand with 9.7 ppg mud.
81K DN Wt
14,219.0 17,789.0
12/10/2022
18:00
12/11/2022
00:00
6.00 COMPZN, CASING RUNL P SIH on 4" drill pipe & 4" HWDP F/17,789
T/20,086' (lost ability to slack off at
20,067') as per Beyond surge schedule.
Started rotating at 20 rpm, 7K TQ at
20,067'. Top filling each stand with 9.7
ppg mud.
Note: Contacted WSG on plan forward
due to not being able to slack off string.
Discussed plan with WSG and Supt and
adivsed to rotate at 20 rpm and 3-4K TQ
above free rotating torque.
76K DN WT
160K UP WT
124K ROT
17,789.0 20,086.0
12/11/2022
00:00
12/11/2022
04:45
4.75 COMPZN, CASING RUNL P SIH on 4" drill pipe & 4" HWDP
F/20,086' T/21,550' as per Beyond
surge schedule rotating at 20 rpm, 8K
TQ. Top filling each stand with 9.7 ppg
mud.
75K DN WT
165K UP WT
125K ROT
20,086.0 21,550.0
12/11/2022
04:45
12/11/2022
06:30
1.75 COMPZN, CASING CIRC P Work string while discussing plan
forward with office and preparing mud
pits.
87K DN WT
197K UP WT
21,550.0 21,550.0
12/11/2022
06:30
12/11/2022
12:00
5.50 COMPZN, CASING RUNL P Continue SIH on 4" drill pipe & 4"
HWDP F/21,550' T/23,075' as per
Beyond surge schedule rotating at 20
rpm, 9K TQ. Top filling each stand with
9.7 ppg mud.
127K ROT
21,550.0 23,075.0
12/11/2022
12:00
12/11/2022
15:00
3.00 COMPZN, CASING RUNL P Continue SIH on 4" drill pipe & 4"
HWDP F/23,075' T/23,756' at setting
depth as per Beyond surge schedule
rotating at 20 rpm, 9K TQ. Top filling
each stand with 9.7 ppg mud. Obtained
parameters as per Baker for setting and
releasing hanger and packer.
218K UP WT
90K DN WT
135K ROT
23,075.0 23,756.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 55/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/11/2022
15:00
12/11/2022
23:00
8.00 COMPZN, CASING CIRC P Space out liner hanger assy. Line up
with 9.7 ppg Kla-Shield mud. Pressured
up to 1,500 psi and did not rupture
flotation sub. Pressured up second time
to 2,178 psi and ruptured 3,500 psi
floatation sub. Continue pumping 99
bbls 9.7 ppg mud at 3.5 bpm filling 4.5"
liner when caught pressure, staged rate
from 0.5 bpm at 1,011 psi to 3 bpm at
1,912 psi. Continue pumping 9.7 ppg
mud at 3 bpm circulating out air using
drillers method as per Beyond rollover
schedule. ICP: 1912 psi. FCP: 1898 psi.
Max Gas: 505 units (after poor boy
degasser).
23,756.0 23,756.0
12/11/2022
23:00
12/12/2022
00:00
1.00 COMPZN, CASING PACK P Pump 10 bbls 9.7 ppg hi-vis, drop
1.125" phenolic ball to shift WIV.
Displace with 10 bbls 9.7 ppg hi-vis.
Continue pumping 9.7 ppg mud at 3
bpm with 1,310 psi.
23,756.0 23,756.0
12/12/2022
00:00
12/12/2022
01:30
1.50 COMPZN, CASING PACK P Continue pumping 9.7 ppg mud at 3
bpm with 1310 psi, decreased to 1 bpm
at 930 psi to seat ball with 2900 stks.
Pressured up to 1,200 psi to close WIV.
23,756.0 23,756.0
12/12/2022
01:30
12/12/2022
03:00
1.50 COMPZN, CASING PACK P Pressure up to set Baker Flex Lock
Liner Hanger as per Baker rep. S/O to
70k, pressured up to 3,850 psi, bled off
pressure and P/U to 220K to verify
running tool released (not released),
S/O to 70K and pressured up to 4,300
psi, bled off pressure, P/U to 196K and
confirmed free travel, tool released and
rotating dog sub above TOL. Set ZXP
Liner Top Packer per Baker Rep. Good
indication observed packer set when
S/O while rotating dog sub,50k-80k
weight applied 4 times.
TOL @ 11,531', Shoe @ 23,756'.
23,756.0 23,756.0
12/12/2022
03:00
12/12/2022
03:30
0.50 COMPZN, CASING PRTS P Closed top VBR rams. Pressure test
with 9.7 ppg mud ZXP Liner Top Packer
to 3,850 psi for 15 minutes - good test
(charted test). Bled off pressure and
opened top VBR's.
23,756.0 23,756.0
12/12/2022
03:30
12/12/2022
03:45
0.25 COMPZN, WELLPR OWFF P OWFF - static. Lined up to circulate 9.7
ppg over the top of the hole with charge
pump #1 on pit #3 through MPD.
23,756.0 23,756.0
12/12/2022
03:45
12/12/2022
10:15
6.50 COMPZN, WELLPR PULD P L/D drill pipe out of derrick. SIMOPS:
Cleaning pits, wait on brine trucks and
load 9.0 ppg brine to pits
23,756.0 23,756.0
12/12/2022
10:15
12/12/2022
12:00
1.75 COMPZN, WELLPR CIRC P PJSM. Displacing wellbore from 9.7 ppg
mud to 9.0 ppg Cl brine at 210 gpm,
1.310 psi at 11,536' (end of slick stinger
- 5' inside tie back)
23,756.0 11,536.0
12/12/2022
12:00
12/12/2022
14:00
2.00 COMPZN, WELLPR CIRC P Continue displacing wellbore from 9.7
ppg mud to 9.0 ppg Cl brine at 210-273
gpm, 1.460-1,810 psi at 11,536' (end of
slick stinger - 5' inside tie back). Shut
down trapping 300 psi with MPD for
negative test as per Beyond.
11,536.0 11,536.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 56/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/12/2022
14:00
12/12/2022
15:30
1.50 COMPZN, WELLPR OWFF P OWFF, Perform negative flow test, trap
300 psi, stepped down in 50 psi
increments's and held monitoring
pressure. No pressure build up
observed. Opened to flow line, slight
fluid return, opened at RCD manifold
and observed. Had trickle and
decreased to static - no flow.
11,536.0 11,536.0
12/12/2022
15:30
12/12/2022
16:00
0.50 COMPZN, WELLPR RURD P Blowdown top drive, mud pumps, MPD
choke system , injection line from
pumps and poor boy degasser.
11,536.0 11,536.0
12/12/2022
16:00
12/12/2022
17:30
1.50 COMPZN, WELLPR MPDA P Pull RCD bearing and install trip nipple. 11,536.0 11,536.0
12/12/2022
17:30
12/13/2022
00:00
6.50 COMPZN, WELLPR PULD P POOH layng down 4" HWDP and DP
F/11,536' T/8,746 to pipe shed.
11,536.0 8,746.0
12/13/2022
00:00
12/13/2022
06:45
6.75 COMPZN, WELLPR PULD P POOH layng down 4" DP F/8,746' to
Baker running tools to pipe shed.
8,746.0 30.0
12/13/2022
06:45
12/13/2022
07:15
0.50 COMPZN, WELLPR BHAH P L/D Baker running tools as per Baker
rep. All tools recovered.
30.0 0.0
12/13/2022
07:15
12/13/2022
12:00
4.75 COMPZN, WELLPR PULD P Laying down 4" drill pipe out of derrick in
mousehole.
0.0 0.0
12/13/2022
12:00
12/13/2022
15:00
3.00 COMPZN, WELLPR PULD P Continue laying down 4" drill pipe out of
derrick in mousehole.
0.0 0.0
12/13/2022
15:00
12/13/2022
15:30
0.50 COMPZN, WELLPR WWWH P M/U wear bushing running tool, pull
wear bushing as per Cameron rep.
0.0 0.0
12/13/2022
15:30
12/13/2022
16:30
1.00 COMPZN, WELLPR WWWH P R/U to wash BOP with wash tool. Flush
with 9.0 ppg NaCl at 336 gpm , R/D
wash tool.
0.0 0.0
12/13/2022
16:30
12/13/2022
17:00
0.50 COMPZN, WELLPR CLEN P Clean and clear excess tools and
equipment from rig floor.
0.0 0.0
12/13/2022
17:00
12/14/2022
00:00
7.00 COMPZN, RPCOMP RURD P P/U Halliburton TEC wire, Access ESP
PEL spool, Doyon casing tools to run 4-
1/2" upper completion. Install sheave in
derrick with Access ESP cable. Ready
all tools and equipment to run 4-1/2"
upper completion.
0.0 0.0
12/14/2022
00:00
12/14/2022
00:30
0.50 COMPZN, RPCOMP SFTY P PJSM with all 3rd party companies and
rig crew.
0.0 0.0
12/14/2022
00:30
12/14/2022
03:15
2.75 COMPZN, RPCOMP RCST P RIH with 4 1/2" HYD 563 upper
completion as per detail T/1,211'. Top
filling every joint with 9.0 ppg NaCL.
Cable clamps ran on every collar.
75K DN WT
0.0 1,211.0
12/14/2022
03:15
12/14/2022
05:15
2.00 COMPZN, RPCOMP RCST P M/U Access PLE cable to Annular
Connection Port. Top filling every joint
with 9.0 ppg NaCL. Cable clamps ran on
every collar.
Meg cable to 1000 volts, A-G=90 G
Ohms, B-G=80 G Ohms, C-G=120 G
Ohms, Good.
1,211.0 1,211.0
12/14/2022
05:15
12/14/2022
09:00
3.75 COMPZN, RPCOMP RCST P Splice Access PLE cable to Summit
ESP cable at mid-joint joint # 28.
Meg ESP cable before splice to 1000
volts. A-G=80.0 G Ohms, B-G=100.0 G
Ohms, C-G=120.0 G Ohms
Meg ESP cable after splice to 1000
volts. A-G=200.0 G Ohms, B-G=200.0 G
Ohms, C-G=200.0 G Ohms
1,211.0 1,230.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 57/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/14/2022
09:00
12/14/2022
09:30
0.50 COMPZN, RPCOMP RCST P RIH with 4 1/2" HYD 563 upper
completion as per detail F/1,230'
T/1,450'. Top filling every joint with 9.0
ppg NaCL. Cable clamps ran on every
collar.
75K DN WT
1,230.0 1,450.0
12/14/2022
09:30
12/14/2022
10:30
1.00 COMPZN, RPCOMP RCST P M/U Halliburton DHG mandrel per
Halliburton procedure. Test 10,000 psi
for 10 minutes - good test. Monitoring
continous surface reading on DHG.
1,450.0 1,450.0
12/14/2022
10:30
12/14/2022
12:00
1.50 COMPZN, RPCOMP RCST P RIH with 4 1/2" HYD 563 upper
completion as per detail F/1,450'
T/2,245'. Top filling every joint with 9.0
ppg NaCL. Cable clamps ran on every
collar.
Monitoring continous surface reading on
DHG.
84K DN WT
1,450.0 2,245.0
12/14/2022
12:00
12/14/2022
14:30
2.50 COMPZN, RPCOMP RCST P RIH with 4 1/2" HYD 563 upper
completion as per detail F/2,245'
T/3,536'. Top filling every joint with 9.0
ppg NaCL. Cable clamps ran on every
collar.
Monitoring continous surface reading on
DHG.
Meg ESP cable to 1000 volts. A-G=12.0
G Ohms, B-G=8.6 G Ohms, C-G=11.0 G
Ohms @ 2699' Jt #60.
84K DN WT
2,245.0 3,536.0
12/14/2022
14:30
12/14/2022
16:15
1.75 COMPZN, RPCOMP SLKL P R/U Halliburton slick line and drift 4 1/2"
completion with 3.83" drift T/ 2,268'
WLM from surface. Monitoring continous
surface reading on DHG.
Meg ESP cable to 1000 volts. A-G=12.5
G Ohms, B-G=9.2 G Ohms, C-G=11.0 G
Ohms @ 3,526' Jt #80.
3,536.0 3,536.0
12/14/2022
16:15
12/14/2022
20:30
4.25 COMPZN, RPCOMP RCST P RIH with 4 1/2" HYD 563 upper
completion as per detail F/3,536'
T/5,623'. Top filling every joint with 9.0
ppg NaCL. Cable clamps ran on every
collar.
Monitoring continous surface reading on
DHG.
Meg ESP cable to 1000 volts. A-G=12.5
G Ohms, B-G=9.2 G Ohms, C-G=11.0 G
Ohms @ 4,354' @ Jt #100.
Meg ESP cable to 1000 volts. A-G=12.0
G Ohms, B-G=8.5 G Ohms, C-G=11.0 G
Ohms @ 5,210' @ Jt #120.
97K DN WT
3,536.0 5,623.0
12/14/2022
20:30
12/14/2022
21:30
1.00 COMPZN, RPCOMP SLKL P R/U Halliburton slick line and drift 4 1/2"
completion with 3.83" drift T/ 2,100'
WLM from surface. Monitoring continous
surface reading on DHG.
Meg ESP cable to 1000 volts. A-G=12.5
G Ohms, B-G=9.2 G Ohms, C-G=11.0 G
Ohms @ 5,623' Jt #130.
5,623.0 5,623.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 58/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/14/2022
21:30
12/15/2022
00:00
2.50 COMPZN, RPCOMP RCST P RIH with 4 1/2" HYD 563 upper
completion as per detail F/5,623'
T/7,012'. Top filling every joint with 9.0
ppg NaCL. Cable clamps ran on every
collar.
Monitoring continous surface reading on
DHG.
Meg ESP cable to 1000 volts. A-G=10.5
G Ohms, B-G=6.9 G Ohms, C-G=9.6 G
Ohms @ 6,453' Jt #150.
96K DN WT
5,623.0 7,012.0
12/15/2022
00:00
12/15/2022
01:00
1.00 COMPZN, RPCOMP RCST P RIH with 4 1/2" HYD 563 upper
completion as per detail F/7,012'
T/7,695'. Top filling every joint with 9.0
ppg NaCL. Cable clamps ran on every
collar.
Monitoring continous surface reading on
DHG.
95K DN WT
7,012.0 7,695.0
12/15/2022
01:00
12/15/2022
02:30
1.50 COMPZN, RPCOMP SLKL P R/U Halliburton slick line and drift 4 1/2"
completion with 3.83" drift T/ 2,200'
WLM from surface. Monitoring continous
surface reading on DHG.
Meg ESP cable to 1000 volts. A-G=9.4
G Ohms, B-G=6.1 G Ohms, C-G=8.2 G
Ohms @ 7,695' Jt #180.
7,693.0 7,693.0
12/15/2022
02:30
12/15/2022
04:45
2.25 COMPZN, RPCOMP RCST P RIH with 4 1/2" HYD 563 upper
completion as per detail F/7,693'
T/9,004' (end of reel #1 cable). Top
filling every joint with 9.0 ppg NaCL.
Cable clamps ran on every collar.
Monitoring continous surface reading on
DHG.
Meg ESP cable to 1000 volts. A-G= 7.6
G Ohms, B-G= 5.4 G Ohms, C-G= 6.6
G Ohms @ 8,755' Jt #205.
95K DN WT
7,693.0 9,004.0
12/15/2022
04:45
12/15/2022
07:45
3.00 COMPZN, RPCOMP RURD P Change out Summit ESP cable reel #1
with reel #2. Make cable splice.
Meg ESP cable to 1000 volts. A-G= 6.9
G Ohms, B-G= 5.2 G Ohms, C-G= 6.1
G Ohms before 2nd splice.
Meg ESP cable to 1000 volts. A-G= 6.1
G Ohms, B-G= 5.1 G Ohms, C-G= 5.0
G Ohms after 2nd splice.
SIMOPS: R/U Halliburton slick line and
drift 4 1/2" completion with 3.83" drift T/
1,500' WLM from surface, R/D.
9,004.0 9,004.0
12/15/2022
07:45
12/15/2022
10:00
2.25 COMPZN, RPCOMP RCST P RIH with 4 1/2" HYD 563 upper
completion as per detail F/9,004'
T/10,036'. Top filling every joint with 9.0
ppg NaCL. Cable clamps ran on every
collar.
Monitoring continous surface reading on
DHG.
Meg ESP cable to 1000 volts. A-G= 4.75
G Ohms, B-G= 3.63 G Ohms, C-G=
4.35 G Ohms @ 10,036' Jt #236.
95K DN WT
9,004.0 10,036.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 59/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/15/2022
10:00
12/15/2022
10:45
0.75 COMPZN, RPCOMP SLKL P R/U Halliburton slick line and drift 4 1/2"
completion with 3.83" drift T/ 1,600'
WLM from surface. Monitoring continous
surface reading on DHG.
Meg ESP cable to 1000 volts. A-G=4.8
G Ohms, B-G=3.6 G Ohms, C-G=4.4 G
Ohms @ 10,036' Jt #236.
10,036.0 10,036.0
12/15/2022
10:45
12/15/2022
12:45
2.00 COMPZN, RPCOMP RCST P RIH with 4 1/2" HYD 563 upper
completion as per detail F/10,036'
T/11,502'. Top filling every joint with 9.0
ppg NaCL. Cable clamps ran on every
collar.
Monitoring continous surface reading on
DHG.
Meg ESP cable to 1000 volts. A-G= 3.7
G Ohms, B-G= 3.3 G Ohms, C-G= 2.8
G Ohms @ 11,072' Jt #261.
100K DN WT
10,036.0 11,502.0
12/15/2022
12:45
12/15/2022
14:00
1.25 COMPZN, RPCOMP RCST P Space out upper completion. RIH with
joints 271-273 and lower HES ratcheting
mule shoe into liner top, continue S/O
10K to shear locator and S/O to nogo.
L/D 3 joints, P/U space out 9.76' pup
joint, 1 jt 4.5" tubing # 271, 3.42' pup
joint T/11,499'.
155K Up WT
100K DN WT
11,502.0 11,499.0
12/15/2022
14:00
12/15/2022
17:00
3.00 COMPZN, RPCOMP THGR P P/U landing joint and M/U Cameron
tubing hanger. Orient tubing hanger to
production tree alignment using 9
o'clock timed collar, blanked off excess
ports on hanger. L/D landing joint.
11,499.0 11,499.0
12/15/2022
17:00
12/15/2022
18:00
1.00 COMPZN, RPCOMP SLKL P R/U Halliburton slick line and drift 4 1/2"
completion with 3.83" drift T/ 1,500'
WLM from surface. R/D slick line.
Monitoring continous surface reading on
DHG.
11,499.0 11,502.0
12/15/2022
18:00
12/16/2022
00:00
6.00 COMPZN, RPCOMP THGR P P/U landing joint #278, terminate TEC
wire and ESP cable through tubing
hanger as per Cameron, Halliburton and
Summit rep's. Cable splice made for
penetrator. Pressure test all swedgeloc
connections to 5,000 psi for 5 minutes
each. Install Summit Flying Lead
extension to ESP leads.
Meg ESP cable to 1000 volts. A-G=3.0
G Ohms, B-G=2.6 G Ohms, C-G=2.5 G
Ohms before penetrator splice.
Meg ESP cable to 1000 volts. A-G=3.2
G Ohms, B-G=2.9 G Ohms, C-G=3.4 G
Ohms after splice before TH feedthru.
SIMOPS: R/D excess 4-1/2" upper
completion running equipment, cleaning
and clearing rig floor.
11,520.0 11,520.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 60/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/16/2022
00:00
12/16/2022
01:00
1.00 COMPZN, RPCOMP THGR P Drain BOP. RIH and land out Cameron
tubing hanger with upper completion.
Ran in all 8 lock down pins.Test tubing
hanger seals to 5,000 psi for 15
minutes.
Meg ESP cable to 1000 volts. A-G=4.9
G Ohms, B-G=5.2 G Ohms, C-G=5.3 G
Ohms after landing out.
S/O 105K
11,520.0 11,537.0
12/16/2022
01:00
12/16/2022
02:00
1.00 COMPZN, RPCOMP RURD P R/U squeeze manifold and chart
recorder. Test surface lines to 4,000 psi.
11,537.0 11,537.0
12/16/2022
02:00
12/16/2022
04:15
2.25 COMPZN, RPCOMP PRTS P Set Halliburton TNT packer per
Halliburton. Pressured up to 4,600 psi
down tubing (observed packer setting at
1,890 psi on DHG). Held for 15 minutes
and charted test. Monitored - no returns.
Bled down tubing to 1,890 psi.
Pressured up on IA/Hanger to 3,950 psi.
Held for 30 minutes and charted test.
Bled off IA and then tubing pressures to
zero. Pressure up on IA and shear SOV
at 3,190 psi. Verify communication with
tubing.
11,537.0 11,537.0
12/16/2022
04:15
12/16/2022
04:45
0.50 COMPZN, RPCOMP OWFF P OWFF - static. SIMOPS: R/D lines and
pull flying lead to surface.
11,537.0 11,537.0
12/16/2022
04:45
12/16/2022
05:45
1.00 COMPZN, RPCOMP MPSP P L/D landing joint Install HP-BPV and test
to 2,500 psi for 10 minutes in direction
of flow.
11,537.0 11,537.0
12/16/2022
05:45
12/16/2022
07:30
1.75 COMPZN, WHDBOP RURD P R/D ESP cable and sheave, clean and
clear rig floor, L/D ESP tools and
equipment.
11,537.0 11,537.0
12/16/2022
07:30
12/16/2022
08:30
1.00 COMPZN, WHDBOP RURD P B/D kill, choke, mud pumps,cement
lines and remove mousehole.
11,537.0 11,537.0
12/16/2022
08:30
12/16/2022
12:00
3.50 COMPZN, WHDBOP NUND P N/D trip nipple, flow box, flow line, MPD
choke manifold.
11,537.0 11,537.0
12/16/2022
12:00
12/16/2022
14:30
2.50 COMPZN, WHDBOP NUND P Continue N/D BOP, loosen choke and
kill line for BOP travel, remove BOP
adapter flange, rack BOP on pedstall
and secure for move.Remove DSA
adapter from wellhead, clean an clear
MPD equipment from cellar. Prepare
wellhead for TEC wire and ESP cables.
11,537.0 11,537.0
12/16/2022
14:30
12/16/2022
20:00
5.50 COMPZN, WHDBOP NUND P Install seals, tree test dart and prep
wellhead for tubing head adapter as per
Cameron rep. Prepare ESP cable and
TEC wire for tubing head adapter as
per Summit and Halliburton reps. Test
seals to 5,000 psi for 15 minutes - good
test. N/U and orientate Cameron 4-1/16"
Frac Tree as per Cameron rep. Summit
performed final ESP cable checks.
Meg ESP cable to 1000 volts. A-G=3.5
G Ohms, B-G=2.9 G Ohms, C-G=2.8 G
Ohms once wellhead adapter on and
tested.
SIMOPS: Ready and move Rockwasher
away from rig, remove excess fluids
from pits, working on rig move checklist.
11,537.0 11,537.0
12/16/2022
20:00
12/17/2022
00:00
4.00 COMPZN, WHDBOP PRTS P Install 4-1/16" 10M wing valve with
blanking flange to Frac tree outlet. R/U
test equipment for tree test. Fill tree with
diesel. Pressure test Frac tree to 250
psi - 5 minutes and 5,000 psi - 15
minutes with IA valve open. R/D test
equipment.
11,537.0 11,537.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 61/61
3S-615
Report Printed: 1/10/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/17/2022
00:00
12/17/2022
00:30
0.50 COMPZN, WHDBOP MPSP P Pull HP-BPV and tree test dart as per
Cameron rep with dry rod.
11,537.0 11,537.0
12/17/2022
00:30
12/17/2022
06:30
6.00 COMPZN, WHDBOP FRZP P R/U freeze protect 2" hp lines and
manifold to Little Red Services. PJSM.
Test lines to 2,500 psi. Pump down IA
with LRS taking returns up tubing.
Pumped at 1.25 bpm 90 bbls diesel ICP:
500 psi, FCP: 650 psi. 90 bbls returns to
pits. Shut down (SIP: 650 psi) and
lined up and u-tube well for 30 minutes.
Troubleshoot gauge. Verify 0 pressure
on Tbg/IA.
Final pressures. Tbg=0 psi, IA=0 psi,
OA=120 psi
SIMOPS: preparing rig and pad for
move to 3S-701 well.
11,537.0 11,537.0
12/17/2022
06:30
12/17/2022
07:00
0.50 COMPZN, WHDBOP MPSP P Set H-BPV as per Cameron rep with dry
rod.
11,537.0 11,537.0
12/17/2022
07:00
12/17/2022
09:00
2.00 DEMOB, MOVE RURD P R/D freeze protect lines and equipment.
Install flanges and gauges. Secure well.
Rig released from 3S-615 at 0900 hrs.
11,537.0 11,537.0
Rig: DOYON 19
RIG RELEASE DATE 12/17/2022
Page 1/1
3S-615
Report Printed: 1/9/2023
Cement
Cement Details
Description
Surface String Cement
Cementing Start Date
11/3/2022 07:00
Cementing End Date
11/3/2022 12:00
Wellbore Name
3S-615
Comment
Cement Stages
Stage # 1
Description
Surface String Cement
Objective Top Depth (ftKB)
36.6
Bottom Depth (ftKB)
3,069.0
Full Return?
Yes
Vol Cement …
396.0
Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
3
Q Pump Final (bbl/…
5
Q Pump Avg (bbl/…
5
P Pump Final (psi)
465.0
P Plug Bump (psi)
931.0
Recip?
Yes
Stroke (ft)
15.00
Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
Perform surface cement job as per HES. Pump 60 Bbl's 10.2 ppg tuned prime spacer with LCM and #4 red dye @ 4.3 BPM while reciprocating, PUW 180K, SOW
130K.
Drop bottom wiper plug and follow with 10.7 PPG Arctic Cem Lead Cement, pump at average 5.3 BPM.
Land hanger while interface exiting casing shoe at total volume pumped 295 Bbl's, pick up and reciprocate after interface clears shoe track at total of 350 Bbl's
pumped. Finish lead cement for a total of 501 Bbl's 10.7 lead cement pumped.
Follow with 58 bbl's 15.8 PPG tail cement at 2 BPM (Cement to surface 17 bbls into Tail slurry).
Drop top wiper plug and chase with 20 Bbl's @ 5.8 bpm fresh water from HES cement unit.
Displace 262 Bbl's 9.8 Spud mud with rig pumps ICP at 6.2 BPM 226 PSI, at 256 bbls pumped reduce rate to 3 bpm 385 PSI FCP.
Bump plug at 2604 strokes and build pressure to 931 PSI and held for 5 minutes. Bleed pressure and check floats, floats holding. Note: Landed hanger 2,000 stks
into displacement, CIP @ 11:57 hrs. PSI held.
Note: Full returns during job, spacer and 306 bbls cement and interface back to surface with 46 bbls 10.6 ppg cement.
S/O 105K prior to landing
Cement Fluids & Additives
Fluid
Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl)
Yield (ft³/sack) Mix H20 Ratio (gal/sack) Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Surface String Cement
Page 1/1
3S-615
Report Printed: 1/9/2023
Cement
Cement Details
Description
Intermediate String 1 Cement
Cementing Start Date
11/13/2022 05:00
Cementing End Date
11/13/2022 11:00
Wellbore Name
3S-615
Comment
Pump 57.2 BBLS 12.5 PPG spacer - Pump 237 BBLS 15.3 Cement with BMII in the first 200 BBLS - Chase with 9.6 PPG mud - bumpp plugs - floats hold - TOC
@ 5,620' MD 3,340' TVD
Cement Stages
Stage # 1
Description
Intermediate String 1
Cement
Objective
CMT to 250' TVD above
Coyote formation
Top Depth (ftKB)
5,620.0
Bottom Depth (ftKB)
11,717.0
Full Return?
Yes
Vol Cement …
0.0
Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
4
Q Pump Final (bbl/…
2
Q Pump Avg (bbl/…
4
P Pump Final (psi)
340.0
P Plug Bump (psi)
1,322.0
Recip?
Yes
Stroke (ft)
15.00
Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
Pump 57.2 BBLS 12.5 PPG spacer - Pump 237 BBLS 15.3 Cement with BMII in the first 200 BBLS - Chase with 9.6 PPG mud - bump plugs - floats hold
Cement Fluids & Additives
Fluid
Fluid Type
Primary Cement
Fluid Description Estimated Top (ftKB)
5,626.0
Est Btm (ftKB)
11,717.0
Amount (sacks)
1,050
Class
G
Volume Pumped (bbl)
233.0
Yield (ft³/sack)
1.25
Mix H20 Ratio (gal/sack)
5.58
Free Water (%) Density (lb/gal)
15.30
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Fluid
Fluid Type
Lead Cement
Fluid Description Estimated Top (ftKB)
0.0
Est Btm (ftKB)
2,569.0
Amount (sacks)
880
Class Volume Pumped (bbl)
Yield (ft³/sack) Mix H20 Ratio (gal/sack)
14.94
Free Water (%) Density (lb/gal)
10.70
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Fluid
Fluid Type
Tail Cement
Fluid Description Estimated Top (ftKB)
2,569.0
Est Btm (ftKB)
3,069.0
Amount (sacks)
272
Class Volume Pumped (bbl)
Yield (ft³/sack) Mix H20 Ratio (gal/sack)
5.08
Free Water (%) Density (lb/gal)
15.80
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Intermediate String 1 Cement
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-615
Will planned perforations require a spacing exception? Yes No
9. Property Designation (Lease Number): 10. Field: Current Pools:
Kuparuk R Torok Oil Pool
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD):
23770 5200.69 5200.64 1985 None None
Casing Collapse
Structural
Conductor
Surface 2470
Intermediate 4790
Intermediate 7850
Liner 7500
Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft):
12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations: OIL WINJ WDSPL Suspended
16. Verbal Approval: Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name:Dustin Morrow
Contact Email:dustin.w.morrow@cop.com
Contact Phone: 832-493-9141
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:
Post Initial Injection MIT Req'd? Yes No
Spacing Exception Required? Yes No Subsequent Form Required:
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
563
4-1/2" 2375611063.6
4-1/2"
5201
7-5/8"
20"
10-3/4"
94
3032.3
Perforation Depth MD (ft):
7-5/8"11107.9
10860
MD
6890
5210
131
2543
4948
113
3069
513011706
11143
Length Size
Proposed Pools:
TVD Burst
PRESENT WELL CONDITION SUMMARY
23590
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL380107/ADL025544/ADL025528
222-101
P.O. Box 100360 Anchorage, Alaska, 99510-0360 50-103-20844-00-00
ConocoPhillips
8430
Tubing Grade: Tubing MD (ft):
TNT Packer @ 11,271' MD/ 4,990' TVD LTP
set at 11,531'MD / 5,075' TVD
Perforation Depth TVD (ft): Tubing Size:
L-80 11537
28-Dec-22
HAL TNT Prod Packer, Baker ZXP
Packer/Flexlock Hanger, No SSSV
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
AOGCC USE ONLY
Perforate
Reppair Well
Exploratory Stratigraphic Development Service
BOP Test Mechanical Integrity Test Location Clearance
No
No
Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
12/21/2022
By Anne Prysunka at 11:31 am, Dec 21, 2022
322-713
SFD
X
CDW 12/22/2022
10-404
SFD
113 SFD
SFD 12/27/2022VTL 12/27/2022GCW 12/27/22
Jessie L.
Chmielowski
Digitally signed by Jessie
L. Chmielowski
Date: 2022.12.27 12:21:46
-09'00'
RBDMS JSB 122922
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-615 Frac sundry
wells that intersect well track buffer
Business Unit ID Business Area ID Field Name API * Well Name Well Type Status Symbology
KUP KRU KUPARUK RIVER UNIT 501032043000 3S-07 PROD ACTIVE Oil
KUP KRU KUPARUK RIVER UNIT 501032043200 3S-09 INJ ACTIVE Injector Miscible Water Alternating Gas
KUP KRU KUPARUK RIVER UNIT 501032043300 3S-18 PROD ACTIVE Oil
KUP KRU KUPARUK RIVER UNIT 501032043900 3S-14 INJ ACTIVE Injector Miscible Water Alternating Gas
KUP KRU KUPARUK RIVER UNIT 501032044000 3S-10 PROD ACTIVE Oil
KUP KRU KUPARUK RIVER UNIT 501032044400 3S-15 PROD PA Plugged and Abandoned
KUP KRU KUPARUK RIVER UNIT 501032044500 3S-16 INJ ACTIVE Injector Miscible Water Alternating Gas
KUP KRU KUPARUK RIVER UNIT 501032044600 3S-22 INJ ACTIVE Injector Miscible Water Alternating Gas
KUP KRU KUPARUK RIVER UNIT 501032044800 3S-17 INJ PA Plugged and Abandoned
KUP KRU KUPARUK RIVER UNIT 501032044801 3S-17A INJ ACTIVE Injector Miscible Water Alternating Gas
KUP KRU KUPARUK RIVER UNIT 501032045000 3S-08 PROD PA Plugged and Abandoned
KUP KRU KUPARUK RIVER UNIT 501032045001 3S-08A PROD PA Plugged and Abandoned
KUP KRU KUPARUK RIVER UNIT 501032045002 3S-08B PROD PA Plugged and Abandoned
KUP KRU KUPARUK RIVER UNIT 501032045003 3S-08C PROD ACTIVE Oil
KUP KRU KUPARUK RIVER UNIT 501032045060 3S-08CL1 PROD ACTIVE Oil
KUP KRU KUPARUK RIVER UNIT 501032045070 3S-08CL1PB1 EXPEND PA Plugged and Abandoned
KUP KRU KUPARUK RIVER UNIT 501032045200 3S-21 INJ ACTIVE Injector Miscible Water Alternating Gas
KUP KRU KUPARUK RIVER UNIT 501032045300 3S-23 PROD PA Plugged and Abandoned
KUP KRU KUPARUK RIVER UNIT 501032045301 3S-23A PROD ACTIVE Oil
KUP KRU KUPARUK RIVER UNIT 501032045400 3S-06 INJ PA Plugged and Abandoned
KUP KRU KUPARUK RIVER UNIT 501032045401 3S-06A INJ ACTIVE Injector Miscible Water Alternating Gas
KUP KRU KUPARUK RIVER UNIT 501032045600 3S-24 PROD PA Plugged and Abandoned
KUP KRU KUPARUK RIVER UNIT 501032045601 3S-24A PROD PA Plugged and Abandoned
KUP COYOTR01 TRACT OPERATION COYOTR01 501032045602 3S-24B PROD ACTIVE Oil
KUP KRU KUPARUK RIVER UNIT 501032045800 3S-03 PROD ACTIVE Oil
KUP KRU KUPARUK RIVER UNIT 501032046000 3S-19 PROD ACTIVE Oil
KUP KRU KUPARUK RIVER UNIT 501032036100 PALM 1 EXPLOR PA Plugged and Abandoned
KUP KRU KUPARUK RIVER UNIT 501032036101 3S-26 INJ ACTIVE Injector Miscible Water Alternating Gas
KUP MORTR02 TRACT OPERATION MORTR02 501032069500 3S-620 PROD ACTIVE Oil
KUP MORTR04 TRACT OPERATION MORTR04 501032077400 3S-611 PROD ACTIVE Oil
KUP MORTR04 TRACT OPERATION MORTR04 501032077470 3S-611PB1 EXPEND PA Plugged and Abandoned
KUP MORTR04 TRACT OPERATION MORTR04 501032077700 3S-612 INJ ACTIVE Injector Miscible Water Alternating Gas
KUP KRU KUPARUK RIVER UNIT 501032069900 MORAINE 1 EXPLOR PA Plugged and Abandoned
KUP MORTR03 TRACT OPERATION MORTR03 501032073500 3S-613 INJ ACTIVE Injector Produced Water
NAK NAK NORTH ALASKA EXPLORATION 501032064500 NUNA 1 EXPLOR SUSP Suspended
NAK NAK NORTH ALASKA EXPLORATION 501032064570 NUNA 1PB1 EXPEND PA Plugged and Abandoned
KUP MORTR05 TRACT OPERATION MORTR05 501032084200 3S-625 SVC PROP Proposed
NAK OU OOOGURUK UNIT 501032066000 NDST-02 EXPLOR SUSP Suspended
NAK OU OOOGURUK UNIT 501032066070 NDST-02PB1 EXPEND 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@ 8,325' MD / 4,113' TVD
3S-615 Wellbore Schematic
Grassroots Horizontal Moraine Producer
Surface Casing: 10-¾" 45.5#, L-80, Hydril 563 @
3,069’ MD / 2,543' TVD, 63° INC
Conductor: 20" driven to +/-119'
Production Liner: 4-½" 12.6#, L-80, Hydril 563
@ 23,756' MD / 5,201' TVD, 90° INC
Tubing: 4-½”12.6#, L-80, Hydril 5639-и" Intermediate Hole
6-1/2" Production Hole
KlaShield WBM13-½" Surface Hole
Intermediate Casing: 7-з" 29.7#, L80, Hydril 563 /
500' 33.7#, P110S, Hyd563 Heavy Heel @ 11,707'
MD / 5,130' TVD, 72° Inc
Updated: 12/18/2022
by K. Herring
4-½” x 6" OD Swell Packer Frac sleeve (ball drop)LSNDSpud Mud3.562" DB Landing Nipple @ 11,345' MD
5-½” x 7-5/8" ZXP Packer @ 11,531' MD
5-½” x 7-5/8" Flexlock Hanger @ 11,553' MD
4-½” x 7-з" Halliburton TNT @ 11,270' MD
TOC 5,620' / 3,340' TVD
(773' TVD above hydrocarbon bearing zone)
Downhole Gauge – @ 10,085' MD
TOC @ Surface
As Drilled
Top Torok Oil Pool (Moraine) @ 11,740' MD / 5141' TVD
Rigless ESP (wireline retrievable pump/motor) @ 10,225' MD
Sliding sleeve w/3.813" X profile @ 10458' MD
Gas Lift Mandrel, 4-½” x 1-½” @ 6,417' MD
Gas Lift Mandrel, 4-½” x 1-½” @ 2,951' MD
WIV/Alpha Sleeve
s Horizontal Moraine Producer
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 on11/3/2022 shows that the original job pumped as
designed. The cement job was pumped with 501 barrels of 10.7 ppg lead cement and 58
barrels 15.8 ppg tail cement, displaced with 9.8ppg mud. The plug was bumped and the
floats held. Cement returns came to surface.
The 7 & 5/8” casing cement report on 11/13/2022 shows that the job was pumped as
designed, indicating competent cementing operations. The first stage cement job was
pumped with 237 barrels of 15.3 ppg The plug was bumped and the floats held. A cement
bond log indicates competent cement with a cement top @ 5,620’ MD (3,340’ 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 11/4/2022 the 10-3/4” casing was pressure tested to 3,000 psi for 30 minutes
On 11/15/2022 the 7-5/8” casing was pressure tested to 4,000 psi for 30 minutes.
On 12/16/2022 the 4-1/2” tubing was pressure tested to 4,600 psi. Good Test
On 12/16/2022 the 7-5/8” casing by 4.5 tubing annulus was pressure tested to 3,950 psi.
Good Test
AOGCC Required Pressures [all in psi]
Maximum Predicted Treating Pressure (MPTP) 7,355
Annulus pressure during frac 3,500
Annulus PRV setpoint during frac 3,600
7-5/8" Annulus pressure test 3,850
4-1/2" Tubing pressure Test 4,550
Electronic PRV 8,455
Highest pump trip 7,855
SECTION 8 – PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE,
WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8)
Size Weight, ppf Grade API Burst, psi API Collapse, psi
10 & 3/4” 45.5 L-80 5,209 2474
7 & 5/8” 29.7 L-80 6,885 4,789
7 & 5/8” 33.7 P-110 10,860 7,870
4.5” 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 reservoir, has an average thickness of approximately 300 ft
TVD over the course of the lateral section of well 3S-615, from where it intersects the top
formation at 11,740’ MD to TD of the well. The Torok is comprised of thinly interbedded
sandstone, siltstone, and mudstone layers. The sandstone and siltstone components are
litharenites, moderately to well sorted, and very fine grained. The mudstones are composed
of clay-rich, moderately to poorly sorted silt and mud grains. 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 mudstone and siltstone
with an average thickness of approximately 770’ TVD. The top of the Torok confining
intervals starts at 4,374 ft. TVDSS (9,273’ 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
5,447 ft TVDSS at the heel, and 5,420’ ft TVDSS at the toe of the well.
The estimated formation pressure is 2500psi at a depth of 5145’ TVD (1,985 psi with a 0.1
psi/ft gas gradient).
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-612: The 7-5/8” casing cement report on 11/4/2018 shows that the job was pumped as
designed, indicating competent cementing operations. 12.5 ppg MPII was pumped before
dropping bottom plug, this was then chased with 15.8 ppg Class G cement and the top plug
was dropped. This was chased with 9.5 ppg LSND mud. The plug bumped, pressured up to
1500 psi and held for 5 min. Floats were checked and they held.
3S-613:The 7-5/8” casing cement report on 5/2/2016 shows that the job was pumped as
designed, indicating competent cementing operations. 12.5 ppg MPII was pumped before
dropping bottom plug, this was then chased with 15.8 ppg cement and dropped top plug. This
was chased with 9.3 ppg LSND mud. Full returns were seen throughout the job. The plug
bumped at 941 psi and the floats were checked and they held.
3S-19:7” casing cement pump report on 7/2/2003 shows that job was pumped as designed,
indicating competent cementing operations. The cement job was pumped with 15.8ppg Class
G Cement, displaced with seawater. The plug bumped at 2000psi, and the floats were
checked and they held. CBL conducted on 12/22/2012 from 9170ft to surface. CBL log
indicates good to fair cement from 9170ft to 7350ftMD.
Nuna 1:According to the Pioneer Natural Resources job log on the AOGCC website, the 7-
5/8” casing was cemented on 2/16/2012. The cement report indicates that the job was
pumped with 192 sx 15.8ppg Class G cement. Partial returns were seen.
Source:http://aogweb.state.ak.us/WebLink/DocView.aspx?id=39505&searchid=edb77d4c-
f03e-451e-ae3b-baa6eeea8f35&dbid=0&cr=1&cc=1#, page 201
Nuna 1 PB1:According to the Pioneer Natural Resources job log on the AOGCC website,
the top plug was pumped in Nuna 1 PB1 on 2/10/2012. The top plug was pumped with 280
sx of Premium Cement. Firm cement was encountered at ~5766’.
Source: http://aogweb.state.ak.us/WebLink/DocView.aspx?id=39505&searchid=edb77d4c-
f03e-451e-ae3b-baa6eeea8f35&dbid=0&cr=1&cc=1#, page 201
3S-625: The 7& 5/8” casing cement report on 9/29/2022 shows that the job was pumped as
designed, indicating competent cementing operations. The first stage cement job was
pumped with 264 barrels of 15.3ppg lead cement and 33 barrels of 15.3ppg tail cement. The
cement was displaced with 574 barrels of 9.6ppg LSND drilling mud. The plug did not bump
and 50% of shoe track volume was pumped. Losses totaled to 21 barrels during the job.
Cement floats held. A cement bond log indicates competent cement with a cement top @
7,850’ MD (3,970’ TVD).
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 no faults transect the Torok oil pool within one half mile radius of the wellbore trajectory
for well 3S-615.
If there is any indication that a fracture has intersected a fault 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-615 was completed in 2022 as a horizontal producer in the Torok formation. The well was
completed with a 4.5” tubing upper completion and a 4.5” liner with a ball actuated sliding
sleeve lower completion. The first stage will be pumped through a toe initiator valve in the toe
of the lateral. After the 1st stage frac balls will be dropped to shift open the 2 nd stage sleeve
and isolate the first stage. The 2nd stage will then be pumped and a third ball drop
(progressively getting larger) after each remaining stage, these balls will provide isolation
from the previous stage and allow fracturing from the toe of the well towards the heel.
Proposed Procedure:
Halliburton Pumping Services: (TorokFrac)
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 2,000’ TVD.
3. Pressure test the rig installed frac tree to 10,000 psi.
4. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC.
5. MIRU 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 (approx.
2,200 barrels are required for each stage with breakdown, maximum pad and
pumping down the next ball. (450 bbls usable volume per tank).
6. MIRU HES Frac Equipment.
7. PT Surface lines to 10,000 psi using a Pressure test fluid.
8. Test IA Pop off system to ensure lines are clear and all components are functioning
properly.
9. Bring up pumps and increase annulus pressure from 2,500 psi to 3,500 psi as the
tubing pressures up.
10. Pump the 300 bbl breakdown stage (30# Hybor G) according to the attached excel
HES pump schedule. Bring pumps up to maximum rate of 30 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 24 stage Frac job by following attached HES schedule @ ~37bpm with a
maximum expected treating pressure of 7,550 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, 5k production tree installation (Pressure
Tested to 5,000 psi) and flowback
(Slickline and possibly CTU).
horizontal producer
?
SECTION 13 – POST-FRACTURE WELLBORE CLEANUP AND FLUID
RECOVERY PLAN 20 AAC 25.283(a)(13)
Flowback will be initiated through a de-sander unit until the fluids clean up at which time it will
be turned over to production for initial clean up production before conversion to injection.
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________KUPARUK RIV UNIT 3S-615
JBR 12/21/2022
MISC. INSPECTIONS:
FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK:
ACCUMULATOR SYSTEM:MUD SYSTEM:
P/F P/F
P/FP/FP/F
Visual Alarm
QuantityQuantity
Time/Pressure
SizeQuantity
Number of Failures:1
Test with 5" test joint. F/P upper kelly Bled to 0 psi and Cycle valve and retest good. Accumulator bottles 11 @ 1036psi
Test Results
TEST DATA
Rig Rep:Kelly Haug/Sean TowerOperator:ConocoPhillips Alaska, Inc.Operator Rep:Andy Lundale/Charles Brow
Rig Owner/Rig No.:Doyon 19 PTD#:2221010 DATE:11/3/2022
Type Operation:DRILL Annular:
250/2500Type Test:INIT
Valves:
250/4000
Rams:
250/4000
Test Pressures:Inspection No:bopKPS221104091912
Inspector Kam StJohn
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 7.0
MASP:
2024
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 P
Misc NA
Upper Kelly 1 FP
Lower Kelly 1 P
Ball Type 1 P
Inside BOP 1 P
FSV Misc 0 NA
14 PNo. Valves
1 PManual Chokes
1 PHydraulic Chokes
0 NACH Misc
Stripper 0 NA
Annular Preventer 1 13 5/8"P
#1 Rams 1 3.5" x 6"P
#2 Rams 1 Blinds P
#3 Rams 1 3.5" x 6"P
#4 Rams 0 NA
#5 Rams 0 NA
#6 Rams 0 NA
Choke Ln. Valves 1 3.125 P
HCR Valves 2 3.125 P
Kill Line Valves 1 3.125 P
Check Valve 0 NA
BOP Misc 1 4" kill line de P
System Pressure P3050
Pressure After Closure P1450
200 PSI Attained P33
Full Pressure Attained P164
Blind Switch Covers:PAll Stations
Bottle precharge P
Nitgn Btls# &psi (avg)P4 @ 2300
ACC Misc NA0
P PTrip Tank
P PPit Level Indicators
P PFlow Indicator
P PMeth Gas Detector
P PH2S Gas Detector
NA NAMS Misc
Inside Reel Valves 0 NA
Annular Preventer P14
#1 Rams P8
#2 Rams P16
#3 Rams P8
#4 Rams NA0
#5 Rams NA0
#6 Rams NA0
HCR Choke P2
HCR Kill P2
FP
Test with 5" test joint. F/P upper kelly Bled to 0 psi and Cycle valve and retest good. Accumulator bottles 11 @ 1036psi
From:Wallace, Chris D (OGC)
To:dustin.w.morrow@cop.com
Cc:Loepp, Victoria T (OGC)
Subject:KRU 3S-615 (PTD 2221010) Hydraulic Fracturing Sundry
Date:Friday, December 23, 2022 9:26:03 AM
Dustin,
We are processing the Hydraulic Fracturing Sundry application for KRU 3S-615 and have noticed
new chemicals in the chemical disclosure section namely ResMetrics OPT 2000-2050 and WPT 1000-
1050.
Please provide the CAS numbers for each component of these chemicals (Possibly a complete
MSDS). 20 AAC 25.283(a)(12)(C) requires that the CAS numbers be provided for each
ingredient/component of the frac fluid. Alaska Admin Code (akleg.gov)
A potential approval delay with this revised sundry application relates to Section 6b, chemical
disclosure.
It looks like chemicals are to be supplied by ResMetrics and the Section 6b disclosure has some
proprietary chemicals listed so I cannot tell directly if the ResMetrics chemicals are proprietary.
If ResMetrics wishes to claim trade secret/proprietary protections, they should review 20 AAC
25.283(k) and apply to AOGCC appropriately.
As part of our due diligence, AOGCC will review the CAS numbers provided in the chemical disclosure
to ensure the frac chemicals are not in conflict with EPA guidance on the prohibition of diesel fuel
fracs. EPA guidance labels diesel fuel fracs as containing CAS numbers:
68334-30-5 Diesel Fuel
68476-34-6 Diesel Fuel No. 2
68476-30-2 Fuel Oil No. 2
68476-31-3 Fuel Oil No. 4
8008-20-6 Kerosene
Thanks and Regards,
Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue,
Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information
from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the
sole use of the intended recipient(s). It may contain confidential and/or privileged information.
The unauthorized review, use or disclosure of such information may violate state or federal law. If
you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding
it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at
907-793-1250 or chris.wallace@alaska.gov.
1
Regg, James B (OGC)
From:Rig 19 <rig19@doyondrilling.com>
Sent:Friday, December 9, 2022 8:01 PM
To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); D19 Company Man;
McLeod, Austin (OGC)
Subject:12-8-22 3S 615 Doyon 19 BOPE Test
Attachments:12-8-22 3S 615 Doyon 19 BOPE Test.xlsx; BOPE test chart 3S-615 12-9-22.pdf
Thank You,
Sean Tower
Doyon Drilling Rig 19 Tour Pusher
Cell: (907) 301-7832
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open
attachments unless you recognize the sender and know the content is safe.
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
Su bm it to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner: Rig No.:19 DATE: 12/9/22
Rig Rep.: Rig Email:
Operator:
Operator Rep.: Op. Rep Email:
Well Name: PTD #2221010 Sundry #
Operation: Drilling: X Workover: Explor.:
Test: Initial: Weekly: Bi-Weekly: x Other:
Rams:250/4000 Annular:250/2500 Valves:250/4000 MASP:2024
MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 1 P
Permit On Location P Hazard Sec.P Lower Kelly 1 P
Standing Order Posted P Misc.NA Ball Type 1 P
Test Fluid Water Inside BOP 1 P
FSV Misc 0 NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0 NA Trip Tank P P
Annular Preventer 1 13-5/8"P Pit Level Indicators P P
#1 Rams 1 3.5" X 6"P Flow Indicator P P
#2 Rams 1 Blinds P Meth Gas Detector P P
#3 Rams 1 3.5" X 6"P H2S Gas Detector P P
#4 Rams 0 NA MS Misc 0 NA
#5 Rams 0 NA
#6 Rams 0 NA ACCUMULATOR SYSTEM:
Choke Ln. Valves 1 3.125 P Time/Pressure Test Result
HCR Valves 2 3.125 FP System Pressure (psi)2940 P
Kill Line Valves 1 3.125 P Pressure After Closure (psi)1550 P
Check Valve 0 NA 200 psi Attained (sec)28 P
BOP Misc 1 4" Kill line Demco P Full Pressure Attained (sec)145 P
Blind Switch Covers: All stations Yes
CHOKE MANIFOLD:Bottle Precharge: 11 @1000 P
Quantity Test Result Nitgn. Bottles # & psi (Avg.): 4 @ 2400 P
No. Valves 14 P ACC Misc 0 NA
Manual Chokes 1 P
Hydraulic Chokes 1 P Control System Response Time:Time (sec) Test Result
CH Misc 0 NA Annular Preventer 17 P
#1 Rams 7 P
Coiled Tubing Only:#2 Rams 7 P
Inside Reel valves 0 NA #3 Rams 7 P
#4 Rams 0 NA
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:1 Test Time:6.0 HCR Choke 1 P
Repair or replacement of equipment will be made within days. HCR Kill 1 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 12/08/22 06:56
Waived By
Test Start Date/Time:12/9/2022 7:30
(date) (time)Witness
Test Finish Date/Time:12/9/2022 13:30
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Austin McLeod
Doyon
Test Annular with 4" and 4.5" test joint 250/2500psi low/high 5min each. Test 3.5" x 6" UPR, LPR with 4 '' and 4.5" test joints.
250/4000psi low/high 5 min each test all other componets 250/4000psi low/high 5min each. Test hydraulic choke & manual choke
2000psi. Bottle Precharge - 1000 psi. FP on Choke HCR valve, greased valve, functioned Retest and passed.
Orville Williams / Sean Tower
Conoco Phillips
Ken Harding / Charles Brown
KRU 3S-615
Test Pressure (psi):
rig19@doyondrilling.com
d19cm@conocophillips.com
Form 10-424 (Revised 08/2022) 2022-1208_BOP_Doyon19_KRU_3S-615
250/4000psi low/high 5 min each test all other componets 250/4000psi low/high 5min each. Test hydraulic choke & manual choke
FP on Choke HCR valve,
FP
1
Regg, James B (OGC)
From:Rig 19 <rig19@doyondrilling.com>
Sent:Tuesday, November 29, 2022 1:05 PM
To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Doyon 19 Operations
Engineer
Subject:Emailing: Revised 11-29-22 3S-615 BOPE Test .xlsx
Attachments:11-29-22 3S-615 BOPE Test .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.
Revised to add 4 nitrogen bottles, Thank you Brian
Rig 19 Toolpusher
Kelly Haug
Cell: 907‐355‐5834
Rig: 907 670‐6098
KRU 3S-615PTD 2221010
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner:Rig No.:19 DATE:11/29/22
Rig Rep.:Rig Email:
Operator:
Operator Rep.:Op. Rep Email:
Well Name:PTD #2221010 Sundry #
Operation:Drilling: X Workover:Explor.:
Test:Initial:Weekly:Bi-Weekly: x Other:
Rams:250/4000 Annular:250/2500 Valves:250/4000 MASP:2024
MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 1 P
Permit On Location P Hazard Sec.P Lower Kelly 1 P
Standing Order Posted P Misc.NA Ball Type 1 P
Test Fluid Water Inside BOP 1 P
FSV Misc 0 NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0 NA Trip Tank P P
Annular Preventer 1 13-5/8"P Pit Level Indicators P P
#1 Rams 1 3.5" X 6"P Flow Indicator P P
#2 Rams 1 Blinds P Meth Gas Detector P P
#3 Rams 1 3.5" X 6"P H2S Gas Detector P P
#4 Rams 0 NA MS Misc 0 NA
#5 Rams 0 NA
#6 Rams 0 NA ACCUMULATOR SYSTEM:
Choke Ln. Valves 1 3.125 P Time/Pressure Test Result
HCR Valves 2 3.125 P System Pressure (psi)3000 P
Kill Line Valves 1 3.125 P Pressure After Closure (psi)1450 P
Check Valve 0 NA 200 psi Attained (sec)24 P
BOP Misc 1 4" Kill line Demco P Full Pressure Attained (sec)155 P
Blind Switch Covers:All stations Yes
CHOKE MANIFOLD:Bottle Precharge:P
Quantity Test Result Nitgn. Bottles # & psi (Avg.):4 @ 2300 P
No. Valves 14 P ACC Misc 0 NA
Manual Chokes 1 P
Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result
CH Misc 0 NA Annular Preventer 14 P
#1 Rams 9 P
Coiled Tubing Only:#2 Rams 11 P
Inside Reel valves 0 NA #3 Rams 8 P
#4 Rams 0 NA
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:0 Test Time:8 hrs. HCR Choke 1 P
Repair or replacement of equipment will be made within days. HCR Kill 1 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 11/28/22 4:44
Waived By
Test Start Date/Time:11/28/2022 19:00
(date)(time)Witness
Test Finish Date/Time:11/29/2022 3:00
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Brian Bixby
Doyon
Test annular with 4" test joint 250/2500psi low/high 5min each, Test 3.5" x 6" VBR's uppers & lowers with 4 ''/ 4.5" test joint
250/4000psi low/high 5 min each test all other componets 250/4000psi low/high 5min each, Test hyd choke & manual choke
2000psi. Bottle Precharge - 1000 psi.
Kelly Haug/Grant Neuharth
Conoco Phillips
Andy Lundale/Dusty Pickworth
KRU 3S-615
Test Pressure (psi):
rig19@doyondrilling.com
d19cm@conocophillips.com
Form 10-424 (Revised 08/2022)2022-1129_BOP_Doyon19_KRU_3S-615
J. Regg; 12/28/2022
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner:Rig No.:19 DATE:11/13/22
Rig Rep.:Rig Email:
Operator:
Operator Rep.:Op. Rep Email:
Well Name:PTD #2221010 Sundry #
Operation:Drilling: X Workover:Explor.:
Test:Initial:Weekly:Bi-Weekly:X Other:
Rams:250/4000 Annular:250/2500 Valves:250/4000 MASP:2024
MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 1 P
Permit On Location P Hazard Sec.P Lower Kelly 1 P
Standing Order Posted P Misc.NA Ball Type 1 P
Test Fluid Water Inside BOP 1 P
FSV Misc 0 NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0 NA Trip Tank P P
Annular Preventer 1 13-5/8"P Pit Level Indicators P P
#1 Rams 1 3.5" X 6"P Flow Indicator P P
#2 Rams 1 Blinds P Meth Gas Detector P P
#3 Rams 1 3.5" X 6"P H2S Gas Detector P P
#4 Rams 0 NA MS Misc 0 NA
#5 Rams 0 NA
#6 Rams 0 NA ACCUMULATOR SYSTEM:
Choke Ln. Valves 1 3.125 P Time/Pressure Test Result
HCR Valves 2 3.125 P System Pressure (psi)3000 P
Kill Line Valves 1 3.125 P Pressure After Closure (psi)1500 P
Check Valve 0 NA 200 psi Attained (sec)31 P
BOP Misc 1 4" Kill line Demco P Full Pressure Attained (sec)152 P
Blind Switch Covers:All stations Yes
CHOKE MANIFOLD:Bottle Precharge:P
Quantity Test Result Nitgn. Bottles # & psi (Avg.):4 @ 2300 P
No. Valves 14 P ACC Misc 0 NA
Manual Chokes 1 P
Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result
CH Misc 0 NA Annular Preventer 14 P
#1 Rams 7 P
Coiled Tubing Only:#2 Rams 15 P
Inside Reel valves 0 NA #3 Rams 7 P
#4 Rams 0 NA
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:0 Test Time:4.5 HCR Choke 1 P
Repair or replacement of equipment will be made within days. HCR Kill 1 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 11/12/22 4:55PM
Waived By
Test Start Date/Time:11/13/2022 19:00
(date)(time)Witness
Test Finish Date/Time:11/13/2022 23:30
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Guy Cook
Doyon
Test Annular with 4" test joint 250/2500psi, test all other componets 250/4000psi low/high 5min each. Test Hydraulic & manual
choke 2000psi. Bottle Precharge 1000 psi (11 btls).
O.W illiams/Sean Tower
Conoco Phillips
Kenny Harding/D. Pickworth
KRU 3S-615
Test Pressure (psi):
rig19@doyondrilling.com
d19cm@conocophillips.com
Form 10-424 (Revised 08/2022)2022-1113_BOP_Doyon19_KRU_3S-615
J. Regg; 12/8/2022
1
Regg, James B (OGC)
From:Rig 19 <rig19@doyondrilling.com>
Sent:Monday, November 14, 2022 7:16 AM
To:Regg, James B (OGC)
Cc:DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Operations Engineer, Doyon 19; D19 Company
Man; Cook, Guy D (OGC); Ben Wedin
Subject:FW: Doyon Rig 19 BOPE Test 3S-615
Attachments:Doyon 19 BOPE 11-13-22 3S-615 .xlsx; Doyon 19 BOP test chart 3S-615 11-13-22.pdf
Resend chart
Thank you
Orville Williams
Rig 19 Toolpusher
907 670‐6098
907 306‐4467
From: Rig 19
Sent: Monday, November 14, 2022 4:17 AM
To: Jim Regg <jim.regg@alaska.gov>; AOGCC.Inspectors@alaska.gov; phoebe. brooks (phoebe.brooks@alaska.gov)
<phoebe.brooks@alaska.gov>; Operations Engineer, Doyon 19 <d19opseng@conocophillips.com>; D19 Company Man
<d19cm@conocophillips.com>; guy. cook@alaska. gov <guy.cook@alaska.gov>
Subject: Doyon Rig 19 BOPE Test 3S‐615
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open
attachments unless you recognize the sender and know the content is safe.
KRU 3S-615PTD 2221010
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
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Date: 2022.08.24 17:50:46
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WELL PERMIT CHECKLIST
Company ConocoPhillips Alaska, Inc.
Well Name:KUPARUK RIV UNIT 3S-615
Initial Class/Type DEV / PEND GeoArea 890 Unit 11170 On/Off Shore On
Program DEVField & Pool Well bore seg
Annular DisposalPTD#:2221010
KUPARUK RIVER, TOROK OIL - 490169
NA1Permit fee attached
Yes Surface Location lies within ADL0380107; Portion of Well Passes Thru ADL0025544;2 Lease number appropriate
Yes Top Prod Int & TD lie within ADL0025528.3 Unique well name and number
Yes4Well located in a defined pool
Yes KUPARUK RIVER, TOROK OIL – 490169 governed by Conservation Order 725A5Well located proper distance from drilling unit boundary
Yes As proposed, well will conform to spacing requirements.6 Well located proper distance from other wells
Yes7Sufficient acreage available in drilling unit
Yes8If deviated, is wellbore plat included
Yes9Operator only affected party
Yes10Operator has appropriate bond in force
Yes11Permit can be issued without conservation order
Yes12Permit can be issued without administrative approval
Yes13Can permit be approved before 15-day wait
NA14Well located within area and strata authorized by Injection Order # (put IO# in comments) (For
NA15All wells within 1/4 mile area of review identified (For service well only)
NA16Pre-produced injector: duration of pre-production less than 3 months (For service well only)
NA17Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)
Yes 59' conductor18Conductor string provided
Yes SC shoe at 2844' MD19Surface casing protects all known USDWs
Yes 180% excess planned20CMT vol adequate to circulate on conductor & surf csg
No21CMT vol adequate to tie-in long string to surf csg
No Productive interval will be completed with uncemented perf joints22CMT will cover all known productive horizons
Yes23Casing designs adequate for C, T, B & permafrost
Yes24Adequate tankage or reserve pit
NA25If a re-drill, has a 10-403 for abandonment been approved
Yes Anti-collision analysis complete; no major risk failures26Adequate wellbore separation proposed
Yes Diverter variance granted per 20 AAC 25.035(h)(2)27 If diverter required, does it meet regulations
Yes Max formation pressure is 2544 psig(9.5 ppg EMW); will drill w/ 9.0-10.5 ppg EMW28Drilling fluid program schematic & equip list adequate
Yes29BOPEs, do they meet regulation
Yes MPSP is 2024 psig; will test BOPs to 3500 psig30BOPE press rating appropriate; test to (put psig in comments)
Yes31Choke manifold complies w/API RP-53 (May 84)
Yes32Work will occur without operation shutdown
Yes H2S measures required33Is presence of H2S gas probable
NA34Mechanical condition of wells within AOR verified (For service well only)
No Measures required: H2S is present in reservoir. Wells 3S-611 and -620 yielded 43-61 ppm H2S in 2021.35 Permit can be issued w/o hydrogen sulfide measures
Yes Expected reservoir pressure is 8.2 to 9.5 ppg EMW; mud program appears sufficient to control36Data presented on potential overpressure zones
NA anticipated pressures. MPD will be utilized to maintain stability in the production hole section.37 Seismic analysis of shallow gas zones
NA Moderate risk of lost circulation; LCM available onsite. Some potential for abnormal reservoir38Seabed condition survey (if off-shore)
NA pressure in Coyote/K3 interval; mitigation discussed on p. 7 & 8.39 Contact name/phone for weekly progress reports [exploratory only]
Appr
SFD
Date
8/3/2022
Appr
VTL
Date
8/24/2022
Appr
SFD
Date
8/3/2022
Administration
Engineering
Geology
Geologic
Commissioner:Date:Engineering
Commissioner:Date Public
Commissioner Date
