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1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Convert to 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):
21983'None
Casing Collapse
Structural
Conductor
Surface
Intermediate
Production
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) 265-6813
Senior Production Engineer
KRU 3S-610
5173'21983'5173'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:
Sydney.Autry@conocophillips.com
AOGCC USE ONLY
Tubing Grade:Tubing MD (ft):
7229' MD and 4573' TVD
7301' MD and 4596' TVD
N/A
Sydney Autry
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL025528, ADL380106, ADL380107, ADL393883
223-126
P.O. Box 100360, Anchorage, AK 99510 50-103-20875-00-00
Kuparuk River Field Torok Oil Pool
ConocoPhillips Alaska, Inc.
Length Size
Proposed Pools:
PRESENT WELL CONDITION SUMMARY
Torok Oil Pool
TVD Burst
7306' MD
MD
129'
2565'
5119'
129'
2713'
20"
10-3/4"
90'
7-5/8"8975'
2674'
9012'
None
4-1/2"
None
Perforation Depth TVD (ft):
20433'13132'
4-1/2"
5178'
Packer: HES TNT Packer
Packer: Baker SLZXP HRD-E
SSSV: None
Perforation Depth MD (ft):
L-80
m
n
P
s
66
t
P
N
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
10/08/2025
Sydney Autry Digitally signed by Sydney Autry
Date: 2025.09.25 09:43:53 -08'00'
325-582
By Grace Christianson at 4:02 pm, Sep 25, 2025
DSR-0/25/25
10-404
A.Dewhurst 26SEP25
VTL 10/2/2025*&:
Jessie L.
Chmielowski
Digitally signed by Jessie L.
Chmielowski
Date: 2025.10.02 11:01:26 -08'00'10/02/25
RBDMS JSB 100625
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Mill Frac Ball Seats/FCO 3S-610 12/30/2024 appleha
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: BPV profile compromised (see June 2024 attempt to set). WILL NEED SHALLOW PLUG
INSTEAD.
6/5/2024 spilch
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 18.5039.0129.0129.0154.34x65
Surface 10 3/4 9.95 39.02,712.92,564.6 45.50 L-80 Hydril 563
Intermediate 7 5/86.87 36.5 9,011.7 5,118.5 29.70 L-80 Hydril 563
Liner 4 1/23.96 7,300.920,433.0 5,177.5 12.95P110S Hydril 563
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
35.7
Set Depth …
7,306.4
Set Depth …
4,597.8
String Max No…
4 1/2
Tubing Description
Tubing – Completion Upper
Wt (lb/ft)
12.60
Grade
L-80
Top Connection
HYD563
ID (in)
3.96
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°)Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
35.7 35.7 0.00 HANGER 4.500 Camero
n
C-SRL-
CL
3.900
40.1 40.1 0.01 COLLAR 4.500 HES Fast
Lock
3.900
2,057.4 2,012.6 26.59 Mandrel - GAS
LIFT
4.500 Camero
n
KBMG 3.860
4,024.1 3,380.3 64.88 Mandrel – GAS
LIFT
4.500 Camero
n
KBMG3.860
5,208.8 3,866.4 66.00 Mandrel – GAS
LIFT
4.500 Camero
n
KBMG3.860
6,023.7 4,190.2 70.03 Mandrel – GAS
LIFT
4.500 Camero
n
KBMG3.860
6,670.7 4,396.3 71.58 Mandrel –
Gauge
4.500 HAL Dual Opsis Gauge Mandrel HES Opsis 3.920
6,772.6 4,428.5 71.56 Gas separator 5.500 CMD Gas Venting Sliding Sleeve
(Closed Position)
AccessE
SP
3.910
6,776.4 4,429.7 71.56 XO Spacer 5.500 5-1/2" VAM FJL Pin x Box AccessE
SP
3.893
6,777.4 4,430.0 71.56 MOTOR 5.500 AccessE
SP
Motor
Shroud
4.548
6,782.2 4,431.6 71.56 Centralizer 5.500 AccessE
SP
3.893
6,783.9 4,432.1 71.56 MOTOR 5.500 AccessE
SP
Motor
Shroud
4.548
6,788.7 4,433.6 71.57 Centralizer 5.500 AccessE
SP
3.893
6,790.5 4,434.2 71.57 MOTOR 5.500 AccessE
SP
Motor
Shroud
4.548
6,795.3 4,435.7 71.57 Centralizer 5.500 AccessE
SP
3.893
6,797.1 4,436.3 71.57 MOTOR 5.500 AccessE
SP
Motor
Shroud
4.548
6,801.9 4,437.8 71.57 Centralizer 5.500 AccessE
SP
3.893
6,803.6 4,438.3 71.57 MOTOR 5.500 AccessE
SP
Motor
Shroud
4.548
6,808.4 4,439.8 71.58 Centralizer 5.500 AccessE
SP
3.893
6,810.2 4,440.4 71.58 Motor 5.500 AccessE
SP
Motor
Shroud
4.548
6,815.0 4,441.9 71.58 Centralizer 5.500 AccessE
SP
3.893
6,816.7 4,442.5 71.58 MOTOR 5.500 AccessE
SP
Motor
Shroud
4.548
6,821.5 4,444.0 71.58 Centralizer 5.500 AccessE
SP
3.893
6,823.3 4,444.5 71.58 MOTOR 5.500 AccessE
SP
Motor
Shroud
4.548
6,828.1 4,446.1 71.59 Centralizer 5.500 AccessE
SP
3.893
6,829.8 4,446.6 71.59 MOTOR 5.500 AccessE
SP
Motor
Shroud
4.548
6,836.1 4,448.6 71.59 Annular
Connection
Port (ACP)
5.950 NEW STYLE ACP - slightly different
no go spacing and latch profile than
original style (same as 3S-624)
AccessE
SP
ACP 3.860
6,859.6 4,456.0 71.60 Nipple - Profile 5.000 AccessE
SP
B-Profile3.913
6,873.1 4,460.3 71.61 NIPPLE - NO
GO
5.220 AccessE
SP
3.813
6,971.1 4,491.2 71.55 Sleeve - Sliding 4.500 CMU NEXA-2, 3.813" GX Profile
(Closed)
SLB NEXA-2 3.813
7,119.8 4,538.5 71.42 Chem Injection
Mandrel
4.500 Vanoil BRO-1 BK-2 (Dummy Valve)PESI BRO-1 3.860
7,229.3 4,573.4 71.50 PACKER 4.500 HES TNT 3.866
7,285.9 4,591.3 71.54 Sub - Ceramic
disc
4.500 Arsenal Glass Plug 5500 psi
(sheared 5/18/24)
Arsenal 3.900
HORIZONTAL, 3S-610, 9/24/2025 5:43:40 PM
Vertical schematic (actual)
R
Liner; 7,300.9-20,433.0
Intermediate; 36.5-9,011.7
PACKER; 7,229.3
Chem Injection Mandrel; 7,119.8
Sleeve - Sliding; 6,971.1
ISO-SLEEVE; 6,971.0
NIPPLE - NO GO; 6,873.1
Nipple - Profile; 6,859.6
ISO-SLEEVE; 6,836.0
Annular Connection Port (ACP);
6,836.1
MOTOR; 6,829.8
Centralizer; 6,828.1
MOTOR; 6,823.3
Centralizer; 6,821.5
MOTOR; 6,816.7
Centralizer; 6,815.0
Motor; 6,810.2
Centralizer; 6,808.4
MOTOR; 6,803.6
Centralizer; 6,801.9
MOTOR; 6,797.1
Centralizer; 6,795.3
MOTOR; 6,790.5
Centralizer; 6,788.7
MOTOR; 6,783.9
Centralizer; 6,782.2
MOTOR; 6,777.4
Gas separator; 6,772.6
Mandrel – Gauge; 6,670.7
Intermediate String 1 Cement;
3,549.0 ftKB
Mandrel – GAS LIFT; 6,023.7
Mandrel – GAS LIFT; 5,208.8
Mandrel – GAS LIFT; 4,024.1
Surface; 39.0-2,712.9
Mandrel - GAS LIFT; 2,057.4
Surface String Cement; 39.0
ftKB
Conductor; 39.0-129.0
HANGER; 35.7
KUP PROD
KB-Grd (ft)
39.00
RR Date
4/12/2024
Other Elev…
3S-610
...
TD
Act Btm (ftKB)
21,983.0
Well Attributes
Field Name
TOROK
Wellbore API/UWI
501032087500
Wellbore Status
PROD
Max Angle & MD
Incl (°)
93.33
MD (ftKB)
13,844.38
WELLNAME WELLBORE
Annotation End DateH2S (ppm)DateComment
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°)Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
7,297.5 4,595.0 71.54 Locator 6.380 Baker NoGo
Locator
3.880
7,298.1 4,595.2 71.54 Locator 5.640 Baker WLEG
Shaer
Type
3.880
7,303.1 4,596.8 71.54 Shoe - Mule 4.500 Halliburt
on
Indexing
Mule
Shoe
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)
6,836.0 4,448.6 71.59 ISO-SLEEVE 3" ACP ISO SLEEVE RUN
WITH COMPLETION
4/10/2024 3.000
6,971.0 4,491.2 71.55 ISO-SLEEVE CMU ISO SLEEVE RUN WITH
COMPLETION (it's from
wireline shop)
4/10/2024 3.056
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)
2,057.4 2,012.6 26.59 1 GAS LIFT GLV BK 1 1,170.0 6/8/2024 0.188
4,024.13,380.364.88 2 GAS LIFT GLV BK 1 1,275.06/9/2024 0.313
5,208.8 3,866.4 66.00 3 GAS LIFT OV BK 1 6/9/2024 0.438
6,023.7 4,190.2 70.03 4 GAS LIFT DV BK 1 4/10/2024ALLO
Y 716
(AKA
INCO
NEL)
BK
LATC
H
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)
7,300.9 4,596.0 71.54 PACKER 6.875 Baker SLZXP
(HRD-E)
MM
13911567
5.750
7,323.3 4,603.1 71.55 RS Bushing 6.500 Baker MM
13867421
5.750
7,324.3 4,603.5 71.55 XO 5.500 5-1/2 H563 x 4-1/2 H563 Baker MM
13918329
4.250
7,579.2 4,682.4 72.04 Packer - Swell 5.900 3.890
7,887.4 4,777.6 72.02 Sleeve - Frac 4.500 #24 Seat ID 2.876" **CLOSED**
(MILLED BALL SEAT TO 2.95")
BakerMX CMB
reclosable
2.950
8,181.6 4,868.6 71.90 Packer - Swell 5.900 3.890
8,489.8 4,963.7 72.06 Sleeve - Frac 4.500 #23 Seat ID 2.836" **CLOSED**
(MILLED BALL SEAT TO 2.95")
BakerMX CMB
reclosable
2.950
8,780.5 5,053.1 72.25 Packer - Swell 5.900 3.890
9,090.3 5,138.5 75.80 Sleeve - Frac 4.500 #22 Seat ID 2.797" **CLOSED**
(MILLED BALL SEAT TO 2.95")
Baker MX CMB
reclosable
2.950
9,384.3 5,200.5 79.70 Packer - Swell 5.900 3.890
9,694.5 5,244.0 84.43 Sleeve - Frac 4.500 #21 Seat ID 2.759" **CLOSED**
(MILLED BALL SEAT TO 2.95")
BakerMX CMB
reclosable
2.950
9,985.9 5,261.4 88.69 Packer - Swell 5.900 3.890
10,294.0 5,259.7 90.68 Sleeve - Frac 4.500 #20 Seat ID 2.720" **CLOSED**
(MILLED BALL SEAT TO 2.95")
Baker MX CMB
reclosable
2.950
10,545.6 5,257.690.33 Packer - Swell 5.900 3.890
10,810.8 5,257.5 89.92 Sleeve - Frac 4.500 #19 Seat ID 2.682" **OPEN**
(MILLED BALL SEAT TO 2.95")
BakerMX CMB
reclosable
2.950
11,055.0 5,258.8 89.19 Packer - Swell 5.900 3.890
11,314.8 5,263.4 88.91 Sleeve - Frac 4.500 #18 Seat ID 2.645" **OPEN**
(MILLED BALL SEAT TO 2.95")
BakerMX CMB
reclosable
2.950
11,566.3 5,269.988.50 Packer - Swell 5.900 3.890
11,835.2 5,275.288.70Sleeve - Frac 4.500 #17 Seat ID 2.608" **OPEN**
(MILLED BALL SEAT TO 2.95")
Baker MX CMB
reclosable
2.950
12,088.0 5,277.1 90.05 Packer - Swell 5.900 3.890
12,354.1 5,275.3 90.80 Sleeve - Frac 4.500 #16 Seat ID 2.571" **OPEN**
(MILLED BALL SEAT TO 2.95")
BakerMX CMB
reclosable
2.950
12,606.6 5,271.991.12 Packer - Swell 5.900 3.890
12,875.8 5,265.891.36 Sleeve - Frac 4.500 #15 Seat ID 2.535" **OPEN**
(MILLED BALL SEAT TO 2.95")
Baker MX CMB
reclosable
2.950
13,128.6 5,258.0 92.09 Packer - Swell 5.900 3.890
13,398.1 5,247.0 92.47 Sleeve - Frac 4.500 #14 Seat ID 2.499" **OPEN**
(MILLED BALL SEAT TO 2.95")
BakerMX CMB
reclosable
2.950
13,650.3 5,233.6 93.29 Packer - Swell 5.900 3.890
HORIZONTAL, 3S-610, 9/24/2025 5:43:40 PM
Vertical schematic (actual)
R
Liner; 7,300.9-20,433.0
Intermediate; 36.5-9,011.7
PACKER; 7,229.3
Chem Injection Mandrel; 7,119.8
Sleeve - Sliding; 6,971.1
ISO-SLEEVE; 6,971.0
NIPPLE - NO GO; 6,873.1
Nipple - Profile; 6,859.6
ISO-SLEEVE; 6,836.0
Annular Connection Port (ACP);
6,836.1
MOTOR; 6,829.8
Centralizer; 6,828.1
MOTOR; 6,823.3
Centralizer; 6,821.5
MOTOR; 6,816.7
Centralizer; 6,815.0
Motor; 6,810.2
Centralizer; 6,808.4
MOTOR; 6,803.6
Centralizer; 6,801.9
MOTOR; 6,797.1
Centralizer; 6,795.3
MOTOR; 6,790.5
Centralizer; 6,788.7
MOTOR; 6,783.9
Centralizer; 6,782.2
MOTOR; 6,777.4
Gas separator; 6,772.6
Mandrel – Gauge; 6,670.7
Intermediate String 1 Cement;
3,549.0 ftKB
Mandrel – GAS LIFT; 6,023.7
Mandrel – GAS LIFT; 5,208.8
Mandrel – GAS LIFT; 4,024.1
Surface; 39.0-2,712.9
Mandrel - GAS LIFT; 2,057.4
Surface String Cement; 39.0
ftKB
Conductor; 39.0-129.0
HANGER; 35.7
KUP PROD 3S-610
...
WELLNAME WELLBORE
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)
13,915.1 5,218.5 93.28 Sleeve - Frac 4.500 #13 Seat ID 2.463" **OPEN**
(MILLED BALL SEAT TO 2.95")
Baker MX CMB
reclosable
2.950
14,168.0 5,204.193.09 Packer - Swell 5.900 3.890
14,436.6 5,191.992.46Sleeve - Frac 4.500 #12 Seat ID 2.428" **OPEN**
(MILLED BALL SEAT TO 2.95")
Baker MX CMB
reclosable
2.950
14,688.4 5,182.7 91.55 Packer - Swell 5.900 3.890
14,957.6 5,176.2 91.57 Sleeve - Frac 4.500 #11 Seat ID 2.393" **OPEN**
(MILLED BALL SEAT TO 2.95")
BakerMX CMB
reclosable
2.950
15,210.1 5,171.5 90.43 Packer - Swell 5.900 3.890
15,479.4 5,169.4 90.47 Sleeve - Frac 4.500 #10 Seat ID 2.358" **OPEN**
(MILLED BALL SEAT TO 2.95")
Baker MX CMB
reclosable
2.950
15,732.0 5,167.7 90.37 Packer - Swell 5.900 3.890
15,994.9 5,166.0 90.44 Sleeve - Frac 4.500 #9 Seat ID 2.324" **OPEN**
(MILLED BALL SEAT TO 2.95")
BakerMX CMB
reclosable
2.950
16,243.1 5,164.6 90.14 Packer - Swell 5.900 3.890
16,512.4 5,164.8 89.84 Sleeve - Frac 4.500 #8 Seat ID 2.290" **OPEN**
(MILLED BALL SEAT TO 2.95")
Baker MX CMB
reclosable
2.950
16,765.3 5,165.7 89.67 Packer - Swell 5.900 3.890
17,033.6 5,166.4 89.78Sleeve - Frac 4.500 #7 Seat ID 2.257" **OPEN**
(MILLED BALL SEAT TO 2.95")
Baker MX CMB
reclosable
2.950
17,283.1 5,168.0 89.52 Packer - Swell 5.900 3.890
17,551.8 5,171.2 89.13 Sleeve - Frac 4.500 #6 Seat ID 2.224" **OPEN**
(MILLED BALL SEAT TO 2.95")
BakerMX CMB
reclosable
2.950
17,804.2 5,172.889.95 Packer - Swell 5.900 3.890
18,074.4 5,173.389.69 Sleeve - Frac 4.500 #5 Seat ID 2.191" **OPEN**
(MILLED BALL SEAT TO 2.95")
Baker MX CMB
reclosable
2.950
18,327.1 5,174.4 89.89 Packer - Swell 5.900 3.890
18,594.6 5,174.5 90.06 Sleeve - Frac 4.500 #4 Seat ID 2.158" **OPEN**
(MILLED BALL SEAT TO 2.95")
BakerMX CMB
reclosable
2.950
18,847.1 5,174.689.89 Packer - Swell 5.900 3.890
19,116.5 5,174.889.99 Sleeve - Frac 4.500 #3 Seat ID 2.123" **OPEN**
(MILLED BALL SEAT TO 2.95")
Baker MX CMB
reclosable
2.950
19,369.2 5,174.9 89.97 Packer - Swell 5.900 3.890
19,638.9 5,175.6 89.84 Sleeve - Frac 4.500 #2 Seat ID 2.094" **OPEN**
(MILLED BALL SEAT TO 2.95")
BakerMX CMB
reclosable
2.950
19,888.5 5,175.9 89.87 Packer - Swell 5.900 3.890
20,165.3 5,176.6 89.78 Alpha Sleeve 4.500 **OPEN** Baker MM
13867421
2.987
20,169.1 5,176.689.77 WIV 4.500 Baker MM
13575403
0.870
Cement Squeezes
Top (ftKB)Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB)Des Com
Pump Start
Date
39.0 2,720.0 39.0 2,570.3 Surface String
Cement
Cement 10-3/4" 45.5# L-80 surface hanger as per
Halliburton pump schedule. Flood lines with % bbls
H2O@ 5 BPM, pressure test lines to 3500 PSI, pump
60 bbl 10.2 ppg Tuned primed spacer with 8lb of red
dye at 3-5 BPM 35 psi. Shut down pumps and drop
bottom plug. Pump 387 bbls of 10.7 ppg lead cement
at 3-5 BPM 24 psi. Pump 57 Bbls of 15.8 ppg tail
cement at 3-5 BPM. Shut down and drop top plug.
Flush with 20 Bbls of fresh water and chase with rig
mud pumps 9.8 ppg spud mud. Displace cement at 6
BPM. ICP 122 PSI reduce rate to 3 BPM at 2256
stokes FCP 461 psi.
Did not have positive indication of bottom float shear.
Pumped max of 2350 strokes and did not bump,
pumped additional 10 strokes and did not bump.
Bled off pressure and positive indication that the
floats are holding.
Cement in place at 15:30 hrs.
ICP 113 PSI
FCP 580 PSI
No losses observed.
60 Bbl spacer and 28 Bbls cement returns to surface.
3/14/2024
3,549.09,016.03,156.3 5,119.6 Intermediate
String 1
Cement
60 bbls 10.5 spacer
201 bbls 15.3 with BMII
22 bbls 15.3 without BMII
20 bbls H2O to kick out top plug
Chase with rig - 183 bbls to catch cement
Bump plug with 315 bbls (calculated - 321)
3/23/2024
HORIZONTAL, 3S-610, 9/24/2025 5:43:40 PM
Vertical schematic (actual)
R
Liner; 7,300.9-20,433.0
Intermediate; 36.5-9,011.7
PACKER; 7,229.3
Chem Injection Mandrel; 7,119.8
Sleeve - Sliding; 6,971.1
ISO-SLEEVE; 6,971.0
NIPPLE - NO GO; 6,873.1
Nipple - Profile; 6,859.6
ISO-SLEEVE; 6,836.0
Annular Connection Port (ACP);
6,836.1
MOTOR; 6,829.8
Centralizer; 6,828.1
MOTOR; 6,823.3
Centralizer; 6,821.5
MOTOR; 6,816.7
Centralizer; 6,815.0
Motor; 6,810.2
Centralizer; 6,808.4
MOTOR; 6,803.6
Centralizer; 6,801.9
MOTOR; 6,797.1
Centralizer; 6,795.3
MOTOR; 6,790.5
Centralizer; 6,788.7
MOTOR; 6,783.9
Centralizer; 6,782.2
MOTOR; 6,777.4
Gas separator; 6,772.6
Mandrel – Gauge; 6,670.7
Intermediate String 1 Cement;
3,549.0 ftKB
Mandrel – GAS LIFT; 6,023.7
Mandrel – GAS LIFT; 5,208.8
Mandrel – GAS LIFT; 4,024.1
Surface; 39.0-2,712.9
Mandrel - GAS LIFT; 2,057.4
Surface String Cement; 39.0
ftKB
Conductor; 39.0-129.0
HANGER; 35.7
KUP PROD 3S-610
...
WELLNAME WELLBORE
KRU 3S-610 Convert to ESP:
Steps:
Slickline
1. Pull ISO-sleeve at 6,836' MD (this is set in the ACP – run on-rig, 3.00" ID, limited info
on iso slv in schematic)
2. Pull ISO-sleeve set across NEXA CMU noted in "Other in Hole" section at 6,971' MD.
3.056" ID, 71.55 deg incl.
3. Shift open sliding sleeve (NEXA-2) at 6,971' MD (71.55 deg incl, CMU, 3.813” GX
ProƱle)
4. Shift open gas venting sliding sleeve at 6,773' MD (71.56 deg incl, 3.91" ID, CMD).
Shift this one last so not accidentally closed on subsequent runs to pull iso slv from
ACP or shifting NEXA slv.
**If SL unable to shift any slvs or pull iso slv from ACP – pivot to CTU to shift slvs
before SL lubricates the seals/motor assembly.
5. RIH with seals/motor assembly (OAL= 58.02, Max OD = 3.80"). **Slickline to
lubricate & hang-oƯ for CTU to RIH/set**
CTU
6. RU CTU. RIH to latch seals/motor assembly deployed by slickline.
7. Tag no-go at 6,873’ MD (3.813” ID, 71.61 deg incl).
8. Pull into B-proƱle (6,860' MD, 71.60 deg incl, 3.913” ID) to release locator pin. Pull
into ACP.
9. Set down and conƱrm electrical connection at the junction box. Release & POOH.
Slickline
10.RU SL. RIH with pump assembly (OAL= 54.32', Max OD = 3.80"). **Slickline to
lubricate & hang-oƯ for CTU to RIH/set**
CTU
11.RU CTU. RIH to latch pump assembly.
12.RIH to install on top of seals/motor assembly. Release & POOH.
Slickline
13.RU SL.
14.Install packoƯ/standing valve/slipstop system (2 runs, OAL ~5', ~70 deg inlc working
depth) on top of pump.
15.RIH and set catcher below mandrel #4 at 6023' MD
16. Pull DV (has been in place since tubing was originally run so please report on
condition of the inconel BK latch) from mandrel #4 at 6023' MD and install an SOV
set to 2000 psi tbg shear
17. Pull OV from mandrel #3 at 5208' MD and install DV into mandrel
18. Pull GLV from mandrel #2 at 4024' MD and install DV into mandrel
19. Pull GLV from mandrel #1 at 2057' MD and install DV into mandrel
20. Pull catcher
21. Perform 10 min MITT to 1000 psi
22. RDMO and hand well over to DSO to BOL w/ Summit assistance.
KƌŝŐŝŶĂƚĞĚ͗ĞůŝǀĞƌĞĚƚŽ͗8-May-25ůĂƐŬĂKŝůΘ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐ08May25-NRddE͗DĞƌĞĚŝƚŚ'ƵŚůϯϯϯt͘ϳƚŚǀĞ͕͘^ƵŝƚĞϭϬϬϲϬϬ ϱϳƚŚWůĂĐĞŶĐŚŽƌĂŐĞ͕ůĂƐŬĂϵϵϱϬϭͲϯϱϯϵŶĐŚŽƌĂŐĞ͕<ϵϵϱϭϴ;ϵϬϳͿϮϳϯͲϭϳϬϬŵĂŝŶ;ϵϬϳͿϮϳϯͲϰϳϲϬĨĂdžt >>ED W/η^ Zs/ KZ Zη &/ >ED ^ Zs/ ^Z/Wd/KE >/s Z> ^Z/Wd/KE ddzW d >K'' 3S-610 501-032-0875-00-00 223-126 Kuparuk River WL TTIX-FSI FINAL FIELD 24-Apr-253B-12 50-029-21370-00-00 185-116 Kuparuk River WL WFL FINAL FIELD 27-Apr-253T-730 50-103-20907-00-00 225-010 Kuparuk River WL TTiX-SCMT FINAL FIELD 1-May-25CD4-24 50-103-20602-00-00 209-097 Colville River WL Packer Setting FINAL FIELD 4-May-25CD1-01A 50-103-20299-01-00 212-099 Colville River WL RST FINAL FIELD 5-May-25dƌĂŶƐŵŝƚƚĂůZĞĐĞŝƉƚͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺyͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺWƌŝŶƚEĂŵĞ ^ŝŐŶĂƚƵƌĞ ĂƚĞWůĞĂƐĞƌĞƚƵƌŶǀŝĂĐŽƵƌŝĞƌŽƌƐŝŐŶͬƐĐĂŶĂŶĚĞŵĂŝůĂĐŽƉLJƚŽ^ĐŚůƵŵďĞƌŐĞƌ͘EƌĂĂƐĐŚΛƐůď͘ĐŽŵ^>ƵĚŝƚŽƌͲdZE^D/dd>d dZE^D/dd>ηĞůŝǀĞƌLJZĞĐĞŝƉƚƐŝŐŶĂƚƵƌĞĐŽŶĨŝƌŵƐƚŚĂƚĂƉĂĐŬĂŐĞ;ďŽdž͕ĞŶǀĞůŽƉĞ͕ĞƚĐ͘ͿŚĂƐďĞĞŶƌĞĐĞŝǀĞĚ͘dŚĞƉĂĐŬĂŐĞǁŝůůďĞŚĂŶĚůĞĚͬĚĞůŝǀĞƌĞĚƉĞƌƐƚĂŶĚĂƌĚĐŽŵƉĂŶLJƌĞĐĞƉƚŝŽŶƉƌŽĐĞĚƵƌĞƐ͘dŚĞƉĂĐŬĂŐĞΖƐĐŽŶƚĞŶƚƐŚĂǀĞŶŽƚďĞĞŶǀĞƌŝĨŝĞĚďƵƚƐŚŽƵůĚďĞĂƐƐƵŵĞĚƚŽĐŽŶƚĂŝŶƚŚĞĂďŽǀĞŶŽƚĞĚŵĞĚŝĂ͘η^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞT40398T40399T40400T40401T404023S-610501-032-0875-00-00223-126Kuparuk RiverWLTTIX-FSIFINAL FIELD24-Apr-25Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.05.08 14:16:08 -08'00'
Originated: Delivered to:30-Jan-25
Alaska Oil & Gas Conservation Commiss 30Jan25-NR
ATTN: Meredith Guhl
333 W. 7th Ave., Suite 100
600 E 57th Place Anchorage, Alaska 99501-3539
Anchorage, AK 99518
(907) 273-1700 main (907)273-4760 fax
WELL NAME API #
SERVICE ORDER
#FIELD NAME
SERVICE
DESCRIPTION
DELIVERABLE
DESCRIPTION DATA TYPE DATE LOGGED
MT7-89 50-103-20889-00-00 224-089 Greater Mooses Tooth WL TTiX-PPROF FINAL FIELD 5-Jan-25
1R-06A 50-029-21331-01-00 210-056 Kuparuk River WL Plug Setting FINAL FIELD 13-Jan-25
3T-612 50-103-20896-00-00 224-128 Kuparuk River WL TTiX-SCMT FINAL FIELD 17-Jan-25
3S-610 50-103-20875-00-00 223-126 Kuparuk River WL TTiX-PPROF FINAL FIELD 23-Jan-25
Transmittal Receipt
________________________________ X_________________________________
Print Name Signature Date
Please return via courier or sign/scan and email a copy to Schlumberger.
Nraasch@slb.com SLB Auditor -
TRANSMITTAL DATE
TRANSMITTAL #
A Delivery Receipt signature confirms that a package (box, envelope,
etc.) has been received. The package will be handled/delivered per
standard company reception procedures. The package's contents have
not been verified but should be assumed to contain the above noted
media.
# Schlumberger-Private
T40040
T40041
T40042
T400433S-610 50-103-20875-00-00 223-126 Kuparuk River WL TTiX-PPROF FINAL FIELD 23-Jan-25
Gavin Gluyas
Digitally signed by Gavin
Gluyas
Date: 2025.01.31 08:15:00
-09'00'
Originated: Delivered to:9-Jul-24
Halliburton Alaska Oil and Gas Conservation Comm.
Wireline & Perforating Attn.: Natural Resource Technician
Attn: Fanny Haroun 333 West 7th Avenue, Suite 100
6900 Arctic Blvd. Anchorage, Alaska 99501
Anchorage, Alaska 99518
Office: 907-275-2605
FRS_ANC@halliburton.com
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of the sender above
WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#
1 3H-33A 50-103-20578-01 909382823 Kuparuk River Patch Setting Record Field- Final 25-Jun-24 0 1
2 3J-14 50-029-21496-00 909382822 Kuparuk River Patch Setting Record Field- Final 29-Jun-24 0 1
3 3N-06 50-029-21538-00 n/a Kuparuk River Plug Setting Record Field- Final 1-May-24 0 1
4 3S-610 50-103-20875-00 909539033 Kuparuk River Plug Setting Record Field- Final 31-May-24 0 1
5 3S-626 50-103-20878-00 909417481 Kuparuk River Cement Evaluation with CASTField & Processed 19-Jun-24 0 1
6 3T-621 50-103-20882-00 909382821 Kuparuk River Correlation Record Field- Final 20-Jun-24 0 1
7 3T-621 50-103-20882-00 909394238 Kuparuk River Sigma and Gadolinium AnalysField & Processed 22-Jun-24 0 1
8
9
10
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:
Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
FRS_ANC@halliburton.com
Date:Signed:
Transmittal Date:
T39140
T39141
T39142
T39143
T39144
T39145
T39145
209-103
185-288
186-027
223-126
224-007
224-022
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.07.10 11:36:20
-08'00'
3S-610 50-103-20875-00 909539033 Kuparuk River Plug Setting Record Field- Final 31-May-24 0 1 T39143
223-126
C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2024-07-03_22175_KRU_3S-610_CaliperSurvey_LogData_Transmittal.docx
DELIVERABLE DISCRIPTION
Ticket # Field Well # API # Log Description Log Date
22175 KRU 3S-610 50-103-20875-00 Caliper Survey w/ Log Data 03-Jul-24
DELIVERED TO
Company & Address
DIGITAL FILE
# of Copies
LOG PRINTS
# of Prints
CD’s
# of Copies
1
AOGCC
Attn: Natural Resources Technician
333 W. 7th Ave., Suite 100
Anchorage, Ak. 99501-3539
Delivered By: CPAI Sharefile
______________________________ _____________________________________
Date received Signature
______________________________ ______________________________________
PLEASE RETURN COPY VIA EMAIL TO:
DIANE.WILLIAMS@READCASEDHOLE.COM
READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503
PHONE: (907)245-8951
E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM
223-126
T39135
Gavin Gluyas
Digitally signed by Gavin
Gluyas
Date: 2024.07.08 14:48:53
-08'00'
T38804
From:Brooks, Phoebe L (OGC)
To:Regg, James B (OGC)
Subject:FW: Doyon 142 3S-610
Date:Monday, May 6, 2024 4:39:49 PM
Attachments:image001.png
Doyon 142 03-23-24 Revised.xlsx
Phoebe Brooks
Research Analyst
Alaska Oil and Gas Conservation Commission
Phone: 907-793-1242
CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the
Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended
recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or
disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail,
please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it
to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov.
From: Rig 142 <rig142@doyondrilling.com>
Sent: Monday, May 6, 2024 4:32 PM
To: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>
Subject: RE: Doyon 142 3S-610
Thank you Ma’am, I will revise my copy by adding 6 to the bottle amount, and I do apologize.
Frank
From: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>
Sent: Monday, May 6, 2024 4:26 PM
To: Rig 142 <rig142@doyondrilling.com>
Subject: RE: Doyon 142 3S-610
Kelly,
The # of Nitgn. Bottles is missing; please advise.
Thank you,
Phoebe
Phoebe Brooks
Research Analyst
Alaska Oil and Gas Conservation Commission
Phone: 907-793-1242
CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the
Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended
<ƵƉĂƌƵŬZŝǀĞƌhŶŝƚϯ^ͲϲϭϬ
WdϮϮϯϭϮϲϬ
adding 6 to the bottle amount
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.
Some people who received this message don't often get email from rig142@doyondrilling.com. Learn why this is
important
recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or
disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail,
please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it
to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov.
From: Rig 142 <rig142@doyondrilling.com>
Sent: Sunday, March 24, 2024 2:18 AM
To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay
<doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>
Subject: Doyon 142 3S-610
Kelly Haug
Rig 142 Tourpusher
Rig142@doyondrilling.com
Doyon Rig 142 Office 907-670-6002
Cell, 907-355-5834
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
SSu bmit to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner: Rig No.:142 DATE: 3/23/24
Rig Rep.: Rig Email:
Operator:
Operator Rep.: Op. Rep Email:
Well Name:PTD #2231260 Sundry #
Operation: Drilling: X Workover: Explor.:
Test: Initial: Weekly: Bi-Weekly: Other: X
Rams:250/4000 Annular:250/2500 Valves:250/4000 MASP:1778
MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping p Well Sign P Upper Kelly 1P
Permit On Location P Hazard Sec.P Lower Kelly 1P
Standing Order Posted P Misc.NA Ball Type 2P
Test Fluid Water Inside BOP 1P
FSV Misc 0NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0NATrip Tank PP
Annular Preventer 1 13-5/8" 5M P Pit Level Indicators PP
#1 Rams 1 3-1/2 x 6" VBR P Flow Indicator PP
#2 Rams 1 Blind/ Shear P Meth Gas Detector PP
#3 Rams 1 3-1/2" x 6" VBR P H2S Gas Detector PP
#4 Rams 0NAMS Misc 0NA
#5 Rams 0NA
#6 Rams 0NAACCUMULATOR SYSTEM:
Choke Ln. Valves 1 3-1/8" 5M P Time/Pressure Test Result
HCR Valves 2 3-1/8" 5M P System Pressure (psi)3000 P
Kill Line Valves 3 3-1/8" 5M P Pressure After Closure (psi)1575 P
Check Valve 0NA200 psi Attained (sec)9 P
BOP Misc 0NAFull Pressure Attained (sec)54 P
Blind Switch Covers: All stations YES
CHOKE MANIFOLD:Bottle Precharge: 1000 P
Quantity Test Result Nitgn. Bottles # & psi (Avg.): 6@ 2000 P
No. Valves 14 P ACC Misc 0NA
Manual Chokes 1P
Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result
CH Misc 0NA Annular Preventer 21 P
#1 Rams 7 P
Coiled Tubing Only:#2 Rams 7 P
Inside Reel valves 0NA #3 Rams 7 P
#4 Rams 0 NA
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:0 Test Time:6.5 HCR Choke 2 P
Repair or replacement of equipment will be made within days. HCR Kill 2 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 3/22/24 08:04 hrs
Waived By
Test Start Date/Time:3/23/2024 14:30
(date) (time)Witness
Test Finish Date/Time:3/23/2024 21:00
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Kam StJohn
Doyon
Test Annular w/ 4" & 4.5" test jt 250/2500psi, Test upper 3.5" x 6" VBR T/ 250/4000 w/ 4" & 4.5" test joint & lower 3.5" x 6" VBR's
250/4000psi w/4" & 4.5" test jt. Test 2ea-4" FOSV/ 1ea-4" Dart 250/4000psi Test manual & hydraulic choke to 2,000 psi, Choke
valves #'s 1-14, Choke & Kill Manuals & HCR's, 2x 4"Demco valve on Kill, Upper & Lower IBOP, 250/4000psi, Test all H2S, LEL
& PVT flow alarms/both audible and visual. All rams functioned from both primary and remote controls. Drawdown conducted w/
2 air, and 2ea electrical pumps. Rig on a 21 day BOP test cycle.
M. Sam/ Kelly Haug
CPAI
K. Hinrichs/ Byron Marmon
KRU-3S-610
Test Pressure (psi):
rig142@doyondrilling.com
d142cm@conocophillips.com
Form 10-424 (Revised 08/2022) 2024-0323_BOP_Doyon142_KRU_3S-610
9
9
9 9 99
9
9
9
9
9
9
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown
Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program
Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ______________________
ConocoPhillips Alaska, Inc. Development Exploratory
Stratigraphic Service 6. API Number:
7. Property Designation (Lease Number): 8. Well Name and Number:
9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s):
11. Present Well Condition Summary:
Total Depth measured 21983 feet feet
true vertical 5172 feet feet
Effective Depth measured 20433 feet 7229 / 7301 feet
true vertical 5177 feet 4573 / 4596 feet
Perforation depth Measured depth N/A feet
True Vertical depth N/A feet
Tubing (size, grade, measured and true vertical depth)4.5" 12.6# L80 7303' MD 4,597' TVD
Baker SLZXP 7301' MD 4596' TVD
Packers and SSSV (type, measured and true vertical depth)HAL TNT 7229' MD 4573' TVD
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
13a.
Prior to well operation:
Subsequent to operation:
13b. Pools active after work: Torok Oil Pool
15. Well Class after work:
Daily Report of Well Operations Exploratory Development Service Stratigraphic
Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL
Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG
Sundry Number or N/A if C.O. Exempt:
Authorized Name and
Digital Signature with Date:Manabu Nozaki 6/21/2024 Contact Name:Manabu Nozaki
Contact Email:Manabu.Nozaki@ConocoPhillips.com
Authorized Title:Completions Engineer Contact Phone:907-265-6519
324-260
Sr Pet Eng:
9210
Sr Pet Geo: Sr Res Eng:
WINJ WAG
Water-BblOil-Bbl
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
TBD
measured
true vertical
Packer
Representative Daily Average Production or Injection Data
Casing Pressure Tubing PressureGas-Mcf
MD
9695' - 20165' MD
Size
129
52102712.9
9-5/8"
11590
7-5/8"
4790
7850
6890
10860
N/A
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
223-126
50-103-20875-00-00
P.O. Box 100360 Anchorage, AK 99510-03603. Address:
Job logs attached
5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work:
ADL380107 / ADL380106 / ADL025528 / ADL393883
Kuparuk Field / Torok Oil Pool
KRU 3S-610
Plugs
Junk measured
4.3 MMlbs 16/20 Wan-Li LWC proppant, 69,000 lbs of 100 Mesh, and 3320 psi treating pressure/4800 psi BHG pressure.
Length
90
2673.9
129Conductor
Surface
Intermediate
20"
10-3/4"
measured
TVD
Intermediate
Liner
8134.5
840.7
13132
Casing
Structural
4865.4
5119
4-1/2"
8171
9011.7
20433 5177
2564.6
Burst Collapse
2470
p
k
ft
t
Fra
O
s O
223
6. A
G
L
PG
,
Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
By Grace Christianson at 3:43 pm, Jun 21, 2024
Prepared By:
William Martin
James Campbell
Nannook Crew
Intervals 1-21
Notice: Although the information contained in this report is based on sound engineering practices, the copyright
owner(s) does (do) not accept any responsibility whatsoever, in negligence or otherwise, for any loss or damage
arising from the possession or use of the report whether in terms of correctness or otherwise. The application,
therefore, by the user of this report or any part thereof, is solely at the users own risk.
3S-610
Conoco Phillips
Harrison Bay County, AK
Post Job Report
Stimulation Treatment
API: 50-103-20875
Prepared for: Manabu Nozaki
May 26, 2024
Torok Formation
30# Hybor G
Table of Contents
Section Page(s)
Executive Summary
Actual Design
Wellbore Information
Interval Summary
Fluid System-Proppant Summary
Interval 1 Plots
Interval 2 Plots
Interval 3 Plots
Interval 4 Plots
Interval 5 Plots
Interval 6 Plots
Interval 7 Plots
Interval 8 Plots
Interval 9 Plots
Interval 10 Plots
Interval 11 Plots
Interval 12 Plots
Interval 13 Plots
Interval 14 Plots
Interval 15 Plots
Interval 16 Plots
Interval 17 Plots
Interval 18 Plots
Interval 19 Plots
Appendix
Well Summary
Chemical Summary
Planned Design
Water Straps 5-18
Water Straps 5-19
Water Straps 5-20
Water Straps 5-21
Water Straps 5-23
Water Straps 5-24
Water Straps 5-25
Water Straps 5-26
Water Analysis 5-18
Water Analysis 5-19
Water Analysis 5-20
Water Analysis 5-21
Water Analysis 5-23
Water Analysis 5-24
Water Analysis 5-25
Water Analysis 5-26
Real-Time QC
Real-Time QC (2)
Event Log 5-18
Event Log 5-19
Event Log 5-20
Event Log 5-21
Event Log 5-23
Event Log 5-24
Event Log 5-25
Event Log 5-26
Prejob Break Test Day 1
Fann 15 min Zone 1
Zone 1B
Zone 2
Zone 3
Zone 4
Zone 5
Zone 6
Zone 8
Zone 9
Zone 10
Zone 11
Zone 12
Zone 13
Zone 14
Zone 15
Zone 16
Zone 17
93 - 96
97 - 105
106 - 109
110 - 113
114 - 117
122 - 131
4
5 - 10
11
62 - 69
70 - 74
75 - 78
12 - 30
31
32 - 49
50 - 61
79 - 88
89 - 92
118 - 121
132 - 135
136 - 139
140 - 143
144 - 152
153 - 158
159
160
161
162 - 167
168
169
170
171
172
173
174
175
176
177
178
179
180
181
182
183
184
185
186
187
188
189
190
191
192
193
194
195
196
197
198
199
200
201
202
203
204
205
206
207
208
209
210
211
Conoco Phillips - 3S-610 TOC 2
Zone 18
Zone 19
Sand Sieve Analysis 214 - 215
212
213
Conoco Phillips - 3S-610 TOC 3
1,740,110 gallons of 30# Hybor G
194,309 gallons of 30# Linear
14,180 gallons of Produced Water
1,000 gallons of Sea Water
4,544,550 pounds of Wanli 16/20 Ceramic
76,000 pounds of 100M
1,676,686 gallons of 30# Hybor G
208,550 gallons of 30# Linear
7,468 gallons of Produced Water
1,067 gallons of Sea Water
4,279,428 pounds of Wanli 16/20 Ceramic
69,000 pounds of 100M
Thank you,
William Martin Steven Sanders
Senior Technical Professional Senior Technical Professional
Halliburton maintains a continuous quality improvement process and appreciates any comments or suggestions that you may
have. Halliburton again thanks you for the opportunity to perform service work on this well. We hope to be your solutions
provider for future projects.
Engineering Executive Summary
On May 18, 2024 a stimulation treatment was performed in the Torok formation on the 3S-610 well in Harrison Bay County,
AK. The 3S-610 was a 21 stage Horizontal Sleeve Design. The proposed treatment consisted of:
The actual treatment fully completed 19 of 21 stages. 2 stages were skipped, 0 stages screened out and 0 stages were cut short
of design. The actual treatment consisted of:
A more detailed description of the actual treatment can be found in the attached reports. The following comments were provided
to summarize events and changes to the proposed treatment:
Interval 01 was started, but during the 4 ppg sand stage a leak was discovered on the blender. The interval was flushed but
resumed and pumped to completion the next day. On interval 20, there was no indication of a ball seat. After pumping one
wellbore volume and reattempting the launch procedure, a second ball was dropped, again with no indication of seating. The well
was flushed while waiting for a third ball to arrive to location. The third attempt to seat a ball for interval 20 also failed, the
decision was made to skip the zone and continue on with interval 21. After there was no indication of a ball seat for interval 21,
Conoco made the decision to rig down. 19 stages were pumped to completion and interval 20 and 21 were skipped due to not
being able to seat balls.
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.
Produced Water was used as the base fluid for all intervals except interval 03. All MO concentrations described in the report are
raw values. During interval 6, while trying to establish stable XL, one tote of MO was discovered to be weak and did not allow the
fluid to achieve proper pH. The tote was swapped out and the desired pH was attained. Throughout the day, MO concentrations
had to be slowly increased to maintain the desired pH range
Conoco Phillips - 3S-610 Executive Summary 4
CUSTOMERConoco Phillips API BFD (lb/gal)8.54LAT 70.39420002LEASE3S-610SALES ORDEBHST (°F)144LONG-150.1961825FORMATIONTorokDATE Max Pressure (psi)8500*Exceeds 80% of burst pressure*Prop Slurry Design Clean Actual Clean Actual Clean Calculated Slurry Design Prop Calculated Prop CL-28M Losurf-300D MO-67 Cat-3 BA-20 WG-36 OPTIFLO-III OPTIFLO-II BE-6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total TotalCrosslinker Surfactant Buffer Catalyst BufferInterval Number Description Description Description(ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)1-1 Shut-In Shut-In -1-2 Produced Water Prime Up Pressure Test 5.0 1,000 1,067 25 251-3 Shut-In Shut-In -1-4 30# Linear Arsenal Sleeve Shift 5.0 1,260 259 6 6 1.00 0.33 30.00 2.00 2.00 0.151-5 30# Linear Step Rate Test 37.0 8,400 2,966 71 71 1.00 0.33 30.00 2.00 2.00 0.151-6 30# Linear DFIT 37.0 1,680 3,063 73 73 1.00 0.33 30.00 2.00 2.00 0.151-7 Shut-In Shut-In -1-8 Shut-In Shut-In -1-9 30# Hybor G Establish Stable Fluid 15.0 8,400 8,821 210 210 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.151-10 30# Hybor G Pad 37.0 19,800 20,048 477 477 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.151-11 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 18,097 431 435 4,000 4,246 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.151-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 3,000 3,366 80 82 3,000 2,019 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.151-13 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 3,750 3,875 92 98 7,500 5,486 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.151-14 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 6,000 6,081 145 161 18,000 15,217 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.151-15 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 7,275 6,439 153 169 29,100 15,123 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.151-16 30# Hybor G Flush Wanli 16/20 Ceramic 37.0 13,956 13,993 333 333 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.151-17 Produced Water Freeze Protect -1-18 Shut-In Shut-In -1-19 Shut-In Shut-In -1-20 Produced Water Prime Up Pressure Test 5.0 1,000 1,067 25 251-21 Shut-In Shut-In -1-22 30# Linear Spacer and Ball Drop 1,260 100 2 2 1.00 0.33 30.00 2.00 0.151-23 30# Hybor G Establish Stable Fluid 37.0 8,400 8,084 192 192 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.151-24 30# Hybor G Pad 37.0 19,800 20,158 480 480 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.151-25 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 3,000 3,012 72 74 3,000 2,280 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.151-26 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 3,750 3,761 90 96 7,500 6,081 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.151-27 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 4,400 4,664 111 124 13,200 11,915 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.151-28 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 5,700 5,708 136 158 22,800 20,652 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.151-29 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 6,200 6,216 148 176 27,900 26,089 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.151-30 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 7,000 7,786 185 227 35,000 38,790 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.151-31 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 7,300 7,326 174 215 40,150 38,571 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.151-32 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 5,800 5,838 139 175 34,800 34,064 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.151-33 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 6,000 6,010 143 182 39,000 36,315 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.151-34 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 3,800 6,378 152 190 26,600 36,131 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.151-35 30# Hybor G Spacer and Dart Drop 37.0 1,571 1,673 40 40 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.152-1 30# Hybor G Minifrac - Treatment 37.0 18,900 20,997 500 500 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.152-2 30# Linear Minifrac - Flush 37.0 13,393 13,426 320 320 1.00 0.33 30.00 2.00 2.00 0.152-3 Produced Water Freeze Protect -2-4 Shut-In Shut-In -2-5 Shut-In Shut-In -2-6 Produced Water Prime Up Pressure Test 5.0 1,000 1,067 25 252-7 Shut-In Shut-In -2-8 30# Linear Spacer and Dart Drop 5.0 250 250 6 6 1.00 0.33 30.00 2.00 2.00 0.152-9 30# Linear Displacement 5.0 13,393 12,503 298 298 1.00 0.33 30.00 2.00 2.00 0.152-10 30# Linear Step Rate Test 20.0 5,000 8,171 195 195 1.00 0.33 30.00 2.00 2.00 0.152-11 30# Hybor G Establish Stable Fluid 20.0 8,400 7,087 169 169 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.152-12 30# Hybor G Pad 37.0 19,800 19,909 474 474 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.152-13 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 16,154 385 389 4,000 3,726 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.152-14 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 3,000 3,694 88 91 3,000 2,432 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.152-15 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 3,750 4,240 101 108 7,500 6,465 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.152-16 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 6,000 5,996 143 159 18,000 15,342 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.152-17 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 7,275 7,294 174 202 29,100 27,041 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.152-18 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 7,500 7,514 179 214 33,750 32,956 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.152-19 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 8,115 8,135 194 236 40,575 39,930 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.152-20 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 8,250 8,281 197 244 45,375 44,036 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.152-21 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 8,700 8,744 208 263 52,200 51,289 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.152-22 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 6,000 6,013 143 185 39,000 39,087 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.152-23 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 4,500 6,506 155 193 31,500 35,788 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.152-24 30# Hybor G Spacer and Dart Drop 37.0 1,571 1,947 46 46 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.153-1 30# Hybor G Pad 37.0 19,800 10,900 260 260 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.153-2 30# Linear Flush 37.0 13,059 13,836 329 329 1.00 0.33 30.00 2.00 2.00 0.153-3 Shut-In Shut-In -50-103-208750909331970Liquid Additives Dry AdditivesInterval 1Kuparuk A Sand@ 20165.3 - 20167.95 ft 142.8 °FInterval 2Kuparuk A Sand@ 19638.9 - 19641.55 ft 142.8 °FConoco Phillips - 3S-610 Actual Design 5
CUSTOMERConoco Phillips API BFD (lb/gal)8.54LAT 70.39420002LEASE3S-610SALES ORDEBHST (°F)144LONG-150.1961825FORMATIONTorokDATE Max Pressure (psi)8500*Exceeds 80% of burst pressure*Prop Slurry Design Clean Actual Clean Actual Clean Calculated Slurry Design Prop Calculated Prop CL-28M Losurf-300D MO-67 Cat-3 BA-20 WG-36 OPTIFLO-III OPTIFLO-II BE-6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total TotalCrosslinker Surfactant Buffer Catalyst BufferInterval Number Description Description Description(ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)50-103-208750909331970Liquid Additives Dry Additives3-4 Shut-In Shut-In -3-5 Sea Water Prime Up Pressure Test 5.0 1,000 1,067 25 253-6 Shut-In Shut-In -3-7 30# Linear Spacer and Ball Drop 15.0 250 100 2 2 1.00 30.00 2.00 2.00 0.153-8 30# Hybor G Establish Stable Fluid 15.0 8,400 8,377 199 199 2.00 1.00 0.85 30.00 2.00 2.00 0.153-9 30# Hybor G Pad 37.0 19,800 19,883 473 473 2.00 1.00 0.85 30.00 2.00 2.00 0.153-10 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 18,086 431 435 4,000 4,356 2.00 1.00 0.85 30.00 2.00 2.00 0.153-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 3,000 4,147 99 102 3,000 3,180 2.00 1.00 0.85 30.00 2.00 2.00 0.153-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 3,750 5,276 126 131 7,500 5,303 2.00 1.00 0.85 30.00 2.00 2.00 0.153-13 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 6,000 6,145 146 163 18,000 15,943 2.00 1.00 0.85 30.00 2.00 2.00 0.153-14 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 7,275 7,283 173 202 29,100 26,604 2.00 1.00 0.85 30.00 2.00 2.00 0.153-15 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 7,500 7,504 179 212 33,750 31,213 2.00 1.00 0.85 30.00 2.00 2.00 0.153-16 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 8,115 8,157 194 236 40,575 39,395 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.153-17 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 8,250 8,245 196 244 45,375 44,513 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.153-18 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 8,700 8,714 207 260 52,200 49,532 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.153-19 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 6,000 6,001 143 182 39,000 37,069 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.153-20 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 4,500 7,780 185 235 31,500 47,252 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.153-21 30# Hybor G Spacer and Ball Drop 10.0 1,570 1,901 45 45 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.154-1 30# Linear Spacer and Dart Drop 37.0 12,723 28,221 672 672 1.00 0.33 30.00 2.00 2.00 0.154-2 30# Hybor G Establish Stable Fluid 37.0 1,500 3,688 88 88 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.154-3 30# Hybor G Pad 37.0 19,800 19,949 475 475 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.154-4 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 16,073 383 387 4,000 3,641 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.154-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 3,000 3,035 72 74 3,000 1,976 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.154-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 3,750 3,764 90 97 7,500 6,664 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.154-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 6,000 6,018 143 160 18,000 16,045 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.154-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 7,275 7,292 174 203 29,100 27,527 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.154-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 7,500 7,513 179 214 33,750 33,125 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.154-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 8,115 8,127 194 236 40,575 40,380 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.154-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 8,250 8,257 197 243 45,375 43,730 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.154-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 8,700 8,702 207 261 52,200 50,648 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.154-13 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 6,000 5,999 143 182 39,000 37,173 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.154-14 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 4,500 7,315 174 217 31,500 40,049 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.154-15 30# Hybor G Spacer and Dart Drop 37.0 1,571 1,675 40 40 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.155-1 30# Hybor G Pad 37.0 19,800 20,526 489 489 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.155-2 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 15,205 362 367 4,000 4,246 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.155-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 3,000 3,062 73 75 3,000 1,899 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.155-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 3,750 3,783 90 97 7,500 6,114 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.155-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 6,000 6,432 153 172 18,000 17,507 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.155-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 7,275 7,281 173 203 29,100 27,737 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.155-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 7,500 7,549 180 215 33,750 33,280 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.155-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 8,115 8,123 193 235 40,575 39,581 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.155-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 8,250 8,269 197 243 45,375 43,272 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.155-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 8,700 8,842 211 268 52,200 53,907 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.155-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 6,000 5,989 143 182 39,000 36,950 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.155-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 4,500 6,937 165 204 31,500 36,311 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.155-13 30# Linear Flush 37.0 12,619 12,533 298 298 1.00 0.25 0.33 30.00 2.00 4.00 0.155-14 Produced Water Freeze Protect 10.0 1,570 -5-15 Shut-In Shut-In -Interval 3Kuparuk A Sand@ 19116.5 - 19119.15 ft 142.8 °FInterval 4Kuparuk A Sand@ 18594.6 - 18597.25 ft 142.8 °FInterval 5Kuparuk A Sand@ 18074.4 - 18077.05 ft 142.8 °FConoco Phillips - 3S-610 Actual Design 6
CUSTOMERConoco Phillips API BFD (lb/gal)8.54LAT 70.39420002LEASE3S-610SALES ORDEBHST (°F)144LONG-150.1961825FORMATIONTorokDATE Max Pressure (psi)8500*Exceeds 80% of burst pressure*Prop Slurry Design Clean Actual Clean Actual Clean Calculated Slurry Design Prop Calculated Prop CL-28M Losurf-300D MO-67 Cat-3 BA-20 WG-36 OPTIFLO-III OPTIFLO-II BE-6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total TotalCrosslinker Surfactant Buffer Catalyst BufferInterval Number Description Description Description(ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)50-103-208750909331970Liquid Additives Dry Additives6-1 Shut-In Shut-In -6-2 Produced Water Prime Up Pressure Test 5.0 1,000 1,067 25 256-3 Shut-In Shut-In - 2.006-4 30# Linear Spacer and Ball Drop 15.0 1,260 168 4 4 1.00 0.33 30.00 2.00 2.00 0.156-5 30# Linear Displacement 15.0 12,059 12,295 293 293 1.00 0.33 30.00 2.00 2.00 0.156-6 30# Linear Step Rate Test 15.0 3,000 5,704 136 136 1.00 0.33 30.00 2.00 2.00 0.156-7 30# Hybor G Establish Stable Fluid 15.0 8,400 26,745 637 637 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.156-8 30# Hybor G Pad 37.0 19,800 10,418 248 248 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.156-9 30# Linear Flush 37.0 12,474 12,474 297 297 1.00 0.33 30.00 2.00 2.00 0.156-10 30# Hybor G Establish Stable Fluid 15.0 8,400 5,289 126 126 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.156-11 30# Hybor G Pad 37.0 19,800 19,846 473 473 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.156-12 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 15,658 373 377 4,000 3,697 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.156-13 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 3,000 3,007 72 73 3,000 1,609 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.156-14 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 3,750 3,746 89 95 7,500 5,500 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.156-15 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 6,000 6,040 144 160 18,000 15,228 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.156-16 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 7,275 7,280 173 202 29,100 26,684 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.156-17 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 7,500 7,653 182 217 33,750 32,724 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.156-18 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 8,115 8,135 194 237 40,575 40,504 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.156-19 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 8,250 8,255 197 245 45,375 45,981 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.156-20 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 8,700 8,898 212 263 52,200 47,827 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.156-21 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 6,000 7,256 173 221 39,000 45,451 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.156-22 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 4,500 7,701 183 230 31,500 44,243 2.00 1.00 1.05 0.25 0.33 30.00 2.00 4.00 0.156-23 30# Hybor G Spacer and Ball Drop 37.0 1,260 2,525 60 60 2.00 1.00 1.05 0.25 0.33 30.00 2.00 4.00 0.157-1 30# Hybor G Pad 37.0 19,800 19,802 471 471 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.157-2 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 17,041 406 410 4,000 3,879 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.157-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 3,000 3,196 76 78 3,000 1,931 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.157-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 3,750 3,773 90 97 7,500 6,497 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.157-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 6,000 6,021 143 162 18,000 17,367 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.157-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 7,275 7,278 173 206 29,100 30,514 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.157-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 7,500 7,485 178 214 33,750 33,617 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.157-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 8,115 8,111 193 236 40,575 40,297 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.157-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 8,250 8,266 197 246 45,375 46,170 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.157-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 8,700 8,673 207 263 52,200 53,090 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.157-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 6,000 6,033 144 184 39,000 38,111 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.157-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 4,500 5,402 129 160 31,500 29,783 2.00 1.00 1.05 0.25 0.33 30.00 2.00 4.00 0.157-13 30# Hybor G Spacer and Ball Drop 37.0 1,260 1,611 38 38 2.00 1.00 1.05 0.25 0.33 30.00 2.00 4.00 0.158-1 30# Hybor G Pad 37.0 19,800 19,910 474 474 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.158-2 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 15,907 379 383 4,000 3,906 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.158-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 3,000 3,016 72 74 3,000 2,501 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.158-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 3,750 3,764 90 97 7,500 6,928 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.158-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 6,000 6,032 144 163 18,000 17,863 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.158-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 7,275 7,336 175 206 29,100 29,902 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.158-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 7,500 7,511 179 215 33,750 33,965 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.158-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 8,115 8,145 194 238 40,575 41,034 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.158-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 8,250 8,272 197 247 45,375 47,121 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.158-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 8,700 8,703 207 260 52,200 50,131 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.158-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 6,000 5,973 142 184 39,000 39,735 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.158-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 4,500 5,631 134 167 31,500 30,665 2.00 1.00 1.05 0.25 0.33 30.00 2.00 4.00 0.158-13 30# Linear Flush 37.0 11,537 11,729 279 279 1.00 0.25 0.33 30.00 2.00 4.00 0.158-14 Produced Water Freeze Protect 5.0 1,570 -8-15 Shut-In Shut-In -Interval 6Kuparuk A Sand@ 17551.8 - 17554.45 ft 142.7 °FInterval 7Kuparuk A Sand@ 17033.6 - 17036.25 ft 142.7 °FInterval 8Kuparuk A Sand@ 16512.4 - 16515.05 ft 142.6 °FConoco Phillips - 3S-610 Actual Design 7
CUSTOMERConoco Phillips API BFD (lb/gal)8.54LAT 70.39420002LEASE3S-610SALES ORDEBHST (°F)144LONG-150.1961825FORMATIONTorokDATE Max Pressure (psi)8500*Exceeds 80% of burst pressure*Prop Slurry Design Clean Actual Clean Actual Clean Calculated Slurry Design Prop Calculated Prop CL-28M Losurf-300D MO-67 Cat-3 BA-20 WG-36 OPTIFLO-III OPTIFLO-II BE-6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total TotalCrosslinker Surfactant Buffer Catalyst BufferInterval Number Description Description Description(ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)50-103-208750909331970Liquid Additives Dry Additives9-1 Shut-In Shut-In -9-2 Produced Water Prime Up Pressure Test 5.0 1,000 1,067 25 259-3 Shut-In Shut-In -9-4 30# Linear Spacer and Ball Drop 15.0 1,260 39 1 1 1.00 0.33 30.00 2.00 2.00 0.159-5 30# Hybor G Establish Stable Fluid 15.0 8,400 7,146 170 170 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.159-6 30# Hybor G Pad 37.0 7,810 7,741 184 184 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.159-7 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 17,068 406 411 4,000 4,239 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.159-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 2,000 2,011 48 50 2,000 1,852 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.159-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 2,500 2,550 61 66 5,000 4,763 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.159-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 4,000 4,033 96 109 12,000 12,419 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.159-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 4,850 4,802 114 135 19,400 19,385 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.159-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 5,000 5,005 119 143 22,500 22,751 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.159-13 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 5,410 5,381 128 157 27,050 27,220 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.159-14 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 5,500 5,476 130 162 30,250 29,529 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.159-15 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 5,800 5,788 138 177 34,800 36,540 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.159-16 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 4,000 3,922 93 120 26,000 25,487 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.159-17 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 3,000 4,203 100 123 21,000 21,154 2.00 1.00 1.05 0.25 0.33 30.00 2.00 4.00 0.159-18 30# Hybor G Spacer and Ball Drop 37.0 1,260 1,390 33 33 2.00 1.00 1.05 0.25 0.33 30.00 2.00 4.00 0.1510-1 30# Hybor G Pad 37.0 7,810 8,059 192 192 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1510-2 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 17,107 407 411 4,000 3,538 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1510-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 2,000 2,068 49 51 2,000 1,428 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1510-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 2,500 2,508 60 65 5,000 4,640 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1510-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 4,000 4,033 96 108 12,000 11,700 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1510-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 4,850 4,931 117 138 19,400 19,856 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1510-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 5,000 5,000 119 143 22,500 22,133 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1510-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 5,410 5,493 131 159 27,050 27,032 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.1510-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 5,500 5,473 130 162 30,250 29,980 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.1510-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 5,800 5,859 140 178 34,800 35,866 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.1510-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 4,000 4,008 95 124 26,000 26,539 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.1510-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 3,000 4,843 115 142 21,000 25,103 2.00 1.00 1.05 0.25 0.33 30.00 2.00 4.00 0.1510-13 30# Hybor G Spacer and Ball Drop 37.0 1,260 1,533 37 37 2.00 1.00 1.05 0.25 0.33 30.00 2.00 4.00 0.1511-1 30# Hybor G Pad 37.0 7,810 7,766 185 185 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1511-2 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 16,364 390 393 4,000 3,119 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1511-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 2,000 2,043 49 51 2,000 1,860 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1511-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 2,500 2,498 59 64 5,000 4,431 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1511-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 4,000 4,081 97 110 12,000 11,970 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1511-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 4,850 4,886 116 137 19,400 19,651 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1511-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 5,000 5,042 120 145 22,500 23,557 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1511-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 5,410 5,477 130 161 27,050 28,575 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.1511-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 5,500 5,508 131 164 30,250 30,956 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.1511-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 5,800 5,850 139 177 34,800 35,903 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.1511-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 4,000 3,993 95 122 26,000 25,668 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.1511-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 3,000 4,064 97 118 21,000 19,711 2.00 1.00 1.05 0.25 0.33 30.00 2.00 4.00 0.1511-13 30# Hybor G Spacer and Ball Drop 37.0 1,260 1,557 37 37 2.00 1.00 1.05 0.25 0.33 30.00 2.00 4.00 0.1512-1 30# Hybor G Pad 37.0 7,810 7,699 183 183 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1512-2 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 16,288 388 392 4,000 3,621 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1512-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 2,000 2,028 48 50 2,000 1,659 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1512-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 2,500 2,561 61 66 5,000 4,425 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1512-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 4,000 4,028 96 108 12,000 10,992 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1512-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 4,850 4,899 117 137 19,400 18,712 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1512-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 5,000 5,046 120 145 22,500 23,107 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1512-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 5,410 5,466 130 159 27,050 27,054 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.1512-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 5,500 5,578 133 165 30,250 30,118 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.1512-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 5,800 6,963 166 204 34,800 36,341 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.1512-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 4,000 4,130 98 126 26,000 25,615 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.1512-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 3,000 4,763 113 141 21,000 26,241 2.00 1.00 1.05 0.25 0.33 30.00 2.00 4.00 0.1512-13 30# Hybor G Spacer and Ball Drop 37.0 1,260 1,954 47 47 2.00 1.00 1.05 0.25 0.33 30.00 2.00 4.00 0.1513-1 30# Hybor G Pad 37.0 7,810 7,683 183 183 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1513-2 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 16,309 388 393 4,000 4,147 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1513-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 2,000 2,015 48 49 2,000 1,227 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1513-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 2,500 2,505 60 65 5,000 4,615 2.00 1.00 1.50 0.33 30.00 2.00 2.00 0.1513-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 4,000 4,057 97 110 12,000 12,466 2.00 1.00 1.50 0.33 30.00 2.00 2.00 0.1513-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 4,850 4,897 117 138 19,400 20,025 2.00 1.00 1.50 0.33 30.00 2.00 2.00 0.1513-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 5,000 4,989 119 143 22,500 22,889 2.00 1.00 1.50 0.33 30.00 2.00 2.00 0.1513-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 5,410 5,422 129 159 27,050 28,068 2.00 1.00 1.50 0.33 30.00 2.00 4.00 0.1513-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 5,500 5,466 130 163 30,250 31,363 2.00 1.00 1.50 0.33 30.00 2.00 4.00 0.1513-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 5,800 5,714 136 174 34,800 35,447 2.00 1.00 1.50 0.33 30.00 2.00 4.00 0.1513-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 4,000 4,008 95 123 26,000 26,254 2.00 1.00 1.50 0.33 30.00 2.00 4.00 0.1513-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 3,000 3,924 93 114 21,000 19,505 2.00 1.00 1.50 0.25 0.33 30.00 2.00 4.00 0.1513-13 30# Linear Flush 37.0 9,878 10,102 241 241 1.00 1.50 0.33 30.00 2.00 4.00 0.1513-14 Produced Water Freeze Protect 5.0 1,570 -13-15 Shut-In Shut-In -Interval 9Kuparuk A Sand@ 15994.9 - 15997.55 ft 142.7 °FInterval 10Kuparuk A Sand@ 15479.4 - 15482.05 ft 142.7 °FInterval 11Kuparuk A Sand@ 14957.6 - 14960.25 ft 142.8 °FInterval 12Kuparuk A Sand@ 14436.6 - 14439.25 ft 143.1 °FInterval 13Kuparuk A Sand@ 13915.1 - 13917.75 ft 143.5 °FConoco Phillips - 3S-610 Actual Design 8
CUSTOMERConoco Phillips API BFD (lb/gal)8.54LAT 70.39420002LEASE3S-610SALES ORDEBHST (°F)144LONG-150.1961825FORMATIONTorokDATE Max Pressure (psi)8500*Exceeds 80% of burst pressure*Prop Slurry Design Clean Actual Clean Actual Clean Calculated Slurry Design Prop Calculated Prop CL-28M Losurf-300D MO-67 Cat-3 BA-20 WG-36 OPTIFLO-III OPTIFLO-II BE-6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total TotalCrosslinker Surfactant Buffer Catalyst BufferInterval Number Description Description Description(ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)50-103-208750909331970Liquid Additives Dry Additives14-1 Shut-In Shut-In -14-2 Produced Water Prime Up Pressure Test 5.0 1,000 1,067 25 2514-3 Shut-In Shut-In -14-4 30# Linear Spacer and Ball Drop 15.0 1,260 174 4 4 1.00 0.33 30.00 2.00 2.00 0.1514-5 30# Linear Displacement 15.0 8,564 22,659 540 540 1.00 0.33 30.00 2.00 2.00 0.1514-6 30# Linear Step Rate Test 15.0 5,700 3,963 94 94 1.00 0.33 30.00 2.00 2.00 0.1514-7 30# Hybor G Establish Stable Fluid 15.0 8,400 3,626 86 86 2.00 1.00 1.10 0.33 30.00 2.00 2.00 0.1514-8 30# Hybor G Pad 37.0 1,000 1,013 24 24 2.00 1.00 1.10 0.33 30.00 2.00 2.00 0.1514-9 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 15,995 381 385 4,000 3,497 2.00 1.00 1.10 0.33 30.00 2.00 2.00 0.1514-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 1,400 1,406 33 35 1,400 976 2.00 1.00 1.10 0.33 30.00 2.00 2.00 0.1514-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 1,750 1,749 42 45 3,500 2,951 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1514-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 2,800 2,794 67 75 8,400 7,974 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1514-13 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 3,395 3,431 82 97 13,580 13,953 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1514-14 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 3,500 3,530 84 101 15,750 16,006 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1514-15 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 3,787 3,797 90 110 18,935 18,711 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1514-16 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 3,850 3,869 92 114 21,175 20,865 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1514-17 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 4,060 4,043 96 121 24,360 23,506 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1514-18 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 2,800 2,820 67 86 18,200 17,783 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1514-19 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 2,100 3,977 95 115 14,700 19,152 2.00 1.00 1.25 0.25 0.33 30.00 2.00 4.00 0.1514-20 30# Hybor G Spacer and Ball Drop 37.0 1,260 1,524 36 36 2.00 1.00 1.25 0.25 0.33 30.00 2.00 4.00 0.1515-1 30# Hybor G Pad 37.0 1,000 989 24 24 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1515-2 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 16,269 387 391 4,000 3,780 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1515-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 1,400 1,417 34 35 1,400 1,138 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1515-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 1,750 1,769 42 45 3,500 3,141 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1515-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 2,800 2,842 68 76 8,400 7,512 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1515-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 3,395 3,344 80 93 13,580 13,003 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1515-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 3,500 3,517 84 100 15,750 15,610 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1515-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 3,787 3,786 90 111 18,935 19,369 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1515-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 3,850 3,878 92 116 21,175 21,951 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1515-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 4,060 4,071 97 122 24,360 23,875 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1515-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 2,800 2,824 67 87 18,200 18,788 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1515-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 2,100 3,166 75 92 14,700 15,393 2.00 1.00 1.25 0.25 0.33 30.00 2.00 4.00 0.1515-13 30# Hybor G Spacer and Ball Drop 37.0 1,260 1,386 33 33 2.00 1.00 1.25 0.25 0.33 30.00 2.00 4.00 0.1516-1 30# Hybor G Pad 37.0 1,000 1,249 30 30 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1516-2 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 15,927 379 384 4,000 4,016 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1516-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 1,400 1,380 33 34 1,400 813 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1516-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 1,750 1,906 45 48 3,500 2,888 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1516-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 2,800 2,790 66 75 8,400 7,764 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1516-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 3,395 3,388 81 95 13,580 13,762 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1516-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 3,500 3,522 84 101 15,750 16,315 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1516-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 3,787 3,787 90 110 18,935 18,972 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1516-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 3,850 3,855 92 114 21,175 20,810 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1516-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 4,060 4,125 98 125 24,360 25,550 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1516-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 2,800 2,768 66 86 18,200 18,892 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1516-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 2,100 3,060 73 88 14,700 14,310 2.00 1.00 1.25 0.25 0.33 30.00 2.00 4.00 0.1516-13 30# Hybor G Spacer and Ball Drop 37.0 1,260 1,437 34 34 2.00 1.00 1.25 0.25 0.33 30.00 2.00 4.00 0.1517-1 30# Hybor G Pad 37.0 1,000 1,067 25 25 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1517-2 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 16,066 383 387 4,000 3,971 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1517-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 1,400 1,421 34 35 1,400 1,352 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1517-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 1,750 1,769 42 45 3,500 2,649 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1517-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 2,800 2,824 67 75 8,400 7,753 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1517-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 3,395 3,401 81 96 13,580 13,693 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1517-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 3,500 3,512 84 101 15,750 16,371 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1517-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 3,787 3,802 91 111 18,935 19,073 2.00 1.00 1.35 0.33 30.00 2.00 4.00 0.1517-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 3,850 3,879 92 115 21,175 21,336 2.00 1.00 1.35 0.33 30.00 2.00 4.00 0.1517-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 4,060 4,067 97 123 24,360 24,717 2.00 1.00 1.35 0.33 30.00 2.00 4.00 0.1517-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 2,800 2,828 67 87 18,200 18,443 2.00 1.00 1.35 0.33 30.00 2.00 4.00 0.1517-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 2,100 3,328 79 96 14,700 15,616 2.00 1.00 1.35 0.25 0.33 30.00 2.00 4.00 0.1517-13 30# Linear Flush 37.0 8,548 8,863 211 211 1.00 0.33 30.00 2.00 4.00 0.1517-14 Produced Water Freeze Protect 5.0 1,000 -17-15 Shut-In Shut-In -Interval 15Kuparuk A Sand@ 12875.8 - 12878.45 ft 144.3 °FInterval 17Kuparuk A Sand@ 11835.2 - 11837.85 ft 144.4 °FInterval 16Kuparuk A Sand@ 12354.1 - 12356.75 ft 144.4 °FInterval 14Kuparuk A Sand@ 13398.1 - 13400.75 ft 143.9 °FConoco Phillips - 3S-610 Actual Design 9
CUSTOMERConoco Phillips API BFD (lb/gal)8.54LAT 70.39420002LEASE3S-610SALES ORDEBHST (°F)144LONG-150.1961825FORMATIONTorokDATE Max Pressure (psi)8500*Exceeds 80% of burst pressure*Prop Slurry Design Clean Actual Clean Actual Clean Calculated Slurry Design Prop Calculated Prop CL-28M Losurf-300D MO-67 Cat-3 BA-20 WG-36 OPTIFLO-III OPTIFLO-II BE-6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total TotalCrosslinker Surfactant Buffer Catalyst BufferInterval Number Description Description Description(ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)50-103-208750909331970Liquid Additives Dry Additives18-1 Shut-In Shut-In -18-2 Produced Water Prime Up Pressure Test 5.0 1,000 1,067 25 2518-3 Shut-In Shut-In -18-4 30# Linear Spacer and Ball Drop 15.0 1,260 55 1 1 1.00 0.33 30.00 2.00 2.00 0.1518-5 30# Linear Displacement 15.0 8,564 6,669 159 159 1.00 0.33 30.00 2.00 2.00 0.1518-6 30# Linear DFIT 15.0 5,700 1,942 46 46 1.00 0.33 30.00 2.00 2.00 0.1518-7 Shut-In Shut-In -18-8 30# Hybor G Establish Stable Fluid 15.0 8,400 4,717 112 112 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1518-9 30# Hybor G Pad 37.0 1,000 978 23 23 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1518-10 30# Hybor G Conditioning Pad 100M 0.25 37.0 16,000 16,071 383 387 4,000 3,967 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1518-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 1,400 1,401 33 35 1,400 1,286 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1518-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 1,750 1,741 41 45 3,500 2,888 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1518-13 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 2,800 2,809 67 75 8,400 7,581 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1518-14 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 3,395 3,418 81 95 13,580 12,515 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1518-15 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 3,500 3,520 84 100 15,750 15,229 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1518-16 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 3,787 3,792 90 110 18,935 18,683 2.00 1.00 1.35 0.33 30.00 2.00 4.00 0.1518-17 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 3,850 3,916 93 115 21,175 20,943 2.00 1.00 1.35 0.33 30.00 2.00 4.00 0.1518-18 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 4,060 4,075 97 123 24,360 24,585 2.00 1.00 1.35 0.33 30.00 2.00 4.00 0.1518-19 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 2,800 3,109 74 95 18,200 19,518 2.00 1.00 1.35 0.33 30.00 2.00 4.00 0.1518-20 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 2,100 3,488 83 101 14,700 16,711 2.00 1.00 1.35 0.25 0.33 30.00 2.00 4.00 0.1518-21 30# Hybor G Spacer and Ball Drop 37.0 1,260 1,398 33 33 2.00 1.00 1.35 0.25 0.33 30.00 2.00 4.00 0.1519-1 30# Hybor G Pad 37.0 1,000 2,073 49 49 2.00 1.00 1.35 0.33 30.00 2.00 2.00 0.1519-2 30# Hybor G Conditioning Pad Wanli 16/20 Ceramic 0.25 37.0 16,000 16,039 382 386 4,000 3,637 2.00 1.00 1.35 0.33 30.00 2.00 2.00 0.1519-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 1,400 1,425 34 35 1,400 1,160 2.00 1.00 1.35 0.33 30.00 2.00 2.00 0.1519-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 1,750 1,834 44 47 3,500 3,353 2.00 1.00 1.35 0.33 30.00 2.00 2.00 0.1519-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 2,800 2,813 67 75 8,400 7,854 2.00 1.00 1.35 0.33 30.00 2.00 2.00 0.1519-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 3,395 3,384 81 94 13,580 13,075 2.00 1.00 1.35 0.33 30.00 2.00 2.00 0.1519-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 3,500 3,509 84 100 15,750 15,379 2.00 1.00 1.35 0.33 30.00 2.00 2.00 0.1519-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 3,787 3,816 91 111 18,935 18,527 2.00 1.00 1.35 0.33 30.00 2.00 4.00 0.1519-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 3,850 3,813 91 113 21,175 20,944 2.00 1.00 1.35 0.33 30.00 2.00 4.00 0.1519-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 4,060 4,097 98 124 24,360 24,864 2.00 1.00 1.35 0.33 30.00 2.00 4.00 0.1519-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 2,800 2,831 67 86 18,200 17,932 2.00 1.00 1.35 0.33 30.00 2.00 4.00 0.1519-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 2,100 3,427 82 99 14,700 16,794 2.00 1.00 1.35 0.25 0.33 30.00 2.00 4.00 0.1519-13 30# Hybor G Spacer and Ball Drop 37.0 1,260 1,406 33 33 2.00 1.00 1.35 0.25 0.33 30.00 2.00 4.00 0.1519-14 30# Hybor G Pad 37.0 1,000 2,112 50 50 2.00 1.00 1.35 0.33 30.00 2.00 2.00 0.1519-15 30# Hybor G Conditioning Pad Wanli 16/20 Ceramic 0.25 37.0 16,000 7,287 174 175 4,000 1,479 2.00 1.00 1.35 0.33 30.00 2.00 2.00 0.1519-16 30# Hybor G Displacement 15.0 1,060 1,095 26 26 2.00 1.00 1.35 0.33 30.00 2.00 2.00 0.1519-17 30# Linear Flush 15.0 1,600 1,599 38 38 1.00 1.35 0.33 30.00 2.00 2.00 0.1519-18 30# Hybor G Establish Stable Fluid 8,400 3,637 87 87 2.00 1.00 1.35 0.33 30.00 2.00 2.00 0.1519-19 30# Hybor G Conditioning Pad Wanli 16/20 Ceramic 0.25 37.0 4,000 5,406 129 130 1,000 1,018 2.00 1.00 1.35 0.33 30.00 2.00 2.00 0.1519-20 30# Linear Flush 37.0 4,000 7,470 178 178 1.00 1.35 0.33 30.00 2.00 2.00 0.1519-21 Shut-In Shut-In - 1.3519-22 30# Hybor G Pad 37.0 1,000 997 24 24 2.00 1.00 1.35 0.33 30.00 2.00 2.00 0.1519-23 30# Hybor G Conditioning Pad Wanli 16/20 Ceramic 0.25 37.0 16,000 7,317 174 176 4,000 1,785 2.00 1.00 1.35 0.33 30.00 2.00 2.00 0.1519-24 30# Linear Flush 15.0 7,179 7,217 172 172 1.00 1.35 0.33 30.00 2.00 2.00 0.1519-25 Shut-In Shut-In - 1.3520-1 30# Hybor G Pad 15.0 1,000 - 2.00 1.00 1.35 0.33 30.00 2.00 2.00 0.1520-2 30# Hybor G Conditioning Pad Wanli 16/20 Ceramic 0.25 37.0 16,000 - 4,000 2.00 1.00 1.35 0.33 30.00 2.00 2.00 0.1520-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 1,400 - 1,400 2.00 1.00 1.35 0.33 30.00 2.00 2.00 0.1520-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 1,750 - 3,500 2.00 1.00 1.35 0.33 30.00 2.00 2.00 0.1520-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 2,800 - 8,400 2.00 1.00 1.35 0.33 30.00 2.00 2.00 0.1520-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 3,395 - 13,580 2.00 1.00 1.35 0.33 30.00 2.00 2.00 0.1520-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 3,500 - 15,750 2.00 1.00 1.35 0.33 30.00 2.00 2.00 0.1520-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 3,787 - 18,935 2.00 1.00 1.35 0.33 30.00 2.00 4.00 0.1520-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 3,850 - 21,175 2.00 1.00 1.35 0.33 30.00 2.00 4.00 0.1520-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 4,060 - 24,360 2.00 1.00 1.35 0.33 30.00 2.00 4.00 0.1520-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 2,800 - 18,200 2.00 1.00 1.35 0.33 30.00 2.00 4.00 0.1520-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 2,100 - 14,700 2.00 1.00 1.35 0.25 0.33 30.00 2.00 4.00 0.1520-13 30# Hybor G Spacer and Ball Drop 37.0 1,260 - 2.00 1.00 1.35 0.25 0.33 30.00 2.00 4.00 0.1521-1 30# Hybor G Pad 37.0 1,000 - 2.00 1.00 1.35 0.33 30.00 2.00 2.00 0.1521-2 30# Hybor G Conditioning Pad Wanli 16/20 Ceramic 0.25 37.0 16,000 - 4,000 2.00 1.00 1.35 0.33 30.00 2.00 2.00 0.1521-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37.0 1,400 - 1,400 2.00 1.00 1.35 0.33 30.00 2.00 2.00 0.1521-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37.0 1,750 - 3,500 2.00 1.00 1.35 0.33 30.00 2.00 2.00 0.1521-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37.0 2,800 - 8,400 2.00 1.00 1.35 0.33 30.00 2.00 2.00 0.1521-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37.0 3,395 - 13,580 2.00 1.00 1.35 0.33 30.00 2.00 2.00 0.1521-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37.0 3,500 - 15,750 2.00 1.00 1.35 0.33 30.00 2.00 2.00 0.1521-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37.0 3,787 - 18,935 2.00 1.00 1.35 0.33 30.00 2.00 4.00 0.1521-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37.0 3,850 - 21,175 2.00 1.00 1.35 0.33 30.00 2.00 4.00 0.1521-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37.0 4,060 - 24,360 2.00 1.00 1.35 0.33 30.00 2.00 4.00 0.1521-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37.0 2,800 - 18,200 2.00 1.00 1.35 0.33 30.00 2.00 4.00 0.1521-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37.0 2,100 - 14,700 2.00 1.00 1.35 0.25 0.33 30.00 2.00 4.00 0.1521-13 30# Linear Flush 37.0 7,179 - 1.00 0.33 30.00 2.00 4.00 0.1521-14 Produced Water Freeze Protect 10.0 1,470 -21-15 Shut-In Shut-In -1,949,599 1,893,770 45,090 49,672 4,620,550 4,313,801Design Total (gal)Actual Total (gal)Design Total (lbs)Calculated Total (lbs)Ticket Total (lbs)CL-28M Losurf-300D MO-67 Cat-3 BA-20 WG-36 OPTIFLO-III OPTIFLO-II BE-61,740,110 1,676,686 4,544,550 4,244,209 4,279,428(gal) (gal) (gal) (gal) (gal) (lbs) (lbs) (lbs) (lbs)194,309 208,550 76,000 69,592 69,000 Initial Design Material Volume 3,463.4 1,924.8 1,795.0 65.8 454.1 57,742.8 3,849.5 5,052.2 288.714,180 7,468 - - - Actual Design Material Volume 3,353.4 1,885.2 1,763.4 74.2 426.7 56,557.1 3,770.5 4,976.1 282.8- - - Physical Material Volume Pumped 3,170 1,787 1673 93 464 54681 3,330 4,510 2941,000 1,067 - - - Physical Material Volume Deviance -5% -5% -5% 25% 9% -3% -12% -9% 4%- -** IFS numbers for proppant are taken from software calculations based on multiple variablesMicroMotion Volume Pumped 3,284 1,804 1,576 81 357 60,515 3,494 4,618 -- -** Proppant is billed from Weight Ticket volumesMicroMotion Volume Deviance -2% -4% -11% 9% -16% 7% -7% -7% -- --Fluid Type30# Hybor G30# LinearProduced WaterFreeze ProtectSea WaterProppant TypeWanli 16/20 Ceramic100M--Interval 18Kuparuk A Sand@ 11314.8 - 11317.45 ft 144.2 °FInterval 19Kuparuk A Sand@ 10810.8 - 10813.45 ft 144.1 °FInterval 20Kuparuk A Sand@ 10294 - 10296.65 ft 144.2 °FInterval 21Kuparuk A Sand@ 9694.5 - 9697.15 ft 143.9 °F---Conoco Phillips - 3S-610 Actual Design 10
Conoco Phillips Torok3S-61050-103-20875*Exceeds 80% of burst pressure*Description OD (in) ID (in) Wt (#) Grade FUF (gal/ft)MD Top (ft)MD Btm (ft) Volume (gal)Tubular Burst Pressure (psi)Tubing4.5 3.958 12.6 L-80 0.6392 0 8,148 5,208 8,430Tubing4.5 3.958 12.6 L-80 0.6392 8,148 21,240 8,368 8,430Total21,24013,577ft1.60ft144.4ftft1.60ft144.4ftTop MD (ft)Btm MD (ft)Average TVD (ft)Interval # Formation DescriptorAverage Interval Temperature (F)Ball Drop Time (HH:MM)Ball Hit Time (HH:MM)JSV Drop (bbl)JSV Slow Down (bbl)JSV Hit (bbl)Early (bbl)Surface Seat Pressure (psi)Surface Peak Pressure (psi)Surface Differential (psi)BH Seat Pressure (psi)BH Peak Pressure (psi)BH Differential (psi)Rate at Shift (bpm)Toe20,165 20,168 5,1771Kuparuk A Sand142.8- - - - - - - - - - - - -19,639 19,642 5,1762Kuparuk A Sand142.85:56:00 PM 6:06:59 PM 2,332 2,611 2,61713.92,675 6,814 4,139 4,274 8,190 3,916 9.419,117 19,119 5,1753Kuparuk A Sand142.88:32:53 AM 8:53:40 AM 2 273 313-0.12,221 4,259 2,038 3,720 5,777 2,057 9.618,595 18,597 5,1754Kuparuk A Sand142.810:14:26 AM 10:24:31 AM 3,156 3,419 3,42910.02,412 7,080 4,668 4,134 9,032 4,898 10.218,074 18,077 5,1735Kuparuk A Sand142.82:19:16 PM 2:28:46 PM 6,705 6,960 6,9728.12,678 6,311 3,633 4,256 7,897 3,641 10.217,552 17,554 5,1716Kuparuk A Sand142.79:59:00 AM 10:19:00 AM 4 251 283-11.61,787 7,078 5,291 3,558 8,893 5,335 10.517,034 17,036 5,1667Kuparuk A Sand142.71:41:00 PM 1:50:00 PM 4,574 4,783 4,8321.22,917 5,834 2,917 4,232 7,164 2,932 10.016,512 16,515 5,1658Kuparuk A Sand142.63:02:00 PM 3:11:00 PM 7,360 7,571 7,6083.32,693 6,917 4,224 4,264 8,684 4,420 10.015,995 15,998 5,1669Kuparuk A Sand142.711:38:00 AM 11:55:00 AM 1 204 23212.12,099 5,268 3,169 3,293 6,308 3,015 9.915,479 15,482 5,16910Kuparuk A Sand142.712:46:00 PM 12:54:00 PM 2,044 2,240 2,2736.62,192 5,099 2,907 3,725 6,534 2,809 10.014,958 14,960 5,17611Kuparuk A Sand142.81:41:00 PM 1:49:00 PM 3,952 4,140 4,1763.62,368 5,247 2,879 3,793 6,434 2,641 10.014,437 14,439 5,19212Kuparuk A Sand143.12:36:00 PM 2:43:00 PM 5,815 5,995 6,0277.72,149 5,838 3,689 3,689 7,295 3,606 10.013,915 13,918 5,21813Kuparuk A Sand143.53:31:00 PM 3:37:00 PM 7,731 7,903 7,92715.81,420 2,894 1,474 3,248 4,703 1,455 10.113,398 13,401 5,24714Kuparuk A Sand143.911:15:00 AM 11:29:00 AM 333 497 5297.9802 2,812 2,010 255 3,812 3,557 9.912,876 12,878 5,26615Kuparuk A Sand144.312:30:00 PM 12:37:00 PM 2,069 2,225 2,2614.02,184 7,085 4,901 3,590 8,746 5,156 10.012,354 12,357 5,27516Kuparuk A Sand144.41:14:00 PM 1:21:00 PM 3,395 3,543 3,5758.01,954 4,984 3,030 3,420 6,072 2,652 10.011,835 11,838 5,27517Kuparuk A Sand144.41:53:00 PM 2:00:00 PM 4,719 4,859 4,8927.11,739 4,056 2,317 3,258 5,612 2,354 10.111,315 11,317 5,26418Kuparuk A Sand144.29:42:00 AM 9:55:00 AM 0 132 15913.2515 1,813 1,298 2,270 3,606 1,336 10.110,811 10,813 5,25819Kuparuk A Sand144.111:02:00 AM 11:08:00 AM 1,655 1,780 1,8163.51,390 3,899 2,509 3,170 4,893 1,723 10.010,294 10,297 5,26020Kuparuk A Sand144.22:37:00 PM No Seat 3,700 3,817 NA NA NA NA NA NAHeel9,695 9,697 5,24421Kuparuk A Sand143.92:55:00 PM No Seat 3,934 4,042 NA NA NA NA NA NA208.0200.1192.2184.5176.7279.2271.3263.4255.6247.6239.7167.58,4058,0727,7507,4207,03710,0689,7359,4049,0708,73711,72811,39511,06410,73410,40113,059 310.912,72612,39312,059Displacement to Top Sleeve/Perf (gal) with 20 bbl over flush(BBLS)13,730 326.913,393 318.9303.0295.1287.1Interval #1Max Pressure (psi)8,500Isolation TypeSwell PackerTreatment TubularsCustomerFormationLeaseAPIDateTemperature DataTemp. Gradient (°F/100 ft)BHST (°F)Directional Data4,5952,23721,240Directional Data2,2375/18/2024KOPTemperature DataSleeve/Perf Depth Sleeves231.8223.9216.078910112345617181920211213141516Temp. Gradient (°F/100 ft)BHST (°F)TVD at Bottom PerfMD at Bottom Perf5,27520,168KOPAvg. TVDTotal MDConoco Phillips - 3S-610 Wellbore Information 11
5/18/24 15:36
5/19/24 17:56
167 min
-bpm
-psi
-psi
-bbl
36.4 bpm
4,674 psi
6,171 psi
29.9 bpm
3,692 psi
3,718 psi
5,277 psi
2,706 hhp
1029 psi
82 psi
739 psi
7.05 ppg
5
5
39 %
40 %
22 cP
98.2 F
8.8
DFIT
10.200 bpm
2358 psi
5119 psi
14.6 bpm
3302 psi
5471 psi
784.5 psi
0.152 psi/ft
784 psi
118 psi
100.9 psi
288,733 lbs
4,246 lbs
292,979 lbs
292,979 lbs
167,334 gal 3,984 bbls
6,388 gal 152 bbls
2,134 gal 51 bbls
40,206 gal 957 bbls
18,097 gal 431 bbls
76,460 gal 1,820 bbls
1,673 gal 40 bbls
100 gal 2 bbls
13,993 gal 333 bbls
2,966 gal 71 bbls
16,905 gal 403 bbls
3,063 gal 73 bbls
259 gal 6 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:Chad Burkett
Steven Sanders
Total Proppant Pumped* :
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Flush Volume:
Establish Stable Fluid Volume:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Step Rate Test Volume:
Spacer and Dart Drop Volume:
Spacer and Ball Drop Volume:
Interval Status:
Nathan Brzezinski
James Campbell
On May 18th the well was opened to start interval 1. Due to a leak during the 4ppg stage the
well had to be flushed. Max surface pressure was 4,253 psi and average surface pressure
was 3351 psi. Max downhole pressure was 6068 psi and average downhole pressure was
4,977 psi. Max rate was 32 bpm and average rate was 27 bpm. Volume pumped on day 1 was
2092 bbls. Stage was resumed and completed on May 19th.
DFIT Volume:
Arsenal Sleeve Shift Volume:
Proppant Summary
Minifrac Average Pressure:
Minifrac Average DH Pressure:
Average Visc:
Average Temp:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Max Rate:
Max Surface Pressure:
Max BH Pressure:
Interval Summary
3S-610 - Torok - Interval 1
Interval Summary
Start Date/Time:
End Date/Time:
Average Surface Pressure:
Average Rate:
Max OA Pressure:
Pumps Starting Stage:
Pad Percentage Design
Average Missile HHP:
Initial BH Pressure (Breakdown):
Average BH Pressure:
Pumps Ending Stage:
Max Proppant Concentration:
Pump Time:
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
ISDP:
Final Fracture Gradient:
Final 10 min:
Pad Volume:
Minifrac Max Surface Pressure:
100M Pumped:
Final 15 min:
Proppant in Formation:
30# Hybor G Volume:
30# Linear Volume:
Produced Water Volume:
Minifrac Max DH Pressure:
Final 5 min:
Dart/Ball Early :
Average pH:
Minifrac Average Rate:
Pad Percentage Actual
Wanli 16/20 Ceramic Pumped:
Diagnostic method
Average Missile Pressure:
Minifrac Max Rate:
Open Well Pressure:
Initial OA Pressure:
Conoco Phillips - 3S-610 Interval Summary 12
5/20/24 10:46
5/20/24 13:12
145 min
9.4 bpm
6,814 psi
8,190 psi
14 bbl
36.8 bpm
5,531 psi
5,552 psi
24.5 bpm
3,742 psi
3,733 psi
5,331 psi
2,247 hhp
1066 psi
8 psi
775 psi
7.20 ppg
5
3
32 %
31 %
23 cP
91.8 F
8.7
Mini Frac
24.500 bpm
5406 psi
6775 psi
34.8 bpm
6642 psi
8026 psi
1129 psi
0.218 psi/ft
1075 psi
904 psi
735 psi
294,366 lbs
3,726 lbs
298,092 lbs
298,092 lbs
132,511 gal 3,155 bbls
34,350 gal 818 bbls
1,067 gal 25 bbls
19,909 gal 474 bbls
16,154 gal 385 bbls
66,417 gal 1,581 bbls
12,503 gal 298 bbls
2,197 gal 52 bbls
8,171 gal 195 bbls
7,087 gal 169 bbls
20,997 gal 500 bbls
13,426 gal 320 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Status:
Interval 2 Mini Frac was completed on the May 19th. Due to leaks on the treating line, the
decision was made to continue the treatment the next morning. On May 20th the job was
completed as per design.
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Greg Clayton
Steven Sanders
Nathan Brzezinski
James Campbell
Wanli 16/20 Ceramic Pumped:
100M Pumped:
Total Proppant Pumped* :
30# Hybor G Volume:
30# Linear Volume:
Produced Water Volume:
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Displacement Volume:
Spacer and Dart Drop Volume:
Step Rate Test Volume:
Establish Stable Fluid Volume:
Minifrac Average Pressure:
Minifrac Average DH Pressure:
Final 15 min:
Proppant Summary
Interval Summary
Start Date/Time:
End Date/Time:
Pump Time:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Max Rate:
Max Surface Pressure:
Max BH Pressure:
Average Rate:
Average Missile Pressure:
Average Surface Pressure:
Minifrac Average Rate:
3S-610 - Torok - Interval 2
Average BH Pressure:
Average Missile HHP:
Open Well Pressure:
Initial OA Pressure:
Max OA Pressure:
Max Proppant Concentration:
Pumps Starting Stage:
Pumps Ending Stage:
Average Visc:
Average Temp:
Average pH:
Diagnostic method
Pad Percentage Design
Pad Percentage Actual
ISDP:
Final Fracture Gradient:
Final 5 min:
Minifrac Max DH Pressure:
Final 10 min:
Proppant in Formation:
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Minifrac Max Rate:
Minifrac Max Surface Pressure:
Pad Volume:
Minifrac - Treatment Volume:
Minifrac - Flush Volume:
Conoco Phillips - 3S-610 Interval Summary 13
5/21/24 8:00
5/21/24 10:24
144 min
9.6 bpm
4,259 psi
5,777 psi
0 bbl
36.9 bpm
6,324 psi
7,672 psi
27.8 bpm
3,965 psi
3,989 psi
5,488 psi
2,702 hhp
861 psi
24 psi
644 psi
7.50 ppg
4
4
42 %
37 %
25 cP
83 F
9.3
300,004 lbs
4,356 lbs
304,360 lbs
304,360 lbs
128,399 gal 3,057 bbls
13,936 gal 332 bbls
1,067 gal 25 bbls
30,783 gal 733 bbls
18,086 gal 431 bbls
69,252 gal 1,649 bbls
2,001 gal 48 bbls
13,836 gal 329 bbls
8,377 gal 199 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Establish Stable Fluid Volume:
30# Hybor G Volume:
Steven Sanders
Nathan Brzezinski
James Campbell
Interval Status:
Interval 3 was pumped as per design with sea water and not produced water as a base fluid.
Extra sea water pumped downhole before pad in order to reduce the quantity on location.
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Total Proppant Pumped* :
Proppant in Formation:
Fluid Summary (by fluid description)
Proppant Laden Fluid Volume:
Flush Volume:
Greg Clayton
3S-610 - Torok - Interval 3
End Date/Time:
Max BH Pressure:
Average Rate:
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Max Rate:
Max Surface Pressure:
Pump Time:
Initial Rate (Breakdown):
Fluid Summary (by stage description)
Conditioning Pad Volume:
Initial Surface Pressure (Breakdown):
Start Date/Time:
Pad Percentage Design
Pad Percentage Actual
Average Visc:
Initial OA Pressure:
Average Missile HHP:
Average Temp:
Average Missile Pressure:
Average Surface Pressure:
Average BH Pressure:
Pumps Starting Stage:
Pumps Ending Stage:
Average pH:
30# Linear Volume:
Sea Water Volume:
100M Pumped:
Max OA Pressure:
Max Proppant Concentration:
Open Well Pressure:
Interval Summary
Wanli 16/20 Ceramic Pumped:
Pad Volume:
Proppant Summary
Spacer and Ball Drop Volume:
Conoco Phillips - 3S-610 Interval Summary 14
5/21/24 10:24
5/21/24 14:28
244 min
10.2 bpm
7,080 psi
9,032 psi
10 bbl
36.8 bpm
6,316 psi
7,897 psi
33.2 bpm
3,955 psi
3,968 psi
5,449 psi
3,218 hhp
590 psi
814 psi
6.75 ppg
4
4
32 %
31 %
26 cP
92 F
8.7
297,317 lbs
3,641 lbs
300,958 lbs
300,958 lbs
107,407 gal 2,557 bbls
28,221 gal 672 bbls
19,949 gal 475 bbls
16,073 gal 383 bbls
66,022 gal 1,572 bbls
29,896 gal 712 bbls
3,688 gal 88 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:Greg Clayton
Steven Sanders
Nathan Brzezinski
At the beginning of interval 4, the pumps kicked out due to high ball seat peak pressure.
Pressure was brought up until kickout pressure was reached and then blead down on surface
until a pressure break was achieved. Another ball was dropped and the remainder of the
interval was completed as per design. James Campbell
Pad Volume:
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Fluid Summary (by stage description)
Establish Stable Fluid Volume:
Interval Status:
Max BH Pressure:
Proppant Summary
Wanli 16/20 Ceramic Pumped:
Total Proppant Pumped* :
Pad Percentage Design
Average Surface Pressure:
Pumps Starting Stage:
100M Pumped:
Max OA Pressure:
Max Proppant Concentration:
Average Visc:
Average Temp:
Average pH:
Initial OA Pressure:
Initial Surface Pressure (Breakdown):
End Date/Time:
Pump Time:
3S-610 - Torok - Interval 4
Interval Summary
Start Date/Time:
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Max Rate:
Average Rate:
Average Missile Pressure:
Average BH Pressure:
Average Missile HHP:
Pumps Ending Stage:
Pad Percentage Actual
30# Linear Volume:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Initial Rate (Breakdown):
Proppant in Formation:
Max Surface Pressure:
Fluid Summary (by fluid description)
Spacer and Dart Drop Volume:
30# Hybor G Volume:
Conoco Phillips - 3S-610 Interval Summary 15
5/21/24 14:28
5/21/24 15:51
82 min
10.2 bpm
6,311 psi
7,897 psi
8 bbl
37.7 bpm
6,298 psi
7,727 psi
34.2 bpm
4,565 psi
4,550 psi
6,028 psi
3,827 hhp
754 psi
815 psi
7.08 ppg
4
4
32 %
31 %
24 cP
110 F
8.6
3091 psi
0.597 psi/ft
3065 psi
3007 psi
2877 psi
296,558 lbs
4,246 lbs
300,804 lbs
300,804 lbs
101,998 gal 2,429 bbls
12,533 gal 298 bbls
20,526 gal 489 bbls
15,205 gal 362 bbls
66,267 gal 1,578 bbls
12,533 gal 298 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
End Date/Time:
Max BH Pressure:
Average Surface Pressure:
Interval Summary
Final 10 min:
Final 15 min:
Proppant Summary
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Wanli 16/20 Ceramic Pumped:
Conditioning Pad Volume:
30# Linear Volume:
100M Pumped:
Flush Volume:
3S-610 - Torok - Interval 5
Average BH Pressure:
Initial OA Pressure:
Max Proppant Concentration:
Start Date/Time:
Pad Percentage Design
Average Rate:
Proppant in Formation:
Pad Volume:
Final 5 min:
Steven Sanders
Average Missile HHP:
Average Visc:
Max Surface Pressure:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Average pH:
Pad Percentage Actual
Greg Clayton
James Campbell
Pump Time:
ISDP:
Nathan Brzezinski
Interval 5 was pumped to completion.
Pumps Starting Stage:
Pumps Ending Stage:
Final Fracture Gradient:
Average Missile Pressure:
Max OA Pressure:
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Average Temp:
Initial Surface Pressure (Breakdown):
Max Rate:
30# Hybor G Volume:
Total Proppant Pumped* :
Initial Rate (Breakdown):
Proppant Laden Fluid Volume:
Interval Status:
Conoco Phillips - 3S-610 Interval Summary 16
5/23/24 9:56
5/23/24 13:50
234 min
10.5 bpm
7,078 psi
8,893 psi
-12 bbl
37.3 bpm
4,849 psi
6,063 psi
33.6 bpm
3,731 psi
3,733 psi
5,178 psi
3,074 hhp
400 psi
130 psi
845 psi
7.10 ppg
6
6
42 %
36 %
23 cP
96 F
8.9
305,751 lbs
3,697 lbs
309,448 lbs
309,448 lbs
148,452 gal 3,535 bbls
30,641 gal 730 bbls
1,067 gal 25 bbls
30,264 gal 721 bbls
15,658 gal 373 bbls
67,971 gal 1,618 bbls
12,295 gal 293 bbls
2,693 gal 64 bbls
12,474 gal 297 bbls
5,704 gal 136 bbls
32,034 gal 763 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Pump Time:
Initial Rate (Breakdown):
Average Missile HHP:
3S-610 - Torok - Interval 6
Interval Summary
Average pH:
Proppant Summary
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Establish Stable Fluid Volume:
Displacement Volume:
Pumps Starting Stage:
Max Rate:
Average Missile Pressure:
Step Rate Test Volume:
Average Rate:
Proppant in Formation:
Average Visc:
Average Surface Pressure:
Average BH Pressure:
100M Pumped:
Pumps Ending Stage:
Conditioning Pad Volume:
Interval Status:
Flush Volume:
Pad Volume:
Wanli 16/20 Ceramic Pumped:
Pad Percentage Design
Average Temp:
Total Proppant Pumped* :
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Dart/Ball Early :
A step rate test was pumped after displacing the ball with linear gel. During the establish stable
fluid pad, good XL pH could not be achieved. Decision was made to switch totes which solved
the issue. Shortly after staging into Pad, one of the hoses to the ADP wedding ring
disconnected and gel had to stop being mixed. After flushing the well with gel and shutting
down for 18 min, the hose was fixed and establish stable fluid was restarted. During 6.0 ppg,
the Mountain Mover engine shut off and sand had to be swapped to a mover, the sand
concentration momentarily dropped. The stage was pumped to completion.
William Martin
Craig Karpinski
James Campbell
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Greg Clayton
Proppant Laden Fluid Volume:
End Date/Time:
Max Surface Pressure:
Max BH Pressure:
Produced Water Volume:
Open Well Pressure:
Max OA Pressure:
Spacer and Ball Drop Volume:
Max Proppant Concentration:
Pad Percentage Actual
Initial OA Pressure:
Start Date/Time:
30# Hybor G Volume:
30# Linear Volume:
Conoco Phillips - 3S-610 Interval Summary 17
5/23/24 13:50
5/23/24 15:11
81 min
10.0 bpm
5,834 psi
7,164 psi
1 bbl
37.4 bpm
4,375 psi
5,680 psi
34.7 bpm
3,571 psi
3,600 psi
5,074 psi
3,039 hhp
755 psi
797 psi
7.38 ppg
6
6
32 %
32 %
21 cP
93.4 F
8.8
297,377 lbs
3,879 lbs
301,256 lbs
301,256 lbs
102,692 gal 2,445 bbls
19,802 gal 471 bbls
17,041 gal 406 bbls
64,238 gal 1,529 bbls
1,611 gal 38 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Status:
Interval 7 was pumped as per design.
Fluid Summary (by fluid description)
Spacer and Ball Drop Volume:
30# Hybor G Volume:
Greg Clayton
William Martin
James Campbell
Fluid Summary (by stage description)
Craig Karpinski
Interval Summary
Pump Time:
Max Rate:
Initial BH Pressure (Breakdown):
Start Date/Time:
Pumps Ending Stage:
Pad Volume:
100M Pumped:
Average pH:
Max Proppant Concentration:
Dart/Ball Early :
Pad Percentage Actual
Initial OA Pressure:
Pad Percentage Design
Pumps Starting Stage:
Proppant Summary
Proppant in Formation:
Proppant Laden Fluid Volume:
Average Visc:
Max Surface Pressure:
Max BH Pressure:
Average Rate:
Average Missile Pressure:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Max OA Pressure:
Total Proppant Pumped* :
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Average BH Pressure:
Average Surface Pressure:
Wanli 16/20 Ceramic Pumped:
Average Temp:
Average Missile HHP:
3S-610 - Torok - Interval 7
End Date/Time:
Conditioning Pad Volume:
Conoco Phillips - 3S-610 Interval Summary 18
5/23/24 15:11
5/23/24 16:29
78 min
10.0 bpm
6,917 psi
8,684 psi
3 bbl
37.2 bpm
4,433 psi
5,731 psi
35.6 bpm
3,586 psi
3,616 psi
5,105 psi
3,126 hhp
630 psi
684 psi
7.03 ppg
6
6
32 %
32 %
23 cP
91.7 F
8.9
3245 psi
0.628 psi/ft
3150 psi
3091 psi
3043 psi
299,845 lbs
3,906 lbs
303,751 lbs
303,751 lbs
100,200 gal 2,386 bbls
11,729 gal 279 bbls
19,910 gal 474 bbls
15,907 gal 379 bbls
64,383 gal 1,533 bbls
11,729 gal 279 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
William Martin
Greg Clayton
Craig Karpinski
James Campbell
30# Hybor G Volume:
Interval Status:
Interval 8 was pumped as per design.
Proppant Laden Fluid Volume:
Wanli 16/20 Ceramic Pumped:
100M Pumped:
Proppant Summary
Interval Summary
3S-610 - Torok - Interval 8
Fluid Summary (by fluid description)
Pad Volume:
Average Visc:
Total Proppant Pumped* :
30# Linear Volume:
Final 5 min:
Final Fracture Gradient:
Final 15 min:
Conditioning Pad Volume:
Average Missile HHP:
Fluid Summary (by stage description)
Pad Percentage Actual
Pad Percentage Design
Initial Surface Pressure (Breakdown):
Start Date/Time:
Initial BH Pressure (Breakdown):
Average pH:
Average Surface Pressure:
Max Rate:
Pumps Starting Stage:
ISDP:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Proppant in Formation:
Final 10 min:
Average Temp:
Average Missile Pressure:
Initial Rate (Breakdown):
Max Surface Pressure:
Pumps Ending Stage:
Average Rate:
Max Proppant Concentration:
Average BH Pressure:
Max OA Pressure:
Initial OA Pressure:
Max BH Pressure:
Dart/Ball Early :
End Date/Time:
Pump Time:
Flush Volume:
Conoco Phillips - 3S-610 Interval Summary 19
5/24/24 11:38
5/24/24 12:54
76 min
9.9 bpm
5,268 psi
6,308 psi
12 bbl
37.6 bpm
3,775 psi
5,127 psi
34.9 bpm
3,275 psi
3,272 psi
4,665 psi
2,803 hhp
249 psi
207 psi
702 psi
7.16 ppg
6
6
32 %
32 %
28 cP
97.3 F
8.7
201,100 lbs
4,239 lbs
205,339 lbs
205,339 lbs
76,516 gal 1,822 bbls
39 gal 1 bbls
1,067 gal 25 bbls
7,741 gal 184 bbls
17,068 gal 406 bbls
43,171 gal 1,028 bbls
1,429 gal 34 bbls
7,146 gal 170 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Start Date/Time:
End Date/Time:
Pump Time:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
William Martin
Craig Karpinski
Average Temp:
Max Proppant Concentration:
Pumps Starting Stage:
Average Surface Pressure:
Greg Clayton
Establish Stable Fluid Volume:
Spacer and Ball Drop Volume:
30# Hybor G Volume:
30# Linear Volume:
3S-610 - Torok - Interval 9
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Initial BH Pressure (Breakdown):
Produced Water Volume:
Fluid Summary (by stage description)
Average pH:
Fluid Summary (by fluid description)
Total Proppant Pumped* :
Max Surface Pressure:
Max BH Pressure:
Initial Rate (Breakdown):
Max Rate:
Pumps Ending Stage:
Initial Surface Pressure (Breakdown):
Proppant Summary
Wanli 16/20 Ceramic Pumped:
Average Missile Pressure:
Interval Summary
Open Well Pressure:
Dart/Ball Early :
Average Visc:
Pad Percentage Design
Max OA Pressure:
Proppant in Formation:
Initial OA Pressure:
Average Rate:
100M Pumped:
Pad Percentage Actual
Interval Status:
Pad Volume:
Average Missile HHP:
James Campbell
Average BH Pressure:
Interval 09 was pumped as per design.
Conoco Phillips - 3S-610 Interval Summary 20
5/24/24 12:54
5/24/24 13:49
55 min
10.0 bpm
5,099 psi
6,534 psi
7 bbl
37.4 bpm
3,734 psi
5,052 psi
35.0 bpm
3,079 psi
3,102 psi
4,573 psi
2,639 hhp
701 psi
830 psi
7.56 ppg
6
6
32 %
32 %
24 cP
97.3 F
8.9
204,277 lbs
3,538 lbs
207,815 lbs
207,815 lbs
70,915 gal 1,688 bbls
8,059 gal 192 bbls
17,107 gal 407 bbls
44,216 gal 1,053 bbls
1,533 gal 37 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Craig Karpinski
James Campbell
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Greg Clayton
Initial BH Pressure (Breakdown):
Pad Percentage Actual
Pumps Starting Stage:
Dart/Ball Early :
30# Hybor G Volume:
Average Visc:
Pad Percentage Design
Max OA Pressure:
Average pH:
Average BH Pressure:
Average Surface Pressure:
Interval Summary
Pump Time:
Start Date/Time:
3S-610 - Torok - Interval 10
End Date/Time:
Interval 10 was pumped as per design.
Average Missile HHP:
Wanli 16/20 Ceramic Pumped:
Initial OA Pressure:
Max Proppant Concentration:
Proppant Laden Fluid Volume:
100M Pumped:
Pad Volume:
Conditioning Pad Volume:
Average Temp:
Initial Surface Pressure (Breakdown):
Proppant Summary
Average Missile Pressure:
Average Rate:
Total Proppant Pumped* :
Proppant in Formation:
Fluid Summary (by fluid description)
Max Surface Pressure:
Max BH Pressure:
Pumps Ending Stage:
Max Rate:
Initial Rate (Breakdown):
Interval Status:
Spacer and Ball Drop Volume:
Fluid Summary (by stage description)
William Martin
Conoco Phillips - 3S-610 Interval Summary 21
5/24/24 13:49
5/24/24 14:43
54 min
10.0 bpm
5,247 psi
6,434 psi
4 bbl
37.3 bpm
5,006 psi
6,347 psi
35.0 bpm
3,518 psi
3,528 psi
4,978 psi
3,019 hhp
825 psi
878 psi
7.18 ppg
6
6
32 %
32 %
26 cP
95.8 F
8.7
202,282 lbs
3,119 lbs
205,401 lbs
205,401 lbs
69,129 gal 1,646 bbls
7,766 gal 185 bbls
16,364 gal 390 bbls
43,442 gal 1,034 bbls
1,557 gal 37 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Fluid Summary (by stage description)
Pad Volume:
After seating the ball and increasing rate, pressure was higher than the previous stages but
trended back down once 100 Mesh hit downhole. Stage pumped to completion.
Greg Clayton
Craig Karpinski
James Campbell
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Pad Percentage Design
Average Surface Pressure:
Max OA Pressure:
Max BH Pressure:
Average Rate:
Average BH Pressure:
Interval Summary
Proppant Summary
Fluid Summary (by fluid description)
Total Proppant Pumped* :
Proppant in Formation:
Pumps Ending Stage:
Pump Time:
Initial BH Pressure (Breakdown):
Dart/Ball Early :
30# Hybor G Volume:
3S-610 - Torok - Interval 11
End Date/Time:
Max Proppant Concentration:
Average Visc:
Average Temp:
Max Rate:
Wanli 16/20 Ceramic Pumped:
Average pH:
Pad Percentage Actual
Initial OA Pressure:
William Martin
Pumps Starting Stage:
100M Pumped:
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Start Date/Time:
Interval Status:
Average Missile HHP:
Initial Rate (Breakdown):
Average Missile Pressure:
Initial Surface Pressure (Breakdown):
Max Surface Pressure:
Spacer and Ball Drop Volume:
Conoco Phillips - 3S-610 Interval Summary 22
5/24/24 14:43
5/24/24 15:37
54 min
10.0 bpm
5,838 psi
7,295 psi
8 bbl
37.7 bpm
3,863 psi
5,196 psi
35.5 bpm
3,228 psi
3,243 psi
4,738 psi
2,807 hhp
861 psi
922 psi
7.07 ppg
6
6
32 %
31 %
23 cP
102.7 F
8.8
204,264 lbs
3,621 lbs
207,885 lbs
207,885 lbs
71,403 gal 1,700 bbls
7,699 gal 183 bbls
16,288 gal 388 bbls
45,462 gal 1,082 bbls
1,954 gal 47 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Pumps Starting Stage:
Max Proppant Concentration:
Pump Time:
3S-610 - Torok - Interval 12
Interval Summary
Initial BH Pressure (Breakdown):
Average Missile HHP:
Initial Surface Pressure (Breakdown):
Max OA Pressure:
Average pH:
Max Rate:
Initial OA Pressure:
End Date/Time:
Dart/Ball Early :
Max BH Pressure:
Average Visc:
Craig Karpinski
Greg Clayton
Average Surface Pressure:
Start Date/Time:
Average Rate:
Average Missile Pressure:
Pad Percentage Actual
Initial Rate (Breakdown):
Average BH Pressure:
Interval 12 was pumped as per design. William Martin
Proppant Summary
Fluid Summary (by fluid description)
30# Hybor G Volume:
Fluid Summary (by stage description)
100M Pumped:
Max Surface Pressure:
Spacer and Ball Drop Volume:
Interval Status:
Pad Volume:
Conditioning Pad Volume:
James Campbell
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Total Proppant Pumped* :
Wanli 16/20 Ceramic Pumped:
Pumps Ending Stage:
Pad Percentage Design
Proppant in Formation:
Proppant Laden Fluid Volume:
Average Temp:
Conoco Phillips - 3S-610 Interval Summary 23
5/24/24 15:37
5/24/24 16:30
53 min
10.1 bpm
2,894 psi
4,703 psi
16 bbl
37.8 bpm
3,593 psi
4,908 psi
36.7 bpm
316 psi
3,176 psi
4,609 psi
284 hhp
867 psi
884 psi
7.14 ppg
6
6
32 %
32 %
23 cP
102.4 F
9
3182 psi
0.610 psi/ft
2989 psi
2934 psi
2762 psi
201,859 lbs
4,147 lbs
206,006 lbs
206,006 lbs
66,989 gal 1,595 bbls
10,102 gal 241 bbls
7,683 gal 183 bbls
16,309 gal 388 bbls
42,997 gal 1,024 bbls
10,102 gal 241 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Proppant Laden Fluid Volume:
Final 15 min:
Fluid Summary (by stage description)
The sleeve shifted at a lower pressure than previous stages and there was another pressure
drop after increasing rate. It is assumed that after seating the ball the sleeve only partially
shifted and fully shifted after gaining rate. MO set point had to be increased to 1.25 in the 2
ppg sand stage. Interval pumped to completion.
William Martin
Craig Karpinski
James Campbell
Fluid Summary (by fluid description)
30# Linear Volume:
Greg Clayton
Interval Summary
End Date/Time:
Average Missile HHP:
Flush Volume:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Final 5 min:
Final 10 min:
Pad Percentage Design
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Max Surface Pressure:
Max Proppant Concentration:
Conditioning Pad Volume:
Pad Percentage Actual
ISDP:
Final Fracture Gradient:
Total Proppant Pumped* :
Average Visc:
Initial OA Pressure:
Average Surface Pressure:
Initial BH Pressure (Breakdown):
Average Missile Pressure:
Pump Time:
3S-610 - Torok - Interval 13
Max BH Pressure:
Pumps Ending Stage:
Pumps Starting Stage:
Average Rate:
Proppant Summary
Dart/Ball Early :
Max OA Pressure:
Average pH:
Average Temp:
Pad Volume:
Start Date/Time:
Max Rate:
Wanli 16/20 Ceramic Pumped:
Average BH Pressure:
100M Pumped:
Proppant in Formation:
30# Hybor G Volume:
Interval Status:
Conoco Phillips - 3S-610 Interval Summary 24
5/25/24 10:46
5/25/24 12:37
111 min
9.9 bpm
2,812 psi
3,812 psi
8 bbl
37.6 bpm
3,214 psi
4,556 psi
34.7 bpm
2,749 psi
2,672 psi
4,128 psi
2,340 hhp
115 psi
29 psi
795 psi
6.82 ppg
6
6
33 %
31 %
22 cP
107.5 F
8.8
141,877 lbs
3,497 lbs
145,374 lbs
145,374 lbs
53,574 gal 1,276 bbls
26,796 gal 638 bbls
1,067 gal 25 bbls
1,013 gal 24 bbls
15,995 gal 381 bbls
31,416 gal 748 bbls
22,659 gal 540 bbls
1,698 gal 40 bbls
3,963 gal 94 bbls
3,626 gal 86 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Conditioning Pad Volume:
After getting injection and launching the ball, no ball signature was observed after pumping a
wellbore volume. The acid pumper was brought online and a ball signature was observed a
wellbore volume after that. Stage pumped to completion.
Fluid Summary (by stage description)
Craig Karpinski
James Campbell
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Initial Surface Pressure (Breakdown):
Total Proppant Pumped* :
Produced Water Volume:
30# Linear Volume:
Displacement Volume:
Proppant Laden Fluid Volume:
Pad Volume:
Proppant in Formation:
Fluid Summary (by fluid description)
30# Hybor G Volume:
Spacer and Ball Drop Volume:
Interval Summary
Start Date/Time:
3S-610 - Torok - Interval 14
William Martin
Greg Clayton
Max Rate:
Max BH Pressure:
Wanli 16/20 Ceramic Pumped:
Pump Time:
Average pH:
End Date/Time:
Average Temp:
Dart/Ball Early :
Max Surface Pressure:
Average Missile HHP:
Open Well Pressure:
Pumps Starting Stage:
Average BH Pressure:
100M Pumped:
Max OA Pressure:
Max Proppant Concentration:
Step Rate Test Volume:
Initial Rate (Breakdown):
Average Visc:
Initial OA Pressure:
Proppant Summary
Pad Percentage Actual
Interval Status:
Initial BH Pressure (Breakdown):
Establish Stable Fluid Volume:
Average Surface Pressure:
Pad Percentage Design
Average Rate:
Average Missile Pressure:
Pumps Ending Stage:
Conoco Phillips - 3S-610 Interval Summary 25
5/25/24 12:37
5/25/24 13:21
44 min
10.0 bpm
7,085 psi
8,746 psi
4 bbl
37.5 bpm
6,138 psi
7,453 psi
31.2 bpm
3,363 psi
3,325 psi
4,800 psi
2,569 hhp
793 psi
853 psi
7.31 ppg
6
6
33 %
32 %
21 cP
108.5 F
8.8
139,780 lbs
3,780 lbs
143,560 lbs
143,361 lbs
49,258 gal 1,173 bbls
989 gal 24 bbls
16,269 gal 387 bbls
30,614 gal 729 bbls
1,386 gal 33 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
While seating the ball, pumps had to be dropped due to high pressure. The sleeve shifted but
interval 17 was treating at a high pressure, rate was stepped up as pressure allowed. Once
100 Mesh hit downhole pressure dropped and design rate of 37 bpm was achieved.
Dart/Ball Early :
3S-610 - Torok - Interval 15
Interval Summary
Average Missile Pressure:
Pad Percentage Actual
Pumps Ending Stage:
Pad Percentage Design
End Date/Time:
Max BH Pressure:
Max Rate:
Initial Surface Pressure (Breakdown):
Initial Rate (Breakdown):
Average Missile HHP:
Initial BH Pressure (Breakdown):
Average BH Pressure:
Pump Time:
Fluid Summary (by fluid description)
Interval Status:
Craig Karpinski
James Campbell
Pad Volume:
Conditioning Pad Volume:
Max Surface Pressure:
Fluid Summary (by stage description)
William Martin
Spacer and Ball Drop Volume:
Average Surface Pressure:
Average Visc:
Average pH:
Wanli 16/20 Ceramic Pumped:
Proppant Summary
Total Proppant Pumped* :
Proppant in Formation:
Average Temp:
Initial OA Pressure:
Max OA Pressure:
Max Proppant Concentration:
100M Pumped:
Proppant Laden Fluid Volume:
Pumps Starting Stage:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Greg Clayton
Start Date/Time:
30# Hybor G Volume:
Average Rate:
Conoco Phillips - 3S-610 Interval Summary 26
5/25/24 13:21
5/25/24 14:00
39 min
10.0 bpm
4,984 psi
6,072 psi
8 bbl
37.5 bpm
3,122 psi
4,484 psi
34.0 bpm
2,654 psi
2,613 psi
4,130 psi
2,214 hhp
828 psi
869 psi
7.13 ppg
6
6
33 %
32 %
20 cP
107.8 F
8.8
140,076 lbs
4,016 lbs
144,092 lbs
144,092 lbs
49,194 gal 1,171 bbls
1,249 gal 30 bbls
15,927 gal 379 bbls
30,581 gal 728 bbls
1,437 gal 34 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
William Martin
Craig Karpinski
James Campbell
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Greg Clayton
Max Proppant Concentration:
Pad Percentage Design
Average Visc:
Pump Time:
Average Surface Pressure:
Average Temp:
Proppant in Formation:
Average pH:
Pumps Starting Stage:
Start Date/Time:
Average BH Pressure:
Average Rate:
End Date/Time:
Max BH Pressure:
Fluid Summary (by fluid description)
Interval Summary
Pad Percentage Actual
Initial OA Pressure:
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Average Missile HHP:
Max OA Pressure:
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Pumps Ending Stage:
Max Surface Pressure:
Pad Volume:
Wanli 16/20 Ceramic Pumped:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
100M Pumped:
30# Hybor G Volume:
Average Missile Pressure:
Proppant Summary
Max Rate:
3S-610 - Torok - Interval 16
Interval Status:
Interval pumped as per design.
Spacer and Ball Drop Volume:
Fluid Summary (by stage description)
Total Proppant Pumped* :
Conoco Phillips - 3S-610 Interval Summary 27
5/25/24 14:00
5/25/24 14:38
38 min
10.1 bpm
4,056 psi
5,612 psi
7 bbl
37.3 bpm
4,310 psi
5,701 psi
34.9 bpm
2,687 psi
2,649 psi
4,168 psi
2,296 hhp
842 psi
873 psi
7.08 ppg
6
6
33 %
32 %
19 cP
111 F
8.7
2914 psi
0.552 psi/ft
2773 psi
2704 psi
2644 psi
141,003 lbs
3,971 lbs
144,974 lbs
144,974 lbs
47,964 gal 1,142 bbls
8,863 gal 211 bbls
1,067 gal 25 bbls
16,066 gal 383 bbls
30,831 gal 734 bbls
8,863 gal 211 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
3S-610 - Torok - Interval 17
Interval Summary
Average pH:
ISDP:
Final Fracture Gradient:
Proppant Summary
Average Rate:
Pad Volume:
Final 5 min:
Proppant in Formation:
Average Missile Pressure:
Initial Rate (Breakdown):
Dart/Ball Early :
Wanli 16/20 Ceramic Pumped:
Final 10 min:
30# Hybor G Volume:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
30# Linear Volume:
Greg Clayton
100M Pumped:
Flush Volume:
Total Proppant Pumped* :
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Stage pumped as per design. William Martin
Craig Karpinski
James Campbell
End Date/Time:
Max Proppant Concentration:
Average BH Pressure:
Start Date/Time:
Pumps Ending Stage:
Pad Percentage Design
Pad Percentage Actual
Final 15 min:
Max Surface Pressure:
Initial BH Pressure (Breakdown):
Interval Status:
Average Visc:
Average Temp:
Max OA Pressure:
Average Surface Pressure:
Max Rate:
Initial OA Pressure:
Max BH Pressure:
Initial Surface Pressure (Breakdown):
Pumps Starting Stage:
Average Missile HHP:
Pump Time:
Conoco Phillips - 3S-610 Interval Summary 28
5/26/24 9:42
5/26/24 11:08
86 min
10.1 bpm
1,813 psi
3,606 psi
13 bbl
37.8 bpm
2,645 psi
3,929 psi
31.0 bpm
2,186 psi
2,105 psi
3,567 psi
1,660 hhp
140 psi
98 psi
738 psi
7.14 ppg
5
5
33 %
31 %
23 cP
109.6 F
8.8
DFIT
9.917 bpm
1496 psi
3259 psi
9.956 bpm
1813 psi
3606 psi
2692 psi
0.511 psi/ft
2304 psi
2110 psi
139,939 lbs
3,967 lbs
143,906 lbs
143,873 lbs
54,433 gal 1,296 bbls
8,666 gal 206 bbls
1,067 gal 25 bbls
978 gal 23 bbls
16,071 gal 383 bbls
31,269 gal 745 bbls
6,669 gal 159 bbls
1,453 gal 35 bbls
4,717 gal 112 bbls
1,942 gal 46 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
William Martin
Proppant Summary
100M Pumped:
Craig Karpinski
A DFIT was pumped at the beginning of interval 18. Pressure was monitored for 15 minutes
before a closure was observed and the stage resumed. Shortly after coming up to 37 bpm, rate
fluctuated due to some debris. Stage pumped to completion. James Campbell
Greg Clayton
Interval Summary
Average Temp:
Average pH:
Minifrac Max DH Pressure:
Minifrac Max Surface Pressure:
Average BH Pressure:
Minifrac Average Pressure:
Minifrac Average DH Pressure:
Pumps Starting Stage:
Pumps Ending Stage:
Final Fracture Gradient:
Final 10 min:
Start Date/Time:
Average Surface Pressure:
Dart/Ball Early :
Initial BH Pressure (Breakdown):
Pad Percentage Design
Max Proppant Concentration:
Pad Percentage Actual
Average Missile Pressure:
ISDP:
Max Rate:
Average Missile HHP:
Open Well Pressure:
Max BH Pressure:
Initial Surface Pressure (Breakdown):
3S-610 - Torok - Interval 18
Pump Time:
Interval Status:
Initial Rate (Breakdown):
Average Rate:
Conditioning Pad Volume:
Spacer and Ball Drop Volume:
End Date/Time:
Displacement Volume:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Pad Volume:
Initial OA Pressure:
Max OA Pressure:
Max Surface Pressure:
Diagnostic method
Minifrac Average Rate:
Wanli 16/20 Ceramic Pumped:
Establish Stable Fluid Volume:
Proppant Laden Fluid Volume:
Total Proppant Pumped* :
Proppant in Formation:
Final 5 min:
30# Hybor G Volume:
Minifrac Max Rate:
DFIT Volume:
Average Visc:
Produced Water Volume:
Fluid Summary (by stage description)
30# Linear Volume:
Fluid Summary (by fluid description)
Conoco Phillips - 3S-610 Interval Summary 29
5/26/24 11:08
5/26/24 15:22
254 min
10.0 bpm
3,899 psi
4,893 psi
4 bbl
37.4 bpm
4,092 psi
5,423 psi
35.1 bpm
2,638 psi
2,576 psi
4,047 psi
2,268 hhp
740 psi
850 psi
7.51 ppg
5
5
61 %
53 %
20 cP
114.4 F
9.1
2521 psi
0.480 psi/ft
2246 psi
2123 psi
2054 psi
147,801 lbs
0 lbs
147,801 lbs
147,801 lbs
78,318 gal 1,865 bbls
16,286 gal 388 bbls
5,182 gal 123 bbls
36,049 gal 858 bbls
30,949 gal 737 bbls
1,095 gal 26 bbls
1,406 gal 33 bbls
16,286 gal 388 bbls
3,637 gal 87 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Status:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Final Fracture Gradient:
Final 5 min:
ISDP:
Establish Stable Fluid Volume:
Spacer and Ball Drop Volume:
Greg Clayton
Average Temp:
Final 10 min:
Final 15 min:
Average Missile Pressure:
Average pH:
Average BH Pressure:
Total Proppant Pumped* :
30# Linear Volume:
Proppant Laden Fluid Volume:
Fluid Summary (by stage description)
30# Hybor G Volume:
Displacement Volume:
James Campbell
Fluid Summary (by fluid description)
Pad Volume:
Wanli 16/20 Ceramic Pumped:
Interval Summary
Average Visc:
Start Date/Time:
End Date/Time:
Dart/Ball Early :
Pumps Starting Stage:
Max Rate:
Initial Rate (Breakdown):
Max BH Pressure:
Average Rate:
Pad Percentage Actual
Max Surface Pressure:
Pump Time:
Initial OA Pressure:
Initial BH Pressure (Breakdown):
Max OA Pressure:
Flush Volume:
Proppant in Formation:
100M Pumped:
Conditioning Pad Volume:
Average Missile HHP:
Max Proppant Concentration:
Pumps Ending Stage:
3S-610 - Torok - Interval 19
Initial Surface Pressure (Breakdown):
Average Surface Pressure:
Pad Percentage Design
Proppant Summary
The 100 Mesh bridged off in the castle presumably due to frozen sand blocking the chute. The
Conditioning Pad was pumped with 16/20. The interval was pumped to completion. While
dropping the ball for interval 20, no ball seat was observed, so it is assumed that the Pad and
Conditioning Pad volumes intended for interval 20 are the tail of interval 19. After the Second
ball for interval 20 failed to seat, decision was made to skip interval 20 and try to pump interval
21. The ball for interval 21 also did not seat and the decision was made to skip the remaining
intervals. Volumes pumped for seating balls for interval 20 and 21 were actually pumped into
interval 19 which is reflected in the summary volumes.
William Martin
Craig Karpinski
Conoco Phillips - 3S-610 Interval Summary 30
CustomerFormationLeaseAPIDateWell SummaryWanli 16/20 Ceramic 100M Total Proppantrface Press Rate Visc Temp pHrface Press Rate gal bbl gal bbl gal bbl gal bbl gal bbl lbs lbs lbs13718 29.9 22 98.2 8.8 4674 36.4 167,334 3,984 6,388 152 2,134 51 175,856 4,187 288,733 4,246 292,979 23733 24.5 23 92 8.7 5531 36.8 132,511 3,155 34,350 818 1,067 25 167,928 3,998 294,366 3,726 298,092 33989 27.8 25 83 9.3 6324 36.9 128,399 3,057 13,936 332 143,402 3,414 300,004 4,356 304,360 43968 33.2 26 92 8.7 6316 36.8 107,407 2,557 28,221 672 135,628 3,229 297,317 3,641 300,958 54550 34.2 24 110 8.6 6298 37.7 101,998 2,429 12,533 298 114,531 2,727 296,558 4,246 300,804 63733 33.6 23 96 8.9 4849 37.3 148,452 3,535 30,641 730 1,067 25 180,160 4,290 305,751 3,697 309,448 73600 34.7 21 93 8.8 4375 37.4 102,692 2,445 102,692 2,445 297,377 3,879 301,256 83616 35.6 23 92 8.9 4433 37.2 100,200 2,386 11,729 279 111,929 2,665 299,845 3,906 303,751 93272 34.9 28 97 8.7 3775 37.6 76,516 1,822 39 1 1,067 25 77,621 1,848 201,100 4,239 205,339 103102 35.0 24 97 8.9 3734 37.4 70,915 1,688 70,915 1,688 204,277 3,538 207,815 113528 35.0 26 96 8.7 5006 37.3 69,129 1,646 69,129 1,646 202,282 3,119 205,401 123243 35.5 23 103 8.8 3863 37.7 71,403 1,700 71,403 1,700 204,264 3,621 207,885 133176 36.7 23 102 9.0 3593 37.8 66,989 1,595 10,102 241 77,091 1,836 201,859 4,147 206,006 142672 34.7 22 108 8.8 3214 37.6 53,574 1,276 26,796 638 1,067 25 81,437 1,939 141,877 3,497 145,374 153325 31.2 21 109 8.8 6138 37.5 49,258 1,173 49,258 1,173 139,780 3,780 143,560 162613 34.0 20 108 8.8 3122 37.5 49,194 1,171 49,194 1,171 140,076 4,016 144,092 Minimum47964 1142 39 1 1067 25 49194 1171 139780 3119 143560 Average88247 2101 16042 382 1245 30 99672 2373 223379 3866 227042 Maximum167334 3984 34350 818 2134 51 180160 4290 305751 4356 309448 Wanli 16/20 Ceramic 100M Total ProppantPressure Rate Visc Temp pH Pressure Rate gal bbl gal bbl gal bbl gal bbl gal bbl lbs lbs TotalPlanned1,740,110 41,431 194,309 4,626 14,180 338 0 0 1,949,599 46,419 4,548,550 72,000 4,620,550Recorded3671 32.8 24 96 8.82 6324 37.8 1,676,686 39,921 208,550 4,965 7,468 178 0 0 1,893,770 45,090 4,244,209 69,592 4,313,801Weight Tickets4,279,428 69,000 4,348,428** Proppant is billed from Weight Ticket volumes** IFS numbers for proppant are taken from software calculations based on Total FluidFluids ProppantsFluids ProppantsTotal FluidFreeze ProtectFreeze ProtectAverage MaxProduced Water30# Hybor G 30# Linear30# Hybor G 30# LinearIntervalAverage MaxProduced WaterMay 18, 202450-103-208753S-610TorokConoco Phillips Conoco Phillips - 3S-610 Fluid System-Proppant Summary 31
<-Paste Interval 1 Plots HereConoco Phillips - 3S-610 Interval 1 Plots 32
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Event Log
Sand Sieve
Fann 15 Minute
Field Break Test
Real-Time QC
Well Summary
Stimulation Treatment
Appendix
Chemical Summary
Planned Design
Water Straps
Water Analysis
Prepared for: Manabu Nozaki
May 26, 2024
Harrison Bay County, AK
Conoco Phillips
3S-610
Intervals 1-21
Torok Formation
API: 50-103-20875
Conoco Phillips - 3S-610 Appendix 159
Interval Date
Designed
Proppant
(lbs)
Proppant in
Formation
(lbs)
Designed Fluid
(bbl)
Vol Clean
(bbl)
Vol Slurry
(bbl)
Pad Percentage
Design
Pad Percentage
Actual
Proppant
Aggressivness (lb/bbl
Clean)
Fluid
System
1 5/19/2024 311,550 292,979 4,179 4187 4,498 39.2 39.6 159 Hybor
2 5/20/2024 304,000 298,092 3,829 3998 4,315 32.0 31.3 186 Hybor
3 5/21/2024 304,000 304,360 3,404 3414 3,738 42.2 37.3 182 Hybor
4 5/21/2024 304,000 300,958 2,731 3229 3,549 32.0 31.3 189 Hybor
5 5/21/2024 304,000 300,804 2,692 2727 3,046 32.0 31.1 188 Hybor
6 5/23/2024 304,000 309,448 3,965 4290 4,618 42.2 36.1 189 Hybor
7 5/23/2024 304,000 301,256 2,385 2445 2,765 32.0 32.3 194 Hybor
8 5/23/2024 304,000 303,751 2,667 2665 2,988 32.0 31.6 196 Hybor
9 5/24/2024 204,000 205,339 1,852 1848 2,066 32.0 32.4 196 Hybor
10 5/24/2024 204,000 207,815 1,598 1688 1,909 32.0 32.2 194 Hybor
11 5/24/2024 204,000 205,401 1,598 1646 1,864 32.0 31.6 196 Hybor
12 5/24/2024 204,000 207,885 1,598 1700 1,921 32.0 30.7 189 Hybor
13 5/24/2024 204,000 206,006 1,841 1836 2,054 32.0 31.7 197 Hybor
14 5/25/2024 144,000 145,374 1,729 1939 2,093 32.5 31.3 190 Hybor
15 5/25/2024 144,000 143,361 1,136 1173 1,325 32.5 32.1 192 Hybor
16 5/25/2024 144,000 144,092 1,136 1171 1,324 32.5 32.0 192 Hybor
17 5/25/2024 144,000 144,974 1,333 1353 1,507 32.5 31.8 192 Hybor
18 5/26/2024 144,000 143,873 1,729 1528 1681 32.5 31.5 188 Hybor
19 5/26/2024 153,000 147,801 2,570 2252 2409 60.9 52.8 190 Hybor
20 144,000 0 1,136 0 0 32.5 NA NA Hybor
21 144,000 0 1,312 0 0 32.5 NA NA Hybor
3S-610 Interval Highlights
Conoco Phillips - 3S-610 Well Summary 160
CustomerConoco Phillips FormationTorokLease3S-610API50-103-20875DateInterval Summary - Chemicals CL-28M Losurf-300D MO-67 Cat-3 BA-20 WG-36 OPTIFLO-III OPTIFLO-II BE-6(gal) (gal) (gal) (gal) (gal) (lbs) (lbs) (lbs) (lbs)Prime Up0 0 0 10 0 0 0 0 01325 130 75 20 40 5855 250 350 262225 150 105 15 40 4112 300 350 243256 149 109 13 35 3701 236 318 224234 140 91 10 34 4016 267 348 -5186 97 130 7 19 3419 147 234 -6207 179 156 4 41 4926 120 200 757205 103 108 3 24 3026 180 270 -8188 78 176 5 27 3129 400 260 -9170 90 88 3 20 2661 150 250 6010142 71 74 2 16 2129 140 220 -11138 69 73 1 16 2110 100 210 012143 71 75 2 16 2309 150 220 -1397 63 16 2 18 2377 150 210 -14105 93 92 0 18 2320 170 270 3615115 50 46 1 22 1336 110 150 -1685 42 62 1 18 1311 130 170 -1765 50 32 1 17 1368 110 180 -18155 87 107 2 23 1903 120 160 5119130 76 58 1 19 2673 100 140 -Total 3170 1787 1673 103 463.652278 54681 3330 4510 294w/o Prime Up3170 1787 1673 93 464 54681 3330 4510 294Interval5/18/2024Dry AdditivesLiquid AdditivesConoco Phillips - 3S-610 Chemical Summary 161
CUSTOMERConoco Phillips FALSEAPI BFD (lb/ga8.54LAT 70.39420002LEASE3S-610SALES OBHST (°F)144LONG-150.1961825FORMATIONTorokDATE Max Press8500*Exceeds 80% of burst pressure*Prop Slurry Design CleanDesign Cleaesign Slur Design Prop Stage Interval CL-28M Losurf-300D MO-67 Cat-3 BA-20 WG-36OPTIFLO-III OPTIFLO-IIBE-6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer Catalyst BufferInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)1-1 Shut-In Shut-In 2:22:37 1-2 Produced Water Prime Up Pressure Test 5 1,000 24 24 0:04:46 2:22:37 1-3 Shut-In Shut-In 2:17:52 1-4 30# Linear Arsenal Sleeve Shift 5 1,260 30 30 0:06:00 2:17:52 1.00 0.33 30.00 2.00 2.00 0.151-5 30# Linear Step Rate Test 37 8,400 200 200 0:05:24 2:11:52 1.00 0.33 30.00 2.00 2.00 0.151-6 30# Linear DFIT 37 1,680 40 40 0:01:05 2:06:27 1.00 0.33 30.00 2.00 2.00 0.151-7 Shut-In Shut-In 2:05:22 1-8 Shut-In Shut-In 2:05:22 1-9 30# Hybor G Establish Stable Fluid 15 8,400 200 200 0:13:20 2:05:22 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.151-10 30# Hybor G Pad 37 19,800 471 471 0:12:44 1:52:02 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.151-11 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 1:39:18 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.151-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 3,000 71 75 3,000 0:02:01 1:28:53 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.151-13 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 3,750 89 97 7,500 0:02:38 1:26:52 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.151-14 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 6,000 143 162 18,000 0:04:23 1:24:14 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.151-15 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 7,275 173 204 29,100 0:05:32 1:19:51 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.151-16 30# Hybor G Flush Wanli 16/20 Ceramic 37 13,956 332 332 0:08:59 1:14:18 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.151-17 Produced Water Freeze Protect 1:05:20 1-18 Shut-In Shut-In 1:05:20 1-19 Shut-In Shut-In 1:05:20 1-20 Produced Water Prime Up Pressure Test 5 1,000 24 24 0:04:46 1:05:20 1-21 Shut-In Shut-In 1:00:34 1-22 30# Linear Spacer and Ball Drop 1,260 30 30 1:00:34 1-23 30# Hybor G Establish Stable Fluid 37 8,400 200 200 0:05:24 1:00:34 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.151-24 30# Hybor G Pad 37 19,800 471 471 0:12:44 0:55:10 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.151-25 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 3,000 71 75 3,000 0:02:01 0:42:25 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.151-26 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 3,750 89 97 7,500 0:02:38 0:40:24 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.151-27 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 4,400 105 119 13,200 0:03:13 0:37:46 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.151-28 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 5,700 136 160 22,800 0:04:20 0:34:33 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.151-29 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 6,200 148 177 27,900 0:04:49 0:30:13 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.151-30 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 7,000 167 204 35,000 0:05:32 0:25:24 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.151-31 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 7,300 174 216 40,150 0:05:53 0:19:52 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.151-32 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:14:00 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.151-33 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 6,000 143 184 39,000 0:05:00 0:09:15 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.151-34 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 3,800 90 119 26,600 0:03:14 0:04:14 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.151-35 30# Hybor G Spacer and Dart Drop 37 1,571 37 37 0:01:01 0:01:01 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.152-1 30# Hybor G Minifrac - Treatment 37 18,900 450 450 0:12:10 3:00:02 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.152-2 30# Linear Minifrac - Flush 37 13,393 319 319 0:08:37 2:47:52 1.00 0.33 30.00 2.00 2.00 0.152-3 Produced Water Freeze Protect 2:39:15 2-4 Shut-In Shut-In 2:39:15 #####Liquid Additives Dry Additives50-103-208750909331970Interval 1Kuparuk A Sand@ 20165.3 - 20167.95 ft 142.8 °FConoco Phillips - 3S-610 Planned Design 162
CUSTOMERConoco Phillips FALSEAPI BFD (lb/ga8.54LAT 70.39420002LEASE3S-610SALES OBHST (°F)144LONG-150.1961825FORMATIONTorokDATE Max Press8500*Exceeds 80% of burst pressure*Prop Slurry Design CleanDesign Cleaesign Slur Design Prop Stage Interval CL-28M Losurf-300D MO-67 Cat-3 BA-20 WG-36OPTIFLO-III OPTIFLO-IIBE-6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer Catalyst BufferInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)#####Liquid Additives Dry Additives50-103-2087509093319702-5 Shut-In Shut-In 2:39:15 2-6 Produced Water Prime Up Pressure Test 5 1,000 24 24 0:04:46 2:39:15 2-7 Shut-In Shut-In 2:34:29 2-8 30# Linear Spacer and Dart Drop 5 250 6 6 0:01:11 2:34:29 1.00 0.33 30.00 2.00 2.00 0.152-9 30# Linear Displacement 5 13,393 319 319 1:03:47 2:33:18 1.00 0.33 30.00 2.00 2.00 0.152-10 30# Linear Step Rate Test 20 5,000 119 119 0:05:57 1:29:31 1.00 0.33 30.00 2.00 2.00 0.152-11 30# Hybor G Establish Stable Fluid 20 8,400 200 200 0:10:00 1:23:34 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.152-12 30# Hybor G Pad 37 19,800 471 471 0:12:44 1:13:34 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.152-13 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 1:00:50 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.152-14 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 3,000 71 75 3,000 0:02:01 0:50:25 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.152-15 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 3,750 89 97 7,500 0:02:38 0:48:24 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.152-16 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 6,000 143 162 18,000 0:04:23 0:45:46 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.152-17 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 7,275 173 204 29,100 0:05:32 0:41:22 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.152-18 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 7,500 179 214 33,750 0:05:49 0:35:50 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.152-19 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 8,115 193 236 40,575 0:06:25 0:30:01 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.152-20 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 8,250 196 245 45,375 0:06:38 0:23:36 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.152-21 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 8,700 207 263 52,200 0:07:08 0:16:58 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.152-22 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 6,000 143 184 39,000 0:05:00 0:09:50 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.152-23 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 4,500 107 141 31,500 0:03:49 0:04:50 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.152-24 30# Hybor G Spacer and Dart Drop 37 1,571 37 37 0:01:01 0:01:01 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.153-1 30# Hybor G Pad 37 19,800 471 471 0:12:44 1:55:56 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.153-2 30# Linear Flush 37 13,059 311 311 0:08:24 1:43:11 1.00 0.33 30.00 2.00 2.00 0.153-3 Shut-In Shut-In 1:34:47 3-4 Shut-In Shut-In 1:34:47 3-5 Sea Water Prime Up Pressure Test 5 1,000 24 24 0:04:46 1:34:47 3-6 Shut-In Shut-In 1:30:01 3-7 30# Linear Spacer and Ball Drop 15 250 6 6 0:00:24 1:30:01 1.00 0.33 30.00 2.00 2.00 0.153-8 30# Hybor G Establish Stable Fluid 15 8,400 200 200 0:13:20 1:29:38 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.153-9 30# Hybor G Pad 37 19,800 471 471 0:12:44 1:16:18 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.153-10 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 1:03:33 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.153-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 3,000 71 75 3,000 0:02:01 0:53:08 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.153-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 3,750 89 97 7,500 0:02:38 0:51:07 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.153-13 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 6,000 143 162 18,000 0:04:23 0:48:29 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.153-14 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 7,275 173 204 29,100 0:05:32 0:44:06 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.153-15 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 7,500 179 214 33,750 0:05:49 0:38:34 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.153-16 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 8,115 193 236 40,575 0:06:25 0:32:45 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.153-17 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 8,250 196 245 45,375 0:06:38 0:26:20 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.153-18 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 8,700 207 263 52,200 0:07:08 0:19:42 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.153-19 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 6,000 143 184 39,000 0:05:00 0:12:34 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.153-20 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 4,500 107 141 31,500 0:03:49 0:07:33 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.153-21 30# Hybor G Spacer and Ball Drop 10 1,570 37 37 0:03:44 0:03:44 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.154-1 30# Linear Spacer and Dart Drop 37 12,723 303 303 0:08:11 1:22:43 1.00 0.33 30.00 2.00 2.00 0.154-2 30# Hybor G Establish Stable Fluid 37 1,500 36 36 0:00:58 1:14:32 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.154-3 30# Hybor G Pad 37 19,800 471 471 0:12:44 1:13:34 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.154-4 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 1:00:50 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.154-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 3,000 71 75 3,000 0:02:01 0:50:25 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.154-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 3,750 89 97 7,500 0:02:38 0:48:24 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.154-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 6,000 143 162 18,000 0:04:23 0:45:46 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.154-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 7,275 173 204 29,100 0:05:32 0:41:22 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.154-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 7,500 179 214 33,750 0:05:49 0:35:50 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.154-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 8,115 193 236 40,575 0:06:25 0:30:01 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.154-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 8,250 196 245 45,375 0:06:38 0:23:36 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.154-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 8,700 207 263 52,200 0:07:08 0:16:58 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.154-13 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 6,000 143 184 39,000 0:05:00 0:09:50 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.154-14 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 4,500 107 141 31,500 0:03:49 0:04:50 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.154-15 30# Hybor G Spacer and Dart Drop 37 1,571 37 37 0:01:01 0:01:01 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.155-1 30# Hybor G Pad 37 19,800 471 471 0:12:44 1:24:25 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.155-2 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 1:11:40 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.155-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 3,000 71 75 3,000 0:02:01 1:01:16 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.155-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 3,750 89 97 7,500 0:02:38 0:59:14 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.155-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 6,000 143 162 18,000 0:04:23 0:56:36 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.155-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 7,275 173 204 29,100 0:05:32 0:52:13 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.155-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 7,500 179 214 33,750 0:05:49 0:46:41 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.155-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 8,115 193 236 40,575 0:06:25 0:40:52 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.155-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 8,250 196 245 45,375 0:06:38 0:34:27 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.155-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 8,700 207 263 52,200 0:07:08 0:27:49 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.155-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 6,000 143 184 39,000 0:05:00 0:20:41 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.155-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 4,500 107 141 31,500 0:03:49 0:15:41 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.155-13 30# Linear Flush 37 12,619 300 300 0:08:07 0:11:52 1.00 0.25 0.33 30.00 2.00 4.00 0.155-14 Produced Water Freeze Protect 10 1,570 37 37 0:03:44 0:03:44 5-15 Shut-In Shut-InInterval 2Kuparuk A Sand@ 19638.9 - 19641.55 ft 142.8 °FInterval 3Kuparuk A Sand@ 19116.5 - 19119.15 ft 142.8 °FInterval 4Kuparuk A Sand@ 18594.6 - 18597.25 ft 142.8 °FInterval 5Kuparuk A Sand@ 18074.4 - 18077.05 ft 142.8 °FConoco Phillips - 3S-610 Planned Design 163
CUSTOMERConoco Phillips FALSEAPI BFD (lb/ga8.54LAT 70.39420002LEASE3S-610SALES OBHST (°F)144LONG-150.1961825FORMATIONTorokDATE Max Press8500*Exceeds 80% of burst pressure*Prop Slurry Design CleanDesign Cleaesign Slur Design Prop Stage Interval CL-28M Losurf-300D MO-67 Cat-3 BA-20 WG-36OPTIFLO-III OPTIFLO-IIBE-6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer Catalyst BufferInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)#####Liquid Additives Dry Additives50-103-2087509093319706-1 Shut-In Shut-In 2:31:28 6-2 Produced Water Prime Up Pressure Test 5 1,000 24 24 0:04:46 2:31:28 6-3 Shut-In Shut-In 2:26:42 2.006-4 30# Linear Spacer and Ball Drop 15 1,260 30 30 0:02:00 2:26:42 1.00 0.33 30.00 2.00 2.00 0.156-5 30# Linear Displacement 15 12,059 287 287 0:19:08 2:24:42 1.00 0.33 30.00 2.00 2.00 0.156-6 30# Linear Step Rate Test 15 3,000 71 71 0:04:46 2:05:34 1.00 0.33 30.00 2.00 2.00 0.156-7 30# Hybor G Establish Stable Fluid 15 8,400 200 200 0:13:20 2:00:48 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.156-8 30# Hybor G Pad 37 19,800 471 471 0:12:44 1:47:28 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.156-9 30# Linear Flush 37 12,474 297 297 0:08:02 1:34:44 1.00 0.33 30.00 2.00 2.00 0.156-10 30# Hybor G Establish Stable Fluid 15 8,400 200 200 0:13:20 1:26:42 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.156-11 30# Hybor G Pad 37 19,800 471 471 0:12:44 1:13:22 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.156-12 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 1:00:38 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.156-13 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 3,000 71 75 3,000 0:02:01 0:50:13 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.156-14 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 3,750 89 97 7,500 0:02:38 0:48:12 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.156-15 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 6,000 143 162 18,000 0:04:23 0:45:34 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.156-16 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 7,275 173 204 29,100 0:05:32 0:41:10 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.156-17 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 7,500 179 214 33,750 0:05:49 0:35:38 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.156-18 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 8,115 193 236 40,575 0:06:25 0:29:49 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.156-19 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 8,250 196 245 45,375 0:06:38 0:23:24 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.156-20 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 8,700 207 263 52,200 0:07:08 0:16:46 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.156-21 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 6,000 143 184 39,000 0:05:00 0:09:38 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.156-22 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 4,500 107 141 31,500 0:03:49 0:04:38 2.00 1.00 1.05 0.25 0.33 30.00 2.00 4.00 0.156-23 30# Hybor G Spacer and Ball Drop 37 1,260 30 30 0:00:49 0:00:49 2.00 1.00 1.05 0.25 0.33 30.00 2.00 4.00 0.157-1 30# Hybor G Pad 37 19,800 471 471 0:12:44 1:13:22 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.157-2 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 1:00:38 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.157-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 3,000 71 75 3,000 0:02:01 0:50:13 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.157-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 3,750 89 97 7,500 0:02:38 0:48:12 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.157-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 6,000 143 162 18,000 0:04:23 0:45:34 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.157-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 7,275 173 204 29,100 0:05:32 0:41:10 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.157-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 7,500 179 214 33,750 0:05:49 0:35:38 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.157-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 8,115 193 236 40,575 0:06:25 0:29:49 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.157-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 8,250 196 245 45,375 0:06:38 0:23:24 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.157-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 8,700 207 263 52,200 0:07:08 0:16:46 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.157-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 6,000 143 184 39,000 0:05:00 0:09:38 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.157-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 4,500 107 141 31,500 0:03:49 0:04:38 2.00 1.00 1.05 0.25 0.33 30.00 2.00 4.00 0.157-13 30# Hybor G Spacer and Ball Drop 37 1,260 30 30 0:00:49 0:00:49 2.00 1.00 1.05 0.25 0.33 30.00 2.00 4.00 0.158-1 30# Hybor G Pad 37 19,800 471 471 0:12:44 1:27:27 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.158-2 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 1:14:43 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.158-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 3,000 71 75 3,000 0:02:01 1:04:18 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.158-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 3,750 89 97 7,500 0:02:38 1:02:17 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.158-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 6,000 143 162 18,000 0:04:23 0:59:39 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.158-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 7,275 173 204 29,100 0:05:32 0:55:16 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.158-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 7,500 179 214 33,750 0:05:49 0:49:44 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.158-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 8,115 193 236 40,575 0:06:25 0:43:55 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.158-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 8,250 196 245 45,375 0:06:38 0:37:30 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.158-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 8,700 207 263 52,200 0:07:08 0:30:51 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.158-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 6,000 143 184 39,000 0:05:00 0:23:44 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.158-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 4,500 107 141 31,500 0:03:49 0:18:43 2.00 1.00 1.05 0.25 0.33 30.00 2.00 4.00 0.158-13 30# Linear Flush 37 11,537 275 275 0:07:25 0:14:54 1.00 0.25 0.33 30.00 2.00 4.00 0.158-14 Produced Water Freeze Protect 5 1,570 37 37 0:07:29 0:07:29 8-15 Shut-In Shut-InInterval 6Kuparuk A Sand@ 17551.8 - 17554.45 ft 142.7 °FInterval 7Kuparuk A Sand@ 17033.6 - 17036.25 ft 142.7 °FInterval 8Kuparuk A Sand@ 16512.4 - 16515.05 ft 142.6 °FConoco Phillips - 3S-610 Planned Design 164
CUSTOMERConoco Phillips FALSEAPI BFD (lb/ga8.54LAT 70.39420002LEASE3S-610SALES OBHST (°F)144LONG-150.1961825FORMATIONTorokDATE Max Press8500*Exceeds 80% of burst pressure*Prop Slurry Design CleanDesign Cleaesign Slur Design Prop Stage Interval CL-28M Losurf-300D MO-67 Cat-3 BA-20 WG-36OPTIFLO-III OPTIFLO-IIBE-6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer Catalyst BufferInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)#####Liquid Additives Dry Additives50-103-2087509093319709-1 Shut-In Shut-In 1:09:17 9-2 Produced Water Prime Up Pressure Test 5 1,000 24 24 0:04:46 1:09:17 9-3 Shut-In Shut-In 1:04:31 9-4 30# Linear Spacer and Ball Drop 15 1,260 30 30 0:02:00 1:04:31 1.00 0.33 30.00 2.00 2.00 0.159-5 30# Hybor G Establish Stable Fluid 15 8,400 200 200 0:13:20 1:02:31 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.159-6 30# Hybor G Pad 37 7,810 186 186 0:05:02 0:49:11 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.159-7 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 0:44:10 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.159-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:33:45 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.159-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:32:24 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.159-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:30:39 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.159-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:27:43 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.159-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:24:02 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.159-13 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:20:09 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.159-14 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:15:52 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.159-15 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:11:27 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.159-16 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:06:42 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.159-17 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:03:21 2.00 1.00 1.05 0.25 0.33 30.00 2.00 4.00 0.159-18 30# Hybor G Spacer and Ball Drop 37 1,260 30 30 0:00:49 0:00:49 2.00 1.00 1.05 0.25 0.33 30.00 2.00 4.00 0.1510-1 30# Hybor G Pad 37 7,810 186 186 0:05:02 0:49:11 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1510-2 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 0:44:10 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1510-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:33:45 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1510-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:32:24 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1510-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:30:39 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1510-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:27:43 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1510-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:24:02 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1510-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:20:09 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.1510-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:15:52 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.1510-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:11:27 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.1510-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:06:42 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.1510-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:03:21 2.00 1.00 1.05 0.25 0.33 30.00 2.00 4.00 0.1510-13 30# Hybor G Spacer and Ball Drop 37 1,260 30 30 0:00:49 0:00:49 2.00 1.00 1.05 0.25 0.33 30.00 2.00 4.00 0.1511-1 30# Hybor G Pad 37 7,810 186 186 0:05:02 0:49:11 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1511-2 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 0:44:10 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1511-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:33:45 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1511-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:32:24 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1511-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:30:39 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1511-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:27:43 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1511-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:24:02 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1511-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:20:09 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.1511-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:15:52 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.1511-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:11:27 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.1511-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:06:42 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.1511-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:03:21 2.00 1.00 1.05 0.25 0.33 30.00 2.00 4.00 0.1511-13 30# Hybor G Spacer and Ball Drop 37 1,260 30 30 0:00:49 0:00:49 2.00 1.00 1.05 0.25 0.33 30.00 2.00 4.00 0.1512-1 30# Hybor G Pad 37 7,810 186 186 0:05:02 0:49:11 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1512-2 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 0:44:10 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1512-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:33:45 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1512-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:32:24 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1512-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:30:39 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1512-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:27:43 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1512-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:24:02 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1512-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:20:09 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.1512-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:15:52 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.1512-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:11:27 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.1512-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:06:42 2.00 1.00 1.05 0.33 30.00 2.00 4.00 0.1512-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:03:21 2.00 1.00 1.05 0.25 0.33 30.00 2.00 4.00 0.1512-13 30# Hybor G Spacer and Ball Drop 37 1,260 30 30 0:00:49 0:00:49 2.00 1.00 0.85 0.25 0.33 30.00 2.00 4.00 0.1513-1 30# Hybor G Pad 37 7,810 186 186 0:05:02 1:02:12 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1513-2 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 0:57:11 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1513-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 2,000 48 50 2,000 0:01:21 0:46:46 2.00 1.00 1.05 0.33 30.00 2.00 2.00 0.1513-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 2,500 60 65 5,000 0:01:45 0:45:25 2.00 1.00 1.50 0.33 30.00 2.00 2.00 0.1513-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 4,000 95 108 12,000 0:02:56 0:43:40 2.00 1.00 1.50 0.33 30.00 2.00 2.00 0.1513-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 4,850 115 136 19,400 0:03:41 0:40:44 2.00 1.00 1.50 0.33 30.00 2.00 2.00 0.1513-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 5,000 119 143 22,500 0:03:53 0:37:03 2.00 1.00 1.50 0.33 30.00 2.00 2.00 0.1513-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 5,410 129 158 27,050 0:04:17 0:33:10 2.00 1.00 1.50 0.33 30.00 2.00 4.00 0.1513-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 5,500 131 163 30,250 0:04:26 0:28:54 2.00 1.00 1.50 0.33 30.00 2.00 4.00 0.1513-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 5,800 138 175 34,800 0:04:45 0:24:28 2.00 1.00 1.50 0.33 30.00 2.00 4.00 0.1513-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 4,000 95 123 26,000 0:03:20 0:19:43 2.00 1.00 1.50 0.33 30.00 2.00 4.00 0.1513-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 3,000 71 94 21,000 0:02:33 0:16:23 2.00 1.00 1.50 0.25 0.33 30.00 2.00 4.00 0.1513-13 30# Linear Flush 37 9,878 235 235 0:06:21 0:13:50 1.00 1.50 0.33 30.00 2.00 4.00 0.1513-14 Produced Water Freeze Protect 5 1,570 37 37 0:07:29 0:07:29 13-15 Shut-In Shut-InInterval 12Kuparuk A Sand@ 14436.6 - 14439.25 ft 143.1 °FInterval 13Kuparuk A Sand@ 13915.1 - 13917.75 ft 143.5 °FInterval 9Kuparuk A Sand@ 15994.9 - 15997.55 ft 142.7 °FInterval 10Kuparuk A Sand@ 15479.4 - 15482.05 ft 142.7 °FInterval 11Kuparuk A Sand@ 14957.6 - 14960.25 ft 142.8 °FConoco Phillips - 3S-610 Planned Design 165
CUSTOMERConoco Phillips FALSEAPI BFD (lb/ga8.54LAT 70.39420002LEASE3S-610SALES OBHST (°F)144LONG-150.1961825FORMATIONTorokDATE Max Press8500*Exceeds 80% of burst pressure*Prop Slurry Design CleanDesign Cleaesign Slur Design Prop Stage Interval CL-28M Losurf-300D MO-67 Cat-3 BA-20 WG-36OPTIFLO-III OPTIFLO-IIBE-6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer Catalyst BufferInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)#####Liquid Additives Dry Additives50-103-20875090933197014-1 Shut-In Shut-In 1:17:39 14-2 Produced Water Prime Up Pressure Test 5 1,000 24 24 0:04:46 1:17:39 14-3 Shut-In Shut-In 1:12:54 14-4 30# Linear Spacer and Ball Drop 15 1,260 30 30 0:02:00 1:12:54 1.00 0.33 30.00 2.00 2.00 0.1514-5 30# Linear Displacement 15 8,564 204 204 0:13:36 1:10:54 1.00 0.33 30.00 2.00 2.00 0.1514-6 30# Linear Step Rate Test 15 5,700 136 136 0:09:03 0:57:18 1.00 0.33 30.00 2.00 2.00 0.1514-7 30# Hybor G Establish Stable Fluid 15 8,400 200 200 0:13:20 0:48:15 2.00 1.00 1.10 0.33 30.00 2.00 2.00 0.1514-8 30# Hybor G Pad 37 1,000 24 24 0:00:39 0:34:55 2.00 1.00 1.10 0.33 30.00 2.00 2.00 0.1514-9 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 0:34:17 2.00 1.00 1.10 0.33 30.00 2.00 2.00 0.1514-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 1,400 33 35 1,400 0:00:57 0:23:52 2.00 1.00 1.10 0.33 30.00 2.00 2.00 0.1514-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 1,750 42 45 3,500 0:01:14 0:22:55 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1514-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 2,800 67 76 8,400 0:02:03 0:21:42 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1514-13 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 3,395 81 95 13,580 0:02:35 0:19:39 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1514-14 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 3,500 83 100 15,750 0:02:43 0:17:04 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1514-15 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 3,787 90 110 18,935 0:03:00 0:14:21 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1514-16 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 3,850 92 114 21,175 0:03:06 0:11:21 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1514-17 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 4,060 97 123 24,360 0:03:20 0:08:15 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1514-18 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 2,800 67 86 18,200 0:02:20 0:04:56 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1514-19 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 2,100 50 66 14,700 0:01:47 0:02:36 2.00 1.00 1.25 0.25 0.33 30.00 2.00 4.00 0.1514-20 30# Hybor G Spacer and Ball Drop 37 1,260 30 30 0:00:49 0:00:49 2.00 1.00 1.25 0.25 0.33 30.00 2.00 4.00 0.1515-1 30# Hybor G Pad 37 1,000 24 24 0:00:39 0:34:55 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1515-2 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 0:34:17 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1515-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 1,400 33 35 1,400 0:00:57 0:23:52 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1515-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 1,750 42 45 3,500 0:01:14 0:22:55 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1515-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 2,800 67 76 8,400 0:02:03 0:21:42 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1515-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 3,395 81 95 13,580 0:02:35 0:19:39 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1515-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 3,500 83 100 15,750 0:02:43 0:17:04 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1515-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 3,787 90 110 18,935 0:03:00 0:14:21 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1515-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 3,850 92 114 21,175 0:03:06 0:11:21 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1515-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 4,060 97 123 24,360 0:03:20 0:08:15 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1515-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 2,800 67 86 18,200 0:02:20 0:04:56 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1515-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 2,100 50 66 14,700 0:01:47 0:02:36 2.00 1.00 1.25 0.25 0.33 30.00 2.00 4.00 0.1515-13 30# Hybor G Spacer and Ball Drop 37 1,260 30 30 0:00:49 0:00:49 2.00 1.00 1.25 0.25 0.33 30.00 2.00 4.00 0.1516-1 30# Hybor G Pad 37 1,000 24 24 0:00:39 0:34:55 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1516-2 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 0:34:17 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1516-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 1,400 33 35 1,400 0:00:57 0:23:52 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1516-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 1,750 42 45 3,500 0:01:14 0:22:55 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1516-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 2,800 67 76 8,400 0:02:03 0:21:42 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1516-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 3,395 81 95 13,580 0:02:35 0:19:39 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1516-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 3,500 83 100 15,750 0:02:43 0:17:04 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1516-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 3,787 90 110 18,935 0:03:00 0:14:21 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1516-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 3,850 92 114 21,175 0:03:06 0:11:21 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1516-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 4,060 97 123 24,360 0:03:20 0:08:15 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1516-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 2,800 67 86 18,200 0:02:20 0:04:56 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1516-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 2,100 50 66 14,700 0:01:47 0:02:36 2.00 1.00 1.25 0.25 0.33 30.00 2.00 4.00 0.1516-13 30# Hybor G Spacer and Ball Drop 37 1,260 30 30 0:00:49 0:00:49 2.00 1.00 1.25 0.25 0.33 30.00 2.00 4.00 0.1517-1 30# Hybor G Pad 37 1,000 24 24 0:00:39 0:44:22 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1517-2 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 0:43:44 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1517-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 1,400 33 35 1,400 0:00:57 0:33:19 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1517-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 1,750 42 45 3,500 0:01:14 0:32:22 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1517-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 2,800 67 76 8,400 0:02:03 0:31:09 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1517-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 3,395 81 95 13,580 0:02:35 0:29:06 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1517-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 3,500 83 100 15,750 0:02:43 0:26:31 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1517-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 3,787 90 110 18,935 0:03:00 0:23:48 2.00 1.00 1.35 0.33 30.00 2.00 4.00 0.1517-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 3,850 92 114 21,175 0:03:06 0:20:48 2.00 1.00 1.35 0.33 30.00 2.00 4.00 0.1517-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 4,060 97 123 24,360 0:03:20 0:17:43 2.00 1.00 1.35 0.33 30.00 2.00 4.00 0.1517-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 2,800 67 86 18,200 0:02:20 0:14:23 2.00 1.00 1.35 0.33 30.00 2.00 4.00 0.1517-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 2,100 50 66 14,700 0:01:47 0:12:03 2.00 1.00 1.35 0.25 0.33 30.00 2.00 4.00 0.1517-13 30# Linear Flush 37 8,548 204 204 0:05:30 0:10:16 1.00 0.33 30.00 2.00 4.00 0.1517-14 Produced Water Freeze Protect 5 1,000 24 24 0:04:46 0:04:46 17-15 Shut-In Shut-InInterval 14Kuparuk A Sand@ 13398.1 - 13400.75 ft 143.9 °FInterval 15Kuparuk A Sand@ 12875.8 - 12878.45 ft 144.3 °FInterval 16Kuparuk A Sand@ 12354.1 - 12356.75 ft 144.4 °FInterval 17Kuparuk A Sand@ 11835.2 - 11837.85 ft 144.4 °FConoco Phillips - 3S-610 Planned Design 166
CUSTOMERConoco Phillips FALSEAPI BFD (lb/ga8.54LAT 70.39420002LEASE3S-610SALES OBHST (°F)144LONG-150.1961825FORMATIONTorokDATE Max Press8500*Exceeds 80% of burst pressure*Prop Slurry Design CleanDesign Cleaesign Slur Design Prop Stage Interval CL-28M Losurf-300D MO-67 Cat-3 BA-20 WG-36OPTIFLO-III OPTIFLO-IIBE-6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer Catalyst BufferInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)#####Liquid Additives Dry Additives50-103-20875090933197018-1 Shut-In Shut-In 1:17:39 18-2 Produced Water Prime Up Pressure Test 5 1,000 24 24 0:04:46 1:17:39 18-3 Shut-In Shut-In 1:12:54 18-4 30# Linear Spacer and Ball Drop 15 1,260 30 30 0:02:00 1:12:54 1.00 0.33 30.00 2.00 2.00 0.1518-5 30# Linear Displacement 15 8,564 204 204 0:13:36 1:10:54 1.00 0.33 30.00 2.00 2.00 0.1518-6 30# Linear DFIT 15 5,700 136 136 0:09:03 0:57:18 1.00 0.33 30.00 2.00 2.00 0.1518-7 Shut-In Shut-In 0:48:15 18-8 30# Hybor G Establish Stable Fluid 15 8,400 200 200 0:13:20 0:48:15 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1518-9 30# Hybor G Pad 37 1,000 24 24 0:00:39 0:34:55 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1518-10 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 0:34:17 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1518-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 1,400 33 35 1,400 0:00:57 0:23:52 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1518-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 1,750 42 45 3,500 0:01:14 0:22:55 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1518-13 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 2,800 67 76 8,400 0:02:03 0:21:42 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1518-14 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 3,395 81 95 13,580 0:02:35 0:19:39 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1518-15 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 3,500 83 100 15,750 0:02:43 0:17:04 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1518-16 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 3,787 90 110 18,935 0:03:00 0:14:21 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1518-17 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 3,850 92 114 21,175 0:03:06 0:11:21 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1518-18 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 4,060 97 123 24,360 0:03:20 0:08:15 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1518-19 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 2,800 67 86 18,200 0:02:20 0:04:56 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1518-20 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 2,100 50 66 14,700 0:01:47 0:02:36 2.00 1.00 1.25 0.25 0.33 30.00 2.00 4.00 0.1518-21 30# Hybor G Spacer and Ball Drop 37 1,260 30 30 0:00:49 0:00:49 2.00 1.00 1.25 0.25 0.33 30.00 2.00 4.00 0.1519-1 30# Hybor G Pad 37 1,000 24 24 0:00:39 1:17:50 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1519-2 30# Hybor G Conditioning Pad 100M 0.25 37 16,000 381 385 4,000 0:10:25 1:17:11 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1519-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 1,400 33 35 1,400 0:00:57 1:06:46 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1519-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 1,750 42 45 3,500 0:01:14 1:05:50 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1519-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 2,800 67 76 8,400 0:02:03 1:04:36 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1519-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 3,395 81 95 13,580 0:02:35 1:02:33 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1519-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 3,500 83 100 15,750 0:02:43 0:59:58 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1519-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 3,787 90 110 18,935 0:03:00 0:57:15 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1519-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 3,850 92 114 21,175 0:03:06 0:54:16 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1519-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 4,060 97 123 24,360 0:03:20 0:51:10 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1519-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 2,800 67 86 18,200 0:02:20 0:47:50 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1519-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 2,100 50 66 14,700 0:01:47 0:45:30 2.00 1.00 1.25 0.25 0.33 30.00 2.00 4.00 0.1519-13 30# Hybor G Spacer and Ball Drop 37 1,260 30 30 0:00:49 0:43:43 2.00 1.00 1.25 0.25 0.33 30.00 2.00 4.00 0.1519-14 30# Hybor G Pad 37 1,000 24 24 0:00:39 0:42:55 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.1519-15 30# Hybor G Conditioning Pad Wanli 16/20 Ceramic 0.25 37 16,000 381 385 4,000 0:10:25 0:42:16 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.1519-16 30# Hybor G Displacement 15 1,060 25 25 0:01:41 0:31:51 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.1519-17 30# Linear Flush 15 1,600 38 38 0:02:32 0:30:10 1.00 0.33 30.00 2.00 2.00 0.1519-18 30# Hybor G Establish Stable Fluid 8,400 200 200 0:27:38 19-19 30# Hybor G Conditioning Pad Wanli 16/20 Ceramic 0.25 37 4,000 95 96 1,000 0:02:36 0:27:38 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.1519-20 30# Linear Flush 37 4,000 95 95 0:02:34 0:25:02 1.00 0.33 30.00 2.00 2.00 0.1519-21 Shut-In Shut-In 0:22:27 19-22 30# Hybor G Pad 37 1,000 24 24 0:00:39 0:22:27 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.1519-23 30# Hybor G Conditioning Pad Wanli 16/20 Ceramic 0.25 37 16,000 381 385 4,000 0:10:25 0:21:49 2.00 1.00 0.85 0.33 30.00 2.00 2.00 0.1519-24 30# Linear Flush 15 7,179 171 171 0:11:24 0:11:24 1.00 0.33 30.00 2.00 2.00 0.1519-25 Shut-In Shut-In20-1 30# Hybor G Pad 15 1,000 24 24 0:01:35 0:35:52 2.00 1.00 0.33 30.00 2.00 2.00 0.1520-2 30# Hybor G Conditioning Pad Wanli 16/20 Ceramic 0.25 37 16,000 381 385 4,000 0:10:25 0:34:17 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1520-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 1,400 33 35 1,400 0:00:57 0:23:52 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1520-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 1,750 42 45 3,500 0:01:14 0:22:55 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1520-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 2,800 67 76 8,400 0:02:03 0:21:42 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1520-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 3,395 81 95 13,580 0:02:35 0:19:39 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1520-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 3,500 83 100 15,750 0:02:43 0:17:04 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1520-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 3,787 90 110 18,935 0:03:00 0:14:21 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1520-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 3,850 92 114 21,175 0:03:06 0:11:21 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1520-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 4,060 97 123 24,360 0:03:20 0:08:15 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1520-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 2,800 67 86 18,200 0:02:20 0:04:56 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1520-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 2,100 50 66 14,700 0:01:47 0:02:36 2.00 1.00 1.25 0.25 0.33 30.00 2.00 4.00 0.1520-13 30# Hybor G Spacer and Ball Drop 37 1,260 30 30 0:00:49 0:00:49 2.00 1.00 1.25 0.25 0.33 30.00 2.00 4.00 0.1521-1 30# Hybor G Pad 37 1,000 24 24 0:00:39 0:42:14 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1521-2 30# Hybor G Conditioning Pad Wanli 16/20 Ceramic 0.25 37 16,000 381 385 4,000 0:10:25 0:41:35 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1521-3 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 1.00 37 1,400 33 35 1,400 0:00:57 0:31:10 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1521-4 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 37 1,750 42 45 3,500 0:01:14 0:30:14 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1521-5 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 3.00 37 2,800 67 76 8,400 0:02:03 0:29:00 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1521-6 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 37 3,395 81 95 13,580 0:02:35 0:26:57 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1521-7 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 4.50 37 3,500 83 100 15,750 0:02:43 0:24:22 2.00 1.00 1.25 0.33 30.00 2.00 2.00 0.1521-8 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.00 37 3,787 90 110 18,935 0:03:00 0:21:39 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1521-9 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 5.50 37 3,850 92 114 21,175 0:03:06 0:18:40 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1521-10 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 37 4,060 97 123 24,360 0:03:20 0:15:34 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1521-11 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 6.50 37 2,800 67 86 18,200 0:02:20 0:12:14 2.00 1.00 1.25 0.33 30.00 2.00 4.00 0.1521-12 30# Hybor G Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 37 2,100 50 66 14,700 0:01:47 0:09:54 2.00 1.00 1.25 0.25 0.33 30.00 2.00 4.00 0.1521-13 30# Linear Flush 37 7,179 171 171 0:04:37 0:08:07 1.00 0.33 30.00 2.00 4.00 0.1521-14 Produced Water Freeze Protect 10 1,470 35 35 0:03:30 0:03:30 21-15 Shut-In Shut-InInterval 21Kuparuk A Sand@ 9694.5 - 9697.15 ft 143.9 °FInterval 18Kuparuk A Sand@ 11314.8 - 11317.45 ft 144.2 °FInterval 19Kuparuk A Sand@ 10810.8 - 10813.45 ft 144.1 °FInterval 20Kuparuk A Sand@ 10294 - 10296.65 ft 144.2 °FConoco Phillips - 3S-610 Planned Design 167
Customer:Well:Date:Formation:SO#:Tank Type Water Source Inches Gallons Barrels Temperature (°F) Inches Gallons Barrels1 Atigan 3J 81 15,306 364 8 1,262 302 Wichita 3J 96 19,320 460 120 12 2,268 543 Wichita 3J 93 18,690 445 125 48 9,240 2204 Wichita 3J 100 20,160 480 117 100 20,160 4805 Wichita 3J 101 20,370 485 118 101 20,370 4856 Wichita 3J 101 20,370 485 117 101 20,370 4857 Wichita 3J 101 20,370 485 122 101 20,370 4858 Wichita 3J 78 15,540 370 12 2,268 549 Wichita 3J 97 19,530 465 120 12 2,268 5410 Wichita 3J 99 19,950 475 109 99 19,950 47511 Wichita 3J 99 19,950 475 110 99 19,950 47512 Wichita 3J 98 19,740 470 115 98 19,740 47013 Wichita 3J 93 18,690 445 130 93 18,690 44514 Wichita 3J 100 20,160 480 130 100 20,160 48015 Wichita 3J 100 20,160 480 126 100 20,160 48016 Wichita 3J 101 20,370 485 127 101 20,370 48517 Atigan 3J 88 16,660 397 127 88 16,660 39718 Atigan 3J 101 19,175 457 101 19,175 45719 Wichita 3J 97 19,530 465 120 97 19,530 46520 Wichita 3J 98 19,740 470 115 98 19,740 47021 Wichita 3J 98 19,740 470 110 98 19,740 47022 Atigan 3J 90 17,047 406 105 90 17,047 40623 Atigan 3J 103 19,562 466 114 103 19,562 46624 Atigan 3J 103 19,562 466 109 103 19,562 46625 Atigan 3J 103 19,562 466 114 103 19,562 466Gallons Barrels Gallons Barrels Gallons Barrels479,252 11,411 408,172 9,718 71,080 1,692General Beginning Strap Ending StrapLocation SummaryStarting Volume Ending Volume Total UsedConoco Phillips 3S-6105/18/2024Torok0909331970Conoco Phillips - 3S-610 Water Straps 5-18 168
Customer:Well:Date:Formation:SO#:Tank Type Water Source Inches Gallons Barrels Temperature (°F) Inches Gallons Barrels1 Atigan 3J 73 13,759 328 73 13,759 3282 Wichita 3J 68 13,440 320 68 13,440 3203 Wichita 3J 47 9,030 215 12 2,268 544 Wichita 3J 100 20,160 480 12 2,268 545 Wichita 3J 101 20,370 485 13 2,478 596 Wichita 3J 101 20,370 485 10 1,890 457 Wichita 3J 101 20,370 485 10 1,890 458 Wichita 3J 91 18,270 435 91 18,270 4359 Wichita 3J 85 17,010 405 85 17,010 40510 Wichita 3J 99 19,950 475 99 19,950 47511 Wichita 3J 99 19,950 475 99 19,950 47512 Wichita 3J 98 19,740 470 98 19,740 47013 Wichita 3J 93 18,690 445 93 18,690 44514 Wichita 3J 100 20,160 480 100 20,160 48015 Wichita 3J 100 20,160 480 100 20,160 48016 Wichita 3J 101 20,370 485 101 20,370 48517 Atigan 3J 88 16,660 397 88 16,660 39718 Atigan 3J 101 19,175 457 101 19,175 45719 Wichita 3J 97 19,530 465 97 19,530 46520 Wichita 3J 98 19,740 470 98 19,740 47021 Wichita 3J 98 19,740 470 98 19,740 47022 Atigan 3J 90 17,047 406 90 17,047 40623 Atigan 3J 103 19,562 466 103 19,562 46624 Atigan 3J 103 19,562 466 103 19,562 46625 Atigan 3J 103 19,562 466 103 19,562 466Gallons Barrels Gallons Barrels Gallons Barrels462,375 11,009 382,869 9,116 79,506 1,893General Beginning Strap Ending StrapLocation SummaryStarting Volume Ending Volume Total UsedConoco Phillips 3S-6105/19/2024Torok0909331970Conoco Phillips - 3S-610 Water Straps 5-19 169
Customer:Well:Date:Formation:SO#:Tank Type Water Source Inches Gallons Barrels Temperature (°F) Inches Gallons Barrels1 Atigan 3J 91 17,241 410 91 17,241 4102 Wichita 3J 86 17,220 410 86 17,220 4103 Wichita 3J 12 2,268 54 12 2,268 544 Wichita 3J 52 10,080 240 12 2,268 545 Wichita 3J 100 20,160 480 10 1,890 456 Wichita 3J 101 20,370 485 12 2,268 547 Wichita 3J 98 19,740 470 10 1,890 458 Wichita 3J 55 10,710 255 12 2,268 549 Wichita 3J 74 14,700 350 13 2,478 5910 Wichita 3J 98 19,740 470 14 2,646 6311 Wichita 3J 98 19,740 470 12 2,268 5412 Wichita 3J 98 19,740 470 15 2,856 6813 Wichita 3J 27 5,124 122 27 5,124 12214 Wichita 3J 96 19,320 460 96 19,320 46015 Wichita 3J 98 19,740 470 98 19,740 47016 Wichita 3J 98 19,740 470 98 19,740 47017 Atigan 3J 99 18,788 447 99 18,788 44718 Atigan 3J 97 18,401 438 97 18,401 43819 Wichita 3J 99 19,950 475 99 19,950 47520 Wichita 3J 99 19,950 475 99 19,950 47521 Wichita 3J 98 19,740 470 98 19,740 47022 Atigan 3J 87 16,467 392 87 16,467 39223 Atigan 3J 98 18,595 443 98 18,595 44324 Atigan 3J 99 18,788 447 99 18,788 44725 Atigan 3J 103 19,562 466 103 19,562 466Gallons Barrels Gallons Barrels Gallons Barrels425,872 10,140 291,724 6,946 134,148 3,194General Beginning Strap Ending StrapLocation SummaryStarting Volume Ending Volume Total UsedConoco Phillips 3S-6105/20/2024Torok0909331970Conoco Phillips - 3S-610 Water Straps 5-20 170
Customer:Well:Date:Formation:SO#:Tank Type Water Source Inches Gallons Barrels Temperature (°F) Inches Gallons Barrels1 Atigan 3J 91 17,241 410 12 1,992 472 Wichita 3J 86 17,220 410 120 11 2,100 503 Wichita 3J 38 7,224 172 125 0 04 Wichita 3J 52 10,080 240 117 13 2,478 595 Wichita 3J 100 20,160 480 118 15 2,856 686 Wichita 3J 101 20,370 485 117 12 2,268 547 Wichita 3J 98 19,740 470 122 22 4,158 998 Wichita 3J 98 19,740 470 12 2,268 549 Wichita 3J 98 19,740 470 120 15 2,856 6810 Wichita 3J 101 20,370 485 109 15 2,856 6811 Wichita 3J 95 19,110 455 110 0 012 Wichita 3J 95 19,110 455 115 0 013 Wichita 3J 95 19,110 455 130 0 014 Wichita 3J 93 18,690 445 130 0 015 Wichita 3J 100 20,160 480 126 0 016 Wichita 3J 99 19,950 475 127 0 017 Atigan 3J 97 18,401 438 127 22 118 Atigan 3J 97 18,401 438 50 9,119 21719 Wichita 3J 48 9,240 220 120 0 020 Wichita 3J 99 19,950 475 115 17 3,234 7721 Wichita 3J 98 19,740 470 110 10 1,890 4522 Atigan 3J 87 16,467 392 105 12 1,992 4723 Atigan 3J 98 18,595 443 114 12 1,992 4724 Atigan 3J 99 18,788 447 109 12 1,992 4725 Atigan 3J 103 19,562 466 114 12 1,992 47Gallons Barrels Gallons Barrels Gallons Barrels447,158 10,647 46,065 1,097 401,093 9,550Conoco Phillips 3S-6105/21/2024Torok0909331970General Beginning Strap Ending StrapLocation SummaryStarting Volume Ending Volume Total UsedConoco Phillips - 3S-610 Water Straps 5-21 171
Customer:Well:Date:Formation:SO#:Tank Type Water Source Inches Gallons Barrels Temperature (°F) Inches Gallons Barrels1 Atigan 3J 76 14,339 341 116 15 2,540 602 Wichita 3J 85 17,010 405 117 15 2,856 683 Wichita 3J 38 7,224 172 115 13 2,478 594 Wichita 3J 100 20,160 480 118 14 2,646 635 Wichita 3J 102 20,580 490 118 16 3,024 726 Wichita 3J 101 20,370 485 125 14 2,646 637 Wichita 3J 101 20,370 485 125 15 2,856 688 Wichita 3J 101 20,370 485 122 15 2,856 689 Wichita 3J 101 20,370 485 122 12 2,268 5410 Wichita 3J 101 20,370 485 128 15 2,856 6811 Wichita 3J 95 19,110 455 127 15 2,856 6812 Wichita 3J 95 19,110 455 104 15 2,856 6813 Wichita 3J 95 19,110 455 130 15 2,856 6814 Wichita 3J 93 18,690 445 118 16 3,024 7215 Wichita 3J 100 20,160 480 132 12 2,268 5416 Wichita 3J 99 19,950 475 138 10 1,890 4517 Atigan 3J 97 18,401 438 135 14 2,357 5618 Atigan 3J 98 18,595 443 103 14 2,357 5619 Wichita 3J 98 19,740 470 126 16 3,024 7220 Wichita 3J 98 19,740 470 133 33 6,258 14921 Wichita 3J 98 19,740 470 126 73 14,490 34522 Atigan 3J 98 18,595 443 126 97 18,401 43823 Atigan 3J 99 18,788 447 125 99 18,788 44724 Atigan 3J 98 18,595 443 126 98 18,595 44325 Atigan 3J 98 18,595 443 126 98 18,595 443Flow Rate Stop Pumping5.2 16:29Gallons Barrels Gallons Barrels Gallons Barrels Gallons Barrels468,081 11,145 145,640 3,468 62,026 1477 384,466 9,154Starting VolumeConoco Phillips 3S-6105/23/2204Torok0909331970General Beginning Strap23-May 11:45Ending StrapOn the Fly Load SummaryDateStart flowing Flowing Temp125Location SummaryEnding Volume On the Fly Flowing Total UsedConoco Phillips - 3S-610 Water Straps 5-23 172
Customer:Well:Date:Formation:SO#:Tank Type Water Source Inches Gallons Barrels Temperature (°F) Inches Gallons Barrels1 Atigan 3J 87 16,467 392 116 15 2,540 602 Wichita 3J 95 19,110 455 117 17 3,234 773 Wichita 3J 96 19,320 460 115 15 2,856 684 Wichita 3J 95 19,110 455 118 15 2,856 685 Wichita 3J 95 19,110 455 118 15 2,856 686 Wichita 3J 95 19,110 455 125 40 7,602 1817 Wichita 3J 95 19,110 455 125 90 18,060 4308 Wichita 3J 88 17,640 420 122 41 7,812 1869 Wichita 3J 101 20,370 485 122 15 2,856 6810 Wichita 3J 101 20,370 485 128 14 2,646 6311 Wichita 3J 105 21,000 500 127 15 2,856 6812 Wichita 3J 103 20,790 495 104 15 2,856 6813 Wichita 3J 103 20,790 495 130 15 2,856 6814 Wichita 3J 62 12,180 290 118 15 2,856 6815 Wichita 3J 65 12,810 305 132 14 2,646 6316 Wichita 3J 65 12,810 305 138 15 2,856 6817 Atigan 3J 66 12,405 295 135 15 2,540 6018 Atigan 3J 17 2,905 69 103 17 2,905 6919 Wichita 3J 22 4,158 99 126 15 2,856 6820 Wichita 3J 32 6,048 144 133 15 2,856 6821 Wichita 3J 91 18,270 435 126 15 2,856 6822 Atigan 3J 66 12,405 295 126 15 2,540 6023 Atigan 3J 92 17,434 415 125 16 2,722 6524 Atigan 3J 98 18,595 443 126 16 2,722 6525 Atigan 3J 101 19,175 457 126 15 2,540 60Flow Rate Stop Flowing5.2 16:30Gallons Barrels Gallons Barrels Gallons Barrels Gallons Barrels401,490 9,559 94,780 2,257 59,405 1414 366,115 8,717Starting VolumeLocation SummaryEnding Volume On the Fly Flowing Total Used24-May 11:58 130General Beginning Strap Ending StrapOn the Fly Load SummaryDateStart flowing Flowing TempConoco Phillips 3S-6105/24/2204Torok0909331970Conoco Phillips - 3S-610 Water Straps 5-24 173
Customer:Well:Date:Formation:SO#:Tank Type Water Source Inches Gallons Barrels Temperature (°F) Inches Gallons Barrels1 Atigan 3J 15 2,540 60 15 2,540 602 Wichita 3J 17 3,234 77 17 3,234 773 Wichita 3J 15 2,856 68 15 2,856 684 Wichita 3J 15 2,856 68 15 2,856 685 Wichita 3J 15 2,856 68 15 2,856 686 Wichita 3J 95 19,110 455 95 19,110 4557 Wichita 3J 91 18,270 435 91 18,270 4358 Wichita 3J 51 9,870 235 51 9,870 2359 Wichita 3J 15 2,856 68 15 2,856 6810 Wichita 3J 14 2,646 63 14 2,646 6311 Wichita 3J 15 2,856 68 15 2,856 6812 Wichita 3J 15 2,856 68 15 2,856 6813 Wichita 3J 15 2,856 68 15 2,856 6814 Wichita 3J 92 18,480 440 35 6,636 15815 Wichita 3J 92 18,480 440 35 6,636 15816 Wichita 3J 92 18,480 440 10 1,890 4517 Atigan 3J 92 17,434 415 12 1,992 4718 Atigan 3J 99 18,788 447 12 1,992 4719 Wichita 3J 98 19,740 470 14 2,646 6320 Wichita 3J 97 19,530 465 11 2,100 5021 Wichita 3J 98 19,740 470 21 3,990 9522 Atigan 3J 98 18,595 443 13 2,174 5223 Atigan 3J 102 19,368 461 15 2,540 6024 Atigan 3J 101 19,175 457 15 2,540 6025 Atigan 3J 101 19,175 457 15 2,540 60Flow Rate Stop Flowing6.2 14:38Gallons Barrels Gallons Barrels Gallons Barrels Gallons Barrels302,646 7,206 113,337 2,699 60,673 1445 249,981 5,952Location SummaryStarting Volume Ending Volume On the Fly Flowing Total Used24-May 10:45 130General Beginning Strap Ending StrapOn the Fly Load SummaryDateStart flowing Flowing TempConoco Phillips 3S-6105/25/2204Torok0909331970Conoco Phillips - 3S-610 Water Straps 5-25 174
Customer:Well:Date:Formation:SO#:Tank Type Water Source Inches Gallons Barrels Temperature (°F) Inches Gallons Barrels1 Atigan 3J 89 16,854 401 89 16,854 4012 Wichita 3J 96 19,320 460 130 96 19,320 4603 Wichita 3J 94 18,900 450 128 94 18,900 4504 Wichita 3J 85 17,010 405 130 85 17,010 4055 Wichita 3J 91 18,270 435 129 91 18,270 4356 Wichita 3J 96 19,320 460 128 96 19,320 4607 Wichita 3J 93 18,690 445 130 93 18,690 4458 Wichita 3J 103 20,790 495 128 103 20,790 4959 Wichita 3J 102 20,580 490 130 102 20,580 49010 Wichita 3J 102 20,580 490 129 102 20,580 49011 Wichita 3J 103 20,790 495 127 103 20,790 49512 Wichita 3J 103 20,790 495 129 103 20,790 49513 Wichita 3J 103 20,790 495 127 33 6,258 14914 Wichita 3J 103 20,790 495 129 16 3,024 7215 Wichita 3J 103 20,790 495 127 15 2,856 6816 Wichita 3J 103 20,790 495 130 17 3,234 7717 Atigan 3J 103 19,562 466 128 15 2,540 6018 Atigan 3J 94 17,821 424 128 94 17,821 42419 Wichita 3J 94 18,900 450 129 94 18,900 45020 Wichita 3J 94 18,900 450 128 94 18,900 45021 Wichita 3J 94 18,900 450 127 94 18,900 45022 Atigan 3J 13 2,174 52 13 2,174 5223 Atigan 3J 15 2,540 60 15 2,540 6024 Atigan 3J 15 2,540 60 15 2,540 6025 Atigan 3J 15 2,540 60 15 2,540 60Flow Rate Stop Flowing7.2 15:22Gallons Barrels Gallons Barrels Gallons Barrels Gallons Barrels418,929 9,975 334,120 7,955 102,816 2448 187,626 4,467Location SummaryStarting Volume Ending Volume On the Fly Flowing Total Used26-May 9:42 130General Beginning Strap Ending StrapOn the Fly Load SummaryDateStart flowing Flowing TempConoco Phillips 3S-6105/25/2204Torok0909331970Conoco Phillips - 3S-610 Water Straps 5-26 175
Specific
Gravity
Testing
Temperature
Dissolved Iron
(Fe2+)
Chloride
(Cl-)
Sulfate
(SO42-)
Calcium
(Ca2+)
Magnesium
(Mg2+)
Total
Hardness
Linear
Viscosity
Water
pH
Gel
pH
Post-Crosslink
pH Crosslink Bacteria
- °F mg/L mg/L mg/L mg/L mg/L mg/L cP - - - (Y/N) BQ Value
Tank #
H2S
present?
Y/N
Hydrometer Digital
Thermometer Strip Strip Strip Titration
Total Hardness
Minus Calcium Titration FANN-35 Probe Probe Probe - Mycometer
1 N 1.010 89.7 2 9,360 400 2,400 -1,000 1,400 25.0 7.70 7.10 8.90 Y 6,118
2 N 1.015 100.5 2 15,160 400 2,240 -880 1,360 26.0 7.70 7.10 9.00 Y 731
3 N 1.016 107.9 2 13,980 400 2,400 -1,000 1,400 26.0 7.80 7.20 9.00 Y 825
4 N 1.014 104.5 2 15,160 400 2,400 -960 1,440 26.0 7.80 7.10 9.10 Y 837
5 N 1.014 94.1 2 13,980 200 1,960 -840 1,120 25.0 7.70 7.00 9.10 Y 510
6 N 1.016 107.0 2 13,980 400 2,240 -760 1,480 25.0 7.70 7.30 9.20 Y 575
7 N 1.015 107.4 2 13,980 400 2,280 -320 1,960 27.0 7.70 7.10 9.20 Y 335
8 N 1.020 108.0 2 15,160 400 800 600 1,400 25.0 7.70 7.31 9.20 Y 68
9 N 1.019 108.0 2 15,160 200 760 200 960 25.0 7.80 7.10 9.00 Y 170
10 N 1.014 108.0 2 13,980 200 800 0 800 25.0 7.70 7.10 9.10 Y 322
11 N 1.014 108.0 2 13,980 200 720 80 800 26.0 7.70 7.20 9.20 Y 198
12 N 1.016 105.0 2 13,980 200 1,520 40 1,560 26.0 7.70 7.20 9.10 Y 147
13 N 1.020 107.4 2 15,160 200 1,720 280 2,000 25.0 7.80 7.10 9.00 Y 76
14 N 1.019 110.2 2 13,980 200 2,280 -840 1,440 25.0 7.70 7.10 9.10 Y 273
15 N 1.014 117.6 2 13,980 200 800 320 1,120 26.0 7.70 7.20 9.20 Y 241
16 N 1.014 122.1 2 13,980 200 760 720 1,480 24.0 7.80 7.10 9.20 Y 341
17 0
18 0
19 N 1.021 87.9 2 25,170 1,200 3,360 -200 3,160 26.0 7.20 7.40 9.30 Y 166
20 N 1.020 93.0 2 21,120 1,200 1,520 1,520 3,040 27.0 7.20 7.50 9.30 Y 473
21 N 1.020 93.0 2 19,410 1,200 1,320 1,760 3,080 25.0 7.20 7.50 9.20 Y 645
22 N 1.022 92.0 2 19,410 1,200 1,200 1,960 3,160 25.0 7.20 7.60 9.30 Y 345
23 N 1.021 87.9 2 27,580 1,200 3,360 -1,920 1,440 26.0 7.00 7.60 9.60 Y 5,107
24 N 1.021 89.0 2 25,170 1,200 3,360 -2,000 1,360 26.0 7.00 7.50 9.30 Y 1,802
Average 1.018 2 15,487 658 1,610 -145 1,465 25.5 7.52 7.27 9.20 - 877
Maximum 1.022 2 33,390 1,200 3,360 1,960 3,160 27.0 7.80 7.60 9.60 - 6,717
Minimum 1.014 2 0 200 0 -2,120 0 24.00 6.90 7.10 9.00 - 0
Range 0.008 0 33,390 1,000 3,360 4,080 3,160 3.0 0.90 0.50 0.60 - 6,717
Alaska District Field QC
Prejob Water Analysis on Location
Company:Conoco Phillips
Well Name:3S-610
Water Source:CPF3
Conoco Phillips - 3S-610 Water Analysis 5-18 176
Specific
Gravity
Testing
Temperature
Dissolved Iron
(Fe2+)
Chloride
(Cl-)
Sulfate
(SO42-)
Calcium
(Ca2+)
Magnesium
(Mg2+)
Total
Hardness
Linear
Viscosity
Water
pH
Gel
pH
Post-Crosslink
pH Crosslink Bacteria
- °F mg/L mg/L mg/L mg/L mg/L mg/L cP - - - (Y/N) BQ Value
Tank #
H2S
present?
Y/N
Hydrometer Digital
Thermometer Strip Strip Strip Titration
Total Hardness
Minus Calcium Titration FANN-35 Probe Probe Probe - Mycometer
1 N 1.022 98.0 2 19,240 1,200 920 1,320 2,240 499
2 N 1.026 98.0 2 24,480 1,200 1,280 1,080 2,360 595
8 N 1.020 108.0 2 15,160 400 800 600 1,400 593
9 N 1.019 108.0 2 15,160 200 760 200 960 710
17 N 1.018 100.0 2 15,230 200 520 400 920 189
18 N 1.020 100.0 2 20,830 1,600 1,480 1,600 3,080 3,219
Average 1.021 2 18,350 800 960 867 1,827 25.3 7.47 7.17 9.03 - 967
Maximum 1.026 2 24,480 1,600 1,480 1,600 3,080 26.0 7.70 7.30 9.20 - 3,219
Minimum 1.018 2 15,230 200 520 400 920 25.00 7.60 7.10 8.90 - 189
Range 0.008 0 9,250 1,400 960 1,200 2,160 1.0 0.10 0.20 0.30 - 3,030
25.0 7.60 7.10 8.90 Y
26.0 7.10 7.30 9.00 Y
25.0 7.70 7.10 9.20 Y
Well Name:3S-610
Water Source:CPF3
Alaska District Field QC
Prejob Water Analysis on Location
Company:Conoco Phillips
Conoco Phillips - 3S-610 Water Analysis 5-19 177
Specific
Gravity
Testing
Temperature
Dissolved Iron
(Fe2+)
Chloride
(Cl-)
Sulfate
(SO42-)
Calcium
(Ca2+)
Magnesium
(Mg2+)
Total
Hardness
Linear
Viscosity
Water
pH
Gel
pH
Post-Crosslink
pH Crosslink Bacteria
- °F mg/L mg/L mg/L mg/L mg/L mg/L cP - - - (Y/N) BQ Value
Tank #
H2S
present?
Y/N
Hydrometer Digital
Thermometer Strip Strip Strip Titration
Total Hardness
Minus Calcium Titration FANN-35 Probe Probe Probe - Mycometer
5 N 1.020 95.0 2 15,230 400 760 240 1,000 2,509
6 N 1.021 95.0 2 14,100 200 800 160 960 499
7 N 1.018 95.0 2 15,230 200 960 120 1,080 180
Average 1.020 2 14,853 267 840 173 1,013 25.0 8.00 7.30 9.00 - 1,063
Maximum 1.021 2 15,230 400 960 240 1,080 25.0 8.00 7.30 9.00 - 2,509
Minimum 1.018 2 14,100 200 760 120 960 25.00 8.00 7.30 9.00 - 180
Range 0.003 0 1,130 200 200 120 120 0.0 0.00 0.00 0.00 - 2,329
25.0 8.00 7.30 9.00 Y
Alaska District Field QC
Prejob Water Analysis on Location
Company:Conoco Phillips
Well Name:3S-610
Water Source:CPF3
Conoco Phillips - 3S-610 Water Analysis 5-20 178
Specific
Gravity
Testing
Temperature
Dissolved Iron
(Fe2+)
Chloride
(Cl-)
Sulfate
(SO42-)
Calcium
(Ca2+)
Magnesium
(Mg2+)
Total
Hardness
Linear
Viscosity
Water
pH
Gel
pH
Post-Crosslink
pH Crosslink Bacteria
- °F mg/L mg/L mg/L mg/L mg/L mg/L cP - - - (Y/N) BQ Value
Tank #
H2S
present?
Y/N
Hydrometer Digital
Thermometer Strip Strip Strip Titration
Total Hardness
Minus Calcium Titration FANN-35 Probe Probe Probe - Mycometer
3 N 1.020 83.0 2 14,100 200 640 120 760 1,188
4 N 1.018 83.0 2 14,100 200 680 120 800 534
5 N 1.018 83.0 2 14,100 200 800 160 960 651
6 N 1.018 83.0 2 14,100 200 560 120 680 548
7 N 1.020 83.0 2 14,100 200 600 120 720 448
8 N 1.017 85.0 2 14,100 200 520 160 680 149
9 N 1.018 85.0 2 14,100 400 560 280 840 67
10 N 1.020 85.0 2 16,460 200 600 160 760 139
11 N 1.016 85.0 2 14,100 200 520 160 680 583
12 N 1.016 85.0 2 14,100 200 640 40 680 149
Average 1.018 2 14,336 220 612 144 756 25.5 7.70 7.35 9.00 - 446
Maximum 1.020 2 16,460 400 800 280 960 26.0 7.70 7.40 9.00 - 1,188
Minimum 1.016 2 14,100 200 520 40 680 25.00 7.70 7.40 9.00 - 67
Range 0.004 0 2,360 200 280 240 280 1.0 0.00 0.00 0.00 - 1,121
25.0 7.70 7.40 9.00 Y
26.0 7.70 7.30 9.00 Y
Alaska District Field QC
Prejob Water Analysis on Location
Company:Conoco Phillips
Well Name:3S-610
Water Source:CPF3
Conoco Phillips - 3S-610 Water Analysis 5-21 179
Specific
Gravity
Testing
Temperature
Dissolved Iron
(Fe2+)
Chloride
(Cl-)
Sulfate
(SO42-)
Calcium
(Ca2+)
Magnesium
(Mg2+)
Total
Hardness
Linear
Viscosity
Water
pH
Gel
pH
Post-
Crosslink
pH
Crosslink Bacteria
- °F mg/L mg/L mg/L mg/L mg/L mg/L cP - - - (Y/N) BQ Value
Tank #
H2S
present?
Y/N
Hydrometer Digital Thermometer Strip Strip Strip Titration
Total Hardness
Minus Calcium Titration FANN-35 Probe Probe Probe - Mycometer
1 N 1.010 92.0 2 13,980 200 560 280 840 78
2 N 1.015 95.0 2 13,980 200 560 280 840 111
3 N 1.016 93.0 2 15,160 200 600 400 1,000 34
4 N 1.014 93.0 2 15,160 200 640 320 960 101
5 N 1.014 93.0 2 13,980 400 800 40 840 167
6 N 1.016 95.0 2 15,160 400 560 840 1,400 125
7 N 1.015 97.0 2 13,980 200 560 640 1,200 59
8 N 1.020 98.0 2 15,160 200 600 480 1,080 180
9 N 1.019 98.0 2 15,160 400 840 160 1,000 176
10 N 1.014 93.0 2 13,980 200 520 320 840 39
11 N 1.014 95.0 2 14,100 200 560 320 880 1,902
12 N 1.016 98.0 2 14,100 200 600 400 1,000 1,653
13 N 1.020 96.0 2 14,100 400 800 160 960 299
14 N 1.019 95.0 2 15,160 400 760 280 1,040 1,210
15 N 1.014 93.0 2 15,160 200 680 120 800 3,046
16 N 1.014 92.0 2 15,160 400 720 120 840 576
17 N 1.014 93.0 2 13,980 400 480 480 960 134
18 N 1.014 95.0 2 13,980 200 520 480 1,000 471
19 N 1.021 87.9 2 6,290 200 520 480 1,000 384
20 N 1.020 93.0 2 14,100 200 520 280 800 1,324
21 N 1.020 93.0 2 14,100 200 560 200 760 809
22 N 1.022 92.0 2 14,100 200 600 440 1,040 910
23 N 1.021 87.9 2 14,100 200 520 400 920 1,222
24 N 1.021 89.0 2 14,100 200 600 320 920 782
25 N 1.021 87.0 2 15,160 200 640 360 1,000 599
Average 1.017 2 14,136 256 613 344 957 20.6 7.94 8.28 9.14 - 656
Maximum 1.022 2 15,160 400 840 840 1,400 21.0 8.00 8.30 9.20 - 3,046
Minimum 1.010 2 6,290 200 480 40 760 20.00 7.90 8.30 9.10 - 34
Range 0.012 0 8,870 200 360 800 640 1.0 0.10 0.00 0.10 - 3,012
21.0 8.00 8.30 9.10 Y
21.0 7.90 8.30 9.10 Y
20.0 7.90 8.30 9.20 Y
21.0 8.00 8.20 9.10 Y
20.0 7.90 8.30 9.20 Y
Well Name:3S-610
Water Source:CPF3
Alaska District Field QC
Prejob Water Analysis on Location
Company:Conoco Phillips
Conoco Phillips - 3S-610 Water Analysis 5-23 180
Specific
Gravity
Testing
Temperature
Dissolved Iron
(Fe2+)
Chloride
(Cl-)
Sulfate
(SO42-)
Calcium
(Ca2+)
Magnesium
(Mg2+)
Total
Hardness
Linear
Viscosity
Water
pH
Gel
pH
Post-
Crosslink
pH
Crosslink Bacteria
- °F mg/L mg/L mg/L mg/L mg/L mg/L cP - - - (Y/N) BQ Value
Tank #
H2S
present?
Y/N
Hydrometer Digital Thermometer Strip Strip Strip Titration
Total Hardness
Minus Calcium Titration FANN-35 Probe Probe Probe - Mycometer
1 N 1.020 87.0 5 24,480 200 520 280 800 667
2 N 1.020 87.0 5 26,600 200 560 80 640 1,126
3 N 1.020 90.0 5 31,600 200 560 80 640 1,311
4 N 1.020 90.0 5 31,600 200 560 160 720 868
5 N 1.021 92.0 5 22,570 200 520 280 800 1,400
6 N
7 N
8 N 1.018 87.0 5 11,170 200 520 80 600 254
9 N 1.020 87.0 5 14,100 200 320 240 560 111
10 N 1.020 77.0 5 14,100 200 360 200 560 86
11 N 1.020 75.0 5 14,100 200 560 0 560 95
12 N 1.020 87.0 5 13,050 200 400 160 560 104
13 N 1.018 87.0 5 14,100 400 480 320 800 1,333
14 N 1.020 92.0 5 28,960 200 480 320 800 672
15 N 1.020 92.0 5 22,570 200 560 0 560 766
16 N
17 N 1.020 85.0 5 38,030 200 520 200 720 856
18 N
19 N
20 N 1.020 85.0 5 22,570 200 520 280 800 853
21 N 1.020 85.0 5 31,600 200 560 240 800 743
22 N 1.022 92.0 2 14,100 200 600 440 1,040 910
23 N 1.021 87.9 2 14,100 200 520 400 920 1,222
24 N 1.021 89.0 2 14,100 200 600 320 920 782
25 N 1.021 87.0 2 15,160 200 640 360 1,000 599
Average 1.020 4 20,933 210 518 222 740 20.0 7.84 8.08 9.18 - 738
Maximum 1.022 5 38,030 400 640 440 1,040 22.0 8.00 8.30 9.30 - 1,400
Minimum 1.018 2 11,170 200 320 0 560 18.00 7.80 7.90 9.10 - 86
Range 0.004 3 26,860 200 320 440 480 4.0 0.20 0.40 0.20 - 1,314
21.0 8.00 8.30 9.10 Y
20.0 7.80 7.90 9.20 Y
22.0 7.80 8.30 9.30 Y
19.0 7.80 8.00 9.10 Y
18.0 7.80 7.90 9.20 Y
Well Name:3S-610
Water Source:CPF3
Alaska District Field QC
Prejob Water Analysis on Location
Company:Conoco Phillips
Conoco Phillips - 3S-610 Water Analysis 5-24 181
Specific
Gravity
Testing
Temperature
Dissolved Iron
(Fe2+)
Chloride
(Cl-)
Sulfate
(SO42-)
Calcium
(Ca2+)
Magnesium
(Mg2+)
Total
Hardness
Linear
Viscosity
Water
pH
Gel
pH
Post-
Crosslink
pH
Crosslink Bacteria
- °F mg/L mg/L mg/L mg/L mg/L mg/L cP - - - (Y/N) BQ Value
Tank #
H2S
present?
Y/N
Hydrometer Digital Thermometer Strip Strip Strip Titration
Total Hardness
Minus Calcium Titration FANN-35 Probe Probe Probe - Mycometer
15 N 1.016 92.0 5 14,100 200 560 160 720 18.0 8.00 7.20 9.20 Y 519
16 N 1.016 93.0 5 14,100 200 560 160 720 1,621
17 N 1.016 95.0 5 14,100 200 480 160 640 783
18 N 1.016 95.0 5 14,100 200 480 160 640 516
19 N 1.016 95.0 5 14,100 200 560 160 720 377
20 N 1.016 95.0 5 14,100 400 560 200 760 2,311
21 N 1.018 95.0 5 14,100 200 520 80 600 373
22 N 1.014 92.0 5 14,100 200 600 200 800 621
23 N 1.012 92.0 5 13,050 400 520 80 600 146
24 N 1.012 95.0 5 14,100 400 480 240 720 340
25 N 1.012 92.0 5 14,100 400 520 280 800 1,041
Average 1.015 5 14,005 273 531 171 702 19.3 7.97 7.17 9.13 - 786
Maximum 1.018 5 14,100 400 600 280 800 22.0 8.00 7.20 9.20 - 2,311
Minimum 1.012 5 13,050 200 480 80 600 18.00 7.90 7.10 9.00 - 146
Range 0.006 0 1,050 200 120 200 200 4.0 0.10 0.10 0.20 - 2,165
22.0 7.90 7.10 9.00 Y
18.0 8.00 7.20 9.20 Y
Alaska District Field QC
Prejob Water Analysis on Location
Company:Conoco Phillips
Well Name:3S-610
Water Source:
Conoco Phillips - 3S-610 Water Analysis 5-25 182
Specific
Gravity
Testing
Temperature
Dissolved Iron
(Fe2+)
Chloride
(Cl-)
Sulfate
(SO42-)
Calcium
(Ca2+)
Magnesium
(Mg2+)
Total
Hardness
Linear
Viscosity
Water
pH
Gel
pH
Post-
Crosslink
pH
Crosslink Bacteria
- °F mg/L mg/L mg/L mg/L mg/L mg/L cP - - - (Y/N) BQ Value
Tank #
H2S
present?
Y/N
Hydrometer Digital Thermometer Strip Strip Strip Titration
Total Hardness
Minus Calcium Titration FANN-35 Probe Probe Probe - Mycometer
1 N 1.020 92.0 0 15,160 400 800 600 1,400 1,204
2 N 1.020 94.0 0 13,980 400 760 200 960 4,004
3 N 1.018 95.0 0 15,160 200 800 120 920 3,772
4 N 1.020 90.0 2 15,160 200 800 40 840 4,386
5 N 1.020 89.0 2 15,160 200 720 80 800 4,333
6 N 1.020 88.0 2 15,160 200 680 120 800 840
7 N 1.022 95.0 2 15,160 200 760 40 800 3,115
8 N 1.019 96.0 2 15,160 200 800 80 880 2,870
9 N 1.020 95.0 2 13,950 200 640 160 800 3,085
10 N 1.020 95.0 0 15,160 200 720 160 880 2,836
11 N 1.022 95.0 2 15,160 400 680 280 960 1,441
12 N 1.020 95.0 0 15,160 400 640 200 840 3,532
13 N 1.018 95.0 2 15,160 400 600 160 760 3,404
14 N 1.018 96.0 2 19,160 400 560 160 720 4,372
15 N 1.018 96.0 2 15,160 200 800 120 920 3,947
Average 1.020 1 15,185 271 727 169 896 24.7 7.07 7.43 9.00 - 3,080
Maximum 1.022 2 19,160 400 840 600 1,400 25.0 7.10 7.60 9.00 - 4,386
Minimum 1.018 0 13,950 200 560 40 720 24.00 7.00 7.30 9.00 - 840
Range 0.004 2 5,210 200 280 560 680 1.0 0.10 0.30 0.00 - 3,546
25.0 7.00 7.30 9.00 Y
Y
24.0 7.10 7.40 9.00 Y
25.0 7.10 7.60 9.00
Well Name:3S-610
Water Source:Produced Water
Alaska District Field QC
Prejob Water Analysis on Location
Company:Conoco Phillips
Conoco Phillips - 3S-610 Water Analysis 5-26 183
Linear Linear XL XL XL Lip time Linear Linear XL XL XL Lip time
Interval Stage Visc pH Temp °F pH min Interval Stage Visc pH Temp °F pH min
1 Pad 22 7..3 102 8.7 1 9 Pad 29 7.3 85 8.8 1
0.25# 23 7.3 87 8.7 1 22 Avg Linear Visc 0.25# 29 7.3 100 8.8 0 28 Avg Linear Visc
1.00# 23 7.3 99 8.8 1 98.2 Avg XLTemp 1.00# 29 7.2 95 8.7 0 97.3 Avg XLTemp
2.00# 22 7.3 101 8.8 1 8.8 Avg XL pH 2.00# 8.7 Avg XL pH
3.00# 21 7.4 102 8.8 1 3.00# 28 7.2 100 8.7 0
4.00# 4.00# 27 7.2 100 8.7 0
4.50# 4.50# 27 7.2 95 8.7 0
5.00# 5.00# 26 7.1 103 8.7 0
5.50# 5.50# 26 7.1 100 8.7 0
6.00# 6.00# 26 7.1 98 8.8 0
6.50# 6.50# 26 7.2 100 8.9 0
7.00#7.00# 26 7.2 100 8.8 0
1B Pad 22 7.3 90 8.7 1 10 Pad 26 7.1 100 8.9 0
0.25# 23 7.3 93 8.7 1 0.25#
1.00# 23 7.3 90 8.7 1 1.00# 24 7.2 95 8.9 0
2.00# 24 7.3 90 8.7 1 23 Avg Linear Visc 2.00# 24 Avg Linear Visc
3.00# 24 7.4 90 8.7 1 91.8 Avg XLTemp 3.00# 25 7.1 100 8.9 0 97.3 Avg XLTemp
4.00# 23 7.3 92 8.7 1 8.7 Avg XL pH 4.00# 8.9 Avg XL pH
4.50# 22 7.3 90 8.5 1 4.50# 23 7.1 98 8.9 0
5.00# 22 7.3 91 8.6 1 5.00# 23 7.2 103 8.8 0
5.50# 21 7.4 91 8.6 1 5.50#
6.00# 21 7.5 93 8.5 1 6.00# 23 7.1 90 8.8 0
6.50# 24 7.3 95 8.9 1 6.50#
7.00# 23 7.3 97 8.9 1 7.00# 23 7.1 95 8.9 0
2 Pad 25 7.3 97 9 1 11 Pad 26 7.3 95 8.7 0
0.25# 25 7.3 97 8.7 1 0.25#
1.00# 23 7.3 97 8.9 1 1.00# 28 7.3 90 8.8 0
2.00# 23 7.3 97 8.9 1 23 Avg Linear Visc 2.00# 26 Avg Linear Visc
3.00# 22 7.3 99 8.9 1 97.1 Avg XLTemp 3.00# 26 7.3 102 8.8 0 95.8 Avg XLTemp
4.00# 22 7.3 97 8.8 1 8.9 Avg XL pH 4.00# 8.7 Avg XL pH
4.50# 22 7.3 97 8.9 1 4.50# 26 7.3 95 8.6 0
5.00# 22 7.1 96 8.8 1 5.00#
5.50# 22 7.1 98 8.8 1 5.50# 24 7.3 95 8.7 0
6.00# 22 7.3 97 8.8 1 6.00#
6.50# 22 7.3 97 8.9 1 6.50# 24 7.3 98 8.7 0
7.00# 22 7.1 96 8.8 1 7.00#
3 Pad 26 7.3 83 9.3 1 12 Pad 23 7.3 102 8.8 0
0.25# 24 7.3 79 9.2 1 0.25#
1.00# 24 7.3 79 9.3 1 1.00# 23 7.2 102 8.8 0
2.00# 24 7.3 80 9.3 1 25 Avg Linear Visc 2.00# 23 Avg Linear Visc
3.00# 24 7.4 84 9.3 1 83.0 Avg XLTemp 3.00# 22 7.2 100 8.8 0 102.7 Avg XLTemp
4.00# 24 7.3 84 9.4 1 9.3 Avg XL pH 4.00# 8.8 Avg XL pH
4.50# 24 7.4 84 9.3 1 4.50# 23 7.1 105 8.7 0
5.00# 24 7.3 84 9.4 1 5.00#
5.50# 24 7.3 84 9.3 1 5.50# 23 7.2 105 8.8 0
6.00# 26 7.3 84 9.3 1 6.00#
6.50# 26 7.3 84 9.4 1 6.50# 23 7.2 102 8.8 0
7.00# 26 7.3 87 9.3 1 7.00#
4 Pad 25 7.4 93 9.1 1 13 Pad
0.25# 27 7.3 97 8.7 1 0.25# 23 7.2 102 8.7 2
1.00# 27 7.3 87 8.7 1 1.00#
2.00# 25 7.3 95 8.7 1 25 Avg Linear Visc 2.00# 23 Avg Linear Visc
3.00# 25 7.3 97 8.5 1 94.9 Avg XLTemp 3.00# 102.4 Avg XLTemp
4.00# 24 7.3 95 8.7 1 8.7 Avg XL pH 4.00# 24 7.2 104 9 0 9.0 Avg XL pH
4.50# 25 7.3 95 8.6 1 4.50#
5.00# 27 7.3 93 8.7 1 5.00#
5.50# 26 7.3 92 8.6 1 5.50# 24 7.2 100 9 0
6.00# 25 7.4 102 8.4 1 6.00# 23 7.2 104 9 0
6.50# 23 7.4 97 8.5 1 6.50#
7.00# 24 7.3 96 8.6 1 7.00# 23 7.2 102 9.1 0
5 Pad 23 7.3 113 8.6 1 14 Pad 21 7.4 106 8.7 1
.25# 23 7.3 120 8.6 1 0.25#
1.00# 27 7.3 99 8.6 1 1.00# 22 7.3 104 8.7 1
2.00# 27 7.3 103 8.6 1 26 Avg Linear Visc 2.00# 22 7.2 105 8.7 1 22 Avg Linear Visc
3.00# 27 7.3 100 8.6 1 105.9 Avg XLTemp 3.00# 22 7.2 112 8.9 0 107.5 Avg XLTemp
4.00# 31 7.3 105 8.6 1 8.5 Avg XL pH 4.00# 22 7.3 112 8.9 0 8.8 Avg XL pH
4.50# 30 7.3 105 8.5 1 4.50#
5.00# 29 7.3 107 8.4 1 5.00# 22 7.3 105 8.7 0
5.50# 25 7.3 107 8.5 1 5.50#
6.0# 24 7.3 105 8.5 1 6.00# 21 7.3 106 8.8 0
6.5# 24 7.3 104 8.4 1 6.50#
7.0# 23 7.4 103 8.4 1 7.00# 22 7.3 110 8.8 0
6 Pad 27 7.4 102 8.8 1 15 Pad 22 7.3 108 8.8 0
0.25# 20 7.4 113 9.1 1 0.25#
1.00# 20 7.4 96 9 0 1.00# 20 7.3 105 8.8 0
2.00# 21 7.3 96 9 0 23 Avg Linear Visc 2.00# 21 Avg Linear Visc
3.00# 22 7.3 104 9 0 96.0 Avg XLTemp 3.00# 21 7.2 108 8.8 0 108.5 Avg XLTemp
4.00# 24 7.4 90 8.9 0 8.9 Avg XL pH 4.00# 8.8 Avg XL pH
4.50# 24 7.3 96 8.9 0 4.50# 21 7.2 112 8.8 0
5.00# 24 7.3 92 8.9 0 5.00#
5.50# 23 7.3 95 8.8 0 5.50# 20 7.3 110 8.8 0
6.00# 23 7.2 92 8.9 0 6.00#
6.50# 22 7.2 86 9 0 6.50# 20 7.2 108 8.8 0
7.00# 23 7.1 90 8.9 0 7.00#
7 Pad 23 7.3 92 8.7 0 16 Pad 19 7.2 112 8.8 0
0.25# 21 7.3 92 8.7 0 0.25#
1.00# 1.00#
2.00# 22 7.3 90 8.8 0 21 Avg Linear Visc 2.00# 20 7.2 105 8.8 0 20 Avg Linear Visc
3.00# 93.4 Avg XLTemp 3.00# 107.8 Avg XLTemp
4.00# 23 7.3 100 8.8 0 8.8 Avg XL pH 4.00# 20 7.2 100 8.8 0 8.8 Avg XL pH
4.50# 4.50#
5.00# 13 7.2 90 8.7 0 5.00# 20 7.2 112 8.7 0
5.50# 19 7.2 90 8.8 0 5.50#
6.00# 22 7.1 98 8.7 0 6.00# 20 7.2 110 8.7 0
6.50# 24 7.3 95 8.8 0 6.50#
7.0# 7.00# 20 7.2 108 8.7 0
8 Pad 24 7.3 85 8.9 0 17 Pad 19 7.3 120 8.8 0
0.25# 0.25#
1.00# 24 7.3 90 8.9 0 1.00# 19 7.3 110 8.7 0
2.00# 23 Avg Linear Visc 2.00# 19 Avg Linear Visc
3.00# 91.7 Avg XLTemp 3.00# 19 7.3 108 8.7 0 111.0 Avg XLTemp
4.00# 22 7.3 95 8.9 0 8.9 Avg XL pH 4.00# 8.7 Avg XL pH
4.50# 4.50# 19 7.3 110 8.6 0
5.00# 23 7.3 95 8.9 0 5.00#
5.50# 22 7.3 92 8.8 0 5.50# 19 7.3 108 8.7 0
6.00# 22 7.3 95 8.8 0 6.00#
6.50# 21 7.2 90 8.8 0 6.50# 18 7.3 110 8.7 0
7.00# 22 7.2 98 8.8 0 7.00#
Customer:ConocoPhillips Alaska, Inc.
Wellname & #:3S-606
Date:May 19, 2024
Comments Comments
Comments Comments
Comments Comments
Comments Comments
Comments Comments
Comments Comments
Comments Comments
Comments Comments
Comments Comments
Conoco Phillips - 3S-610 Real-Time QC 184
Linear Linear XL XL XL Lip time Linear Linear XL XL XL Lip time
Interval Stage Visc pH Temp °F pH min Interval Stage Visc pH Temp °F pH min
18 Pad 23 7.4 103 8.5 2
0.25# 23 7.3 105 8.8 0 23 Avg Linear Visc
1.00# 109.6 Avg XLTemp
2.00# 23 7.3 112 8.7 0 8.8 Avg XL pH
3.00#
4.00# 23 7.3 108 8.7 0
4.50#
5.00# 22 7.3 112 8.9 0
5.50#
6.00# 22 7.3 115 8.9 0
6.50#
7.00# 22 7.3 112 8.9 0
19 Pad 20 7.2 112 9.2 0
0.25#
1.00# 20 7.4 112 9 0
2.00# 20 Avg Linear Visc
3.00# 22 7.3 118 9 0 114.4 Avg XLTemp
4.00# 9.1 Avg XL pH
4.50# 20 7.3 119 9.2 0
5.00# 20 7.2 110 9.1 0
5.50# 20 7.1 115 9 0
6.00# 20 7.2 117 9.1 0
6.50# 20 7 112 9 0
7.00#
20 Pad 19 7 108 9 0
0.25#
1.00#
2.00# 19 Avg Linear Visc
3.00# 108.0 Avg XLTemp
4.00# 9.0 Avg XL pH
4.50#
5.00#
5.50#
6.00#
6.50#
7.00#
21 Pad 20 7 112 9.1 0
0.25#
1.00#
2.00# 20 Avg Linear Visc
3.00# 112.0 Avg XLTemp
4.00# 9.1 Avg XL pH
4.50#
5.00#
5.50#
6.00#
6.50#
7.00#
Customer:ConocoPhillips Alaska, Inc.
Wellname & #:3S-606
Date:May 19, 2024
Comments Comments
Comments
Comments
Comments
Conoco Phillips - 3S-610 Real-Time QC (2)185
Seq No. Time Activity Code Comment Job Slurry Vol Treating Pressure Treating Pressure @Pump Slurry Rate Tubing Gauge BH Pres1 11:23:22 (05/18/24) Start Job Starting Job 0 0 0 1.6 01 11:23:22 (05/18/24) Next Treatment Treatment Interval 1 0 0 0 1.6 02 11:56:16 Pressure Test ePRV Test - Primary Tubing 20.14 646 663 0 03 11:57:25 Pressure Test ePRV Test - Primary IA 20.14 540 556 0 04 11:59:34 Pressure Test ePRV Test - Secondary Tubing 20.14 750 769 0 05 12:00:50 Pressure Up ePRV Test - Secondary IA 20.14 682 679 0 06 12:01:38 Pressure Test Pressure Test - Locals 20.14 185 175 0 07 12:02:05 Pressure Test Pressure Test - Globals 0 174 176 0 08 12:14:45 Pressure Test Pressure Test - Max 0 9468 9404 0 09 12:22:02 Pressure Test Pressure Test - Pass 0 9404 9334 0 010 13:30:37 Pre-Job Safety Meeting Pre-Job Safety Meeting 0 21 -11 0 011 15:35:15 Open Well Open Well 0 846 822 0 012 15:39:46 Other Arsenal Burst Disk 1.82 5731 5695 0.2 013 15:44:33 Other Shift Sleeve 6.06 5900 5863 1.2 014 17:02:55 Open Well Open Well 149.79 902 873 0 537515 17:15:55 Alarm Delta Stage At Top Perf = 2 330.83 2105 2102 15.8 372316 17:15:56 Alarm Delta Stage At Top Perf = 4 331.1 2105 2101 15.8 372117 17:16:19 Alarm Delta Stage At Top Perf = 5 337.14 2115 2111 15.8 371818 17:19:56 Alarm Delta Stage At Top Perf = 6 407.75 3449 3423 28.9 477919 17:22:17 Alarm Delta Stage At Top Perf = 9 480.78 3422 3396 29.9 484220 17:28:59 Alarm Delta Stage At Top Perf = 10 691.47 3822 3786 31.9 516521 17:43:57 Alarm Delta Stage At Top Perf = 11 1169.58 3704 3670 32 518522 17:43:59 Other Tank Swap 1170.64 3448 3378 31.5 516223 17:57:51 Alarm Delta Stage At Top Perf = 12 1605.17 3601 3563 31.6 515424 18:00:27 Alarm Delta Stage At Top Perf = 13 1687.33 3691 3649 31.7 528825 18:01:11 Other Pinhole in Discharge Manifold 1709.74 3707 3664 31.7 531426 18:03:33 Alarm Delta Stage At Top Perf = 14 1785.65 3881 3849 32.1 539427 18:07:03 Other Finishing Flush with ADP 1897.56 4167 4195 32 543928 18:07:34 NPT Due to HES - Start Pinhole on Dishcarge Manifold 1904.81 750 382 0 277429 18:19:27 NPT Due to HES - End NPT Due to HES - End 1904.81 1046 66 0 298930 18:19:36 Other Resuming Flush 1904.81 1053 1120 0 298931 18:24:04 Alarm Delta Stage At Top Perf = 15 1946.89 4069 4078 24.1 550032 18:29:46 Alarm Delta Stage At Top Perf = 16 2116.4 863 224 7.7 246633 18:29:58 ISIP ISIP 2116.7 1146 216 0 3192Event Log 5-18Conoco Phillips - 3S-610 Event Log 5-18 186
Seq No. Time Activity Code Comment Job Slurry Vol Treating Pressure Treating Pressure @Pump Slurry Rate Tubing Gauge BH Pres1 06:37:48 (05/19/24) Start Job Starting Job 0 0 0 0.7 01 06:37:48 (05/19/24) Next Treatment Treatment Interval 1 0 0 0 0.7 02 7:11:25 NPT Due to HES - Start Leak on Blender Discharge Manifold 4.14 51 0 0 21293 14:58:34 NPT Due to HES - End NPT Due to HES - End 4.14 34 3 0 20674 15:19:42 Prime Pumps Prime Pumps 0 33 15 0 20655 15:41:34 Pressure Test Pressure Test - Globals 0 622 184 0 20646 15:42:15 Pressure Test Pressure Test - Locals 0 621 459 0 20637 15:47:22 Pressure Test Pressure Test - Max 0 9430 9384 0 20638 15:52:49 Pressure Test Pressure Test - Pass 0 9360 9315 0 20639 16:00:25 Pre-Job Safety Meeting Pre-Job Safety Meeting 0 7 12 0 206210 16:37:37 Open Well Open Well 0 1030 1031 0 207511 16:50:54 Start Pad Good Xlink (Stage to pad) 188.91 2483 2458 17.8 408412 16:55:54 Alarm Delta Stage At Top Perf = 9 330.31 3849 3799 31.9 521713 17:02:00 Alarm Delta Stage At Top Perf = 10 525.54 3621 3594 32 499814 17:17:10 Alarm Delta Stage At Top Perf = 11 1007.11 3713 3682 31.6 528515 17:19:31 Alarm Delta Stage At Top Perf = 12 1081.29 3663 3637 31.6 533716 17:22:35 Alarm Delta Stage At Top Perf = 13 1177.58 3640 3614 31.5 534417 17:23:53 Other Design Change - Rate Increase 1218.59 3633 3598 31.6 534518 17:26:16 Alarm Delta Stage At Top Perf = 14 1301.1 4170 4155 36.3 580219 17:30:36 Alarm Delta Stage At Top Perf = 15 1458.63 4209 4169 36.3 586820 17:35:27 Alarm Delta Stage At Top Perf = 16 1634.9 4379 4367 36.3 601721 17:40:27 Start Mix Ball Loaded 1816.32 4493 4468 36.3 610322 17:41:41 Alarm Delta Stage At Top Perf = 17 1861.04 4499 4488 36.2 612323 17:45:30 Other Frozen Proppant 1994.38 4208 4185 33.8 588924 17:47:56 Alarm Delta Stage At Top Perf = 18 2076.59 4253 4255 33.7 593625 17:52:30 Other Shut Bin on Sand 2221.64 3874 3870 31 567926 17:53:29 Alarm Delta Stage At Top Perf = 19 2251.94 3929 3896 31 569827 17:56:05 Drop Ball Launch Ball 2331.04 4163 4110 30.5 57052 17:56:06 (05/19/24) Next Treatment Treatment Interval 2 2331.55 4184 4130 30.5 570528 17:59:12 Alarm Delta Stage At Top Perf = 20 2424.9 4121 4137 30.4 563029 18:04:20 Other Slow for ball 2577.72 3653 3665 29.8 512730 18:06:46 Alarm Delta Stage At Top Perf = 21 2614.77 4948 4941 9.5 627431 18:06:59 Break Formation Break Formation 2616.66 6807 6819 9.4 819032 18:08:37 Start Minifrac Start Minifrac 2623.09 4433 4430 3.2 6093Event Log 5-19Conoco Phillips - 3S-610 Event Log 5-19 187
Seq No. Time Activity Code Comment Job Slurry Vol Treating Pressure Treating Pressure @Pump Slurry Rate Tubing Gauge BH Pres1 08:36:55 (05/20/24) Start Job Starting Job 0 0 0 0 01 08:36:55 (05/20/24) Next Treatment Treatment Interval 1 0 0 0 0 02 9:09:55 Prime Pumps Prime Pumps 0 36 -2 0 21253 9:39:49 Pressure Test Pressure Test - Globals 0 809 162 0 21214 9:40:38 Pressure Test Pressure Test - Locals 0 808 234 0 21215 9:45:36 Pressure Test Pressure Test- Max 0 9434 9404 0 21206 9:50:56 Pressure Test Pressure Test - Pass 0 9367 9313 0 21207 9:53:30 Pre-Job Safety Meeting Pre-Job Safety Meeting 0 20 9 0 21198 10:47:18 Open Well Open Well 0 1070 1060 0 21132 10:48:11 (05/20/24) Next Treatment Treatment Interval 2 0.58 546 584 1.9 23559 10:50:01 Open Well Launch Ball 1.16 423 449 0 217510 11:08:41 Other Slow for ball 264.4 2273 2320 14.9 393511 11:10:39 Ball on Seat Ball on Seat 285.44 1753 1801 9.7 351612 11:11:12 Break Formation Break Formation 290.78 3912 3948 9.7 569613 11:12:25 Other Neutral for Step Rate Test 302.52 3250 3298 9.6 504614 11:14:07 Start Step Rate Start Step Rate 304.77 1163 1263 0 312315 11:19:46 Alarm Delta Stage At Top Perf = 1 323.17 2756 2813 4.9 467116 11:19:57 Alarm Delta Stage At Top Perf = 3 324.07 2779 2834 4.9 468817 11:41:36 Other Pump 458 - Valve Issue 620.86 3622 3670 19.6 523718 11:41:56 Alarm Delta Stage At Top Perf = 4 627.08 3331 3393 17.8 497419 11:43:40 Start Pad Good Xlink (Stage to pad) 658.27 3657 3683 19.5 518720 11:49:13 Alarm Delta Stage At Top Perf = 5 822.04 5287 5319 36.8 669821 11:49:30 Other Pump 458 - Rate Adjusting 831.83 5189 5193 36.6 652822 11:53:59 Alarm Delta Stage At Top Perf = 6 990.58 4738 4738 36 607823 12:07:08 Alarm Delta Stage At Top Perf = 7 1465.13 4398 4408 36.1 578024 12:17:56 Alarm Delta Stage At Top Perf = 8 1853.53 4160 4158 35.9 570725 12:20:28 Alarm Delta Stage At Top Perf = 9 1944.38 4154 4140 35.9 571326 12:23:29 Alarm Delta Stage At Top Perf = 10 2052.48 4184 4163 35.8 577927 12:27:56 Alarm Delta Stage At Top Perf = 11 2211.63 4202 4188 35.8 583428 12:33:36 Alarm Delta Stage At Top Perf = 12 2413.74 4236 4226 35.8 588029 12:39:35 Alarm Delta Stage At Top Perf = 13 2627.72 4329 4316 35.7 597730 12:40:11 Other Pump 621 - Blew Coolant Line 2649.13 4337 4325 35.7 598431 12:46:50 Alarm Delta Stage At Top Perf = 14 2864.4 4401 4410 35.4 608432 12:52:27 Other Load Ball 3063.51 4415 4399 35.5 610233 12:53:43 Alarm Delta Stage At Top Perf = 15 3108.36 4455 4434 35.4 615434 13:01:08 Alarm Delta Stage At Top Perf = 16 3370.81 4681 4677 35.4 637635 13:03:52 Drop Ball Launch Ball 3468.06 4992 4983 35.8 64333 13:03:58 (05/20/24) Next Treatment Treatment Interval 3 3471.65 4997 4987 35.8 643236 13:06:21 Alarm Delta Stage At Top Perf = 17 3548.1 4974 4951 35.9 636537 13:09:13 Other Suspected Debris Through Pumps 3651.07 4421 4367 36.1 576238 13:11:22 Other Slow for Ball 3719.78 3431 3429 30.6 489539 13:11:37 Ball on Seat Ball on Seat 3726.39 1631 1611 18.1 356040 13:12:01 Break Formation Break Formation 3731.34 5242 5251 10.5 654841 13:12:55 Alarm Delta Stage At Top Perf = 18 3740.49 3314 3275 10.1 496342 13:17:34 Alarm Delta Stage At Top Perf = 1 3787.21 3318 3301 10 483843 13:18:27 Other Flushing Well to Fix leak on ePRV 3795.92 3329 3311 10 485744 13:37:36 NPT Due to HES - Start NPT Due to HES - Start 4060.6 1166 963 0 319045 16:14:53 NPT Due to HES - End NPT Due to HES - End 4060.6 0 -5 0 250047 20:17:21 Prime Pumps Prime Pumps 3154.45 453 32 0 254248 20:23:56 Pressure Test Pressure Test 3154.45 498 139 0 252249 20:27:51 Pressure Test Pressure Test - Max 3154.45 9454 9471 0 251150 20:31:26 Pressure Test Pressure Test - Pass 3154.45 9377 9359 0 250151 20:34:47 Other Pumping Gel Downhole 3154.45 628 653 0.1 260452 20:35:14 Alarm Delta Stage At Top Perf = 2 3154.88 784 842 2.2 2795Event Log 5-20Conoco Phillips - 3S-610 Event Log 5-20 188
Seq No. Time Activity Code Comment Job Slurry Vol Treating Pressure Treating Pressure @Pump Slurry Rate Tubing Gauge BH Pres1 06:53:34 (05/21/24) Start Job Starting Job 0 0 0 0 01 06:53:34 (05/21/24) Next Treatment Treatment Interval 1 0 0 0 0 03 07:16:31 (05/21/24) Next Treatment Treatment Interval 3 34.19 405 86 0 21262 7:28:12 Other ePRV - Primary Tubing 34.19 483 486 0 21253 7:29:39 Other ePRV - Primary IA 34.19 482 496 0 21254 7:32:07 Other ePRV - Secondary Tubing 34.19 526 515 0 21255 7:33:59 Other ePRV - Secondary IA 34.19 545 561 0 21256 7:35:06 Pressure Test Pressure Test - Globals 34.19 546 146 0 21257 7:35:53 Pressure Test Pressure Test - Locals 34.19 520 471 0 21248 7:40:02 Pressure Test Pressure Test - Max 34.19 9475 9457 0 21249 7:45:36 Pressure Test Pressure Test - Pass 34.19 9424 9370 0 212410 7:47:42 Pre-Job Safety Meeting Pre-Job Safety Meeting 34.19 89 32 0 212411 8:29:31 Open Well Open Well 34.19 861 853 0 212112 8:31:28 Other Ball Loaded 34.19 381 357 0 213213 8:32:53 Drop Ball Launch Ball 34.19 445 415 0 216614 8:43:27 Start Pad Good Xlink 175.16 2484 2450 15.3 416915 8:49:43 Other Slow for ball 270.96 2418 2387 15.3 400716 8:53:39 Ball on Seat Ball on Seat 311.5 2221 2202 9.7 372017 8:54:06 Break Formation Break Formation 315.69 4259 4199 9.7 577718 8:56:43 Alarm Delta Stage At Top Perf = 1 348.2 4518 4490 19 598819 9:03:15 Alarm Delta Stage At Top Perf = 2 550.66 5362 5320 35.6 662020 9:16:10 Alarm Delta Stage At Top Perf = 3 1025.01 4930 4908 36.8 618621 9:28:02 Alarm Delta Stage At Top Perf = 4 1460.14 4438 4426 36.7 587922 9:30:49 Alarm Delta Stage At Top Perf = 5 1562.2 4228 4220 36.6 572323 9:34:24 Alarm Delta Stage At Top Perf = 6 1693.58 4436 4418 36.7 595724 9:38:51 Alarm Delta Stage At Top Perf = 7 1856.79 4651 4626 36.7 618325 9:44:22 Alarm Delta Stage At Top Perf = 8 2058.82 4836 4805 36.6 634726 9:50:10 Alarm Delta Stage At Top Perf = 9 2270.89 4990 4964 36.6 652527 9:56:37 Alarm Delta Stage At Top Perf = 10 2506.47 5044 5011 36.5 660228 9:59:38 Other Wet Proppant 2616.49 5126 5097 36.5 665229 10:03:18 Alarm Delta Stage At Top Perf = 11 2750.19 5168 5131 36.5 670230 10:03:32 Other Ball Loaded 2758.11 5155 5131 36.5 669831 10:10:27 Alarm Delta Stage At Top Perf = 12 3010.67 5313 5295 36.4 687332 10:11:13 Other Close Bin on Mover 3038.56 5338 5292 36.4 689833 10:14:28 Drop Ball Launch Ball 3157.42 5652 5622 36.6 70064 10:14:29 (05/21/24) Next Treatment Treatment Interval 4 3158.03 5654 5623 36.6 700734 10:15:14 Alarm Delta Stage At Top Perf = 13 3185.5 5724 5706 36.7 702935 10:20:36 Other Slow for Ball 3382.94 4343 4294 37 563036 10:23:41 Alarm Delta Stage At Top Perf = 14 3420.47 2326 2323 10.2 406737 10:24:32 Ball on Seat Ball on Seat 3429.17 2415 2413 10.2 415738 10:25:00 Other Pumps Kicked Out 3433.76 6944 6860 10 888839 10:27:49 Other Bleeding Down Well 3434.84 6930 6906 0 890240 10:32:16 Other Dropped Pump 3438.5 6607 6626 2.8 783841 10:40:58 Other Dropped Pump 3441.63 6790 6737 4.4 758942 10:48:50 Other Pump Kicked Out 3443.73 6988 6917 3.7 733443 12:06:28 Alarm Delta Stage At Top Perf = 1 3465.91 6050 5995 5.7 625744 12:15:13 Other Load Ball 3488.49 1327 1318 0 324345 12:17:41 Drop Ball Launch Ball 3488.49 1239 1233 0 316346 12:55:10 Other Swap to Produced Water 3828.73 1231 1280 0.1 319147 13:01:25 Start Pad Good Xlink (Stage to Pad) 3911.94 2274 2288 14.6 397148 13:08:39 Alarm Delta Stage At Top Perf = 2 4137.75 4192 4172 36.7 547849 13:11:02 Alarm Delta Stage At Top Perf = 3 4225.34 4290 4280 36.7 549150 13:24:01 Alarm Delta Stage At Top Perf = 4 4700.55 4094 4081 36.7 540151 13:34:36 Alarm Delta Stage At Top Perf = 5 5087.17 3932 3919 36.4 539652 13:36:39 Alarm Delta Stage At Top Perf = 6 5161.76 3977 3955 36.3 546653 13:39:19 Alarm Delta Stage At Top Perf = 7 5258.6 4028 4014 36.3 554654 13:43:44 Alarm Delta Stage At Top Perf = 8 5418.95 4118 4098 36.2 565155 13:49:19 Alarm Delta Stage At Top Perf = 9 5621.56 4154 4138 36.3 572856 13:55:13 Alarm Delta Stage At Top Perf = 10 5835.59 4204 4188 36.2 576357 14:01:45 Alarm Delta Stage At Top Perf = 11 6072.61 4224 4212 36.3 579558 14:08:27 Alarm Delta Stage At Top Perf = 12 6315.49 4289 4268 36.2 589059 14:09:40 Other Load Ball 6358.97 4300 4288 36.3 590460 14:15:39 Alarm Delta Stage At Top Perf = 13 6576.28 4417 4405 36.2 601861 14:19:16 Drop Ball Launch Ball 6705.69 4716 4710 36.4 61335 14:19:19 (05/21/24) Next Treatment Treatment Interval 5 6707.5 4730 4718 36.4 613462 14:20:30 Alarm Delta Stage At Top Perf = 14 6751.29 4829 4803 36.6 616263 14:28:43 Alarm Delta Stage At Top Perf = 15 6967.69 2671 2694 10.3 425164 14:28:45 Ball on Seat Ball on Seat 6968.03 2678 2700 10.3 425665 14:29:07 Break Formation Break Formation 6971.78 6311 6255 10.2 789766 14:33:06 Alarm Delta Stage At Top Perf = 1 7007.94 5149 5131 19.4 641867 14:48:18 Alarm Delta Stage At Top Perf = 2 7496.62 5988 5978 35.8 735368 14:58:26 Alarm Delta Stage At Top Perf = 3 7863.35 4526 4522 36.1 597369 15:00:30 Alarm Delta Stage At Top Perf = 4 7938.03 4427 4397 36.2 582270 15:03:11 Alarm Delta Stage At Top Perf = 5 8034.96 4312 4302 36.1 577071 15:07:57 Alarm Delta Stage At Top Perf = 6 8206.34 4346 4320 36 581372 15:13:35 Alarm Delta Stage At Top Perf = 7 8409.37 4252 4235 36.1 578073 15:19:33 Alarm Delta Stage At Top Perf = 8 8624.51 4049 4035 36.1 562574 15:26:05 Alarm Delta Stage At Top Perf = 9 8860.21 3958 3951 36.1 559575 15:32:49 Alarm Delta Stage At Top Perf = 10 9102.8 3821 3813 36 551476 15:39:53 Other Close Gates on Castle 9356.59 4004 4003 36 570377 15:40:15 Alarm Delta Stage At Top Perf = 11 9369.77 4001 3991 35.9 570378 15:42:59 Start Flush Start Flush 9468.53 4076 4084 35.8 566879 15:45:18 Alarm Delta Stage At Top Perf = 12 9552.53 4562 4571 36.3 584080 15:51:06 ISIP ISIP 9754.5 1350 1232 0 341781 15:56:06 Shut-In Pressure @ 5 Minutes Shut-In Pressure @ 5 Minutes 9754.5 225 490 0 306582 16:01:08 Shut-In Pressure @ 10 Minutes Shut-In Pressure @ 10 Minutes 9754.5 212 161 0 300783 16:11:07 Shut-In Pressure @ 15 Minutes Shut-In Pressure @ 15 Minutes 9754.5 18 81 0 2877Event Log 5-21Conoco Phillips - 3S-610 Event Log 5-21 189
Seq No. Time Activity Code Comment Job Slurry Vol Treating Pressure Treating Pressure @Pump Slurry Rate Tubing Gauge BH Pres1 07:52:53 (05/23/24) Start Job Starting Job 0 0 0 1.7 20131 07:52:53 (05/23/24) Next Treatment Treatment Interval 1 0 0 0 1.7 20136 07:53:34 (05/23/24) Next Treatment Treatment Interval 6 1.1 0 -8 1.6 20132 8:06:34 Prime Pumps Prime Pumps 0 0 -8 0 20123 8:31:04 Pressure Test ePRV - Primary Tubing 0 725 691 0 20114 8:33:24 Pressure Test ePRV - Primary IA 0 1310 1162 0 20115 8:34:53 Pressure Test ePRV - Secondary Tubing 0 1342 213 0 20116 8:37:13 Pressure Test ePRV - Secondary IA 0 1542 1103 0 20117 8:39:51 Pressure Test Pressure Test - Global 0 1525 232 0 20118 8:39:57 Pressure Test Pressure Test - Locals 0 1525 244 0 20119 8:41:58 Pressure Test Pressure Test - Max 0 9439 9367 0 201110 8:44:38 Other Begin Bucket Tests 0 9409 9329 0 201111 8:46:57 Pressure Test Pressure Test - Pass 0 9396 9301 0 201212 8:50:31 Pre-Job Safety Meeting Pre-Job Safety Meeting 0 203 190 0 201113 9:13:07 Other Bring on Chems and Mix Gel 0 182 175 0 201114 9:37:39 Other Start Mixing Gel 0 177 171 0 201015 9:56:40 Open Well Open Well 0.16 400 323 0.8 215516 9:57:29 Other Load Ball 6 1.24 390 420 2.4 222317 9:59:26 Other Drop Ball 6 4.46 278 263 1.2 204418 10:14:06 Other Slow Down For Ball 6 220.24 2222 2211 15.3 391319 10:18:50 Alarm Delta Stage At Top Perf = 1 271.99 1788 1782 10.9 356220 10:19:49 Other Ball 6 on Seat 282.56 1787 1780 10.9 355821 10:20:23 Break Formation Break Formation 288.74 7076 7120 10.7 887322 10:20:36 Alarm Delta Stage At Top Perf = 4 290.36 1485 1492 3.8 396423 10:21:44 Alarm Delta Stage At Top Perf = 5 295.16 1693 1735 6 363324 10:33:14 Other Reboot Blender 297.47 259 262 0 222825 10:44:04 Other Step Rate Test - Step 1 307.33 1375 1446 3.1 330626 10:46:05 Other Step Rate Test - Step 2 316.16 1673 1716 4.7 357327 10:47:15 Other Step Rate Test - Step 3 321.97 1690 1730 5.2 360228 10:48:48 Other Step Rate Test - Step 4 330.93 1774 1812 6.1 367129 10:50:17 Other Step Rate Test - Step 5 340.99 1888 1921 7.1 375130 10:51:43 Other Step Rate Test - Step 6 352.07 1987 2019 8.1 382631 10:53:04 Other Step Rate Test - Step 7 363.73 2097 2136 9 391832 10:54:18 Other Step Rate Test - Step 8 375.61 2234 2264 10.1 402833 10:55:49 Other Step Rate Test - Step 9 391.75 2281 2317 11 405134 10:57:13 Other Step Rate Test - Step 10 408.06 2291 2333 11.9 405035 10:58:42 Other Step Rate Test - Step 11 429.06 2702 2755 15 439336 11:08:16 Alarm Delta Stage At Top Perf = 6 588.98 2480 2544 18 417537 11:16:04 Alarm Delta Stage At Top Perf = 7 724.71 2460 2485 17.4 410838 11:39:07 Start Pad Start Pad 1065.01 2468 2465 12.2 418039 11:45:00 Other Produced Water Skid Came Online40 11:47:57 Start Flush Start Flush 1304.3 3485 3483 31.7 472141 11:48:16 Otherut XL - Wedding Ring on Mixer Trouble Shootin1314.64 3373 3344 30.3 460842 11:49:50 Alarm Delta Stage At Top Perf = 8 1361.71 3247 3266 29.2 460343 12:07:14 Other Shut Down for ADP Mixing Bowl 1611.47 1987 2063 13 366044 12:09:22 Other Rebuilding a Gel Tub 1615.17 1109 599 0 304345 12:23:05 Start Pad Start Pad 1737.13 2276 2357 15.1 389846 12:25:11 Alarm Delta Stage At Top Perf = 9 1780.7 4534 4530 30.3 582547 12:28:52 Alarm Delta Stage At Top Perf = 10 1907.25 4489 4542 38.7 564948 12:32:23 Alarm Delta Stage At Top Perf = 11 2032.78 4073 4086 36.1 528649 12:45:19 Alarm Delta Stage At Top Perf = 12 2505.53 3827 3830 36.9 509550 12:55:32 Alarm Delta Stage At Top Perf = 13 2881.13 3669 3644 36.5 510751 12:57:33 Alarm Delta Stage At Top Perf = 14 2954.8 3718 3703 36.5 516552 13:00:09 Alarm Delta Stage At Top Perf = 15 3050 3723 3717 36.7 522753 13:04:29 Alarm Delta Stage At Top Perf = 16 3209.55 3797 3782 36.9 533154 13:09:57 Alarm Delta Stage At Top Perf = 17 3411.39 3819 3791 36.9 536355 13:15:50 Alarm Delta Stage At Top Perf = 18 3628.29 3869 3846 36.8 542756 13:22:17 Alarm Delta Stage At Top Perf = 19 3866.32 3928 3906 36.8 551257 13:26:42 Other Mountain Mover Engine Shut Down 4028.6 3971 3941 36.8 554958 13:28:56 Alarm Delta Stage At Top Perf = 20 4112 4125 4097 36.9 558259 13:29:17 Other Back on the Mountain Mover 4124.29 4158 4118 36.8 560160 13:36:04 Alarm Delta Stage At Top Perf = 21 4374.69 4007 3968 36.8 556861 13:37:42 Other Mover Shut 4434.16 4130 4102 36.8 568262 13:39:39 Other Load Ball 7 4505.99 4196 4163 37.1 573963 13:41:28 Other Drop Ball 7 4573.48 4398 4376 37 577864 13:42:02 (05/23/24) Next Treatment Treatment Interval 7 4594.64 4450 4418 37 575965 13:42:03 Alarm Delta Stage At Top Perf = 22 4595.25 4451 4419 37 576166 13:47:13 Other Slow Down For Ball 7 4784.61 3498 3510 35 487967 13:50:02 Alarm Delta Stage At Top Perf = 23 4818.21 2765 2758 10 416668 13:51:24 Other Ball 7 on Seat 4831.74 2917 2911 10 423269 13:51:39 Break Formation Break Formation 4834.4 5807 5733 10 659870 13:54:37 Alarm Delta Stage At Top Perf = 1 4878.83 3394 3372 27.2 457871 14:07:30 Alarm Delta Stage At Top Perf = 2 5349.65 3427 3407 37 476072 14:18:39 Alarm Delta Stage At Top Perf = 3 5759.89 3383 3355 36.5 488373 14:20:48 Alarm Delta Stage At Top Perf = 4 5838.26 3456 3425 36.4 495774 14:23:27 Alarm Delta Stage At Top Perf = 5 5934.61 3499 3460 36.4 504575 14:27:51 Alarm Delta Stage At Top Perf = 6 6096.53 3602 3556 36.8 518776 14:33:26 Alarm Delta Stage At Top Perf = 7 6302.54 3649 3618 36.8 522877 14:39:14 Alarm Delta Stage At Top Perf = 8 6516.36 3749 3717 36.8 526478 14:45:40 Alarm Delta Stage At Top Perf = 9 6752.31 3826 3797 36.7 540879 14:52:22 Alarm Delta Stage At Top Perf = 10 6998.14 3869 3844 36.7 545980 14:55:16 Other Load Ball 8 7104 3874 3839 36.7 547081 14:58:52 Other Shut Mover Gate 7234.73 3419 3368 34.3 532982 14:59:35 Alarm Delta Stage At Top Perf = 11 7260.99 3960 3931 36.6 554083 15:02:16 Other Drop Ball 8 7359.58 4258 4227 36.9 563184 15:02:17 (05/23/24) Next Treatment Treatment Interval 8 7360.2 4263 4229 36.9 563185 15:04:22 Alarm Delta Stage At Top Perf = 12 7437.6 4358 4318 36.9 565186 15:07:33 Other Slow Down for Ball 8 7554.28 3807 3762 36.8 507687 15:10:57 Alarm Delta Stage At Top Perf = 13 7597.93 2599 2587 10 421088 15:11:59 Ball on Seat Ball 8 on Seat 7608.26 2693 2681 10 426489 15:12:23 Break Formation Break Formation 7612.25 6650 6784 9.9 868490 15:15:33 Alarm Delta Stage At Top Perf = 1 7636.64 3301 3266 20.6 472091 15:28:47 Alarm Delta Stage At Top Perf = 2 8110.42 3464 3429 37 477692 15:39:10 Alarm Delta Stage At Top Perf = 3 8493.26 3236 3215 36.7 477693 15:41:12 Alarm Delta Stage At Top Perf = 4 8567.77 3325 3300 36.5 486094 15:43:50 Alarm Delta Stage At Top Perf = 5 8664.73 3428 3400 36.9 499495 15:48:14 Alarm Delta Stage At Top Perf = 6 8827.45 3521 3501 37 510996 15:53:50 Alarm Delta Stage At Top Perf = 7 9034.22 3607 3585 36.9 521297 15:59:39 Alarm Delta Stage At Top Perf = 8 9249.04 3686 3660 36.9 529998 16:06:06 Alarm Delta Stage At Top Perf = 9 9486.9 3735 3703 36.9 537499 16:12:48 Alarm Delta Stage At Top Perf = 10 9733.86 3814 3776 36.8 5418100 16:19:54 Alarm Delta Stage At Top Perf = 11 9994.15 4042 4009 36.7 5662101 16:21:57 Start Flush Start Flush 10069.66 4097 4074 37.1 5699102 16:24:54 Alarm Delta Stage At Top Perf = 12 10178.75 4420 4395 36.9 5694103 16:29:24 Alarm Delta Stage At Top Perf = 13 10345.33 1000 1030 30.9 4886104 16:29:53 ISIP ISIP 10348.34 1322 1407 0 3245105 16:34:51 Shut-In Pressure @ 5 Minutes Shut-In Pressure @ 5 Minutes 10348.34 26 41 0 3150106 16:39:52 Shut-In Pressure @ 10 Minutes Shut-In Pressure @ 10 Minutes 10348.34 30 124 0 3091107 16:44:54 Shut-In Pressure @ 15 Minutes Shut-In Pressure @ 15 Minutes 10348.34 155 177 0 3043Event Log 5-23Conoco Phillips - 3S-610 Event Log 5-23 190
Seq No. Time Activity Code Comment Job Slurry Vol Treating Pressure Treating Pressure @Pump Slurry Rate Tubing Gauge BH Pres1 08:11:51 (05/24/24) Start Job Starting Job 0 0 0 0 01 08:11:51 (05/24/24) Next Treatment Treatment Interval 1 0 0 0 0 02 8:14:40 Other Troubleshooting Downhole Gauge 5.96 -8 -5 2.1 03 9:40:02 Other Chemical Float Arrived 0 0 -4 0 19774 9:55:23 Other Loop Test 0 -2 -4 0 19765 10:04:25 Prime Pumps Prime Pumps 0 -2 -5 0 19756 10:26:44 Pressure Test ePRV - Primary Tubing 0 0 863 0 19737 10:28:17 Pressure Test ePRV - Primary IA 0 -2 1168 0 19738 10:29:46 Pressure Test ePRV - Secondary Tubing 0 0 1201 0 19729 10:31:03 Pressure Test ePRV - Secondary IA 0 -1 1189 0 197210 10:35:06 Pressure Test Pressure Test - Global 0 1047 748 0 197211 10:35:14 Pressure Test Pressure Test - Locals 0 1047 771 0 197212 10:36:48 Pressure Test Pressure Test - Max 0 9456 9460 0 197213 10:41:48 Pressure Test Pressure Test - Pass 0 9429 9326 0 197114 10:43:28 Pre-Job Safety Meeting Pre-Job Safety Meeting 0 179 129 0 197115 11:00:00 Other Enough Water Loaded to Start Job 0 150 117 0 197016 11:03:01 Other Start Pulling on Chems 0 130 95 0 19699 11:20:51 Other Mixing Gel 0 89 84 0 196817 11:33:44 (05/24/24) Next Treatment Treatment Interval 9 0 88 80 0 196818 11:35:30 Open Well Open Well 0 249 175 0 198719 11:37:55 Drop Ball Drop Ball 9 0.72 267 233 0 199320 11:50:49 Start Pad Start Pad 171.05 2041 2067 15.1 370321 11:52:53 Other Slow Down For Ball 9 202.25 2192 2217 15.1 366122 11:55:44 Ball on Seat Ball 9 on Seat 232.25 2099 2126 9.9 329323 11:56:03 Break Formation Break Formation 235.23 5268 5310 9.9 630824 11:58:14 Other Lynden To Start Pushing Produced Water 266.15 2724 2752 21.8 373225 11:58:18 Alarm Delta Stage At Top Perf = 4 267.63 2743 2773 22.5 374626 11:58:20 Alarm Delta Stage At Top Perf = 5 268.39 2745 2775 22.8 375327 12:03:32 Alarm Delta Stage At Top Perf = 6 438.73 3422 3435 37.2 464328 12:08:32 Alarm Delta Stage At Top Perf = 7 623.95 3371 3384 37 459429 12:19:40 Alarm Delta Stage At Top Perf = 8 1035.03 3232 3256 37 468630 12:21:01 Alarm Delta Stage At Top Perf = 9 1084.94 3221 3259 37 470331 12:22:48 Alarm Delta Stage At Top Perf = 10 1150.82 3262 3276 36.9 472632 12:25:45 Alarm Delta Stage At Top Perf = 11 1259.73 3283 3294 36.9 478533 12:29:25 Alarm Delta Stage At Top Perf = 12 1395.08 3325 3330 37.1 484234 12:33:17 Alarm Delta Stage At Top Perf = 13 1538.45 3334 3328 37 486935 12:37:32 Alarm Delta Stage At Top Perf = 14 1695.57 3316 3300 36.9 487236 12:41:55 Alarm Delta Stage At Top Perf = 15 1857.31 3434 3425 36.9 500037 12:44:00 Other Mover Shut 1934.08 3512 3497 36.8 504710 12:46:42 Alarm Delta Stage At Top Perf = 16 2033.84 3685 3668 37.6 511738 12:46:54 (05/24/24) Next Treatment Treatment Interval 10 2041.35 3722 3712 37.6 511439 12:46:58 Drop Ball Drop Ball 10 2043.86 3737 3719 37.6 511340 12:49:44 Alarm Delta Stage At Top Perf = 17 2146.38 3690 3675 37 500441 12:52:18 Other Slow Down for Ball 2241.43 3146 3112 37.1 446642 12:54:29 Alarm Delta Stage At Top Perf = 18 2268.92 2152 2159 10 370943 12:54:53 Ball on Seat Ball 10 on Seat 2272.76 2192 2199 10 372544 12:55:08 Break Formation Break Formation 2275.27 5071 5059 10 617245 12:57:07 Alarm Delta Stage At Top Perf = 1 2302.51 2801 2795 25.7 415646 13:02:29 Alarm Delta Stage At Top Perf = 2 2494.63 3102 3078 37.2 443847 13:13:34 Alarm Delta Stage At Top Perf = 3 2905.42 2952 2924 37 444948 13:14:56 Alarm Delta Stage At Top Perf = 4 2956.52 2966 2941 36.9 451049 13:16:42 Alarm Delta Stage At Top Perf = 5 3021.16 3030 2995 37 456050 13:19:38 Alarm Delta Stage At Top Perf = 6 3129.8 3100 3056 37 462551 13:23:22 Alarm Delta Stage At Top Perf = 7 3267.86 3106 3088 36.9 467052 13:27:14 Alarm Delta Stage At Top Perf = 8 3410.48 3147 3121 36.9 472053 13:31:34 Alarm Delta Stage At Top Perf = 9 3570.06 3195 3175 36.8 479554 13:35:58 Alarm Delta Stage At Top Perf = 10 3732.61 3261 3237 37 487455 13:38:26 Other Mover Shut 3823.58 3330 3306 36.8 492011 13:40:47 Alarm Delta Stage At Top Perf = 11 3910.26 3433 3405 37.2 498356 13:41:53 (05/24/24) Next Treatment Treatment Interval 11 3951.16 3643 3623 37.1 501557 13:41:53 Drop Ball Drop Ball 11 3951.16 3643 3624 37.1 501558 13:43:54 Alarm Delta Stage At Top Perf = 12 4025.99 3722 3690 37.1 502759 13:46:51 Other Slow Down For Ball 11 4136.09 3210 3180 37.4 447560 13:49:11 Alarm Delta Stage At Top Perf = 13 4167.89 2269 2278 10 374261 13:49:57 Ball on Seat Ball 11 on Seat 4175.59 2368 2378 10 379362 13:50:11 Break Formation Break Formation 4177.93 5232 5207 10 643463 13:52:17 Alarm Delta Stage At Top Perf = 1 4204.65 3496 3504 21 475964 13:57:48 Alarm Delta Stage At Top Perf = 2 4389.67 4538 4523 37.1 586265 14:08:25 Alarm Delta Stage At Top Perf = 3 4782.65 3786 3777 36.8 520766 14:09:47 Alarm Delta Stage At Top Perf = 4 4833.12 3569 3562 37 504467 14:11:31 Alarm Delta Stage At Top Perf = 5 4897.19 3417 3412 36.9 489468 14:14:30 Alarm Delta Stage At Top Perf = 6 5007.26 3348 3341 36.9 484769 14:18:13 Alarm Delta Stage At Top Perf = 7 5144.46 3316 3311 37.1 483670 14:22:08 Alarm Delta Stage At Top Perf = 8 5289.5 3238 3225 37 479871 14:26:29 Alarm Delta Stage At Top Perf = 9 5450.37 3256 3239 36.9 481372 14:30:56 Alarm Delta Stage At Top Perf = 10 5614.71 3250 3236 36.9 484073 14:35:44 Alarm Delta Stage At Top Perf = 11 5792.16 3321 3310 37.1 489112 14:36:21 Drop Ball Drop Ball 12 5814.4 3449 3433 37.1 488874 14:36:22 (05/24/24) Next Treatment Treatment Interval 12 5815.64 3451 3436 37.1 488875 14:38:47 Alarm Delta Stage At Top Perf = 12 5905.37 3490 3473 37.2 482476 14:41:18 Other Slow Down For Ball 5998.95 3081 3080 37.3 440477 14:42:28 Alarm Delta Stage At Top Perf = 13 6018.86 2048 2057 10 366278 14:43:15 Ball on Seat Ball 12 on Seat 6026.71 2149 2165 10 368979 14:43:33 Break Formation Break Formation 6029.55 5836 5818 10 729580 14:45:48 Alarm Delta Stage At Top Perf = 1 6060.06 3037 3019 23.9 434381 14:51:02 Alarm Delta Stage At Top Perf = 2 6243.11 3773 3745 37.1 511882 15:01:34 Alarm Delta Stage At Top Perf = 3 6633.87 3534 3502 37 501083 15:02:55 Alarm Delta Stage At Top Perf = 4 6683.7 3403 3385 36.9 492284 15:04:42 Alarm Delta Stage At Top Perf = 5 6749.43 3236 3220 36.9 477185 15:07:37 Alarm Delta Stage At Top Perf = 6 6857.2 3175 3159 36.9 473686 15:11:19 Alarm Delta Stage At Top Perf = 7 6993.82 3069 3052 36.9 465087 15:15:14 Alarm Delta Stage At Top Perf = 8 7138.21 3051 3048 36.8 464488 15:19:32 Alarm Delta Stage At Top Perf = 9 7297.17 3081 3060 37 465789 15:19:59 Other Sand Drop Due To Bin Swap 7313.19 3098 3074 37 467090 15:23:59 Alarm Delta Stage At Top Perf = 10 7462.22 3125 3121 36.9 469613 15:29:31 Alarm Delta Stage At Top Perf = 11 7666.18 3120 3102 36.8 473091 15:31:23 (05/24/24) Next Treatment Treatment Interval 13 7735.56 3355 3350 37.6 483992 15:31:23 Drop Ball Drop Ball 13 7735.56 3356 3351 37.6 484193 15:32:40 Alarm Delta Stage At Top Perf = 12 7783.84 3436 3419 37.6 482394 15:35:47 Other Slow Down For Ball 13 7901.17 2868 2854 37.7 423695 15:37:23 Alarm Delta Stage At Top Perf = 13 7925.33 1420 1417 10.1 324896 15:37:35 Ball on Seat Ball 13 on Seat 7927.35 1420 1419 10.1 324897 15:37:44 Break Formation Break Formation 7928.69 2894 2912 10.1 470398 15:40:31 Alarm Delta Stage At Top Perf = 1 7972.17 2728 2698 25.5 421899 15:45:42 Alarm Delta Stage At Top Perf = 2 8154.94 3391 3367 36.9 4783100 15:56:22 Alarm Delta Stage At Top Perf = 3 8547.76 3017 3012 36.4 4440101 15:57:43 Alarm Delta Stage At Top Perf = 4 8597 3126 3118 36.8 4537102 15:59:28 Alarm Delta Stage At Top Perf = 5 8661.79 3135 3116 37 4567103 16:02:26 Alarm Delta Stage At Top Perf = 6 8771.57 3172 3152 37 4606104 16:06:10 Alarm Delta Stage At Top Perf = 7 8909.69 3138 3120 37 4647105 16:10:03 Alarm Delta Stage At Top Perf = 8 9053.02 3078 3056 36.9 4609106 16:14:21 Alarm Delta Stage At Top Perf = 9 9211.48 3105 3095 36.8 4642107 16:18:48 Alarm Delta Stage At Top Perf = 10 9375 3168 3154 37.1 4710108 16:23:07 Other Screws Clean and Cut 9535.27 3241 3228 37.8 4783109 16:23:29 Alarm Delta Stage At Top Perf = 11 9549.12 3195 3190 37.8 4744110 16:26:47 Alarm Delta Stage At Top Perf = 12 9672.02 3514 3500 37.1 4715111 16:29:52 Alarm Delta Stage At Top Perf = 13 9786.47 1891 2234 37.1 4317112 16:30:03 ISIP ISIP 9790.33 1459 1555 10.4 3182113 16:35:04 Shut-In Pressure @ 5 Minutes Shut-In Pressure @ 5 Minutes 9790.33 13 32 0 2989114 16:40:04 Shut-In Pressure @ 10 Minutes Shut-In Pressure @ 10 Minutes 9790.33 38 58 0 2934115 16:45:02 Shut-In Pressure @ 15 Minutes Shut-In Pressure @ 15 Minutes 9790.33 25 69 0 2762Event Log 5-24Conoco Phillips - 3S-610 Event Log 5-24 191
Seq No. Time Activity Code Comment Job Slurry Vol Treating Pressure Treating Pressure @Pump Slurry Rate Tubing Gauge BH Pres1 07:45:45 (05/25/24) Start Job Starting Job 0 0 0 0 01 07:45:45 (05/25/24) Next Treatment Treatment Interval 1 0 0 0 0 02 7:49:54 Other Fire Up Equipment 0 1 70 0 18383 9:12:47 Other Loop Test 0 -4 65 0 18324 9:16:06 Prime Pumps Prime Pumps 0 -5 159 0 18315 9:34:39 Pressure Test ePRV - Primary Tubing 0 1149 1181 0 18306 9:36:09 Pressure Test ePRV - Primary IA 0 1056 1168 0 18307 9:37:37 Pressure Test ePRV - Secondary Tubing 0 1115 1250 0 18308 9:39:20 Pressure Test ePRV - Secondary IA 0 1172 1099 0 18309 9:44:58 Pressure Test Pressure Test - Global 0 1163 517 0 183010 9:45:05 Pressure Test Pressure Test - Locals 0 1163 516 0 183011 9:47:03 Pressure Test Pressure Test - Max 0 9509 9534 0 183012 9:52:03 Pressure Test Pressure Test - Pass 0 9447 9405 0 182913 9:54:22 Pre-Job Safety Meeting Pre-Job Safety Meeting 0 97 136 0 182914 9:58:47 Other Pull on Chemicals 0 76 121 0 182915 10:00:00 Other Received Enough Water To Start Job 0 79 129 0 182816 10:39:17 (05/25/24) Next Treatment Treatment Interval 14 0 104 151 0 182717 10:45:05 Other Load Ball 14 0 101 149 0 182618 10:47:04 Open Well Open Well 0.01 114 135 0.2 186619 10:48:53 Drop Ball Drop Ball 14 1.25 84 134 0.3 184720 11:01:30 Other Slow Down For Ball 14 162.74 1023 1121 14.8 269021 11:08:05 Alarm Delta Stage At Top Perf = 5 232.65 960 1039 14.7 262822 11:09:21 Alarm Delta Stage At Top Perf = 4 251.48 982 1072 15 263923 11:09:50 Other Shut Down To Possibly Free Ball 257.84 254 351 7.5 221824 11:15:04 Other Drop Ball 14v2 333.34 1041 1167 15 270225 11:25:35 Other Slow Down for Ball 14 492.35 1124 1248 15.1 277926 11:28:59 Ball on Seat Ball 14 on Seat 528.89 802 914 9.9 255527 11:29:09 Break Formation Break Formation 530.54 1895 1991 9.9 381228 11:33:29 Other Step Rate Test - Step 1 544.95 932 1054 1.1 287029 11:34:49 Other Step Rate Test - Step 2 547.21 981 1098 2 290530 11:36:03 Other Step Rate Test - Step 3 550.59 1017 1132 3.1 293331 11:37:29 Other Step Rate Test - Step 4 556.09 1075 1188 4.2 297732 11:38:42 Other Step Rate Test - Step 5 562.05 1124 1236 5.1 300033 11:39:55 Other Step Rate Test - Step 6 569.06 1175 1289 6 302134 11:41:22 Other Step Rate Test - Step 7 578.76 1222 1336 7 304135 11:42:35 Other Step Rate Test - Step 8 588.12 1269 1383 8.1 307136 11:43:52 Other Step Rate Test - Step 9 599.21 1315 1431 9 310437 11:45:23 Other Step Rate Test - Step 10 613.86 1362 1483 10 313138 11:46:37 Other Step Rate Test - Step 11 626.95 1408 1536 11 316539 11:47:37 Other Step Rate Test - Step 12 638.6 1451 1578 11.9 319040 11:53:25 Other Start Pad 724.58 1561 1687 15 326541 11:55:19 Alarm Delta Stage At Top Perf = 6 773.55 2675 2792 33.7 404742 11:57:55 Alarm Delta Stage At Top Perf = 7 867.26 2488 2620 34.7 389643 11:58:19 Other Debris in Pumps 880.57 2433 2591 33.8 385744 12:00:23 Alarm Delta Stage At Top Perf = 8 953.39 2752 2836 36.8 403545 12:01:02 Alarm Delta Stage At Top Perf = 9 977.42 2775 2849 37 405046 12:11:28 Alarm Delta Stage At Top Perf = 10 1362.36 2610 2683 36.9 411347 12:12:24 Alarm Delta Stage At Top Perf = 11 1396.86 2631 2707 37 415748 12:13:36 Alarm Delta Stage At Top Perf = 12 1441.26 2640 2721 37 418449 12:15:38 Alarm Delta Stage At Top Perf = 13 1516.42 2667 2732 37 421950 12:18:15 Alarm Delta Stage At Top Perf = 14 1613.13 2659 2734 36.9 422051 12:20:59 Alarm Delta Stage At Top Perf = 15 1713.9 2681 2742 36.9 424452 12:23:58 Alarm Delta Stage At Top Perf = 16 1824.09 2710 2774 36.9 428115 12:27:04 Alarm Delta Stage At Top Perf = 17 1938.4 2773 2838 36.8 434153 12:30:21 Alarm Delta Stage At Top Perf = 18 2060.15 2914 2983 37.5 440854 12:30:34 (05/25/24) Next Treatment Treatment Interval 15 2068.25 2981 3040 37.3 441555 12:30:34 Drop Ball Drop Ball 15 2068.25 2981 3041 37.3 441556 12:32:28 Alarm Delta Stage At Top Perf = 19 2138.64 3063 3123 36.9 442857 12:34:46 Other Slow Down For Ball 15 2223.85 2750 2833 37.2 407458 12:36:55 Alarm Delta Stage At Top Perf = 20 2253.23 2112 2193 9.9 356559 12:37:42 Ball on Seat Ball 15 on Seat 2261.01 2184 2266 10 359060 12:38:07 Break Formation Break Formation 2265.16 7085 7071 9.9 872161 12:42:08 Alarm Delta Stage At Top Perf = 1 2289.67 5592 5629 11.4 698262 12:43:56 Alarm Delta Stage At Top Perf = 2 2313.31 5687 5694 16.4 695763 12:55:46 Alarm Delta Stage At Top Perf = 3 2704.42 3266 3309 37 478564 12:56:43 Alarm Delta Stage At Top Perf = 4 2739.54 3039 3082 37 456665 12:57:57 Alarm Delta Stage At Top Perf = 5 2785.1 2816 2863 36.9 436166 13:00:00 Alarm Delta Stage At Top Perf = 6 2860.77 2740 2784 36.9 431667 13:02:32 Alarm Delta Stage At Top Perf = 7 2954.31 2645 2703 36.9 425068 13:05:15 Alarm Delta Stage At Top Perf = 8 3054.6 2604 2655 36.9 424669 13:07:07 Other Load Ball 16 3123.45 2624 2669 36.9 424416 13:08:15 Alarm Delta Stage At Top Perf = 9 3165.25 2644 2692 36.9 426370 13:11:23 Alarm Delta Stage At Top Perf = 10 3280.75 2660 2701 36.9 429871 13:14:26 (05/25/24) Next Treatment Treatment Interval 16 3393.88 2852 2874 37.3 431172 13:14:27 Drop Ball Drop Ball 16 3394.5 2885 2921 37.3 431173 13:14:29 Alarm Delta Stage At Top Perf = 11 3395.74 2931 2974 37.3 436574 13:16:50 Alarm Delta Stage At Top Perf = 12 3483.18 2946 2989 37.3 431475 13:18:26 Other Slow Down For Ball 16 3542.81 2688 2731 37.2 403876 13:20:52 Alarm Delta Stage At Top Perf = 13 3573.91 1943 2003 10 341977 13:21:00 Ball on Seat Ball 16 on Seat 3575.25 1954 2014 10 342078 13:21:13 Break Formation Break Formation 3577.26 4984 4984 10 605279 13:23:26 Alarm Delta Stage At Top Perf = 1 3607.64 2462 2516 23.9 378980 13:24:29 Alarm Delta Stage At Top Perf = 2 3637.81 2861 2902 31.5 411881 13:34:54 Alarm Delta Stage At Top Perf = 3 4021.28 2766 2812 36.8 433082 13:35:49 Alarm Delta Stage At Top Perf = 4 4055.06 2759 2799 36.8 435983 13:37:07 Alarm Delta Stage At Top Perf = 5 4103.15 2697 2741 37.1 431084 13:39:08 Alarm Delta Stage At Top Perf = 6 4177.86 2587 2633 37 420785 13:41:43 Alarm Delta Stage At Top Perf = 7 4273.38 2510 2552 37 414186 13:44:27 Alarm Delta Stage At Top Perf = 8 4374.38 2496 2539 36.9 413217 13:47:27 Alarm Delta Stage At Top Perf = 9 4485.03 2480 2517 36.8 413487 13:50:32 Alarm Delta Stage At Top Perf = 10 4598.68 2508 2551 36.8 417188 13:53:47 (05/25/24) Next Treatment Treatment Interval 17 4718.55 2697 2748 37.3 415189 13:53:47 Drop Ball Drop Ball 17 4718.55 2698 2748 37.3 415190 13:53:47 Alarm Delta Stage At Top Perf = 11 4719.17 2724 2775 37.2 415291 13:55:59 Alarm Delta Stage At Top Perf = 12 4800.99 2782 2818 37.2 416992 13:57:28 Other Slow Down For Ball 17 4855.62 2563 2586 37.3 391393 14:00:06 Alarm Delta Stage At Top Perf = 13 4890.25 1728 1784 10.1 325094 14:00:15 Ball on Seat Ball 17 on Seat 4891.6 1739 1796 10.1 325895 14:00:31 Break Formation Break Formation 4894.29 3991 3944 10 561296 14:02:55 Alarm Delta Stage At Top Perf = 1 4923.12 3256 3289 18.9 468797 14:04:03 Alarm Delta Stage At Top Perf = 2 4948.46 4205 4222 26.4 563598 14:14:44 Alarm Delta Stage At Top Perf = 3 5335.21 2860 2896 37 443799 14:15:42 Alarm Delta Stage At Top Perf = 4 5370.92 2567 2620 37 4187100 14:16:55 Alarm Delta Stage At Top Perf = 5 5415.9 2403 2441 37 4036101 14:18:57 Alarm Delta Stage At Top Perf = 6 5491.04 2259 2294 36.9 3899102 14:21:32 Alarm Delta Stage At Top Perf = 7 5586.46 2201 2248 37 3848103 14:24:17 Alarm Delta Stage At Top Perf = 8 5687.95 2202 2247 37 3848104 14:27:17 Alarm Delta Stage At Top Perf = 9 5798.71 2235 2263 37 3877105 14:30:23 Alarm Delta Stage At Top Perf = 10 5913.4 2267 2315 37 3920106 14:33:42 Alarm Delta Stage At Top Perf = 11 6036.56 2331 2371 37.3 3872107 14:36:02 Alarm Delta Stage At Top Perf = 12 6123.5 2601 2650 37.2 3874108 14:38:37 Alarm Delta Stage At Top Perf = 13 6219.5 2290 2335 37.1 3573109 14:38:47 ISIP ISIP 6223.86 986 1069 20 2914110 14:43:45 Shut-In Pressure @ 5 Minutes Shut-In Pressure @ 5 Minutes 6225.87 -14 43 0 2773111 14:48:44 Shut-In Pressure @ 10 Minutes Shut-In Pressure @ 10 Minutes 6225.87 -15 49 0 2704112 14:53:43 Shut-In Pressure @ 15 Minutes Shut-In Pressure @ 15 Minutes 6225.87 161 151 0 2629Event Log 5-25Conoco Phillips - 3S-610 Event Log 5-25 192
Seq No. Time Activity Code Comment Job Slurry Vol Treating Pressure Treating Pressure @Pump Slurry Rate Tubing Gauge BH Pres1 06:52:23 (05/26/24) Start Job Starting Job 0 0 0 0 01 06:52:23 (05/26/24) Next Treatment Treatment Interval 1 0 0 0 0 018 06:52:55 (05/26/24) Next Treatment Treatment Interval 18 0 19 40 0 02 7:30:19 Other Loop Test Complete 111.93 24 102 45.7 18233 7:32:26 Prime Pumps Prime Pumps 128.18 23 103 1.9 18234 7:57:40 Pressure Test ePRV - Primary Tubing 0 1097 1197 0 18195 7:59:47 Pressure Test ePRV - Primary IA 0 1113 1212 0 18186 8:01:12 Pressure Test ePRV - Secondary Tubing 0 1224 281 0 18187 8:02:33 Other Pressure From Acid Pump Pressure Test 0 2299 253 0 18178 8:05:12 Pressure Test ePRV - Secondary IA 0 1042 1178 0 18169 8:07:38 Pressure Test Pressure Test - Locals 0 1012 389 0 182010 8:07:47 Pressure Test Pressure Test - Global 0 1011 836 0 182011 8:11:07 Pressure Test Pressure Test - Max 0 9470 9452 0 182312 8:11:53 Other Pump 453 Packing Leaking 0 9260 9177 0 182313 8:12:07 Other Leak Observed Around WH 0 9171 9089 0 182314 8:43:53 Pressure Test Pressure Test - Locals 0 831 869 0 182415 8:44:11 Pressure Test Pressure Test - Global 0 831 865 0 182416 8:47:49 Pressure Test Pressure Test - Max 0 9523 9521 0 182317 8:52:50 Pressure Test Pressure Test - Pass 0 9453 9411 0 182418 8:54:46 Pre-Job Safety Meeting Pre-Job Safety Meeting 0 112 155 0 182419 9:21:05 Other Load Chemicals 0 105 165 0 182320 9:40:52 Other Load Ball 18 0 87 153 0 182521 9:42:22 Open Well Open Well 0.02 140 174 0.5 185422 9:43:21 Drop Ball Drop Ball 18 0.94 98 153 0.4 182523 9:46:04 Alarm Delta Stage At Top Perf = 1 32.71 1009 1070 14.9 243624 9:52:44 Other Slow Down For Ball 18 131.84 897 963 14.9 256025 9:55:13 Ball on Seat Ball 18 on Seat 158.23 515 595 10 227026 9:55:25 Break Formation Break Formation 160.22 1813 1966 10 360627 9:55:34 Other Start DFIT 161.71 1621 1717 10 331528 9:59:07 Alarm Delta Stage At Top Perf = 4 196.92 1579 1714 9.9 335429 9:59:14 Alarm Delta Stage At Top Perf = 5 198.08 1586 1716 9.9 336730 10:00:08 ISIP ISIP 206.26 755 773 2.2 269231 10:05:03 Shut-In Pressure @ 5 Minutes Shut-In Pressure @ 5 Minutes 206.33 79 145 0 230432 10:09:58 Shut-In Pressure @ 10 Minutes Shut-In Pressure @ 10 Minutes 206.33 76 145 0 211033 10:20:37 Other Pre-Load Adjustment 252.41 1320 1420 12.8 303134 10:28:15 Alarm Delta Stage At Top Perf = 9 403.55 2296 2404 34.2 353635 10:28:46 Other Debris in Pumps 421.36 2073 2139 33.7 331736 10:31:26 Alarm Delta Stage At Top Perf = 10 515.66 2379 2467 37.2 360437 10:32:03 Alarm Delta Stage At Top Perf = 11 538.65 2381 2461 37.3 359438 10:42:29 Alarm Delta Stage At Top Perf = 12 926.1 2271 2340 36.9 365339 10:43:25 Alarm Delta Stage At Top Perf = 13 960.54 2222 2290 36.9 364940 10:44:38 Alarm Delta Stage At Top Perf = 14 1005.38 2210 2268 36.8 365141 10:46:40 Alarm Delta Stage At Top Perf = 15 1080.21 2160 2228 36.8 363942 10:49:15 Alarm Delta Stage At Top Perf = 16 1175.06 2133 2191 36.7 364443 10:51:58 Alarm Delta Stage At Top Perf = 17 1274.67 2107 2168 36.7 364944 10:54:28 Other Ball 19 Loaded 1365.59 2120 2167 36.6 366645 10:54:59 Alarm Delta Stage At Top Perf = 18 1385.09 2121 2160 36.6 367446 10:58:08 Alarm Delta Stage At Top Perf = 19 1500.41 2150 2207 36.8 371247 11:01:27 Alarm Delta Stage At Top Perf = 20 1623.43 2193 2238 37.7 376548 11:02:18 Drop Ball Drop Ball 19 1654.87 2314 2342 37.5 372319 11:02:18 (05/26/24) Next Treatment Treatment Interval 19 1655.49 2314 2342 37.5 372349 11:03:48 Alarm Delta Stage At Top Perf = 21 1711 2446 2549 36.8 376650 11:05:41 Other Slow Down For Ball 19 1779.91 2301 2436 37.2 359651 11:08:02 Alarm Delta Stage At Top Perf = 22 1811.31 1381 1496 10 318152 11:08:33 Ball on Seat Ball 19 on Seat 1816.3 1390 1500 10 317053 11:08:52 Break Formation Break Formation 1819.45 2283 2262 9.9 523854 11:10:55 Alarm Delta Stage At Top Perf = 1 1844.83 2483 2551 21.4 398355 11:12:33 Alarm Delta Stage At Top Perf = 2 1894.15 4074 4119 34.8 539556 11:23:12 Alarm Delta Stage At Top Perf = 3 2280.34 3051 3102 36.8 450357 11:24:09 Alarm Delta Stage At Top Perf = 4 2315.28 2793 2859 36.8 427858 11:25:26 Alarm Delta Stage At Top Perf = 5 2362.52 2606 2668 36.8 411359 11:27:29 Alarm Delta Stage At Top Perf = 6 2437.92 2491 2543 36.7 400460 11:30:03 Alarm Delta Stage At Top Perf = 7 2532.45 2276 2340 36.9 381761 11:32:45 Alarm Delta Stage At Top Perf = 8 2632.03 2233 2289 36.9 376962 11:33:58 Other Load Ball 20 2676.24 2206 2259 36.8 374163 11:35:45 Alarm Delta Stage At Top Perf = 9 2742.51 2138 2188 36.8 371464 11:38:50 Alarm Delta Stage At Top Perf = 10 2856.02 2124 2175 36.8 370565 11:42:12 Alarm Delta Stage At Top Perf = 11 2980.05 2106 2165 37.3 370066 11:43:01 Other Potential Drop Ball 20 3009.89 2160 2207 37.2 368320 11:43:01 (05/26/24) Next Treatment Treatment Interval 20 3009.89 2161 2208 37.2 368167 11:43:41 Drop Ball Drop Ball 3034.7 2430 2475 37.3 370368 11:44:18 Alarm Delta Stage At Top Perf = 12 3058.33 2434 2472 37.4 372069 11:46:11 Other Slow Down For Ball 20 3128.04 2301 2338 37.3 358370 11:48:18 Alarm Delta Stage At Top Perf = 13 3157.86 1734 1796 10 316271 11:51:41 Alarm Delta Stage At Top Perf = 1 3191.54 1881 1938 10 321172 11:56:42 Alarm Delta Stage At Top Perf = 2 3241.86 1933 1985 10 326073 11:56:56 Other Pressure Up on Acid Pumper 3244.2 1940 1993 10 325774 12:02:17 Other Shut Down to Load Ball 20v2 3297.55 1923 1962 9.9 331575 12:05:29 Other Drop Ball 20 v2 3299.47 1374 1446 0 280276 12:13:59 Other Slow Down For Ball 20v2 3415.88 1251 1276 15 309977 12:14:04 Alarm Delta Stage At Top Perf = 3 3417.02 1207 1253 12.9 291778 12:16:38 Alarm Delta Stage At Top Perf = 4 3443.12 1279 1321 10 290379 12:20:17 Alarm Delta Stage At Top Perf = 5 3481.59 1484 1531 14.7 294580 12:23:06 Other Acid Pumper Online 3523.57 1617 1674 14.8 300081 12:26:06 Alarm Delta Stage At Top Perf = 6 3568.1 1579 1607 14.8 303482 12:35:29 Other Shut Down and Wait For a Thrid Ball 20 3694.44 540 527 0 252283 14:20:05 Other Ball Received From CoP 3694.44 55 114 0 185884 14:33:02 Other Ball 20 v3 Loaded 3694.44 55 114 0 184585 14:35:12 Open Well Open Well 3694.44 258 323 0 184486 14:36:44 Alarm Delta Stage At Top Perf = 7 3697.93 77 170 4.2 194287 14:37:09 Other Launch Ball 20v3 3699.65 73 170 4.1 194688 14:45:54 Other Slow Down for Ball 20v3 3814.72 652 770 15.2 237189 14:51:43 Alarm Delta Stage At Top Perf = 8 3875.71 871 964 13.9 231590 14:51:50 Alarm Delta Stage At Top Perf = 9 3877.37 872 960 14.5 233091 14:52:12 Alarm Delta Stage At Top Perf = 10 3882.79 883 975 14.9 232992 14:54:22 Other Load Ball 21 3915.32 998 1091 15 238693 14:55:36 Drop Ball Drop Ball 21 3933.84 1101 1197 15 246421 14:55:38 (05/26/24) Next Treatment Treatment Interval 21 3934.09 1111 1205 15 246294 15:01:27 Alarm Delta Stage At Top Perf = 11 4021.26 1514 1592 14.9 280895 15:02:51 Other Slow Down For Ball 21 4041.9 1292 1326 14.7 287496 15:09:00 Alarm Delta Stage At Top Perf = 1 4106.68 1709 1808 14.8 299897 15:10:35 Alarm Delta Stage At Top Perf = 2 4130.37 1676 1772 15 303698 15:22:28 ISIP ISIP 4305.63 659 728 5.5 252199 15:27:32 Shut-In Pressure @ 5 Minutes Shut-In Pressure @ 5 Minutes 4305.88 0 175 0 2246100 15:32:30 Shut-In Pressure @ 10 Minutes Shut-In Pressure @ 10 Minutes 4305.88 426 616 0 2123101 15:37:27 Shut-In Pressure @ 15 Minutes Shut-In Pressure @ 15 Minutes 4305.88 42 194 0 2054Event Log 5-26Conoco Phillips - 3S-610 Event Log 5-26 193
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Break Test2.0091 9.20 1.0091 9.20 1.00 2.00 0.25 0.85 4.002.00 0.85 4.000.85 2.002.0091 9.20 1.00 2.00 2.00Temp 0FPH LOSURF-300D CL-28M CAT-3 MO-67 Optiflo-III OptiFlo-IID. martinezHydration Visc: 31 63All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH: 6.80Torok Hydration pH: 7.303S-610 Stage(s): Break Test140 Water Source: CPF3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date: 5/18/2024ConocoPhillips Project No:020040060080010001200140016001800200000:00 02:00 04:00 10:00 20:00 30:00 1:00 30:00 00:00 30:00 00:00Viscosity (cp)Time (min:sec)Prejob Crosslink Break TestsOpti III @ 2.0 & Opti II @ 2.0Opti III @ 2.0 & Opti II @ 2.0Opti III @ 4.0 & Opti II @ 2.0 w/CAT3Fluid is broken at 200cpConoco Phillips - 3S-610 Prejob Break Test Day 1 194
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini FracPAD1 ppg 2 ppg3 ppg4 ppg3S-610 Stage(s): 1140 Water Source: CPF 3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date: 5/18/2024ConocoPhillips Project No:D. MartinezHydration Visc: 25 80All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:Narwhal Hydration pH:Temp 0FPH LOSURF-300D CL-28M MO-67 Optiflo II Optiflo III2.00 0.85 2.00 2.0067 8.50 1.000200400600800100012001400160000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 1 Crosslink TestsMini Frac0.5 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-610 Fann 15 min Zone 1 195
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini FracPad2 ppg3 ppg4 ppg5 ppg3S-610 Stage(s): 1B140 Water Source: CPF 3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date: 5/19/2024ConocoPhillips Project No:D. MartinezHydration Visc: 25 80All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:Narwhal Hydration pH:Temp 0FPH LOSURF-300D CL-28 Cat3 MO-67 Optiflo II Optiflo III2.00 0.85 2.00 2.0090 8.80 1.0090 8.80 1.00 2.00 0.85 2.00 2.00020040060080010001200140016001800200000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 1B Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-610 Zone 1B 196
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini FracPad2 ppg3 ppg4 ppg5 ppg3S-610 Stage(s): 2140 Water Source: CPF 3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date: 5/20/2024ConocoPhillips Project No:D. MartinezHydration Visc: 25 80All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:Narwhal Hydration pH:Temp 0FPH LOSURF-300D CL-28 Cat3 MO-67 Optiflo II Optiflo III2.00 0.85 2.00 2.0090 8.80 1.0090 8.80 1.00 2.00 0.85 2.00 2.0002004006008001000120014001600180000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 2 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-610 Zone 2 197
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini FracPad2 ppg3 ppg4 ppg5 ppg3S-610 Stage(s): 3140 Water Source: CPF 3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date: 5/21/2024ConocoPhillips Project No:D. MartinezHydration Visc: 25 80All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:Narwhal Hydration pH:Temp 0FPH LOSURF-300D CL-28 Cat3 MO-67 Optiflo II Optiflo III2.00 0.85 2.00 2.0090 8.80 1.0090 8.80 1.00 2.00 0.85 2.00 2.000200400600800100012001400160000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 3 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-610 Zone 3 198
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini FracPad2 ppg3 ppg4 ppg5 ppg3S-610 Stage(s): 4140 Water Source: CPF 3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date: 5/21/2024ConocoPhillips Project No:D. MartinezHydration Visc: 25 80All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:Narwhal Hydration pH:Temp 0FPH LOSURF-300D CL-28 Cat3 MO-67 Optiflo II Optiflo III2.00 0.85 2.00 2.0090 8.80 1.0090 8.80 1.00 2.00 0.85 2.00 2.000200400600800100012001400160000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 4 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-610 Zone 4 199
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini FracPad2 ppg3 ppg4 ppg5 ppg3S-610 Stage(s): 5140 Water Source: CPF 3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date: 5/21/2024ConocoPhillips Project No:D. MartinezHydration Visc: 25 80All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:Narwhal Hydration pH:Temp 0FPH LOSURF-300D CL-28 Cat3 MO-67 Optiflo II Optiflo III2.00 0.85 2.00 2.0090 8.80 1.0090 8.80 1.00 2.00 0.85 2.00 2.000200400600800100012001400160000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 5 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-610 Zone 5 200
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini FracPad2 ppg3 ppg4 ppg5 ppg3S-610 Stage(s): 6140 Water Source: CPF 3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date: 5/23/2024ConocoPhillips Project No:E BRITTONHydration Visc: 25 80All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:Narwhal Hydration pH:Temp 0FPH LOSURF-300D CL-28 BA-20 MO-67 Optiflo II Optiflo III2.00 0.33 0.85 2.00 2.0090 8.80 1.0090 8.80 1.00 2.00 0.33 0.85 2.00 2.000500100015002000250000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 6 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-610 Zone 6 201
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini FracPad2 ppg3 ppg4 ppg5 ppg3S-610 Stage(s): 8140 Water Source: CPF 3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date: 5/23/2024ConocoPhillips Project No:E BRITTONHydration Visc: 25 80All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:Narwhal Hydration pH:Temp 0FPH LOSURF-300D CL-28 BA-20 MO-67 Optiflo II Optiflo III2.00 0.33 0.85 2.00 2.0090 8.80 1.0090 8.80 1.00 2.00 0.33 0.85 2.00 2.000500100015002000250000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 8 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-610 Zone 8 202
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini FracPad2 ppg3 ppg4 ppg5 ppg3S-610 Stage(s): 9140 Water Source: CPF 3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date: 5/24/2024ConocoPhillips Project No:E BRITTONHydration Visc: 25 80All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:Narwhal Hydration pH:Temp 0FPH LOSURF-300D CL-28 BA-20 MO-67 Optiflo II Optiflo III2.00 0.33 0.85 2.00 2.0090 8.80 1.0090 8.80 1.00 2.00 0.33 0.85 2.00 2.000200400600800100012001400160000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 9 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-610 Zone 9 203
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini FracPad2 ppg3 ppg4 ppg5 ppg3S-610 Stage(s): 10140 Water Source: CPF 3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date: 5/24/2024ConocoPhillips Project No:E BRITTONHydration Visc: 25 80All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:Narwhal Hydration pH:Temp 0FPH LOSURF-300D CL-28 BA-20 MO-67 Optiflo II Optiflo III2.00 0.33 0.85 2.00 2.0090 8.80 1.0090 8.80 1.00 2.00 0.33 0.85 2.00 2.000500100015002000250000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 10 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-610 Zone 10 204
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini FracPad2 ppg3 ppg4 ppg5 ppg3S-610 Stage(s): 11140 Water Source: CPF 3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date: 5/24/2024ConocoPhillips Project No:E BRITTONHydration Visc: 25 80All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:Narwhal Hydration pH:Temp 0FPH LOSURF-300D CL-28 BA-20 MO-67 Optiflo II Optiflo III2.00 0.33 0.85 2.00 2.0090 8.80 1.0090 8.80 1.00 2.00 0.33 0.85 2.00 2.0005001000150020002500300000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 11 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-610 Zone 11 205
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini FracPad2 ppg3 ppg4 ppg5 ppg3S-610 Stage(s): 12140 Water Source: CPF 3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date: 5/24/2024ConocoPhillips Project No:E BRITTONHydration Visc: 25 80All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:Narwhal Hydration pH:Temp 0FPH LOSURF-300D CL-28 BA-20 MO-67 Optiflo II Optiflo III2.00 0.33 0.85 2.00 2.0090 8.80 1.0090 8.80 1.00 2.00 0.33 0.85 2.00 2.000500100015002000250000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 12 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-610 Zone 12 206
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini FracPad2 ppg3 ppg4 ppg5 ppg3S-610 Stage(s): 13140 Water Source: CPF 3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date: 5/24/2024ConocoPhillips Project No:E BRITTONHydration Visc: 25 80All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:Narwhal Hydration pH:Temp 0FPH LOSURF-300D CL-28 BA-20 MO-67 Optiflo II Optiflo III2.00 0.33 0.85 2.00 2.0090 8.80 1.0090 8.80 1.00 2.00 0.33 0.85 2.00 2.0005001000150020002500300000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 13 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-610 Zone 13 207
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini FracPad2 ppg3 ppg4 ppg5 ppg3S-610 Stage(s): 14140 Water Source: CPF 3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date: 5/25/2024ConocoPhillips Project No:E BRITTONHydration Visc: 25 80All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:Narwhal Hydration pH:Temp 0FPH LOSURF-300D CL-28 BA-20 MO-67 Optiflo II Optiflo III2.00 0.33 0.85 2.00 2.0090 8.80 1.0090 8.80 1.00 2.00 0.33 0.85 2.00 2.0002004006008001000120014001600180000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 14 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-610 Zone 14 208
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini FracPad2 ppg3 ppg4 ppg5 ppg3S-610 Stage(s): 15140 Water Source: CPF 3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date: 5/25/2024ConocoPhillips Project No:E BRITTONHydration Visc: 25 80All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:Narwhal Hydration pH:Temp 0FPH LOSURF-300D CL-28 BA-20 MO-67 Optiflo II Optiflo III2.00 0.33 0.85 2.00 2.0090 8.80 1.0090 8.80 1.00 2.00 0.33 0.85 2.00 2.0002004006008001000120014001600180000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 15 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-610 Zone 15 209
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini FracPad2 ppg3 ppg4 ppg5 ppg3S-610 Stage(s): 16140 Water Source: CPF 3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date: 5/25/2024ConocoPhillips Project No:E BRITTONHydration Visc: 25 80All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:Narwhal Hydration pH:Temp 0FPH LOSURF-300D CL-28 BA-20 MO-67 Optiflo II Optiflo III2.00 0.33 0.85 2.00 2.0090 8.80 1.0090 8.80 1.00 2.00 0.33 0.85 2.00 2.0005001000150020002500300000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 16 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-610 Zone 16 210
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini FracPad2 ppg3 ppg4 ppg5 ppg3S-610 Stage(s): 17140 Water Source: CPF 3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date: 5/25/2024ConocoPhillips Project No:E BRITTONHydration Visc: 25 80All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:Narwhal Hydration pH:Temp 0FPH LOSURF-300D CL-28 BA-20 MO-67 Optiflo II Optiflo III2.00 0.33 0.85 2.00 2.0090 8.80 1.0090 8.80 1.00 2.00 0.33 0.85 2.00 2.00020040060080010001200140016001800200000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 17 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-610 Zone 17 211
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini FracPad2 ppg3 ppg4 ppg5 ppg3S-610 Stage(s): 18140 Water Source: CPF 3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date: 5/26/2024ConocoPhillips Project No:E BRITTONHydration Visc: 25 80All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:Narwhal Hydration pH:Temp 0FPH LOSURF-300D CL-28 BA-20 MO-67 Optiflo II Optiflo III2.00 0.33 0.85 2.00 2.0090 8.80 1.0090 8.80 1.00 2.00 0.33 0.85 2.00 2.000500100015002000250000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 18 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-610 Zone 18 212
Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Mini FracPad2 ppg3 ppg4 ppg5 ppg3S-610 Stage(s): 19140 Water Source: CPF 3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date: 5/26/2024ConocoPhillips Project No:E BRITTONHydration Visc: 25 80All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:Narwhal Hydration pH:Temp 0FPH LOSURF-300D CL-28 BA-20 MO-67 Optiflo II Optiflo III2.00 0.33 0.85 2.00 2.0090 8.80 1.0090 8.80 1.00 2.00 0.33 0.85 2.00 2.000500100015002000250000:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec)Zone 19 Crosslink TestsMini FracPad2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-610 Zone 19 213
Company: Conoco Phillips
Well: 3S-610
Sand Type 16/20 Proppant
Date Tested 5/17/2024
Total Sample Size Seive Weight Seive Weight 100.0 g
Sieve Size Before Sand With sand WT. rtn'd % rtn'd % API Spec
12 355.4 355.4 0 0.0% 0.00% <0.1%
16 340.5 344.2 3.7 3.7%
18 673.1 739.1 66 66.0%
20 296.8 325.3 28.5 28.5%
25 419.8 420.9 1.1 1.1%
30 281.8 281.9 0.1 0.1%
40 408.2 408 -0.2 -0.2%
Pan 306.8 306.9 0.1 0.1% 0.10% <1.0%
Total: 99.3 99%
Total Sample Size Seive Weight Seive Weight 100.0 g
Sieve Size Before Sand With sand WT. rtn'd % rtn'd % API Spec
12 355.4 355.4 0 0.0% 0.00% <0.1%
16 340.5 343.8 3.3 3.3%
18 673.1 743.8 70.7 70.7%
20 296.8 322.3 25.5 25.5%
25 419.8 419.7 -0.1 -0.1%
30 281.8 282.1 0.3 0.3%
40 408.2 408.5 0.3 0.3%
Pan 306.8 306.8 0 0.0% 0.00% <1.0%
Total: 100 100%
Total Sample Size Seive Weight Seive Weight 100.0 g
Sieve Size Before Sand With sand WT. rtn'd % rtn'd % API Spec
12 355.4 355.4 0 0.0% 0.00% <0.1%
16 340.5 348 7.5 7.5%
18 673.1 746.7 73.6 73.6%
20 296.8 315 18.2 18.2%
25 419.8 420.3 0.5 0.5%
30 281.8 281.9 0.1 0.1%
40 408.2 408 -0.2 -0.2%
Pan 306.8 306.9 0.1 0.1% 0.10% <1.0%
Total: 99.8 100%
Ceramic Proppant Sieves
Sample: 16/20 - 05/17/24
95.70% >/= 90%
Sample: 16/20 - 5/19/24
96.40% >/= 90%
Sample: 16/20 - 5/20/24
92.40% >/= 90%
Conoco Phillips - 3S-610 Sand Sieve Analysis 214
Total Sample Size Seive Weight Seive Weight 100.0 g
Sieve Size Before Sand With sand WT. rtn'd % rtn'd % API Spec
12 355.4 355.4 0 0.0% 0.00% <0.1%
16 340.5 348 7.5 7.5%
18 673.1 740.7 67.6 67.6%
20 296.8 322.3 25.5 25.5%
25 419.8 418.7 -1.1 -1.1%
30 281.8 281.9 0.1 0.1%
40 408.2 408 -0.2 -0.2%
Pan 306.8 306.9 0.1 0.1% 0.10% <1.0%
Total: 99.5 99%
Total Sample Size Seive Weight Seive Weight 100.0 g
Sieve Size Before Sand With sand WT. rtn'd % rtn'd % API Spec
12 355.4 355.4 0 0.0% 0.00% <0.1%
16 340.4 342.01 1.61 1.6%
18 673.1 766.05 92.95 92.9%
20 296.8 302.18 5.38 5.4%
25 419.8 419.8 0 0.0%
30 281.8 281.8 0 0.0%
40 408.2 408.2 0 0.0%
Pan 306.8 306.8 0 0.0% 0.00% <1.0%
Total: 99.94 100%
Total Sample Size Seive Weight Seive Weight 100.0 g
Sieve Size Before Sand With sand WT. rtn'd % rtn'd % API Spec
12 355.4 355.4 0 0.0% 0.00% <0.1%
16 340.4 342.8 2.4 2.4%
18 673.1 765.2 92.1 92.1%
20 296.8 302.14 5.34 5.3%
25 419.8 419.8 0 0.0%
30 281.8 281.8 0 0.0%
40 408 408 0 0.0%
Pan 306.8 306.8 0 0.0% 0.00% <1.0%
Total: 99.84 100%
Total Sample Size Seive Weight Seive Weight 100.0 g
Sieve Size Before Sand With sand WT. rtn'd % rtn'd % API Spec
12 355.4 355.4 0 0.0% 0.00% <0.1%
16 340.4 349.86 9.46 9.5%
18 673.1 758.67 85.57 85.6%
20 296.8 301.67 4.87 4.9%
25 419.8 419.8 0 0.0%
30 281.8 281.8 0 0.0%
40 408 408 0 0.0%
Pan 306.8 306.8 0 0.0% 0.00% <1.0%
Total: 99.9 100%
Sample: 16/20 - 5/24/24
Sample: 16/20 - 5/21/24
92.10% >/= 90%
Sample: 16/20 - 5-26-24
98.33% >/= 90%
Sample: 16/20 - 5-25-24
97.44% >/= 90%
90.44% >/= 90%
Conoco Phillips - 3S-610 Sand Sieve Analysis 215
Hydraulic Fracturing Fluid Product Component Information Disclosure
2024-05-19
Alaska
HARRISON BAY
50-103-20875-00-00
CONOCOPHILLIPS
3S 610
-150.19610000
70.39420000
NAD83
none
Oil
5300
1893771
Hydraulic Fracturing Fluid Composition:
Trade Name Supplier Purpose Ingredients
Chemical
Abstract
Service
Number
(CAS #)
Maximum Ingredient
Concentration in
Additive (% by mass)**
Maximum
Ingredient
Concentration in
HF Fluid (% by
mass)**
Ingredient Mass
lbs Comments Company First Name Last Name Email Phone
Produced Water
(Density 8.5) Operator Base Fluid Density = 8.50
SEAWATER (SG
8.52) Operator Base Fluid Density = 8.52
BA-20
BUFFERING
AGENT Halliburton Buffer
BE-6(TM)
Bactericide Halliburton Microbiocide
CAT-3
ACTIVATOR Halliburton Activator
CL-28M
CROSSLINKER Halliburton Crosslinker
LoSurf-300D Halliburton Non-ionic Surfactant
MO-67 Halliburton pH Control
OPTIFLO-II
DELAYED
RELEASE
BREAKER Halliburton Breaker
OPTIFLO-III
DELAYED
RELEASE
BREAKER Halliburton Breaker
WG-36 GELLING
AGENT Halliburton Gelling Agent
Ceramic
Proppant - Wanli Wanli Proppant
SAND, COMMON
BROWN 100
MESH Halliburton Proppant
Flow Insurance
Copper
Patina
Energy Tracer
Ingredients Water 7732-18-5 100.00%72.28884%14878137
Corundum 1302-74-5 65.00%13.51518%2781629
Mullite 1302-93-8 45.00%9.35666%1925743
Water 7732-18-5 100.00%5.93632%1221786
Crystalline silica, quartz 14808-60-7 100.00%0.34246%70484
Sodium chloride 7647-14-5 5.00%0.29682%61090
Guar gum 9000-30-0 100.00%0.26568%54681
Water 7732-18-5 100.00%0.19393%39915
Borate salts Proprietary 60.00%0.09787%20143
Denise Tuck,
Halliburton, 3000
N. Sam Houston
Pkwy E.,
Houston, TX
77032, 281-871-
6226 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Ethanol 64-17-5 60.00%0.03959%8149
Ammonium persulfate 7727-54-0 100.00%0.03809%7840
Sodium hydroxide 1310-73-2 30.00%0.02582%5316
Ammonium acetate 631-61-8 100.00%0.02072%4265
Heavy aromatic petroleum
naphtha 64742-94-5 30.00%0.01980%4075
Oxyalkylated nonyl phenolic resin Proprietary 30.00%0.01980%4075 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Oxylated phenolic resin Proprietary 30.00%0.01143%2352 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Potassium chloride 7447-40-7 5.00%0.00816%1679
Inorganic mineral 1317-65-3 5.00%0.00816%1679
Oxyalkylated phenolic resin Proprietary 10.00%0.00660%1359 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Acetic acid 64-19-7 30.00%0.00622%1280
Poly(oxy-1,2-ethanediyl), alpha-(4-
nonylphenyl)-omega-hydroxy-,
branched 127087-87-0 5.00%0.00330%680
Naphthalene 91-20-3 5.00%0.00330%680
Flow Insurance Copper Proprietary 100.00%0.00214%441 Patina Energy Product Stewardship
test@patinae
nergy.com 6692416025
Inorganic mineral Proprietary 1.00%0.00163%336 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Gluteraldehyde 111-30-8 1.00%0.00163%336
Calcium magnesium carbonate 16389-88-1 1.00%0.00163%336
Polymer Proprietary 1.00%0.00163%336 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00%0.00143%294
EDTA/Copper chelate Proprietary 30.00%0.00113%233 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Sodium chloride 7647-14-5 1.00%0.00086%178
1,2,4 Trimethylbenzene 95-63-6 1.00%0.00066%136
C.I. pigment Orange 5 3468-63-1 1.00%0.00022%46
Ammonium chloride 12125-02-9 5.00%0.00019%39
Methanesulfonic acid, 1-hydroxy-,
sodium salt 870-72-4 0.10%0.00016%34
Sodium bisulfate 7681-38-1 0.10%0.00016%34
Ammonia 7664-41-7 1.00%0.00004%8
Magnesium nitrate 10377-60-3 0.01%0.00002%4
5-Chloro-2-methyl-3(2H)-
Isothaiazolone 26172-55-4 0.01%0.00002%4
2-Methyl-4-isothiazolin-3-one 2682-20-4 0.01%0.00002%4
Magensium chloride 7786-30-3 0.01%0.00002%4
0.00%0.00000%0
* Total Water Volume sources may include fresh water, produced water, and/or recycled water _
** Information is based on the maximum potential for concentration and thus the total may be over 100%
Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided.Version web 1.4
All component information listed was obtained from the suppliers Material Safety Data Sheets (MSDS). As such, the Operator is not responsible for inaccurate and/or incomplete information. Any questions regarding the content of the MSDS should be directed to the supplier
who provided it. The Occupational Safety and Health Administrations (OSHA) regulations govern the criteria for the disclosure of this information. Please note that Federal Law protects "proprietary", "trade secret", and "confidential business information" and the criteria for
how this information is reported on an MSDS is subject to 29 CFR 1910.1200(i) and Appendix D.
Production Type:
True Vertical Depth (TVD):
Total Water Volume (gal)*:
MSDS and Non-MSDS Ingredients are listed below the green line
Well Name and Number:
Longitude:
Latitude:
Long/Lat Projection:
Indian/Federal:
Fracture Date
State:
County:
API Number:
Operator Name:
Page 1/1
3S-610
Report Printed: 6/21/2024
Daily STIM Report REPORT # [ 1]
REPORT DATE: [ 5/9/2024]
API / UWI
5010320875
Original KB/RT Elevation (ft)
63.30
Ground Elevation (ft)
24.30
Original Spud Date
3/9/2024
Primary Job Type
INITIAL COMPLETION
Secondary Job Type
STIMULATION
Total AFE (Cost) AFE / RFE / Maint.#
10441022
Network/Order Number
10441022
AFE+Supp Amt (Cost) Daily Cost Total (Cost)
25,000.00
Cumulative Cost (Cost)
25,000.00
Weather Temperature (°F) Road Condition Wind
Last 24hr Summary
FRAC, PRE CONTAINMENT PAD WORK, LAY OUT CONTAINMENT, SEAM SECTIONS, SPOT TANKS AND MANIFOLD
PRODUCED WATER, N2 COMPRESSOR TEST AND WATER PRESSURE TEST THE SKID
24hr Forecast
COMPLETE TANK FARM
General Remarks
IN PROGRESS
ZX Code
ZX02 Fracturing
Contact Name Title Mobile
FAUR, DAN Frac Supervisor 907-301-9670
BECK, BRENT Supervisor 907-616-0445
Time Log
Start Time End Time Dur (hr) Phase Activity Code
Time P-
T-X Operation
06:00 08:00 2.00 COMPZN, STIM RURD P PAD PREP FOR CONTAINMENT, LEVEL OUT TANK AREA, DEFINE BOUNDARIES
08:00 14:00 6.00 COMPZN, STIM RURD P ROLLOUT CONTAINMENT, SPOT ANCHOR TANKS, SEAM CONTAINMENT SECTIONS,
CONTINUE SPOTTING TANKS
14:00 18:00 4.00 COMPZN, STIM RURD P FOUND TANKS WITH FLUID, UNABLE TO BE MOVED, CALLED VAC TRUCK TO PULL
ALL THAWED BOTTOMS (BRINE TANK), APPLIED HEAT FOR OVERNIGHT THAW ON
REMAINING ICE, SPOTTED THE REMAIING AVALIBLE TANKS, OFFLOADED WATER
TO TANK FARM.
18:00 23:59 5.99 COMPZN, STIM RURD P CONTAINER PROPPANT HAUL FROM NES YARD TO 3T
Report Fluids Summary
Fluid To well (bbl) Cum to Well (bbl)
Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/9/2024 06:00 5/9/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/10/2024 00:00 5/10/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/11/2024 00:00 5/11/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/12/2024 00:00 5/12/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/13/2024 00:00 5/13/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/14/2024 00:00 5/14/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/15/2024 00:00 5/15/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/16/2024 00:00 5/16/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/17/2024 00:00 5/17/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/18/2024 00:00 5/18/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/19/2024 00:00 5/19/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/20/2024 00:00 5/20/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/21/2024 00:00 5/21/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/22/2024 00:00 5/22/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/23/2024 00:00 5/23/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/24/2024 00:00 5/24/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/25/2024 00:00 5/25/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/26/2024 00:00 5/26/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/27/2024 00:00 5/27/2024 18:00 FRAC
Page 1/1
3S-610
Report Printed: 6/21/2024
Daily STIM Report REPORT # [ 2]
REPORT DATE: [ 5/10/2024]
API / UWI
5010320875
Original KB/RT Elevation (ft)
63.30
Ground Elevation (ft)
24.30
Original Spud Date
3/9/2024
Primary Job Type
INITIAL COMPLETION
Secondary Job Type
STIMULATION
Total AFE (Cost) AFE / RFE / Maint.#
10441022
Network/Order Number
10441022
AFE+Supp Amt (Cost) Daily Cost Total (Cost)
2,500.00
Cumulative Cost (Cost)
27,500.00
Weather Temperature (°F) Road Condition Wind
Last 24hr Summary
FRAC, COMPLETE TANK FARM, CONTINUE HAULING PROPPANT, STAGING PROPPANT FOR FRAC.
PW SKID, CONTINUE FUNCTION TESTING UNIT RUN THE CLEAN WATER OUT, SKIM OUT,
24hr Forecast
FRAC, CONTINUE PROPPANT OPERATIONS
PW, CONTINUE PREFLOW CHECKLIST
General Remarks
IN PROGRESS
ZX Code
ZX02 Fracturing
Contact Name Title Mobile
FAUR, DAN Frac Supervisor 907-301-9670
BECK, BRENT Supervisor 907-616-0445
Time Log
Start Time End Time Dur (hr) Phase Activity Code
Time P-
T-X Operation
00:00 06:00 6.00 COMPZN, STIM RURD OFFLOADING PROPPANT TRUCKS, STAGING PROPPANT FOR LOADING
06:00 14:00 8.00 COMPZN, STIM RURD COMPLETE TANK FARM, BUILD BERMING, COMPLETE HOSE CONNECTIONS
14:00 18:00 4.00 COMPZN, STIM RURD SPOT SHOP, FUNCTION TEST TRANSFER PUMP AND BLOWER, COMPLETE TANK
CONNECTION POINTS, CONTINUED PROPPANT OPERATIONS
18:00 23:59 5.99 COMPZN, STIM RURD CONTINUE OFFLOADING PROPPANT
Report Fluids Summary
Fluid To well (bbl) Cum to Well (bbl)
Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/9/2024 06:00 5/9/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/10/2024 00:00 5/10/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/11/2024 00:00 5/11/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/12/2024 00:00 5/12/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/13/2024 00:00 5/13/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/14/2024 00:00 5/14/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/15/2024 00:00 5/15/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/16/2024 00:00 5/16/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/17/2024 00:00 5/17/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/18/2024 00:00 5/18/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/19/2024 00:00 5/19/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/20/2024 00:00 5/20/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/21/2024 00:00 5/21/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/22/2024 00:00 5/22/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/23/2024 00:00 5/23/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/24/2024 00:00 5/24/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/25/2024 00:00 5/25/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/26/2024 00:00 5/26/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/27/2024 00:00 5/27/2024 18:00 FRAC
Page 1/1
3S-610
Report Printed: 6/21/2024
Daily STIM Report REPORT # [ 3]
REPORT DATE: [ 5/11/2024]
API / UWI
5010320875
Original KB/RT Elevation (ft)
63.30
Ground Elevation (ft)
24.30
Original Spud Date
3/9/2024
Primary Job Type
INITIAL COMPLETION
Secondary Job Type
STIMULATION
Total AFE (Cost) AFE / RFE / Maint.#
10441022
Network/Order Number
10441022
AFE+Supp Amt (Cost) Daily Cost Total (Cost)
2,500.00
Cumulative Cost (Cost)
30,000.00
Weather Temperature (°F) Road Condition Wind
Last 24hr Summary
FRAC, MORNING TRAINING, TRIP OUT REMAINING EQUIPMENT
LYNDEN, CONTINUE OFFLOADING PROPPANT,
PW, CONTINUED CIRCULATING FRESH WATER, COMPLETED RIG IN
24hr Forecast
START FRAC IRON RIG IN
General Remarks
IN PROGRESS
ZX Code
ZX02 Fracturing
Contact Name Title Mobile
FAUR, DAN Frac Supervisor 907-301-9670
BECK, BRENT Supervisor 907-616-0445
Time Log
Start Time End Time Dur (hr) Phase Activity Code
Time P-
T-X Operation
00:00 10:00 10.00 COMPZN, STIM RURD CONTINUED OFFLOADING PROPPANT CONTAINERS, STAGING PROPPANT
10:00 16:00 6.00 COMPZN, STIM RURD PLACED CONTAINMENT, SPOTTED IA/OA POP, BLEED, PRV TANKS INSTALLED
WELL INTEGRALS, COMPLETED PW SKID SKIM LINE, COMPLETED CLEAN WATER
OUT LINE.
16:00 23:59 7.99 COMPZN, STIM RURD CONTINUED PROPPANT WORK, TOTAL OFFLOADED 3.2MMLB.
Report Fluids Summary
Fluid To well (bbl) Cum to Well (bbl)
Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/9/2024 06:00 5/9/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/10/2024 00:00 5/10/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/11/2024 00:00 5/11/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/12/2024 00:00 5/12/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/13/2024 00:00 5/13/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/14/2024 00:00 5/14/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/15/2024 00:00 5/15/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/16/2024 00:00 5/16/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/17/2024 00:00 5/17/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/18/2024 00:00 5/18/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/19/2024 00:00 5/19/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/20/2024 00:00 5/20/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/21/2024 00:00 5/21/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/22/2024 00:00 5/22/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/23/2024 00:00 5/23/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/24/2024 00:00 5/24/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/25/2024 00:00 5/25/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/26/2024 00:00 5/26/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/27/2024 00:00 5/27/2024 18:00 FRAC
Page 1/1
3S-610
Report Printed: 6/21/2024
Daily STIM Report REPORT # [ 4]
REPORT DATE: [ 5/12/2024]
API / UWI
5010320875
Original KB/RT Elevation (ft)
63.30
Ground Elevation (ft)
24.30
Original Spud Date
3/9/2024
Primary Job Type
INITIAL COMPLETION
Secondary Job Type
STIMULATION
Total AFE (Cost) AFE / RFE / Maint.#
10441022
Network/Order Number
10441022
AFE+Supp Amt (Cost) Daily Cost Total (Cost)
2,500.00
Cumulative Cost (Cost)
32,500.00
Weather Temperature (°F) Road Condition Wind
Last 24hr Summary
FRAC, LAID OUT CONTAINMENT, SPOTTED SUCK SIDE AND PROPPANT EQUIPMENT
LOIL, CONTINUED OFFLOADING PROPPANT, INSTALLED SHOP COMPONENTS AND A LOAD BANK FOR THE GENERATOR
PW, WORKED ON COMS, CONTINUED PSSR PREP
24hr Forecast
CONTINUE RIG IN
General Remarks
IN PROGRESS
ZX Code
ZX02 Fracturing
Contact Name Title Mobile
BRZEZINSKI, NATE Frac Supervisor 814-553-0901
BECK, BRENT Supervisor 907-616-0445
VAUGHT,RYAN Supervisor 903-721-3182
Time Log
Start Time End Time Dur (hr) Phase Activity Code
Time P-
T-X Operation
00:00 06:00 6.00 COMPZN, STIM RURD P OFFLOADING PROPPANT, UIC LOOSE SACKS AND AFC CONTAINERS,
06:00 12:00 6.00 COMPZN, STIM RURD P FRAC, PAD PREPARATION, LEVEL PAD FOR FRAC RIG IN, LAY CONTAINMENT, PW
TIED IN ELECTRICAL TO MOBILE SHOP
12:00 18:00 6.00 COMPZN, STIM RURD P SPOT SUCK SIDE EQUIPMENT AND PROPPANT EQUIPMENT, PLAN FOR MISSILE
AND PUMP PLACEMENT, SPOT MISSILE, STAND 2 CASTLES, PW SKID CONTINUED
TYING IN AUTOMATION.
18:00 23:59 5.99 COMPZN, STIM RURD P CONTINUE PROPPANT OFFLOADING
Report Fluids Summary
Fluid To well (bbl) Cum to Well (bbl)
Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/9/2024 06:00 5/9/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/10/2024 00:00 5/10/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/11/2024 00:00 5/11/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/12/2024 00:00 5/12/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/13/2024 00:00 5/13/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/14/2024 00:00 5/14/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/15/2024 00:00 5/15/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/16/2024 00:00 5/16/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/17/2024 00:00 5/17/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/18/2024 00:00 5/18/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/19/2024 00:00 5/19/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/20/2024 00:00 5/20/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/21/2024 00:00 5/21/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/22/2024 00:00 5/22/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/23/2024 00:00 5/23/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/24/2024 00:00 5/24/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/25/2024 00:00 5/25/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/26/2024 00:00 5/26/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/27/2024 00:00 5/27/2024 18:00 FRAC
Page 1/1
3S-610
Report Printed: 6/21/2024
Daily STIM Report REPORT # [ 5]
REPORT DATE: [ 5/13/2024]
API / UWI
5010320875
Original KB/RT Elevation (ft)
63.30
Ground Elevation (ft)
24.30
Original Spud Date
3/9/2024
Primary Job Type
INITIAL COMPLETION
Secondary Job Type
STIMULATION
Total AFE (Cost) AFE / RFE / Maint.#
10441022
Network/Order Number
10441022
AFE+Supp Amt (Cost) Daily Cost Total (Cost)
2,500.00
Cumulative Cost (Cost)
35,000.00
Weather Temperature (°F) Road Condition Wind
Last 24hr Summary
FRAC, CONTINUED RIGGING IN, ALL PROPPANT EQUIPMENT READY FOR LOADING, SPOTTED PUMPS AND MISSILE.
LOIL, CONTINUED OFFLOADING PROP. STARTED JOB LOADING PREPARATIONS, PRESSURE TESTED TANK FARM MANIFOLD.
THUNDERBIRD, PSSR PREPARATIONS,
24hr Forecast
CONTINUE RIG IN
General Remarks
IN PROGRESS
ZX Code
ZX02 Fracturing
Contact Name Title Mobile
BRZEZINSKI, NATE Frac Supervisor 814-553-0901
BECK, BRENT Supervisor 907-616-0445
VAUGHT,RYAN Supervisor 903-721-3182
Time Log
Start Time End Time Dur (hr) Phase Activity Code
Time P-
T-X Operation
00:00 06:00 6.00 COMPZN, STIM RURD P CONTINUED PROPPANT OFFLOADING,
06:00 18:00 12.00 COMPZN, STIM RURD P CONTINUED SPOTTING EQUIPMENT, MOBILIZED CRANE AND IRON TRUCK TO 3S,
FINAL PROP. EQUIPMENT SPOTTED, PRESSURE TESTED TANK FARM MANIFOLD,
PREPARED PROPPANT HANDLING EQUIPMENT, STAGED PROPPANT FOR FRAC
LOADING, PW SKID CONTINUED PSSR PREP.
18:00 23:59 5.99 COMPZN, STIM RURD P OFFLOADING PROPPANT CONTAINERS AND SACKS, FINAL CONTAINERS FROM
AFC DELIVERED
Report Fluids Summary
Fluid To well (bbl) Cum to Well (bbl)
Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/9/2024 06:00 5/9/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/10/2024 00:00 5/10/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/11/2024 00:00 5/11/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/12/2024 00:00 5/12/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/13/2024 00:00 5/13/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/14/2024 00:00 5/14/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/15/2024 00:00 5/15/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/16/2024 00:00 5/16/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/17/2024 00:00 5/17/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/18/2024 00:00 5/18/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/19/2024 00:00 5/19/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/20/2024 00:00 5/20/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/21/2024 00:00 5/21/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/22/2024 00:00 5/22/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/23/2024 00:00 5/23/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/24/2024 00:00 5/24/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/25/2024 00:00 5/25/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/26/2024 00:00 5/26/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/27/2024 00:00 5/27/2024 18:00 FRAC
Page 1/1
3S-610
Report Printed: 6/21/2024
Daily STIM Report REPORT # [ 6]
REPORT DATE: [ 5/14/2024]
API / UWI
5010320875
Original KB/RT Elevation (ft)
63.30
Ground Elevation (ft)
24.30
Original Spud Date
3/9/2024
Primary Job Type
INITIAL COMPLETION
Secondary Job Type
STIMULATION
Total AFE (Cost) AFE / RFE / Maint.#
10441022
Network/Order Number
10441022
AFE+Supp Amt (Cost) Daily Cost Total (Cost)
2,500.00
Cumulative Cost (Cost)
37,500.00
Weather Temperature (°F) Road Condition Wind
Last 24hr Summary
FRAC, RIGGED IN GEL UNIT, BLENDER, PUMP HARDLINE AND HOSES TO THE MISSILE, STARTED IRON RUN
LOIL, BLOWING OFF PROPPANT, STAGED PROPANT FOR OPERATIONS
THUNDERBIRD, CONTINUED STARTUP PREPARATIONS, ENVIRONMENTAL PSSR COMPLETED, MOC PSSR COMPLETED, AI INSPECTION COMPLETE.
24hr Forecast
CONTINUE RIG IN
General Remarks
IN PROGRESS
ZX Code
ZX02 Fracturing
Contact Name Title Mobile
BRZEZINSKI, NATE Frac Supervisor 814-553-0901
BECK, BRENT Supervisor 907-616-0445
VAUGHT,RYAN Supervisor 903-721-3182
Time Log
Start Time End Time Dur (hr) Phase Activity Code
Time P-
T-X Operation
00:00 06:00 6.00 COMPZN, STIM RURD P CONTINUE OFFLOADING PROPPANT SACKS, CURRENTLY HAULING TO 3S, AND
STAGING FOR OPERATIONS
06:00 18:00 12.00 COMPZN, STIM RURD P CONTINUED RIGGING UP SUCK SIDE EQUIPMENT, RIGGED IN PUMPS HARDLINE,
HOSES, SPOTTED HARD LINE EQUIPMENT. BEGAN PRELOADING PROPPANT,
STAGED JOB PROPPANT, PW CONTINUED STARTUP PREPARATIONS
18:00 23:59 5.99 COMPZN, STIM RURD CONTINUED HARD LINE RUN, PROPPANT LOADING, PW FINAL PREP.
Report Fluids Summary
Fluid To well (bbl) Cum to Well (bbl)
Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/9/2024 06:00 5/9/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/10/2024 00:00 5/10/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/11/2024 00:00 5/11/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/12/2024 00:00 5/12/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/13/2024 00:00 5/13/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/14/2024 00:00 5/14/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/15/2024 00:00 5/15/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/16/2024 00:00 5/16/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/17/2024 00:00 5/17/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/18/2024 00:00 5/18/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/19/2024 00:00 5/19/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/20/2024 00:00 5/20/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/21/2024 00:00 5/21/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/22/2024 00:00 5/22/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/23/2024 00:00 5/23/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/24/2024 00:00 5/24/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/25/2024 00:00 5/25/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/26/2024 00:00 5/26/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/27/2024 00:00 5/27/2024 18:00 FRAC
Page 1/1
3S-610
Report Printed: 6/21/2024
Daily STIM Report REPORT # [ 7]
REPORT DATE: [ 5/15/2024]
API / UWI
5010320875
Original KB/RT Elevation (ft)
63.30
Ground Elevation (ft)
24.30
Original Spud Date
3/9/2024
Primary Job Type
INITIAL COMPLETION
Secondary Job Type
STIMULATION
Total AFE (Cost) AFE / RFE / Maint.#
10441022
Network/Order Number
10441022
AFE+Supp Amt (Cost) Daily Cost Total (Cost)
2,500.00
Cumulative Cost (Cost)
40,000.00
Weather Temperature (°F) Road Condition Wind
Last 24hr Summary
FRAC CONTINUED RIGGING IN HARDLINE TO THE PIPE RACK ON THE EQUIPMENT SIDE, HUNG RISERS OFF OF 3S-610, GREAT NORTH WITH
WELLS HARDLINE ASSISTANCE STABBED THE GOAT HEAD, LAUNCHER STACK, DART LAUNCHER, HOOKED UP THE ACCUMULATOR, WELLS
COMPLETED THE IA/OA, TUBING LINE /BLEED TIE IN, LOIL CONTINUED LOADING PROPPANT, AND ARE ON STANDBY FOR WATER LOADING, PW
TRIED FOR A PT, DISCOVERED A N2 GENERATOR ISSUE, PREVENTING THE ASD OPERATION AND A TOTE VALVE LEAKING, CONTINUED TROUBLE
SHOOTING.
24hr Forecast
CONTINUE RIG IN
General Remarks
IN PROGRESS
ZX Code
ZX02 Fracturing
Contact Name Title Mobile
BRZEZINSKI, NATE Frac Supervisor 814-553-0901
BECK, BRENT Supervisor 907-616-0445
VAUGHT,RYAN Supervisor 903-721-3182
Time Log
Start Time End Time Dur (hr) Phase Activity Code
Time P-
T-X Operation
00:00 06:00 6.00 COMPZN, STIM RURD P LOIL CONTINUED PROPPANT LOADING, HES RAN IRON FROM THE PUMPS TO
TRIPLE TANK CONTAINMENT, PW SKID CONTINUED START UP PREPARATIONS
06:00 18:00 12.00 COMPZN, STIM RURD P LOIL CONTINUED PROPPANT LOADING AND OFFLOADING SUPER SACKS, HES RAN
IRON TO THE PIPE RACK, THEN SWITCHED TO THE WELL RIG UP DROPPING THE
RISERS AND SETTING THE CVA, AND BLEED MANIFOLD, RUNNING IRON TO THE
VALVE SHED T.B. HELD STARTUP MEETING, PREPPED TO FLOOD LINES FOR PT,
FOUND N2 GENERATOR WAS NOT BUILD PRESSURE, BEGAN TROUBLESHOOTING,
A TOTE VALVE FROM THIRD PARTY LEAKED WHEN VALVE OPENED, SWAPPED
TOTES.
18:00 23:59 5.99 COMPZN, STIM RURD P HES CONTINUED RIGGING IN IRON, LOIL CONTINUED PROPPANT LOADING, T.B.
CONTINUED N2 GENERATOR TROUBLE SHOOTING
Report Fluids Summary
Fluid To well (bbl) Cum to Well (bbl)
Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/9/2024 06:00 5/9/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/10/2024 00:00 5/10/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/11/2024 00:00 5/11/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/12/2024 00:00 5/12/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/13/2024 00:00 5/13/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/14/2024 00:00 5/14/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/15/2024 00:00 5/15/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/16/2024 00:00 5/16/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/17/2024 00:00 5/17/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/18/2024 00:00 5/18/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/19/2024 00:00 5/19/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/20/2024 00:00 5/20/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/21/2024 00:00 5/21/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/22/2024 00:00 5/22/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/23/2024 00:00 5/23/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/24/2024 00:00 5/24/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/25/2024 00:00 5/25/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/26/2024 00:00 5/26/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/27/2024 00:00 5/27/2024 18:00 FRAC
Page 1/1
3S-610
Report Printed: 6/21/2024
Daily STIM Report REPORT # [ 8]
REPORT DATE: [ 5/16/2024]
API / UWI
5010320875
Original KB/RT Elevation (ft)
63.30
Ground Elevation (ft)
24.30
Original Spud Date
3/9/2024
Primary Job Type
INITIAL COMPLETION
Secondary Job Type
STIMULATION
Total AFE (Cost) AFE / RFE / Maint.#
10441022
Network/Order Number
10441022
AFE+Supp Amt (Cost) Daily Cost Total (Cost)
2,500.00
Cumulative Cost (Cost)
42,500.00
Weather Temperature (°F) Road Condition Wind
Last 24hr Summary
HES, CONTINUED RUNNING IRON, COMPLETED FRAC FUELER SYSTEM, CONTINUED LOADING PROPPANT, STARTED FILLING TANKS, PW WATER
SKID RUNNING @ 8:30 PM, DECIDED TO ASSIST WITH VAC TRUCKS, FIRST TRUCK SHOWED @ 9:00 PM
24hr Forecast
CONTINUE RIG IN
General Remarks
IN PROGRESS
ZX Code
ZX02 Fracturing
Contact Name Title Mobile
BRZEZINSKI, NATE Frac Supervisor 814-553-0901
BECK, BRENT Supervisor 907-616-0445
VAUGHT,RYAN Supervisor 903-721-3182
Time Log
Start Time End Time Dur (hr) Phase Activity Code
Time P-
T-X Operation
00:00 06:00 6.00 COMPZN, STIM RURD P CONTINUED LOADING PROPPANT, RUNNING IRON ALONG VALVE HOUSES,
TROUBLE SHOOTING PW SKID
06:00 12:00 6.00 COMPZN, STIM RURD P COMPLETED IRON RUN TO WELL, TIED IN TO WELL RISERS, SAND CASTLES ARE
FULL, SWITCHED TO LOADING THE BESSER, PW SKID, FLOODED SYSTEM, FOUND
CHOKE LEAK AT BONNET, AND OUT OF SPEC IRON,SECOND ATTEMPT WAS
SUCCESSFUL LOOSING 15 LBS IN 10 MINUTES,
12:00 18:00 6.00 COMPZN, STIM RURD P SPOTTED TCC CONTINUED FINAL ITEMS ON RIG IN, FRAC SHACK COMPLETED
EQUIPMENT RIG UP, CONTINUED RECEIVING PROPPANT SACKS, LOADING
PROPPANT, PW SKID CONTINUED ISSUE WITH N2 GENERATOR PROBLEM
18:00 23:59 5.99 COMPZN, STIM RURD P PW SKID TAKING WATER @8:30 PM, STARTING RATE 2500 BPD, INCREASED TO
5000 BPD, UP TO 7500 BPD, DISPATCHED WATER TRUCKS FIRST TRUCK SHOWED
@ 9:00 PM, STARTED WATER HEATING AND TRUCK OFFLOADING, STARTED WATER
TESTING, TRANSFERRING WATER.
Report Fluids Summary
Fluid To well (bbl) Cum to Well (bbl)
Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/9/2024 06:00 5/9/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/10/2024 00:00 5/10/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/11/2024 00:00 5/11/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/12/2024 00:00 5/12/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/13/2024 00:00 5/13/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/14/2024 00:00 5/14/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/15/2024 00:00 5/15/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/16/2024 00:00 5/16/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/17/2024 00:00 5/17/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/18/2024 00:00 5/18/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/19/2024 00:00 5/19/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/20/2024 00:00 5/20/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/21/2024 00:00 5/21/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/22/2024 00:00 5/22/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/23/2024 00:00 5/23/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/24/2024 00:00 5/24/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/25/2024 00:00 5/25/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/26/2024 00:00 5/26/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/27/2024 00:00 5/27/2024 18:00 FRAC
Page 1/1
3S-610
Report Printed: 6/21/2024
Daily STIM Report REPORT # [ 9]
REPORT DATE: [ 5/17/2024]
API / UWI
5010320875
Original KB/RT Elevation (ft)
63.30
Ground Elevation (ft)
24.30
Original Spud Date
3/9/2024
Primary Job Type
INITIAL COMPLETION
Secondary Job Type
STIMULATION
Total AFE (Cost) AFE / RFE / Maint.#
10441022
Network/Order Number
10441022
AFE+Supp Amt (Cost) Daily Cost Total (Cost)
2,500.00
Cumulative Cost (Cost)
45,000.00
Weather Temperature (°F) Road Condition Wind
Last 24hr Summary
WELLS, COMPLETED SCAFFOLDING, RIGGED IN LAUNCHER EQALIZATION LINE, HES LOADED CHEMS SPOTTED OPS TCC, LAUNCH PUMP,STARTED
COMMS CABLES, LOIL LOADING AND HEATING WATER PROPPANT FULLY LOADED, THUNDERBIRD, PROCESSING @6000BPD, CHOKE
MALFUNCTION CAUSING PRESSURE TRIPS, TOTAL ~16 TANKS FULL.
24hr Forecast
PUMP STAGES 1-3
General Remarks
IN PROGRESS
ZX Code
ZX02 Fracturing
Contact Name Title Mobile
BECK, BRENT Supervisor 907-616-0445
VAUGHT,RYAN Supervisor 903-721-3182
BRZEZINSKI, NATE Frac Supervisor 814-553-0901
Time Log
Start Time End Time Dur (hr) Phase Activity Code
Time P-
T-X Operation
00:00 06:00 6.00 COMPZN, STIM RURD P PROCESSING WATER @3.5 BPM, LEL ISSUES, WATER HAULING RECEIVED 3
TRUCKS,
06:00 16:00 10.00 COMPZN, STIM RURD P HES COMPLETED LAUNCH PUMP TIE IN, SPOTTED TCC, SPOTTED CHEMS, GEL,
PLACED EQUIPMENT AS IRON BARRIER, LOIL CONTINUED OFFLOADING
PROPPANT, LOADING AND HEATING TRUCKED WATER, TB CONTINUED
PRODUCING WATER @6000 BPD
16:00 20:00 4.00 COMPZN, STIM RURD P HES FUNCTION TESTING EQUIPMENT, PERFORMING WATER TESTING, LOIL
CONTINUED PROPPANT OFFLOAD, OFFLOADING/HEATING WATER, TB SHUT DOWN
FOR CHOKE SWAP, EXPRO RIGGED OUT THE 3" MALFUNCTIONING CHOKE,
SWAPPED IN 3" CHOKE SKID, NIPPLED UP NEW FLANGE CONNECTION,
COMPLETED IRON TIE IN, PERFORMED PT ON PW INLET TO 3000 PSI HELD FOR 5
MINUTES 75 PSI LOSS, BLED OFF OPENED UP TO RESUME WATER PROCESSING.
20:00 23:59 3.99 COMPZN, STIM RURD P HES, WATER TESTING, EQUIPMENT TESTING, LOIL OFFLOADING HAULED WATER/
HEATING WATER, TB PROCESSING PW@7000 BPD
Report Fluids Summary
Fluid To well (bbl) Cum to Well (bbl)
Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/9/2024 06:00 5/9/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/10/2024 00:00 5/10/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/11/2024 00:00 5/11/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/12/2024 00:00 5/12/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/13/2024 00:00 5/13/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/14/2024 00:00 5/14/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/15/2024 00:00 5/15/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/16/2024 00:00 5/16/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/17/2024 00:00 5/17/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/18/2024 00:00 5/18/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/19/2024 00:00 5/19/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/20/2024 00:00 5/20/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/21/2024 00:00 5/21/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/22/2024 00:00 5/22/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/23/2024 00:00 5/23/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/24/2024 00:00 5/24/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/25/2024 00:00 5/25/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/26/2024 00:00 5/26/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/27/2024 00:00 5/27/2024 18:00 FRAC
Page 1/2
3S-610
Report Printed: 6/21/2024
Daily STIM Report REPORT # [ 10]
REPORT DATE: [ 5/18/2024]
API / UWI
5010320875
Original KB/RT Elevation (ft)
63.30
Ground Elevation (ft)
24.30
Original Spud Date
3/9/2024
Primary Job Type
INITIAL COMPLETION
Secondary Job Type
STIMULATION
Total AFE (Cost) AFE / RFE / Maint.#
10441022
Network/Order Number
10441022
AFE+Supp Amt (Cost) Daily Cost Total (Cost)
7,677.00
Cumulative Cost (Cost)
52,677.00
Weather Temperature (°F) Road Condition Wind
Last 24hr Summary
START HICCUPS, TANK FARM MANIFOLD LEAK, ADP MIXING BOWL NO WETTING RING FLOW, AFTER RESOLVED PRIMED UP, PRESSURE TESTED,
BROKE THE GLASS DISC @ 5732 PSI, CONTINUED PRESSURING UP TO 5916 SHIFTED THE ALPHA SLEEVE, ROLLED INTO TO STEP RATE TEST UP
TO 15 BPM@ 2BBL INCREMENTS, AT 15BPM, HELD 5 MINUTES FOR THE DFIT. STARTED THE FRAC ON STAGE 1, DURING THE 2 LB STAGE THE
BLENDER DISCHARGE MANIFOLD DEVOLVED A LEAK, SHUT DOWN, SWAPPED TO THE ADP, RESUMED FLUSHING, DURING THIS TIME ACW
STARTED BRINGING RATE UP 7000 BPD, WHEN THE CHOKE MALFUNCTIONED,
24hr Forecast
FRAC STAGES 1-3
General Remarks
IN PROGRESS
ZX Code
ZX02 Fracturing
Contact Name Title Mobile
BECK, BRENT Supervisor 907-616-0445
VAUGHT,RYAN Supervisor 903-721-3182
BRZEZINSKI, NATE Frac Supervisor 814-553-0901
Time Log
Start Time End Time Dur (hr) Phase Activity Code
Time P-
T-X Operation
00:00 06:00 6.00 COMPZN, STIM RURD P CONTINUE LOADING/HEATING TRUCKED WATER, CONTINUED PRODUCED WATER
OPERATIONS
06:00 10:30 4.50 COMPZN, STIM RURD P FINAL EQUIPMENT PREPARATIONS, PICKED UP TRACER, AND BALLS FOR STAGES
1-3
10:30 11:30 1.00 COMPZN, STIM RURD P PRIMED EQUIPMENT, HAD A DRIP ON A SUCTION HOSE, REPLACED O RING,
FOUND A LEAK ON THE TANK FARM MANIFOLD, REPLACED O RING
11:30 12:30 1.00 COMPZN, STIM RURD P POPPED PRVS AT 500, BOTH FUNCTION CONTINUED TO PRESSURE TEST,LOW
TEST TO 5K, NO VISIBLE, PSI LINED OUT ~4500, CONTINUED TO 9500 PSI TEST
START 9468 PSI, END 9408 GOOD TEST,
12:30 13:30 1.00 COMPZN, STIM RURD T 8" HOSE MANIFOLD LEAK, TIGHTEN WING, LOOSENING THE OPPOSITE SIDE
BREAKING THE SEAL, RESEALED HAMMERED UP, MONITORING LEAK AREA
13:30 14:00 0.50 COMPZN, STIM RURD P SITE SAFETY MEETING
14:00 14:30 0.50 COMPZN, STIM RURD P LOADED BALL1 FOR STAGE 2 2.118", SN#00308438-1, LOADED BALL2 FOR STAGE 3
2.150" MEASURED SN# 00307164-2, WALKED EPRV AND IA /OA PRV LINES, MIXED
GEL LOADED CHEMS.
14:30 15:30 1.00 COMPZN, STIM RURD T ADP GEL UNIT MIXING BOWL PROBLEM
15:30 17:00 1.50 COMPZN, STIM PUMP P WELL OPEN 941 PSI, PUMPED STEP RATE TEST UP TO 15 BPM, ROLLED TO DFIT,
HELD 5 MIN, HARD SHUT DOWN, MONITORED PSI FOR 45 MINUTES.
17:00 19:00 2.00 COMPZN, STIM PUMP P RESUMED PUMPING ROLLING INTO STAGE 1, DURING THE 2 LB STAGE THE
BLENDER DISCHARGE MANIFOLD DEVELOPED A LEAK. SHUT DOWN, SWAPPED TO
FLUSH WITH THE ADP. DURING THIS TIME ACW DEVELOPED A CHOKE
MALFUNCTION, THE ADJUSTABLE CHOKE DEVELOPED A LEAK, SWAPPED TO THE
POSITIVE, SET UP FOR A LOWER RATE, THE GUT LINE WAS OPENED TO SUPPLY
DESIRED FLOW TO ACHIEVE 7000 BPD, AT THIS TIME THE GENERATOR STARTED
SURGING,SHUTTING DOWN THE ACW SKID, AFTER REBOOT ANOTHER SURGE HIT,
SHUTTING IT DOWN AGAIN, LEFT THE UNIT DOWN UNTIL FRAC ISSUES
RESOLVED.
19:00 23:59 4.99 COMPZN, STIM WAIT T REPLACING THE BLENDER DISCHARGE MANIFOLD, REPAIRING THE ACW SUPPLY
CHOKE, LOAD TESTING THE GENERATOR. STARTED RELOADING PROPPANT,
OFFLOADING WATER TO MAKE A DIRTY TRUCK, TO DUMP THE 400 BBL UPRIGHT
FROM ACW.
Report Fluids Summary
Fluid To well (bbl) Cum to Well (bbl)
Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/9/2024 06:00 5/9/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/10/2024 00:00 5/10/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/11/2024 00:00 5/11/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/12/2024 00:00 5/12/2024 23:59 FRAC
Page 2/2
3S-610
Report Printed: 6/21/2024
Daily STIM Report REPORT # [ 10]
REPORT DATE: [ 5/18/2024]
Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/13/2024 00:00 5/13/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/14/2024 00:00 5/14/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/15/2024 00:00 5/15/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/16/2024 00:00 5/16/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/17/2024 00:00 5/17/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/18/2024 00:00 5/18/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/19/2024 00:00 5/19/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/20/2024 00:00 5/20/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/21/2024 00:00 5/21/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/22/2024 00:00 5/22/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/23/2024 00:00 5/23/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/24/2024 00:00 5/24/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/25/2024 00:00 5/25/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/26/2024 00:00 5/26/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/27/2024 00:00 5/27/2024 18:00 FRAC
Page 1/2
3S-610
Report Printed: 6/21/2024
Daily STIM Report REPORT # [ 11]
REPORT DATE: [ 5/19/2024]
API / UWI
5010320875
Original KB/RT Elevation (ft)
63.30
Ground Elevation (ft)
24.30
Original Spud Date
3/9/2024
Primary Job Type
INITIAL COMPLETION
Secondary Job Type
STIMULATION
Total AFE (Cost) AFE / RFE / Maint.#
10441022
Network/Order Number
10441022
AFE+Supp Amt (Cost) Daily Cost Total (Cost)
24,425.29
Cumulative Cost (Cost)
77,102.29
Weather Temperature (°F) Road Condition Wind
Last 24hr Summary
AFTER BLENDER REPAIRS WERE COMPLETED, WE RESTARTED THE FIRST STAGE PLACING A (2 DAY TOTAL) TOTAL OF 292, 979 LB AND 4137 BBL
CLEAN, DROPPED BALL 1 FOR STAGE 2 GOOD SEAT 11 BBL EARLY COMPLETED MINIFRAC, SHUT DOWN FOR 30 MINUTES, WHEN COMING BACK
UP FOR THE TREATMENT A LEAK WAS NOTICED ON THE PUMP IRON,DURING RETEST THIS OCCURRED 2 MORE TIMES. BY THE TIME THE
CORRECTIONS WERE COMPLETED THE BALL HAD COME OFF SEAT, WE WILL RESUME STAGE 2 TOMORROW.
24hr Forecast
frAC STAGES 2-4
General Remarks
IN PROGRESS
ZX Code
ZX02 Fracturing
Contact Name Title Mobile
BECK, BRENT Supervisor 907-616-0445
VAUGHT,RYAN Supervisor 903-721-3182
BRZEZINSKI, NATE Frac Supervisor 814-553-0901
Time Log
Start Time End Time Dur (hr) Phase Activity Code
Time P-
T-X Operation
00:00 06:00 6.00 COMPZN, STIM WAIT T BLENDER REPAIRS,
06:00 15:00 9.00 COMPZN, STIM WAIT T BLENDER REPAIRS,
15:00 16:00 1.00 COMPZN, STIM WAIT P PRIME EQUIPMENT, PRESSURE TEST TO 9431 5 MINUTES DROPPED TO 9362,
GOOD TEST
16:00 16:30 0.50 COMPZN, STIM WAIT P SAFETY MEETING
16:30 17:30 1.00 COMPZN, STIM PUMP P WELL OPEN OPENING PSI 480, RESTARTING STAGE 1 PLANNED FOR 250 K
PROPPANT, STAGE PUMPED TO DESIGN, 251006# 16/20 PLACED MAX RATE 36.4
BPM, AVG RATE 29.9 BPM, AVG PSI 3718, AVG BH PSI 5277, AVG HHP 2706, BALL
LAUNCHED AT 2326 JSV GETTING OUT OF ONE PUMP FOR POSSIBLE COCKED
VALVE BALL ON SEAT11 BBL EARLY
17:30 18:30 1.00 COMPZN, STIM PUMP P BALL ON SEAT @ 2613, 11 BBL EARLY, PUMP KICKED , WALKED RATE UP SLOW
FOR BREAKDOWN, CONTINUED TO MINIFRAC REACHING 34 BPM, SHUT DOWN
FOR PSI MONITORING, WHEN COMING BACK UP WITH RATE A DRIP WAS NOTICED
ON A DOUBLE CHICKSAN OFF A PUMP, WHEN PSI TESTING A LEAK WAS
DISCOVERED ON A SINGLE CHICKSAN ON THE TREATING LINE.
18:30 21:30 3.00 COMPZN, STIM PUMP T CONTINUED IRON REPAIRS, PRESSURE TESTED TO 9500 LB GOOD TEST,OPENED
WELL DISPLACED GEL TUB, HAD LRS PUMP 35 BBL FREEZE PROTECT.
21:30 23:59 2.49 COMPZN, STIM WAIT P RELOADING PROPPANT AND WATER
Report Fluids Summary
Fluid To well (bbl) Cum to Well (bbl)
DIESEL 35.0 35.0
WATER 4,137.0 4,137.0
Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/9/2024 06:00 5/9/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/10/2024 00:00 5/10/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/11/2024 00:00 5/11/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/12/2024 00:00 5/12/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/13/2024 00:00 5/13/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/14/2024 00:00 5/14/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/15/2024 00:00 5/15/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/16/2024 00:00 5/16/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/17/2024 00:00 5/17/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/18/2024 00:00 5/18/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/19/2024 00:00 5/19/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/20/2024 00:00 5/20/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/21/2024 00:00 5/21/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/22/2024 00:00 5/22/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/23/2024 00:00 5/23/2024 23:59 FRAC
Page 2/2
3S-610
Report Printed: 6/21/2024
Daily STIM Report REPORT # [ 11]
REPORT DATE: [ 5/19/2024]
Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/24/2024 00:00 5/24/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/25/2024 00:00 5/25/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/26/2024 00:00 5/26/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/27/2024 00:00 5/27/2024 18:00 FRAC
Page 1/2
3S-610
Report Printed: 6/21/2024
Daily STIM Report REPORT # [ 12]
REPORT DATE: [ 5/20/2024]
API / UWI
5010320875
Original KB/RT Elevation (ft)
63.30
Ground Elevation (ft)
24.30
Original Spud Date
3/9/2024
Primary Job Type
INITIAL COMPLETION
Secondary Job Type
STIMULATION
Total AFE (Cost) AFE / RFE / Maint.#
10441022
Network/Order Number
10441022
AFE+Supp Amt (Cost) Daily Cost Total (Cost)
182,119.59
Cumulative Cost (Cost)
259,221.88
Weather Temperature (°F) Road Condition Wind
Last 24hr Summary
PERFORM SRT UP TO 20 BPM.
STIMULATE STAGE #2 PER DESIGN w/ 3,726 LBS OF 100 MESH & 294,366 LBS OF 16/20 PROPPANT UP TO 7.20 PPG. HAD TO FLUSH THE WELL DUE
TO A LEAK THAT DEVELOPED ON THE EPRV MANIFOLD. ALSO HAD TO BREAK INTO 3 PUMPS THAT WERE ACTING UP DURING FLUSH. DISCOVERED
ROCKS IN ALL 3 PUMPS. IN PROGRESS
24hr Forecast
PERFORM PUMP MAINT. RELOAD WATER & SAND. PUMP STAGES 3 & 4
General Remarks
IN PROGRESS
ZX Code
ZX02 Fracturing
Contact Name Title Mobile
BECK, BRENT Supervisor 907-616-0445
LUSTER, CHOICE Supervisor
BRZEZINSKI, NATE Frac Supervisor 814-553-0901
Time Log
Start Time End Time Dur (hr) Phase Activity Code
Time P-
T-X Operation
00:00 06:00 6.00 COMPZN, STIM WAIT P NIGHT . LOAD WATER, SAND & PUMP MAINT.
06:00 08:45 2.75 COMPZN, STIM WAIT P ARRIVE ON LOCATION. SIM OPS WIT D142 RIG & PREP EQUIPMENT FOR PT
08:45 10:00 1.25 COMPZN, STIM WAIT P PRIME UP PUMPS. TEST POP OFFS & EPRV'S. PT TREATING LINE TO 9500 PSI.
PASS.
10:00 10:15 0.25 COMPZN, STIM WAIT P SAFETY MEETING WITH ALL INVOLVED PARTIES
10:15 11:00 0.75 COMPZN, STIM WAIT P FLOOD WATER & CHEM LINES. START MIXING GEL
LOAD STAGE #2 BALL (2.116" OD BALL / 2.094" ID SEAT)
LOAD STAGE #3 BALL (2.148" OD BALL / 2.123" ID SEAT)
VERIFY VALVES ARE LINED UP READY TO PUMP DOWNHOLE.
11:00 12:45 1.75 COMPZN, STIM PUMP P OPEN SWAB & COME ONLINE. PUMPED SRT UP TO 20 BPM. ESTABLISH STABLE
FLUID AND BEGIN STAGE.
INTERVAL - #2
SEAT SLURRY VOLUME (BBL) -
DART SEAT SLURRY VOLUME (BBL) - (SEE SHIFT 34 BBLS EARLY)
SURFACE SLV DIFF SHIFT PRESSURE (PSI) = PSI
TOTAL STAGE CLEAN VOLUME (BBLS) - 4663
TOTAL PROPPANT PLACED (LBS) - 298,092
100 MESH (LBS) - 3726
16/20 (LBS) - 294,366
MAX PROP CONC (PPG) - 7.20
AVERAGE SURFACE (PSI) - 3733
AVG BHP (PSI) 5331
AVG RATE (BPM) - 24.5
12:45 13:00 0.25 COMPZN, STIM PUMP P DROPPED STAGE #3 BALL. SLOW DOWN 30 BBLS OUT. SEE BIG WATER HAMMER
BUT DO NOT SEE BALL SEAT.
13:00 13:30 0.50 COMPZN, STIM PUMP P HAD TO FLUSH THE WELL DUE TO A LEAK THAT DEVELOPED ON THE EPRV
MANIFOLD. ALSO HAD TO BREAK INTO 3 PUMPS THAT WERE ACTING UP DURING
FLUSH. DISCOVERED ROCKS IN ALL 3 PUMPS.
13:30 16:30 3.00 COMPZN, STIM WAIT P BLOW DOWN LINES AND FREEZE PROTECT THE WELL.
16:30 23:59 7.49 COMPZN, STIM WAIT P LOAD WATER, SAND & PERFORM REMAINING PUMP MAINTENANCE.
Report Fluids Summary
Fluid To well (bbl) Cum to Well (bbl)
DIESEL 35.0 70.0
WATER 4,663.0 8,800.0
Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/9/2024 06:00 5/9/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/10/2024 00:00 5/10/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/11/2024 00:00 5/11/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/12/2024 00:00 5/12/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/13/2024 00:00 5/13/2024 23:59 FRAC
Page 2/2
3S-610
Report Printed: 6/21/2024
Daily STIM Report REPORT # [ 12]
REPORT DATE: [ 5/20/2024]
Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/14/2024 00:00 5/14/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/15/2024 00:00 5/15/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/16/2024 00:00 5/16/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/17/2024 00:00 5/17/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/18/2024 00:00 5/18/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/19/2024 00:00 5/19/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/20/2024 00:00 5/20/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/21/2024 00:00 5/21/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/22/2024 00:00 5/22/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/23/2024 00:00 5/23/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/24/2024 00:00 5/24/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/25/2024 00:00 5/25/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/26/2024 00:00 5/26/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/27/2024 00:00 5/27/2024 18:00 FRAC
Page 1/2
3S-610
Report Printed: 6/21/2024
Daily STIM Report REPORT # [ 13]
REPORT DATE: [ 5/21/2024]
API / UWI
5010320875
Original KB/RT Elevation (ft)
63.30
Ground Elevation (ft)
24.30
Original Spud Date
3/9/2024
Primary Job Type
INITIAL COMPLETION
Secondary Job Type
STIMULATION
Total AFE (Cost) AFE / RFE / Maint.#
10441022
Network/Order Number
10441022
AFE+Supp Amt (Cost) Daily Cost Total (Cost)
263,764.49
Cumulative Cost (Cost)
522,986.37
Weather Temperature (°F) Road Condition Wind
Last 24hr Summary
STIMULATE STAGES #3, 4 & 5 PER DESIGN. PLACED A TOTAL OF 906,112 LBS OF PROPPANT WITH 9486 BBLS CLEAN VOLUME. IN PROGRESS
24hr Forecast
General Remarks
INITIAL T/I/O=388/0/20
FINAL T/I/O= 1225/700/490
ZX Code
ZX02 Fracturing
Contact Name Title Mobile
BECK, BRENT Supervisor 907-616-0445
LUSTER, CHOICE Supervisor
BRZEZINSKI, NATE Frac Supervisor 814-553-0901
Time Log
Start Time End Time Dur (hr) Phase Activity Code
Time P-
T-X Operation
00:00 06:00 6.00 COMPZN, STIM WAIT P NIGHT CREWS RELOADED WATER & SAND. HAL PERFORMED PUMP
MAINTENANCE AND PREPPED EQUIPMENT TO PUMP IN THE MORNING.
06:00 07:00 1.00 COMPZN, STIM WAIT P CHANGE OUT WITH NIGHT CREW. SIM OPS WITH THE RIG. FIRE UP EQUIPMENT IN
PREPERATION TO PRESSURE TEST.
07:00 07:45 0.75 COMPZN, STIM WAIT P PRIME UP PUMPS. TEST POP OFFS & PRESSURE TEST IRON TO 9500 PSI **PASS**
07:45 08:00 0.25 COMPZN, STIM WAIT P SAFETY MEETING WITH ALL INVOLVED PARTIES
08:00 08:30 0.50 COMPZN, STIM WAIT P FLOOD WATER & CHEM LINES. START MIXING GEL. VERIFY VALVES ARE LINED UP
TO GO DOWN HOLE
LOAD STAGE #3 BALL (2.148" OD BALL / 2.123" ID SEAT)
LOAD STAGE #4 BALL (2.181" OD BALL / 2.158" ID SEAT)
LOAD STAGE #5 BALL (2.214" OD BALL / 2.191" ID SEAT)
08:30 10:00 1.50 COMPZN, STIM PUMP P OPEN WELL & LAUNCH STAGE #3 BACK UP BALL. BALL ON SEAT & BEGIN STAGE.
BASE FLUID IS SEAWATER ON THIS STAGE.
INTERVAL - #3
SEAT SLURRY VOLUME (BBL) - 324
DART SEAT SLURRY VOLUME (BBL) - 312 (SEE SHIFT 12 BBLS EARLY)
SURFACE SLV DIFF SHIFT PRESSURE (PSI) = 2038 PSI
TOTAL STAGE CLEAN VOLUME (BBLS) - 3530
TOTAL PROPPANT PLACED (LBS) - 304,360
100 MESH (LBS) - 4356
16/20 (LBS) - 300,004
MAX PROP CONC (PPG) - 7.50
AVERAGE SURFACE (PSI) - 3989
AVG BHP (PSI) 5488
AVG RATE (BPM) - 27.8
10:00 13:00 3.00 COMPZN, STIM PUMP P LAUNCH STAGE #4 BALL. SEE BALL SEAT, BUT SLEEVE DID NOT SHIFT.
MANIPULATE PRESSURES FOR ~2 HOURS AND REGAIN INJECTION UP TO 13 BPM.
SHUT DOWN AND LOAD BACK UP BALL FOR STAGE #4. DID NOT SEE 2ND BALL
SEAT. DISCUSS WITH ENGINEER AND WE ARE ASSUMING THE 1ST BALL IS
HOLDING AND CONTINUE PUMPING STAGE #4
13:00 14:30 1.50 COMPZN, STIM PUMP P INTERVAL - #4
SEAT SLURRY VOLUME (BBL) - 3436
DART SEAT SLURRY VOLUME (BBL) - 3429 (SEAT 7 BBLS EARLY)
SURFACE SLV DIFF SHIFT PRESSURE (PSI) = N/A
TOTAL STAGE CLEAN VOLUME (BBLS) - 3229
TOTAL PROPPANT PLACED (LBS) - 300,958
100 MESH (LBS) - 3641
16/20 (LBS) - 297,317
MAX PROP CONC (PPG) - 6.75
AVERAGE SURFACE (PSI) - 3968
AVG BHP (PSI) 5449
AVG RATE (BPM) - 33.2
Page 2/2
3S-610
Report Printed: 6/21/2024
Daily STIM Report REPORT # [ 13]
REPORT DATE: [ 5/21/2024]
Time Log
Start Time End Time Dur (hr) Phase Activity Code
Time P-
T-X Operation
14:30 15:45 1.25 COMPZN, STIM PUMP P LAUNCH STAGE #5 BALL.
INTERVAL - #5
SEAT SLURRY VOLUME (BBL) - 6980
DART SEAT SLURRY VOLUME (BBL) - 6968 (SEE SHIFT 12 BBLS EARLY)
SURFACE SLV DIFF SHIFT PRESSURE (PSI) = 3633 PSI
TOTAL STAGE CLEAN VOLUME (BBLS) - 2727
TOTAL PROPPANT PLACED (LBS) - 300,804
100 MESH (LBS) - 4246
16/20 (LBS) - 296,558
MAX PROP CONC (PPG) - 7.08
AVERAGE SURFACE (PSI) - 4550
AVG BHP (PSI) 6028
AVG RATE (BPM) - 34.2
15:45 16:00 0.25 COMPZN, STIM PUMP P FLUSH WELL. SHUT DOWN & MONITOR FOR 15 MIN.
16:00 18:00 2.00 COMPZN, STIM WAIT P SHUT IN WELL. BLEED DOWN THE IA. BEGIN BLOWING DOW LINES. FREEZE
PROTECT THE WELL WITH 35 BBLS
18:00 23:59 5.99 COMPZN, STIM WAIT P NIGHT CREWS - RELOAD WATER, SAND & PUMP MAINTENANCE.
Report Fluids Summary
Fluid To well (bbl) Cum to Well (bbl)
DIESEL 35.0 105.0
SEAWATER 3,530.0 3,530.0
WATER 5,956.0 14,756.0
Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/9/2024 06:00 5/9/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/10/2024 00:00 5/10/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/11/2024 00:00 5/11/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/12/2024 00:00 5/12/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/13/2024 00:00 5/13/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/14/2024 00:00 5/14/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/15/2024 00:00 5/15/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/16/2024 00:00 5/16/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/17/2024 00:00 5/17/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/18/2024 00:00 5/18/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/19/2024 00:00 5/19/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/20/2024 00:00 5/20/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/21/2024 00:00 5/21/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/22/2024 00:00 5/22/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/23/2024 00:00 5/23/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/24/2024 00:00 5/24/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/25/2024 00:00 5/25/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/26/2024 00:00 5/26/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/27/2024 00:00 5/27/2024 18:00 FRAC
Page 1/1
3S-610
Report Printed: 6/21/2024
Daily STIM Report REPORT # [ 14]
REPORT DATE: [ 5/22/2024]
API / UWI
5010320875
Original KB/RT Elevation (ft)
63.30
Ground Elevation (ft)
24.30
Original Spud Date
3/9/2024
Primary Job Type
INITIAL COMPLETION
Secondary Job Type
STIMULATION
Total AFE (Cost) AFE / RFE / Maint.#
10441022
Network/Order Number
10441022
AFE+Supp Amt (Cost) Daily Cost Total (Cost)
2,500.00
Cumulative Cost (Cost)
525,486.37
Weather Temperature (°F) Road Condition Wind
Last 24hr Summary
RELOAD SAND & WATER. PERFORM EQUIPMENT MAINTENANCE. HALLIBURTON CREW CHANGE.
24hr Forecast
PUMP STAGES 6 - 8
General Remarks
ZX Code
ZX02 Fracturing
Contact Name Title Mobile
BECK, BRENT Supervisor 907-616-0445
LUSTER, CHOICE Supervisor
GAMEZ, ABDON Frac Supervisor 956-598-3108
Time Log
Start Time End Time Dur (hr) Phase Activity Code
Time P-
T-X Operation
00:00 23:59 23.99 COMPZN, STIM WAIT P RELOADED SAND & WATER. PERFORM EQUIPMENT MAINTENANCE. HALLIBURTON
CREW CHANGE.
Report Fluids Summary
Fluid To well (bbl) Cum to Well (bbl)
DIESEL 105.0
SEAWATER 3,530.0
WATER 9,712.0 24,468.0
Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/9/2024 06:00 5/9/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/10/2024 00:00 5/10/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/11/2024 00:00 5/11/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/12/2024 00:00 5/12/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/13/2024 00:00 5/13/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/14/2024 00:00 5/14/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/15/2024 00:00 5/15/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/16/2024 00:00 5/16/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/17/2024 00:00 5/17/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/18/2024 00:00 5/18/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/19/2024 00:00 5/19/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/20/2024 00:00 5/20/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/21/2024 00:00 5/21/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/22/2024 00:00 5/22/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/23/2024 00:00 5/23/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/24/2024 00:00 5/24/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/25/2024 00:00 5/25/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/26/2024 00:00 5/26/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/27/2024 00:00 5/27/2024 18:00 FRAC
Page 1/2
3S-610
Report Printed: 6/21/2024
Daily STIM Report REPORT # [ 15]
REPORT DATE: [ 5/23/2024]
API / UWI
5010320875
Original KB/RT Elevation (ft)
63.30
Ground Elevation (ft)
24.30
Original Spud Date
3/9/2024
Primary Job Type
INITIAL COMPLETION
Secondary Job Type
STIMULATION
Total AFE (Cost) AFE / RFE / Maint.#
10441022
Network/Order Number
10441022
AFE+Supp Amt (Cost) Daily Cost Total (Cost)
273,645.93
Cumulative Cost (Cost)
799,132.30
Weather Temperature (°F) Road Condition Wind
Last 24hr Summary
PERFORMED SRT UP TO 15 BPM
FRAC STAGES #6, 7 & 8 PER DESIGN w/ A TOTAL OF 914,505 LBS OF PROPPANT w/ 9,375 BBLS CLEAN VOLUME. IN PROGRESS
24hr Forecast
RELOAD WATER, SAND & CHEMS. PUMP STAGES 9 - 12 DEPENDING ON WATER RELOAD.
General Remarks
INITIAL T/I/O=350/0/0
FINAL T/I/O=1100/700/400
ZX Code
ZX02 Fracturing
Contact Name Title Mobile
BECK, BRENT Supervisor 907-616-0445
LUSTER, CHOICE Supervisor
GAMEZ, ABDON Frac Supervisor 956-598-3108
Time Log
Start Time End Time Dur (hr) Phase Activity Code
Time P-
T-X Operation
00:00 06:00 6.00 COMPZN, STIM WAIT P NIGHT CREWS RELOAD WATER & SAND. PUMP MAINTENANCE IN PREPERATION
FOR AM RESTART.
06:00 08:00 2.00 COMPZN, STIM WAIT P ARRIVE ON LOC. SIM OPS WITH RIG. FIRE UP EQUIPMENT IN PREPERATION TO
PRESSURE TEST.
08:00 09:00 1.00 COMPZN, STIM WAIT P PRIME UP PUMPS. TEST POP OFFS & PRESSURE TEST IRON TO 9500 PSI **PASS**
09:00 09:15 0.25 COMPZN, STIM WAIT P SAFETY MEETING WITH ALL INVOLVED PARTIES
09:15 10:00 0.75 COMPZN, STIM WAIT P FLOOD WATER & CHEM LINES. START MIXING GEL
LOAD STAGE #6 BALL (2.247" OD BALL / 2.224" ID SEAT)
LOAD STAGE #7 BALL (2.280" OD BALL / 2.257" ID SEAT)
LOAD STAGE #8 BALL (2.314" OD BALL / 2.290" ID SEAT)
WALK LINES & VERIFY THEY ARE LINED UP TO GO DOWN HOLE.
10:00 10:30 0.50 COMPZN, STIM PUMP P OPEN THE WELL. LAUNCH STAGE #6 BALL & DISP WITH LINEAR GEL. SEE BALL
SEAT. HAD TO SHUT DOWN PUMP DUE TO MAX PRESSURE AND SLEEVE SHIFTED.
SHUT DOWN AND ZERO MAG METER ON BLENDER.
10:30 11:30 1.00 COMPZN, STIM WAIT T COME ONLINE AND PERFORM SRT UP TO 15 BPM. BEGIN MAKING FLUID & WAS
UNABLE TO GET PH TO INCREASE. SWAPPED TOTES OF MO-67 AND WAS ABLE TO
GET PH UP. DURING PAD, ENCOUNTER ISSUE WITH ADP & HAD TO FLUSH. TOTAL
FLUID PUMPED DURING NPT WAS 1100 BBLS.
11:30 13:00 1.50 COMPZN, STIM PUMP P MIX A NEW TUB OF GEL & COME ONLINE
INTERVAL - #6
SEAT SLURRY VOLUME (BBL) - 271
DART SEAT SLURRY VOLUME (BBL) - 283 (SEE SHIFT 12 BBLS LATE) MAG METER
ON BLENDER NEEDED TO BE ZEROED.
SURFACE SLV DIFF SHIFT PRESSURE (PSI) = 5693PSI
TOTAL STAGE CLEAN VOLUME (BBLS) - 4265
TOTAL PROPPANT PLACED (LBS) - 309,448
100 MESH (LBS) - 3697
16/20 (LBS) - 305,751
MAX PROP CONC (PPG) - 7.1
AVERAGE SURFACE (PSI) - 3733
AVG BHP (PSI) 5178
AVG RATE (BPM) - 33.6
Page 2/2
3S-610
Report Printed: 6/21/2024
Daily STIM Report REPORT # [ 15]
REPORT DATE: [ 5/23/2024]
Time Log
Start Time End Time Dur (hr) Phase Activity Code
Time P-
T-X Operation
13:00 15:15 2.25 COMPZN, STIM PUMP P LAUNCH STAGE #7 BALL. GOOD SHIFT
INTERVAL - #7
SEAT SLURRY VOLUME (BBL) - 4833
DART SEAT SLURRY VOLUME (BBL) - 4832 (SEE SHIFT 1 BBLS EARLY)
SURFACE SLV DIFF SHIFT PRESSURE (PSI) = 2917 PSI
TOTAL STAGE CLEAN VOLUME (BBLS) - 2445
TOTAL PROPPANT PLACED (LBS) - 301,256
100 MESH (LBS) - 3879
16/20 (LBS) - 297,377
MAX PROP CONC (PPG) - 7.38
AVERAGE SURFACE (PSI) - 3600
AVG BHP (PSI) 5074
AVG RATE (BPM) - 34.7
15:15 16:30 1.25 COMPZN, STIM PUMP P LAUNCH STAGE #8 BALL. GOOD SHIFT
INTERVAL - #8
SEAT SLURRY VOLUME (BBL) - 7609
DART SEAT SLURRY VOLUME (BBL) - 7608 (SEE SHIFT 1 BBLS EARLY)
SURFACE SLV DIFF SHIFT PRESSURE (PSI) = 4224 PSI
TOTAL STAGE CLEAN VOLUME (BBLS) - 2665
TOTAL PROPPANT PLACED (LBS) - 303,751
100 MESH (LBS) - 3906
16/20 (LBS) - 299,845
MAX PROP CONC (PPG) - 7.03
AVERAGE SURFACE (PSI) - 3616
AVG BHP (PSI) 5105
AVG RATE (BPM) - 35.6
16:30 17:00 0.50 COMPZN, STIM PUMP P FLUSH WELL & SHUT DOWN. MONITOR WELL PRESSURE FOR 15 MIN & SHUT IN
THE WELL
17:00 18:30 1.50 COMPZN, STIM WAIT P BLOW DOWN LINES, BLEED IA DOWN TO 700 PSI & FREEZE PROTECT WELL WITH
35 BBLS OF DIESEL
18:30 23:59 5.49 COMPZN, STIM WAIT P NIGHT CREWS RELOADED SAND & WATER. PERFORMED PUMP MAINTENANCE &
RELOADED CHEMS.
23:59 23:59 COMPZN, STIM
Report Fluids Summary
Fluid To well (bbl) Cum to Well (bbl)
DIESEL 35.0 140.0
SEAWATER 3,530.0
WATER 12,672.0 37,140.0
Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/9/2024 06:00 5/9/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/10/2024 00:00 5/10/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/11/2024 00:00 5/11/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/12/2024 00:00 5/12/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/13/2024 00:00 5/13/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/14/2024 00:00 5/14/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/15/2024 00:00 5/15/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/16/2024 00:00 5/16/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/17/2024 00:00 5/17/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/18/2024 00:00 5/18/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/19/2024 00:00 5/19/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/20/2024 00:00 5/20/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/21/2024 00:00 5/21/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/22/2024 00:00 5/22/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/23/2024 00:00 5/23/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/24/2024 00:00 5/24/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/25/2024 00:00 5/25/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/26/2024 00:00 5/26/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/27/2024 00:00 5/27/2024 18:00 FRAC
Page 1/3
3S-610
Report Printed: 6/21/2024
Daily STIM Report REPORT # [ 16]
REPORT DATE: [ 5/24/2024]
API / UWI
5010320875
Original KB/RT Elevation (ft)
63.30
Ground Elevation (ft)
24.30
Original Spud Date
3/9/2024
Primary Job Type
INITIAL COMPLETION
Secondary Job Type
STIMULATION
Total AFE (Cost) AFE / RFE / Maint.#
10441022
Network/Order Number
10441022
AFE+Supp Amt (Cost) Daily Cost Total (Cost)
291,825.56
Cumulative Cost (Cost)
1,090,957.86
Weather Temperature (°F) Road Condition Wind
Last 24hr Summary
FRAC STAGES #9 - #13 PER DESIGN w/ A TOTAL OF 1,032,446 LBS OF PROPPANT w/ 8,798 BBLS CLEAN VOLUME. IN PROGRESS
24hr Forecast
RELOAD WATER, SAND, GEL & CHEMS. PUMP STAGES 14 - 18.
General Remarks
INITIAL T/I/O=250/0/0
FINAL T/I/O=1100700550
ZX Code
ZX02 Fracturing
Contact Name Title Mobile
BECK, BRENT Supervisor 907-616-0445
LUSTER, CHOICE Supervisor
GAMEZ, ABDON Frac Supervisor 956-598-3108
Time Log
Start Time End Time Dur (hr) Phase Activity Code
Time P-
T-X Operation
00:00 06:00 6.00 COMPZN, STIM WAIT P NIGHT SHIFTS - LOADED PW WATER & SAND. HAL NIGHT CREWS PERFORMED
PUMP MAINTENANCE
06:00 09:30 3.50 COMPZN, STIM WAIT P ARRIVE ON LOCATION & CHECK IN WITH THE RIG. CONTINUE FLOWING WATER
UNTIL WE HAVE ENOUGH USABLE WATER ON LOCATION. DUE TO LACK OF
LOADER SUPPORT DURING NIGHT SHIFT SEND GUYS TO LOAD CHEMS @ 3F-PAD
09:30 10:00 0.50 COMPZN, STIM WAIT P CHEMS ON LOCATION & BEGIN TESTING NEW CHEMS. GOOD ON USABLE WATER.
CHEM TEST COMPLETE.
10:00 10:45 0.75 COMPZN, STIM WAIT P BRING ON WATER & BEGING PRIME UP PUMPS. TEST POP OFFS & PRESSURE
TEST IRON TO 9500 PSI **PASS**
10:45 11:00 0.25 COMPZN, STIM WAIT P SAFETY MEETING WITH ALL PARTIES
11:00 11:30 0.50 COMPZN, STIM WAIT P BRING ON CHEM LINES. START MIXING GEL
LOAD STAGE #9 BALL (2.348" OD BALL / 2.324" ID SEAT)
LOAD STAGE #10 BALL (2.383" OD BALL / 2.358" ID SEAT)
LOAD STAGE #11 BALL (2.418" OD BALL / 2.393" ID SEAT)
LOAD STAGE #12 BALL (2.453" OD BALL / 2.428" ID SEAT)
LOAD STAGE #13 BALL (2.489" OD BALL / 2.463" ID SEAT)
WALK LINES & VERIFY THEY ARE LINED UP TO GO DOWN HOLE.
11:30 13:00 1.50 COMPZN, STIM PUMP P OPEN WELL & LAUNCH STAGE #9. GOOD SHIFT
INTERVAL - #9
SEAT SLURRY VOLUME (BBL) - 244
DART SEAT SLURRY VOLUME (BBL) - 232 (SEE SHIFT 12 BBLS EARLY)
SURFACE SLV DIFF SHIFT PRESSURE (PSI) = 3169 PSI
TOTAL STAGE CLEAN VOLUME (BBLS) - 1928
TOTAL PROPPANT PLACED (LBS) - 205,339
100 MESH (LBS) - 4239
16/20 (LBS) - 201,100
MAX PROP CONC (PPG) - 7.16
AVERAGE SURFACE (PSI) - 3272
AVG BHP (PSI) 4665
AVG RATE (BPM) - 34.9
13:00 13:45 0.75 COMPZN, STIM PUMP P LAUNCH STAGE #10 BALL.GOOD SHIFT
INTERVAL - #10
SEAT SLURRY VOLUME (BBL) - 2280
DART SEAT SLURRY VOLUME (BBL) - 2273 (SEE SHIFT 7 BBLS EARLY)
SURFACE SLV DIFF SHIFT PRESSURE (PSI) = 2907 PSI
TOTAL STAGE CLEAN VOLUME (BBLS) - 1688
TOTAL PROPPANT PLACED (LBS) - 207,815
100 MESH (LBS) - 3538
16/20 (LBS) - 204,227
MAX PROP CONC (PPG) - 7.56
AVERAGE SURFACE (PSI) - 3102
AVG BHP (PSI) 4573
AVG RATE (BPM) - 35.0
Page 2/3
3S-610
Report Printed: 6/21/2024
Daily STIM Report REPORT # [ 16]
REPORT DATE: [ 5/24/2024]
Time Log
Start Time End Time Dur (hr) Phase Activity Code
Time P-
T-X Operation
13:45 14:45 1.00 COMPZN, STIM PUMP P LAUNCH STAGE #11 BALL. GOOD SHIFT
INTERVAL - #11
SEAT SLURRY VOLUME (BBL) - 4178
DART SEAT SLURRY VOLUME (BBL) - 4176 (SEE SHIFT 2 BBLS EARLY)
SURFACE SLV DIFF SHIFT PRESSURE (PSI) = 2879 PSI
TOTAL STAGE CLEAN VOLUME (BBLS) - 1646
TOTAL PROPPANT PLACED (LBS) -
100 MESH (LBS) - 3119
16/20 (LBS) - 202,282
MAX PROP CONC (PPG)- 7.18
AVERAGE SURFACE (PSI) - 3528
AVG BHP (PSI) 4978
AVG RATE (BPM) - 35.0
14:45 15:30 0.75 COMPZN, STIM PUMP P LAUNCH STAGE #12 BALL
INTERVAL - #12
SEAT SLURRY VOLUME (BBL) - 6035
DART SEAT SLURRY VOLUME (BBL) - 6027 (SEE SHIFT BBLS EARLY)
SURFACE SLV DIFF SHIFT PRESSURE (PSI) = 3689 PSI
TOTAL STAGE CLEAN VOLUME (BBLS) - 1700
TOTAL PROPPANT PLACED (LBS) - 207,885
100 MESH (LBS) - 3621
16/20 (LBS) - 204,264
MAX PROP CONC (PPG) - 7.07
AVERAGE SURFACE (PSI) - 3243
AVG BHP (PSI) 4738
AVG RATE (BPM) - 35.5
15:30 16:45 1.25 COMPZN, STIM PUMP P LAUNCH BALL #13
INTERVAL - #13
SEAT SLURRY VOLUME (BBL) - 7941
DART SEAT SLURRY VOLUME (BBL) - 7928 (SEE SHIFT 13 BBLS EARLY)
SURFACE SLV DIFF SHIFT PRESSURE (PSI) = 1474 PSI
TOTAL STAGE CLEAN VOLUME (BBLS) - 1836
TOTAL PROPPANT PLACED (LBS) - 206,006
100 MESH (LBS) - 4147
16/20 (LBS) - 201,859
MAX PROP CONC (PPG) - 7.14
AVERAGE SURFACE (PSI) - 3176
AVG BHP (PSI) 4609
AVG RATE (BPM) - 36.7
FLUSH WELL & MONITOR DHG FOR 15 MIN.
16:45 18:00 1.25 COMPZN, STIM WAIT P CLOSE WELL & BLOW DOWN LINES & BLEED DOWN THE IA. RU LRS ON TUBING
AND PUMP 35 BBL DSL FREEZE PROTECT.
18:00 23:59 5.99 COMPZN, STIM WAIT P NIGHT CREWS WILL RELOAD SAND & TREAT PW WATER. HAL NIGHT SHIFT LOAD
GEL, CHEMS & BREAK INTO A FEW PUMPS.
23:59 23:59 COMPZN, STIM
Report Fluids Summary
Fluid To well (bbl) Cum to Well (bbl)
DIESEL 35.0 175.0
SEAWATER 3,530.0
WATER 15,391.0 52,531.0
Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/9/2024 06:00 5/9/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/10/2024 00:00 5/10/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/11/2024 00:00 5/11/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/12/2024 00:00 5/12/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/13/2024 00:00 5/13/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/14/2024 00:00 5/14/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/15/2024 00:00 5/15/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/16/2024 00:00 5/16/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/17/2024 00:00 5/17/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/18/2024 00:00 5/18/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/19/2024 00:00 5/19/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/20/2024 00:00 5/20/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/21/2024 00:00 5/21/2024 23:59 FRAC
Page 3/3
3S-610
Report Printed: 6/21/2024
Daily STIM Report REPORT # [ 16]
REPORT DATE: [ 5/24/2024]
Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/22/2024 00:00 5/22/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/23/2024 00:00 5/23/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/24/2024 00:00 5/24/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/25/2024 00:00 5/25/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/26/2024 00:00 5/26/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/27/2024 00:00 5/27/2024 18:00 FRAC
Page 1/2
3S-610
Report Printed: 6/21/2024
Daily STIM Report REPORT # [ 17]
REPORT DATE: [ 5/25/2024]
API / UWI
5010320875
Original KB/RT Elevation (ft)
63.30
Ground Elevation (ft)
24.30
Original Spud Date
3/9/2024
Primary Job Type
INITIAL COMPLETION
Secondary Job Type
STIMULATION
Total AFE (Cost) AFE / RFE / Maint.#
10441022
Network/Order Number
10441022
AFE+Supp Amt (Cost) Daily Cost Total (Cost)
168,025.19
Cumulative Cost (Cost)
1,258,983.05
Weather Temperature (°F) Road Condition Wind
Last 24hr Summary
PERFORM SRT UP TO 12 BPM
FRAC STAGES #14 - #17 PER DESIGN w/ A TOTAL OF 581,000 LBS OF PROPPANT w/ 5697 BBLS CLEAN VOLUME. IN PROGRESS
24hr Forecast
RELOAD WATER, SAND, GEL & CHEMS. PUMP STAGES 18 - 21.
General Remarks
INITIAL T/I/O=150/0/0
FINAL T/I/O=895/700/600
ZX Code
ZX02 Fracturing
Contact Name Title Mobile
BECK, BRENT Supervisor 907-616-0445
CAMPBELL, JAMES Frac Supervisor 661-203-1472
LUSTER, CHOICE Supervisor
Time Log
Start Time End Time Dur (hr) Phase Activity Code
Time P-
T-X Operation
00:00 06:00 6.00 COMPZN, STIM WAIT P NIGHT CREWS CONT. LOADING SAND, WATER, GEL & CHEMS. PREP EQUIPMENT
TO PUMP IN THE MORNING.
06:00 09:00 3.00 COMPZN, STIM WAIT P ARRIVE ON LOCATION. SIM OPS WITH RIG. FIRE UP EQUIPMENT AND PREPARE TO
PT.
09:00 10:00 1.00 COMPZN, STIM WAIT P CONTINUE FLOWING WATER. PRIME UP PUMPS. TEST POP OFFS & PRESSURE
TEST IRON TO 9500 PSI **PASS**
10:00 10:15 0.25 COMPZN, STIM WAIT P SAFETY MEETING WITH ALL INVOLVED PARTIES
10:15 10:45 0.50 COMPZN, STIM WAIT P FLOOD CHEM LINES. START MIXING GEL
LOAD STAGE #14 BALL (2.525" OD BALL / 2.499" ID SEAT)
LOAD STAGE #15 BALL (2.561" OD BALL / 2.535" ID SEAT)
LOAD STAGE #16 BALL (2.598" OD BALL / 2.571" ID SEAT)
LOAD STAGE #17 BALL (2.635" OD BALL / 2.608" ID SEAT)
LOAD STAGE #18 BALL (2.672" OD BALL / 2.645" ID SEAT)
WALK LINES & VERIFY THEY ARE LINED UP TO GO DOWN HOLE.
10:45 11:45 1.00 COMPZN, STIM PUMP P LAUNCH STAGE #14 BALL & CHASE WITH FRAC. DID NOT SEE BALL SEAT. GO
THROUGH LAUUCH SEQUENCE AGAIN AND PUMP WITH ACID PUMP AND HEAR
BALL. SEE GOOD SHIFT @ CORRECT DISP VOLUME. SHUT DOWN & PERFORM A
SRT f/ 1 BPM TO 12 BPM.
11:45 12:30 0.75 COMPZN, STIM PUMP P BRING RATE UP TO 15 BPM & ESTABLISH STABLE FLUID
INTERVAL - #14
SEAT SLURRY VOLUME (BBL) - 537
DART SEAT SLURRY VOLUME (BBL) - 530 (SEE SHIFT 7 BBLS EARLY)
SURFACE SLV DIFF SHIFT PRESSURE (PSI) = 2010 PSI
TOTAL STAGE CLEAN VOLUME (BBLS) - 2000
TOTAL PROPPANT PLACED (LBS) - 145,374
100 MESH (LBS) - 3497
16/20 (LBS) - 144,877
MAX PROP CONC (PPG) - 6.82
AVERAGE SURFACE (PSI) - 2672
AVG BHP (PSI) 4128
AVG RATE (BPM) - 34.7
12:30 13:15 0.75 COMPZN, STIM PUMP P LAUNCH STAGE #15 BALL. GOOD SHIFT
INTERVAL - #15
SEAT SLURRY VOLUME (BBL) - 2264
DART SEAT SLURRY VOLUME (BBL) - 2262 (SEE SHIFT 2 BBLS EARLY)
SURFACE SLV DIFF SHIFT PRESSURE (PSI) = 2901 PSI
TOTAL STAGE CLEAN VOLUME (BBLS) - 1173
TOTAL PROPPANT PLACED (LBS) - 143,361
100 MESH (LBS) - 3780
16/20 (LBS) - 139,780
MAX PROP CONC (PPG) - 7.31
AVERAGE SURFACE (PSI) - 3325
AVG BHP (PSI) 4800
AVG RATE (BPM) - 31.2
Page 2/2
3S-610
Report Printed: 6/21/2024
Daily STIM Report REPORT # [ 17]
REPORT DATE: [ 5/25/2024]
Time Log
Start Time End Time Dur (hr) Phase Activity Code
Time P-
T-X Operation
13:15 14:00 0.75 COMPZN, STIM PUMP P LAUNCH STAGE #16 BALL. GOOD SHIFT
INTERVAL - #16
SEAT SLURRY VOLUME (BBL) - 3581
DART SEAT SLURRY VOLUME (BBL) - 3575 (SEE SHIFT 6 BBLS EARLY)
SURFACE SLV DIFF SHIFT PRESSURE (PSI) = 3030 PSI
TOTAL STAGE CLEAN VOLUME (BBLS) - 1171
TOTAL PROPPANT PLACED (LBS) - 144,092
100 MESH (LBS) - 4016
16/20 (LBS) - 140,076
MAX PROP CONC (PPG) - 7.13
AVERAGE SURFACE (PSI) - 2613
AVG BHP (PSI) 4130
AVG RATE (BPM) - 34.0
14:00 15:00 1.00 COMPZN, STIM PUMP P LAUNCH STAGE #17 BALL.
INTERVAL - #17
SEAT SLURRY VOLUME (BBL) - 4898
DART SEAT SLURRY VOLUME (BBL) - 4892 (SEE SHIFT 6 BBLS EARLY)
SURFACE SLV DIFF SHIFT PRESSURE (PSI) = 2317 PSI
TOTAL STAGE CLEAN VOLUME (BBLS) - 1353
TOTAL PROPPANT PLACED (LBS) - 144,974
100 MESH (LBS) - 3971
16/20 (LBS) - 141,003
MAX PROP CONC (PPG) - 7.08
AVERAGE SURFACE (PSI) - 2649
AVG BHP (PSI) 4168
AVG RATE (BPM) - 34.9
FLUSH WELL & SHUT DOWN. MONITOR PRESSURES FOR 15 MIN AND SHUT IN THE
WELL
15:00 17:00 2.00 COMPZN, STIM WAIT P CLOSE WELL & BLOW DOWN LINES & BLEED DOWN THE IA. RU LRS ON TUBING
AND PUMP 35 BBL DSL FREEZE PROTECT.
17:00 23:59 6.99 COMPZN, STIM WAIT P NIGHT CREWS WILL RELOAD SAND & TREAT PW WATER. HAL NIGHT SHIFT LOAD
GEL, CHEMS & BREAK INTO A FEW PUMPS.
Report Fluids Summary
Fluid To well (bbl) Cum to Well (bbl)
DIESEL 35.0 210.0
SEAWATER 3,530.0
WATER 13,828.0 66,359.0
Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/9/2024 06:00 5/9/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/10/2024 00:00 5/10/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/11/2024 00:00 5/11/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/12/2024 00:00 5/12/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/13/2024 00:00 5/13/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/14/2024 00:00 5/14/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/15/2024 00:00 5/15/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/16/2024 00:00 5/16/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/17/2024 00:00 5/17/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/18/2024 00:00 5/18/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/19/2024 00:00 5/19/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/20/2024 00:00 5/20/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/21/2024 00:00 5/21/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/22/2024 00:00 5/22/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/23/2024 00:00 5/23/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/24/2024 00:00 5/24/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/25/2024 00:00 5/25/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/26/2024 00:00 5/26/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/27/2024 00:00 5/27/2024 18:00 FRAC
Page 1/2
3S-610
Report Printed: 6/21/2024
Daily STIM Report REPORT # [ 18]
REPORT DATE: [ 5/26/2024]
API / UWI
5010320875
Original KB/RT Elevation (ft)
63.30
Ground Elevation (ft)
24.30
Original Spud Date
3/9/2024
Primary Job Type
INITIAL COMPLETION
Secondary Job Type
STIMULATION
Total AFE (Cost) AFE / RFE / Maint.#
10441022
Network/Order Number
10441022
AFE+Supp Amt (Cost) Daily Cost Total (Cost)
6,508.00
Cumulative Cost (Cost)
1,265,491.05
Weather Temperature (°F) Road Condition Wind
Last 24hr Summary
PUMPED DFIT INTO INTERVAL #18
PUMPED STAGE #18 PER DESIGN w/ 139,939 LBS OF 16/20 & 3967 LBS OF 100 MESH.
STAGE #19 - UNABLE TO GET 100 MESH TO FLOW OUT OF CASTLE. **LIKELY FROZEN** PUMPED STAGE PER DESIGN w/ ALL 16/20, TOTAL OF
147,801 LBS OF PROPPANT.
STAGE #20 - DROPPED A TOTAL OF 3 BALLS & DID NOT SEE A PRESSURE RESPONSE ON ANY OF THEM. DECISION WAS MADE TO SKIP STAGE.
STAGE #21 - DROPPED PRIMARY BALL, NO SEAT OBSERVED, NO PRESSURE RESPONSE.
DECISION WAS MADE TO ALSO SKIP THIS STAGE. FRAC IS COMPLETE. BEGIN RIGGING DOWN AND MOVING TO 3S-606. IN PROGRESS
24hr Forecast
RIG DOWN & MOVE TO 3S-606
General Remarks
INITIAL T/I/O=150/0/0
FINAL T/I/O= 500/700/600
ZX Code
ZX02 Fracturing
Contact Name Title Mobile
BECK, BRENT Supervisor 907-616-0445
CAMPBELL, JAMES Frac Supervisor 661-203-1472
LUSTER, CHOICE Supervisor
Time Log
Start Time End Time Dur (hr) Phase Activity Code
Time P-
T-X Operation
00:00 06:00 6.00 COMPZN, STIM WAIT P NIGHT CREWS CONT. LOADING SAND, WATER, GEL & CHEMS. PREP EQUIPMENT
TO PUMP IN THE MORNING.
06:00 07:30 1.50 COMPZN, STIM WAIT P ARRIVE ON LOCATION. SIM OPS WITH RIG. FIRE UP EQUIPMENT AND PREPARE TO
PT.
07:30 09:00 1.50 COMPZN, STIM WAIT P PRIME UP PUMPS. TEST POP OFFS & PRESSURE TEST IRON TO 9500 PSI.
DISCOVER LEAK @ GREYLOCK CONNECTION BELOW GOAT HEAD. TIGHTEN UP
FLANGE BOLTS. RETEST TO 9500 PSI **PASS**
09:00 09:15 0.25 COMPZN, STIM WAIT P SAFETY MEETING WITH ALL INVOLVED PARTIES
09:15 09:45 0.50 COMPZN, STIM WAIT P BRING ON CHEM LINES. START MIXING GEL
LOAD STAGE #18 BALL (2.672" OD BALL / 2.645" ID SEAT)
LOAD STAGE #19 BALL (2.710" OD BALL / 2.682" ID SEAT)
LOAD STAGE #20 BALL (2.749" OD BALL / 2.720" ID SEAT)
LOAD STAGE #21 BALL (2.787" OD BALL / 2.759" ID SEAT)
WALK LINES AND VERIFY VALVES ARE LINED UP TO GO DOWN HOLE.
09:45 10:15 0.50 COMPZN, STIM PUMP P LAUNCH STAGE #18 BALL. GOOD SHIFT
PERFORM DFIT
10:15 11:00 0.75 COMPZN, STIM PUMP P BRING PUMPS BACK ONLINE AND ESTABLISH STABLE FLUID.
INTERVAL - #18
SEAT SLURRY VOLUME (BBL) - 173
DART SEAT SLURRY VOLUME (BBL) - 159 (SEE SHIFT 14 BBLS EARLY)
SURFACE SLV DIFF SHIFT PRESSURE (PSI) = 1298 PSI
TOTAL STAGE CLEAN VOLUME (BBLS) - 1502
TOTAL PROPPANT PLACED (LBS) - 143,906
100 MESH (LBS) - 3967
16/20 (LBS) - 139,939
MAX PROP CONC (PPG) - 7.14
AVERAGE SURFACE (PSI) - 2105
AVG BHP (PSI) 3567
AVG RATE (BPM) - 31.0
Page 2/2
3S-610
Report Printed: 6/21/2024
Daily STIM Report REPORT # [ 18]
REPORT DATE: [ 5/26/2024]
Time Log
Start Time End Time Dur (hr) Phase Activity Code
Time P-
T-X Operation
11:00 11:45 0.75 COMPZN, STIM PUMP P LAUNCH STAGE #19 BALL. GOOD SHIFT. 100 MESH BIN IS PLUGGED/FROZEN.
SUBSTITUTED 16/20 FOR .25 PPG
INTERVAL - #19
SEAT SLURRY VOLUME (BBL) - 1819
DART SEAT SLURRY VOLUME (BBL) - 1817 (SEE SHIFT 2 BBLS EARLY)
SURFACE SLV DIFF SHIFT PRESSURE (PSI) =2509 PSI
TOTAL STAGE CLEAN VOLUME (BBLS) - 2376
TOTAL PROPPANT PLACED (LBS) - 147,801
100 MESH (LBS) - 1785 - CASTLE BIN HOLDING 100 MESH IS FROZEN
16/20 (LBS) - 146,016
MAX PROP CONC (PPG) - 7.51
AVERAGE SURFACE (PSI) - 2576
AVG BHP (PSI) 4047
AVG RATE (BPM) - 35.1
11:45 12:30 0.75 COMPZN, STIM PUMP P LAUNCH STAGE #20 BALL. HEARD LOUD SOUND WHEN LAUNCHING. DID NOT SEE
BALL SEAT ON DISP. VOLUME. LOAD BACK UP BALL & LAUNCH NO SEAT
OBSERVED. FLUSH WELL & HOT SHOT FOR 3RD BALL.
12:30 14:30 2.00 COMPZN, STIM WAIT T WAIT ON RIG TO GET TO 3G TO GET BACK TO 3S WITH BALL
14:30 15:00 0.50 COMPZN, STIM PUMP T LAUNCH STAGE #20 (3RD BALL). NO SEAT OBSERVED. CONFER WITH ENGINEERS
& DECISION MADE TO SKIP STAGE #20 & MOVE TO STAGE #21
15:00 15:45 0.75 COMPZN, STIM PUMP P LAUNCH STAGE #21 BALL. NO BALL SEAT OBSERVED. NO PRESSURE RESPONSE
OBSERVED. FLUSH WELL. DECISION MADE TO RIG DOWN & MOVE TO 3S-606,
WHILE WAITING ON PLAN FORWARD.
15:45 17:15 1.50 COMPZN, STIM RURD P SHUT IN WELL. BLEED DOWN IA & RU LRS ON TUBING FOR FREEZE PROTECT.
BLOW DOWN LINES IN PREPERATION TO RIG DOWN
17:15 23:59 6.74 COMPZN, STIM DMOB P BEGIN RIGGING DOWN
Report Fluids Summary
Fluid To well (bbl) Cum to Well (bbl)
DIESEL 35.0 245.0
SEAWATER 3,530.0
WATER 9,480.0 75,839.0
Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/9/2024 06:00 5/9/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/10/2024 00:00 5/10/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/11/2024 00:00 5/11/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/12/2024 00:00 5/12/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/13/2024 00:00 5/13/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/14/2024 00:00 5/14/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/15/2024 00:00 5/15/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/16/2024 00:00 5/16/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/17/2024 00:00 5/17/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/18/2024 00:00 5/18/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/19/2024 00:00 5/19/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/20/2024 00:00 5/20/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/21/2024 00:00 5/21/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/22/2024 00:00 5/22/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/23/2024 00:00 5/23/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/24/2024 00:00 5/24/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/25/2024 00:00 5/25/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/26/2024 00:00 5/26/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/27/2024 00:00 5/27/2024 18:00 FRAC
Page 1/1
3S-610
Report Printed: 6/21/2024
Daily STIM Report REPORT # [ 19]
REPORT DATE: [ 5/27/2024]
API / UWI
5010320875
Original KB/RT Elevation (ft)
63.30
Ground Elevation (ft)
24.30
Original Spud Date
3/9/2024
Primary Job Type
INITIAL COMPLETION
Secondary Job Type
STIMULATION
Total AFE (Cost) AFE / RFE / Maint.#
10441022
Network/Order Number
10441022
AFE+Supp Amt (Cost) Daily Cost Total (Cost)
3,215,095.44
Cumulative Cost (Cost)
4,480,586.49
Weather Temperature (°F) Road Condition Wind
Last 24hr Summary
RIG DOWN FRONT YARD, ACID PUMP & GREAT NORTH LAUNCHER EQUIPMENT. WELL SUPPORT RIGGED DOWN IA, TUBING & OA LINES. READY
FOR SLICKLINE. JOB COMPLETE
24hr Forecast
General Remarks
ZX Code
ZX02 Fracturing
Contact Name Title Mobile
BECK, BRENT Supervisor 907-616-0445
CAMPBELL, JAMES Frac Supervisor 661-203-1472
LUSTER, CHOICE Supervisor
Time Log
Start Time End Time Dur (hr) Phase Activity Code
Time P-
T-X Operation
00:00 18:00 18.00 COMPZN, STIM DMOB P RIG DOWN FRONT YARD, ACID PUMP & GREAT NORTH LAUNCHER EQUIPMENT.
WELL SUPPORT RIGGED DOWN IA, TUBING & OA LINES.
Report Fluids Summary
Fluid To well (bbl) Cum to Well (bbl)
DIESEL 245.0
SEAWATER 3,530.0
WATER 75,839.0
Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/9/2024 06:00 5/9/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/10/2024 00:00 5/10/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/11/2024 00:00 5/11/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/12/2024 00:00 5/12/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/13/2024 00:00 5/13/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/14/2024 00:00 5/14/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/15/2024 00:00 5/15/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/16/2024 00:00 5/16/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/17/2024 00:00 5/17/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/18/2024 00:00 5/18/2024 23:59 FRAC
HES Frac Equipment BURKETT, CHAD,Wells Supervisor 5/19/2024 00:00 5/19/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/20/2024 00:00 5/20/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/21/2024 00:00 5/21/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/22/2024 00:00 5/22/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/23/2024 00:00 5/23/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/24/2024 00:00 5/24/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/25/2024 00:00 5/25/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/26/2024 00:00 5/26/2024 23:59 FRAC
HES Frac Equipment CLAYTON, GREG,Wells Supervisor 5/27/2024 00:00 5/27/2024 18:00 FRAC
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:1366' FSL, 3964' FWL S12 T12N R7E 9. Ref Elevations: KB: 17. Field / Pool(s):
GL: 25 BF:
Total Depth:10. Plug Back Depth MD/TVD: 18. Property Designation:
4b. Location of Well (State Base Plane Coordinates, NAD 27):11. Total Depth MD/TVD: 19. DNR Approval Number:
Surface: x- y- Zone- 4
TPI:x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD:
Total Depth:x- y- Zone- 4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 N/A (ft MSL)
22. Logs Obtained:
23.
BOTTOM
20"x65 129'
10-3/4"L-80 2565'
7-5/8"L-80 5119'
4-1/2"P110S 5178'
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
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,
TUBING RECORD
20433'
Lead: 223bbl 15.3 ppg Class G
4596'
9-7/8"
6-1/2"
7306'4.5"7229'MD/4573'TVD
7301'MD/4596'TVD
BOTTOM
13-1/2"Lead: 387bbl 10.7ppg Blend
Tail: 57bbl 15.8 Class G
CASING
50-103-20875-00-00
KRU 3S-610
3/9/2024
21983'MD/5173'TVD
N/A
64
P.O.Box 100360, Anchorage, AK 99510-0360
476273
2780' FSL, 3819' FWL S18 T12N R8E
3124' FSL, 2174' FWL S35 T13N R7E
4/1/2024
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
ConocoPhillips Alaska, Inc.
WAG
Gas
4/12/2024 223-126
1722'MD/1701'TVD
SETTING DEPTH TVD
6010130
TOP HOLE SIZE AMOUNT
PULLEDTOP
SETTING DEPTH MD
GR, RES, DEN, DIR, AZI, PWD, NEU, POR, SONIC, CALIPER
PACKER SET (MD/TVD)
7301'
42"
12.95
5993915
Kuparuk River Field/Torok Oil Pool
ADL380107, ADL380106, ADL025528,
ADL393883
LONs 01-013
39'
39'
2713'
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size
and Number; Date perf'd or liner run):
WT. PER
FT.GRADE
471152
467826
CEMENTING RECORD
5997799
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and
Number; Date perf'd or liner run):
Liner (Ran on 4/6/2024): 7301'MD/4596'TVD - 20433'MD/5178'MD
Gas-Oil Ratio:Choke Size:
suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud
log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing
collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary.
N/A
39'
39'
Per 20 AAC 25.283 (i)(2) attach electronic information
29.7 36.5'
154.3
45.5
129'
36.5'9012'
SIZE DEPTH SET (MD)
10 Yards
Sr Res EngSr Pet GeoSr Pet Eng
N/A
Oil-Bbl:Water-Bbl:
Water-Bbl:
PRODUCTION TEST
N/A
Date of Test:Oil-Bbl:
24
Flow Tubing
W
d 1b
0 D p
op and B om;Perf
L
s
((atta
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
By Grace Christianson at 4:10 pm, May 09, 2024
Completed
4/12/2024
JSB
RBDMS JSB 052024
G
DSR-11/22/24
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
Surface Surface
1375 1368
Ugnu B 1655 1638
1722 1701
1778 1754
Top West Sak 2054 2010
Base West Sak 2555 2437
C-80 2770 2610
C-50 4222 3463
C-35 5283 3897
Top Coyote 5751 4087
6893 4467
9109 5143
21983 5173
31. List of Attachments:
Directional Survey, Well Schematic, Cement Operations, Operations Summary
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Matt Smith
Digital Signature with Date:
Contact Phone:907-263-4324
General:
Item 1a:
Item 1b:
Item 4b:
Item 9:
Item 15:
Item 19:
Item 20:
Item 22:
Item 23:
Item 24:
Item 27:
Item 28:
Item 30:
Item 31:
If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if
needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired.
Attached Seperately
Formation Name at TD:
Torok Oil
Yes No
Well tested? Yes No
28. CORE DATA
If Yes, list intervals and formations tested, briefly summarizing test results for
each. Attach separate pages if needed and submit detailed test info including
reports and Excel or ASCII tables per 20 AAC 25.071.
NAME
Permafrost - Top
Ugnu C
29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered)FORMATION TESTS
Top of Productive Interval:
Torok Oil
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Base Coyote
Permafrost - Base
Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic
diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from
a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071.
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core
analysis, paleontological report, production or well test results, per 20 AAC 25.070.
Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
TPI (Top of Producing Interval).
Authorized Name and
INSTRUCTIONS
Contact Email:matt.smith@conocophillips.com
Authorized Title: Drilling Engineer
Ugnu A
Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment; or 90 days after log acquisition, whichever occurs first.
N
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
Base Perm
1722' MD/1701' TVD
Top Coyote
5776' MD/4097' TVD
3S-610 Grassroots Horizontal Moraine Producer
20" Conductor 129' MD
4-½" 12.6# P110S H563 20433' MD / 5177' TVD 90° INC
4-½”12.6# L80 H563MS
9-и" Intermediate Hole
6-1/2" Production HoleNA
F
13-½" Surface Hole
Updated: 4/20/2023
5.9" Oil Swell Packer, Baker Frac sleeve
FW
P
Sp
u
d
M
u
d
5-½” x 7-5/8" SLZXP LTP-HGR 7301' MD / 4596' TVD
7229' MD 4-½” x 7-5/8" Production Packer, TNT
TOC (SonicScope)
3549' MD/3156' TVD
6671' MD Gauge Mandrel, Dual OPSIS
Top Moraine
9113' MD / 5143' TVD
6773' MD Gas Venting Sliding Sleeve, CMD (Closed)
6971' MD Sliding sleeve, CMU, (Closed w/ISO sleeve installed)
6024' MD Gas Lift Mandrel, 4-½” x 1” (DV)
2057' MD Gas Lift Mandrel, 4-½” x 1” (SOV Sheard)
WIV/Alpha Sleeve
7120' MD Chemical Injection Mandrel (DV)
4024' MD Gas Lift Mandrel, 4-½” x 1” (DV)
5209' MD Gas Lift Mandrel, 4-½” x 1” (DV)
10-¾” 45.5# L80 H563 2713' MD/2565' TVD 36°Inc
7-5/8" 29.7# L-80 H563 9012' MD / 5119' TVD 75° Inc
7-5/8" 29.7# L80 H563 8171' MD
6-½” TD @ 21983' MD / 5172' TVD 90° INC
7-5/8" 33.7# P110S H563 8171'- 8878' MD
Swell #24 7579' MD
Swell #23 8182' MD
Swell #22 8781' MD
7303' MD Bottom of Mule Shoe
Page 1/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/5/2024
12:00
3/5/2024
13:00
1.00 MIRU, MOVE MOB P Jack up Module pin tires hookup trucks
to motor complex.
0.0 0.0
3/5/2024
13:00
3/5/2024
14:00
1.00 MIRU, MOVE MOB P Jack up module pin tires on pump
module
0.0 0.0
3/5/2024
14:00
3/5/2024
15:00
1.00 MIRU, MOVE MOB P Jack up pipeshed pin tires move pipe
shed
0.0 0.0
3/5/2024
15:00
3/5/2024
17:00
2.00 MIRU, MOVE MOB P Move Rockwasher and Magtec vac unit
cuttings tank and air heater, Remove
Herculite from ground where cutting
tanks were positioned.
0.0 0.0
3/5/2024
17:00
3/5/2024
18:00
1.00 MIRU, MOVE MOB P Raise pit module pin tires and move pit
module
0.0 0.0
3/5/2024
18:00
3/5/2024
20:00
2.00 MIRU, MOVE MOB P PJSM skid rig floor and connect Drill sub
tow hitch. Raise sub stompers and
secure each. Raise rear windwall door
and secure door. Remove rig mats from
well 3S-606 footprint.
0.0 0.0
3/5/2024
20:00
3/5/2024
21:45
1.75 MIRU, MOVE MOB P Jack sub complex, hook up trucks and
pull off well 3S-606. Witness by CPAI
Rep, CPAI pad operator, Doyon Rep.
0.0 0.0
3/5/2024
21:45
3/6/2024
00:00
2.25 MIRU, MOVE MOB P Scrape and grade pad. Assisted Tool
house Reps in removing leg on well
house beside 3S-610 well to able loader
operator to assemble rig mats footprint
for 3S-610 well
0.0 0.0
3/6/2024
00:00
3/6/2024
08:30
8.50 MIRU, MOVE MOB P Shuffle rig mats and orient for layout.
Move sub into position and spot over
well.
0.0 0.0
3/6/2024
08:30
3/6/2024
10:30
2.00 MIRU, MOVE MOB T Wait on CPAI scaffolding crew to
remove scaffolding from bull rail and 3S-
611. In order to clear stompers.
SIMOPS remove tongue on sub.
0.0 0.0
3/6/2024
10:30
3/6/2024
12:00
1.50 MIRU, MOVE MOB P Lower stompers into drilling position. 0.0 0.0
3/6/2024
12:00
3/6/2024
12:30
0.50 MIRU, MOVE MOB P Attempt to skid rig floor all 4 polished
rods rotating due to cold weather.
0.0 0.0
3/6/2024
12:30
3/6/2024
14:30
2.00 MIRU, MOVE MOB T Stroke cylinders back and fourth to
warm hydraulic oil. Low temps effecting
hydraulic system.
0.0 0.0
3/6/2024
14:30
3/6/2024
15:00
0.50 MIRU, MOVE MOB T Connect NES truck to pit module and
shuffle rig mats. NES truck have
mechanical difficulties moving.
0.0 0.0
3/6/2024
15:00
3/6/2024
16:00
1.00 MIRU, MOVE MOB T Troubleshoot NES truck transmission
problems wait on NES mechanic
SIMOPS: Move Frac equipment to make
room for pump module rig mat foot print.
0.0 0.0
3/6/2024
16:00
3/6/2024
18:00
2.00 MIRU, MOVE MOB T Standby-by waiting for NES mechanic to
arrive.
SIMOPS: Stage portable heaters in the
cellar and BOP deck.
Warm up starting flange.
0.0 0.0
3/6/2024
18:00
3/6/2024
22:15
4.25 MIRU, MOVE MOB T NES truck mechanical problems waiting
on mechanic or new truck to continue.
Resolve fuel issue on NES truck.
Another NES truck was dispatched from
Alpine.
SIMOPS: PJSM Cameron Rep. install
riser starter flange, Ready tools and
equipment to change out wash-pipe on
top drive.
Secure skate rail to free up tugger for
operations.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 2/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/6/2024
22:15
3/6/2024
23:00
0.75 MIRU, MOVE MOB P Rig up to pits module and spot into
position against sub, verify good and set
down module. Rig down NES trucks mat
out in front pit module for pump module
layout. Install mat transition, rig up NES
truck to pump module and ready to spot.
2nd NES truck from Alpine arrived at 3S
pad 11:00 PM
0.0 0.0
3/6/2024
23:00
3/7/2024
00:00
1.00 MIRU, MOVE MOB P Spot pump module to pits and set down
to verify proper rig up for service lines.
(Good) Set down module rig down NES
truck and prepare layout to spot motor
module in place.
0.0 0.0
3/7/2024
00:00
3/7/2024
04:00
4.00 MIRU, MOVE MOB P Continue spotting pump and motor
complexes using NES trucks.
SIMOPS start connecting module
interconnects on pit module and Change
out wash pipe on top drive.
0.0 0.0
3/7/2024
04:00
3/7/2024
06:45
2.75 MIRU, MOVE MOB P Continue spotting modules, add shims
and adjust motor complex and pump
complex to level.
Continue making electrical connections
in pits, pump and gen modules.
0.0 0.0
3/7/2024
06:45
3/7/2024
08:45
2.00 MIRU, MOVE MOB P Spot pipe shed and continue with pits
and sub interconnects, begin hooking up
steam lines.
0.0 0.0
3/7/2024
08:45
3/7/2024
12:00
3.25 MIRU, MOVE MOB P Release NES trucks secure walkways
and landings, Secure walkways and
landings, continue with module
interconnects.
Bring on steam to sub and pit mod's.
Clean up 3S-606 cellar area.
Welder making penetration for mouse
hole on rig floor to BOP deck, continue
working on mud lines and
containments . Work on rig acceptance
checklist items.
0.0 0.0
3/7/2024
12:00
3/7/2024
18:00
6.00 MIRU, MOVE MOB P Continue working on rig acceptance
checklist, install upper skate rail,
mobilize wellhead and frac tree adapter
flange to cellar via bop deck, begin
taking on spud mud to pits, string up
skate cables for trough. SIMOPS: Install
jaw assembly on ST-100.
Note spud vis was to thick to pump off
mud trucks, mixed and pumped Desco
pills to thin mud out on trucks.
0.0 0.0
3/7/2024
18:00
3/7/2024
20:00
2.00 MIRU, MOVE RURD P Continue working on rig acceptance
checklist, string drum and function test
skate to ensure proper setup, install
mousehole, ready tools and equip. to
change saver sub. Continue to work
spud mud to transferable vis with Desco
pills. Rig accepted at 18:00 hrs
0.0 0.0
3/7/2024
20:00
3/7/2024
23:15
3.25 MIRU, MOVE RURD P Obtain surface equipment RKB’s, nipple
up the lower surface riser and upper
riser nipple, install air-boots, secure in-
place
Continue to work spud mud to
transferable vis with Desco pills.
0.0 0.0
3/7/2024
23:15
3/8/2024
00:00
0.75 MIRU, MOVE RURD P Install 5" elevators, change out saver
sub from XT-39 to 4.5IF, install bell
guides
Continue to work spud mud to
transferable vis with Desco pills.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 3/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/8/2024
00:00
3/8/2024
02:15
2.25 MIRU, MOVE RURD P Continue to change saver sub. Change
dies on ST-100 from 4" to 5" Offload
spare BHA tools and prepare pipe shed
for surface casing.
SIMOPS: Continue to offload spud mud
to pits treating with Desco for transfer
process.
0.0 0.0
3/8/2024
02:15
3/8/2024
03:45
1.50 MIRU, MOVE RURD P Change out wash pipe assembly and
follow break in procedure.
0.0 0.0
3/8/2024
03:45
3/8/2024
06:00
2.25 MIRU, MOVE PULD P Pick up 20 jts 5" drill pipe from pipe
shed and jar assembly and rack back in
derrick.
0.0 0.0
3/8/2024
06:00
3/8/2024
09:00
3.00 MIRU, MOVE RURD P Mobilize surface BHA to rig floor,
pressure test high pressure mud lines
with air to verify connection integrity.
Install drain hoses from flow box to
cellar, trash pumps operational. Adjust
and align surface riser, begin loading
10.75" surface casing in pipe shed.
Bring generator #3 online and sync with
Gen #1.
0.0 0.0
3/8/2024
09:00
3/8/2024
09:45
0.75 MIRU, MOVE SEQP P Fill conductor with spud mud verify no
leaks and pressure test surface lnes to
4000 psi. Blow down top drive.
0.0 0.0
3/8/2024
09:45
3/8/2024
10:30
0.75 MIRU, MOVE SFTY P Conduct Pre-spud meeting with drill
crew and third party personnel.
0.0 0.0
3/8/2024
10:30
3/8/2024
11:30
1.00 SURFAC, DRILL BHAH P P/U and M/u clean out BHA as per SLB
directional driller.
SIMOPS: Load 10-3/4" surface casing.
0.0 0.0
3/8/2024
11:30
3/8/2024
12:00
0.50 SURFAC, DRILL TRIP P RIH with clean out BHA on 5" HWDP
from derrick from surface to 45'
Obstruction encountered decision made
to wash down.
0.0 45.0
3/8/2024
12:00
3/8/2024
12:15
0.25 SURFAC, DRILL REAM P Ream in hole from 45' MD to 66' MD
200GPM
40 RPM
45.0 66.0
3/8/2024
12:15
3/8/2024
13:15
1.00 SURFAC, DRILL REAM P Drill 13-1/2" surface hole clean out BHA
to 225' MD to make room for directional
BHA.
GPM 225 to 450
PSI on 624
RPM 40
TQ on 3.5
Flow out 25%
PUW 55k SOW 49K RTW 53K
66.0 225.0
3/8/2024
13:15
3/8/2024
13:30
0.25 SURFAC, DRILL CIRC P CBU while reciprocate 500 GPM and
observed losses at 209' MD
Shut down pumps and reestablish
circulation by bringing pumps up slowly.
GPM 120 to 500
PSI on 570
Flow out 25%
PUW 55k SOW 49K RTW 53K
225.0 225.0
3/8/2024
13:30
3/8/2024
14:00
0.50 SURFAC, DRILL CIRC P Pump 30 bbls LCM pill from pit 6 and
spot on bottom.
GPM 110
PSI 73
total stroke for pill 335.
225.0 225.0
3/8/2024
14:00
3/8/2024
14:15
0.25 SURFAC, DRILL RURD P Blow down top drive and line up hole fill
on active pits.
225.0 225.0
3/8/2024
14:15
3/8/2024
14:45
0.50 SURFAC, DRILL TRIP P Trip out of hole on elevators with clean
out BHA monitoring hole via jet line on
active system.
225.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 4/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/8/2024
14:45
3/8/2024
18:00
3.25 SURFAC, DRILL BHAH P P/U and M/U surface directional BHA as
per SLB DD/MWD. Orient and scribe
motor. Taking weight inside conductor
running to bottom. work in 20 degree
increments to getting to bottom while
reciprocating often to verify pipe free.
0.0 152.0
3/8/2024
18:00
3/8/2024
19:30
1.50 SURFAC, DRILL CIRC T @152" to 208" MD Make up 5" double
HWDP to collars and establish
circulation with 200/450 GPM 309/527
PSI. Wash and ream down to 208" MD
to clear obstruction with 30 RPM, 1K
TQ, F/O 37% ROT 62k
152.0 208.0
3/8/2024
19:30
3/8/2024
23:00
3.50 SURFAC, DRILL CIRC T Increase in cutting load at flow box,
Packing out in flow box, riser and flow
line with clay, rocks, shutdown pumps
and clean out flow box, pull inspection
covers on flow line and clean out.
established full circulation @ 450 GPM,
521 PSI while rotating and reciprocating
pipe at 208' MD to 152' MD 30 RPM, 1k
TQ, F/O 40% Obstruction cleared.
208.0 151.0
3/8/2024
23:00
3/8/2024
23:30
0.50 SURFAC, DRILL CLEN T @ 175' MD obtain GYRO survey as per
SLB DD. (Good survey) rack stand
HWDP back in derrick. Blow down top-
drive
151.0 151.0
3/8/2024
23:30
3/9/2024
00:00
0.50 SURFAC, DRILL BHAH P @ 151' MD Pickup remaining surface
BHA as per SLB DD.
151.0 151.0
3/9/2024
00:00
3/9/2024
00:30
0.50 SURFAC, DRILL BHAH P Continue P/U BHA as per SLB DD 151.0 182.0
3/9/2024
00:30
3/9/2024
00:45
0.25 SURFAC, DRILL REAM P Wash in hole from 182' to 225' MD,
450 GPM
574 PSI
30 RPM
63K RTW
182.0 225.0
3/9/2024
00:45
3/9/2024
06:00
5.25 SURFAC, DRILL DDRL P Drill ahead 13-1/2" surface hole section
from 225' MD to 462 MD sliding as
needed to keep on well plan.
457 GPM
685 PSI
40 RPM
PUW 75K
SOW 72K
68K RTW
Work and wash trough several surface
clay ball pack offs in riser and flow line.
Continue flow line jetting and proactive
packoff prevention measures.
225.0 462.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 5/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/9/2024
06:00
3/9/2024
12:00
6.00 SURFAC, DRILL DDRL P Drill ahead 13-1/2" surface hole section
from 462' MD to 646' MD sliding as
needed to keep on well plan.
500 GPM
840 PSI
40 RPM
PUW 78K
SOW 84K
78K RTW
10.65 ECD
Work and wash trough several surface
clay ball pack offs in riser, flow box and
flow line.
Continue flow line jetting and proactive
packoff prevention measures.
Pumped 30 bbl Bit balling sweep 480'
MD
Pumped 30 bbl Soap Sap sweep at 580'
MD
Pumped 30 bbl bit balling sweep at 598'
MD
462.0 646.0
3/9/2024
12:00
3/9/2024
18:00
6.00 SURFAC, DRILL DDRL P Drill ahead 13-1/2" surface hole section
from 646' MD to 1022' MD 1018' TVD,
sliding as needed to keep on well plan.
500 GPM
1055 PSI
40 RPM
PUW 80K
SOW 86K
80K RTW
9.73 ECD
Pump sweeps after every other
connection
Pumped 30 bbl Bit balling sweep
Pumped 30 bbl Soap Sap sweep
646.0 1,022.0
3/9/2024
18:00
3/10/2024
00:00
6.00 SURFAC, DRILL DDRL P Drill ahead 13-1/2" surface hole section
from 1022' MD to 1325' MD 1295' TVD,
sliding as needed to keep on well plan.
500 GPM
960PSI
40 RPM
PUW 98K
SOW 97K
83K RTW
9.69 ECD
Pump sweeps after every other
connection
Pumped 2x 30 bbl Bit balling sweep
1,022.0 1,325.0
3/10/2024
00:00
3/10/2024
06:00
6.00 SURFAC, DRILL DDRL P Drill ahead 13-1/2" surface hole section
from 1325' MD to 1530' MD 1295' TVD,
sliding as needed to keep on well plan.
500 GPM
3.5k WOB
1016 PSI
40 RPM
PUW 105K
SOW 102K
RTW 100K
9.47 ECD
1,325.0 1,530.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 6/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/10/2024
06:00
3/10/2024
12:00
6.00 SURFAC, DRILL DDRL P Drill ahead 13-1/2" surface hole section
from 1530' MD to 1803' MD 1295' TVD,
sliding as needed to keep on well plan.
500 GPM
3.5k WOB
1016 PSI
40 RPM
PUW 105K
SOW 102K
RTW 100K
9.47 ECD
1,530.0 1,803.0
3/10/2024
12:00
3/10/2024
18:00
6.00 SURFAC, DRILL DDRL P Drill ahead 13-1/2" surface hole section
from 1803' MD to 2156' MD 2102' TVD,
sliding as needed to keep on well plan.
700 GPM
1k WOB
1948 PSI
40 RPM
PUW 92K
SOW 101K
RTW 100K
10.0 ECD
1,803.0 2,102.0
3/10/2024
18:00
3/11/2024
00:00
6.00 SURFAC, DRILL DDRL P Drill ahead 13-1/2" surface hole section
from 2156' MD to 2500' MD 2392' TVD,
sliding as needed to keep on well plan.
700 GPM
7.5k WOB
2134 PSI
40 RPM
PUW 97K
SOW 108K
RTW 105K
10.45 ECD
2,102.0 2,500.0
3/11/2024
00:00
3/11/2024
04:00
4.00 SURFAC, DRILL DDRL P Drill ahead 13-1/2" surface hole section
from 2500' MD to 2720' MD 2392' TVD,
sliding as needed to keep on well plan.
720 GPM
9k WOB
2196 PSI
40 RPM
PUW105K
SOW 102K
RTW 100K
10.69 ECD
At TD 2720' Obtain final survey and
parameters.
2,500.0 2,720.0
3/11/2024
04:00
3/11/2024
04:15
0.25 SURFAC, TRIPCAS OWFF P Perform flow check, verify well static. 2,720.0 2,720.0
3/11/2024
04:15
3/11/2024
06:00
1.75 SURFAC, TRIPCAS BKRM P BROOH from 2720' to 2585' MD
720 GPM
2174 PSI
40 RPM
3.5K TQ
PUW104K
SOW 100K
RTW 98K
10.49 ECD
2,720.0 2,585.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 7/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/11/2024
06:00
3/11/2024
12:00
6.00 SURFAC, TRIPCAS BKRM P BROOH from 2585' to 1904' MD
720 GPM
2100 PSI
40 RPM
3K TQ
PUW105K
SOW 102K
RTW 100K
10.59 ECD
Slight restriction noted at 2183' MD
2,585.0 1,904.0
3/11/2024
12:00
3/11/2024
16:45
4.75 SURFAC, TRIPCAS BKRM P BROOH from 1904' to 1050' MD
720 GPM
2100 PSI
40 RPM
3K TQ
PUW105K
SOW 102K
RTW 100K
10.59 ECD
Large increase in sand at the shakers
starting around 1500' MD
Signs of wood at shakers starting at
around 1300' MD
Continued hole unloading in waves with
large clay patties 4" to 8" average.
Increased amount of gravel size
material on the scalpers.
1,904.0 1,050.0
3/11/2024
16:45
3/11/2024
19:45
3.00 SURFAC, TRIPCAS CIRC P @ 1050' Magtec cuttings vac line
frozen, cutting box volume to high in
cutting box to continue BROOH. Thaw
lines take returns to rockwasher while
thawing lines and getting cutting box
cleared out. before starting to BROOH.
Circulating while working pipe.
500 GPM
900 PSI
40 RPM
3K TQ
PUW105K
SOW 102K
RTW 100K
10.42 ECD
1,050.0 1,050.0
3/11/2024
19:45
3/11/2024
22:00
2.25 SURFAC, TRIPCAS BKRM P BROOH from 1050' to ' MD 941'
720 GPM
2100 PSI
40 RPM
3K TQ
PUW105K
SOW 102K
RTW 100K
10.59 ECD
Continued signs of wood.
Sand still present but tapered off some.
Massive unloading in waves , large
amounts of gravel material and
continued clay patties 4" to 8".
1,050.0 941.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 8/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/11/2024
22:00
3/12/2024
00:00
2.00 SURFAC, TRIPCAS CIRC P @ 941' Magtec cuttings vac line frozen,
cutting box volume to high in cutting box
to continue BROOH. Thaw lines take
returns to rockwasher while thawing
lines and getting cutting box cleared out.
before starting to BROOH Circulating
while working pipe.
500 GPM
867 PSI
40 RPM
3K TQ
PUW105K
SOW 102K
RTW 100K
10.32 ECD
941.0 941.0
3/12/2024
00:00
3/12/2024
05:15
5.25 SURFAC, TRIPCAS BKRM P BROOH from 941' to 182' MD
550 GPM
920 PSI
40 RPM
2K TQ
PUW56K
10.92 ECD
941.0 182.0
3/12/2024
05:15
3/12/2024
05:30
0.25 SURFAC, TRIPCAS OWFF P Perform flow check.
Well deemed static.
182.0 182.0
3/12/2024
05:30
3/12/2024
07:30
2.00 SURFAC, TRIPCAS BHAH P From 182' to surface Blow down top
drive and rack back 5" HWDP. rack back
drill collars and L/D BHA as per SLB
DD.
182.0 0.0
3/12/2024
07:30
3/12/2024
12:00
4.50 SURFAC, TRIPCAS RURD P Clean and clear rig floor and rig up
casing running equipment.
Move and treat mud system.
0.0 0.0
3/12/2024
12:00
3/12/2024
12:45
0.75 SURFAC, CASING RURD P Continue preparing pits and rig up
Volant to top drive.
0.0 0.0
3/12/2024
12:45
3/12/2024
14:15
1.50 SURFAC, CASING SFTY P Pre Job safety meeting with crews and
third party personnel.
Running 10-3/4" casing. reviewed and
discussed Doyon SOP, potential
hazards and identified relevant past
incidents.
0.0 0.0
3/12/2024
14:15
3/12/2024
21:30
7.25 SURFAC, CASING PULD P RIH with 10-3/4" 45.5# L-80 Hyd 563
surface casing as per casing detail. M/U
and Bakerlok shoe track to pin on 4th
joint.
Torque all connections to 16200# and
double bump. Verify with make up by
hash marks.
Pipe dope BOL, AG 2000 pipe dope.
from surface to 1357' MD
When making up joint #7 to joint #6 the
make up hash marks indicated that the
connection was not properly made up.
Torque was double checked and still no
good. Joint #7 and joint #6 were pulled
and replaced by joints #72 and #73.
0.0 1,357.0
3/12/2024
21:30
3/13/2024
00:00
2.50 SURFAC, CASING PULD T Obstruction encountered @ 1357' MD
Attempt to work staging up pumps from
103/231 GPM, 160/210 PSI
F/O 55%
P/U 97k
S/O 84K
1,357.0 1,357.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 9/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/13/2024
00:00
3/13/2024
06:00
6.00 SURFAC, CASING REAM T Obstruction encountered @ 1357' MD
Attempt to work staging up pumps from
103/269 GPM, 133 PSI
Work casing with varying parameters
from 1357' MD to 1360' MD.
GPM 269
PSI 133
F/O 55%
P/U 97k
S/O 84K
Pump 25 bbl nut plug and drill zone
sweep.
Pump 25 bbl nut plug and SAPP sweep.
Minimal cuttings observed at shakers.
1,357.0 1,360.0
3/13/2024
06:00
3/13/2024
12:00
6.00 SURFAC, CASING REAM T Continue working through obstruction
encountered @ 1360' MD Attempt to
work staging up pumps from 103/294
GPM, 133 PSI
Work casing with varying parameters
from 1357' MD to 1363' MD.
GPM 294
PSI 133
F/O 55%
P/U 97k
S/O 84K
Pump 20 bbl weighted H2O sweep
followed by 25 bbl HiVis nut plug sweep.
Minimal cuttings observed at shakers.
1,360.0 1,363.0
3/13/2024
12:00
3/13/2024
13:00
1.00 SURFAC, CASING REAM T Continue to work through obstruction
encountered @ 1357' MD Attempt to
work staging up pumps from 103/294
GPM, 133 PSI
Work casing with varying parameters
from 1357' MD to 1363' MD.
GPM 294
PSI 133
F/O 55%
P/U 97k
S/O 84K
Various RPM and pump rate parameters
tried to move through obstruction.
1,363.0 1,363.0
3/13/2024
13:00
3/14/2024
00:00
11.00 SURFAC, CASING PUTB P RIH, Washing and rotating down from
1363'MD to 2150'MD with 10-3/4" 45.5#
L-80 Hyd 563 surface casing as per
casing detail. Torque all connections to
16200# and double bump. Verify with
make up by hash marks. Pipe dope
BOL, AG 2000 pipe dope. While
washing down through tight hole
obstructions coming out of hole over
shakers was heavy clay, gravel large 4"
small pea size, and wood. Pumped 2
nut plug, soap and drillzone sweeps to
help clean up well.
GPM 294
PSI 171
F/O 55%
P/U 113k
ROT 10
1,363.0 2,150.0
3/14/2024
00:00
3/14/2024
04:15
4.25 SURFAC, CASING PUTB P From 2150' to 2670' MD wash and
rotate 10-3/4" casing
GPM 294
RPM 10
PSI 200
F/O 35%
RTW 132k
TQ 10-13K
2,150.0 2,670.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 10/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/14/2024
04:15
3/14/2024
05:30
1.25 SURFAC, CASING CIRC P Pick up joint #68 wash and rotate to
bottom to verify hanger can be run with
no rotation.
GPM 336
RPM 10
PSI 213
PUW 132K
SOW 120K
RTW 117K
TQ 12
Pump 30 bbl nut plug/soap/drillzone
sweep.
2,670.0 2,670.0
3/14/2024
05:30
3/14/2024
06:00
0.50 SURFAC, CASING PUTB P L/D joint #68 to pipe shed Blow down
top drive and drain BOP stack, inspect
landing profile.
2,670.0 2,670.0
3/14/2024
06:00
3/14/2024
06:30
0.50 SURFAC, CASING HOSO P Pick up Cameron 10-3/4" hanger
assembly as per Cameron rep.
Make up to landing joint and run in hole
to set at 2712.93' MD.
2,670.0 2,712.9
3/14/2024
06:30
3/14/2024
08:30
2.00 SURFAC, CEMENT CIRC P Circulate and condition mud for cement
job,
GPM 336
PSI 225
PUW 132K
SOW 117K
Initially reciprocating pipe, hanger
appears to be tagging inner component
on starting head or riser. Stop
reciprocation and land out hanger on
depth 2712.9 MD.
2,712.9 2,712.9
3/14/2024
08:30
3/14/2024
11:00
2.50 SURFAC, CEMENT CIRC P PJSM and blow down top drive, R/U
cement hose and equipment for surface
cement job establish circulation through
cement hose.
GPM 6 BPM
PSI 225
circulated for 13365 stokes.
2,712.9 2,712.9
3/14/2024
11:00
3/14/2024
15:45
4.75 SURFAC, CEMENT CMNT P Cement 10-3/4" 45.5# L-80 surface
hanger as per Halliburton pump
schedule. Flood lines with % bbls
H2O@ 5 BPM, pressure test lines to
3500 PSI, pump 60 bbl 10.2 ppg Tuned
primed spacer with 8lb of red dye at 3-5
BPM 35 psi. Shut down pumps and drop
bottom plug. Pump 387 bbls of 10.7 ppg
lead cement at 3-5 BPM 24 psi. Pump
57 Bbls of 15.8 ppg tail cement at 3-5
BPM. Shut down and drop top plug.
Flush with 20 Bbls of fresh water and
chase with rig mud pumps 9.8 ppg spud
mud. Displace cement at 6 BPM. ICP
122 PSI reduce rate to 3 BPM at 2256
stokes FCP 461 psi.
Did not have positive indication of
bottom float shear.
Pumped max of 2350 strokes and did
not bump, pumped additional 10 strokes
and did not bump.
Bled off pressure and positive indication
that the floats are holding.
Cement in place at 15:30 hrs.
ICP 113 PSI
FCP 580 PSI
No losses observed.
60 Bbl spacer and 28 Bbls cement
returns to surface.
2,712.9 2,712.9
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 11/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/14/2024
15:45
3/14/2024
19:00
3.25 SURFAC, CEMENT RURD P Blow down cement lines, Rig Down
Volant CRT flush riser, clean up from
cement job.
2,712.9 2,712.9
3/14/2024
19:00
3/14/2024
23:00
4.00 SURFAC, WHDBOP NUND P Nipple down surface riser and Cameron
starter head. Remove starter head from
cellar. SIMOPS: Clean up pits and
pumps
0.0 0.0
3/14/2024
23:00
3/15/2024
00:00
1.00 SURFAC, WHDBOP NUND P Nipple up Cameron wellhead, Test to
5000 psi 10 minutes. Witness by CPAI
Rep.
0.0 0.0
3/15/2024
00:00
3/15/2024
06:00
6.00 SURFAC, WHDBOP NUND P Nipple up spacer spool, BOP stack,
Kill/Choke lines, Lay down 20" surface
riser, remove 4" Conductor valves.
Install inner/outer annulus valves.
SIMOPS load row of 7-5/8" casing in
pipe shed and clean pits.
0.0 0.0
3/15/2024
06:00
3/15/2024
08:30
2.50 SURFAC, WHDBOP MPDA P PJSM Install test plug W/ 5" test joint,
R/U RCD head, orbit valve and 2" RCD
hardlines and 1502 equipment. Test cap
seal and RCD clamp function, Obtain
RKB's.
0.0 0.0
3/15/2024
08:30
3/15/2024
09:30
1.00 SURFAC, WHDBOP MPDA P Rig up and flood RCD and related MPD
equipment and purge air from system.
0.0 0.0
3/15/2024
09:30
3/15/2024
09:45
0.25 SURFAC, WHDBOP MPDA P Pressure test RCD and related MPD
piping and valves to 250 low psi and
1250 high psi for 5 minutes low and 10
minutes high.
0.0 0.0
3/15/2024
09:45
3/15/2024
10:45
1.00 SURFAC, WHDBOP SVRG P Frozen line found on test pump. Service
rig while replumb water supply line to
test pump.
0.0 0.0
3/15/2024
10:45
3/15/2024
11:30
0.75 SURFAC, WHDBOP MPDA P Continue pressure test RCD and related
MPD piping and valves to 250 low psi
and 1250 high psi for 5 minutes low and
10 minutes high.
0.0 0.0
3/15/2024
11:30
3/15/2024
13:00
1.50 SURFAC, WHDBOP RURD P Rig down MPD test lines, remove RCD
test cap.
Install MPD trip nipple and adjust stack
alignment.
Secure stack for BOP test.
0.0 0.0
3/15/2024
13:00
3/15/2024
20:30
7.50 SURFAC, WHDBOP BOPE P Test BOPE to 250 low, 5,000 high for
5/5 charted min. w/ the exception of the
manual operated & super choke tested
to 2,000 psi. With 7-5/8” and 5" test jts.
test annular, 7-5/8" upr and 3.5" x 6"
lower vbr's, choke valves 1-14, manual
operated and super choke, choke & kill
manuals and HCR's, 4" kill line, 4"
FOSV (x2), 4" dart valve. Test upper
and lower IBOP with blind shear rams.
Perform Koomey drawdown - acc - 3000
psi, manifold - 1600 psi, acc - 1875 after
all functions, 9 sec for 200 psi build w/ 2
elec pumps, 47 sec to build full system
psi w/ 2 elec pumps and 2 air pumps.
Closing times for annular - 20 sec, upr -
7 sec, blind / shears - 7 sec, lwr - 7 sec,
choke HCR - 1 sec, kill HCR - 1 sec. 6
bottle nitrogen backup ave. - 2000 psi.
Test PVT gain/loss and flow out alarms.
Test LEL and H2S alarms. AOGCC rep
Austin McLeod waived witness.
0.0 0.0
3/15/2024
20:30
3/15/2024
21:30
1.00 SURFAC, WHDBOP RURD P Pull test plug and test joint, Rig down
test equipment, Blow down Choke and
kill lines. Line up choke manifold for
drilling operations
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 12/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/15/2024
21:30
3/15/2024
22:00
0.50 SURFAC, WHDBOP WWSP P Set wear bushing Length 30 3/4" OD =
10 3/4" ID = 10"
0.0 0.0
3/15/2024
22:00
3/16/2024
00:00
2.00 SURFAC, WHDBOP SLPC P PJSM slip and cut drill line as per SOP
132' 9 wraps
0.0 0.0
3/16/2024
00:00
3/16/2024
01:00
1.00 SURFAC, WHDBOP SLPC P Slip and cut drilling line. 0.0 0.0
3/16/2024
01:00
3/16/2024
01:30
0.50 SURFAC, WHDBOP SVRG P Conduct rig service. 0.0 0.0
3/16/2024
01:30
3/16/2024
02:30
1.00 SURFAC, DRILLOUT BHAH P Mobilize INT BHA to rig floor through
beaver slide.
0.0 0.0
3/16/2024
02:30
3/16/2024
07:30
5.00 SURFAC, DRILLOUT BHAH P PJSM make up 9-7/8" INT BHA as per
SLB DD/MWD to 331' MD.
Observed Ice plug in collar stand, rack
back in derrick and attempt to thaw with
steam unsuccessfully. Break down
stand and clear ice plug. Continue to
M/U BHA, single in hole with 6 joints
HWDP from pipe shed,
0.0 331.0
3/16/2024
07:30
3/16/2024
11:30
4.00 SURFAC, DRILLOUT TRIP P Trip in hole from 331' MD to 989' with 7
stands of HWDP from pipeshed, 5"
HWDP in derrick is plugged with ice.
Steam drillpipe to thaw ice verify pipe its
clear and RIH.
331.0 989.0
3/16/2024
11:30
3/16/2024
12:30
1.00 SURFAC, DRILLOUT TRIP P RIH from 989' MD to 1549' with 5"
drillpipe from derrick,
PUW 90K
SOW 90K
989.0 1,549.0
3/16/2024
12:30
3/16/2024
13:30
1.00 SURFAC, DRILLOUT TRIP P RIH from 1549' MD to 2401' MD with 5"
drill pipe from derrick.
1,549.0 2,401.0
3/16/2024
13:30
3/16/2024
14:00
0.50 SURFAC, DRILLOUT CIRC P Connect top drive and circulate and
condition mud for casing test. Shallow
test MWD tools. Blow down top drive.
2,401.0 2,401.0
3/16/2024
14:00
3/16/2024
15:45
1.75 SURFAC, DRILLOUT PRTS P Test 10 3/4" surface casing to 3000 psi
for 30 minutes. Monitoring via Totco
sensor and annular, Pumped 4.7 bbls,
Bled off pressure, pressure loss was
unacceptable.
2,401.0 2,401.0
3/16/2024
15:45
3/16/2024
16:15
0.50 SURFAC, DRILLOUT CIRC P @ 2401' MD circulate and condition
mud for casing test.
GPM 246,
PSI 472
F/O 34%
Total strokes 1520.
2,401.0 2,401.0
3/16/2024
16:15
3/16/2024
17:30
1.25 SURFAC, DRILLOUT PRTS P Test 10 3/4" surface casing to 3000 psi
for 30 minutes. Monitor via Totco sensor,
and lower pipe rams. Pumped 3.2 bbls.
(Good Test ) Volume bled back was 3.0
bbls
2,401.0 2,401.0
3/16/2024
17:30
3/16/2024
18:00
0.50 SURFAC, DRILLOUT RURD P Rig down testing equipment and ready
rig floor to drill out 10 3/4" shoe track
2,401.0 2,401.0
3/16/2024
18:00
3/16/2024
19:00
1.00 SURFAC, DRILLOUT REAM P Wash down from 2401' MD to 2592' MD
GPM 250
PSI 280
F/O 25%
ECD 10.23
P/U 111k
S/O 106k
RT 109k
Tag top of cement 2592', set down 15k
to verify
2,401.0 2,592.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 13/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/16/2024
19:00
3/17/2024
00:00
5.00 SURFAC, DRILLOUT DRLG P Drill 10 3/4" cement and shoe track and
rat hole from 2592' MD to 2720' MD as
per SLB DD.
GPM 650
PSI 1665
RPM 80
TQ 5/8
ECD 10.23
2,592.0 2,720.0
3/17/2024
00:00
3/17/2024
00:30
0.50 SURFAC, DRILLOUT DDRL P Directionally drill 9-7/8" hole section
from 2720' MD to 2740' MD
GPM 650
PSI 1665
F/O 48%
ECD 10.23
RPM 80
WOB 6K
TQ 6K
Collect SCR's @ 00:15 2700' MD 2564'
TVD
MP#1 - 30 SPM - 100 PSI 40 SPM - 130
PSI
2,720.0 2,740.0
3/17/2024
00:30
3/17/2024
01:30
1.00 SURFAC, DRILLOUT CIRC P Circulate and condition well for FIT test
GPM 550
PSI 1287
F/O 42%
ECD 10.20
RPM 80
WOB 6K
TQ 4K
RW 113K
Pumped 7725 strokes.
2,740.0 2,740.0
3/17/2024
01:30
3/17/2024
02:30
1.00 SURFAC, DRILLOUT LOT P Rig up for FIT/LOT test and perform
test. Pressure up down drill string at 6
SPM, and observed leak at 545 psi
(13.8 EMW). Shut in and monitor
pressure for 10 minutes. Pressure
decrease and stabilized at 411 PSI.
Pumped1.4 bbls 9.7 spud mud and bled
back 1 bbl. Max test pressure 646 psi.
2,740.0 2,740.0
3/17/2024
02:30
3/17/2024
03:30
1.00 INTRM1, DRILL DISP P Displace well to 9.0 ppg FWP
GPM 900
PSI 643
F/O 43%
RPM 30
TQ 3.5K
2,740.0 2,740.0
3/17/2024
03:30
3/17/2024
06:00
2.50 INTRM1, DRILL DDRL P Directionally drill 9-7/8" hole section
from 2740' MD to 2803' MD as per
program with the following parameters,
GPM 700
PSI 1150
F/O 47%
ECD 9.73
RPM 100
WOB 5K
TQ 4.5K
2,740.0 2,803.0
3/17/2024
06:00
3/17/2024
12:00
6.00 INTRM1, DRILL DDRL P Directionally drill 9-7/8" hole section
from 2803' MD to 3253' MD as per
program with the following parameters,
GPM 753
PSI 1406
F/O 51%
ECD 9.93
RPM 120
WOB 3.2K
TQ 5.4K
2,803.0 3,253.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 14/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/17/2024
12:00
3/17/2024
18:00
6.00 INTRM1, DRILL DDRL P Directionally drill 9-7/8" hole section
from 3253' MD to 3914' MD as per
program with the following parameters,
GPM 753
PSI 1406
F/O 51%
ECD 9.93
RPM 120
WOB 3.2K
TQ 5.4K
3,253.0 3,914.0
3/17/2024
18:00
3/18/2024
00:00
6.00 INTRM1, DRILL DDRL P Directionally drill 9-7/8" hole section
from 3914' MD to 4447' MD as per
program with the following parameters,
GPM 750
PSI 1818
F/O 52%
ECD 10.82
RPM 130
WOB 10K
TQ 6.0K
3,914.0 4,447.0
3/18/2024
00:00
3/18/2024
06:00
6.00 INTRM1, DRILL DDRL P Directionally drill 9-7/8" hole section
from 4447' MD to 4674' MD as per
program with the following parameters,
GPM 750
PSI 1665
F/O 49%
ECD 10.45
RPM 150
WOB 4K
TQ 3.5K
PUW 123K
SOW 120K
RTW 120K
4,447.0 4,674.0
3/18/2024
06:00
3/18/2024
12:00
6.00 INTRM1, DRILL DDRL P Directionally drill 9-7/8" hole section
from 4674' MD to 5170' MD as per
program with the following parameters,
GPM 750
PSI 1777
F/O 48%
ECD 10.56
RPM 150
WOB 8K
TQ 3.5K
PUW 129K
SOW 129K
RTW 131K
4,674.0 5,170.0
3/18/2024
12:00
3/18/2024
18:00
6.00 INTRM1, DRILL DDRL P Directionally drill 9-7/8" hole section
from 5170' MD to 5727' MD as per
program with the following parameters,
GPM 750
PSI 1777
F/O 48%
ECD 10.56
RPM 150
WOB 8K
TQ 3.5K
PUW 129K
SOW 129K
RTW 131K
5,170.0 5,727.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 15/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/18/2024
18:00
3/19/2024
00:00
6.00 INTRM1, DRILL DDRL P Directionally drill 9-7/8" hole section
from 5727' MD to 6094' MD as per
program with the following parameters,
GPM 750
PSI 1777
F/O 48%
ECD 10.56
RPM 150
WOB 8K
TQ 3.5K
PUW 129K
SOW 129K
RTW 131K
5,727.0 6,094.0
3/19/2024
00:00
3/19/2024
06:00
6.00 INTRM1, DRILL DDRL P Directionally drill 9-7/8" hole section
from 6094' MD to 6460' MD as per
program with the following parameters,
GPM 750
PSI 1884
F/O 47%
ECD 10.37
RPM 160
WOB 7K
TQ 6K
PUW 144K
SOW 139K
RTW 133K
6,094.0 6,460.0
3/19/2024
06:00
3/19/2024
12:00
6.00 INTRM1, DRILL DDRL P Directionally drill 9-7/8" hole section
from 6460' MD to 7216' MD as per
program with the following parameters,
GPM 750
PSI 2190
F/O 47%
ECD 11.20
RPM 160
WOB 7K
TQ 6K
PUW 151K
SOW 139K
RTW 141K
6,460.0 7,216.0
3/19/2024
12:00
3/19/2024
18:00
6.00 INTRM1, DRILL DDRL P Directionally drill 9-7/8" hole section
from 7,216' MD to 7,875' MD as per
program with the following parameters,
GPM 750
PSI 2198
F/O 49%
ECD 10.97
RPM 160
WOB 15.5K
TQ 7.5K
PUW 156K
SOW 143K
RTW 135K
7,216.0 7,875.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 16/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/19/2024
18:00
3/20/2024
00:00
6.00 INTRM1, DRILL DDRL P Directionally drill 9-7/8" hole section
from 7,875' MD to 8,438' MD as per
program with the following parameters,
GPM 750
PSI 2227
F/O 47%
ECD 10.73
RPM 160
WOB 14K
TQ 7.5K
PUW 161K
SOW 145K
RTW 145K
Formation losses last 24 hours: 0 bbls
Total interval formation losses: 0 bbls
7,875.0 8,438.0
3/20/2024
00:00
3/20/2024
07:00
7.00 INTRM1, DRILL DDRL P Directionally drill 9-7/8" hole section
from 8,438' MD to 8,965' MD as per
program with the following parameters,
GPM 750
PSI 2265
F/O 47%
ECD 10.54
RPM 160
WOB 11K
TQ 7.5K
PUW 161K
SOW 145K
RTW 145K
8,438.0 8,965.0
3/20/2024
07:00
3/20/2024
08:00
1.00 INTRM1, DRILL DDRL P Directionally drill 9-7/8" hole section
from 8,965' MD to 9,016' MD as per
program with the following parameters,
GPM 750
PSI 2265
F/O 47%
ECD 10.54
RPM 160
WOB 11K
TQ 7.5K
PUW 162K
SOW 138K
RTW 145K
8,965.0 9,016.0
3/20/2024
08:00
3/20/2024
09:00
1.00 INTRM1, TRIPCAS CIRC P Circulate and reciprocate from 9016' MD
to 8915' MD. Obtain final survey while
circulate around spike fluid to increase
MDWT to 9.5 ppg.
GPM 750
PSI 2362
F/O 49%
ECD 10.83
RPM 160
WOB 11K
TQ 4.5K
Final parameters
PUW 152K
SOW 147K
RTW 147K
TQ 4.5K
Collect SCR's at 8900' MD 5119' TVD
#1MP - 30 SPM 340 psi 40 SPM - 360
psi
#2MP - 30 SPM 340 psi 40 SPM - 360
psi
9,016.0 8,915.0
3/20/2024
09:00
3/20/2024
09:15
0.25 INTRM1, TRIPCAS OWFF P Perform 15 minute flow check. 8,915.0 8,915.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 17/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/20/2024
09:15
3/20/2024
11:00
1.75 INTRM1, TRIPCAS BKRM P BROOH at full drilling parameters. Rack
back first 3 stands one bottoms up per
stand from 8915' MD to 8725' MD
PSI 2275
F/O 48%
ECD 10.93
RPM 160
TQ 4.5K
PUW 138K @ rate.
8,915.0 8,725.0
3/20/2024
11:00
3/20/2024
18:00
7.00 INTRM1, TRIPCAS BKRM P BROOH at full drilling parameters,
laying down singles (21 stds) to pipe
shed from 8725' MD to 6725' MD
PSI 1966
F/O 48%
ECD 10.81
RPM 160
TQ 3.5K
PUW 130K @ rate.
8,725.0 6,725.0
3/20/2024
18:00
3/21/2024
00:00
6.00 INTRM1, TRIPCAS BKRM P BROOH at full drilling parameters,
laying down singles (16 stds) to pipe
shed from 6725' MD to 5,122' MD.
Observing a steady stream of cuttings
across the shakers. No unloading
event.
PSI 1745
F/O 49%
ECD 10.73
RPM 160
TQ 4K
PUW 124K @ rate.
Formation losses last 24 hours: 0 bbls
Total interval formation losses: 0 bbls
6,725.0 5,122.0
3/21/2024
00:00
3/21/2024
09:45
9.75 INTRM1, TRIPCAS BKRM P BROOH at full drilling parameters,
laying down singles to pipe shed from
5122' MD to 2690' MD. Observing a
steady stream of cuttings across the
shakers. No unloading event.
PSI 1476
F/O 47%
ECD 10.59
RPM 160
TQ 2K
PUW 122K @ rate.
Noted ECD spike at 3005" MD to 16.8,
slowed down pull speed and ECD
dropped quickly, no losses observed.
Pump HiVis Nut plug sweep and
witnessed slight hole unloading.
Pulled into shoe with no rotation noted
slight increase in ECD, no over pull
noted.
5,122.0 2,690.0
3/21/2024
09:45
3/21/2024
10:30
0.75 INTRM1, TRIPCAS CIRC P Circulate while rotate and reciprocate
from 2690' MD to 2595' MD
PSI 1498
F/O 47%
ECD 10.42
RPM 160
TQ 2K
PUW 111K @ rate.
Pump 25 bbl HiVis nut plug sweep on
second bottoms up, increase in material
from sweep but no significant unloading
noted.
2,690.0 2,595.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 18/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/21/2024
10:30
3/21/2024
12:00
1.50 INTRM1, TRIPCAS BKRM P BROOH at full drilling parameters,
laying down singles to pipe shed from
2595' MD to 2120' MD. Observing a
steady stream of cuttings across the
shakers. No unloading event.
PSI 1438
F/O 47%
ECD 10.49
RPM 160
TQ 1.5K
PUW 105K @ rate.
2,595.0 2,120.0
3/21/2024
12:00
3/21/2024
14:15
2.25 INTRM1, TRIPCAS BKRM P BROOH at full drilling parameters,
laying down singles to pipe shed from
2120' MD to 1555' MD. Observing a
steady stream of cuttings across the
shakers. No unloading event. Cutting
diminished to very little at 1550' MD
PSI 1295
F/O 47%
ECD 10.23
RPM 160
TQ 1K
PUW 100K @ rate.
Pump 25 bbl HiVis nut plug sweep at
1600' MD.
2,120.0 1,555.0
3/21/2024
14:15
3/21/2024
14:30
0.25 INTRM1, TRIPCAS OWFF P Perform flow check (well static). 1,555.0 1,555.0
3/21/2024
14:30
3/21/2024
17:30
3.00 INTRM1, TRIPCAS PULD P Pull out of hole laying down singles to
the pipe shed. From 1555' to 1,050'
BHA,
Hole fill running, monitor displacement
via trip tank.
PUW 46K
1,555.0 1,050.0
3/21/2024
17:30
3/21/2024
18:00
0.50 INTRM1, TRIPCAS OWFF P PJSM L/D BHA and perform flow check
verified well static.
1,050.0 1,050.0
3/21/2024
18:00
3/21/2024
20:00
2.00 INTRM1, TRIPCAS BHAH P L/D HWDP, Drill Collars and MWD
components as per SLB DD/MWD Rep.
1,050.0 0.0
3/21/2024
20:00
3/21/2024
20:30
0.50 INTRM1, CASING BHAH P Clean and clear rig floor. 0.0 0.0
3/21/2024
20:30
3/21/2024
21:30
1.00 INTRM1, CASING WWWH P Flush BOPE w/ 600 GPM, 20 PSI, 10
RPM.
SIMOPS - Mobilize 7-5/8" csg running
equipment to the rig floor.
0.0 0.0
3/21/2024
21:30
3/22/2024
00:00
2.50 INTRM1, CASING RURD P Drain stack to pull wear bushing.
Observe clay buildup inside BOPE. Re-
flush BOPE w/ 880 GPM, 88 psi, 10
rpm. Drain stack and observe the clay
column still inside the stack. Decision
made to pull wear bushing as per
Cameron Rep. Observe large build up
of clay on wear bushing. Decision made
to re-flush the stack with 5" test jt and
closed floor valve to help aid in breaking
down the clay column build up with 200-
250 gpm, 1700-2231 psi, 25 rpm
(successful).
SIMOPS - Mobilize 7-5/8" csg running
equipment to the rig floor.
0.0 0.0
3/22/2024
00:00
3/22/2024
01:00
1.00 INTRM1, CASING RURD P Blow down top drive/choke and clean rig
floor.
0.0 0.0
3/22/2024
01:00
3/22/2024
03:00
2.00 INTRM1, CASING RURD P Rig up 7-5/8" Volant and bail
extensions, elevators power tongs and
FOSV X/O, mobilize hanger and pack
off assembly.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 19/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/22/2024
03:00
3/22/2024
06:00
3.00 INTRM1, CASING PUTB P Run 7-5/8" 29.7# L-80 HYD 563 casing
from surface to 1006' MD Monitor
displacement on Pit #1 & #2. Pump
through shoe track verify floats are
holding.
Continue RIH filling on the fly and
topping off every 10 stands.
PUW 69K
SOW 72K
Make up torque 33.7# to 12,100 ft/lb
Make up torque 29.7# to 10,300 ft/lb
0.0 1,006.0
3/22/2024
06:00
3/22/2024
09:00
3.00 INTRM1, CASING PUTB P Run 7-5/8" 29.7# L-80 HYD 563 casing
from 1006' MD to 2705' MD Monitor
displacement on Pit #1 & #2.
Filling on the fly and topping off every 10
stands.
SOW 108K
Make up torque 29.7# to 10,300 ft/lb
1,006.0 2,705.0
3/22/2024
09:00
3/22/2024
10:00
1.00 INTRM1, CASING CIRC P Circulate bottoms up starting at 2705'
with .5 BPM and working up to 6 BPM
in .5 BPM increments.
107 PSI
PUW 106K
SOW 107K
Total 1520 strokes pumped.
2,705.0 2,705.0
3/22/2024
10:00
3/22/2024
12:45
2.75 INTRM1, CASING PUTB P Run 7-5/8" 29.7# L-80 HYD 563 casing
from 2705' MD to 4240' MD Monitor
displacement on Pit #1 & #2.
Filling on the fly and topping off every 10
stands.
SOW 108K
Make up torque 33.7# to 12,100 ft/lb
Make up torque 29.7# to 10,300 ft/lb
2,705.0 4,240.0
3/22/2024
12:45
3/22/2024
13:30
0.75 INTRM1, CASING CIRC P Circulate bottoms up starting at 4200'
with .5 BPM and working up to 6 BPM
in .5 BPM increments.
162 PSI
PUW 106K
SOW 125K
Total 2188 strokes pumped.
4,240.0 4,240.0
3/22/2024
13:30
3/22/2024
22:00
8.50 INTRM1, CASING PUTB P Run 7-5/8" 29.7# L-80 HYD 563 casing
from 4240' MD to 8,887' MD Monitor
displacement on Pit #1 & #2.
Filling on the fly and topping off every 10
stands.
SOW 147K
Make up torque 29.7# to 10,300 ft/lb
4,240.0 8,887.0
3/22/2024
22:00
3/22/2024
22:30
0.50 INTRM1, CASING WASH P Run 7-5/8" 29.7# L-80 HYD 563 casing
from 8,887' MD to 8,971' MD washing
down @ 2 BPM, 324 PSI.
SOW 148K
Make up torque 29.7# to 10,300 ft/lb
8,887.0 8,971.0
3/22/2024
22:30
3/22/2024
22:45
0.25 INTRM1, CASING HOSO P Pick up hanger and landing jt. Wash
down from 8,971' MD to 9,011' MD @ 2
BPM, 351 PSI.
SOW 147K
Make up torque 29.7# to 10,300 ft/lb
8,971.0 9,011.0
3/22/2024
22:45
3/23/2024
00:00
1.25 INTRM1, CEMENT CIRC P Circulate and condition mud while recip
pipe from 9,011' MD to 8,996' MD
staging pumps up to 6 BPM, 351 PSI,
20% F/O, Up Wt - 172K, S/O Wt - 137K.
9,011.0 9,011.0
3/23/2024
00:00
3/23/2024
01:15
1.25 INTRM1, CEMENT CIRC P Circulate and condition mud while recip
pipe from 9,011' MD to 8,996' MD
staging pumps up to 6 BPM, 385 PSI,
20% F/O, Up Wt - 176K, S/O Wt - 143K.
SIMOP: Conduct Cement job PJSM with
parties involved.
9,011.0 9,011.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 20/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/23/2024
01:15
3/23/2024
01:45
0.50 INTRM1, CEMENT RURD P Rig down Volant and rig up Halliburton
cement head, preload wiper plug in
head and 1st bottom wiper in string.
9,011.0 9,011.0
3/23/2024
01:45
3/23/2024
05:30
3.75 INTRM1, CEMENT CMNT P Cement 7-5/8" intermediate casing
string.
Drop 1st bottom wiper plug, flood lines
with water and pressure test lines to
4000 psi.
Pump 60 bbls of 10.5 ppg tuned primed
spacer at 4 BPM and 360 psi.
Drop 2nd bottom wiper plug and pump
201 bbls of 15.3 ppg primary cement
with BMII at 4 BPM and 100 PSI ICP.
Follow with 22 bbls of 15.3 ppg primary
cement without BMII at 4 BPM. Shut
down cement pumps and drop top wiper
plug.
Pump 20 bbls 8.33 ppg fresh water. Line
up on rig mud pumps to displace
cement with 389.5 bbls of 9.5 ppg FWP
at 8 BPM.
151 psi ICP. Pump at 8 BPM to1919
strks, slow rate to 6 BPM 1016 psi and
pump to 3713 stks and slow rate to 3
BPM at 3915 strks.
Did not bump plugs. FCP 1140 psi.
Cement in place at 04:56. Bleed down
pressure and check floats, floats are
holding.
9,011.0 9,011.0
3/23/2024
05:30
3/23/2024
06:30
1.00 INTRM1, CEMENT RURD P Rig down cementers blow down cement
line. Demobilize cement equipment from
rig floor.
0.0 0.0
3/23/2024
06:30
3/23/2024
08:00
1.50 INTRM1, CEMENT RURD P Rig down casing running equipment and
lay down beaverslide. Clean and clear
rig floor.
0.0 0.0
3/23/2024
08:00
3/23/2024
09:30
1.50 INTRM1, CEMENT RURD P Lay down landing joint and rig up to
install 7-5/8" pack-off. Test pack off to
5000 psi, for 10 minutes.
0.0 0.0
3/23/2024
09:30
3/23/2024
10:00
0.50 INTRM1, WHDBOP WWWH P Flush BOP stack preparing from upper
ram change.
675 GPM
495 PSI
0.0 0.0
3/23/2024
10:00
3/23/2024
12:30
2.50 INTRM1, WHDBOP RURD P PJSM and change upper pipe rams.
Remove 7-5/8" solid body rams to 3-1/2"
x 6" VBR's.
0.0 0.0
3/23/2024
12:30
3/23/2024
14:30
2.00 INTRM1, WHDBOP RURD P Rig up to test BOP's, set test plug and
flood lines with water. Shell test to 3500
psi. Change out iron rough neck dies to
4".
Make up TIW and dart valves to test.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 21/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/23/2024
14:30
3/23/2024
20:30
6.00 INTRM1, WHDBOP BOPE P Test BOPE to 250 low, 4,000 high for
5/5 charted min. w/ the exception of the
manual operated & super choke tested
to 2,000 psi. With 4” and 4½" test jts.
test, 3½" x 6" upper and lower, choke
valves 1-14, manual operated and super
choke, choke & kill manuals and HCR's,
4" kill line, 4" FOSV (x2), 4" dart valve.
Test upper and lower IBOP, blind shear
rams. Perform koomey drawdown - acc
- 3000 psi, manifold - 1500 psi, acc -
1575 after all functions, 9 sec for 200 psi
build w/ 2 elec pumps, 54 sec to build
full system psi w/ 2 elec pumps and 2 air
pumps. Closing times for annular - 18
sec, upr - 7 sec, blind / shears - 7 sec,
lwr- 7 sec, choke HCR - 1 sec, kill HCR
- 1 sec. 6 bottle nitrogen backup ave. -
2000 psi. Test PVT gain/loss and flow
out alarms. Test LEL and H2S alarms.
AOGCC rep Kam StJohn waived
witness to the test.
0.0 0.0
3/23/2024
20:30
3/23/2024
21:00
0.50 INTRM1, WHDBOP BOPE T Observed lower rams were missed while
testing with the 4½" test jt. Picked 4½"
test jt up and test lower 3½" x 6" VBR's
to 250 low 4000 high (good).
0.0 0.0
3/23/2024
21:00
3/23/2024
22:00
1.00 INTRM1, DRILLOUT RURD P Install 10" ID wear bushing. RILDS.
SIMOPS - B/D and rig down test
equipment.
0.0 0.0
3/23/2024
22:00
3/23/2024
23:00
1.00 INTRM1, DRILLOUT BHAH P Mobilize production BHA to the rig floor. 0.0 0.0
3/23/2024
23:00
3/23/2024
23:30
0.50 INTRM1, DRILLOUT SFTY P PJSM on picking up BHA with rig crew,
DDX, MWD, Doyon TP, CPAI rep.
0.0 0.0
3/23/2024
23:30
3/24/2024
00:00
0.50 INTRM1, DRILLOUT BHAH P Pick up SLB 6½" production BHA to 22'.
Monitor disp via TT.
0.0 22.0
3/24/2024
00:00
3/24/2024
02:30
2.50 INTRM1, DRILLOUT BHAH P Continue to pick up 6-1/2" production
BHA as per SLB DD/MWD from 22' to
198' MD.
Monitor hole displacement via trip tank.
22.0 198.0
3/24/2024
02:30
3/24/2024
03:30
1.00 INTRM1, DRILLOUT PULD P Single in hole with 4" drill pipe from the
pipe shed from 198' MD to 1081' MD.
Monitor hole displacement via trip tank.
PUW 58K
SOW 62K
Drift 2.30"
198.0 1,081.0
3/24/2024
03:30
3/24/2024
05:00
1.50 INTRM1, DRILLOUT RGRP T Communications loss with Amphion
troubleshoot with rig electrician. Fiber
optic to MOXA system dislocated at
drillers chair.
1,081.0 1,081.0
3/24/2024
05:00
3/24/2024
08:15
3.25 INTRM1, DRILLOUT PULD P Single in hole with 4" drill pipe from the
pipe shed from 1081' MD to 2930' MD.
Monitor hole displacement via trip tank.
SOW 84K
Drift 2.30"
1,081.0 2,930.0
3/24/2024
08:15
3/24/2024
08:45
0.50 INTRM1, DRILLOUT DHEQ P Shallow test MWD tools with downlinks.
GPM 250
PSI 1435
F/O 22%
SOW 85K
2,930.0 2,930.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 22/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/24/2024
08:45
3/24/2024
12:00
3.25 INTRM1, DRILLOUT QEVL P Perform real time logging @ 450 FPH.
Logged free ringing pipe from 2930' to
first presence of cement at 3357' MD,
good cement noted at 3549' MD.
Continue logging to 3967' MD for 300
feet of good cement logged. Depths
noted require final interpretation by
Petrophysicist.
2,930.0 3,970.0
3/24/2024
12:00
3/24/2024
12:30
0.50 INTRM1, DRILLOUT RURD P Down link tools to memory fast mode.
Blow down top drive and rig up to trip on
elevators.
3,970.0 3,970.0
3/24/2024
12:30
3/24/2024
13:15
0.75 INTRM1, DRILLOUT PULD P Run in hole with 4" drill pipe stands from
the derrick 3970' MD to 4828' MD.
Monitor hole displacement Pit #1, PP#2.
SOW 92K
Drift 2.30"
3,970.0 4,828.0
3/24/2024
13:15
3/24/2024
20:00
6.75 INTRM1, DRILLOUT PULD P Run in hole with 4" drill pipe stands from
the derrick 4828' MD to 8,775' MD.
Monitor hole displacement Pit #1, PP#2.
SOW 126K
Drift 2.30"
SIMOPS: Conduct injectivity test on 10-
3/4" x 7-5/8" OA. With 9.5 ppg mud
pressure up to max of 661 psi. Shut in
for 10 minutes to final pressure of 438
psi. Achieve 14.5 EMW FIT. Charted on
Totco OA channel and LOT form.
4,828.0 8,775.0
3/24/2024
20:00
3/24/2024
21:45
1.75 INTRM1, DRILLOUT CIRC P Wash down from 8,775' MD to 8,806'
MD w/ 268 GPM, 2465 PSI, 25% F/O,
40 RPM, 4.6K TQ. Observe cement
stringers. Continue to circ and condtion
mud for csg test. Total stks pumped -
5582 (562 bbls).
8,775.0 8,806.0
3/24/2024
21:45
3/24/2024
23:00
1.25 INTRM1, DRILLOUT PRTS P Pressure test 7-5/8" csg to 4000 psi.
6.3 bbs to pressure up. 6 bbls bled
back (good).
8,806.0 8,806.0
3/24/2024
23:00
3/25/2024
00:00
1.00 INTRM1, DRILLOUT REAM P Continue to wash and ream in the hole
from 8,806' MD to 8,888' MD.
Observing intermittent cement stringers
taking 3-7K WOB. Wash and ream dn
w/ 250 GPM, 2183 PSI, 50 RPM, 6K
TQ, 23% F/O.
8,806.0 8,888.0
3/25/2024
00:00
3/25/2024
01:30
1.50 INTRM1, DRILLOUT DRLG P Wash in hole from 8,888' MD to 8915'
MD. Drill float collar from 8915' to 8920'
MD. Continue drilling firm cement to
8966' MD.
GPM 250
PSI 2352
RPM 50
TQ 7.5K
FO 22%
8,888.0 8,966.0
3/25/2024
01:30
3/25/2024
03:30
2.00 INTRM1, DRILLOUT DISP P Circulate bottoms up and displace well
from 9.5 FWP to 9.0 NAF, pump 100 bbl
deep clean spacer followed by 345 bbls
of NAF, total strokes pumped 4662.
Noted 40 bbls interface to surface
between deep clean spacer and NAF.
8,966.0 8,966.0
3/25/2024
03:30
3/25/2024
07:00
3.50 INTRM1, DRILLOUT CLEN P Blow down top drive and clean pits and
surface system to remove remnants of
FWP mud. Bring on LVT to pit #7 and
condition NAF.
Service top drive.
8,966.0 8,966.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 23/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/25/2024
07:00
3/25/2024
08:00
1.00 INTRM1, DRILLOUT DRLG P Drill shoe track from 8966' MD to 9016'
MD.
Tag shoe at 9007' MD.
GPM 250
PSI 3116
RPM 80
TQ 5.5K
ECD 9.89
FO 22%
8,966.0 9,016.0
3/25/2024
08:00
3/25/2024
08:45
0.75 INTRM1, DRILLOUT DDRL P Drill new hole from 9016' MD to 9036'
MD - 20 foot of new hole for FIT test.
GPM 250
PSI 3133
RPM 80
TQ 5K
WOB 5K
ECD 9.92
FO 19%
9,016.0 9,036.0
3/25/2024
08:45
3/25/2024
10:00
1.25 INTRM1, DRILLOUT CIRC P CBU to clean well bore for FIT/LOT test. 9,036.0 9,036.0
3/25/2024
10:00
3/25/2024
10:15
0.25 INTRM1, DRILLOUT OWFF P Conduct flow check for 15 minutes - well
deemed static.
9,036.0 9,036.0
3/25/2024
10:15
3/25/2024
11:30
1.25 INTRM1, DRILLOUT PRTS P PJSM rig up and perform LOT test.
Use pump #1 at 2 SPM 36 strokes
pumped and bleed off noted at 34
strokes and 1516 psi. Shut in and record
pressure drop for 10 minutes. After
engineer evaluation LOT point
determined to be 14.7 ppg EQV.
9,036.0 9,036.0
3/25/2024
11:30
3/25/2024
13:45
2.25 PROD1, DRILL MPDA P Flow check well while PJSM and install
RCD bearing.
9,036.0 9,036.0
3/25/2024
13:45
3/25/2024
17:00
3.25 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 9,036'
MD to 9,247' / 5,174' TVD, WOB 8k,
GPM 260, PSI 3275, RPM 80, TQ 8k,
ECD 10.16 ppg, MWT 9.0 ppg, P/U
168k, S/O - 135k, ROT 138k, ADT 1.97,
Total bit hrs 2.46, Max gas = 20 units.
Maintaining 10 ppg EMW with MPD @
connections.
9,036.0 9,247.0
3/25/2024
17:00
3/25/2024
18:00
1.00 PROD1, DRILL CIRC P Rot and recip pipe from 9,247' MD to
9,156' MD while circulating 15 bbl, 45
ppg LCM sweep S/S @ GPM 220, PSI
2435, RPM 110, TQ 6.5k, ECD 9.90
ppg. P/U 147k, S/O 138k to help
mitigate discrepancy in SPP vs
modeling.
9,247.0 9,247.0
3/25/2024
18:00
3/26/2024
00:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 9,247'
MD to 9,645' / 5,235' TVD, WOB 5k,
GPM 260, PSI 3295, RPM 120, TQ
8.5k, ECD 10.26 ppg, MWT 9.0 ppg,
P/U 178k, S/O - 108k, ROT 144k, ADT
4.17, Total bit hrs 6.63, Max gas = 39
units. Maintaining 10 ppg EMW with
MPD @ connections.
9,247.0 9,645.0
3/26/2024
00:00
3/26/2024
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 9,945'
MD to 10,140' / 5,262' TVD, WOB 8k,
GPM 260, PSI 3345, RPM 120, TQ
9.5k, ECD 10.37 ppg, MWT 9.0 ppg,
P/U 184k, S/O - 99k, ROT 142k, ADT
4.84, Total bit hrs 11.47, Max gas = 20
units. Maintaining 10 ppg EMW with
MPD @ connections.
9,645.0 10,140.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 24/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/26/2024
06:00
3/26/2024
12:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 10,140'
MD to 10,667' / 5,257' TVD, WOB 5.5k,
GPM 260, PSI 3303, RPM 120, TQ
10.5k, ECD 10.58 ppg, MWT 9.0 ppg,
P/U 183k, S/O - 92k, ROT 135k, ADT
4.43, Total bit hrs 15.90, Max gas = 59
units. Maintaining 10 ppg EMW with
MPD @ connections.
10,140.0 10,667.0
3/26/2024
12:00
3/26/2024
18:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 10,667'
MD to 11,045' / 5,258' TVD, WOB 5.5k,
GPM 260, PSI 3303, RPM 120, TQ
10.5k, ECD 10.58 ppg, MWT 9.0 ppg,
P/U 180k, S/O - 90k, ROT 133k, ADT
4.78, Total bit hrs 20.68, Max gas = 29
units. Maintaining 10.5 ppg EMW with
MPD @ connections.
10,667.0 11,045.0
3/26/2024
18:00
3/27/2024
00:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 11,045'
MD to 11,467' / 5,270' TVD, WOB 5k,
GPM 260, PSI 3471, RPM 110, TQ 13k,
ECD 10.46 ppg, MWT 9.0 ppg, P/U
190k, S/O - 71k, ROT 131k, ADT 5.0,
Total bit hrs 25.68, Max gas = 30 units.
Maintaining 10.5 ppg EMW with MPD @
connections.
11,045.0 11,467.0
3/27/2024
00:00
3/27/2024
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 11,467'
MD to 11,992' / 5,278' TVD, WOB 5.5k,
GPM 260, PSI 3547, RPM 120, TQ 13k,
ECD 10.68 ppg, MWT 9.0 ppg, P/U
195k, S/O - 70k, ROT 126k, ADT 4.64,
Total bit hrs 30.32, Max gas = 30 units.
Maintaining 10.5 ppg EMW with MPD @
connections.
11,467.0 11,992.0
3/27/2024
06:00
3/27/2024
12:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 11,992'
MD to 12,540' / 5,273' TVD, WOB 4k,
GPM 260, PSI 3734, RPM 120, TQ 14k,
ECD 10.82 ppg, MWT 9.0 ppg, P/U
198k, S/O - 64k, ROT 123k, ADT 4.95,
Total bit hrs 35.27, Max gas = 59 units.
Maintaining 10.5 ppg EMW with MPD @
connections.
11,992.0 12,540.0
3/27/2024
12:00
3/27/2024
18:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 12,540'
MD to 12,924' / 5,264' TVD, WOB 5k,
GPM 260, PSI 3685, RPM 120, TQ 11k,
ECD 10.75 ppg, MWT 9.0 ppg, P/U
195k, S/O - 62k, ROT 124k, ADT 4.94,
Total bit hrs 40.21, Max gas = 30 units.
Maintaining 10.5 ppg EMW with MPD @
connections.
12,540.0 12,924.0
3/27/2024
18:00
3/28/2024
00:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 12,924'
MD to 13,313' / 5,250' TVD, WOB 7k,
GPM 270, PSI 3475, RPM 110, TQ 13k,
ECD 10.46 ppg, MWT 9.0 ppg, P/U
198k, S/O - 64k, ROT 123k, ADT 4.01,
Total bit hrs 44.22, Max gas = 59 units.
Maintaining 10.5 ppg EMW with MPD @
connections.
12,924.0 13,313.0
3/28/2024
00:00
3/28/2024
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 13,313'
MD to 13,835' / 5,224' TVD, WOB 7k,
GPM 270, PSI 3545, RPM 120, TQ 10k,
ECD 10.6 ppg, MWT 9.0 ppg, P/U
191k, S/O - 61k, ROT 125k, ADT 4.63,
Total bit hrs 48.85, Max gas = 59 units.
Maintaining 10.6 ppg EMW with MPD @
connections.
13,313.0 13,835.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 25/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/28/2024
06:00
3/28/2024
12:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 13,835'
MD to 14,389' / 5,194' TVD, WOB 7k,
GPM 270, PSI 3622, RPM 120, TQ
9.6k, ECD 10.83 ppg, MWT 9.0 ppg,
P/U 190k, S/O - N/A, ROT 130k, ADT
4.66, Total bit hrs 53.51, Max gas = 116
units. Maintaining 10.8 ppg EMW with
MPD @ connections.
13,835.0 14,389.0
3/28/2024
12:00
3/28/2024
18:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 14,389'
MD to 14,828' / 5,178' TVD, WOB 10k,
GPM 270, PSI 3675, RPM 120, TQ
9.6k, ECD 10.71 ppg, MWT 9.0 ppg,
P/U 193k, S/O - N/A, ROT 118k, ADT
4.72, Total bit hrs 58.23, Max gas = 60
units. Maintaining 10.8 ppg EMW with
MPD @ connections.
14,389.0 14,828.0
3/28/2024
18:00
3/29/2024
00:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 14,828'
MD to 15,395' / 5,170' TVD, WOB 10k,
GPM 270, PSI 3786, RPM 120, TQ 11k,
ECD 10.97 ppg, MWT 9.0 ppg, P/U
195k, S/O - N/A, ROT 122k, ADT 4.38,
Total bit hrs 62.61, Max gas = 98 units.
Maintaining 10.9 ppg EMW with MPD @
connections.
Formation losses last 24 hours: 0 bbls
Total interval formation losses: 0 bbls
14,828.0 15,395.0
3/29/2024
00:00
3/29/2024
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 15,395'
MD to 15,963' / 5,166' TVD, WOB 11k,
GPM 270, PSI 3854, RPM 120, TQ 11k,
ECD 11.20 ppg, MWT 9.0 ppg, P/U
195k, S/O - N/A, ROT 122k, ADT 4.24,
Total bit hrs 66.85, Max gas = 20 units.
Maintaining 10.9 ppg EMW with MPD @
connections.
15,395.0 15,963.0
3/29/2024
06:00
3/29/2024
12:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 15,963'
MD to 16,600' / 5,165' TVD, WOB 12k,
GPM 270, PSI 3967, RPM 120, TQ 12k,
ECD 11.16 ppg, MWT 9.0 ppg, P/U
182k, S/O - N/A, ROT 113k, ADT 4.49,
Total bit hrs 71.34, Max gas = 98 units.
Maintaining 10.9 ppg EMW with MPD @
connections.
15,963.0 16,600.0
3/29/2024
12:00
3/29/2024
18:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 16,600'
MD to 17,126' / 5,166' TVD, WOB 6k,
GPM 270, PSI 3978, RPM 120, TQ 12k,
ECD 10.97 ppg, MWT 9.0 ppg, P/U
202k, S/O - N/A, ROT 110k, ADT 4.53,
Total bit hrs 75.87, Max gas = 117 units.
Maintaining 10.9 ppg EMW with MPD @
connections.
16,600.0 17,126.0
3/29/2024
18:00
3/30/2024
00:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 17,126
MD to 17,730' / 5,171' TVD, WOB 10k,
GPM 270, PSI 4165, RPM 120, TQ 13k,
ECD 10.97 ppg, MWT 9.0 ppg, P/U
206k, S/O - N/A, ROT 102k, ADT 4.58,
Total bit hrs 80.45, Max gas = 59 units.
Maintaining 10.9 ppg EMW with MPD @
connections.
Formation losses last 24 hours: 0 bbls
Total interval formation losses: 0 bbls
17,126.0 17,730.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 26/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/30/2024
00:00
3/30/2024
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 17,730'
MD to 18,285' / 5,173' TVD, WOB 8k,
GPM 270, PSI 4216, RPM 120, TQ 13k,
ECD 11.58 ppg, MWT 9.0 ppg, P/U
222k, S/O - N/A, ROT 110k, ADT 4.45,
Total bit hrs 84.90, Max gas = 59 units.
Maintaining 10.9 ppg EMW with MPD @
connections.
17,730.0 18,285.0
3/30/2024
06:00
3/30/2024
12:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 18,285'
MD to 18,804' / 5,174' TVD, WOB 6k,
GPM 270, PSI 4298, RPM 120, TQ 14k,
ECD 11.58 ppg, MWT 9.0 ppg, P/U
240k, S/O - N/A, ROT 101k, ADT 4.46,
Total bit hrs 89.36, Max gas = 59 units.
Maintaining 10.9 ppg EMW with MPD @
connections.
Perform injectivity test on 10-3/4" x 7-
5/8" outer annulus. Pump 12.6 bbls 9.0
NAF total and establish an injection rate
of 1150 - 1200 psi at .5 bpm (18.0
EMW)
18,285.0 18,804.0
3/30/2024
12:00
3/30/2024
18:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 18,804'
MD to 19,365' / 5,174' TVD, WOB 8k,
GPM 270, PSI 4371, RPM 120, TQ 16k,
ECD 11.74 ppg, MWT 9.0 ppg, P/U
247k, S/O - N/A, ROT 102k, ADT 4.56,
Total bit hrs 93.92, Max gas = 78 units.
Maintaining 10.9 ppg EMW with MPD @
connections.
SIMOPS - LRS freeze protect 10-3/4" x
7-5/8" outer annulus. Pump 82 bbls of
6.8 ppg diesel. Initial .9 bpm at 1300 psi
& Final 1.75 bpm at 670 psi. Monitor
pressure for 20 min. Initial shut in
pressure 670 psi & Final shut in
pressure 690 psi. Bleed off 3.8 bbls to
450 psi, leaving 78.2 bbls in the OA.
18,804.0 19,365.0
3/30/2024
18:00
3/31/2024
00:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 19,365'
MD to 19,920' / 5,175' TVD, WOB 11k,
GPM 270, PSI 4479, RPM 120, TQ 14k,
ECD 11.89 ppg, MWT 9.0 ppg, P/U
271k, S/O - N/A, ROT 120k, ADT 4.57,
Total bit hrs 98.49, Max gas = 59 units.
Maintaining 10.9 ppg EMW with MPD @
connections.
Formation losses last 24 hours: 0 bbls
Total interval formation losses: 0 bbls
19,365.0 19,920.0
3/31/2024
00:00
3/31/2024
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 19,920'
MD to 20,411' / 5,177' TVD, WOB 12k,
GPM 270, PSI 4507, RPM 120, TQ 14k,
ECD 11.99 ppg, MWT 9.0 ppg, P/U
271k, S/O - N/A, ROT 125k, ADT 4.28,
Total bit hrs 102.77, Max gas = 98 units.
Maintaining 10.9 ppg EMW with MPD @
connections.
19,920.0 20,411.0
3/31/2024
06:00
3/31/2024
12:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 20,411'
MD to 20,979' / 5,176' TVD, WOB 5k,
GPM 270, PSI 4580, RPM 120, TQ 16k,
ECD 11.96 ppg, MWT 9.0 ppg, P/U
207k, S/O - N/A, ROT 106k, ADT 4.58,
Total bit hrs 107.35, Max gas = 59 units.
Maintaining 10.9 ppg EMW with MPD @
connections.
20,411.0 20,979.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 27/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
3/31/2024
12:00
3/31/2024
16:00
4.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 20,979'
MD to 21,262' / 5,174' TVD, WOB 5k,
GPM 270, PSI 4575, RPM 120, TQ 16k,
ECD 11.89 ppg, MWT 9.0 ppg, P/U
271k, S/O - N/A, ROT 125k, ADT 2.64,
Total bit hrs 109.99, Max gas = 59 units.
Maintaining 10.9 ppg EMW with MPD @
connections.
20,979.0 21,262.0
3/31/2024
16:00
3/31/2024
17:00
1.00 PROD1, DRILL RGRP T Observe failed wash pipe. Blow down
top drive and replace wash pipe.
21,262.0 21,262.0
3/31/2024
17:00
3/31/2024
17:30
0.50 PROD1, DRILL SRVY T Attempt to send downlink to powerdrive
and observe command not taken.
Change parameters in downlink
sequence to 60 sec cycles and
successfully achieve downlink.
21,262.0 21,262.0
3/31/2024
17:30
3/31/2024
18:00
0.50 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 21,262'
MD to 21,291' / 5,174' TVD, WOB 5k,
GPM 270, PSI 4530, RPM 120, TQ 16k,
ECD 11.89 ppg, MWT 9.0 ppg, P/U
207k, S/O - N/A, ROT 107k, ADT .20,
Total bit hrs 110.19, Max gas = 79 units.
Maintaining 10.9 ppg EMW with MPD @
connections.
21,262.0 21,291.0
3/31/2024
18:00
4/1/2024
00:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 21,291'
MD to 21,763' / 5,172' TVD, WOB 11k,
GPM 270, PSI 4528, RPM 125, TQ 15k,
ECD 11.65 ppg, MWT 9.0 ppg, P/U
222k, S/O - N/A, ROT 111k, ADT 4.41,
Total bit hrs 114.6, Max gas = 20 units.
Maintaining 10.9 ppg EMW with MPD @
connections.
Formation losses last 24 hours: 0 bbls
Total interval formation losses: 0 bbls
21,291.0 21,763.0
4/1/2024
00:00
4/1/2024
02:30
2.50 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 21,763'
MD to production section TD of 21,983' /
5,172' TVD, WOB 12k, GPM 270, PSI
4538, RPM 125, TQ 15k, ECD 11.67
ppg, MWT 9.0 ppg, P/U 200k, S/O -
N/A, ROT 110k, ADT 1.97, Total bit hrs
116.57, Max gas = 20 units. Maintaining
10.9 ppg EMW with MPD @
connections.
21,763.0 21,983.0
4/1/2024
02:30
4/1/2024
04:00
1.50 PROD1, TRIPCAS CIRC P Circulate 1 full B/U with 270 GPM, 4470
PSI, 125 RPM, 13k TQ. Reciprocate full
stand. P/U ROT wt 102k
21,983.0 21,983.0
4/1/2024
04:00
4/1/2024
04:15
0.25 PROD1, TRIPCAS CIRC P Pump up final survey. SPR's. Collect
final T&D data. P/U 200k, S/O - N/A,
ROT 110k,
21,983.0 21,983.0
4/1/2024
04:15
4/1/2024
08:00
3.75 PROD1, TRIPCAS CIRC P BROOH 1 stand from 21,983' to 21,830'
and perform wellbore cleanup for 2
more B/U (3 B/U total) with 270 GPM,
4420 PSI, 125 RPM, 11k TQ. ECD
decreased from 11.67 ppg to 11.38 ppg.
Max gas on B/U - 369 units. Saw a
slight decrease in volume of cuttings
after first B/U, but still small volume of
pulverized cuttings on shakers.
21,983.0 21,830.0
4/1/2024
08:00
4/1/2024
08:45
0.75 PROD1, TRIPCAS SMPD P StripOOH maintaining 10.9 ppg EMW at
33' per min from 21,830' to 21,504''. P/U
180k. Had to top drive up to each stand
due to floats not holding.
21,830.0 21,504.0
4/1/2024
08:45
4/1/2024
09:15
0.50 PROD1, TRIPCAS SMPD T At 21,504' lost comms with Amphion
mud pump controls and had to reboot
system and reset mud pumps at VFD.
21,504.0 21,504.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 28/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
4/1/2024
09:15
4/1/2024
12:00
2.75 PROD1, TRIPCAS SMPD P StripOOH maintaining 10.7 ppg EMW at
33' per min from 21,504' to 18,913'. P/U
173k. Observed 25k max overpull tight
hole from 19,950' to 19,920'. Tight spot
correlates to same tight spot while
drilling and Megaturbidite stringer.
21,504.0 18,913.0
4/1/2024
12:00
4/1/2024
17:00
5.00 PROD1, TRIPCAS SMPD P StripOOH maintaining 10.5 ppg EMW at
33' per min from 18,913' to 14,070'. P/U
173k. Observed 30k overpull at 17,880'.
(Lost 12 bbls NAF to formation while
StripOOH)
18,913.0 14,070.0
4/1/2024
17:00
4/1/2024
21:00
4.00 PROD1, TRIPCAS DISP P Displace wellbore to 9.5 ppg while
BROOH from 14,070' MD to 13,788'
MD. Displace with 270 GPM, ICP
3,542, FCP 3684, 130 RPM, 12K tq, (I)
ECD 10.54, (F)ECD - 10.91. Total stks
pumped - 16,059 (1617 bbls).
14,070.0 13,788.0
4/1/2024
21:00
4/2/2024
00:00
3.00 PROD1, TRIPCAS SMPD P StripOOH maintaining 10.5 ppg EMW at
40' per min from 13,788' to 11,047'. P/U
165K. Monitor displacement via pits 1-
2.
13,788.0 11,047.0
4/2/2024
00:00
4/2/2024
02:00
2.00 PROD1, TRIPCAS SMPD P StripOOH maintaining 10.5 ppg EMW at
40' per min from 11,047 to inside 7-5/8"
casing shoe 8,968'. P/U 175K. Monitor
displacement via pits 1-2. (Observed 20
- 25 k overpull at 10,085', 10,072',
9,591', 9,559').
11,047.0 8,968.0
4/2/2024
02:00
4/2/2024
03:00
1.00 PROD1, TRIPCAS CIRC P Circ B/U with 270 GPM, 3292 PSI,
reciprocate full stand with 75 RPM, 5k
TQ, ROT P/U wt 140k. SIMOPS - L/D 2
stands 4" DP from derrick via 90' mouse
hole.
8,968.0 8,968.0
4/2/2024
03:00
4/2/2024
03:45
0.75 PROD1, TRIPCAS CIRC P Drop 1.75" OD well commander ball.
Pump down with 2 bpm. Ball on seat 35
bbls. Pressure up to 1655 PSI and
observe well commander shift open.
8,968.0 8,968.0
4/2/2024
03:45
4/2/2024
06:00
2.25 PROD1, TRIPCAS CIRC P Perform cased hole wellbore cleanup.
Pump 30 bbl sweep and circ 4 B/U with
500 GPM, 3250 PSI, reciprocate full
stand with 75 RPM, 6k TQ, ROT P/U wt
140k. Nothing significant observed on
shakers while circulating. SIMOPS - L/D
12 stands 4" DP from derrick via 90'
mouse hole (14 total L/D).
8,968.0 8,968.0
4/2/2024
06:00
4/2/2024
06:45
0.75 PROD1, TRIPCAS CIRC P Drop 1.75" OD well commander ball.
Pump down with 2 bpm. Ball on seat 35
bbls. Pressure up to 1600 PSI and
observe well commander shift closed.
8,968.0 8,968.0
4/2/2024
06:45
4/2/2024
07:30
0.75 PROD1, TRIPCAS OWFF P Gingerly relax wellbore and OWFF
(static). Pre-tour safety meeting with
daylight rig crew.
8,968.0 8,968.0
4/2/2024
07:30
4/2/2024
09:30
2.00 PROD1, TRIPCAS CIRC T Observe mud properties out of spec.
Continue to circulate and condition mud
to get back to 9.5 ppg in/out with 270
GPM, 3322 PSI. Back ream stand out of
hole from 8,968' to 8,880'. ROT P/U wt
139k.
8,968.0 8,880.0
4/2/2024
09:30
4/2/2024
15:00
5.50 PROD1, TRIPCAS CIRC P StripOOH maintaining 9.7 ppg EMW at
90' per min from 8,880' to 1,147'. P/U wt
initial 115k / final 63k.
8,880.0 1,147.0
4/2/2024
15:00
4/2/2024
15:30
0.50 PROD1, TRIPCAS OWFF P OWFF (static). 1,147.0 1,147.0
4/2/2024
15:30
4/2/2024
17:30
2.00 PROD1, TRIPCAS MPDA P PJSM - Remove MPD bearing and
install trip nipple.
1,147.0 1,147.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 29/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
4/2/2024
17:30
4/2/2024
18:00
0.50 PROD1, TRIPCAS TRIP P POOH on elevators from 1,147' to BHA
at 196'
1,147.0 196.0
4/2/2024
18:00
4/2/2024
20:00
2.00 PROD1, TRIPCAS BHAH P L/D 6-1/2" production BHA from 196' MD
as per DDX. Monitor disp via TT.
196.0 0.0
4/2/2024
20:00
4/2/2024
22:15
2.25 PROD1, TRIPCAS BHAH P Clear and clean rig floor. 0.0 0.0
4/2/2024
22:15
4/2/2024
23:30
1.25 COMPZN, CASING RURD P Rig up to run 4-1/2" 12.6# P-110S
Hyd563 lower completion. SIMOPS -
Mobilize frac sleeves to the rig floor, drift
and no go.
0.0 0.0
4/2/2024
23:30
4/3/2024
00:00
0.50 COMPZN, CASING WWWH P M/U flushing tool and flush BOPE w/
500 GPM, 242 PSI, 30 RPM. SIMOPS -
Mobilize 4-1/2" handling equipment to
the rig floor. Function Annular - 23 sec
closing time. Function upper rams - 11
sec. closing time. Function lower rams -
11 sec closing time. Close blind/shear's
- 14 sec closing time.
0.0 0.0
4/3/2024
00:00
4/3/2024
00:30
0.50 COMPZN, CASING RURD P Continue to mobilze frac sleeves to rig
floor and drift and stage in run order on
rig floor.
0.0 0.0
4/3/2024
00:30
4/3/2024
02:30
2.00 COMPZN, CASING RURD P R/U Doyon casing tools and equipment.
M/U 4-1/2" CRT, 4-1/2" double stack
power tongs and 4-1/2" handling
equipment.
0.0 0.0
4/3/2024
02:30
4/3/2024
03:00
0.50 COMPZN, CASING SVRG P Service rig, draw works and top drive. 0.0 0.0
4/3/2024
03:00
4/3/2024
03:30
0.50 COMPZN, CASING SFTY P PJSM on running lower completion. 0.0 0.0
4/3/2024
03:30
4/3/2024
12:00
8.50 COMPZN, CASING PUTB P RIH 4-1/2" 12.6# P110 Hyd563 lower
completion liner fully evacuated to
4,642'. S/O wt 62k. Perform inflow test
#1 at 2,100' (static).
Monitor displacement on an isolated pit.
SIMOPS - clean pits and prep for brine
displacement.
0.0 4,642.0
4/3/2024
12:00
4/3/2024
18:00
6.00 COMPZN, CASING PUTB P RIH 4-1/2" 12.6# P110 Hyd563 lower
completion liner fully evacuated from
4,642' to 8719'. Up Wt 65k, S/O wt 63k.
Monitor displacement on an isolated pit.
SIMOPS - clean pits and prep for brine
displacement.
4,642.0 8,719.0
4/3/2024
18:00
4/4/2024
00:00
6.00 COMPZN, CASING PUTB P RIH 4-1/2" 12.6# P110 Hyd563 lower
completion liner fully evacuated from
8,719' to 11,244'. Up Wt 72k, S/O wt
57k. Monitor displacement on an
isolated pit. Collect T&D at the shoe
(8,991') 67k up, 61k s/o, 65k rot.
20rpm, 2k, 30 rpm 2.5k. Continue to
take T&D every 1000'. Encounter
obstruction at 11,207' MD. Unable to
slack off past. Engage Volant CRT and
successfully rot by obstruction dn to
11,244' MD with 20 rpm, 3-5k tq, 57k rot
wt.
SIMOPS - clean pits and prep for brine
displacement.
8,719.0 11,244.0
4/4/2024
00:00
4/4/2024
03:15
3.25 COMPZN, CASING PUTB P RIH 4-1/2" 12.6# P110 Hyd563 lower
completion liner fully evacuated from
11,244' to 12,020', P/U 72k, S/O 56k.
Monitor displacement on an isolated pit.
Encounter obstruction at 11,771',
11,792'. Rotate thru with 20 rpm, 3-5k
tq, 57k rot wt.
11,244.0 12,020.0
4/4/2024
03:15
4/4/2024
03:45
0.50 COMPZN, CASING OWFF P OWFF (static) - Inflow test #2 12,020.0 12,020.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 30/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
4/4/2024
03:45
4/4/2024
10:15
6.50 COMPZN, CASING PUTB P RIH 4-1/2" 12.6# P110 Hyd563 lower
completion liner fully evacuated from
12,020' to 13,102', P/U 72k, S/O N/A.
Monitor displacement on an isolated pit.
Lost slack of wt at 12,230'. Had to work
through significant trouble spot from
12,230' to 12,292'. Stalling out top drive
at 11k trq. (Rotate liner down from
12,292' to 13,102' with 20 rpm / 3.5 - 5k
trq)
12,020.0 13,102.0
4/4/2024
10:15
4/4/2024
11:15
1.00 COMPZN, CASING OTHR P R/D CRT and 4-1/2" handling
equipment. M/U SLZXP and fill with pal
mix. RIH liner/SLZXP on 1 stand of
HWDP to 13,235'. Collect T&D
parameters: P/U 80k, S/O 58k, ROT
67k, 20 RPM 3.3k trq, 30 RPM 3.4k trq.
13,102.0 13,235.0
4/4/2024
11:15
4/4/2024
18:00
6.75 COMPZN, CASING RUNL P RIH 4-1/2" 12.6# P110 Hyd563 lower
completion liner fully evacuated on 4"
DP/HWDP from 13,235' to 17,030'.
Rotating down with 20 RPM 3.3 - 5.5k
trq. Tight spots or torque spikes while
rotating appear to correlate with high
DLS and swell packers trying to pass
through them. Monitor displacement on
isolated pit.
Attempted to RIH on elevators from
13,968' to 14,339' before all forward
progress was halted. Attempted to ream
from 14,339' to 14,345' with no success.
Stalling out top drive and not making
forward progress. Had to pull out of hole
1 full stand to get pipe moving again.
Ream through area with 20 rpm.
13,235.0 17,030.0
4/4/2024
18:00
4/5/2024
00:00
6.00 COMPZN, CASING RUNL P RIH 4-1/2" 12.6# P110 Hyd563 lower
completion liner fully evacuated on 4"
DP/HWDP from 17,030' to 18,326'.
Rotating down with 20 RPM 3.3 - 5.5k
trq. Tight spots or torque spikes while
rotating appear to correlate with high
DLS and swell packers trying to pass
through them. Monitor displacement on
isolated pit. Observe tq spikes through
upper morraine from 17,328' MD to
18,326' MD of 7-11k tq.
17,030.0 18,326.0
4/5/2024
00:00
4/5/2024
06:00
6.00 COMPZN, CASING RUNL P RIH 4-1/2" 12.6# P110 Hyd563 lower
completion liner fully evacuated on 4"
DP/HWDP from 18,326' to 19,405'.
Rotating down with 20 RPM / 8 - 13 k
trq. ROT 92 - 97k. Maximizing running
speeds within liner and running tools
limitations. Monitoring displacement on
isolated pit.
SIMOPS - Housekeeping and PM's,
prepping tools and equipment for
flooding liner and displacing to brine.
18,326.0 19,405.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 31/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
4/5/2024
06:00
4/5/2024
12:00
6.00 COMPZN, CASING RUNL P RIH 4-1/2" 12.6# P110 Hyd563 lower
completion liner fully evacuated on 4"
DP/HWDP from 9,405' to 20,307'.
Rotating down with 20 RPM / 8 - 13 k
trq. ROT 92 - 97k. Maximizing running
speeds within liner and running tools
limitations. Monitoring displacement on
isolated pit. Observing swell packer
rubber across scalper deck.
SIMOPS - Housekeeping and PM's,
prepping tools and equipment for
flooding liner and displacing to brine.
19,405.0 20,307.0
4/5/2024
12:00
4/5/2024
13:00
1.00 COMPZN, CASING RUNL P RIH 4-1/2" 12.6# P110 Hyd563 lower
completion liner fully evacuated on 4"
DP/HWDP from 20,307' 20,435'.
Rotating down with 20 RPM / 8 - 13 k
trq. ROT 92 - 97k. Maximizing running
speeds within liner and running tools
limitations. Monitoring displacement on
isolated pit. Observing swell packer
rubber across scalper deck.
SIMOPS - Housekeeping and PM's.
20,307.0 20,435.0
4/5/2024
13:00
4/5/2024
16:30
3.50 COMPZN, CASING RUNL P At 20,435', swell packer #1 is trying to
come through know tight hole section of
19,920' - 19,950'. All forward progress
has stopped. Attempt to work through
tight hole rotating at 20 rpm and stalling
out top drive at 13.5 k max trq limit.
Good free travel above tight spot and
free rotating trq at 20 rpm is 8 k with
ROT wt 113k. Vary parameters and
reciprocate pipe in attempt to make
forward progress. Not able to make
forward progress and decision made to
fill pipe. BROOH from 20,435' to 20,403'
to space out TOL.
20,435.0 20,403.0
4/5/2024
16:30
4/5/2024
18:00
1.50 COMPZN, CASING RURD P R/U closed loop burping assembly.
Stage working single drill pipe on pipe
skate. Blow down MPD lines and prep to
fill pipe.
20,403.0 20,403.0
4/5/2024
18:00
4/5/2024
19:30
1.50 COMPZN, CASING CIRC P Fill pipe with 9.5 ppg NAF at 5 bpm
through closed loop burping assembly.
Pump 252 bbls and fluid pack liner and
drill pipe.
Shoe at 20,403', TOL at 7,271'. SLZXP
packer element at 7,287' (7-5/8" casing
collars at 7,284' and 7,325')
20,403.0 20,403.0
4/5/2024
19:30
4/5/2024
21:30
2.00 COMPZN, CASING CIRC P Establish circulation staging up to 2
bpm, 1008 psi. Observe loss rt of 60
bph. Reduce rate to 1.5 bpm, 955 psi.
Rot and recip pipe from 20,405' MD to
20,433' MD w/ 15 rpm, 11k tq. Total stks
pumped - 1892 (160 bbls)
20,403.0 20,403.0
4/5/2024
21:30
4/6/2024
00:00
2.50 COMPZN, CASING RUNL P L/D working single. Kelly up to std 79.
Establish circ at 70 gpm, 925 psi, 7%
f/o, rot @ 15 rpm, 11k tq and ream in the
hole to 20,443' MD.
Observe rubber at the shakers at ~4000
stks. Total stks pumped - 5002 (424
bbls)
Total losses to formation - 200 bbls.
20,403.0 20,443.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 32/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
4/6/2024
00:00
4/6/2024
07:45
7.75 COMPZN, CASING RUNL P Wash and ream liner in hole from
20,443' to 20,450' MD with 1.7 bpm, 960
psi, 15 rpm, 11 - 13.4 k trq. Not able to
make forward progress and hole
conditions appear to be deteriorating.
Hole attempting to pack off as we try to
work swell packer through tight hole.
Decision made to set SLZXP. BROOH
from 20,450' to 20,433' MD and prep to
set SLZXP.
Lost 32 bbls to formation while W&R
liner.
Observe 25 bbls of 10.7 ppg 300+ vis at
shakers at 5280 stks.
20,433.0 20,443.0
4/6/2024
07:45
4/6/2024
12:15
4.50 COMPZN, CASING PACK P Drop 1.125" primary WIV ball and chase
with 10 bbls high vis spacer and 380
bbls total (125 bbls over calculated) 9.5
ppg NAF. Initially pumped down at 2
bpm / 800 psi. Ball would not seat.
Varied flow rates from 2 - 5 bpm to get
ball on seat. Set SLZXP as per Baker
rep. Shut in on upper pipe rams and
pressure test liner top packer thru IA to
3850 psi (good).
4-1/2" shoe 20,433' / TOL 7,301'
20,433.0 7,301.0
4/6/2024
12:15
4/6/2024
13:30
1.25 COMPZN, WELLPR PRTS P Pull liner running tools out of SLZXP
assembly and space out 40' above liner
top. R/U TIW and head pin. Shut in on
upper pipe rams. Pump down drill string
and pressure test entire annulus to 3850
psi for 30 min (Barrier Test - good).
7,301.0 7,301.0
4/6/2024
13:30
4/6/2024
15:30
2.00 COMPZN, WELLPR RURD P R/D testing equipment. RIH and space
out liner running tools directly above
liner top at 7,301' MD and prep for
displacement. Blow down choke, kill and
injection lines. Prep rig and pits for brine
displacement.
7,301.0 7,301.0
4/6/2024
15:30
4/6/2024
18:45
3.25 COMPZN, WELLPR DISP P PJSM - Displace well above liner top at
7,301' MD from 9.5 ppg NAF to 9.5 ppg
CI Brine with 4 bpm / 529 psi. Rotate 20
rpm @ 6 k trq and reciprocate full stand.
Total stks pumped - 8,211 (695 bbls).
7,301.0 7,301.0
4/6/2024
18:45
4/6/2024
19:15
0.50 COMPZN, WELLPR OWFF P OWFF for 30 min (static). SIMOPS -
Blow down top drive and re-energize
fresh water to sub base and pits
modules.
7,301.0 7,301.0
4/6/2024
19:15
4/7/2024
00:00
4.75 COMPZN, WELLPR CLEN P Clean rig floor, BOPE's and cellar, and
mud pits from post NAF activities.
Monitor well over top of hole on trip
tank.
7,301.0 7,301.0
4/7/2024
00:00
4/7/2024
08:30
8.50 COMPZN, WELLPR PULD P POOH from 7,301' laying down drill pipe
to pipe shed. Monitor hole fill on trip
tank.
7,301.0 0.0
4/7/2024
08:30
4/7/2024
09:00
0.50 COMPZN, WELLPR PULD P L/D Baker liner running tools. All
components functioned correctly.
0.0 0.0
4/7/2024
09:00
4/7/2024
12:00
3.00 COMPZN, WELLPR TRIP P RIH with stands out of derrick to 6,670'.
Monitor displacement on trip tank.
0.0 6,670.0
4/7/2024
12:00
4/7/2024
14:00
2.00 COMPZN, WELLPR PULD P POOH from 6,670' to 6,070' laying down
drill pipe to pipe shed. Monitor hole fill
on trip tank.
6,670.0 6,070.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 33/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
4/7/2024
14:00
4/7/2024
14:30
0.50 COMPZN, WELLPR SFTY P H2S rig evacuation drill. SCBA's
dawned in 210 sec. Well shut in 270
sec, All hands accounted for in safe
briefing area in 480 sec.
6,070.0 6,070.0
4/7/2024
14:30
4/7/2024
21:00
6.50 COMPZN, WELLPR PULD P POOH from 6,070' laying down drill pipe
to pipe shed. Monitor hole fill on trip
tank.
6,070.0 0.0
4/7/2024
21:00
4/7/2024
23:15
2.25 COMPZN, WELLPR TRIP P RIH with stands out of derrick to 3,260'.
Monitor displacement on trip tank.
0.0 3,260.0
4/7/2024
23:15
4/7/2024
23:45
0.50 COMPZN, WELLPR SVRG P Service roughneck, air slips. 3,260.0 3,260.0
4/7/2024
23:45
4/8/2024
00:00
0.25 COMPZN, WELLPR TRIP P RIH with stands out of derrick from
3,260' to 3,608'. Monitor displacement
on trip tank. S/O wt = 86k.
3,260.0 3,608.0
4/8/2024
00:00
4/8/2024
01:00
1.00 COMPZN, WELLPR TRIP P RIH with stands out of derrick from
3,608' to 5,511'. Monitor displacement
on trip tank. S/O wt = 89k.
3,608.0 5,511.0
4/8/2024
01:00
4/8/2024
01:30
0.50 COMPZN, WELLPR SVRG P Service iron roughneck. 5,511.0 5,511.0
4/8/2024
01:30
4/8/2024
02:00
0.50 COMPZN, WELLPR TRIP P RIH with stands out of derrick from
5,511' to 6,457'. Monitor displacement
on trip tank. S/O wt = 94k.
5,511.0 6,457.0
4/8/2024
02:00
4/8/2024
02:45
0.75 COMPZN, WELLPR CIRC P R/U head pin and circ equipment. Pump
12 bbl dry job with 5 bpm / 278 psi
6,457.0 6,457.0
4/8/2024
02:45
4/8/2024
04:15
1.50 COMPZN, WELLPR RGRP T Trouble shoot iron roughneck.
Determined clamp function solenoid
wiring compromised. Replace and
function test. (good)
6,457.0 6,457.0
4/8/2024
04:15
4/8/2024
11:00
6.75 COMPZN, WELLPR PULD P POOH laying down drill pipe from
6,457'. Monitor displacement on trip
tank.
6,457.0 0.0
4/8/2024
11:00
4/8/2024
12:00
1.00 COMPZN, WELLPR CLEN P Clean and clear rig floor. SIMOPS -
prep to slip and cut.
0.0 0.0
4/8/2024
12:00
4/8/2024
14:15
2.25 COMPZN, WELLPR SLPC P PJSM - Slip and cut drill line. SIMOPS -
mobilize NC50 saver sub and IBOP
assy to rig floor.
0.0 0.0
4/8/2024
14:15
4/8/2024
18:30
4.25 COMPZN, WELLPR RURD P Change out save sub to NC50, Change
out IBOP assembly and wash pipe.
0.0 0.0
4/8/2024
18:30
4/8/2024
19:15
0.75 COMPZN, WELLPR RURD P Make up wear bushing running tool and
pull wear bushing as per Cameron rep.
0.0 0.0
4/8/2024
19:15
4/8/2024
20:30
1.25 COMPZN, WELLPR WWWH P Make up stack flushing tool and flush
BOPE w/ 750 GPM, 578 PSI. Blow
down top drive. Function annular and
VBRs and make note of weekly function
in IADC. Change out elevators to 4½"
tubing elevators.
0.0 0.0
4/8/2024
20:30
4/8/2024
21:15
0.75 COMPZN, WELLPR RURD P Change out wash pipe. 0.0 0.0
4/8/2024
21:15
4/8/2024
22:00
0.75 COMPZN, RPCOMP SFTY P PJSM w/ rig team and 3rd party on
rigging up to run upper completion.
0.0 0.0
4/8/2024
22:00
4/9/2024
00:00
2.00 COMPZN, RPCOMP RURD P Rig up to run 4-1/2" ESP upper
completion.
0.0 0.0
4/9/2024
00:00
4/9/2024
08:15
8.25 COMPZN, RPCOMP RURD P Continue to rig up for upper completion.
Stage spooling units and align with
beaver slide. Build hooch around
spooling units. Hang sheaves for ESP,
TEC and chemical injection lines. Pull
lines from spooling units up beaver slide
and stage on rig floor for running in hole.
Flag off no go areas and prep tools and
equipment. SIMOPS - Clean BOPE
deck, house keeping and P.M.'s
0.0 0.0
4/9/2024
08:15
4/9/2024
09:00
0.75 COMPZN, RPCOMP SFTY P PJSM with all parties on running upper
completion.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 34/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
4/9/2024
09:00
4/9/2024
12:00
3.00 COMPZN, RPCOMP PUTB P RIH 4-1/2" 12.6# L-80 Hyd563 upper
ESP completion to 186', Monitor
displacement on isolated pit and fill
tubing from top with 2" fill up hose. @
186' install chemical injection line fluid
pack line and pressure test to 2000 psi
(Good)
0.0 186.0
4/9/2024
12:00
4/9/2024
18:00
6.00 COMPZN, RPCOMP PUTB P RIH 4-1/2" 12.6# L-80 Hyd563 upper
ESP completion to from 186' to 565',
Monitor displacement on isolated pit and
fill tubing from top with 2" fill up hose.
Perform electrical and pressure test
checks on ESP/TEC every 1000'.
Continuously monitor 2000 psi on
chemical injection line. (M/U Access
ESP ACP and PLE @ 470'. Perform
connectivity test (good).
186.0 565.0
4/9/2024
18:00
4/10/2024
00:00
6.00 COMPZN, RPCOMP PUTB P RIH w/ 4-1/2'' 12.6# l-80 Hyd 563 upper
ESP completion tubing as per detail with
ESP/Tec/Chem. Injection lines from/
565' to 1,375', B.O.L. ag 2k on pins,
make up torque 3,800 ft lb, top filling
tubing monitoring displacement via
pit#1, performing electrical tests on
DHG/TEC every 1,000' (M/U access
ESP assy, ACP & PLE and perform
connectivity test @ 470', M/U HES
Opsis gauge mandrel & pt 10,000 psi for
10 min @ 635')SIMOPS: Prep 3S-626
cellar area
565.0 1,375.0
4/10/2024
00:00
4/10/2024
06:00
6.00 COMPZN, RPCOMP PUTB P RIH w/ 4-1/2'' 12.6# l-80 Hyd 563 upper
ESP completion tubing as per detail with
ESP/Tec/Chem. Injection lines from
1,375' to 4,165' MD, Make up torque
3,800 ft lb, top filling tubing and
monitoring displacement via pit#1.
Performing electrical tests on DHG/TEC
every 1,000'.
1,375.0 4,165.0
4/10/2024
06:00
4/10/2024
12:00
6.00 COMPZN, RPCOMP PUTB P RIH w/ 4-1/2'' 12.6# l-80 Hyd 563 upper
ESP completion tubing as per detail with
ESP/Tec/Chem. Injection lines from
4,165' to fully located at 7,308' MD,
Make up torque 3,800 ft lb, top filling
tubing and monitoring displacement via
pit#1. Performing electrical tests on
DHG/TEC every 1,000'. (saw 15k wob
shear on locator assy)
4,165.0 7,308.0
4/10/2024
12:00
4/10/2024
13:00
1.00 COMPZN, RPCOMP PUTB P POOH laying down 3 joints of tubing
from 7,308' to 7,2-4' MD. M/U 15.5' pf
space out pups and M/U last full joint of
4-1/2" tubing and RIH to 7,261' MD
7,308.0 7,261.0
4/10/2024
13:00
4/10/2024
17:00
4.00 COMPZN, RPCOMP THGR P M/U lower Fast Lock assy to stump and
torque to 3,800 ft/lbs. M/U landing joint,
tubing hanger and upper Fast Lock assy
and torque to 3,800 ft/lbs. Orient hanger
and ESP ports. Verify pre-torque gap on
Fast Lock assy is correct. Torque Fast
Lock collar to 4,800 ft/lbs with torque
turn. Verify gap as per CPAI/Hal reps.
(good). Terminate ESP, Hal TEC, and
chemical injections line thru tubing
hanger. RIH and land on hanger at
7,306.5' (1.5' from fully located) Monitor
well over top on pit isolated pit.
7,261.0 7,306.5
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 35/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
4/10/2024
17:00
4/10/2024
18:00
1.00 COMPZN, RPCOMP THGR P R/U to pump down tubing. XO, head pin,
block valve and cement hose.Pressure
test up on tubing to 1000 psi for 10 min
to confirm seal on Fast Lock Swivel
assy. Good Test.
0.0 0.0
4/10/2024
18:00
4/10/2024
19:00
1.00 COMPZN, RPCOMP THGR P Run in lock down screws on wellhead &
pressure test hanger seals thru test port
to 5000 psi for 15 minutes. Good Test
0.0 0.0
4/10/2024
19:00
4/10/2024
20:45
1.75 COMPZN, RPCOMP PRTS P Pressure test tubing and set Halliburton
TNT packer as per procedure. Pump
rate .5bpm, 24strokes/2.4bbls to psi to
4650psi, shut in test for 30minutes.
Bleed tubing to 2200psi. Pressure test
IA and tubing hanger seals to 3850psi
for 30minutes. Pump rate .5bpm,
32strokes/3.2bbls to psi. Bleed IA to
3000psi, then bleed tubing to 0 psi
rapidly to shear the SOV. Observe
tubing and IA psi bleed too psi.
Confirming SOV shear. Bleed back=
3.4bbls
0.0 0.0
4/10/2024
20:45
4/10/2024
21:45
1.00 COMPZN, RPCOMP OWFF P OWFF ( well static) 0.0 0.0
4/10/2024
21:45
4/10/2024
22:45
1.00 COMPZN, RPCOMP MPSP P Lay down landing joint. Install HP-BPV
pressure test to 2500psi, for 10minutes.
pump rate .5bpm, 28strokes/2.8bbls to
psi up.
0.0 0.0
4/10/2024
22:45
4/10/2024
23:15
0.50 COMPZN, WHDBOP RURD P Blow down cement, mud pump,
injection, kill, choke, hole fill, jet lines.
0.0 0.0
4/10/2024
23:15
4/11/2024
00:00
0.75 COMPZN, WHDBOP CLEN P Clean and clear rig floor. completion,
casing running equipment
0.0 0.0
4/11/2024
00:00
4/11/2024
02:00
2.00 COMPZN, WHDBOP CLEN P Continue to clean and clear rig floor of
completion, casing running tools and
equipment.
0.0 0.0
4/11/2024
02:00
4/11/2024
06:00
4.00 COMPZN, WHDBOP NUND P PJSM. Lay down mouse hole. N/D trip
nipple, choke and kill lines. N/D MPD
RCD head with Orbit valve. Remove
drip pan.
0.0 0.0
4/11/2024
06:00
4/11/2024
07:30
1.50 COMPZN, WHDBOP NUND P N/D BOPE's. Take measurements for
Stream Flow for BOPE flange. Rack
back BOPE's on pedestal and secure.
N/D DSA and space spools and stage
on BOPE deck.
0.0 0.0
4/11/2024
07:30
4/11/2024
10:30
3.00 COMPZN, WHDBOP NUND P Install metal to metal seals and install
test dart in BPV. N/U tubing spool
adaptor and terminate Access ESP,
chemical injection, and Hal TEC lines.
Test hanger seals to 250/500o psi for 15
min (good). Collect final downhole data.
ESP cable legs; A = 2.26, B = 3.19, C =
4.23, Chemical injection line = 1900 psi,
TEC downhole gauge; Tubing = 2169
psi @ 113*, IA = 2179 psi @ 113*
0.0 0.0
4/11/2024
10:30
4/11/2024
13:00
2.50 COMPZN, WHDBOP NUND P Orient and N/U 10 k frac tree valve assy.
Break connection and orient and N/U
frac inlet. Fill tree with diesel and
function valves. Ensure SSV is in open
position. R/U Totco sensor to 1502 frac
inlet. SIMOPS - Check air pressure and
prep tires on rig for move. C/O pump
liners in MP#1 to 6"
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
Page 36/36
3S-610
Report Printed: 5/6/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
4/11/2024
13:00
4/11/2024
18:00
5.00 COMPZN, WHDBOP PRTS P Fill tree with diesel and purge air from
system. Attempt to pressure test frac
tree to 3000 psi. Not able to get a
successful test. Confirm leaking out the
4" seals on the Otis connection. Shut in
on swap valve and attempt to pressure
test with no success. Retighten all
flanges and cycle all valves and attempt
to test no success, Was not able to PT
frac tree. Confirm all barriers are in
place and CPAI decision made to move
off well and address frac tree post rig.
Secure well and install gauges on Tree
cap, OA and IA flanges.
0.0 0.0
4/11/2024
18:00
4/12/2024
00:00
6.00 DEMOB, MOVE DMOB P Rig down all modules, electric
interconnects, water, steam and air.
Prep and ready rig for move. Rig down
Magtec equipment. Loader operator
moving matting boards and equipment
for move. Release rig at 0000 hrs
Final Pressures: OA = 200 psi, IA = 0
psi, Tubing = 0 psi
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 4/12/2024
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Page 1/1
3S-610
Report Printed: 5/6/2024
Cement
Cement Details
Description
Surface String Cement
Cementing Start Date
3/14/2024 11:00
Cementing End Date
3/14/2024 15:30
Wellbore Name
3S-610
Comment
Cement 10-3/4" 45.5# L-80 surface hanger as per Halliburton pump schedule. Flood lines with % bbls H2O@ 5 BPM, pressure test lines to 3500 PSI, pump 60
bbl 10.2 ppg Tuned primed spacer with 8lb of red dye at 3-5 BPM 35 psi. Shut down pumps and drop bottom plug. Pump 387 bbls of 10.7 ppg lead cement at 3-5
BPM 24 psi. Pump 57 Bbls of 15.8 ppg tail cement at 3-5 BPM. Shut down and drop top plug. Flush with 20 Bbls of fresh water and chase with rig mud pumps 9.8
ppg spud mud. Displace cement at 6 BPM. ICP 122 PSI reduce rate to 3 BPM at 2256 stokes FCP 461 psi.
Did not have positive indication of bottom float shear.
Pumped max of 2350 strokes and did not bump, pumped additional 10 strokes and did not bump.
Bled off pressure and positive indication that the floats are holding.
Cement in place at 15:30 hrs.
ICP 113 PSI
FCP 580 PSI
No losses observed.
60 Bbl spacer and 28 Bbls cement returns to surface.
Cement Stages
Stage # 1
Description
Surface String Cement
Objective
Cement surface string
with full returns
Top Depth (ftKB)
39.0
Bottom Depth (ftKB)
2,720.0
Full Return?
Yes
Vol Cement …
28.0
Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
5
Q Pump Final (bbl/…
2
Q Pump Avg (bbl/…
5
P Pump Final (psi)
240.0
P Plug Bump (psi) Recip?
Yes
Stroke (ft)
7.00
Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB)
2,592.0
Tag Method
Drill Bit
Depth Plug Drilled Out To (ftKB)
2,720.0
Drill Out Diameter (in)
9 7/8
Comment
Cement 10-3/4" 45.5# L-80 surface hanger as per Halliburton pump schedule. Flood lines with % bbls H2O@ 5 BPM, pressure test lines to 3500 PSI, pump 60
bbl 10.2 ppg Tuned primed spacer with 8lb of red dye at 3-5 BPM 35 psi. Shut down pumps and drop bottom plug. Pump 387 bbls of 10.7 ppg lead cement at 3-5
BPM 24 psi. Pump 57 Bbls of 15.8 ppg tail cement at 3-5 BPM. Shut down and drop top plug. Flush with 20 Bbls of fresh water and chase with rig mud pumps 9.8
ppg spud mud. Displace cement at 6 BPM. ICP 122 PSI reduce rate to 3 BPM at 2256 stokes FCP 461 psi.
Did not have positive indication of bottom float shear.
Pumped max of 2350 strokes and did not bump, pumped additional 10 strokes and did not bump.
Bled off pressure and positive indication that the floats are holding.
Cement in place at 15:30 hrs.
ICP 113 PSI
FCP 580 PSI
No losses observed.
60 Bbl spacer and 28 Bbls cement returns to surface.
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-610
Report Printed: 5/6/2024
Cement
Cement Details
Description
Intermediate String 1 Cement
Cementing Start Date
3/23/2024 01:45
Cementing End Date
3/23/2024 05:00
Wellbore Name
3S-610
Comment
Kick out btm wiper plug w/ 5 bbls water. PT lines to 4000. Pump 60 bbls mud push. Kick out 2nd wiper plug. Pump 201 bbls BMII 15.3 ppg cement. Pump 22
bbls 15.3 cement w/o BMII. Kick out upper plug with 10 bbls water. Chase with rig pumps. Pump 3915 stks. Did not bump plug. Floats held. CIP at 4:56 hrs.
Cement Stages
Stage # 1
Description
Intermediate String 1
Cement
Objective
Place cement ~250'
above Coyote formation
Top Depth (ftKB)
3,549.0
Bottom Depth (ftKB)
9,016.0
Full Return?
Yes
Vol Cement …
0.0
Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
4
Q Pump Final (bbl/…
3
Q Pump Avg (bbl/…
6
P Pump Final (psi)
1,140.0
P Plug Bump (psi)
0.0
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
60 bbls 10.5 spacer
201 bbls 15.3 with BMII
22 bbls 15.3 without BMII
20 bbls H2O to kick out top plug
Chase with rig - 183 bbls to catch cement
Bump plug with 315 bbls (calculated - 321)
Cement Fluids & Additives
Fluid
Fluid Type
Primary Cement
Fluid Description Estimated Top (ftKB)
3,000.0
Est Btm (ftKB)
9,011.0
Amount (sacks)
1,134
Class
G
Volume Pumped (bbl)
223.0
Yield (ft³/sack)
1.24
Mix H20 Ratio (gal/sack)
5.56
Free Water (%) Density (lb/gal)
15.30
Plastic Viscosity (cP) Thickening Time (hr)
5.50
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-610
Yes No
9. Property Designation (Lease Number): 10. Field:
Torok Oil Pool
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
21983 5172 20433 5177 2291 None None
Casing Collapse
Structural
Conductor
Surface 2470
Intermediate 4790
Intermediate 7850
Liner 9210
Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft):
12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations: OIL WINJ WDSPL Suspended
16. Verbal Approval: Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name:Manabu Nozaki
Manabu Nozaki Contact Email:Manabu.Nozaki@cop.com
Contact Phone: 907-265-6519
Authorized Title: Staff Completions Engineer
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other Conditions of Approval:
Post Initial Injection MIT Req'd? Yes No
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
4/30/2024
Length
AOGCC USE ONLY
11590
Tubing Grade: Tubing MD (ft):
TNT Packer: 7229' MD/ 4573' TVD
SLZXP: 7301' MD / 4596' TVD
Subsequent Form Required:
Suspension Expiration Date:
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
Tubing Size:
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL380107 / ADL380106 / ADL0255528 / ADL393883
223-126
P.O. Box 100360, Anchorage, Alaska 99510-0360 50-103-20875-00-00
ConocoPhillips Alaska Inc.
Kuparuk Field
Will perfs require a spacing exception due to property boundaries?
Current Pools:
Size
Proposed Pools:
TVD Burst
MPSP (psi): Plugs (MD):
MD
PRESENT WELL CONDITION SUMMARY
6890
5210
129
2564.6
4865.4
129
2712.9
51197-5/8"
20"
10-3/4"
90
7-5/8"8134.5
2673.9
9011.7
8171
840.7
4-1/2"
5/17/2024
2043313132
4-1/2"
5177
Halliburton TNT Prod Packer
Baker SLZXP, No SSSV
L-80
10860
Perforation Depth TVD (ft):Perforation Depth MD (ft):
m
n
P
2
66
t
_
N
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
By Grace Christianson at 12:18 pm, May 01, 2024
VTL 5/14/2024
10-404
CDW 05/13/2024
5/17/2024
Fracture Stimulate
X
SFD 5/13/2024
025528 SFD
DSR-5/1/24JLC 5/14/2024
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)
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.
SECTION 6 ASSESSMENT OF EACH CASING AND CEMENTING
OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE
WELL 20 AAC 25.283(a)(6)
Casing & Cement Assessments:
10 & 3/4 casing cement pump report on 3/14/2024 shows that the original job pumped as
designed. The cement job was pumped with 387 barrels of 10.7 ppg lead cement and 57
barrels 15.8 ppg tail cement, displaced with 9.8 ppg spud mud. The plug did not bump, bled
off pressure and positive indication that the floats held. Cement returns came to surface.
The 7 & 5/8 casing cement report on 3/23/2024 shows that the job was pumped as designed,
indicating competent cementing operations. The cement job was pumped with 201 barrels of
15.3 ppg with BM-II (Bridge Maker II), followed with 22 barrels of 15.3 ppg without BMII. The
plug did not bumped, pressure held at 1140 psi indicating that floats are competent. A cement
bond log indicates competent cement with a cement top @ 3,549 MD (3,156 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.
p p g p,
Cement returns came to surface.
ppg
plug did not bump
SECTION 7 PRESSURE TEST INFORMATION AND PLANS TO
PRESSURE-TEST CASINGS AND TUBINGS INSTALLED IN THE
WELL 20 AAC 25.283(a)(7)
On 3/16/2024 the 10-3/4 casing was pressure tested to 3,000 psi for 30 minutes
On 3/24/2024 the 7-5/8 casing was pressure tested to 4,000 psi for 30 minutes.
On 4/10/2024 the 4-1/2 tubing was pressure tested to 4,550 psi. Good Test
On 4/10/2024 the 7-5/8 casing by 4-1/2 tubing annulus was pressure tested to 3,850 psi.
Good Test
AOGCC Required Pressures [all in psi]
Maximum Predicted Treating Pressure (MPTP) 7,000
Annulus pressure during frac 3,500
Annulus PRV setpoint during frac 3,600
7-5/8" Annulus pressure test 3,850
4-1/2" Tubing pressure Test 4,550
Electronic PRV 8,000
Highest pump trip 7,500
SECTION 8 PRESSURE RATINGS AND SCHEMATICS FOR THE
WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC
25.283(a)(8)
Size Weight, ppf Grade API Burst, psi API Collapse, psi
10-3/4 45.5 L-80 5,209 2474
7-5/8 29.7 L-80 6,885 4,789
7-5/8 33.7 P-110S 10,860 7,870
4-1/2 12.6 L-80 8,430 7,500
Table 2: Wellbore pressure ratings
Stimulation Surface Rig-Up
Kuparuk 10K Frac Tree
SECTION 9 DATA FOR FRACTURING ZONE AND CONFINING
ZONES 20 AAC 25.283(a)(9)
CPAI has formed the opinion, based on seismic, well, and other subsurface information
currently available that:
The fracturing zone, the Torok Oil Pool, has an average thickness of approximately 260 ft TVD
over the course of the lateral section of well 3S-610, from where it intersects the top formation
at 9,108 MD to TD of the well. The Torok Oil Pool is comprised of thinly interbedded sandstone,
siltstone, and silty shale layers. The sandstone and siltstone components are litharenites,
moderately to well sorted, and very fine grained. The silty shales are composed of clay-rich,
moderately to poorly sorted silt and clay. The estimated fracture pressure for the Moraine
interval is approximately 12.5-13.5 ppg.
The overlying confining interval of the Torok Formation consists of mudstones and siltstones
with an average thickness of approximately 842 TVD. The top of the Torok confining intervals
starts at 4,403 TVDSS (6,893 MD). The estimated fracture gradient of the overlying Torok
formation is approximately 0.82 psi/ft.
The underlying confining zone below the Base Moraine consists of lower Torok, HRZ, and
Kalubik shales totaling approximately 500 TVD. The estimated fracture gradient for this section
ranges from 15-18 ppg, with the gradient increasing down section. The Base Moraine is
estimated from seismic to be at 5,298 ft TVDSS at the heel, and 5,255 ft TVDSS at the toe of
the well.
The estimated formation pressure within the Torok Oil Pool is 2285psi at a depth of 5200
TVDSS.
SECTION 10 LOCATION, ORIENTATION AND A REPORT ON
MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT
CONFINING ZONE 20 AAC 25.283(a)(10)
ConocoPhillips has formed the opinion, based on following assessments for each well and
seismic, well, and other subsurface information currently available that none of these wells will
interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the
proposed wellbore trajectory.
Casing & Cement assessments for all wells that transect the confining zone:
3S-15: The well is targeting Kuparuk formation. The well is completely plugged and abandoned
per state regulations on 9/8/2020. Per Form 10-407 report on the AOGCC website, casing was
cemented with TOC at 297 MD based on observation from THA (Tubing Head Adapter). Top
cement job was performed to surface on 8/30/2020.The 7 CBL log data was re-evaluated.
The log was run from 7,650 to 8,202 MD. The effective top of the CBL was 7,807 MD where
the WLEG was entered. The top of quality cement is confirmed at 8,130 MD (5,923 TVDRKB),
above this poor cement distribution was seen to the WLEG. We have no data to evaluate
cement coverage across the Moraine and Coyote intervals. However, given the vertical and
longitudinal orientation of our planned stimulation operations in both zones, the hydraulic
fractures will not intersect the 3S-15 well in either the Moraine or Coyote sand.
Source:202-254 - Laserfiche WebLink (state.ak.us)
3S-17 & 3S-17A: ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations
on 3S-17 and 3S-17A (sidetrack from 3S-17 on 4/29/2003), commencing operations on
4/12/2023 and completing the Plug and Abandonment on 9/25/2023 The top cement job was
performed on 9/5/2023. The casing was cemented to surface.
Source: 203-080 Lasefiche WebLink (state.ak.us)
NDST-02PB1: According to the Pioneer Natural Resources Operation Summary Report on the
AOGCC website, on 1/30/2013, the bottom plug was pumped with 254 sxs of Premium
Cement. TOC was tagged at 8,012 MD. On 1/31/2013, the top plug was pumped with 60 bbl
of 17ppg Premium Class G Cement was pumped. Tagged firm cement at 5,236 MD.
Source: 212-163- Laserfiche WebLink (state.ak.us)
NDST-02: According to the Pioneer Natural Resources Operation Summary Report on the
AOGCC website, the 7-5/8 casing was cemented on 2/8/2013. The cement report indicates
that the job was pumped with 60 bbl of 15.8ppg Premium Cement with 3% Halad (R)-344 low
fluid loss control. Full circulation was seen throughout the entire job. Frac operations could not
be completed because a lodged ball damaged the tubing, and 60 bbl of CaCO3 was spotted
on 4/13/2013. On 4/14/2013, XX plug was set in nipple at 4,550 WLMD. ConocoPhillips Alaska
Inc. re-entered on 1/3/2023, pulled the XX plug at 8,360 CTMD (restriction) instead of at the
nipple and performed injectivity test at 0.5 bpm on 1/21/2023.
Source: 212-163- Laserfiche WebLink (state.ak.us)
3S-620: The 7-5/8 casing cement report on 2/16/2015 shows that the job was pumped as
designed, indicating competent cementing operations. 11.5 ppg Mud Push II was pumped
before dropping bottom plug, this was then chased with 15.8 ppg Class G cement and the top
T/ Kup C is
8,102' MD. SFD
Cement evaluation log indicates Moraine is isolated. SFD
( , ),
no data to evaluatep
cement coverage across the Moraine and Coyote intervals
Cement coverage for Moraine and Coyote is unknown. Separation
distance from 3S-610 at T/Moraine is 2400'. SFD
CBL suggests fair cement coverage across Moraine.
Separation distance at T/Moraine is 1920'. SFD
,p
top of quality cement is confirmed at 8,130 MD
Cement isolates the Moraine reservoir. SFD
Log suggests good-quality cement isolates both the Moraine and Coyote. SFD
plug was dropped. This was chased with 9.7 ppg mud. The plug bumped, pressured up to 1500
psi and held for 5 min. Floats were checked and they held.
3S-611: The 7-5/8 casing cement report on 10/13/2018 shows that the job was pumped as
designed, indicating competent cementing operations. 12.5 ppg MPII was pumped before
dropping bottom plug, this was then chased with 15.8 ppg Class G cement and the top plug
was dropped. This was chased with 9.4 ppg LSND mud. The plug bumped, pressured up to
1500 psi and held for 5 min. Floats were checked and they held.
3S-612: The 7-5/8 casing cement report on 11/4/2018 shows that the job was pumped as
designed, indicating competent cementing operations. 12.5 ppg MPII was pumped before
dropping bottom plug, this was then chased with 15.8 ppg Class G cement and the top plug
was dropped. This was chased with 9.5 ppg LSND mud. The plug bumped, pressured up to
1500 psi and held for 5 min. Floats were checked and they held.
3S-617:The 7 & 5/8 casing cement report on 11/5/2023 shows that the job was pumped as
designed, indicating competent cementing operations. The cement job was pumped with 142
barrels of 15.3 ppg. The plug was not bumped. Pressure was being monitored and no pressure
built up indicating that the floats held. A cement bond log indicates competent cement with a
cement top @ 3,841 MD (3,157 TVD).
3S-624: The 7-5/8 casing cement report on 12/24/2023 shows that the job was pumped as
designed, indicating competent cementing operations. The cement job was pumped with 125
barrels of 15.3ppg primary cement with LCM and 22 barrels of 15.3ppg primary cement without
LCM. The plug was bumped and the floats held. A cement bond log indicates competent
cement with a cement top @ 3,435 MD (2,778 TVD).
3S-606: The 7-5/8 casing cement report on 2/11/2024 shows that the job was pumped as
designed, indicating competent cementing operations. The cement job was pumped with 111
barrels of 15.3 ppg with BM-II (Bridge Maker II), followed with 29 barrels of 15.3 ppg without
BMII. The plug was bumped, pressure increased to 1500 psi and held for 5 minutes. A cement
bond log indicates competent cement with a cement top @ 3,950 MD (3,164 TVD).
Volumetric calculations suggest cement isolates the Moraine. SFD
ppg p
cement bond log
Log suggests very good-quality cement isolates the Moraine. SFD
p
cement bond log
cement
bond log
Log suggests very good-quality cement isolates the Moraine. SFD
g p
cement top @ 3,435 MD
Log suggests good-quality cement isolates the Moraine. SFD
p
cement top @ 3,950 MD
Volumetric calculations suggest cement isolates the Moraine. SFD
p g
cement top @ 3,841 MD
SECTION 11 LOCATION OF, ORIENTATION OF AND GEOLOGICAL
DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE
CONFINING ZONES 20 AAC 25.283(a)(11)
CPAI has formed the opinion, based on seismic, well, and other subsurface information
currently available that a single fault transects the Torok Oil Pool reservoir within one half mile
radius of the 3S-610 wellbore trajectory. While the fault doesnt intersect the 3S-617 or any
other nearby well trajectories, it is interpreted to have offset the toe section of the 3S-617 well
downwards by about 40ft. The fault trace has been mapped on seismic to run wellbore-parallel
between the 3S-617 and 3S-624 trajectories, as shown in Plat 1. It is interpreted to not affect
overburden integrity and therefore its presence will not interfere with containment.
If there is any indication that a fracture has intersected the mapped fault (or any other faults
unmapped to date) during fracturing operations, ConocoPhillips will go to flush and terminate
the stage immediately.
SECTION 12 PROPOSED HYDRAULIC FRACTURING PROGRAM
20 AAC 25.283(a)(12)
3S-610 was completed in 2024 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 2nd stage sleeve and
isolate the first stage. The 2nd stage will then be pumped and a third ball drop (progressively
getting larger) after each remaining stage, these balls will provide isolation from the previous
stage and allow fracturing from the toe of the well towards the heel.
Proposed Procedure:
Halliburton Pumping Services:
1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition
to identify any pre-existing conditions.
2. Ensure the frac tree was tested to 10,000 psi on the rig.
3. Ensure all pre-frac Well work has been completed and confirm the tubing and annulus
are filled with a freeze protect fluid to 2,057 MD/ 2,012 TVD.
4. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC.
5. MIRU 30 clean insulated Frac tanks (450 bbls usable volume per tank), with a berm
surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with
100ºF treated produced water (approx. 1,130 to 3,350 barrels are required for each
stage with breakdown, maximum pad and pumping down the next ball) [Contingency:
Seawater the chemical concentrations will be adjusted. See the attached chemical
disclosures for both options].
6. MIRU HES Frac Equipment.
7. PT Surface lines to 10,000 psi using a Pressure test fluid.
8. Test IA Pop off system to ensure lines are clear and all components are functioning
properly.
9. Bring up pumps and increase annulus pressure to 3,500 psi as the tubing pressures
up.
10. Perform DFIT after opening the Alpha Sleeve according to the attached pump
schedule. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to
shut down. Resume pumping to pump Frac Stage 1.
11. Perform minifrac test after opening the frac sleeve for Stage 2. Resume pumping to
pump Frac Stage 2.
12. Pump Frac Stages 3 through 24 by following attached pump schedule at ~37bpm
with a maximum expected treating pressure of 7,000 psi.
13. The well is ready for Post Frac well prep/production tree installation and flowback
(after Slickline and Coiled Tubing Cleanout).
SECTION 13 POST-FRACTURE WELLBORE CLEANUP AND FLUID
RECOVERY PLAN 20 AAC 25.283(a)(13)
Flowback will be initiated through a de-sander unit until the fluids clean up at which time it will
be turned over to production for initial clean up production.
From:Brooks, Phoebe L (OGC)
To:Rig 142
Cc:Regg, James B (OGC)
Subject:RE: 3S-610 3-15-24.xlsx
Date:Thursday, April 18, 2024 10:18:05 AM
Attachments:Doyon 142 03-15-24 Revised.xlsx
image001.png
image002.png
Thank you. I’ve attached a revised report adding the operator, changing the test type to Initial (as
this is the first test for KRU 3S-610). Please update your copy or let me know if you disagree.
Phoebe Brooks
Research Analyst
Alaska Oil and Gas Conservation Commission
Phone: 907-793-1242
CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the
Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended
recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or
disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail,
please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it
to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov.
From: Rig 142 <rig142@doyondrilling.com>
Sent: Wednesday, April 17, 2024 6:08 PM
To: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>
Subject: RE: 3S-610 3-15-24.xlsx
6 Bottles @ 1991 average psi. Corrected on this form.
Thank you
Harley Huntington
Rig 142 Tourpusher
Rig142@doyondrilling.com
Doyon Rig 142 Office 907-670-6002
Cell, 907-602-2105
From: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>
Sent: Wednesday, April 17, 2024 3:28 PM
To: Rig 142 <rig142@doyondrilling.com>
Subject: RE: 3S-610 3-15-24.xlsx
.586
37'
revised report operator,test type
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.
Some people who received this message don't often get email from rig142@doyondrilling.com. Learn why this is
important
The # of Ntgn. Bottles is missing; please advise.
Thank you,
Phoebe
Phoebe Brooks
Research Analyst
Alaska Oil and Gas Conservation Commission
Phone: 907-793-1242
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the
Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended
recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or
disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail,
please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it
to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov.
From: Rig 142 <rig142@doyondrilling.com>
Sent: Saturday, March 16, 2024 8:08 AM
To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay
<doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>
Cc: Doyon 142 Company Man <d142cm@conocophillips.com>
Subject: 3S-610 3-15-24.xlsx
Results of Initial 3S-610 BOPE test.
/#66*'95#/
Rig 142 Toolpusher
Rig142@doyondrilling.com
Doyon Rig 142 907-670-6002
Cell, 907-322-3715
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
SSu bmit to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner: Rig No.:142 DATE: 3/15/24
Rig Rep.: Rig Email:
Operator:
Operator Rep.: Op. Rep Email:
Well Name:PTD #2231260 Sundry #
Operation: Drilling: X Workover: Explor.:
Test: Initial: X Weekly: Bi-Weekly: Other:
Rams:250/5000 Annular:250/3500 Valves:250/5000 MASP:1778
MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping p Well Sign P Upper Kelly 1P
Permit On Location P Hazard Sec.P Lower Kelly 1P
Standing Order Posted P Misc.NA Ball Type 2P
Test Fluid WATER Inside BOP 1P
FSV Misc 0NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0NATrip Tank PP
Annular Preventer 1 13-5/8" 5M P Pit Level Indicators PP
#1 Rams 1 7-5/8" Solid P Flow Indicator PP
#2 Rams 1 Blind/ Shear P Meth Gas Detector PP
#3 Rams 1 3-1/2" x 6" VBR P H2S Gas Detector PP
#4 Rams 0NAMS Misc 0NA
#5 Rams 0NA
#6 Rams 0NAACCUMULATOR SYSTEM:
Choke Ln. Valves 1 3-1/8" 5M P Time/Pressure Test Result
HCR Valves 2 3-1/8" 5M P System Pressure (psi)3000 P
Kill Line Valves 3 3-1/8" 5M P Pressure After Closure (psi)1875 P
Check Valve 0NA200 psi Attained (sec)9 P
BOP Misc 0NAFull Pressure Attained (sec)47 P
Blind Switch Covers: All stations YES
CHOKE MANIFOLD:Bottle Precharge: 1000 P
Quantity Test Result Nitgn. Bottles # & psi (Avg.): 6 @ 1991 P
No. Valves 14 P ACC Misc 0NA
Manual Chokes 1P
Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result
CH Misc 0NA Annular Preventer 20 P
#1 Rams 7 P
Coiled Tubing Only:#2 Rams 7 P
Inside Reel valves 0NA #3 Rams 7 P
#4 Rams 0 NA
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:0 Test Time:6.8 HCR Choke 2 P
Repair or replacement of equipment will be made within days. HCR Kill 2 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 3/14/24 06:00 hrs
Waived By
Test Start Date/Time:3/15/2024 13:45
(date) (time)Witness
Test Finish Date/Time:3/15/2024 20:30
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Austin McLeod
Doyon
Test Annular w/ 5" & 7-5/8"" test jt 250/3500psi, Test upper 7 5/8: solid body rams T/ 250/5000 w/ 7 5/8" test joint & lower 3-1/2" x
6" VBR's 250/5000psi w/5" test jt. Test 2ea-5" FOSV/ 1ea-5" Dart 250/5000psi Test manual & hydraulic choke to 2,000 psi,
Choke valves #'s 1-14, Choke & Kill Manuals & HCR's, 2x 4"Demco valve on Kill, Upper & Lower IBOP, 250/5000psi, Test all
H2S, LEL & PVT flow alarms/both audible and visual. All rams functioned from both primary and remote controls. Drawdown
conducted w/ 2 air, and 2ea electrical pumps. Rig on a 21 day BOP test cycle.
M. Sam/ H. Huntington
ConocoPhillips Alaska, Inc.
K. Hinrichs/ M. Arthur
KRU 3S-610
Test Pressure (psi):
rig142@doyondrilling.com
d142cm@conocophillips.com
Form 10-424 (Revised 08/2022) 2024-0315_BOP_Doyon142_KRU_3S-610
9 9
9999
9
9
9
9
9
-5HJJ
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Chris Brillon
Wells Engineering Manager
Conoco Phillips Alaska, Inc.
700 G Street
Anchorage, AK, 99501
Re: Kuparuk River Field, Torok Oil Pool, KRU 3S-610
Conoco Phillips Alaska, Inc.
Permit to Drill Number: 223-126
Surface Location: 2780' FSL, 3819' FWL, SENE S18 T12N R8E
Bottomhole Location: 3333' FSL, 2037' FWL, SENW S35 T13N R7E
Dear Mr. Brillon:
Enclosed is the approved application for the permit to drill the above referenced well.
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well
logs run must be submitted to the AOGCC within 90 days after completion, suspension, or
abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first.
This permit to drill does not exempt you from obtaining additional permits or an approval required
by law from other governmental agencies and does not authorize conducting drilling operations
until all other required permits and approvals have been issued. In addition, the AOGCC reserves
the right to withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska
Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply
with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code,
or an AOGCC order, or the terms and conditions of this permit may result in the revocation or
suspension of the permit.
Sincerely,
Brett W. Huber, Sr.
Chair, Commissioner
DATED this ___ day of January 2024.
Brett W. Huber, Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2024.01.16 10:31:25 -09'00'
16
1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for:
Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates
Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas
2.Operator Name:5. Bond: Blanket Single Well 11. Well Name and Number:
Bond No.
3. Address: 6. Proposed Depth: 12. Field/Pool(s):
MD: 22192 TVD: 5122
4a. Location of Well (Governmental Section): 7.Property Designation:
Surface:
Top of Productive Horizon: 8.DNR Approval Number: 13.Approximate Spud Date:
1/30/2024
Total Depth: 9. Acres in Property: 14. Distance to Nearest Property:
3334' to ADL025528
4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 64 15. Distance to Nearest Well Open
Surface: x-476273 y- 5993915 Zone- 4 25 to Same Pool: 1763' to 3S-611
16. Deviated wells: Kickoff depth: 450 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 90 degrees Downhole: Surface:
Hole Casing Weight Grade Coupling Length MD TVD MD TVD
42" 20" 94 H-40 Welded 81 39 39 120 120
13.5" 10.75" 45.5 L-80 Hyd563 2651 39 39 2690 2555
9.875" 7.625" 29.7 L80 Hyd563 8384 39 39 8423 4806
9.875" 7.625" 33.7 P110S Hyd563 800 8423 4806 9223 5145
6.5" 4.5" 12.6 P110S Hyd563 13119 9073 5091 22192 5122
19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations)
Junk (measured):
TVD
Hydraulic Fracture planned? Yes No
20. Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis
Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements
Contact Name: Matt Smith
Chris Brillon Contact Email:matt.smith2@cop.com
Wells Engineering Manager Contact Phone:907-263-4324
Date:
Permit to Drill API Number: Permit Approval
Number:Date:
Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales:
Samples req'd: Yes No Mud log req'd: Yes No
H2S measures: Yes No Directional svy req'd: Yes No
Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No
Post initial injection MIT req'd: Yes No
APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
Perforation Depth MD (ft): Perforation Depth TVD (ft):
21. I hereby certify that the foregoing is true and the procedure approved herein will not be
deviated from without prior written approval.
Authorized Name:
Authorized Title:
Authorized Signature:
Commission Use Only
See cover letter for other
requirements.
Intermediate
Production
Liner
Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft):
Surface
Conductor/Structural
Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks
Casing Length Size Cement Volume MD
Total Depth MD (ft): Total Depth TVD (ft):
850sks 10.7ppg, 280sks 15.8ppg
970sks 15.3ppg
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
ConocoPhillips 59-52-180 3S-610
10 yds
P.O. Box 100360 Anchorage, Alaska, 99510-0360 Kuparuk River Field
Torok Oil Pool
2780' FSL, 3819' FWL, SENE S18 T12N R8E ADL380107 / ADL380106 / ADL025528 / ADL393883
(including stage data)
1482' FSL, 3779' FWL, NWSE S12 T12N R7E LONS 01-013
3333' FSL, 2037' FWL, SENW S35 T13N R7E 2448 / 2437 / 2560 / 5760
GL / BF Elevation above MSL (ft):
2291 1778
18. Casing Program:
Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g)
By Grace Christianson at 2:11 pm, Dec 19, 2023
KRU
A.Dewhurst 03JAN23
50-103-20875-00-00
Alaska, Inc.
223-126
Initial BOP test to 5000 psig; subsequent BOP test to 4000 psig
Annular preventer test to 2500 psig
Waiver for CPAI Rotary BOPE Test Frequency applies according to order OTH-21-018 extension attached
Intermediate II cement evaluation may use SonicScope under the attached Conditions of Approval
Surface casing LOT and annular LOT to the AOGCC as soon as available
Diverter variance request granted per 20 AAC 20.035(h)(2), based on CPAI offset
analysis of 3S-617 and other wells drilled at the 3S-pad. -A.Dewhurst 02JAN23
DSR-12/19/23VTL 01/16/2024
X
JLC 1/16/2024
Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr.
Date: 2024.01.16 10:31:45 -09'00'
01/16/24
01/16/24
<Zhϯ^ͲϲϭϬ
Conditions of Approval:
Approval is granted to run the LWD-Sonic on upcoming well with the following provisions:
1. CPAI will provide a written log evaluation/interpretation to the AOGCC along with the log as
soon as they become available. The evaluation is to include/highlight the intervals of competent
cement that CPAI is using to meet the objective requirements for annular isolation, reservoir
isolation, or confining zone isolation etc. Providing the log without an evaluation/interpretation
is not acceptable.
2. LWD sonic logs must show free pipe and Top of Cement, just as the e-line log does. CPAI must
start the log at a depth to ensure the free pipe above the TOC is captured as well as the TOC.
Starting the log below the actual TOC based on calculations predicting a different TOC will not
be acceptable.
3. CPAI will provide a cement job summary report and evaluation along with the cement log and
evaluation to the AOGCC when they become available
4. CPAI will provide the results of the FIT when available.
5. Depending on the cement job results indicated by the cement job report, the logs and the FIT,
remedial measures or additional logging may be required.
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
March 2, 2023
Mr. Luke Lawrence
Wells Manager
ConocoPhillips Alaska
700 G Street
Anchorage, AK 99501
Re: Docket Number: OTH-21-018
CPAI Rotary Rig BOPE Test Frequency
Dear Mr. Lawrence:
By letter dated January 12, 2023, ConocoPhillips Alaska, Inc. (CPAI) requested a continuance of
the waiver granted under Docket OTH-21-018 allowing certain CPAI rotary drilling rigs to test
blowout prevention equipment (BOPE) on a 21-day test schedule. The Alaska Oil and Gas
Conservation Commission (AOGCC) grants CPAI’s request for a limited duration and scope.
OTH-21-018 approved the 21-day test interval for a 1-year period which expired on January 25,
2023. The AOGCC approved an extension to the pilot program by electronic mail on February 6,
2023, to accommodate review of the July-December 2022 BOPE Between Wells Maintenance
Report (received January 27, 2023, and revised February 3, 2023). AOGCC met with CPAI on
February 22, 2023 to discuss the Between Wells Maintenance Report and BOPE performance of
the CPAI-operated rigs during 2022 in considering the requested continuance.1
During the past year, CPAI-operated rigs Doyon 25 and Doyon 26 were authorized to participate
in the pilot – the other rigs working for CPAI failed to meet the conditions for testing BOPE at 21-
day intervals.2
CPAI’s request to continue the pilot project allowing BOPE testing on a 21-day interval is
approved for drilling rigs Doyon 25 and Doyon 26, with the following conditions:
- The pilot test duration is for ONE year from the approval date of this letter, subject to
potential extension and expansion to include other CPAI operated rigs with at least 3
months of continuous rig work and AOGCC review of a rig’s BOPE system reliability.
1 AOGCC approval of the Between Wells Maintenance program has enabled CPAI workover rigs to extend the
interval between BOPE tests from every 7 days to not exceeding 14 days and was also part of the justification for
allowing certain rigs to test BOPE on a 21-day interval. CPAI data shows the BWM has reduced the number of
component failures during BOPE testing by replacing components that indicate suspect integrity before those
components fail during testing.
2 Doyon 26 has additionally been approved (Permit-to-Drill) to test BOPE on an event-basis instead of at pre-
determined time intervals while drilling specific sections in an ultra-extended reach well.
Docket Number: OTH-21-018
March 2, 2023
Page 2 of 2
- CPAI must continue to implement the BWM program as approved by AOGCC.
- Development drilling wells only are included in this approval.
- The initial test after rigging up BOPE to drill a well must be to the rated working pressure
as provided in API Standard 53.
- CPAI is encouraged to take advantage of opportunities to test.
- CPAI must adhere to original equipment manufacturer recommendations and replacement
parts for BOPE.
- Requests for extensions beyond 21 days must include justification with supporting
information demonstrating the additional time is necessary for well control purposes or to
mitigate a stuck drill string.
- 48-hour advance notice for a BOPE test shall be provided to AOGCC for opportunity to
witness.
If you have questions regarding this, please contact Jim Regg at (907) 793-1236.
Sincerely,
Brett W. Huber, Sr.
Chair, Commissioner
cc: Greg Hobbs (CPAI)
Mike Kneale (CPAI)
Victoria Loepp (AOGCC)
AOGCC Inspectors (email)
Brett W. Huber,
Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.03.02 11:09:23
-09'00'
ConocoPhillips Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907-276-1215
December 15, 2023
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
Re: Application for Permit to Drill 3S-610
Dear Sir or Madam:
ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Moraine Producer well from the 3S drilling pad.
The intended spud date for this well is 1/30/2024. It is intended that Doyon 142 be used to drill the well.
3S-610 will utilize a 13 1/2” surface hole drilled to TD and 10 3/4” casing will be set and cemented to surface. As noted in
section 4 of the attached proposed drilling program, the low maximum anticipated surface pressure of the well allows use of a
three preventer BOPE per 20 AAC 25.035 (e) (1) (A) (i-iii). The fourth preventer will contain solid body pipe rams that will
be sized for the intermediate casing string. The 9 7/8” intermediate hole will be drilled and topset the Moraine reservoir. A 7
5/8” casing string will be set and cemented from TD to secure the shoe and cover 500’MD or 250’TVD above any
hydrocarbon-bearing zones (Coyote).
The production interval will be comprised of a 6 1/2” horizontal hole that will be landed and geo-steered in the Moraine
formation. The well will be completed as an uncemented, fracture stimulated Producer with 4 1/2” liner, frac sleeves and swell
packers. The upper completion will include a production packer with GLM’s, chem injection line and an ESP, and tied back to
surface.
It is requested that a variance of the diverter requirement under 20AAC 25.035(h)(2) is granted for well 3S-610. At 3S, there
has not been a significant indication of shallow gas hydrates though the surface hole interval.
Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information
attached to this application includes the following:
1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a)
2. A proposed drilling program
3. A proposed completion diagram
4. A drilling fluids program summary
5. Pressure information as required by 20 ACC 25.035 (d)(2)
6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b)
Information pertinent to the application that is presently on file at the AOGCC:
1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC
25.035 (a) and (b).
2. A description of the drilling fluids handling system.
3. Diagram of riser set up.
If you have any questions or require further information, please contact Matt Smith at 907-263-4324
(matt.smith2@conocophillips.com) or Chris Brillon at 907-265-6120.
Sincerely, cc:
3S-610 Well File / Jenna Taylor ATO 1560
David Lee ATO 1552
Matt Smith Chris Brillon ATO 1548
Drilling Engineer Roland Kirschner ATO 636
It is requested that a variance of the diverter requirement under 20AAC 25.035(h)(2) is granted for well 3S-610.
Application for Permit to Drill, 3S-610
Saved: 15-Dec-23
3S-610 PTD
Page 1 of 9
Printed: 15-Dec-23
3S-610
Application for Permit to Drill Document
Table of Contents
1. Well Name (Requirements of 20 AAC 25.005 (f)) ........................................................................................................ 1
2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) ......................................................................................... 1
3. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) ........................................................................ 3
4. Blowout Prevention Equipment (Requirements of 20 AAC 25.005(c)(3)) ............................................................. 4
5. Diverter System (Requirements of 20 AAC 25.005(c)(7)) ..................................................................................... 5
6. MASP Calculations (Requirements of 20 AAC 25.005(c)(4)) ................................................................................ 5
7. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) ............................ 6
8. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) ........................................................... 6
9. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) .................................................................................. 7
10. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) ........................................ 8
11. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) ................................................................................... 8
12. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) ................................................................... 8
13. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) ............................................................................. 8
14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005 (c)(14)) ......... 8
15. Drilling Hazards Summary ................................................................................................................................. 8
16. Proposed Completion Schematic ..................................................................................................................... 10
1. Well Name (Requirements of 20 AAC 25.005 (f))
The well for which this application is submitted will be designated as 3S-610
2. Location Summary (Requirements of 20 AAC 25.005(c)(2))
Location at Surface 2,780 FSL, 3,819 FWL, SENE S18 T12N R8E, UM
NAD 1927
Northings: 5993915
Eastings:476273
RKB Elevation 64’AMSL
Pad Elevation 25’AMSL
Top of Productive Horizon
(Heel)
1482‘ FSL, 3779‘ FWL, NWSE S12 T12N R7E, UM
NAD 1927
Northings: 5997915
Eastings: 470968
Measured Depth, RKB:
9,223
Total Vertical Depth, RKB:5,145
Total Vertical Depth, SS:5,081
Total Depth (Toe) 3333‘ FSL, 2037‘ FWL, SENW S35 T13N R7E, UM
NAD 1927
Northings: 6010340
Eastings: 467689
Measured Depth, RKB:22,192
Total Vertical Depth, RKB:5,122
Total Vertical Depth, SS:5,058
Pad Layout
3. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13))
The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic.
1. MIRU Doyon 142 onto 3S-610
2. Rig up and test riser, dewater cellar as needed.
3. Drill 13 1/2” hole to the surface casing point as per the directional plan.
4. Run and cement 10 3/4” surface casing to surface.
5. Install BOPE and MPD equipment.
6. Test BOPE to 250 psi low / 5,000 psi high (24-48 hr regulatory notice).
7. Pick up and run in hole with 9 7/8” drilling BHA to drill the intermediate hole section.
8. Chart casing pressure test to 3000 psi for 30 minutes.
9. Drill out 20’ of new hole and perform LOT. Maximum LOT to 18 ppg. Minimum LOT required to drill ahead is 11.5
ppg EMW.
10. Drill 9 7/8” hole to section TD, setting pipe above the Moraine Reservoir. (LWD Program: GR/RES/Den/Neu).
11. Run 7 5/8” casing and cement to a minimum of 500’ MD or 250’ TVD above any hydrocarbon bearing zones
(cementing schematic attached). Pressure test casing if possible on plug bump to 4000 psi.
12. Test BOPE to 250 psi low / 4,000 psi high (24-48 Regulatory notice).
13. Pick up and run in hole with 6 1/2” drilling BHA. Log top of cement with sonic tool in recorded mode.
14. Chart casing pressure test to 4,000 psi for 30 minutes if not tested on plug bump.
15. Drill out shoe track and 20 feet of new formation. Perform LOT to a maximum of 14.5 ppg. Minimum required leak-
off value is 11.5 ppg EMW.
16. Drill 6 1/2” hole to section TD (LWD Program: GR/RES/Den/Neu).
17. Pull out of hole with drilling BHA. Review cement job details and sonic log TOC.
18. Run 4 1/2” liner with toe valve, frac sleeves and swell packers and liner hanger to TD.
19. Run 4 1/2” upper completion with glass plug, production packer, chemical injection mandrel with cap string, sliding
sleeve, ESP, downhole gauge, and gas lift mandrels. Space out and land tubing hanger with pre-installed and pre-
tested BPV.
20. Pressure test hanger seals to 3,850 psi.
21. Pressure test against the glass plug to set production packer, test tubing to 3,850 psi, chart test.
22. Bleed tubing pressure to 2200 psi and test IA to 3,850 psi, chart test.
23. Install HP-BPV and test to 2500 psi.
24. Nipple down BOP.
25. Install tubing head adapter assembly. N/U tree and test to 5000 psi/10 minutes.
26. Freeze protect down tubing and annulus.
27. Secure well. Rig down and move out.
Please note – This well will be frac’d
4. Blowout Prevention Equipment (Requirements of 20 AAC 25.005(c)(3))
Please reference BOP schematics on file for Doyon 142.
Doyon 142 will use a BOPE stack equipped with an annular preventer, fixed 7 5/8” solid body rams, blind/shear rams and
variable rams while drilling and running casing in the intermediate section of 3S-610.
3S-610 has a MASP of 1,778 psi in the intermediate hole section using the methodology in section 6 MASP calculations.
With a MASP less than 3000 psi ConocoPhillips classifies the operation as a Class 2.
Per 20AAC 25.035.e.a.A:
For an operation with a maximum potential surface pressure of 3,000 psi or less, BOPE must have at least
three preventers, including:
i. One equipped with pipe rams that fit the size of drill pipe, tubing or casing begin used, except that
pipe rams need not be sixed to bottom-hole assemblies and drill collars.
ii. One with blind rams
iii. One annular type
Intermediate Drilling/Casing Production
Proposed Configuration: Proposed Configuration:
Annular Preventer (iii) Annular Preventer
7 5/8” fixed rams during drilling Intermediate VBRs in Upper Cavity
Blind/Shear Rams (ii) Blind/Shear Rams
VBRs (i) VBRs in Lower Cavity
5. Diverter System (Requirements of 20 AAC 25.005(c)(7))
It is requested that a variance of the diverter requirement under 20 AAC 25.035(h)(2) is granted. At 3S, there has not been
significant indication of shallow gas or gas hydrates through the surface hole interval. There is 1 previously drilled wells
(3S-617) within 500’ of the proposed 3S-610 surface shoe location. This well did not encounter any significant indication of
shallow gas or gas hydrates.
6. MASP Calculations (Requirements of 20 AAC 25.005(c)(4))
The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well:
Casing
Size (in)
Csg Setting Depth
MD/TVD(ft)
Fracture
Gradient (ppg)
Pore pressure
(psi)
ASP Drilling
(psi)
20 97 / 97 10.9 54 56
10 3/4 2,690 / 2,555 12.5 1,143 1,405
7 5/8 9223 / 5,145 13.5 2,301 1,778
4 1/2 22,192 / 5,122 13.0 2,291 n/a
PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP)
ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the
surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows:
1) ASP = [(FG x 0.052) - 0.1]*D
Where: ASP = Anticipated Surface pressure in psi
FG = Fracture gradient at the casing seat in lb/gal
0.052 = Conversion from lb./gal to psi/ft
0.1 = Gas gradient in psi/ft
D = true Vertical depth of casing seat in ft RKB
OR
2) ASP = FPP – (0.1 x D)
Where: FPP = Formation Pore Pressure at the next casing point
FPP = 0.4525 x TVD
1. ASP CALCULATIONS
1. Drilling below 20” conductor
ASP = [(FG x 0.052) – 0.1] D
= [(10.9 x 0.052) – 0.1] x 97 = 56 psi
OR
ASP = FPP – (0.1 x D)
= 1,143 – (0.1 x 2,555 ) = 887 psi
2. Drilling below 10.75” surface casing
ASP = [(FG x 0.052) – 0.1] D
= [(12.5 x 0.052) – 0.1] x 2,555 = 1,405 psi
OR
ASP = FPP – (0.1 x D)
= 2,301 – (0.1 x 5,145 ) = 1,786 psi
3. Drilling below 7.625” intermediate casing
ASP = [(FG x 0.052) – 0.1] D
= [(13.0 x 0.052) – 0.1] x 5,145 = 3,097 psi
OR
ASP = FPP – (0.1 x D)
= 2,291 – (0.1 x 5,122 )= 1,778 psi
(B) data on potential gas zones;
The well bore is not expected to penetrate any shallow gas zones.
(C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones,
and zones that have a propensity for differential sticking;
Please see Drilling Hazards Summary
7. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5))
Drill out the casing shoe and perform LOT/FIT as per the procedure that ConocoPhillips Alaska has on file with
the Commission.
8. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6))
Casing and Cementing Program
Csg/Tbg
OD (in)
Hole Size
(in)
Weight
(lb/ft) Grade Conn. Cement Program
20 42 94 H-40 Welded Cemented to surface with 10 yds slurry
10 3/4 13 1/2 45.50 L-80 Hyd563 Cement to Surface
7 5/8 9 7/8 29.70
33.70
L80
P110S Hyd563 250’ TVD or 500’ MD, whichever is greater, above upper
most producing zone (Coyote)
4 1/2 6 1/2 12.60 P110S Hyd563 Unemented liner with frac sleeves and swell packers
Cementing Calculations
10 3/4” Surface Casing run to 2,690 ’ MD / 2,555 ’ TVD
Cement 2,690 MD to 2,190 (500’ of tail) with Class G + Add's@ 15.8 PPG, and from 2,190' to surface with 10.7 ppg
Arctic Lite Crete. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost (1,741 ’
MD), zero excess in 20” conductor.
Lead slurry from 2,190’ MD to surface with Arctic Lite Crete @ 10.7 ppg
Total Volume = 2,461ft3 => 850 sx of 10.7 ppg Class G + Add's @ 2.92 ft3 /sk
Tail slurry from 2,690 MD to 2,190’ MD with 15.8 ppg Class G + Add's
Total Volume = 316 ft3 => 280 sx of 15.8ppg Class G + Add's @ 1.16 ft3/sk
7 5/8” Intermediate Casing run to 9223’ MD / 5,145 ’ TVD
Top of slurry is designed to be at 5,351 ’ MD, which is 500’MD or 250’ TVD above the prognosis shallowest
hydrocarbon bearing zone, Coyote. If a shallower hydrocarbon zone of producible volumes, is encountered while
drilling, a 2-stage cement job will be performed to isolate this zone. Assume 40% excess annular volume.
Tail slurry from 9,223 MD to 5,351’ MD with 15.3 ppg Class G + Add's
Total Volume = 1,185 ft3 => 970 sx of 15.3 ppg Class G + Add's @ 1.23 ft3/sk
9. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8))
Surface Intermediate Production
Hole Size in. 13 1/2 9 7/8 6 1/2
Casing Size in. 10 3/4 7 5/8 4 1/2
Density PPG 9.0 – 10.5 9.0 – 9.8 9.0 – 10.0
PV cP 20-50 8-15 7-12
YP lb./100 ft2 30 - 80 20 - 30 15 - 25
Funnel Viscosity s/qt.
250 – 300 to
base perm
200-300 to TD
40-60 35-50
Initial Gels lb./100 ft2 30 - 50 8 - 15 5- 10
10 Minute Gels lb./100 ft2 50 - 70 <20 7 - 15
API Fluid Loss cc/30 min. N.C. – 15.0 < 10.0 < 6.0
HPHT Fluid Loss cc/30 min. N/A N/A < 10.0
pH 9.0 – 10.0 9.0 – 10.0 9.5 – 10.5
Surface Hole:
A water based spud mud will be used for the surface interval. Mud engineer to perform regular mud checks to maintain
proper specifications The mud weight will be maintained at N10.0 ppg by use of solids control system and dilutions
where necessary.
Intermediate:
Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular
velocity. Maintain mud weight at or below 9.5 ppg for formation stability and be prepared to add loss circulation
material if necessary. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required)
will all be important. The mud will be weighted up to 9.5 ppg before pulling out of the hole.
Production Hole:
The horizontal production interval will be drilled with a water-based mud drill-in fluid (KlaShield) weighted to 9 – 10
ppg. MPD will be available for adding backpressure during connections if necessary.
Diagram of Doyon 142 Mud System on file.
Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033.
10. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9))
N/A - Application is not for an exploratory or stratigraphic test well.
11. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10))
N/A - Application is not for an exploratory or stratigraphic test well.
12. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11))
N/A - Application is not for an offshore well.
13. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12))
Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.
14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC
25.005 (c)(14))
Waste fluids and cuttings generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II
disposal well at the 1B Facility. If needed, excess cuttings generated will be hauled to Milne Point or Prudhoe Bay Grind
and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored,
tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in
accordance with a permit from the State of Alaska.
15. Drilling Hazards Summary
13 1/2" Hole / 10 3/4” Casing Interval
Event Risk Level Mitigation Strategy
Conductor Broach Low Monitor cellar continuously during interval.
Well Collision Low Follow real time surveys very closely, gyro survey as
needed to ensure survey accuracy.
Gas Hydrates Low If observed – control drill, reduce pump rates and
circulating time, reduce mud temperatures
Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),
pumping out
Washouts/Hole Sloughing Low Cool mud temperatures, minimize circulating times
when possible
Running sands and gravels Low Maintain planned mud properties, increase mud
weight, use weighted sweeps
9 7/8” Hole /7 5/8” Liner - Casing Interval
Event Risk Level Mitigation Strategy
Sloughing shale / Tight hole /
Stuck Pipe
Low Good hole cleaning, pre-treatment with LCM, stabilized
BHA, maintain planned mud weights and adjust as
needed, real time equivalent circulating density (ECD)
monitoring
Lost circulation Moderate Reduce pump rates, reduce trip speeds, real time ECD
monitoring, mud rheology, add lost circulation material
Hole swabbing on trips Moderate Reduce trip speeds, condition mud properties, proper
hole filling, pump out of hole, real time ECD monitoring,
Liner will be in place at TD
Abnormal Reservoir Pressure
(Coyote / K3)
Low Well control drills, check for flow during connections,
increase mud weight if necessary
6 1/2” Hole / 4 1/2” Liner - Horizontal Production Hole
Event Risk Level Mitigation Strategy
Lost circulation Moderate Reduce pump rates, real time ECD monitoring,
maintain mud rheology, add lost circulation material
Hole swabbing on trips Moderate Reduce trip speeds, condition mud properties, proper
hole filling, pump out of hole, real time ECD monitoring
Abnormal Reservoir Pressure Low Well control drills, check for flow during connections,
increased mud weight
Differential Sticking Moderate Uniform reservoir pressure along lateral, keep pipe
moving, control mud weight
Running Liner to Bottom Moderate Properly clean hole on the trip out with BHA, perform
clean out run if necessary, utilize super sliders for
weight transfer if needed, monitor T&D real time
Well Proximity Risks:
3S is a multi-well pad. Directional drilling / collision avoidance information as required by AOGCC 20 ACC 25.050 (b) is
provided in the following attachments.
Drilling Area Risks:
Reservoir Pressure: Offset injection has the potential to increase reservoir pressure over predicted. Although this is unlikely,
the rig will be prepared to weight up if required.
Weak sand stringers could be present in the overburden. LCM material will be available to seal in losses in the intermediate
section.
Lost Circulation: Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost
circulation if needed.
Good drilling practices will be stressed to minimize the potential of taking swabbed kicks.
H2S on 3S pad – There have been elevated H2S levels noted on the 3S pad post drilling. Lift gas from CPF3 facility has ~200-
250ppm H2S in it. The rig will have H2S sensors which will be tested, escape packs staged around the rig, and personal
monitors will be worn by the core crew members. A detailed emergency operating procedure will be communicated to all
personnel, in the event H2S is encountered
16. Proposed Completion Schematic
2
34
18
712
35
14
6
13
31
11
36
1
T12NR8E
T13NR8E
T1
2
N
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T13NR7E
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T13NR7E
ADL380107
L390697
ADL355032
ADL380106
ADL393883
ADL025528
ADL025544
DL390434
MOR
A
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3S-16
PALM 1
3S-07
3
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-
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3S-18
3S-08
3S-08A
3S-08B
3S-26
3S-08C
3S-0
3
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9
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3S
Document Path: S:\ANC\Longterm\AK GIS\GKA\DM\GKA_Wells_AD01\CPF_3_Wells\Well_3S-610\Well_3S-610.aprx
k12/12/2023
3S-610
PTD
3
S
-
6
1
0
010.5 Miles
Open Inteval
Well Trajectory
Well Pad
Suspended Well
P+A Well
Active Well
Roads and Pads
Torok PA (Proposed)
Kuparuk PA
Unit Boundary
ADNR Section
ADNR Township
CPAI Lease
39 500
500 800
800 1100
1100 1500
1500 2000
2000 3000
3000 3600
3600 3800
3800 5000
5000 10000
10000 22193
3S-610 wp09.1 Plan Summary
0
3
Do
g
l
e
g
S
e
v
e
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i
t
y
0 3500 7000 10500 14000 17500 21000
Measured Depth
10-3/4" Surface Casing
7-5/8" Intermediate Casing
30.0
30.0
60.0
60.0
0
90
180
270
30
210
60
240 120
300
150
330
Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in]
58108158208258308
358407457507
3S-07
58
108158208258308357
407
457
506
554
603
3S-08
58
108158208258308357
407
457
506
554
603
58
108158208258308357
407
457
506
554
603
59
109159209259309358408
458
507
555
604
59
109159209259309358408
458
507
555
604
59
109159209259309358408
458
507
555
604
58107157207257307357407457506556605655704
3S-09
58
108158208258308357407457507557607
656
706
755
803
3S-10
4050100150200250300
350400450500551601651701752802853904954100510551106
115712071258
3S-611
4050100150200250300
350400450500551601651701752802853904954100510551106
115712071258
50100150200250300
350400450501551601651702752803853904954100510561106
1157
1207 1258
4050100150
200250300350400450500551601652702753
3S-612
39501001502002503003503994495003S-613
3726
3S-723 wp02
0
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Tr
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0 2500 5000 7500 10000 12500 15000 17500
Vertical Section at 332.22°
10-3/4" Surface Casing
7-5/8" Intermediate Casing
0
18
35
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0 400 800 1200 1600 2000 2400 2800
Measured Depth
Equivalent Magnetic Distance
DDI
7.134
SURVEY PROGRAM
Date: 2021-02-19T00:00:00 Validated: Yes Version:
Depth From Depth To Survey/Plan Tool
39.00 1400.00 3S-610 wp09.1 (3S-610) SDI_URSA1_I4
1400.00 2690.00 3S-610 wp09.1 (3S-610) MWD+IFR2+SAG+MS
2690.00 9220.00 3S-610 wp09.1 (3S-610) MWD+IFR2+SAG+MS
9220.00 22192.11 3S-610 wp09.1 (3S-610) MWD+IFR2+SAG+MS
Ground / 25.00
CASING DETAILS
TVD MD Name
2555.00 2690.20 10-3/4" Surface Casing5145.12 9223.00 7-5/8" Intermediate Casing
5122.00 22192.11 4-1/2" Production Liner
Mag Model & Date: BGGM2023 15-Feb-24
Magnetic North is 14.35° East of True North (Magnetic Declinatio
Mag Dip & Field Strength: 80.64° 57220.26nT
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00
2 450.00 0.00 0.00 450.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.00
3 600.00 1.50 305.00 599.98 1.13 -1.61 1.00 305.00 1.75 Start Build 1.50
4 750.00 3.75 305.00 749.82 5.07 -7.24 1.50 0.00 7.85 Start Build 2.00
5 1688.85 22.53 305.00 1660.00 126.92 -181.26 2.00 0.00 196.77 Start 108.26 hold at 1688.85 MD
6 1797.11 22.53 305.00 1760.00 150.71 -215.24 0.00 0.00 233.66 Start Build 1.00
7 2706.63 31.62 305.00 2569.00 387.91 -553.99 1.00 0.00 601.38 Start 20.00 hold at 2706.63 MD
8 2726.63 31.62 305.00 2586.03 393.92 -562.58 0.00 0.00 610.71 Start DLS 3.00 TFO 2.13
9 4004.51 69.94 306.41 3379.02 963.73 -1349.63 3.00 2.13 1481.65 Start 4745.59 hold at 4004.51 MD
10 8750.10 69.94 306.41 5006.40 3609.58 -4937.34 0.00 0.00 5494.63 Start DLS 3.00 TFO 66.52
11 10101.04 89.00 343.00 5260.51 4676.92 -5676.55 3.00 66.52 6783.47 Start 200.00 hold at 10101.04 MD
1210301.04 89.00 343.00 5264.00 4868.15 -5735.01 0.00 0.00 6979.91 3S-610 T01 120823 Start 20.00 hold at 10301.04 MD
1310321.04 89.00 343.00 5264.35 4887.28 -5740.86 0.00 0.00 6999.56 Start DLS 1.50 TFO 68.81
1410538.52 90.18 346.04 5265.91 5096.83 -5798.89 1.50 68.81 7212.01 Start 1609.48 hold at 10538.52 MD
15 12148.00 90.18 346.04 5260.85 6658.78 -6187.13 0.00 0.00 8774.90 Start DLS 1.00 TFO -6.36
1612230.50 91.00 345.95 5260.00 6738.83 -6207.09 1.00 -6.36 8855.03 3S-610 T02 121123 Start DLS 1.00 TFO -9.83
1712299.91 91.68 345.83 5258.37 6806.12 -6224.01 1.00 -9.83 8922.44 Start 2414.64 hold at 12299.91 MD
1814714.54 91.68 345.83 5187.42 9146.29 -6814.80 0.00 0.0011268.27 Start DLS 1.00 TFO 175.25
1914773.13 91.10 345.88 5186.00 9203.08 -6829.11 1.00 175.2511325.19 3S-610 T03 121123 Start DLS 1.00 TFO 178.93
2014833.96 90.49 345.89 5185.16 9262.07 -6843.94 1.00 178.9311384.29 Start 7358.15 hold at 14833.96 MD
2122192.11 90.49 345.89 5122.00 16398.00 -8637.50 0.00 0.0018533.77 3S-610 T04 121123 TD at 22192.11
FORMATION TOP DETAILS
TVDPath Formation1375.00 Top Ugnu C1639.00 Top Ugnu B
1708.00 Base Permafrost
1747.00 Top Ugnu A
2015.00 Top West Sak
2467.00 Base West Sak
2605.00 C-803451.00 C-503886.00 C-354091.00Top Coyote (Nanushuk), K34488.00 Base Coyote (Nanushuk)
5165.00 Top Torok (Moraine)
By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surroundingwells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basiis
for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance.
Prepared by Checked by Accepted by Approved by
plan 25+39 @ 64.00usft (D142)
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v v v v v
v v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
v v v v v
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7
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7
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7
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v
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0
30
60
Ce
n
t
r
e
t
o
C
e
n
t
r
e
S
e
p
a
r
a
t
i
o
n
0 450 900 1350 1800 2250
Partial Measured Depth
3S
-
0
7
3S
-
0
8
3S
-
09
3S
-
1
0
3S
-
6
1
1
Equivalent Magnetic Distance
3S-610 wp09.1 Ladder View
0
150
300
Ce
n
t
r
e
t
o
C
e
n
t
r
e
S
e
p
a
r
a
t
i
o
n
0 3500 7000 10500 14000 17500 21000
Measured Depth
3S
-
0
3
3S
-
0
6
3S
-
0
6
A
3S
-
0
7
3S
-
08
3S
-
08
A
3S
-
08
B
3S
-
08
C
3S
-
08
C
L
1
3S
-
08
C
L
1
P
B
1
3S
-
09
3S
-
1
0
3S
-
1
4
3S
-
1
5
3S
-16
3S
-
1
7
3S
-
1
7
A
3S
-
1
8
3S
-
1
9
3S
-
2
1
3S
-
22
3S
-
2
6
PA
L
M
1
3S-
61
1
3S-
6
1
1
PB
1
3S-
61
1
A
w
p
0
4
3S
-
6
1
2
3S
-
6
1
3
3S
-
6
1
5
3S
-
6
1
7
3S
-
6
2
0
3S
-
6
2
4
w
p
0
7
.
1
3S-
7
0
1
3S
-
7
0
1
A
3S
-
70
4
3S
-
6
0
2
wp
0
4
3S
-
6
0
5
w
p
0
4
3S
-
6
0
6
w
p
0
6
.
1
3S
-
7
1
4
wp
0
3
3S
-
7
1
8
w
p
0
4
3S
-
7
1
9
w
p
0
3
3S
-
7
2
1
w
p
0
3
3S
-
7
2
2
w
p
0
4
3S
-
7
2
3
w
p
0
2
3T
-
6
0
7
w
p
04
v
5
Equivalent Magnetic Distance
SURVEY PROGRAM
Depth From Depth To Survey/Plan Tool
39.00 1400.00 3S-610 wp09.1 (3S-610) SDI_URSA1_I4
1400.00 2690.00 3S-610 wp09.1 (3S-610) MWD+IFR2+SAG+MS
2690.00 9220.00 3S-610 wp09.1 (3S-610) MWD+IFR2+SAG+MS
9220.0022192.11 3S-610 wp09.1 (3S-610) MWD+IFR2+SAG+MS
10:02, December 12 2023
CASING DETAILS
TVD MD Name
2555.00 2690.20 10-3/4" Surface Casing
5145.12 9223.007-5/8" Intermediate Casing
5122.00 22192.11 4-1/2" Production Liner
39 500
500 800
800 1100
1100 1500
1500 2000
2000 3000
3000 3600
3600 3800
3800 5000
5000 10000
10000 22193
3S-610 wp09.1 TC View
30
30
60
60
90
90
120
120
150
150
0
90
180
270
30
210
60
240 120
300
150
330
Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in]
58108158208258308358408458507556
604
652
700
748
794
840
885
930
975
1018
3S-03
57
107157207257307357407457506
555
604
653701750798846894942990103710851133
118112281276132413711418
1465
1511
1558 3S-06
57
107157207257307357407457506
555
604
653701750798846894942990103710851133
118112281276132413711418
1465
1511
1558
58108158208258308
358407457507556605654702751799 846 893 939 985 3S-07
58
108158208258308357407457
506
554
603
650
698
744
790
834
877
3S-08
58
108158208258308357407457
506
554
603
650
698
744
790
834
877
3S-08A
58
108158208258308357407457
506
554
603
650
698
744
790
834
877
59
109159209259309358408
458
507
555
604
651
699
745
791
835
878
59
109159209259309358408
458
507
555
604
651
699
745
791
835
878
59
109159209259309358408
458
507
555
604
651
699
745
791
835
878
58107157207257307357407457506556605655704753801850 897 945 992
1038
1083 3S-09
58
108158208258308357407457507557607656
706
755
803
851
899
946
993
1039
1084
3S-10
58108158208258308358408458508558
609
659
709
760
810
861
911
961
1012
1062
1112
1161
1211
1260
3S-14
57107157207257307357407457507558609660711
762
813
865
917
968
1020
1071
1123
1174
1226
3S-15
57107157207
257307357407457508559610661712763814865915966101710671117116712161265
1314
1362
1410
1457
1504
1550
1595
1641
1685
1731 3S-16
581081582082573073574074575085586096617127643S-17
58108158208257307357407457508558609661712
764
58108158208258
3083584084583S-18
4050100150200250300
3504004505005516016517017528028539049541005105511061157120712581309
1360
1411
1461
1512
1563
1614
1666
1716
1765
1815
1866
1917
1968
3S-611
4050100150200250300
3504004505005516016517017528028539049541005105511061157120712581309
1360
1411
1461
1512
1563
1614
1666
1716
1765
1815
1866
1917
1968
50100150200250300
3504004505015516016517027528038539049541005105611061157120712581309
1360
1411
1461
1512
1563
1614
1666
1716
1766
1816
1866
1917
1968
4050100150
20025030035040045050055160165270275380385490695710081059111111621214126513171368142014721524157616281680173017791829188019303S-612
3950100150200250300350399449500550600650700
750
800
850
900
950
999
1048
1098
1147
1196
1244
1292
3S-613
4053103153203253303353403453503554
604
654
704
754
804
853
902
951
1000
3S-615
40511011512012513013514014515025526036547067578098619139651016106811201172122412751327137914301482153415851637168817381788
1838
1889
1939
1990
2040
2091
2142
2192
2243
2294
2344
2395
2446
2496
2547
3S-617
50100150200250300350
399449498547596645693741789837885
932
980
1028
1075
1123
1170
1217
1263
1310
1357
1403
1449
1494
1539
1584
1629
3S-701
50100150200250300350
399449498547596645693741789837885
932
980
1028
1075
1123
1170
1217
1263
1310
1357
1403
1449
1494
1539
1584
1629
3952102152202252302352402452501550599
648
696
744
792
840
887
934
981
1028
1074
1120
1166
1212
1257
1302
3S-704
4797147197247297347397447496546595643692741789
837
885
933
3S-602 wp04
4797147197247297347397447497546596645694
743
791
840
888
936
984
1032
1080
3S-605 wp04
395010015020025030035040045049954959864869774779684589494499310421091114011891238128713361385
1433
1482
1531
1579
1628
1677 3S-606 wp06.1
4797147197247297347397447498548598649700
750
801
852
902
953
1003
1053
1104
1154
1203
1253
1303
1352
3S-714 wp03
4797147197247297347397447498549599650700
750
799
847
894
941
986
1030
1072
1113
1153
3S-718 wp04
998
1044
1089
1133
1175
1217
3S-722 wp04
4797147197247297347397447498548599650700751802
854
905
956
1007
1058
1109
1160
1211
1262
1313
1364
1415
3651
3678
3703
3726
3747
3765
3781
3S-723 wp02
21584
21631
21677
21725
21772
21820
21868
21916
21964
22013
22062
22111
22160
3T-607 wp04 v5
SURVEY PROGRAM
Date: 2021-02-19T00:00:00 Validated: Yes Version:
From To Tool
39.00 1400.00 SDI_URSA1_I4
1400.00 2690.00 MWD+IFR2+SAG+MS
2690.00 9220.00 MWD+IFR2+SAG+MS
9220.00 22192.11 MWD+IFR2+SAG+MS
CASING DETAILS
TVD MD Name2555.00 2690.20 10-3/4" Surface Casing
5145.12 9223.00 7-5/8" Intermediate Casing5122.00 22192.11 4-1/2" Production Liner
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00
2 450.00 0.00 0.00 450.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.00
3 600.00 1.50 305.00 599.98 1.13 -1.61 1.00 305.00 1.75 Start Build 1.50
4 750.00 3.75 305.00 749.82 5.07 -7.24 1.50 0.00 7.85 Start Build 2.00
5 1688.85 22.53 305.00 1660.00 126.92 -181.26 2.00 0.00 196.77 Start 108.26 hold at 1688.85 MD
6 1797.11 22.53 305.00 1760.00 150.71 -215.24 0.00 0.00 233.66 Start Build 1.00
7 2706.63 31.62 305.00 2569.00 387.91 -553.99 1.00 0.00 601.38 Start 20.00 hold at 2706.63 MD
8 2726.63 31.62 305.00 2586.03 393.92 -562.58 0.00 0.00 610.71 Start DLS 3.00 TFO 2.13
9 4004.51 69.94 306.41 3379.02 963.73 -1349.63 3.00 2.13 1481.65 Start 4745.59 hold at 4004.51 MD
10 8750.10 69.94 306.41 5006.40 3609.58 -4937.34 0.00 0.00 5494.63 Start DLS 3.00 TFO 66.52
11 10101.04 89.00 343.00 5260.51 4676.92 -5676.55 3.00 66.52 6783.47 Start 200.00 hold at 10101.04 MD
1210301.04 89.00 343.00 5264.00 4868.15 -5735.01 0.00 0.00 6979.91 3S-610 T01 121123 Start 20.00 hold at 10301.04 MD
1310321.04 89.00 343.00 5264.35 4887.28 -5740.86 0.00 0.00 6999.56 Start DLS 1.50 TFO 68.81
1410538.52 90.18 346.04 5265.91 5096.83 -5798.89 1.50 68.81 7212.01 Start 1609.48 hold at 10538.52 MD
1512148.00 90.18 346.04 5260.85 6658.78 -6187.13 0.00 0.00 8774.90 Start DLS 1.00 TFO -6.36
1612230.50 91.00 345.95 5260.00 6738.83 -6207.09 1.00 -6.36 8855.03 3S-610 T02 121123 Start DLS 1.00 TFO -9.83
1712299.91 91.68 345.83 5258.37 6806.12 -6224.01 1.00 -9.83 8922.44 Start 2414.64 hold at 12299.91 MD
1814714.54 91.68 345.83 5187.42 9146.29 -6814.80 0.00 0.0011268.27 Start DLS 1.00 TFO 175.25
1914773.13 91.10 345.88 5186.00 9203.08 -6829.11 1.00 175.2511325.19 3S-610 T03 121123 Start DLS 1.00 TFO 178.93
2014833.96 90.49 345.89 5185.16 9262.07 -6843.94 1.00 178.9311384.29 Start 7358.15 hold at 14833.96 MD
2122192.11 90.49 345.89 5122.00 16398.00 -8637.50 0.00 0.0018533.77 3S-610 T04 121123 TD at 22192.11
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3S-610wp09.1 Surface Location
3S-610wp09.1 Surface Location
# Schlumberger-Confidential
3S-610wp09.1 Surface Casing
3S-610wp09.1 Surface Casing
# Schlumberger-Confidential
3S-610wp09.1 Intermediate Csg
3S-610wp09.1 Intermediate Csg
# Schlumberger-Confidential
3S-610wp09.1 Top Torok
3S-610wp09.1 Top Torok
# Schlumberger-Confidential
3S-610wp09.1 TD
3S-610wp09.1 TD
# Schlumberger-Confidential
Certificate Of Completion
Envelope Id: 094C807DBBFB4C35AE1FA9585A571D31 Status: Completed
Subject: Complete with DocuSign: 3S-610 Permit Combined.pdf
Source Envelope:
Document Pages: 66 Signatures: 2 Envelope Originator:
Certificate Pages: 5 Initials: 0 Matt Smith
AutoNav: Enabled
EnvelopeId Stamping: Disabled
Time Zone: (UTC-06:00) Central Time (US & Canada)
600 N Dairy Ashford Rd
Houston, TX 77079-1100
Matt.Smith2@conocophillips.com
IP Address: 138.32.8.5
Record Tracking
Status: Original
12/15/2023 3:49:36 PM
Holder: Matt Smith
Matt.Smith2@conocophillips.com
Location: DocuSign
Signer Events Signature Timestamp
Chris Brillon
chris.l.brillon@cop.com
Security Level: Email, Account Authentication
(None)
Signature Adoption: Pre-selected Style
Using IP Address: 24.237.110.236
Signed using mobile
Sent: 12/15/2023 3:52:51 PM
Viewed: 12/18/2023 10:01:11 AM
Signed: 12/18/2023 10:01:25 AM
Electronic Record and Signature Disclosure:
Accepted: 12/18/2023 10:01:11 AM
ID: e578b5c4-2919-4e12-89aa-27553923e83f
Matt Smith
matt.smith2@conocophillips.com
ConocoPhillips
Security Level: Email, Account Authentication
(None)Signature Adoption: Drawn on Device
Using IP Address: 138.32.8.5
Sent: 12/15/2023 3:52:50 PM
Viewed: 12/15/2023 3:53:13 PM
Signed: 12/15/2023 3:53:18 PM
Electronic Record and Signature Disclosure:
Accepted: 7/19/2021 1:20:17 PM
ID: f6bd13a1-d6f1-46e0-9474-5f45090fce43
In Person Signer Events Signature Timestamp
Editor Delivery Events Status Timestamp
Agent Delivery Events Status Timestamp
Intermediary Delivery Events Status Timestamp
Certified Delivery Events Status Timestamp
Carbon Copy Events Status Timestamp
Witness Events Signature Timestamp
Notary Events Signature Timestamp
Envelope Summary Events Status Timestamps
Envelope Sent Hashed/Encrypted 12/15/2023 3:52:51 PM
Certified Delivered Security Checked 12/15/2023 3:53:13 PM
Envelope Summary Events Status Timestamps
Signing Complete Security Checked 12/15/2023 3:53:18 PM
Completed Security Checked 12/18/2023 10:01:25 AM
Payment Events Status Timestamps
Electronic Record and Signature Disclosure
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ConocoPhillips.
1
Dewhurst, Andrew D (OGC)
From:Smith, Matt <Matt.Smith2@conocophillips.com>
Sent:Wednesday, January 3, 2024 07:28
To:Dewhurst, Andrew D (OGC)
Cc:Davies, Stephen F (OGC); Guhl, Meredith D (OGC); Loepp, Victoria T (OGC); Roby, David S (OGC)
Subject:RE: [EXTERNAL]KRU 3S-610 (PTD 223-126) - Questions
Yes sir, the diīerence is the plat shows FNL/FEL, and I showed as FSL/FWL. The point is correct, just displayed in
diīerent format.
Matt Smith
Drilling Engineer – Kuparuk
700 G ST ANCHORAGE ALASKA, ATO-1566
OFFICE: +1.907.263.4324
CELL: +1.432.269.6432
MATT.SMITH2@COP.COM
You don't often get email from matt.smith2@conocophillips.com. Learn why this is important
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open
attachments unless you recognize the sender and know the content is safe.
2
From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Sent: Tuesday, January 2, 2024 6:15 PM
To: Smith, Matt <Matt.Smith2@conocophillips.com>
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Loepp,
Victoria T (OGC) <victoria.loepp@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>
Subject: [EXTERNAL]KRU 3S-610 (PTD 223-126) - Questions
CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you
recognize the sender and know the content is safe.
MaƩ,
I’m compleƟng the review of the KRU 3S-610 PTD and have one quesƟon:
Would you please take a look at the SecƟon Oīset values? The “as built” survey appears to have diīerent secƟon oīset
values than the 10-401 form. That being said, the proposed well plots correctly against the other wells using both the
State Plane XY and the secƟon oīset values provided on the 10-401 page.
Thanks,
Andy
Andrew Dewhurst
Senior Petroleum Geologist
Alaska Oil and Gas ConservaƟon Commission
333 W. 7th Ave, Anchorage, AK 99501
andrew.dewhurst@alaska.gov
Direct: (907) 793-1254
Revised 7/2022
TRANSMITTAL LETTER CHECKLIST
WELL NAME: ______________________________________
PTD: _____________________________________________
___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional
FIELD: __________________________ POOL: ____________________________________
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK OPTIONS TEXT FOR APPROVAL LETTER
MULTI
LATERAL
(If last two digits
in API number are
between 60-69)
The permit is for a new wellbore segment of existing well Permit
Number _____________, API Number 50-______________________.
Production from or injection into this wellbore must be reported under
the original API Number stated above.
Spacing
Exception
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce or inject is contingent upon issuance of a
conservation order approving a spacing exception. The Operator
assumes the liability of any protest to the spacing exception that may
occur.
Dry Ditch Sample
All dry ditch sample sets submitted to the AOGCC must be in no greater
than 30-foot sample intervals from below the permafrost or from where
samples are first caught and 10-foot sample intervals through target
zones.
Non-
Conventional
Well
Please note the following special condition of this permit: Production or
production testing of coal bed methane is not allowed for this well until
after the Operator has designed and implemented a water-well testing
program to provide baseline data on water quality and quantity. The
Operator must contact the AOGCC to obtain advance approval of such
a water-well testing program.
Well Logging
Requirements
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types
of well logs to be run. In addition to the well logging program proposed
by the Operator in the attached application, the following well logs are
also required for this well:
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
composite curves for all well logs run must be submitted to the AOGCC
within 90 days after completion, suspension, or abandonment of this
well, or within 90 days of acquisition of the data, whichever occurs first.
X
KUPARUK RIVER
KRU 3S-610
223-126
TOROK OIL POOL
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25
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2
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A
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2
5
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3
5
(
h
)
(
2
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27
If
d
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d
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;
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/
9
.
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0
p
p
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28
Dr
i
l
l
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n
g
f
l
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p
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h
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m
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c
&
e
q
u
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p
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d
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q
u
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Ye
s
29
BO
P
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s
,
d
o
t
h
e
y
m
e
e
t
r
e
g
u
l
a
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s
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S
P
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s
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7
7
8
p
s
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;
w
i
l
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t
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5
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p
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d
4
0
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p
s
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s
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b
s
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q
u
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t
l
y
30
BO
P
E
p
r
e
s
s
r
a
t
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n
g
a
p
p
r
o
p
r
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a
t
e
;
t
e
s
t
t
o
(
p
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t
p
s
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g
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n
c
o
m
m
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n
t
s
)
Ye
s
31
Ch
o
k
e
m
a
n
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f
o
l
d
c
o
m
p
l
i
e
s
w
/
A
P
I
R
P
-
5
3
(
M
a
y
8
4
)
Ye
s
32
Wo
r
k
w
i
l
l
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c
c
u
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w
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t
h
o
u
t
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p
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o
n
s
h
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t
d
o
w
n
Ye
s
33
Is
p
r
e
s
e
n
c
e
o
f
H
2
S
g
a
s
p
r
o
b
a
b
l
e
NA
34
Me
c
h
a
n
i
c
a
l
c
o
n
d
i
t
i
o
n
o
f
w
e
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l
s
w
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t
h
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n
A
O
R
v
e
r
i
f
i
e
d
(
F
o
r
s
e
r
v
i
c
e
w
e
l
l
o
n
l
y
)
No
H2
S
m
e
a
s
u
r
e
s
r
e
q
u
i
r
e
d
.
L
i
f
t
g
a
s
f
r
o
m
C
P
F
3
f
a
c
i
l
i
t
y
h
a
s
~
2
0
0
-
2
5
0
p
p
m
H
2
S
.
35
Pe
r
m
i
t
c
a
n
b
e
i
s
s
u
e
d
w
/
o
h
y
d
r
o
g
e
n
s
u
l
f
i
d
e
m
e
a
s
u
r
e
s
Ye
s
Re
s
e
r
v
o
i
r
p
o
r
e
p
r
e
s
s
u
r
e
a
n
t
i
c
i
p
a
t
e
d
t
o
b
e
8
.
6
p
p
g
E
M
W
.
M
a
y
v
a
r
y
d
u
e
t
o
o
f
f
s
e
t
p
r
o
d
u
c
t
i
o
n
a
n
d
i
n
j
e
c
t
i
o
n
.
36
Da
t
a
p
r
e
s
e
n
t
e
d
o
n
p
o
t
e
n
t
i
a
l
o
v
e
r
p
r
e
s
s
u
r
e
z
o
n
e
s
NA
37
Se
i
s
m
i
c
a
n
a
l
y
s
i
s
o
f
s
h
a
l
l
o
w
g
a
s
z
o
n
e
s
NA
38
Se
a
b
e
d
c
o
n
d
i
t
i
o
n
s
u
r
v
e
y
(
i
f
o
f
f
-
s
h
o
r
e
)
NA
39
Co
n
t
a
c
t
n
a
m
e
/
p
h
o
n
e
f
o
r
w
e
e
k
l
y
p
r
o
g
r
e
s
s
r
e
p
o
r
t
s
[
e
x
p
l
o
r
a
t
o
r
y
o
n
l
y
]
Ap
p
r
AD
D
Da
t
e
1/
2
/
2
0
2
4
Ap
p
r
VT
L
Da
t
e
1/
1
6
/
2
0
2
4
Ap
p
r
AD
D
Da
t
e
1/
2
/
2
0
2
4
Ad
m
i
n
i
s
t
r
a
t
i
o
n
En
g
i
n
e
e
r
i
n
g
Ge
o
l
o
g
y
Ge
o
l
o
g
i
c
Co
m
m
i
s
s
i
o
n
e
r
:
Da
t
e
:
En
g
i
n
e
e
r
i
n
g
Co
m
m
i
s
s
i
o
n
e
r
:
Da
t
e
Pu
b
l
i
c
Co
m
m
i
s
s
i
o
n
e
r
Da
t
e
JL
C
1
/
1
6
/
2
0
2
4
