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HomeMy WebLinkAbout222-134 T R A N S M I T T A LL
FROM:Kelsey Anderson TO: Meredith Guhl
ConocoPhillips Alaska, Inc. AOGCC
700 G Street 333 W.7
th Ave., Suite 100
Anchorage AK 99501 Anchorage, Alaska
RE:: 3S-701A
Permit: 222-134
DATE: 03/31/2025
Transmitted:
North Slope
3S-701A
Via SFTP
____ Isotech Gas Data
Size 111 KB, 1 file
Transmittall instructions: please promptly sign, scan, and e-mail to AKGGREDTSupport@ConocoPhillips.onmicrosoft.COM
CC: 3S-701A - e-transmittal well folder
Receipt: Date:
Alaska/IT-Data Services |ConocoPhillips Alaska |
222-134
T40255
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2025.04.02 09:04:29 -08'00'
From:Heusser, Heather A (DNR)
To:Guhl, Meredith D (OGC)
Cc:Morgan, Kirk A (DNR)
Subject:RE: KRU 3S-701 and 3S-701A, Extended confidentiality? Due for release Mar 5
Date:Thursday, March 13, 2025 11:36:08 AM
Good morning, Meredith,
We have not received a request for extended confidentiality for KRU 3S-701 or KRU 3S-701A.
Thank you,
Heather Ann Heusser
Natural Resource Specialist IV
State of Alaska
Department of Natural Resources
Division of Oil and Gas
550 West 7th Avenue, Suite 1100
Anchorage AK 99501-3560
heather.heusser@alaska.gov
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information
from the Department of Natural Resources (DNR), 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 DNR is aware of the mistake in sending it to you, contact Heather Ann Heusser. E-
mail:heather.heusser@alaska.gov Phone: (907) 269-0137
From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Sent: Monday, March 3, 2025 8:27 AM
To: Heusser, Heather A (DNR) <heather.heusser@alaska.gov>
Cc: Morgan, Kirk A (DNR) <kirk.morgan@alaska.gov>
Subject: KRU 3S-701 and 3S-701A, Extended confidentiality? Due for release Mar 5
Good Morning Heather,
Has ConocoPhillips Alaska requested extended confidentiality for KRU 3S-701 (API:
5010320847000, PTD 222-133) and KRU 3S-701A (API: 50103208470100, PTD 222-134) due for
release after March 5, 2025?
Thank you,
Meredith
Meredith Guhl (she/her)
Petroleum Geology Assistant
Alaska Oil and Gas Conservation Commission
333 W. 7th Ave, Anchorage, AK 99501
meredith.guhl@alaska.gov
Direct: (907) 793-1235
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 Meredith Guhl
at 907-793-1235 or meredith.guhl@alaska.gov.
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TT RR AA NN SS MM II TT TT AA LL
CONFIDENTIALL DATA
FROM:Kelsey Anderson TO: Meredith Guhl
ConocoPhillips Alaska, Inc. AOGCC
P.O. Box 100360 333 W.7
th Ave., Suite 100
Anchorage AK 99510-0360 Anchorage, Alaska
RE: KRU 3S-701 & KRU 3S-701A
Permit: 222-133 & 222-134
DATE: 02/27/2025
Transmitted:
North Slope Exploratory
KRU 3S-701 & KRU 3S-701A Via SFTP
____ 3S-701 Core Description
____ 3S-701 Mudlog LAS with lithology %
____ 3S-701A Mudlog LAS with lithology %
____ 3S-701A VISION Service RM Composite DLIS
Transmittall instructions: please promptly sign, scan, and e-mail to Kelsey.Anderson@conocophillips.com
Receipt: Date:
T37656
T37628
T37655
T40158
222-134
____ 3S-701A Mudlog LAS with lithology %
____ 3S-701A VISION Service RM Composite DLIS
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2025.02.28 08:45:19 -09'00'
222-134
T39270
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.07.24 09:55:29 -08'00'
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Tuesday, October 17, 2023
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Bob Noble
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
3S-701A
KUPARUK RIV UNIT 3S-701A
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 10/17/2023
3S-701A
50-103-20847-01-00
222-134-0
W
SPT
4021
2221340 1500
300 300 310 310
335 430 414 411
INITAL P
Bob Noble
9/16/2023
Initial MIT-IA for producer to injector conversion, Sundry 323-271
30 MinPretestInitial15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:KUPARUK RIV UNIT 3S-701A
Inspection Date:
Tubing
OA
Packer Depth
785 1810 1720 1705IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitRCN230916155340
BBL Pumped:0.9 BBL Returned:0.9
Tuesday, October 17, 2023 Page 1 of 1
9
9
9
9
9
9
9 9
9 99
9
9
9
producer to injector conversion,
James B. Regg Digitally signed by James B. Regg
Date: 2023.10.17 15:17:01 -08'00'
Operations shutdownPull TubingFracture StimulatePlug PerforationsSusp Well Insp1. Operations
Change Approved ProgramAlter CasingOther StimulatePerforateInstall WhipstockPerformed:
Other: Convert PROD to INJCoiled Tubing OpsRepair WellPerforate New PoolMod Artificial Lift
ExploratoryDevelopment
ServiceStratigraphic
8. Well Name and Number:7. Property Designation (Lease Number):
10. Field/Pool(s):9. Logs (List logs and submit electronic data per 20AAC25.071):
11. Present Well Condition Summary:
measuredTotal Depth 17340'feet None feet
true vertical 4267'feet None feet
measuredEffective Depth 17340'feet 8078', 8254'feet
true vertical 4267'feet 4022', 4057'feet
Measured depthPerforation depth
True Vertical depth
4058' TVD8261' MDL-804-1/2"Tubing (size, grade, measured and true vertical depth)
8078' MDPackers and SSSV (type, measured and true vertical depth)
8254' MD
N/A
4022' TVD
4057' TVD
N/A
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
N/ATreatment descriptions including volumes used and final pressure:
13a.
Prior to well operation:
Subsequent to operation:
13b. Pools active after work:
15. Well Class after work:
StratigraphicServiceExploratory DevelopmentDaily Report of Well Operations
WDSPLGasOil16. Well Status after work:Copies of Logs and Surveys Run
SPLUGSUSPGINJGSTORElectronic Fracture Stimulation Data
Sundry Number or N/A if C.O. Exempt:
Authorized Name and
Contact Name:Digital Signature with Date:
Contact Email:
Contact Phone:Authorized Title:
2573'2910'
CollapseBurst
Production
Liner
8404'
9078'
Casing
4094'
4-1/2"
8438'
4267'17332'
2873'
115'Conductor
Surface
Intermediate
20"
10-3/4"
78'
measured
TVD
7-5/8"
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
222-134
P.O. Box 100360
Anchorage, AK 99510
3. Address:
ConocoPhillips Alaska, Inc.
N/A
5. Permit to Drill Number:2. Operator Name
N
4. Well Class Before Work:
ADL380107, ADL025544, ADL025551
Kuparuk River Oil Field/ Coyote Undefined Oil Pool
KRU 3S-701A
Plugs
measuredJunk
Length
measured
true vertical
Packer
Representative Daily Average Production or Injection Data
Tubing PressureCasing Pressure
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
INJECTOR
Gas-Mcf
MD
1339
Size
115'
~~~
2764983198
~
323-271
Sr Res Eng:Sr Pet Geo:Sr Pet Eng:
WINJ WAG
8354
Water-BblOil-Bbl
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
N/A
Packer: TNT Prod Packer
Packer: Baker Liner Top Packer
SSSV: None
Lynn Aleshire
lynn.aleshire@conocophillips.com
(907) 265-6525Surveillance Reservoir Engineer
None
None
Submit in PDF format to aogcc.permitting@alaska.govDue Within 30 days of OperationsForm 10-404 Revised 10/2022
6. API Number:
50-103-20847-01-00
By Grace Christianson at 4:04 pm, Oct 03, 2023
Lynn Aleshire Digitally signed by Lynn Aleshire
Date: 2023.10.03 10:17:35 -08'00'
RBDMS JSB 100523
VTL 2/11/2025 DSR-10/5/23
SFD
SFD 2/11/2025
DTTMSTART JOBTYP SUMMARYOPS
8/28/2023 CHANGE
WELL TYPE
DRIFT TBG ENCOUNTER LIGHT PARAFFIN FROM 3500'-3700' SLM, FAILED
ATTEMPT TO SET PXX PLUG DUE TO SPANGS LOCKING UP WHILE DOWN HOLE,
SET PXX PLUG @ 3879' RKB (METAL SHAVINGS IN X-LINE RUNNING TOOL), PULL
OV @ 3829' RKB, IN PROGRESS
9/1/2023 CHANGE
WELL TYPE
SPOT EQUIPMENT AND R/U LRS FOR CIRC-OUT
9/1/2023 CHANGE
WELL TYPE
CIRC OUT
PUMPED 120 BBLS SW (SHORTED 29 BBLS OF REQUESTED 149)
FOLLOWED BY 113 BBLS DSL TAKING RETURNS OFF IA TO WELL 3S-03
PUMPED 10 BBLS DSL DWN 3S-03 FL FOR FREEZE PROTECT
U-TUBED FOR FREEZE PROTECT
9/2/2023 CHANGE
WELL TYPE
SET DMY IN STA #2 @3829' RKB. REPLACE GLV W/ DMY IN STA #1 @ 2641' RKB.
CONDUCT PASSING MIT-IA. PULL PXX PLUG @ 3897' RKB. COMPLETED
3S-701A Convert to Injector
Summary of Operations
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: DMY off string. 3S-701A 9/2/2023 fergusp
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 19.12 37.0 115.0 115.0 62.58 B
Surface 10 3/4 9.95 37.3 2,910.0 2,573.3 45.50 L80 H563
Intermediate 7 5/8 6.88 34.0 8,438.0 4,093.8 29.70 L-80 Hyd 563
Liner 4 1/2 3.95 8,254.1 17,332.0 4,266.9 12.60 P-110 HYD 563
Tubing Strings: string max indicates LONGEST segment of string
Top (ftKB)
33.9
Set Depth …
8,260.7
Set Depth …
4,058.1
String Ma…
4 1/2
Tubing Description
Tubing – Completion Upper
Wt (lb/ft)
12.60
Grade
L80
Top Connection
H563
ID (in)
3.96
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
33.9 33.9 0.00 Hanger 11.000 Cameron 4-1/2" Tubing Hanger, Hyd
563
Camero
n
2200453
6-28-01
3.958
2,641.5 2,399.5 47.21 Mandrel – GAS
LIFT
4.500 4-1/2" Camco KBG-4-5 GLM Camco KBG-4-5 3.957
3,829.1 2,994.9 73.23 Mandrel – GAS
LIFT
4.500 4-1/2" Camco KBG-4-5 GLM Camco KBG-4-
5
3.957
3,897.0 3,014.1 73.85 Nipple - X 4.500 Landing Nipple, X, 3.813" Packing
Bore
Halliburt
on
3.813
8,014.0 4,008.1 77.66 Sensor -
Discharge
Gauge
4.500 Gauge Mandrel, HES OPSIS Single
Ended
Otis 3.878
8,078.5 4,021.6 78.19 Packer 4.500 TNT Production Packer, HES,
7.625"X4.5", VAMTOP B X P
Halliburt
on
TNT 3.856
8,145.1 4,034.9 78.59 Nipple - DB 4.500 Landing Nipple, DB, 4.5" X 3.75" Camco 3.75" DB 3.750
8,198.4 4,045.6 78.47 Sub - Shear
Out - SOS
4.500 Arsenal Glass Disc Sub, 5500 psi
Shear
Arsenal 11937-
01-02
3.890
8,251.5 4,056.2 78.32 Locator 5.300 Baker Shear Type Locator sub -
above locating shoulder
3.860
8,252.2 4,056.4 78.32 Locator 5.640 Baker Shear Type Locator - to
locating shoulder (Shear pins 1'
below shoulder)
3.860
8,257.4 4,057.4 78.30 Wireline Guide 5.200 Halliburton Ratcheting Muleshoe 3.880
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)
2,641.5 2,399.5 47.21 1 GAS LIFT DMY BK 1 0.0 9/2/2023 KBG 4-5 0.000
3,829.1 2,994.9 73.23 2 GAS LIFT DMY BK 1 0.0 9/2/2023 KBG 4-5 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)
8,254.1 4,056.8 78.31 Packer 5.500 5.5" X 7-5/8" Liner Top Packer w/
11' x 5.76" ID TieBK Sleeve
Baker ZAN173 5.760
8,276.5 4,061.3 78.24 Nipple - RS 6.050 5.5" X 7-5/8" SLZXP (HRD-E)
Liner Top Hanger
Baker 13760865 4.260
8,278.8 4,061.8 78.23 XO Reducing 5.500 5.5" Hyd 563 box X pin 4.5" Hyd
563 cross over
3.890
9,208.4 4,203.8 84.82 Packer - Swell 4.500 PACKER,SWELL, 5.80", BAKER,
HYD563 Assem. 16
Baker 3.910
9,312.5 4,211.4 87.24 Sleeve - Frac 5.000 Advanced Upstream Frac Sleeve
(Trigger)
Advance
d
Upstrea
m
107394-
000031
3.500
9,480.1 4,212.7 90.64 Sleeve - Frac 5.000 Advanced Upstream Frac Sleeve
#15
Advance
d
Upstrea
m
107394-
000040
3.500
9,733.5 4,210.6 90.40 Packer - Swell 4.500 PACKER,SWELL, 5.80", BAKER,
HYD563 Assem. 15
Baker 3.900
10,003.9 4,209.4 90.23 Sleeve - Frac 5.000 Advanced Upstream Frac Sleeve
#14
Advance
d
Upstrea
m
107394-
000028
3.500
10,262.3 4,208.3 90.36 Packer - Swell 4.500 PACKER,SWELL, 5.80", BAKER,
HYD563 Assem. 14
Baker 3.850
10,532.2 4,205.0 90.74 Sleeve - Frac 5.000 Advanced Upstream Frac Sleeve
#13
Advance
d
Upstrea
m
107394-
000042
3.500
10,790.3 4,201.0 90.83 Packer - Swell 4.500 PACKER,SWELL, 5.80", BAKER,
HYD563 Assem. 13
Baker 3.870
11,059.9 4,197.2 90.76 Sleeve - Frac 5.000 Advanced Upstream Frac Sleeve
#12
Advance
d
Upstrea
m
107394-
000041
3.500
11,317.2 4,193.5 90.64 Packer - Swell 4.500 PACKER,SWELL, 5.80", BAKER,
HYD563 Assem. 12
Baker 3.880
11,587.6 4,191.7 90.14 Sleeve - Frac 5.000 Advanced Upstream Frac Sleeve
#11
Advance
d
Upstrea
m
107394-
000037
3.500
11,804.5 4,191.3 90.40 Packer - Swell 4.500 PACKER,SWELL, 5.80", BAKER,
HYD563 Assem. 11
Baker 3.870
HORIZONTAL, 3S-701A, 9/20/2023 4:31:45 PM
Vertical schematic (actual)
Liner; 8,254.1-17,332.0
Intermediate; 34.0-8,438.0
Tubing - Pup Joint; 8,147.1
Nipple - DB; 8,145.1
Packer; 8,078.5
Intermediate String 1 Cement;
7,262.0 ftKB
Nipple - X; 3,897.0
Mandrel – GAS LIFT; 3,829.1
Surface; 37.3-2,910.0
Mandrel – GAS LIFT; 2,641.5
Stage Cementing; 37.4 ftKB
Conductor; 37.0-115.0
Hanger; 33.9
KUP INJ
KB-Grd (ft)
45.20
RR Date
2/5/2023
Other Elev…
3S-701A
...
TD
Act Btm (ftKB)
17,340.0
Well Attributes
Field Name Wellbore API/UWI
501032084701
Wellbore Status
INJ
Max Angle & MD
Incl (°)
91.02
MD (ftKB)
11,222.24
WELLNAME WELLBORE3S-701
Annotation End DateH2S (ppm) DateComment
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)
12,070.8 4,189.9 90.20 Sleeve - Frac 5.000 Advanced Upstream Frac Sleeve
#10
Advance
d
Upstrea
m
107394-
000030
3.500
12,287.5 4,188.6 90.40 Packer - Swell 4.500 PACKER,SWELL, 5.80", BAKER,
HYD563 Assem. 10
Baker 3.870
12,557.4 4,187.8 89.96 Sleeve - Frac 5.000 Advanced Upstream Frac Sleeve
#9
Advance
d
Upstrea
m
107394-
000039
3.500
12,774.2 4,188.9 89.36 Packer - Swell 4.500 PACKER,SWELL, 5.80", BAKER,
HYD563 Assem. 9
Baker 3.910
13,044.0 4,192.2 89.23 Sleeve - Frac 5.000 Advanced Upstream Frac Sleeve
#8
Advance
d
Upstrea
m
107394-
000036
3.500
13,261.0 4,195.2 89.29 Packer - Swell 4.500 PACKER,SWELL, 5.80", BAKER,
HYD563 Assem. 8
Baker 3.820
13,531.3 4,198.4 89.22 Sleeve - Frac 5.000 Advanced Upstream Frac Sleeve
#7
Advance
d
Upstrea
m
107394-
000032
3.500
13,748.2 4,201.5 89.10 Packer - Swell 4.500 PACKER,SWELL, 5.80", BAKER,
HYD563 Assem. 7
Baker 3.960
14,015.5 4,206.1 88.93 Sleeve - Frac 5.000 Advanced Upstream Frac Sleeve
#6
Advance
d
Upstrea
m
107394-
000035
3.500
14,230.5 4,210.7 88.59 Packer - Swell 4.500 PACKER,SWELL, 5.80", BAKER,
HYD563 Assem. 6
Baker 3.900
14,500.2 4,216.6 88.63 Sleeve - Frac 5.000 Advanced Upstream Frac Sleeve
#5
Advance
d
Upstrea
m
107394-
000029
3.500
14,717.0 4,221.1 88.82 Packer - Swell 4.500 PACKER,SWELL, 5.80", BAKER,
HYD563 Assem. 5
Baker 3.870
14,986.9 4,226.3 89.24 Sleeve - Frac 5.000 Advanced Upstream Frac Sleeve
#4
Advance
d
Upstrea
m
107394-
000038
3.500
15,243.2 4,230.2 89.11 Packer - Swell 4.500 PACKER,SWELL, 5.80", BAKER,
HYD563 Assem. 4
Baker 3.920
15,513.2 4,234.5 89.37 Sleeve - Frac 5.000 Advanced Upstream Frac Sleeve
#3
Advance
d
Upstrea
m
107394-
000044
3.500
15,771.7 4,237.5 89.22 Packer - Swell 4.500 PACKER,SWELL, 5.80", BAKER,
HYD563 Assem. 3
Baker 3.910
16,041.9 4,240.4 89.45 Sleeve - Frac 5.000 Advanced Upstream Frac Sleeve
#2
Advance
d
Upstrea
m
107394-
000033
3.500
16,298.5 4,244.0 88.67 Packer - Swell 4.500 PACKER,SWELL, 5.80", BAKER,
HYD563 Assem. 2
Baker 3.900
16,568.5 4,249.8 88.63 Sleeve - Frac 5.000 Advanced Upstream Frac Sleeve
#1
Advance
d
Upstrea
m
107394-
000034
3.500
16,825.2 4,255.9 88.57 Packer - Swell 4.500 PACKER,SWELL, 5.80", BAKER,
HYD563 Assem. 1
Baker 3.900
HORIZONTAL, 3S-701A, 9/20/2023 4:31:45 PM
Vertical schematic (actual)
Liner; 8,254.1-17,332.0
Intermediate; 34.0-8,438.0
Tubing - Pup Joint; 8,147.1
Nipple - DB; 8,145.1
Packer; 8,078.5
Intermediate String 1 Cement;
7,262.0 ftKB
Nipple - X; 3,897.0
Mandrel – GAS LIFT; 3,829.1
Surface; 37.3-2,910.0
Mandrel – GAS LIFT; 2,641.5
Stage Cementing; 37.4 ftKB
Conductor; 37.0-115.0
Hanger; 33.9
KUP INJ 3S-701A
...
WELLNAME WELLBORE3S-701
TT RR AA NN SS MM II TT TT AA LL
CONFIDENTIAL DATA
FROM: Sandra D. Lemke TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC
P.O. Box 100360 333 W. 7th Ave., Suite 100
Anchorage AK 99510-0360 Anchorage, Alaska 99501
RE: 3S-701A
Permit: 222-133
DATE: 05/18/2023
Transmitted:
Kuparuk River Unit, North Slope, Alaska
3S-701A
Via SFTP
_Geolog Mudlog 23.8 MB 10 files
Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com
CC: 3S-701A- e-transmittal well folder
Receipt: Date:
Alaska/IT-Data Services/ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512
PTD: 222-134
T37656
Kayla Junke
Digitally signed by
Kayla Junke
Date: 2023.05.18
15:35:44 -08'00'
TT RR AA NN SS MM II TT TT AA LL
CONFIDENTIAL DATA
FROM: Sandra D. Lemke TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC
P.O. Box 100360 333 W. 7th Ave., Suite 100
Anchorage AK 99510-0360 Anchorage, Alaska 99501
RE: 3S-701A
Permit: 222-134
DATE: 05/04/2023
Transmitted:
Kuparuk River Unit, North Slope, Alaska
3S-701A
Via SFTP
16.2 GB
- 6.5in PROD
Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com
CC: 3S-701A- e-transmittal well folder
Receipt: Date:
Alaska/IT-Data Services|ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512
PTD: 222-134
T37628
Kayla
Junke
Digitally signed by
Kayla Junke
Date: 2023.05.04
16:17:41 -08'00'
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 INJ
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?
Will planned perforations require a spacing exception? Yes No
9. Property Designation (Lease Number): 10. Field: Current Pools:
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD):
17340'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:
Post Initial Injection MIT Req'd? Yes No
Spacing Exception Required? Yes No Subsequent Form Required:
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
AOGCC USE ONLY
Lynn Aleshire
lynn.aleshire@conocophillips.com
(907) 265-6525
Surveillance Reservoir Engineer
Tubing Grade: Tubing MD (ft):
8078' MD and 4022' TVD
8254' MD and 4057' TVD
N/A
Perforation Depth TVD (ft): Tubing Size:
L-80 8261'
5/15/2023
Packer: TNT Prod Packer
Packer: Baker Liner Top Packer
SSSV: None
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL380107, ADL025544, ADL025551
222-134
P.O. Box 100360, Anchorage, AK 99510 50-103-20847-01-00
ConocoPhillips Alaska, Inc.
KRU 3S-701A
Exploratory Pool Exploratory Pool Kuparuk River Field
N/A
Length Size
Proposed Pools:
TVD Burst
PRESENT WELL CONDITION SUMMARY
4267' 17340' 4267' None
MD
115'
2573'
4094'
115'
2910'
8438'
20"
10-3/4"
78'
2873'
Perforation Depth MD (ft):
7-5/8"8404'
None
4-1/2"
None
17332'9078'
4-1/2"
4267'
Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
323-271
By Kayla Junke at 3:00 pm, May 05, 2023
Lynn Aleshire Digitally signed by Lynn Aleshire
Date: 2023.05.05 13:35:09 -08'00'
WAG
Coyote Undefined Oil
SFD 5/8/2023
X
DSR-5/9/23
X
VTL 6/22/2023
SFD
10-404
GCW 06/22/2023
06/23/23
Jessie L.
Chmielowski
Digitally signed by Jessie L.
Chmielowski
Date: 2023.06.23 09:00:54
-08'00'
RBDMS JSB 062723
1
Lynn Aleshire
Surveillance Reservoir Engineer
ConocoPhillips Alaska, Inc.
Attachments:
Sundry applications
ConocoPhillips Alaska, Inc.
700 G St.
Anchorage, AK 99501-3448
May 5, 2023
AOGCC Commissioner
State of Alaska, Oil & Gas Conservation Commission
333 W. 7th Ave., Ste. 100
Anchorage, AK 99501
Re: KRU 3S-701A (PTD 222-134) Conversion to Injection
Dear Commissioner,
ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit Well 3S-
701A from Production to Water-Alternating Gas Service. A 10-404 was recently
submitted to inform of our intention to flow back this injector for more than 30 days,
effectively, converting it to a producer. The required flowback will be complete soon
and the well should be placed in water injection service.
Attached you will find the 10-403 Application for Sundry Approval for ConocoPhillips
Alaska, Inc. for conversion of KRU 3S-701A to WAG service.
If you have any questions regarding this matter, please contact me at 907-265-6525 or
by email at lynn.aleshire@cop.com.
Sincerely,
Lynn Aleshire
Digitally signed by Lynn
Aleshire
Date: 2023.05.05 13:35:57
-08'00'
r conversion of KRU 3S-701A to WAG service.
3S-701A
DESCRIPTION SUMMARY OF PROPOSAL
ConocoPhillips Alaska Inc. requests approval to convert Kuparuk River Unit Well 3S-701A from Oil
Production service to Water Alternating Gas Injection service now that the post-drill flowback has been
completed.
Area of Review:
KRU Well 3S-701A was originally completed as a WAG injector in the Coyote reservoir in March 2023. The
flowback period required to clean up the completion exceded the 30 day window for flowback and the well
was converted to production.
The top of the Coyote sand in 3S-701A is at 8382' MD / 4082' TVDSS
Area Map with 1/4 mile radius around target injection zone (see attached)
The attached map shows that two KRU wells are located within the 1/4 mile radius, 3S-24B, the Coyote
appraisal well, and 3S-21 a suspended Kuparuk producer which is in the process of full abandonment below-
grade.
Mechanical Condition of Well to be Converted:
The mechanical condition of 3S-701A is good. The injection tubing / casing annulus is isolated with a
Halliburton TNT Prod Packer set at 8079' MD / 4027' TVD.
A NON-witnessed MITIA will be performed prior to injection. After injection has stablized a State-witnessed
SW MITIA will be performed.
CBL and interpretation of cement quality
All hydrocarbon zones penetrated by the well are isolated. See attached Area of Review Detail for offset
wells.
The 10-3/4" Surface Casing was cemented with 460 bbls of 10.7 ppg lead cement and 57 bbls of 15.7 ppg
tail cement.
The 7-5/8" intermediate string was cemented with 46 bbls of 12.5 ppg lead cement and 23 bbls of 15.1 ppg
tail cement. Sonic log indicates top of cement at 6800' MD / 3723' TVD.
qpp
Water Alternating Gas Injection
ppg
6800' MD / 3723' TVD.
Cement returns to surface.
SFD 5/8/2023
y
3S-21 a suspended Kuparuk producer which is in the process of full abandonment
KRU 3S-701A AREA OF REVIEWPTD API WELL NAME STATUSTop of Coyote Oil Pool (MD)Top of Coyote Oil Pool (TVDSS)Top of Cement (MD)Top of Cement (TVDSS)Top of Cement Determined ByReservoir Status Zonal Isolation Cement Operations Summary Mechanical Integrity203-031 50-103-20452 3S-21 Suspended 5769' 3674' Surface Surface CBL across CoyoteSuspended & WO abandonment completionN/APerf Coyote in 9-5/8" 6332' MD (3980' TVDSS) - 6422' MD (4030' TVDSS). Perf wash then cement with 70 bbls 15.8 ppg cement. Final abondonment cement: 122 bbls down the OA and 250 barrels to surface.9/22/22 State witness tag and MIT-IA & MIT-T after squeeze of Coyote. 221-078 50-103-20456 3S-24B Production 7880' 4037' 7140' 3,546 CBL Perfs open to Prod. Baker Liner Top Packer, HRDE ZXP4-1/2" Liner: 34 bbls of 15.8 ppg cement. Plug bumped; returns at surface10/2/21 State Witnessed Cement Tag, MIT-IA, MIT-T: PASS
Operations shutdownPull TubingFracture StimulatePlug PerforationsSusp Well Insp1. Operations
Change Approved ProgramAlter CasingOther StimulatePerforateInstall WhipstockPerformed:
Other: Flowback >30 daysCoiled Tubing OpsRepair WellPerforate New PoolMod Artificial Lift
ExploratoryDevelopment
ServiceStratigraphic
8. Well Name and Number:7. Property Designation (Lease Number):
10. Field/Pool(s):9. Logs (List logs and submit electronic data per 20AAC25.071):
11. Present Well Condition Summary:
measuredTotal Depth 17340'feet None feet
feetNonefeet4267'true vertical
Effective Depth measured 17340'feet 8078', 8254'feet
feet4022', 4057'feet4267'true vertical
Measured depthPerforation depth
True Vertical depth
4058' TVD8261' MDL-804-1/2"Tubing (size, grade, measured and true vertical depth)
8078' MDPackers and SSSV (type, measured and true vertical depth)
8254' MD
N/A
4022' TVD
4057' TVD
N/A
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
N/ATreatment descriptions including volumes used and final pressure:
13a.
Prior to well operation:
Subsequent to operation:
13b. Pools active after work:
15. Well Class after work:
StratigraphicServiceExploratory DevelopmentDaily Report of Well Operations
WDSPLGasOil16. Well Status after work:Copies of Logs and Surveys Run
GSTOR SPLUGSUSPGINJElectronic Fracture Stimulation Data
Sundry Number or N/A if C.O. Exempt:
Authorized Name and
Contact Name:Digital Signature with Date:
Contact Email:
Contact Phone:Authorized Title:
2573'2910'
CollapseBurst
Production
Liner
8404'
9078'
Casing
4094'
4-1/2"
8438'
4267'17332'
2873'
115'Conductor
Surface
Intermediate
20"
10-3/4"
78'
measured
TVD
7-5/8"
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
222-134
P.O. Box 100360
Anchorage, AK 99510
3. Address:
ConocoPhillips Alaska, Inc.
N/A
5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work:
ADL380107, ADL025544, ADL025551
Kuparuk River Oil Field/ Exploratory Oil Pool
KRU 3S-701A
Plugs
measuredJunk
Length
measured
true vertical
Packer
Representative Daily Average Production or Injection Data
Tubing PressureCasing Pressure
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
271
Gas-Mcf
MD
0
Size
115'
762163843
000
481
N/A
Sr Res Eng:Sr Pet Geo:Sr Pet Eng:
WINJ WAG
0
Water-BblOil-Bbl
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
N/A
Packer: TNT Prod Packer
Packer: Baker Liner Top Packer
SSSV: None
Lynn Aleshire
lynn.aleshire@conocophillips.com
(907) 265-6525Surveillance Reservoir Engineer
None
None
Submit in PDF format to aogcc.permitting@alaska.govDue Within 30 days of OperationsForm 10-404 Revised 10/2022
6. API Number:
50-103-20847-01-00
By Kayla Junke at 10:39 am, May 03, 2023
Lynn Aleshire
Digitally signed by Lynn
Aleshire
Date: 2023.05.03 10:04:06
-08'00'
AOGCC
DSR-5/923VTL 2/11/2025
RBDMS JSB 050423
SFD
SFD 2/11/2025
DTTMSTART JOBTYP SUMMARYOPS
3/20/2023 SUPPORT
OTHER
OPERATIONS
INSTALL FLOW CROSS ON THE WELLHEAD AND A FLANGE AND DOWN COMER ON THE OUTLET WELL 3S-03. LAY
PIT-LINER. BEGIN TO SPOT EQUIPMENT INTO POSITION.
3/20/2023 MAINTAIN
WELL
FREEZE PROTECT
PUMPED 10 BBLS METH DWN IA
3/21/2023 SUPPORT
OTHER
OPERATIONS
FLOWBACK EQUIPMENT AND TANKS SET IN PLACE. BEGIN RIGGING UP HARD LINE.
3/22/2023 SUPPORT
OTHER
OPERATIONS
ALL HARDLINE RIGGED UP. HES TECH/EXPRO ESTABLISH BHP/BHT COMMUNICATION WITH EXPRO DAS SYSTEM.
3/23/2023 SUPPORT
OTHER
OPERATIONS
PRESSURE TEST COMPLETED, RIGGED UP AND FUNCTION TEST SAFETY SYSTEM. TEST FIRED LINE
HEATER.VERIFIED COMMUNICATION WITH DHG.PREPARE LOCATION FOR WALKDOWN WITH CPF-3 OPERATIONS.
3/24/2023 SUPPORT
OTHER
OPERATIONS
PERFORMED WALK DOWN WITH CPF-3 OPERATIONS AND WELLS SAFETY. 13:45 START INJECTING LIFT GAS AT A
RATE OF .5MMSCF/D.EXPRO BEGIN WARPING HARD LINE.16:00 DHD PERFORM AN I/A FLUID LEVEL SHOT
@1908'.THAT IS 1921' ABOVE OV.
3/25/2023 SUPPORT
OTHER
OPERATIONS
OPEN WELL AT 09:20 AM. GAS RETURN GOING TO PRODUCTION, LIQUID RETURNS TO THE FLOWBACK
TANKS.UNLOAD WELL PER PROCEDURE..
3/26/2023 SUPPORT
OTHER
OPERATIONS
CONTINUE TO UNLOAD THE WELL PER PROCEDURE.PERMISSION WAS GRANTED TO INCREASE THE LIFT GAS
RATE AND WORK OPEN THE INLET CHOKE AS NEEDED. BHP NOT TO FALL BELOW 1200 PSI.
3/27/2023 SUPPORT
OTHER
OPERATIONS
CONTINUE TO UNLOAD THE WELL PER PROCEDURE. NOW SENDING FLUID RETURNS TO PRODUCTION.
3/28/2023 SUPPORT
OTHER
OPERATIONS
CONTINUE TO UNLOAD THE WELL PER PROCEDURE.
3/29/2023 SUPPORT
OTHER
OPERATIONS
CONTINUE TO UNLOAD THE WELL PER PROCEDURE.
3/30/2023 SUPPORT
OTHER
OPERATIONS
CONTINUE TO UNLOAD THE WELL PER PROCEDURE.
3/31/2023 SUPPORT
OTHER
OPERATIONS
CONTINUE TO UNLOAD THE WELL PER PROCEDURE.
3/31/2023 SUPPORT
OTHER
OPERATIONS
RUN 2-7/8" VENTURI W/ 3.45" MULE SHOE. VENTURI WASH W/ S. DIESEL FROM 3472' - 3583' W/ REPEATED WEIGHT
SET OFFS. OOH W/ FRAC SAND IN VENTURI BASKET & FLOWBACK SAND TRAP. RBIH W/ 2.50" JSN TO DRY TAG @
3648' CTMD. JOB IN PROGRESS.
4/1/2023 SUPPORT
OTHER
OPERATIONS
ASSIST CTU WITH FCO
4/1/2023 SUPPORT
OTHER
OPERATIONS
FCO FROM 3550' TO 7903 PUMPING 1.80 BPM S. DIESEL. WELL UNLOADED, BHP SWINGING 2100 TO 3000 PSI.
REDUCE PUMP RATE TO STAY UNDER MAX BHP LIMIT. POOH. HANDOVER TO EXPRO WELL TESTERS. RELEASED
KRU 3S-701A Flowback > 30 Days
Summary of Operations
4/2/2023 SUPPORT
OTHER
OPERATIONS
CONTINUE FLOWING WELL PER PROCEDURE
4/3/2023 SUPPORT
OTHER
OPERATIONS
SI WELL @ 0:05 DUE TO EROSION ISSUES ON A 90 GOING INTO THE FLOWBACK TANK, PIN HOLE LEAK.
UT HARDLINE, INSPECT INLET CHOKE, SWAP OUT 90'S ON FLOWBACK TANKS
4/4/2023 SUPPORT
OTHER
OPERATIONS
FINISH UT ON CRITICAL POINTS OF INSPECTION.
POP WELL, OPENING CHOKE SLOWLY TO PREVENT LARGE AMOUNTS OF SOLID SLUGS
4/5/2023 SUPPORT
OTHER
OPERATIONS
CONTINUE FLOWING WELL PER PROCEDURE, OPENING CHOKE SLOWLY TO MINIMZE SOLIDS SLUGGING
4/6/2023 SUPPORT
OTHER
OPERATIONS
CONTINUE FLOWING WELL PER PROCEDURE, OPENING CHOKE SLOWLY TO MINIMZE SOLIDS SLUGGING
4/7/2023 SUPPORT
OTHER
OPERATIONS
CONTINUE FLOWING WELL PER PROCEDURE,
CONTINUE STEPPING UP THE CHOKE AND MONITOR FOR SOLIDS
4/8/2023 SUPPORT
OTHER
OPERATIONS
CONTINUE FLOWING WELL PER PROCEDURE,
CONTINUE STEPPING UP THE CHOKE AND MONITOR FOR SOLIDS
4/9/2023 SUPPORT
OTHER
OPERATIONS
CONTINUE FLOWING WELL PER PROCEDURE,
ATTEMPTED TO OPEN CHOKE PAST 38 BEANS AND EVERYTIME THE WELL SLUGS WITH SOLIDS, BOTH FRAC AND
FORMATION
4/10/2023 SUPPORT
OTHER
OPERATIONS
CONTINUE FLOWING WELL PER PROCEDURE,
SI WELL PER ENGINEERS, SB FOR CTU
4/16/2023 SUPPORT
OTHER
OPERATIONS
EXPRO OPENED UP WELL AT 7:30 AM. RETURNS SHIPPED TO PRODUCTION. WILL WORK TO SLOWLY LOWER THE
BHP TO 1600 PSI AND ESTABLISH STABLE FLOW IN PREPARATION OF THE CTU CLEANOUT.
4/17/2023 SUPPORT
OTHER
OPERATIONS
CONTINUE TO UNLOAD THE WELL PER PROCEDURE. THE TARGET BHP OF 1600 PSI HAS BEEN
REACHED.PERMISSION WAS GRANTED TO LOWER THE BHP TO 1500 PSI.
4/18/2023 SUPPORT
OTHER
OPERATIONS
CONTINUE TO UNLOAD WELL. S/I @ 19:30 AND FREEZE PROTECT. BEGIN RIG DOWN.
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Installed GLD. Pulled catcher & plug. 3S-701A 3/19/2023 fergusp
General Notes: Last 3 entries
Com Date Last Mod By
IA by Tbg communication through SOV in GLM at 2,641' MD 2/4/2023 rmoore22
Tree tested to 5K only 2/4/2023 d19cm
Total losses to production hole= 414 BBLS 2/2/2023 jhanse11
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 19.12 37.0 115.0 115.0 62.58 B
Surface 10 3/4 9.95 37.3 2,910.0 2,573.3 45.50 L80 H563
Intermediate 7 5/8 6.88 34.0 8,438.0 4,093.8 29.70 L-80 Hyd 563
Liner 4 1/2 3.95 8,254.1 17,332.0 4,266.9 12.60 P-110 HYD 563
Tubing Strings: string max indicates LONGEST segment of string
Top (ftKB)
33.9
Set Depth …
8,260.7
Set Depth …
4,058.1
String Ma…
4 1/2
Tubing Description
Tubing – Completion Upper
Wt (lb/ft)
12.60
Grade
L80
Top Connection
H563
ID (in)
3.96
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
33.9 33.9 0.00 Hanger 11.000 Cameron 4-1/2" Tubing Hanger, Hyd
563
Camero
n
2200453
6-28-01
3.958
2,641.5 2,399.5 47.21 Mandrel – GAS
LIFT
4.500 4-1/2" Camco KBG-4-5 GLM Camco KBG-4-5
W/BK
latch
3.957
3,829.1 2,994.9 73.23 Mandrel – GAS
LIFT
4.500 4-1/2" Camco KBG-4-5 GLM Camco KBG-4-
5 W/1"
dummy
BK latch
3.957
3,897.0 3,014.1 73.85 Nipple - X 4.500 Landing Nipple, X, 3.813" Packing
Bore
Halliburt
on
3.813" X
landing
nipple
3.813
8,014.0 4,008.1 77.66 Sensor -
Discharge
Gauge
4.500 Gauge Mandrel, HES OPSIS Single
Ended
Otis Single
end
gauge
mandrel
3.878
8,078.5 4,021.6 78.19 Packer 4.500 TNT Production Packer, HES,
7.625"X4.5", VAMTOP B X P
Halliburt
on
7.625" x
4.5" TNT
Packer
3.856
8,145.1 4,034.9 78.59 Nipple - DB 4.500 Landing Nipple, DB, 4.5" X 3.75" Camco 3.75" DB 3.750
8,198.4 4,045.6 78.47 Sub - Shear
Out - SOS
4.500 Arsenal Glass Disc Sub, 5500 psi
Shear
Arsenal 11937-
01-02
3.890
8,251.5 4,056.2 78.32 Locator 5.300 Baker Shear Type Locator sub -
above locating shoulder
3.860
8,252.2 4,056.4 78.32 Locator 5.640 Baker Shear Type Locator - to
locating shoulder (Shear pins 1'
below shoulder)
3.860
8,257.4 4,057.4 78.30 Wireline Guide 5.200 Halliburton Ratcheting Muleshoe 3.880
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)
2,641.5 2,399.5 47.21 1 GAS LIFT GLV BK 1 1,360.0 3/19/2023 KBG 4-5 0.188
3,829.1 2,994.9 73.23 2 GAS LIFT OV BK 1 0.0 3/19/2023 KBG 4-5 0.438
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)
8,254.1 4,056.8 78.31 Packer 5.500 5.5" X 7-5/8" Liner Top Packer w/
11' x 5.76" ID TieBK Sleeve
Baker ZAN173 5.760
8,276.5 4,061.3 78.24 Nipple - RS 6.050 5.5" X 7-5/8" SLZXP (HRD-E)
Liner Top Hanger
Baker 13760865 4.260
8,278.8 4,061.8 78.23 XO Reducing 5.500 5.5" Hyd 563 box X pin 4.5" Hyd
563 cross over
3.890
9,208.4 4,203.8 84.82 Packer - Swell 4.500 #REF! Baker 3.910
9,312.5 4,211.4 87.24 Sleeve - Frac 5.000 Advanced Upstream Frac Sleeve
(Trigger)
Advance
d
Upstrea
m
107394-
000031
3.500
9,480.1 4,212.7 90.64 Sleeve - Frac 5.000 Advanced Upstream Frac Sleeve
#15
Advance
d
Upstrea
m
107394-
000040
3.500
9,733.5 4,210.6 90.40 Packer - Swell 4.500 PACKER,SWELL, 5.80", BAKER,
HYD563 Assem. 15
Baker 3.900
10,003.9 4,209.4 90.23 Sleeve - Frac 5.000 Advanced Upstream Frac Sleeve
#14
Advance
d
Upstrea
m
107394-
000028
3.500
10,262.3 4,208.3 90.36 Packer - Swell 4.500 PACKER,SWELL, 5.80", BAKER,
HYD563 Assem. 14
Baker 3.850
10,532.2 4,205.0 90.74 Sleeve - Frac 5.000 Advanced Upstream Frac Sleeve
#13
Advance
d
Upstrea
m
107394-
000042
3.500
10,790.3 4,201.0 90.83 Packer - Swell 4.500 PACKER,SWELL, 5.80", BAKER,
HYD563 Assem. 13
Baker 3.870
HORIZONTAL, 3S-701A, 5/1/2023 4:41:10 PM
Vertical schematic (actual)
Liner; 8,254.1-17,332.0
Intermediate; 34.0-8,438.0
Tubing - Pup Joint; 8,147.1
Nipple - DB; 8,145.1
Packer; 8,078.5
Intermediate String 1 Cement;
7,262.0 ftKB
Nipple - X; 3,897.0
Mandrel – GAS LIFT; 3,829.1
Surface; 37.3-2,910.0
Mandrel – GAS LIFT; 2,641.5
Stage Cementing; 37.4 ftKB
Conductor; 37.0-115.0
Hanger; 33.9
KUP PROD
KB-Grd (ft)
45.20
RR Date
2/5/2023
Other Elev…
3S-701A
...
TD
Act Btm (ftKB)
17,340.0
Well Attributes
Field Name Wellbore API/UWI
501032084701
Wellbore Status
PROD
Max Angle & MD
Incl (°)
91.02
MD (ftKB)
11,222.24
WELLNAME WELLBORE3S-701
Annotation End DateH2S (ppm) DateComment
Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal ID
(in)
11,059.9 4,197.2 90.76 Sleeve - Frac 5.000 Advanced Upstream Frac Sleeve
#12
Advance
d
Upstrea
m
107394-
000041
3.500
11,317.2 4,193.5 90.64 Packer - Swell 4.500 PACKER,SWELL, 5.80", BAKER,
HYD563 Assem. 12
Baker 3.880
11,587.6 4,191.7 90.14 Sleeve - Frac 5.000 Advanced Upstream Frac Sleeve
#11
Advance
d
Upstrea
m
107394-
000037
3.500
11,804.5 4,191.3 90.40 Packer - Swell 4.500 PACKER,SWELL, 5.80", BAKER,
HYD563 Assem. 11
Baker 3.870
12,070.8 4,189.9 90.20 Sleeve - Frac 5.000 Advanced Upstream Frac Sleeve
#10
Advance
d
Upstrea
m
107394-
000030
3.500
12,287.5 4,188.6 90.40 Packer - Swell 4.500 PACKER,SWELL, 5.80", BAKER,
HYD563 Assem. 10
Baker 3.870
12,557.4 4,187.8 89.96 Sleeve - Frac 5.000 Advanced Upstream Frac Sleeve
#9
Advance
d
Upstrea
m
107394-
000039
3.500
12,774.2 4,188.9 89.36 Packer - Swell 4.500 PACKER,SWELL, 5.80", BAKER,
HYD563 Assem. 9
Baker 3.910
13,044.0 4,192.2 89.23 Sleeve - Frac 5.000 Advanced Upstream Frac Sleeve
#8
Advance
d
Upstrea
m
107394-
000036
3.500
13,261.0 4,195.2 89.29 Packer - Swell 4.500 PACKER,SWELL, 5.80", BAKER,
HYD563 Assem. 8
Baker 3.820
13,531.3 4,198.4 89.22 Sleeve - Frac 5.000 Advanced Upstream Frac Sleeve
#7
Advance
d
Upstrea
m
107394-
000032
3.500
13,748.2 4,201.5 89.10 Packer - Swell 4.500 PACKER,SWELL, 5.80", BAKER,
HYD563 Assem. 7
Baker 3.960
14,015.5 4,206.1 88.93 Sleeve - Frac 5.000 Advanced Upstream Frac Sleeve
#6
Advance
d
Upstrea
m
107394-
000035
3.500
14,230.5 4,210.7 88.59 Packer - Swell 4.500 PACKER,SWELL, 5.80", BAKER,
HYD563 Assem. 6
Baker 3.900
14,500.2 4,216.6 88.63 Sleeve - Frac 5.000 Advanced Upstream Frac Sleeve
#5
Advance
d
Upstrea
m
107394-
000029
3.500
14,717.0 4,221.1 88.82 Packer - Swell 4.500 PACKER,SWELL, 5.80", BAKER,
HYD563 Assem. 5
Baker 3.870
14,986.9 4,226.3 89.24 Sleeve - Frac 5.000 Advanced Upstream Frac Sleeve
#4
Advance
d
Upstrea
m
107394-
000038
3.500
15,243.2 4,230.2 89.11 Packer - Swell 4.500 PACKER,SWELL, 5.80", BAKER,
HYD563 Assem. 4
Baker 3.920
15,513.2 4,234.5 89.37 Sleeve - Frac 5.000 Advanced Upstream Frac Sleeve
#3
Advance
d
Upstrea
m
107394-
000044
3.500
15,771.7 4,237.5 89.22 Packer - Swell 4.500 PACKER,SWELL, 5.80", BAKER,
HYD563 Assem. 3
Baker 3.910
16,041.9 4,240.4 89.45 Sleeve - Frac 5.000 Advanced Upstream Frac Sleeve
#2
Advance
d
Upstrea
m
107394-
000033
3.500
16,298.5 4,244.0 88.67 Packer - Swell 4.500 PACKER,SWELL, 5.80", BAKER,
HYD563 Assem. 2
Baker 3.900
16,568.5 4,249.8 88.63 Sleeve - Frac 5.000 Advanced Upstream Frac Sleeve
#1
Advance
d
Upstrea
m
107394-
000034
3.500
16,825.2 4,255.9 88.57 Packer - Swell 4.500 PACKER,SWELL, 5.80", BAKER,
HYD563 Assem. 1
Baker 3.900
HORIZONTAL, 3S-701A, 5/1/2023 4:41:11 PM
Vertical schematic (actual)
Liner; 8,254.1-17,332.0
Intermediate; 34.0-8,438.0
Tubing - Pup Joint; 8,147.1
Nipple - DB; 8,145.1
Packer; 8,078.5
Intermediate String 1 Cement;
7,262.0 ftKB
Nipple - X; 3,897.0
Mandrel – GAS LIFT; 3,829.1
Surface; 37.3-2,910.0
Mandrel – GAS LIFT; 2,641.5
Stage Cementing; 37.4 ftKB
Conductor; 37.0-115.0
Hanger; 33.9
KUP PROD 3S-701A
...
WELLNAME WELLBORE3S-701
AOGCC
RBDMS JSB 040423
DSR-4/4/23
CDW 04/17/2023
VTL 2/11/2025
323-092
JSB
SFD 2/11/2025
Prepared By:
Keegan Lambe
Daniel Faur
Nannook Crew
Intervals 1-16
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
own risk.
3S-701
Conoco Phillips
Harrison Bay County, AK
Post Job Report
Stimulation Treatment
API: 50-103-20847
Prepared for: Dustin Morrow
March 13, 2023
Coyote Formation
25# Delta Frac
Table of Contents
Section Page(s)
Executive Summary
Wellbore Information
Actual Design
Interval Summary
Fluid System-Proppant Summary
Interval 1 Plots
Interval 2 Plots
Interval 3 Plots
Interval 4 Plots
Interval 5 Plots
Interval 6 Plots
Interval 7 Plots
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
Appendix
Well Summary
Chemical Summary
Planned Design
Water Analysis 2-26
Water Analysis 3-2
Water Analysis 3-3
Water Analysis 3-6
Water Analysis 3-7
Water Analysis 3-8
Water Analysis 3-9
Water Analysis 3-10
Water Analysis 3-11
Water Analysis 3-12
Real-Time QC
Event Log March 1
Event Log March 2
Event Log March 5
Event Log March 6
Event Log March 7
Event Log March 8
Event Log March 9
Event Log March 10-11
Event Log March 12
168
169
170
171
172
163
164
165
166
167
158
159
160
161
162
153
154
155
156
157
135 - 145
146
147
148
149 - 152
103 - 110
111 - 114
115 - 122
123 - 130
131 - 134
72 - 75
76 - 79
80 - 91
92 - 98
99 - 102
48 - 51
52 - 63
64 - 71
9 - 27
28
29 - 39
40 - 47
3
4
5 - 8
Conoco Phillips - 3S-701 TOC 2
Alexander Bentz
Associate Technical Professional
Keegan Lambe Pablo Hernandez Gonzalez
Senior Technical Professional Senior Technical Professional
Engineering Executive Summary
The MO-67 for this job was diluted prior to arriving to location to ensure pH control of the fluid system could be managed at the
designed rates of the job.
Interval 5 was skipped due to no dart signatures. During the pumping of the first 7 stages, 100Mesh was over pumped. Issue
was realized and corrected for the remaining stages. The values for proppant listed above are the delivered ticketed weight.
Conoco Phillips - 3S-701 Executive Summary 3
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Li
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A
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D
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s
Interval 1
Coyote
@ 17094 - 17096.78 ft 104.8 °F
Interval 2
Coyote
@ 16569 - 16571.78 ft 104.6 °F
Interval 3
Coyote
@ 16042 - 16044.78 ft 104.5 °F
Interval 4
Coyote
@ 15513 - 15515.78 ft 104.5 °F
Interval 5
Coyote
@ 14987 - 14989.78 ft
104.4 °F
Co
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Interval 6
Coyote
@ 14500 - 14502.78 ft 104.3 °F
Interval 7
Coyote
@ 14015 - 14017.78 ft 104.2 °F
Interval 8
Coyote
@ 13531 - 13533.78 ft 104.1 °F
Interval 9
Coyote
@ 13044 - 13046.78 ft 104 °F
Interval 10
Coyote
@ 12557 - 12559.78 ft 104 °F
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Interval 15
Coyote
@ 9962 - 9964.78 ft 104.2 °F
Interval 11
Coyote
@ 12071 - 12073.78 ft 104 °F
Interval 12
Coyote
@ 11546 - 11548.78 ft 104 °F
Interval 13
Coyote
@ 11019 - 11021.78 ft 104.1 °F
Interval 14
Coyote
@ 10491 - 10493.78 ft 104.2 °F
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0
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1
5
16
-
1
4
25
#
D
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Pr
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De
s
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t
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(g
a
l
)
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)
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s
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M
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a
l
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24
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4
%
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%
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%
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%
0
%
-
--
**
I
F
S
n
u
m
b
e
r
s
f
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M
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--
**
P
r
o
p
p
a
n
t
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s
b
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l
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d
f
r
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m
W
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t
T
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t
v
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s
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c
r
o
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D
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v
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3
%
1
%
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3
%
-
1
%
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1
9
%
5
%
-
-
--
-
Fl
u
i
d
T
y
p
e
25
#
D
e
l
t
a
F
r
a
c
25
#
L
i
n
e
a
r
Se
a
w
a
t
e
r
Fr
e
e
z
e
P
r
o
t
e
c
t
Po
t
a
s
s
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u
m
F
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m
a
t
e
Pr
o
p
p
a
n
t
T
y
p
e
Wa
n
l
i
1
6
/
2
0
C
e
r
a
m
i
c
10
0
M
--
---
Interval 16
Coyote
@ 9312.5 - 9315.28 ft 104.2 °F
Co
n
o
c
o
P
h
i
l
l
i
p
s
-
3
S
-
7
0
1
Ac
t
u
a
l
D
e
s
i
g
n
8
NA bpm
psi
psi
bpm
psi
psi
bpm
psi
psi
psi
hhp
psi
psi
ppg
cP
F
psi
psi/ft
psi
psi
psi
lbs
lbs
lbs
lbs
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
*
Proppant Summary
Interval Summary
3S-701 - Coyote - Interval 1
Interval Summary
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Conoco Phillips - 3S-701 Interval Summary 9
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Conoco Phillips - 3S-701 Interval Summary 10
bpm
psi
psi
bpm
psi
psi
bpm
psi
psi
psi
hhp
psi
psi
ppg
cP
F
lbs
lbs
lbs
lbs
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
3S-701 - Coyote - Interval 2
Interval Summary
*
Proppant Summary
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Conoco Phillips - 3S-701 Interval Summary 11
bpm
psi
psi
bpm
psi
psi
bpm
psi
psi
psi
hhp
psi
psi
ppg
cP
F
psi
psi/ft
lbs
lbs
lbs
lbs
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Fluid Summary (by stage description)
Proppant Summary
*
3S-701 - Coyote - Interval 3
Interval Summary
Fluid Summary (by fluid description)
Conoco Phillips - 3S-701 Interval Summary 12
bpm
psi
psi
bpm
psi
psi
bpm
psi
psi
psi
hhp
psi
psi
ppg
cP
F
psi
psi/ft
lbs
lbs
lbs
lbs
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Summary
Proppant Summary
3S-701 - Coyote - Interval 4
Fluid Summary (by stage description)
*
Fluid Summary (by fluid description)
Conoco Phillips - 3S-701 Interval Summary 13
NA bpm
psi
psi
bpm
psi
psi
bpm
psi
psi
psi
hhp
psi
psi
ppg
cP
F
lbs
lbs
lbs
lbs
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Proppant Summary
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Interval Summary
3S-701 - Coyote - Interval 5
*
Conoco Phillips - 3S-701 Interval Summary 14
bpm
psi
psi
bpm
psi
psi
bpm
psi
psi
psi
hhp
psi
psi
ppg
cP
F
psi
psi/ft
lbs
lbs
lbs
lbs
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
3S-701 - Coyote - Interval 6
Interval Summary
Proppant Summary
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
*
Conoco Phillips - 3S-701 Interval Summary 15
bpm
psi
psi
bpm
psi
psi
bpm
psi
psi
psi
hhp
psi
psi
ppg
cP
F
psi
psi/ft
lbs
lbs
lbs
lbs
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Summary
3S-701 - Coyote - Interval 7
Proppant Summary
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
*
Conoco Phillips - 3S-701 Interval Summary 16
bpm
psi
psi
bpm
psi
psi
bpm
psi
psi
psi
hhp
psi
psi
ppg
cP
F
psi
psi/ft
psi
psi
psi
lbs
lbs
lbs
lbs
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Summary
Fluid Summary (by stage description)
Fluid Summary (by fluid description)
*
3S-701 - Coyote - Interval 8
Proppant Summary
Conoco Phillips - 3S-701 Interval Summary 17
bpm
psi
psi
bpm
psi
psi
bpm
psi
psi
psi
hhp
psi
psi
ppg
cP
F
lbs
lbs
lbs
lbs
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Summary
Fluid Summary (by stage description)
Proppant Summary
*
Fluid Summary (by fluid description)
3S-701 - Coyote - Interval 9
Conoco Phillips - 3S-701 Interval Summary 18
bpm
psi
psi
bpm
psi
psi
bpm
psi
psi
psi
hhp
psi
psi
ppg
cP
F
psi
psi/ft
psi
psi
psi
lbs
lbs
lbs
lbs
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Proppant Summary
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
*
Interval Summary
3S-701 - Coyote - Interval 10
Conoco Phillips - 3S-701 Interval Summary 19
bpm
psi
psi
bpm
psi
psi
bpm
psi
psi
psi
hhp
psi
psi
ppg
cP
F
lbs
lbs
lbs
lbs
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Summary
Proppant Summary
Fluid Summary (by fluid description)
3S-701 - Coyote - Interval 11
Fluid Summary (by stage description)
*
Conoco Phillips - 3S-701 Interval Summary 20
bpm
psi
psi
bpm
psi
psi
bpm
psi
psi
psi
hhp
psi
psi
ppg
cP
F
psi
psi/ft
psi
psi
psi
lbs
lbs
lbs
lbs
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Summary
Proppant Summary
3S-701 - Coyote - Interval 12
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
*
Conoco Phillips - 3S-701 Interval Summary 21
bpm
psi
psi
bpm
psi
psi
bpm
psi
psi
psi
hhp
psi
psi
ppg
cP
F
psi
psi/ft
psi
psi
psi
lbs
lbs
lbs
lbs
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
Engineer:
Treater:
Supervisor:
Interval Summary
Proppant Summary
*
Fluid Summary (by stage description)
3S-701 - Coyote - Interval 13
Fluid Summary (by fluid description)
Conoco Phillips - 3S-701 Interval Summary 22
Customer Engineer:
Customer Rep:
Conoco Phillips - 3S-701 Interval Summary 23
bpm
psi
psi
bpm
psi
psi
bpm
psi
psi
psi
hhp
psi
psi
ppg
cP
F
lbs
lbs
lbs
lbs
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Summary
Proppant Summary
*
Fluid Summary (by stage description)
Fluid Summary (by fluid description)
3S-701 - Coyote - Interval 14
Conoco Phillips - 3S-701 Interval Summary 24
NA bpm
psi
psi
bpm
psi
psi
bpm
psi
psi
psi
hhp
psi
psi
ppg
cP
F
psi
psi/ft
psi
psi
psi
lbs
lbs
lbs
lbs
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Summary
*
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
3S-701 - Coyote - Interval 15
Proppant Summary
Conoco Phillips - 3S-701 Interval Summary 25
bpm
psi
psi
bpm
psi
psi
bpm
psi
psi
psi
hhp
psi
psi
ppg
cP
F
psi
psi/ft
psi
psi
psi
lbs
lbs
lbs
lbs
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
gal bbls
Fluid Summary (by stage description)
Interval Summary
3S-701 - Coyote - Interval 16
Proppant Summary
*
Fluid Summary (by fluid description)
Conoco Phillips - 3S-701 Interval Summary 26
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Conoco Phillips - 3S-701 Interval Summary 27
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28
Hydraulic Fracturing Fluid Product Component Information Disclosure
Job Start Date: 03/01/2023
Job End Date: 03/12/2023
State: Alaska
County: Harrison Bay
API Number: 50-103-20847-01-00
Operator Name:ConocoPhillips
Company/Burlington Resources
Well Name and Number: 3S-701A
Latitude: 70.394616
Longitude: -150.191678
Datum: NAD27
Federal Well: NO
Indian Well: NO
True Vertical Depth: 4267
Total Base Water Volume (gal)*: 1650727
Total Base Non Water Volume: 82536.352
Water Source Percent
Other, > 1000TDS 100.00%
Hydraulic Fracturing Fluid Composition:
Trade Name Supplier Purpose Ingredients
Chemical
Abstract
Service
Number
(CAS #)
Maximum
Ingredient
Concentration
in Additive (%
by mass)**
Maximum
Ingredient
Concentration
in HF Fluid (%
by mass)**
Comments
BC-140 X2 Halliburton Initiator
BE-6(TM)
Bactericide Halliburton Microbiocide
CAT-3
ACTIVATOR Halliburton Activator
Ceramic
Proppant -
Wanli
Wanli Proppant
LoSurf-300D Halliburton Non-ionic Surfactant
LVT-200 Baker
Hughes Additive
MO-67 Halliburton pH Control
OPTIFLO-II
DELAYED
RELEASE
BREAKER
Halliburton Breaker
Potassium
Formate Brine MI Swaco Completion/Stimulation
Sand-
Common
White-100
Mesh, SSA-2
Halliburton Proppant
SEAWATER
(SG 8.52)Halliburton Base Fluid
WG-36
GELLING
AGENT
Halliburton Gelling Agent
Items above are Trade Names. Items below are the individual ingredients.
Water 7732-18-5 100.00000 70.57895
Density =
8.52
Corundum 1302-74-5 65.00000 15.46439 None
Mullite 1302-93-8 45.00000 10.70612 None
Sodium chloride 7647-14-5 5.00000 3.75924 None
Crystalline silica, quartz 14808-60-7 100.00000 0.43383 None
Guar gum 9000-30-0 100.00000 0.21838 None
Distillates (petroleum),
hydrotreated light 64742-47-8 100.00000 0.10886 None
Water 7732-18-5 100.00000 0.10658 None
Potassium Formate 590-29-4 100.00000 0.06052 None
Ethanol 64-17-5 60.00000 0.03917 None
Monoethanolamine
borate 26038-87-9 100.00000 0.03894 None
EDTA/Copper chelate Proprietary 30.00000 0.01981 None
Heavy aromatic
petroleum naphtha 64742-94-5 30.00000 0.01959 None
Oxyalkylated nonyl
phenolic resin Proprietary 30.00000 0.01959 None
Ethylene glycol 107-21-1 30.00000 0.01168 None
Sodium hydroxide 1310-73-2 30.00000 0.00866 None
Ammonium persulfate 7727-54-0 100.00000 0.00849 None
Oxyalkylated phenolic
resin Proprietary 10.00000 0.00653 None
Ammonium chloride 12125-02-9 5.00000 0.00330 None
Poly(oxy-1,2-
ethanediyl), alpha-(4-
nonylphenyl)-omega-
hydroxy-, branched
127087-87-
0 5.00000 0.00326 None
Naphthalene 91-20-3 5.00000 0.00326 None
Oxylated phenolic resin Proprietary 30.00000 0.00255 None
2-Bromo-2-nitro-1,3-
propanediol 52-51-7 100.00000 0.00133 None
Ammonia 7664-41-7 1.00000 0.00066 None
1,2,4 Trimethylbenzene 95-63-6 1.00000 0.00065 None
C.I. pigment Orange 5 3468-63-1 1.00000 0.00008 None
2,7-
Naphthalenedisulfonic
acid, 3-hydroxy-4-[(4-
sulfor-1-naphthalenyl)
azo] -, trisodium salt
915-67-3 0.10000 0.00004 None
* Total Water Volume sources may include various types of water including fresh water, produced water, and recycled water
** Information is based on the maximum potential for concentration and thus the total may be over 100%
Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided.
Ingredient information for chemicals subject to 29 CFR 1910.1200(i) and Appendix D are obtained from suppliers Material Safety Data Sheets
(MSDS)
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
March 30, 2023
Erika Livingston
Wells Chief Engineer
ConocoPhillips Alaska, Inc.
P. O. Box 100360
Anchorage, AK 99510-0360
Re: Notice of Violation – Closeout
Failure to Test BOPE
Doyon 19
Kuparuk River Unit 3S-701 (PTD 2221330)
Kuparuk River Unit 3S-701A (PTD 2221340)
Dear Ms. Livingston:
ConocoPhillips Alaska, Inc. (CPAI) responded to the above referenced notice of violation by
letter dated March 13, 2023. That letter identifies specific actions to prevent recurrence of the
notice of violation, notably a checklist that is now part of CPAI’s standard procedure for its
drilling programs. The corrective actions outlined in your letter address the procedural concerns
identified in the notice of violation.
The Alaska Oil and Gas Conservation Commission (AOGCC) does not intend to pursue any
further enforcement action regarding these missed blowout prevention equipment tests.
Sincerely,
Brett W. Huber, Sr.
Chair, Commissioner
cc: AOGCC Inspectors
Phoebe Brooks
Brett W. Huber,
Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.03.30 10:48:00 -08'00'
By Samantha Carlisle at 3:02 pm, Mar 13, 2023
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: 49' FNL, 1515' FEL SESW S24 T21N R7E 9. Ref Elevations: KB: 17. Field / Pool(s):
GL: 27.7 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" L-80 115'
10.75" L-80 2573'
7.625" L-80 4094'
4 1/2" L-80 4267'
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
8254'
501-103-20847-01-00
KRU 3S-701A
1/13/2023
17340'MD/4267'TVD
N/A
64.5
P.O.Box 100360, Anchorage, AK 99510-0360
476442
2820' FSL, 818' FEL NWSE S18 T12N R8E
1666' FSL, 457' FEL SESW S25 T12N R7E
1/28/2023
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
ConocoPhillips Alaska, Inc.
WAG
Gas
2/5/2023 222-134
5993955
Kuparuk River Field/ Exploratory Oil Pool
ADL380107, ADL025544, ADL025551
LONS 01-013
40'
40'
2910'
115'
1821'MD/1761'TVD
SETTING DEPTH TVD
5982257
TOP HOLE SIZE AMOUNT
PULLEDTOP
SETTING DEPTH MD
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,
BOTTOM
470929
471954
CEMENTING RECORD
5991105
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and
Number; Date perf'd or liner run):
Liner: 8254'MD/4057' TVD - 17332'MD/4267' TVD
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.
2930'MD/2586'TVD
40'
40'
Per 20 AAC 25.283 (i)(2) attach electronic information
29.7 40'
94
45.5
42"
12.6
40'
N/A
Oil-Bbl: Water-Bbl:
Water-Bbl:
PRODUCTION TEST
N/A
Date of Test: Oil-Bbl:
Flow Tubing
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
8438'
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
TUBING RECORD
GR, RES, DEN, GWD, DIR, AZI, PWD, SONIC, CALIPER, NEU, NMR
SIZE DEPTH SET (MD)
Sr Res EngSr Pet GeoSr Pet Eng
17332'
67bbl of 12.5ppg Class G
4057'
9.875"
6.5"
8261'4.5 8079'MD/4022'TVD
8254'MD/4057'TVD
13.5"
CASING
PACKER SET (MD/TVD)
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
Received by James Brooks on 3/6/2023 at 2:35 PM
Completed
2/5/2023
JSB
RBDMS JSB 030923
G
AOGCC
, Mudlog
VTL 2/11/2024 DSR-3/14/23SFD 2/11/2025
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
Surface Surface
1821 1761
Top West Sak 2133 2023
2732 2460
3068 2670
C-50 5482 3408
8379 4082
17340 4267
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: Shane McCraken
Digital Signature with Date:
Contact Phone:907-265-6926
General:
Item 1a:
Item 1b:
Item 4b:
Item 9:
Item 15:
Item 19:
Item 20:
Item 22:
Item 23:
Item 24:
Item 27:
Item 28:
Item 30:
Item 31:
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.
Formation Name at TD:
Nanushuk
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
Permafrost - Base
29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS
Top of Productive Interval
Nanushuk
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Base West Sak
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: shane.mckraken@conocophillips.com
Authorized Title: Drilling Engineer
Campanian Sand (C-80)
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.
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
Page 1/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/17/2022
09:00
12/17/2022
13:30
4.50 MIRU, MOVE MOB P Blow down steam and water lines. Prep
pad for rig move. Remove tarp wall in
cellar, prepare pipe shed, pits and motor
complex's for move.
0.0 0.0
12/17/2022
13:30
12/17/2022
14:15
0.75 MIRU, MOVE MOB P Skid rig floor to move position. R/D
stompers, ready cellar to move off well.
0.0 0.0
12/17/2022
14:15
12/17/2022
15:45
1.50 MIRU, MOVE MOB P Pull off well with sub and stage ready to
crab.
0.0 0.0
12/17/2022
15:45
12/17/2022
20:30
4.75 MIRU, MOVE MOB P Move sub and crab over to mats at 701
well. Move pits and motor complexes
closer to 701. Continue spottong
equipment in cellar on 701.
0.0 0.0
12/17/2022
20:30
12/17/2022
22:30
2.00 MIRU, MOVE MOB P Install lower rear drillers side wind wall
on cellar.
0.0 0.0
12/17/2022
22:30
12/18/2022
00:00
1.50 MIRU, MOVE MOB P Clear rig mats footprint for cellar from
615 to 704 cellar area. Install riser
adapter on starting head on 701 and
continue setting mat layout for pits and
motor complexes.
0.0 0.0
12/18/2022
00:00
12/18/2022
03:00
3.00 MIRU, MOVE MOB P Align sub, spot and shim over 3S-701.
Lower stompers and set pressures.
Lower rear cellar wind walls. Continue
setting mat layout for and boards for 3S-
704 cellar area.
0.0 0.0
12/18/2022
03:00
12/18/2022
04:00
1.00 MIRU, MOVE MOB P Skid rig floor to drilling position while
preparing pit and motor complex's to
spot onto sub.
0.0 0.0
12/18/2022
04:00
12/18/2022
12:00
8.00 MIRU, MOVE MOB P Spot pits, motors, and pipe shed to sub,
spot rockwasher, and berm around
complexes. Spot Magtec equipment and
MPD choke manifold house. Welder
working on steam lines in motor room.
0.0 0.0
12/18/2022
12:00
12/18/2022
16:00
4.00 MIRU, MOVE MOB P Continue to spot pipe shed to sub and
berm and trim all herculite around
modules. Work on steam lines in pits,
centrifuge dump system. Working on rig
acceptance check list. Clean and clear
3S-615 cellar herculite. Spot pipe shed
tioga heater, MWD unit, Geoprolog unit.
Organize cellar excess equipment and
preapre for drilling. Ready all modules
for surface driling. Ready mud pumps
for taking on spud mud.
RKB-Landing Ring shoulder = 37.38'
RKB-GL = 36.78'
0.0 0.0
12/18/2022
16:00
12/18/2022
22:00
6.00 MIRU, MOVE MOB P Install 4" conductor valves, N/U surface
equipment, install riser adapter spool to
starting head and surface riser to
starting head to confirm length. Surface
riser too short. Sent to shop to add 16".
SIMOPS: Function test gas alarms and
take on spud mud to pits.
Rig accepted at 18:00 hrs.
0.0 0.0
12/18/2022
22:00
12/19/2022
00:00
2.00 MIRU, MOVE SFTY P Rig Crews B & C taking Conoco
IFC/Prep training at camp. Driller
(previously had training) changing out
saver sub from XT39 to NC50.
0.0 0.0
12/19/2022
00:00
12/19/2022
02:00
2.00 MIRU, MOVE SFTY P Rig Crews B & C taking Conoco
IFC/Prep training at camp.
0.0 0.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 2/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/19/2022
02:00
12/19/2022
06:00
4.00 MIRU, MOVE RURD P Complete changing out saver sub from
XT39 to NC50. Perform pre-spud derrick
inspection. SIMOPS: Tally 5" HWDP in
pipe shed. Welder adding extension to
surface riser in shop. load 75 joints 5"
drill pipe in shed. Spotted Halliburton
cement silos in place, stock pits with
products.
0.0 0.0
12/19/2022
06:00
12/19/2022
12:00
6.00 MIRU, MOVE PULD P P/U 13 stands 5" DP and rack in derrick.
Stage 13.5" BHA equipment on floor
and serviceTDS. SIMOPS: Welder
adding extension to surface riser in
shop.
0.0 0.0
12/19/2022
12:00
12/19/2022
12:45
0.75 MIRU, MOVE PULD P Continue P/U 5" DP and rack in derrick. 0.0 0.0
12/19/2022
12:45
12/19/2022
18:00
5.25 MIRU, MOVE RURD P Stage surface riser into cellar. N/U
surface riser, flowline, low pressure
bleed off line, mud bucket return line.
Installed air boot on riser and gel up
same. Test Cameron slip lock adapter
seal to 500 psi for 15 minutes - good
test as per Cameron rep.
Found slip lock to be hanging up on 16"
condutor weld (weld is where a
extension piece was added to the 16"
conductor length). Dressed off weld to
allow slip lock to fit down properly.
Torque riser flange connection studs.
0.0 0.0
12/19/2022
18:00
12/19/2022
19:00
1.00 MIRU, MOVE PULD P Continue to P/U 5" DP and rack in
derrick while dressing conductor weld
for Cameron starting head slip lock
connection. Locked in starting head slip
lock adapter as per Cameron rep.
0.0 0.0
12/19/2022
19:00
12/19/2022
21:00
2.00 MIRU, MOVE RURD P Finish N/U surface riser, install hole fill
line, secure flow line to air boot, torque
mid flange connection and secure drain
lines to cellar box.
0.0 0.0
12/19/2022
21:00
12/20/2022
00:00
3.00 MIRU, MOVE PULD P Continue to P/U 5" DP and rack in
derrick followed with 17 joints 5" HWDP
and Jars.
0.0 0.0
12/20/2022
00:00
12/20/2022
00:45
0.75 MIRU, MOVE PULD P Finish P/U 5" HWDP and rack in derrick. 115.0 115.0
12/20/2022
00:45
12/20/2022
02:15
1.50 MIRU, MOVE BHAH P P/U 13-1/2" clean out BHA. TIH tag ice
at 42'.
115.0 115.0
12/20/2022
02:15
12/20/2022
02:30
0.25 MIRU, MOVE SFTY P Pre-spud meeting with rig crew and
service personal.
115.0 115.0
12/20/2022
02:30
12/20/2022
03:30
1.00 SURFAC, DRILL PRTS P Fill conductor with 8.8 ppg spud mud
and confirm no leaks. Pressure test
surface lines to 4,000 psi.
115.0 115.0
12/20/2022
03:30
12/20/2022
04:00
0.50 SURFAC, DRILL REAM P Clean out conductor F/42' to 115' at
shoe. 350 GPM 330 PSI 30 RPM 2K TQ
115.0 115.0
12/20/2022
04:00
12/20/2022
05:30
1.50 SURFAC, DRILL DDRL P Drill 13-1/2" directional surface hole
F/115' to 222'.
Spud well @ 04:00 hrs 12-20-2022
380 GPM
480 PSI
30 RPM
2K TQ
4-6K WOB
81K P/U
75K S/O
78K ROT
ADT: 1.51 HRS
BIT: 1.51 HRS
115.0 222.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 3/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/20/2022
05:30
12/20/2022
05:45
0.25 SURFAC, DRILL CIRC P Circulate hole clean with 8.8 ppg spud
mud.
380 GPM
450 PSI
30 RPM
2.5K TQ
81K P/U
75K S/O
78K ROT
222.0 222.0
12/20/2022
05:45
12/20/2022
06:00
0.25 SURFAC, DRILL OWFF P OWFF - static. 222.0 222.0
12/20/2022
06:00
12/20/2022
06:30
0.50 SURFAC, DRILL TRIP P BROOH with BHA #1 F/222' T/41'.
350 GPM
30 RPM
222.0 41.0
12/20/2022
06:30
12/20/2022
08:30
2.00 SURFAC, DRILL BHAH P PJSM. M/U BHA #2 as per SLB and
Gyro reps F/41' to 185'.
41.0 185.0
12/20/2022
08:30
12/20/2022
09:00
0.50 SURFAC, DRILL CIRC P Shallow test MWD/ GWD tools pumping
400 gpm, 575 psi - good test.
Precautionary wash and ream F/185'
T/222'.
400 GPM
575 PSI
30 RPM
1.5K TQ
87K S/O
185.0 222.0
12/20/2022
09:00
12/20/2022
11:45
2.75 SURFAC, DRILL DDRL P Drill 13-1/2" directional surface hole
F/222' T/ 490'.
500 GPM
990 PSI
50 RPM
3K TQ
5-10K WOB
95K P/U
98K S/O
95K ROT
ADT: 1.83 HRS
BIT: 3.34 HRS
222.0 490.0
12/20/2022
11:45
12/20/2022
12:00
0.25 SURFAC, DRILL CIRC P Circulate at 100 gpm allowing rock
washer shaker to clear.
490.0 490.0
12/20/2022
12:00
12/20/2022
18:00
6.00 SURFAC, DRILL DDRL P Drill 13-1/2" directional surface hole
F/490' T/ 918'.
Note: At 815' experiencing losses (29
bbls lost). Pumped 60 bbls LCM pill at
40 ppb while drilling ahead and healed
losses. Observed an increase of 40%
cuttings at shaker on bottoms up.
450-500 GPM
880-990 PSI
50 RPM
3K TQ
5-10K WOB
101K P/U
101K S/O
99K ROT
ADT: 4.41 HRS
BIT: 7.75 HRS
490.0 918.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 4/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/20/2022
18:00
12/21/2022
00:00
6.00 SURFAC, DRILL DDRL P Drill 13-1/2" directional surface hole
F/918' T/ 1,388'.
Note: At 1,225' experiencing losses (74
bbl's lost). Pumped 40 bbl's LCM pill at
40 ppb while drilling ahead and healed
losses. Observed an increase of 30%
cuttings (small gravel and sand) at
shaker on bottoms up.
450-500 GPM
880-1070 PSI
50 RPM
3K OFF 4K ON TQ
5-10K WOB
101K P/U
101K S/O
99K ROT
ADT: 5.55 HRS
BIT: 13.3 HRS
918.0 1,388.0
12/21/2022
00:00
12/21/2022
06:00
6.00 SURFAC, DRILL DDRL P Drill 13-1/2" directional surface hole
F/1,388' T/ 2,152' MD / 2,043' TVD.
600 GPM
1510 PSI
80 RPM
2K OFF 6K ON TQ
5-10K WOB
145K P/U
124K S/O
131K ROT
ADT: 3.96 HRS
BIT: 13.92 HRS
1,388.0 2,152.0
12/21/2022
06:00
12/21/2022
12:00
6.00 SURFAC, DRILL DDRL P Drill 13-1/2" directional surface hole
F/2,152' T/ 2,719'MD / 2,455'TVD.
675 GPM
2200 PSI
80 RPM
5K OFF 7K ON TQ
10-20K WOB
145K P/U
124K S/O
131K ROT
ADT: 3.39 HRS
BIT: 18.55 HRS
2,152.0 2,719.0
12/21/2022
12:00
12/21/2022
14:30
2.50 SURFAC, DRILL DDRL P Drill 13-1/2" directional surface hole
F/2,719' T/ 2,920'MD / 2,579'TVD at
section TD. Partial losses while drilling
at 2,753' (40 bph). Pumped 60 bbl LCM
pill at 40 ppb while drilling and losses
decreased to 20 bph.
675 GPM
2050 PSI
80 RPM
4K OFF 7K ON TQ
18-17K WOB
141K P/U
127K S/O
131K ROT
ADT: 1.86 HRS
BIT: 19.17 HRS
2,719.0 2,920.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 5/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/21/2022
14:30
12/21/2022
16:00
1.50 SURFAC, TRIPCAS CIRC P Pump 40 bbls 40 ppb LCM sweep and
circulate bottoms up with 9.8 ppg mud.
675 GPM
2110 PSI
80 RPM
4.5K TQ
141K P/U
127K S/O
131K ROT
2,920.0 2,920.0
12/21/2022
16:00
12/21/2022
16:30
0.50 SURFAC, TRIPCAS BKRM P BROOH 1 stand per b/u F/2,920'
T/2,815.
675 GPM
2050 PSI
80 RPM
6K TQ
2,920.0 2,815.0
12/21/2022
16:30
12/21/2022
16:45
0.25 SURFAC, TRIPCAS OWFF P OWFF - fluid dropped 14" in riser while
monitoring.
2,815.0 2,815.0
12/21/2022
16:45
12/21/2022
21:30
4.75 SURFAC, TRIPCAS BKRM P BROOH F/2,815 T/1,870'.
675 GPM
2060 PSI
80 RPM
6K TQ
2,815.0 1,870.0
12/21/2022
21:30
12/21/2022
21:45
0.25 SURFAC, TRIPCAS TRIP P POOH on elevators F/1,870' T/1,825'.
Observed 25K overpull, made a couple
of attempts without any success. Drop
back to 1,870'.
Note: Permafrost base at 1,821'.
1,870.0 1,870.0
12/21/2022
21:45
12/21/2022
23:00
1.25 SURFAC, TRIPCAS PMPO P Pump OOH F/1,870' T/1,485'.
650 GPM
1780 PSI
127K P/U
117K S/O
1,870.0 1,485.0
12/21/2022
23:00
12/22/2022
00:00
1.00 SURFAC, TRIPCAS TRIP P B/D top drive, line up trip tank on hole.
POOH on elevators F/1,485' T/1,299'.
129K P/U
116K S/O
1,485.0 1,299.0
12/22/2022
00:00
12/22/2022
00:15
0.25 SURFAC, TRIPCAS PMPO P Attempt to POOH on Elev F/1,299'
T/1,244' - pull 20K over 3 times , RIH to
1,266'
1,299.0 1,266.0
12/22/2022
00:15
12/22/2022
02:00
1.75 SURFAC, TRIPCAS PMPO P Observed 25K overpull. Pump
OOH /1,299' T/780' , Stage up to 20K
over pull , observe pack off , Wash down
from 780' T/851' , work thru with 250 -
500 GPM notice large increase in
cuttings on B/U
500-650 GPM
1575 PSI
105K P/U
100K S/O
1,266.0 851.0
12/22/2022
02:00
12/22/2022
03:00
1.00 SURFAC, TRIPCAS BKRM P BROOH F/851' to 700' at 500 GPM
1000 PSI , 20/30 RPM 2/3K TQ
851.0 700.0
12/22/2022
03:00
12/22/2022
04:00
1.00 SURFAC, TRIPCAS PMPO P POOH with pumps at 100 GPM 200 PSI
F/700' T/370'
95K UP
85K DN
700.0 370.0
12/22/2022
04:00
12/22/2022
04:30
0.50 SURFAC, TRIPCAS BKRM P BROOH F/370' T/300'
450 GPM 650 PSI , 30 RPM 2K TQ
370.0 300.0
12/22/2022
04:30
12/22/2022
04:45
0.25 SURFAC, TRIPCAS OWFF P Flow check - static 300.0 300.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 6/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/22/2022
04:45
12/22/2022
05:00
0.25 SURFAC, TRIPCAS TRIP P POOH F/300' T/185' 300.0 185.0
12/22/2022
05:00
12/22/2022
09:00
4.00 SURFAC, TRIPCAS BHAH P L/D BHA as per SLBG DD 185.0 0.0
12/22/2022
09:00
12/22/2022
11:45
2.75 SURFAC, CASING OTHR P Clean/Clear rig floor , monitor well on
trip tank , rig up to run 10 3/4" casing
0.0 0.0
12/22/2022
11:45
12/22/2022
12:30
0.75 SURFAC, CASING PUTB P Perform dummy run with 10 3/4" casing
hanger
Hanger drifted to 9.90"
0.0 0.0
12/22/2022
12:30
12/22/2022
13:45
1.25 SURFAC, CASING RURD P Fininsh rig up to run 10 3/4" casing 0.0 0.0
12/22/2022
13:45
12/22/2022
21:45
8.00 SURFAC, CASING PUTB P PJSM , run 10 3/4" casing , RIH T/166'
check floats , floats holding
Cont to RIH F/166' T/1,900' , as per
detail
Baker lok shoe track
Make up TQ 16.2K double bump each
connection
0.0 1,900.0
12/22/2022
21:45
12/22/2022
22:45
1.00 SURFAC, CASING CIRC P Circulate at 2 joints below base of
permafrost
Stage up to 7 BPM 210 PSI
141K UP
105K DN
1,900.0 1,900.0
12/22/2022
22:45
12/23/2022
00:00
1.25 SURFAC, CASING PUTB P RIH with 10 3/4" casing F/1,900'
T/1,977'
Tag up @ 1,970' , take 30K DN , work
thru with 2 BPM 150 PSI , set DN 30K ,
pull 50K over working thru it
1,900.0 1,977.0
12/23/2022
00:00
12/23/2022
03:30
3.50 SURFAC, CASING PUTB P RIH with 10 3/4" casing F/1,977'
T/2,869'
1,977.0 2,869.0
12/23/2022
03:30
12/23/2022
04:00
0.50 SURFAC, CASING PUTB P Make up 10 3/4" hanger
Circ down @ 1 BPM 150 PSI F/2,869'
T/2,910'
2,869.0 2,910.0
12/23/2022
04:00
12/23/2022
08:15
4.25 SURFAC, CEMENT CIRC P Circ cond mud for cement job
Stage pumps up to 5 BPM in .5 BBLS
increments
5 BPM 160 PSI
192K UP
122K DN
2,910.0 2,910.0
12/23/2022
08:15
12/23/2022
09:00
0.75 SURFAC, CEMENT CIRC P Blow down top drive , rig up cement line 2,910.0 2,910.0
12/23/2022
09:00
12/23/2022
10:30
1.50 SURFAC, CEMENT CIRC P Cont circuate and condtion mud for
cement job at 5 BPM 240 PSI
190K UP
125K DN
2,910.0 2,910.0
12/23/2022
10:30
12/23/2022
11:45
1.25 SURFAC, CEMENT CMNT T PJSM - trouble shoot cement line , valve
leak by , freeze up 2" hose and hard line
out side
2,910.0 2,910.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 7/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/23/2022
11:45
12/23/2022
16:00
4.25 SURFAC, CEMENT CMNT P Cement 10 3/4" casing as per program
Perform surface cement job as per HES.
Pump 60 BBLS 10.2 PPG tuned prime
spacer with LCM and #4 red dye @ 3.8
BPM while reciprocating, P/U 198K S/O
125K.
Drop bottom wiper plug and follow with
460 PPG Arctic Cem Lead Cement,
pump at average 4.7 BPM.
Land hanger while interface exiting
casing shoe at total volume pumped 210
BBLS pick up and reciprocate after
interface clears shoe track at total of
250 BBLS pumped. Finish lead cement
for a total of 460 BBLS 10.7 PPG lead
cement pumped.
Follow with 57 BBLS 15.6 PPG tail
cement at 2.5 BPM
Drop top wiper plug and chase with 20
BBLS @ 4.7 BPM fresh water from HES
cement unit.
Displace 249.8 BBLS 9.7 PPG Spud
mud with rig pumps ICP at 4 BPM 310
PSI, at 240 BBLS pumped reduce rate
to 3 BPM 640 PSI FCP. At 140 BBLS
mud pump cement to surface
Bump plug at 2479 STKS and build
pressure to 1200 PSI and held for 5
minutes. Bleed pressure off and check
floats, floats holding. Note: Landed
hanger 400 STKS into displacement,
CIP @ 15:47 hrs.
Note: Full returns during job until 10
BBLS into tail cement , then regain
returns 20 BBLS into H20 and full
returns from there , 120 BBLS cement
and interface back to surface with 110
BBLS 10.7 PPG cement , 65 BBLS
spacer/mud interface back for a totat of
295 BBLS
Lost 33 BBLS during cement job
S/O 115K prior to landing
2,910.0 2,910.0
12/23/2022
16:00
12/23/2022
18:15
2.25 SURFAC, CEMENT CLEN P Flush riser and flowline with black
water , B/D and R/D cement lines ,
break out and lay down volant tool ,
drain stack , clean up shakers , flow
line , possum belly , start cleaning pits
2,910.0 0.0
12/23/2022
18:15
12/23/2022
19:30
1.25 SURFAC, CEMENT OTHR P Break out and lay down landing joint ,
flush with water
0.0 0.0
12/23/2022
19:30
12/23/2022
20:30
1.00 SURFAC, CEMENT NUND P Make stack washer , flush stack with
black water , blow down top drive and
mud line , blow down hole fill line
0.0 0.0
12/23/2022
20:30
12/24/2022
00:00
3.50 SURFAC, CEMENT NUND P Clean clear floor of casing equipment ,
clean out under drip pan
PJSM , remove lines on riser , nipple
down surface riser
PJSM , lay down riser out side cellar ,
remove conductor valves , start
removing starting head from conductor
0.0 0.0
12/24/2022
00:00
12/24/2022
00:30
0.50 SURFAC, CEMENT NUND P Nipple down starting head from
conductor
Cement 2.5' down from hanger
0.0 0.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 8/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/24/2022
00:30
12/24/2022
01:45
1.25 SURFAC, WHDBOP NUND P Nipple up Cameron well head
Pad operator verify orientation of well
head
Test wellhead seals to 5000 PSI for 10
min , good test , test witnessed by CPAI
rep
Obtain RKB's to lock down screws
0.0 0.0
12/24/2022
01:45
12/24/2022
12:00
10.25 SURFAC, WHDBOP NUND P PJSM , N/U BOP
Install 13 5/8" x 11" adapter flange ,
Nipple up BOP ,install flow box , hook
up service lines , install trip nipple and
flow line , install 1502 flanges to upper
and lower annuals valves , install MPD
manifold , tighten up choke line . install
turn buckles , M/U choke/flare line's
Sim Ops , modify trip nipple add 14"
load pipe shed with 5" DP , clean pits for
LSND mud
0.0 0.0
12/24/2022
12:00
12/24/2022
16:30
4.50 SURFAC, WHDBOP OTHR P Perform Conoco BOP between the well
maintenance
Inspect annular , open up UPR , LPR
and blind ram doors and inspect rams ,
close doors and tighten bolts
Sim Ops , modify trip nipple add 14"
load pipe shed with 5" DP , clean pits for
LSND mud
0.0 0.0
12/24/2022
16:30
12/24/2022
17:30
1.00 SURFAC, WHDBOP BOPE P Set test plug as per Cameron with 5"
test joint
Sim Ops , modify trip nipple add 14"
load pipe shed with 5" DP , clean pits for
LSND mud
0.0 0.0
12/24/2022
17:30
12/24/2022
18:30
1.00 SURFAC, WHDBOP BOPE P Rig up test BOP make up FOSV to dart
valve , make up test sub to top drive ,
fill stack and lines with water , purge air
from system
Shell test on BOP's and choke manifold
and lines
Sim Ops , load pipe shed with 5" DP ,
clean pits for LSND mud
0.0 0.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 9/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/24/2022
18:30
12/25/2022
00:00
5.50 SURFAC, WHDBOP BOPE P All test BOPE with 5" test joint to 250
PSI low 4,000 PSI for 5 minutes each
test charted. Test annular preventer with
5" test joint to 250 psi low and 2,500 psi
high for 5 minutes each.
Test 4" Demco kill, choke valves 1 to 14,
3.5" x 6" VBR top and bottom rams,
blind rams, auto/manual IBOP, HCR
kill/choke valve's, manual kill/choke
valve's , Dart valve , FOSV to 250 psi
low and 4,000 psi high for 5 minutes
each. Test remote and hydraulic chokes
to 2,000 psi and observed pressure drop
when opening.
Accumulator drawdown:
ISP = 2900 psi
PSI after functioning = 1350 psi
200 psi rec = 18 seconds
Full system recovery = 155 seconds
4 bottles back up average = 2275 psi
Bottle pre-charge average = 11 @ 1000
psi
Closing times: Annular = 24 seconds,
UPR = 7 seconds, Blind rams = 7
seconds, LPR = 7 seconds, Choke HCR
= 2 seconds, Kill HCR = 2 seconds
Test all gas alarms, PVT gain/loss, Flow
paddle
Witness by AOGCC Sean Sullivan
0.0 0.0
12/25/2022
00:00
12/25/2022
02:30
2.50 SURFAC, WHDBOP BOPE P Pick up 3 1/2" test joint and crossover
make up to test plug , rig up BOP test
equipment
Test Ann to 250/2500 PSI for 5 min each
Test upper and lower 3 1/2" x 6" VPR to
250/4000 PSI 5 min each , all test
charted
SimOps - clean pits for LSND
0.0 0.0
12/25/2022
02:30
12/25/2022
03:00
0.50 SURFAC, WHDBOP BOPE P Rig down BOP test equipment and lay
down test joint
SimOps - clean pits for LSND
0.0 0.0
12/25/2022
03:00
12/25/2022
07:00
4.00 SURFAC, WHDBOP MPDA P PJSM , N/U MPD equipment on RCD
head
Install MPD test cap , M/U Orbit valve ,
2" manifold on side of RCD , hook up
hydraulic and air lines
Test MPD to 250/1250 PSI 5 min each
R/D test equipment , pull test cap , B/D
lines
0.0 0.0
12/25/2022
07:00
12/25/2022
09:00
2.00 SURFAC, WHDBOP MPDA P Pull test plug , drain stack , blow down
lines , clean trip nipple flange , check
seal
0.0 0.0
12/25/2022
09:00
12/25/2022
11:00
2.00 SURFAC, WHDBOP NUND P Install trip nipple
Simops - Hook up MPD 4" lines and
manifold , MPD choke lines in cellar ,
clear floor
0.0 0.0
12/25/2022
11:00
12/25/2022
12:00
1.00 SURFAC, WHDBOP OTHR P Install wear ring
ID = 10"
0.0 0.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 10/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/25/2022
12:00
12/25/2022
13:30
1.50 SURFAC, DRILLOUT BHAH P Mobilize BHA component's to rig floor ,
lay out BHA in order in pipe shed
0.0 0.0
12/25/2022
13:30
12/25/2022
16:00
2.50 SURFAC, DRILLOUT BHAH P PJSM - Make up BHA 3# as per SLBG
DD T/424'
0.0 424.0
12/25/2022
16:00
12/25/2022
18:00
2.00 SURFAC, DRILLOUT TRIP P RIH F/424' T/2,305'
121K UP
110K DN
424.0 2,305.0
12/25/2022
18:00
12/25/2022
20:30
2.50 SURFAC, DRILLOUT SLPC P PJSM - Hang blocks , slip cut drilling
line
Service top drive , drawworks , iron
roughneck , perform MP2's , calibrate
block height with Totco and MWD
2,305.0 2,305.0
12/25/2022
20:30
12/25/2022
21:15
0.75 SURFAC, DRILLOUT TRIP P RIH F/2,305' T/2,596'
121K UP
111K DN
2,305.0 2,596.0
12/25/2022
21:15
12/25/2022
21:45
0.50 SURFAC, DRILLOUT CIRC P Break circulation , shallow test MWD
tools
500 GPM 920 PSI
Blow down top drive
2,596.0 2,596.0
12/25/2022
21:45
12/26/2022
00:00
2.25 SURFAC, DRILLOUT PRTS P Pressure test 10 3/4” CSG T/3000 PSI
for 30 MIN W/9.8 PPG mud , charted
Pump total 37 STKS , 2.9 BBLS
PSI loss over 30 Min = 0 PSI , casing
held 100%
Total bled back = 2.9 BBLS
R/D and B/D lines and test equipment
2,596.0 2,596.0
12/26/2022
00:00
12/26/2022
01:30
1.50 SURFAC, DRILLOUT CIRC P RIH F/2,596' T/2,691'
Wash/Ream down F/2,691' T/2,805'
460 GPM 800 PSI
Tag up at 2,805' with 5K DN
Drift 5" DP off skate with 2.88" OD rabbit
2,596.0 2,805.0
12/26/2022
01:30
12/26/2022
04:30
3.00 SURFAC, DRILLOUT REAM P Wash ream down F/2,805' T/2,822'
450 GPM 795 PSI 50 RPM 5.5K TQ
Tag plugs clean out shoe track F/2,822'
T/2,910'
400 GPM 600 PSI 45 RPM 7K TQ
Drill up float with 15-20K WOB 40-50
RPM
Drill up shoe with 1-10K WOB 80-100
RPM - ROP max 5 FPH on the last 1' of
shoe for nose cone
Work thru BHA thru shoe 3 times with
ROT and once with no rotary - no over
pull seen
Clean out rat hole F/2,910' T/2,920'
2,805.0 2,920.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 11/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/26/2022
04:30
12/26/2022
04:45
0.25 SURFAC, DRILLOUT DDRL P Drill 20' new hole F/2,920' T/2,940'
450 GPM
760 PSI
90 RPM
8K TQ
3-5K WOB
ECD = 9.45
ADT = ..23
Bit HRS= 2.23
Jar HRS = 21.40
2,920.0 2,940.0
12/26/2022
04:45
12/26/2022
05:15
0.50 SURFAC, DRILLOUT CIRC P Circ cond mud for FIT test F/2,940'
T/2,883'
450 GPM 730 PSI
50 RPM 5.5K TQ
2,940.0 2,883.0
12/26/2022
05:15
12/26/2022
05:30
0.25 SURFAC, DRILLOUT FIT P Flow check , B/D top drive , rig up for
FIT test
2,883.0 2,883.0
12/26/2022
05:30
12/26/2022
06:45
1.25 SURFAC, DRILLOUT FIT P Perform FIT to 1109 PSI = 18.1 PPG
EMW with 9.8 PPG mud
Pump 1.3 BBLS , bleed back 1.3 BBLS
10 3/4" shoe at 2,910' MD 2,573' TVD
Flow check , rig down test equipment ,
blow down lines
2,883.0 2,883.0
12/26/2022
06:45
12/26/2022
07:15
0.50 SURFAC, DRILLOUT CIRC P Pump up survey to retrieve data from
MWD tool , 500 GPM 890 PSI
2,883.0 2,883.0
12/26/2022
07:15
12/26/2022
07:30
0.25 SURFAC, DRILLOUT REAM P Wash and ream down F/2,883' T/2,940'
500 GPM 870 PSI
60 RPM 6K TQ
2,883.0 2,940.0
12/26/2022
07:30
12/26/2022
08:00
0.50 SURFAC, DRILLOUT CIRC P Dispace to 9.0 PPG LSND mud
Pump 52.5 BBLS 9.5 PPG spacer and
displace T/9.0 PPG LSND at 500 GPM
550 PSI , 60 RPM 2.5K TQ
Obtain SPR's
2,940.0 2,940.0
12/26/2022
08:00
12/26/2022
08:45
0.75 SURFAC, DRILLOUT CIRC P Flow check , slight flow
CBU @ 375 GPM 390 PSI 20 RPM 2.5K
TQ
No gas on B/U , no pit gain while
circulating , mud U-tubing
2,940.0 2,940.0
12/26/2022
08:45
12/26/2022
09:15
0.50 SURFAC, DRILLOUT OWFF P Flow check 15 min , static 2,940.0 2,940.0
12/26/2022
09:15
12/26/2022
12:00
2.75 PROD1, DRILL DDRL P Drill F/2,940' T/3,100'
550 GPM
790 PSI
120 RPM
4K TQ
3-5K WOB
ECD = 9.78
ADT = 1.49
Bit HRS= 3.72
Jar HRS = 22.89
2,940.0 3,100.0
12/26/2022
12:00
12/26/2022
13:15
1.25 PROD1, DRILL CIRC P CBU @ 550 GPM 780 PSI 120 RPM 4K
TQ until shakers clean up
Had to slow down for clay unlaoding
Pump up survey
3,100.0 3,100.0
12/26/2022
13:15
12/26/2022
14:30
1.25 PROD1, DRILL BKRM P BROOH F/3,100' T/2,880'
500 GPM 670 PSI
120 RPM 4K TQ
118K Rot WT
3,100.0 2,880.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 12/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/26/2022
14:30
12/26/2022
15:15
0.75 PROD1, DRILL CIRC P CBU x3 at 512 GPM 690 PSI , 80 RPM
4K TQ
117K Rot WT
2,880.0 2,880.0
12/26/2022
15:15
12/26/2022
15:45
0.50 PROD1, DRILL OWFF P B/D top drive , flow check 15 min static 2,880.0 2,880.0
12/26/2022
15:45
12/26/2022
18:00
2.25 PROD1, DRILL TRIP P POOH F/2,880' T/424' 2,880.0 424.0
12/26/2022
18:00
12/26/2022
18:30
0.50 PROD1, DRILL OWFF P Flow check 15 min , static 424.0 424.0
12/26/2022
18:30
12/26/2022
20:45
2.25 PROD1, DRILL BHAH P Stand back 5" HWDP , L/D BHA as per
SLBG DD
424.0 0.0
12/26/2022
20:45
12/26/2022
21:30
0.75 PROD1, DRILL BHAH P Clean clear rig floor of BHA #3 , mobilize
BHA #4 componets to rig floor
0.0 0.0
12/26/2022
21:30
12/26/2022
23:30
2.00 PROD1, DRILL BHAH P Make up 8 3/4" BHA #4 as per SLBG
DD
T/430'
0.0 430.0
12/26/2022
23:30
12/27/2022
00:00
0.50 PROD1, DRILL TRIP P RIH F/430' T/1,753'
115K DN
430.0 1,753.0
12/27/2022
00:00
12/27/2022
00:45
0.75 PROD1, DRILL TRIP P RIH F/1,753' T/2,317'
115K DN
1,753.0 2,317.0
12/27/2022
00:45
12/27/2022
01:15
0.50 PROD1, DRILL CIRC P Shallow test MWD tools at 500 GPM
830 PSI
Blow DN top drive
2,317.0 2,317.0
12/27/2022
01:15
12/27/2022
01:30
0.25 PROD1, DRILL TRIP P RIH F/2,317' T/2,885'
110K DN
2,317.0 2,885.0
12/27/2022
01:30
12/27/2022
03:15
1.75 PROD1, DRILL WASH P Wash down F/2,885' T/3,100'
400 GPM 1540 PSI
Get SPR and UP/DN WT's before going
into open hole , send down links
2,885.0 3,100.0
12/27/2022
03:15
12/27/2022
06:00
2.75 PROD1, DRILL DDRL P Drill 8 3/4" hole F/3,100 T/3,277'
Control drill until upper stab out of the 9
7/8" hole and into the 8 3/4" hole
600 GPM
1200 PSI
120 RPM
5K TQ on 3K off
5K WOB
9.75 ECD
P/U - 131K
S/O - 125K
ROT- 130K
AVG = 64 FPH W/connections
ADT= 2.1
Bit HRS = 2.1
Jar HRS = 24.99
3,100.0 3,277.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 13/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/27/2022
06:00
12/27/2022
12:00
6.00 PROD1, DRILL DDRL P Drill 8 3/4" hole F/3,277' T/3,817'
700 GPM
1700 PSI
160 RPM
5K TQ on 3K off
8K WOB
10.62 ECD
P/U - 135K
S/O - 125K
ROT- 130K
AVG = 90 FPH W/connections
ADT= 4.84
Bit HRS = 6.94
Jar HRS = 29.83
3,277.0 3,817.0
12/27/2022
12:00
12/27/2022
18:00
6.00 PROD1, DRILL DDRL P Drill 8 3/4" hole F/3,817 T/4,301'
700 GPM
1990 PSI
160 RPM
5K TQ on 3K off
11K WOB
11.38 ECD
P/U - 150K
S/O - 138K
ROT- 143K
AVG = 80.6 FPH W/connections
ADT= 4.29
Bit HRS = 11.23
Jar HRS = 34.12
3,817.0 4,301.0
12/27/2022
18:00
12/27/2022
23:30
5.50 PROD1, DRILL DDRL P Drill 8 3/4" hole F/4,301' T/4,764'
720 GPM
202 PSI
160 RPM
6K TQ on 4K off
11K WOB
11.1 ECD
P/U - 166K
S/O - 150K
ROT- 156K
AVG = 84 FPH W/connections
ADT= 4.21
Bit HRS = 15.44
Jar HRS = 35.33
4,301.0 4,764.0
12/27/2022
23:30
12/28/2022
00:00
0.50 PROD1, CORING CIRC P Take final survey , TQ and drag , obtain
SPR's
Pump 40 BBL Hi vis sweep @ 720 GPM
1995 PSI
160 RPM 5K TQ
ECD = 10.88 before sweep
ECD = 10.61 after sweep back and 1
B/U
4,764.0 4,764.0
12/28/2022
00:00
12/28/2022
07:00
7.00 PROD1, CORING CIRC P Circ hole clean @ 720 GPM 1950 PSI ,
160 RPM 5K TQ - Circ 7 B/U after
sweep around while prepping for OBM
ECD F/10.61 T/10.45
Turn pumps down to 335 GPM for C/O
swab on #1 M/P and pit cleaning
Simops - prep pits , rig floor and cellar
for OBM - Change a swap/liner on MP
#1
4,764.0 4,764.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 14/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/28/2022
07:00
12/28/2022
11:15
4.25 PROD1, CORING CIRC P Circ @ 490 GPM 1030 PSI , 120 RPM
4.5K TQ
Take check shot surveys @ 4,764' ,
4,688' , 4,593' MD
Wash back T/4,764' @ 190 GPM 360
PSI , 50 RPM 3K TQ
4,764.0 4,764.0
12/28/2022
11:15
12/28/2022
13:15
2.00 PROD1, CORING CIRC P PJSM - displace to OBM
Pump 10 BBLS H2O , 30 BBLS LVT , 70
BBLS 9.0 PPG Hi-Vis spacer , 100
BBLS 9.0 PPG Versacore OBM
4/5 BPM 300/215 PSI , 120 RPM 5K TQ
163K Rot WT
VSST @ .7
R6/3 @ 7/6
4,764.0 4,764.0
12/28/2022
13:15
12/28/2022
15:00
1.75 PROD1, CORING CLEN P Shut down clean pits , under shakers
and mud trough , redress shakers
screens to 170's
Rot @ 5 RPM 4K TQ 163K rot WT
4,764.0 4,764.0
12/28/2022
15:00
12/28/2022
17:30
2.50 PROD1, CORING CIRC P CBU x3 standing one stand back per
B/U , to ensure mud properly sheared
650 GPM 2050 PSI
120 RPM 5K TQ
147K Rot WT
ECD = 9.95
4,764.0 4,498.0
12/28/2022
17:30
12/28/2022
19:45
2.25 PROD1, CORING CIRC P Circ condtion mud for low end mud
rheology
650 GPM 2050 PSI
120 RPM 5K TQ
147K Rot WT
ECD = 9.95
VSST @ .3
R6/3 @ 8/7
4,498.0 4,498.0
12/28/2022
19:45
12/28/2022
20:00
0.25 PROD1, CORING OWFF P Obtain final TQ and drag , SPR's , drop
2.76" OD hollow drift
Flow check - dropping slightly
162K UP
150K DN
157K Rot 4K TQ
4,498.0 4,498.0
12/28/2022
20:00
12/28/2022
21:45
1.75 PROD1, CORING BKRM P BROOH F/4,498' T/4,212'
650 GPM 2100 PSI
120 RPM 5 TQ
138 Rot Wt
ECD = 10.32
Shakers unload claystones and small
shale pieces - meduim size clay stones
Circ until shakers clean up ECD down to
10.05
Call WSC and rig engineer decide to
RIH to bottom due to having low end
rheology mud properties in the last 250'
of hole and the chance of dirty hole
running core barrels in
4,498.0 4,304.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 15/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/28/2022
21:45
12/28/2022
22:45
1.00 PROD1, CORING WASH T Wash and ream F/4,304' T/4,764'
400 GPM 820 PSI
120 RPM 4.5K TQ
4,304.0 4,764.0
12/28/2022
22:45
12/29/2022
00:00
1.25 PROD1, CORING CIRC T CBU until shakers clean up and make
sure low end mud rheology good
650 GPM 2050 PSI
120 RPM 6K TQ
150K Rot WT
ECD at start = 9.95
ECD at end = 9.80
4,764.0 4,764.0
12/29/2022
00:00
12/29/2022
00:30
0.50 PROD1, CORING CIRC T CBU until shakers clean up and make
sure low end mud rheology good
650 GPM 2050 PSI
120 RPM 6K TQ
150K Rot WT
VSST @ .34
R6/3 @ 9/8
4,764.0 4,764.0
12/29/2022
00:30
12/29/2022
11:15
10.75 PROD1, CORING BKRM P BROOH F/4,764' T/2,890'
600/650 GPM 2040/1550 PSI
140/80 RPM 5/3K TQ
Work thru cuttings beds , flow
restrictions and TQ increase at 4,385' ,
4,302' , 3,974' , 3,750' , 3,415' , 3,242' ,
3,075'
Pull BHA thru shoe F/3,016' T/2,910' no
over pull seen
4,764.0 2,890.0
12/29/2022
11:15
12/29/2022
13:00
1.75 PROD1, CORING CIRC P Circ casing clean @ 720 GPM 2100
PSI , 80 RPM 3K TQ
117K Rot WT
2,890.0 2,890.0
12/29/2022
13:00
12/29/2022
17:30
4.50 PROD1, CORING BKRM P BROOH F/2,890' T/1,375'
700 GPM 1600 PSI
80 RPM 2 K TQ
100K Rot WT
2,890.0 1,375.0
12/29/2022
17:30
12/29/2022
18:00
0.50 PROD1, CORING OWFF P Blow down top drive , line up on trip tank
Flow check 15 min , dropping slightly
1,375.0 1,375.0
12/29/2022
18:00
12/29/2022
19:00
1.00 PROD1, CORING TRIP P POOH F/1,375' T/424' 1,375.0 424.0
12/29/2022
19:00
12/29/2022
19:15
0.25 PROD1, CORING OWFF P Flow check , dropping slightly 424.0 424.0
12/29/2022
19:15
12/29/2022
19:45
0.50 PROD1, CORING TRIP P Stand back HWDP in derrick T/153'
Did not find 2.76" OD rabbit on wire tail
424.0 153.0
12/29/2022
19:45
12/29/2022
20:15
0.50 PROD1, CORING OTHR P Clean rig floor of OBM for BHA handling 153.0 153.0
12/29/2022
20:15
12/29/2022
21:30
1.25 PROD1, CORING BHAH P PJSM - L/D BHA #4 as per SLBG DD 153.0 0.0
12/29/2022
21:30
12/29/2022
22:45
1.25 PROD1, CORING OTHR P Break apart jar stand , lay jars on pipe
skate verify drift not in them
Clean clear rig floor of BHA components
and OBM in prep for P/U coring BHA
Monitor well on TT
0.0 0.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 16/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/29/2022
22:45
12/30/2022
00:00
1.25 PROD1, CORING OTHR P Perform dummy run with core barrel
carrying cage
Modify core carrying cage to fit up pipe
skate to rig floor
Mobilize core BHA components and
tools to rig floor
Monitor well on TT
0.0 0.0
12/30/2022
00:00
12/30/2022
01:30
1.50 PROD1, CORING OTHR P Modify core carrying cage to fit up pipe
skate to rig floor
Perform dummy run with core barrel
carrying cage and 4" core barrel , pick
up core barrel carring cage with tugger ,
pick 4" core barrel with top drive put
core barrel in core carrier , L/D to shed
Monitor well on TT - Lost 1.5 BBLS in 4
HRS
0.0 0.0
12/30/2022
01:30
12/30/2022
04:15
2.75 PROD1, CORING BHAH P PJSM - pick up core BHA T/129' as per
Procor rep
0.0 129.0
12/30/2022
04:15
12/30/2022
07:45
3.50 PROD1, CORING TRIP P RIH F/129' T/2,859'
Drifting 5" DP and 5" HWDP from
derrick with 2.58" OD rabbit
Find 2.76" hollow drift in stand #8
129.0 2,859.0
12/30/2022
07:45
12/30/2022
08:15
0.50 PROD1, CORING OTHR P Take parameters and SPR's
135 GPM 130 PSI
123K UP
119K DN
120K Rot WT at 20 RPM with 2K TQ
2,859.0 2,859.0
12/30/2022
08:15
12/30/2022
14:30
6.25 PROD1, CORING WASH P Wash DN F/2,859' T/4,751'
135 GPM 120 PSI
Tag up 11' high
Wash/Ream F/4,751' T/4,764'
300 GPM 440 PSI
45 RPM 4K TQ
150K Rot WT
2,859.0 4,764.0
12/30/2022
14:30
12/30/2022
18:45
4.25 PROD1, CORING CIRC P Stand one stand back for space out
Add Tritium to mud as per CoreLab rep
circ as per CoreLab and ProCore rep
Circ @ 350 GPM 550 PSI , 12 RPM 4K
TQ 150K Rot WT
4,764.0 4,746.0
12/30/2022
18:45
12/30/2022
19:15
0.50 PROD1, CORING CIRC P Shut Down pumps , pick up 15' pup for
space out , drop 1.25" ball
Pump ball to seat @ 250 GPM 320 PSI
at 358 STKS ball on seat PSI up to 620
PSI
Slack off tag bottom @ 4764' gather
parameters
250 GPM 680 PSI
55 RPM 5K TQ
168K UP
150K DN
160K Rot WT
4,746.0 4,764.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 17/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/30/2022
19:15
12/30/2022
22:00
2.75 PROD1, CORING CORE P Core drill 8 3/4" hole with 4" inner core
barrels as per ProCore rep
Core F/4,764' T/4,854'
250 GPM 740 PSI
55 RPM 5K TQ
5k TQ on
Max Gas = 195 units
4,764.0 4,854.0
12/30/2022
22:00
12/30/2022
23:00
1.00 PROD1, CORING CIRC P Stop rotary P/U break off core , P/U to
175K , 5K over to break core
170K UP
CBU @ 250 GPM 660 PSI
Max Gas = 200 units
Stand one stand back to 4,752'
4,854.0 4,752.0
12/30/2022
23:00
12/30/2022
23:45
0.75 PROD1, CORING OWFF P Break out 15' pup , B/D top drive
OWFF
4,752.0 4,752.0
12/30/2022
23:45
12/31/2022
00:00
0.25 PROD1, CORING TRIP P POOH F/4,752' T/4,657
170K UP
4,752.0 4,657.0
12/31/2022
00:00
12/31/2022
06:00
6.00 PROD1, CORING TRIP P POOH F/4,657' T/680'
As per CoreLab trip schedule
4,657.0 680.0
12/31/2022
06:00
12/31/2022
06:30
0.50 PROD1, CORING OWFF P OWFF and for gas expansion as per
CoreLab procedure
Clean rig floor for L/D cores and BHA
handling
680.0 680.0
12/31/2022
06:30
12/31/2022
08:15
1.75 PROD1, CORING TRIP P POOH F/680' T/126'
As per CoreLab trip schedule
680.0 126.0
12/31/2022
08:15
12/31/2022
12:45
4.50 PROD1, CORING BHAH P Break out and lay down float sub and
top sub
L/D 4" inner core barrels as per ProCore
Rep.
Total core recovered = 91.30'
126.0 126.0
12/31/2022
12:45
12/31/2022
15:30
2.75 PROD1, CORING BHAH P Pull up inspect core bit , make up coring
BHA for 120' core
M/U BHA T/617'
126.0 617.0
12/31/2022
15:30
12/31/2022
16:00
0.50 PROD1, CORING SVRG P Service rig 617.0 617.0
12/31/2022
16:00
12/31/2022
20:45
4.75 PROD1, CORING TRIP P RIH F/617' T/4,782'
165K UP
150K DN
Fill pipe every 10 stands
617.0 4,782.0
12/31/2022
20:45
12/31/2022
21:15
0.50 PROD1, CORING WASH P Wash down F/4,782' T/4,843'
300 GPM 460 PSI
165K UP
150K DN
Tag up wash/ream T/4,854'
300 GPM 460 PSI 10 RPM 3.7K TQ
4,782.0 4,854.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 18/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/31/2022
21:15
1/1/2023
00:00
2.75 PROD1, CORING CIRC P Lay down single of drill pipe
CBU @ 300 GPM 440 PSI , 5 RPM 3K
TQ
157K UP
156K DN
Max gas = 146 units
Wait on word from town about
proceeding to cut core's
4,854.0 4,839.0
1/1/2023
00:00
1/1/2023
00:45
0.75 PROD1, CORING TRIP P PJSM - P/U 10' pup (drift 2.30" rabbit) ,
grab stand 46 from derrick ( drift 2.30")
drop 1.25" OD steel ball kelly up, slack
off F/4,839 tag up at 4,854'
Obtain parameters
260 GPM 360 PSI
55 RPM 5K TQ
Ball on seat @ 333 STKS PSI up to 740
168K UP
153K DN
163K Rot WT
4,839.0 4,854.0
1/1/2023
00:45
1/1/2023
04:30
3.75 PROD1, CORING CORE P Core drill 8 3/4" hole with 4" inner core
barrels as per ProCore rep
Core F/4,854' T/4,974'
Hard spot at 4,933'
See TQ increase at 4,972' , decrease in
ROP , thru it at 4,974'
250 GPM 750 PSI
55 RPM 5K TQ
5k TQ on
Max Gas = 133 units
4,854.0 4,974.0
1/1/2023
04:30
1/1/2023
05:30
1.00 PROD1, CORING CIRC P Stop rotary P/U break off core , P/U to
185K , 10K over to break core
175K UP
CBU @ 300 GPM 1040 PSI @ 4,950'
Max Gas = 95 units
Stand one stand bac kand 10' pup to
4,845'
4,974.0 4,845.0
1/1/2023
05:30
1/1/2023
06:00
0.50 PROD1, CORING OWFF P OWFF - static 4,845.0 4,845.0
1/1/2023
06:00
1/1/2023
07:00
1.00 PROD1, CORING TRIP P POOH F/4,845' T/4,305' as per CoreLab
trip schedule
Pump dry job , B/D top drive
4,845.0 4,305.0
1/1/2023
07:00
1/1/2023
11:15
4.25 PROD1, CORING TRIP P POOH F/4,305' T/660' as per CoreLab
trip schedule
4,305.0 660.0
1/1/2023
11:15
1/1/2023
12:00
0.75 PROD1, CORING OWFF P Flow check , gas expansion time
Load core cradle on skate , prep
ProCore handling equipment
660.0 660.0
1/1/2023
12:00
1/1/2023
14:00
2.00 PROD1, CORING TRIP P POOH stand back HWDP F/660' T/159' 660.0 159.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 19/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/1/2023
14:00
1/1/2023
17:00
3.00 PROD1, CORING BHAH P Break out and lay down float sub and
top sub
L/D 4" inner core barrels as per ProCore
Rep.
Core recovered this run = 122.60'
Total core recovered = 213.90'
159.0 159.0
1/1/2023
17:00
1/1/2023
21:00
4.00 PROD1, CORING BHAH P Pull up inspect core bit , make up coring
BHA for 180' core
M/U BHA #7 T/677'
0.0 677.0
1/1/2023
21:00
1/1/2023
22:45
1.75 PROD1, CORING TRIP P RIH F/677' T/2,850'
110K DN
677.0 2,850.0
1/1/2023
22:45
1/2/2023
00:00
1.25 PROD1, CORING WAIT T Wait on word from town about core
processing timing
Weekly function test BOP
SimOps - Service top drive ,
housekeeping
Monitor well on pit 3
2,850.0 2,850.0
1/2/2023
00:00
1/2/2023
10:00
10.00 PROD1, CORING WAIT T Wait on word from town about core
processing timing
SimOps - housekeeping , work orders ,
adjust tong hanging lines , adjust
draworks brakes , service drawworks
Monitor well on pit 3
2,850.0 2,850.0
1/2/2023
10:00
1/2/2023
12:15
2.25 PROD1, CORING TRIP P RIH F/2,850' T/4,842'
165K UP
150K DN
2,850.0 4,842.0
1/2/2023
12:15
1/2/2023
12:30
0.25 PROD1, CORING WASH P Wash down F/4,842' T/4,974'
Tag @ 4,974' set DN 5K , rack back a
stand , P/U 5' pup and single
300 GPM 538 PSI
165K UP
150K DN
4,842.0 4,937.0
1/2/2023
12:30
1/2/2023
13:00
0.50 PROD1, CORING OTHR T Recalibrate block height , Totco not
tracking correct
4,937.0 4,937.0
1/2/2023
13:00
1/2/2023
15:00
2.00 PROD1, CORING CIRC P Drop 1.25" ball pump down at 195 GPM
200 PSI 10 RPM 5K TQ
Ball on seat at 255 STKS , PSI F/250
T/580
Stage up flow rate to 300 GPM 875 PSI
Wash/ream tag bottom
4,937.0 4,974.0
1/2/2023
15:00
1/2/2023
21:00
6.00 PROD1, CORING CORE P Core drill 8 3/4" hole with 4" inner core
barrels as per ProCore rep
Core F/4,974'' T/5,154'
Hard spot at 5,013' , 5,044' , 5,098'
250 GPM 1020 PSI
55 RPM 6K TQ
6k TQ on
Max Gas = 45 units
4,974.0 5,154.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 20/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/2/2023
21:00
1/2/2023
22:00
1.00 PROD1, CORING CIRC P Stop rotary P/U break off core , P/U to
195K , 10K over to break core
185K UP
CBU @ 300 GPM 1210 PSI
Max Gas = 39 units
Stand one stand back to 5,068'
5,154.0 5,068.0
1/2/2023
22:00
1/2/2023
22:45
0.75 PROD1, CORING OWFF P Flow check - static
Pump dry job , B/D top drive
190K UP
155K DN
5,068.0 5,068.0
1/2/2023
22:45
1/3/2023
00:00
1.25 PROD1, CORING TRIP P POOH F/5,068' T/4,179'
158K UP
As per CoreLab tripping schedule
5,068.0 4,179.0
1/3/2023
00:00
1/3/2023
04:45
4.75 PROD1, CORING TRIP P POOH F/4,179' T/761'
As per CoreLab schedule
4,179.0 761.0
1/3/2023
04:45
1/3/2023
05:15
0.50 PROD1, CORING OWFF P Flow check , gas expansion time
Prep ProCore handling equipment
761.0 761.0
1/3/2023
05:15
1/3/2023
07:00
1.75 PROD1, CORING TRIP P POOH stand back HWDP F/761' T/219' 761.0 219.0
1/3/2023
07:00
1/3/2023
10:00
3.00 PROD1, CORING BHAH P Break out and lay down float sub and
top sub
L/D 4" inner core barrels as per ProCore
Rep.
Core recovered this run = 178.2
Total core recovered = 392.10'
219.0 219.0
1/3/2023
10:00
1/3/2023
14:00
4.00 PROD1, CORING BHAH P Lay down outter core barrels
Clean clear rig floor - Prep pipe shed for
picking up BHA #8
219.0 0.0
1/3/2023
14:00
1/3/2023
16:15
2.25 PROD1, DRILL BHAH P PJSM - M/U BHA #8 T/490' 0.0 490.0
1/3/2023
16:15
1/3/2023
18:00
1.75 PROD1, DRILL TRIP P RIH F/490' T/2,878'
127K DN
490.0 2,878.0
1/3/2023
18:00
1/3/2023
18:45
0.75 PROD1, DRILL DHEQ P Shallow hole test MWD , calibrate
TerraSphere
500 GPM 1340 PSI , 60 RPM 4K TQ
133K UP
127K DN
127K Rot WT
Obtain SPR's
2,878.0 2,878.0
1/3/2023
18:45
1/3/2023
20:00
1.25 PROD1, DRILL TRIP P RIH F/2,878' T/4,305'
Pushing a little mud away while RIH
150K UP
140K DN
2,878.0 4,305.0
1/3/2023
20:00
1/3/2023
20:45
0.75 PROD1, DRILL WASH P Wash down F/4,305' T/4,450'
500 GPM 1550 PSI 60 RPM 5K TQ
150K Rot WT
4,305.0 4,450.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 21/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/3/2023
20:45
1/4/2023
00:00
3.25 PROD1, DRILL DLOG P Perform MADD pass F/4,450' T/4,594'
50 FPH max speed for logging data
500 GPM 1560 PSI
60 RPM 5K TQ
170K UP
145K DN
158K Rot WT
Max gas = 96 units
4,450.0 4,594.0
1/4/2023
00:00
1/4/2023
12:00
12.00 PROD1, DRILL DLOG P Perform MADD pass F/4,594' T/5,105'
50 FPH max speed for logging data
500 GPM 1520 PSI
60 RPM 6K TQ
170K Rot WT
ECD = 9.45
Max gas = 33 units
4,594.0 5,105.0
1/4/2023
12:00
1/4/2023
14:00
2.00 PROD1, DRILL DLOG P Perform MADD pass F/5,105' T/5,154'
50 FPH max speed for logging data
500 GPM 1560 PSI
60 RPM 6K TQ
180K UP
160K DN
170K Rot WT
ECD = 9.45
Max gas = 22 units
5,105.0 5,154.0
1/4/2023
14:00
1/4/2023
14:30
0.50 PROD1, DRILL CIRC P CBU @ 600 GPM 2220 PSI 60 RPM 5K
TQ
180K UP
160K DN
170K Rot WT
ECD = 9.5
Max gas = 32 units
5,154.0 5,154.0
1/4/2023
14:30
1/5/2023
00:00
9.50 PROD1, DRILL DDRL P Drill 8 3/4" hole F/5,154' T/5,560' ,
control drill at 50 FPH max for logging
605 GPM
2088 PSI
120 RPM
8K TQ on 6K off
5-10K WOB
9.69 ECD
P/U - 195K
S/O - 160K
ROT- 175K
110 Units Max Gas
AVG = 42.7 FPH W/connections
ADT= 9
Bit HRS= 27.93
Jar HRS = 50.82
5,154.0 5,560.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 22/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/5/2023
00:00
1/5/2023
00:45
0.75 PROD1, DRILL DDRL P Drill 8 3/4" hole F/5,560' T/5,600' ,
control drill at 50 FPH max for logging
605 GPM
2088 PSI
120 RPM
8K TQ on 6K off
5-10K WOB
9.69 ECD
P/U - 203K
S/O - 162K
ROT- 180K
ADT= .38
Bit HRS= 28.31
Jar HRS = 51.2
5,560.0 5,600.0
1/5/2023
00:45
1/5/2023
02:45
2.00 PROD1, EVALFM CIRC P Take final TQ and drag , final survey and
SPR's
CBU x3 at 600 GPM 1280 PSI , 120
RPM 7K TQ
ECD at start = 9.69
ECD at end = 9.61
Stand one stand back per B/U T/5,316'
5,600.0 5,316.0
1/5/2023
02:45
1/5/2023
03:15
0.50 PROD1, EVALFM OWFF P OWFF slight drop , drop 2.76" hollow
drift
5,316.0 5,316.0
1/5/2023
03:15
1/5/2023
04:00
0.75 PROD1, EVALFM TRIP P POOH F/5,316' T/4,840'
175K UP
5,316.0 4,840.0
1/5/2023
04:00
1/5/2023
04:15
0.25 PROD1, EVALFM OTHR P Pump 22 BBL 11.3 PPG dry job , blow
down top drive
4,840.0 4,840.0
1/5/2023
04:15
1/5/2023
09:00
4.75 PROD1, EVALFM TRIP P POOH F/4,840' T/214'
Flow check at shoe , slight drop
4,840.0 214.0
1/5/2023
09:00
1/5/2023
12:00
3.00 PROD1, EVALFM BHAH P L/D BHA as per SLBG 214.0 0.0
1/5/2023
12:00
1/5/2023
13:30
1.50 PROD1, EVALFM BHAH P Clean clear rig floor of SLBG BHA tools ,
load logging tools in pipe shed
0.0 0.0
1/5/2023
13:30
1/5/2023
15:45
2.25 PROD1, EVALFM ELOG P M/U APS-NGI-MSIP SLBG eline logging
BHA , bore hole imaging and sonic
logging tool
0.0 160.0
1/5/2023
15:45
1/5/2023
19:30
3.75 PROD1, EVALFM ELOG P RIH with logging tools to 3,297' ,
installing 55 WLSO's on 1st 2,541' of
eline every 25' -45'
Tag up at 3,297' , attempt to work thru
multiple times with no success
160.0 3,297.0
1/5/2023
19:30
1/5/2023
20:45
1.25 PROD1, EVALFM ELOG T POOH with eline , remove WLSO's 3,297.0 160.0
1/5/2023
20:45
1/5/2023
23:00
2.25 PROD1, EVALFM ELOG T L/D SLBG eline tools to pipe shed 160.0 0.0
1/5/2023
23:00
1/5/2023
23:30
0.50 PROD1, EVALFM BHAH T Clean floor , bring up clean out BHA
components
0.0 0.0
1/5/2023
23:30
1/6/2023
00:00
0.50 PROD1, EVALFM BHAH T M/U clean out BHA 0.0 0.0
1/6/2023
00:00
1/6/2023
02:45
2.75 PROD1, EVALFM TRIP T RIH with clean out BHA T/3,291'
123K UP
115K DN
0.0 3,291.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 23/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/6/2023
02:45
1/6/2023
03:45
1.00 PROD1, EVALFM REAM T Set DN 7K twice at 3,291' , P/U T/3,275'
Wash ream F/3,275' T/3,306' , didnt see
anything while washing and reaming
thru spot at 3,291'
CBU @ 450 GPM 720 PSI 60 RPM 4K
TQ
Nothing back on bottoms up
Drift F/3,258' T/3,306' twice clean
3,275.0 3,306.0
1/6/2023
03:45
1/6/2023
05:30
1.75 PROD1, EVALFM TRIP T RIH F/3,306' T/4,368'
At 3,357' take 3-5K DN , wipe twice and
clean
At 4,368' set down 10K
Pick up to 4,350'
146K UP
135K DN
3,306.0 4,350.0
1/6/2023
05:30
1/6/2023
08:30
3.00 PROD1, EVALFM REAM T Wash and ream F/4,350' T/4,440'
450 GPM 800PSI , 60 RPM 4K TQ
146K UP
135K DN
142K Rot WT
Pick to 4,350' , attempt drift spot at
4,368' , take WT at 4,362' , drift with
pumps only @ 450 GPM , S/O to
4,441' , back ream up , work stand until
cleaned up
4,350.0 4,350.0
1/6/2023
08:30
1/6/2023
08:45
0.25 PROD1, EVALFM TRIP T RIH F/4,350' T/4,425'
Set DN 10K at 4,425'
P/U to 4,400'
4,350.0 4,425.0
1/6/2023
08:45
1/6/2023
22:00
13.25 PROD1, EVALFM REAM T Wash and ream F/4,400' T/5,600'
450 GPM 800 PSI
60 RPM 4K TQ
At 4,413' attempt to wash and ream at
85 GPM 20 RPM , start to TQ up and
PSI up , work pipe get better circ stage
up to 450 GPM
See PSI and TQ increases at 4,509' ,
4,640' , 4,653' , 4,661' , 4,667' work thru
clean up
4,400.0 5,600.0
1/6/2023
22:00
1/7/2023
00:00
2.00 PROD1, EVALFM CIRC T Stage pumps up to 650 GPM 1640 PSI ,
120 RPM 7.5-8K TQ
Circ standing one stand back per 2 B/U
T/5,484'
168K UP
147K DN
160K Rot WT
5,600.0 5,484.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 24/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/7/2023
00:00
1/7/2023
02:15
2.25 PROD1, EVALFM CIRC T Cont to CBU standing one stand back
per 2 B/U for a total of 9 B/U T/5,293'
After 6 B/U seen increase in cuttings at
shakers , cont to circulate 2 more B/U
shakers clean up
650 GPM 1640 PSI , 120 RPM 7.5K TQ
154K Rot WT
5,484.0 5,293.0
1/7/2023
02:15
1/7/2023
02:45
0.50 PROD1, EVALFM OWFF T OWFF - slight drop , B/D top drive 5,293.0 5,293.0
1/7/2023
02:45
1/7/2023
04:30
1.75 PROD1, EVALFM TRIP T POOH F/5,293' T/5,004'
Pulled 15K over at 5,070' , wipe twice
and clean , only seen 3K down
Pulled 15K over at 5,013' , wipe twice
and gone , only seen 3K down
Pulled 25-30K over at 5,004' did not
break over , tried going down didnt
break over , grab a stand to break over
take 15K down
180K UP
150K DN
5,293.0 5,008.0
1/7/2023
04:30
1/7/2023
05:00
0.50 PROD1, EVALFM TRIP T RIH F/5,008' T/ 5,295'
Clean going down
150K DN
5,008.0 5,295.0
1/7/2023
05:00
1/7/2023
08:00
3.00 PROD1, EVALFM BKRM T Stage up pumps to 650 GPM , RPM
T/120
BROOH F/5,295' T/4,729'
650 GPM 1580 PSI
120 RPM 7K TQ
145K UP
130K DN
145K Rot WT
5,295.0 4,729.0
1/7/2023
08:00
1/7/2023
10:00
2.00 PROD1, EVALFM TRIP T POOH F/4,729' T/4,147'
At 4,679' took 20K over pull wipe clean
At 4,110' take 15K over pull
140K UP
130K DN
4,729.0 4,147.0
1/7/2023
10:00
1/7/2023
12:00
2.00 PROD1, EVALFM BKRM T BROOH F/4,147' T/3,963'
550 GPM 1030 PSI , 60 RPM 4K TQ
While staging pumps up to 650 GPM
seen 200 PSI increase in pump PSI @
4,100' , drop down clean up
130K Rot WT
4,147.0 3,963.0
1/7/2023
12:00
1/7/2023
12:15
0.25 PROD1, EVALFM OWFF T OWFF - slight drop 3,963.0 3,963.0
1/7/2023
12:15
1/7/2023
17:00
4.75 PROD1, EVALFM TRIP T POOH F/3,963' T/280' 3,963.0 280.0
1/7/2023
17:00
1/7/2023
17:15
0.25 PROD1, EVALFM OWFF T OWFF - slight drop 280.0 280.0
1/7/2023
17:15
1/7/2023
18:00
0.75 PROD1, EVALFM TRIP T POOH F/280' to surface , break off bit
and bit sub
280.0 0.0
1/7/2023
18:00
1/7/2023
18:30
0.50 PROD1, EVALFM OTHR T Clean clear rig floor of OBM for wire line
ops
0.0 0.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 25/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/7/2023
18:30
1/7/2023
19:00
0.50 PROD1, EVALFM SFTY T PJSM , make up SLB Eline tools , rig up
Eline to rig floor
0.0 0.0
1/7/2023
19:00
1/7/2023
20:15
1.25 PROD1, EVALFM ELOG T M/U NGI , PPC , MSIP SLBG eline
logging BHA , bore hole imaging and
sonic logging tool T/148' , rig up eline to
rig floor
0.0 148.0
1/7/2023
20:15
1/7/2023
23:30
3.25 PROD1, EVALFM ELOG T RIH with logging tools to 3,104' ,
installing 55 WLSO's on 1st 2,541' of
eline every 25' -45'
Tag up at 3,104' , Attempt to work thru
with no success
148.0 3,104.0
1/7/2023
23:30
1/8/2023
00:00
0.50 PROD1, EVALFM ELOG T POOH with eline , removing WLSO's
T/2,292'
3,104.0 2,292.0
1/8/2023
00:00
1/8/2023
01:30
1.50 PROD1, EVALFM ELOG T POOH with eline , removing WLSO's
F/2,292' T/148'
2,292.0 148.0
1/8/2023
01:30
1/8/2023
02:30
1.00 PROD1, EVALFM ELOG T L/D SLB Eline tools to reconfigure for
stiffness and flexibility
M/U tools NGI , PPC , MSIP for logging
148.0 148.0
1/8/2023
02:30
1/8/2023
03:30
1.00 PROD1, EVALFM ELOG T RIH with Eline tools F/148' T/3,104'
Tag up at 3,104' - attempt to work thru
with no success
148.0 3,104.0
1/8/2023
03:30
1/8/2023
06:00
2.50 PROD1, EVALFM ELOG T POOH with Eline to reconfigure and
test caliper tool for next run
3,104.0 0.0
1/8/2023
06:00
1/8/2023
06:45
0.75 PROD1, EVALFM ELOG T RIH with loggin tools T/3,105'
Tag up attempt to work thru with no
sucsses
0.0 3,105.0
1/8/2023
06:45
1/8/2023
09:00
2.25 PROD1, EVALFM ELOG T POOH with Eline to surface
R/D Elin etools , clean clear rig floor
3,105.0 0.0
1/8/2023
09:00
1/8/2023
10:30
1.50 PROD1, WHDBOP WWWH P Make up stack washer , function rams
and bag , flush stack
0.0 0.0
1/8/2023
10:30
1/8/2023
11:00
0.50 PROD1, WHDBOP OTHR P Blow down top drive , drain stack 0.0 0.0
1/8/2023
11:00
1/8/2023
12:00
1.00 PROD1, WHDBOP RURD P Pull wear ring , set test plug 0.0 0.0
1/8/2023
12:00
1/8/2023
13:30
1.50 PROD1, WHDBOP RURD P Rig up to test BOP make up FOSV to
dart valve , make up test sub to top
drive , fill stack and lines with water ,
purge air from system
0.0 0.0
1/8/2023
13:30
1/8/2023
14:30
1.00 PROD1, WHDBOP BOPE P Attempt to shell test on BOP's and
choke manifold and lines
Auto and manual IBOP's leak , remove
test sub from top drive , get good shell
test
0.0 0.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 26/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/8/2023
14:30
1/8/2023
20:30
6.00 PROD1, WHDBOP BOPE P All test BOPE with 3 1/2" and 5"" test
joints to 250 PSI low 4,000 PSI for 5
minutes each test charted. Test annular
preventer with 3 1/2" test joint to 250 psi
low and 2,500 psi high for 5 minutes
each.
Test 4" Demco kill , choke valves 1 to
14 , 3.5" x 6" VBR top and bottom
rams , blind rams , auto/manual IBOP ,
HCR kill/choke valve , manual kill/choke
valve , Dart valve , FOSV to 250 psi low
and 4,000 psi high for 5 minutes each.
Test remote and hydraulic chokes to
2,000 psi and observed pressure drop
when opening.
Accumulator drawdown:
ISP = 2975 psi
PSI after functioning = 1475 psi
200 psi rec = 28 seconds
Full system recovery = 167 seconds
4 bottles back up average = 2400 psi
Bottle pre-charge average = 1000 psi
Closing times: Annular = 16 seconds,
UPR = 7 seconds, Blind rams = 17
seconds, LPR = 7 seconds, Choke HCR
= 1 seconds, Kill HCR = 1 seconds
Test all gas alarms, PVT gain/loss, Flow
paddle
Witness waived by Brian Bixby on 1-6-
23 @ 10:12 AM HRS
Fail/Pass on manual and auto IBOP's
0.0 0.0
1/8/2023
20:30
1/8/2023
21:30
1.00 PROD1, WHDBOP RURD P Pull test plug , set wear ring 0.0 0.0
1/8/2023
21:30
1/8/2023
22:00
0.50 PROD1, WHDBOP RURD P B/D all surface equipment line up choke
manifold and mud cross on stack
0.0 0.0
1/8/2023
22:00
1/9/2023
00:00
2.00 PROD1, WHDBOP RURD T Change out auto and manual IBOP's 0.0 0.0
1/9/2023
00:00
1/9/2023
01:30
1.50 PROD1, WHDBOP RURD T Install fedder rings on quill shaft for
IBOP's , TQ to spec , install safety wire
0.0 0.0
1/9/2023
01:30
1/9/2023
02:00
0.50 PROD1, WHDBOP RURD T R/U test IBOP's 0.0 0.0
1/9/2023
02:00
1/9/2023
02:30
0.50 PROD1, WHDBOP BOPE T Test manual and auto IBOP's to
250/4000 PSI , 5 min each
0.0 0.0
1/9/2023
02:30
1/9/2023
03:00
0.50 PROD1, WHDBOP RURD T R/D testing equipment 0.0 0.0
1/9/2023
03:00
1/9/2023
04:00
1.00 PROD1, EVALFM DLOG T Prep pipe shed and rig floor for picking
up logging tools for to run on 5" DP
PJSM , P/U and make up logging tools
0.0 0.0
1/9/2023
04:00
1/9/2023
05:00
1.00 PROD1, EVALFM DLOG T Make up logging tools as per SLB T/139' 0.0 139.0
1/9/2023
05:00
1/9/2023
07:00
2.00 PROD1, EVALFM DLOG T Plug in SLB Eline to tool string , test
comms to tools
139.0 139.0
1/9/2023
07:00
1/9/2023
07:30
0.50 PROD1, EVALFM DLOG T M/U crossovers for logging tools to drill
string
139.0 139.0
1/9/2023
07:30
1/9/2023
10:00
2.50 PROD1, EVALFM DLOG T RIH F/139' T/2,853'
Fill pipe every 10 STDS
120K UP
110K DN
139.0 2,853.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 27/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/9/2023
10:00
1/9/2023
15:30
5.50 PROD1, EVALFM DLOG T Hang Eline sheave in derrick , run Eline
thru side entry sub , make up cross
overs and side entry sub to each other
M/U side entry sub and cross overs to
string , pump down eline to wet
connect , latch up confirm tools
working , install Eline clamp to side
entry sub and pull test to 3,000 pounds
Circ @ 300 GPM 100 PSI while rigging
up Eline
2,853.0 2,853.0
1/9/2023
15:30
1/9/2023
16:00
0.50 PROD1, EVALFM DLOG T RIH F/2,853' T/3,087' , Start taking
weight at 3,085' - Tag up at 3,087'
118K UP
113K DN
2,853.0 3,087.0
1/9/2023
16:00
1/9/2023
20:45
4.75 PROD1, EVALFM DLOG T Work logs down F/3,087' T/3,094'
setting DN 5K working up to 20K DN
Rack a stand back work pipe 30' in
attempt to work pipe , L/D a double of
DP , pick up pull 50' slack off in attempt
to work pipe down through spot at
3,094' with no success
118K UP
113K DN
3,087.0 3,094.0
1/9/2023
20:45
1/9/2023
21:15
0.50 PROD1, EVALFM DLOG T OWFF - POOH F/3,094' T/2,857' 3,094.0 2,857.0
1/9/2023
21:15
1/10/2023
00:00
2.75 PROD1, EVALFM DLOG T Pull Eline from wet connect , R/D Eline
and sheave from derrick and beaver
slide
Break out and lay down X/overs and
side entry sub
2,857.0 2,857.0
1/10/2023
00:00
1/10/2023
01:45
1.75 PROD1, EVALFM DLOG T POOH F/2,857' T/238' 2,857.0 238.0
1/10/2023
01:45
1/10/2023
02:30
0.75 PROD1, EVALFM DLOG T OWFF - POOH 1 stand DP
PJSM - L/D logging tools
238.0 143.0
1/10/2023
02:30
1/10/2023
04:00
1.50 PROD1, EVALFM DLOG T L/D SLB logging tools 143.0 0.0
1/10/2023
04:00
1/10/2023
05:00
1.00 PROD1, EVALFM OTHR T Clean , clear rig floor of SLB tools and
OBM
Prep pipe shed for picking up tubing
Clear out beaver slide area
0.0 0.0
1/10/2023
05:00
1/10/2023
06:30
1.50 PROD1, PLUG RURD P Rig up to run 3 1/2" TBG , bring up
power tongs , R/U hyd hoses , put 3 1/2"
elevtors on , bring up slips.
Make up X/over to floor valve
0.0 0.0
1/10/2023
06:30
1/10/2023
10:00
3.50 PROD1, PLUG PUTB P RIH W/3 1/2" 9.3# TBG T/2,192'
M/U BHKA and ACME cross over to 5"
DP
80 K DN
0.0 2,192.0
1/10/2023
10:00
1/10/2023
10:45
0.75 PROD1, PLUG CIRC P RIH one stand of 5" DP T/2,285'
Circulate to clear tubing of any depris to
keep BHKA clear @ 254 GPM 330 PSI
2,192.0 2,285.0
1/10/2023
10:45
1/10/2023
11:15
0.50 PROD1, PLUG TRIP P RIH on 5" DP F/2,285' T/3,044'
95K UP
90K DN
2,285.0 3,304.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 28/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/10/2023
11:15
1/10/2023
12:30
1.25 PROD1, PLUG WASH P Wash down F/3,304' T/3,515' as a
precaution to not pack off TBG tail @ 86
GPM 100 PSI
Take WT at 3,105' , work thru with 13K
DN and 100 PSI increase in pump
pressure
3,304.0 3,515.0
1/10/2023
12:30
1/10/2023
14:00
1.50 PROD1, PLUG TRIP P RIH F/3,515' T/5,238' , notice incorrect
hole fill make up top drive to pump , PSI
up to 675 slowly bleed off and clear ,
circulate at 89 GPM 120 PSI
119K DN
3,515.0 5,238.0
1/10/2023
14:00
1/10/2023
20:15
6.25 PROD1, PLUG WASH P Wash down F/5,238' T/5,600'
93 GPM 130 PSI
Tag up at 5,552' , work DN T/5,600'
staging pumps up to 7 BPM 560 PSI
5,238.0 5,600.0
1/10/2023
20:15
1/10/2023
21:45
1.50 PROD1, PLUG CIRC P Circulate at 7 BPM 560 PSI
138K UP
125K DN
Simops R/U to cement unit , blow air
from rig floor to cement unit , bring
CMT/plug dropping head to rig floor ,
M/U lift sub to X/over to head , load
BHKA plug in head
5,600.0 5,596.0
1/10/2023
21:45
1/10/2023
22:30
0.75 PROD1, PLUG RURD P L/D single of 5" DP , blow down top
drive , make up cement head to string ,
rig up cement hose to head for
circulating
5,596.0 5,596.0
1/10/2023
22:30
1/10/2023
23:30
1.00 PROD1, PLUG SFTY P Break circulation @ 1 BPM 210 PSI ,
stage up to 6 BPM 460 PSI
138K UP
130K DN
PJSM for cement job
5,596.0 5,597.0
1/10/2023
23:30
1/11/2023
00:00
0.50 PROD1, PLUG CMNT P Line up to cement unit , halliburton
break circ , test lines to 4500 PSI good
test
Pump 40 BBLS 10 PPG tuned spacer
5,597.0 5,597.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 29/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/11/2023
00:00
1/11/2023
01:30
1.50 PROD1, PLUG CMNT P Pump cement abandonment plug
Pump 208.1 BBLS 15.3 PPG cement
avg pump rate @ 2.7 BPM 626 PSI at
start 690 PSI final
Shut down drop BHKA dart , kick out
with 9.4 BBLS 10 PPG spacer @ 2.9
BPM 114 PSI
Chase with 9.2 PPG OBM with rig
pumps at 4.9 BPM , catch cement @
230 STKS 250 PSI , at 360 STKS 4.9
BPM 460 PSI , slow pumps down to 3
BPM @ 372 STKS 310 PSI
Dart latch up at 443 STKS PSI up F/350
T/2600 , release from BHKA
Work pipe 30' strokes while pumping
cement up until 210 BBLS pumped , no
losses during cement job or during
chase
P/U weight after release 120K loss of
18K
CIP @ 1:29
Mule shoe set depth @ 5,597' , BHKA
@ 3,406.25'
5,597.0 3,406.0
1/11/2023
01:30
1/11/2023
01:45
0.25 PROD1, PLUG CMNT P Shut in cement head , break 2" hose
off , open 2" valve on head check for
flow back up pipe
Rig down and lay down cement head
and lines
Load foam ball in drill pipe
P/U to 3,389'
3,406.0 3,389.0
1/11/2023
01:45
1/11/2023
03:00
1.25 PROD1, PLUG CIRC P Stage pumps up to 8 BPM 310 PSI
ICP ,220 FCP
118K UP
116K DN
Work pipe from 3,384' T/3,370'
Circ until clean mud back to surface
Start dumping mud at 1500 STKS ,
dump 204 BBLS to rock washer
3,389.0 3,370.0
1/11/2023
03:00
1/11/2023
03:30
0.50 PROD1, PLUG OWFF P Flow check- static
Blow down top drive and cement line
3,370.0 3,370.0
1/11/2023
03:30
1/11/2023
08:00
4.50 PROD1, PLUG TRIP P POOH F/3,370' to surface
Breaking every connection looking for
cement rings in box end
3,370.0 0.0
1/11/2023
08:00
1/11/2023
09:00
1.00 PROD1, PLUG OTHR P Clean and clear rig floor 0.0 0.0
1/11/2023
09:00
1/11/2023
09:30
0.50 PROD1, PLUG SVRG P Service drawworks , top drive 0.0 0.0
1/11/2023
09:30
1/11/2023
10:00
0.50 PROD1, PLUG RURD P R/U to run 3 1/2" TBG 0.0 0.0
1/11/2023
10:00
1/11/2023
12:00
2.00 PROD1, PLUG TRIP P RIH W/3 1/2" 9.3# EUE TBG T/1,085'
80K DN
0.0 1,085.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 30/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/11/2023
12:00
1/11/2023
13:30
1.50 PROD1, PLUG TRIP P M/U cross overs from 3 1/2" EUE to 4
1/2" IF
RIH one STD 5" DP , Circ string volume
@ 6 BPM 170 PSI
RIH F/1,176' T/2,885'
100K DN
1,085.0 2,885.0
1/11/2023
13:30
1/11/2023
14:00
0.50 PROD1, PLUG SVRG P Service topdrive , draworks and iron
roughneck
SimOps - change out air boot on flow
line in pits
2,885.0 2,885.0
1/11/2023
14:00
1/11/2023
14:45
0.75 PROD1, PLUG WASH P Wash DN F/2,885' T/3,385' at 2 BPM
130 PSI staging up to 6.5 BPM 300 PSI
108K UP
100K DN
2,885.0 3,385.0
1/11/2023
14:45
1/11/2023
17:00
2.25 PROD1, PLUG CIRC P Circulate condtion mud at 2 BPM
staging up to 6.5 BPM 110/300 PSI
108K UP
108K DN
3,385.0 3,385.0
1/11/2023
17:00
1/11/2023
17:30
0.50 PROD1, PLUG RURD P Blow down top drive , rig up head pin
and cement hose
3,385.0 3,385.0
1/11/2023
17:30
1/11/2023
19:00
1.50 PROD1, PLUG CIRC P Circulate @ 7 BPM 530 PSI , while
rigging up cementers blow air to cement
unit from rig, spot water trucks , get
cement labs confirmed
3,385.0 3,385.0
1/11/2023
19:00
1/11/2023
19:45
0.75 PROD1, PLUG SFTY P PJSM pump kick off plug while
circulating at 7 BPM 530 PSI
108K UP
108K DN
3,385.0 3,385.0
1/11/2023
19:45
1/11/2023
20:00
0.25 PROD1, PLUG CMNT P Line up to cement unit , halliburton
break circ , test lines to 4500 PSI good
test
Start batch mixing spacer get ~16 BBLS
of 10.6 PPG mixed up , have trouble
getting spacer product from tanks to
cement unit , blow down cement line to
cementers , trouble shoot problem
3,385.0 3,385.0
1/11/2023
20:00
1/12/2023
00:00
4.00 PROD1, PLUG CMNT T Find out tanks for spacer are empty ,
call town and discuss options , decide to
wait on more spacer to get to location
from Deadhorse
Circ with rig pumps @ 7 BPM 530 PSI
108K UP
108K DN
3,385.0 3,385.0
1/12/2023
00:00
1/12/2023
00:30
0.50 PROD1, PLUG CMNT T Wait on more spacer to get to location
from Deadhorse
Circ with rig pumps @ 7 BPM 530 PSI
PJSM for pumping cement
108K UP
108K DN
3,385.0 3,385.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 31/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/12/2023
00:30
1/12/2023
02:00
1.50 PROD1, PLUG CMNT P Pump kick off cement plug
Line up to cement unit
Pump 44 BBLS 10 PPG tuned spacer
Pump 62 BBLS 16.5 PPG CMT - 32.9
BBLS mix water
Pump 5 BBLS 10 PPG tuned spacer
Chase with 33.8 BBLS 336 total STKS
9.2 PPG OBM
Chase at 5 BPM 50 PSI
Slow to 3 BPM 70 PSI @ 237 STKS
Slow to 2 BPM 100 PSI @ 277 STKS
Work pipe 30' strokes while pumping
cement up until 62 BBLS CMT pumped ,
no losses during cement job or during
chase
110K UP
110K DN
Shut down , check for flow back up pipe
CIP @ 1:51 HRS
Cement wet @ 01:04 HRS
3,385.0 3,385.0
1/12/2023
02:00
1/12/2023
03:00
1.00 PROD1, PLUG TRIP P R/D CMT hose and head pin
POOH F/3,385' T/2,596' - pulling at 1100
FPH
110K UP
3,385.0 2,596.0
1/12/2023
03:00
1/12/2023
04:00
1.00 PROD1, PLUG CIRC P Load nerf ball , circ 8 BPM 390 PSI
CBU while pulling a stand T/2,501'
Cont circ 8 BPM until 9.2 ppg mud in
and out
2,596.0 2,501.0
1/12/2023
04:00
1/12/2023
05:00
1.00 PROD1, PLUG OWFF P Flow check 15 min - static, pump dry
job , blow down top drive
2,501.0 2,501.0
1/12/2023
05:00
1/12/2023
06:30
1.50 PROD1, PLUG TRIP P POOH F/2,501' T/1,085' checking
connections for cement.
2,501.0 1,085.0
1/12/2023
06:30
1/12/2023
07:00
0.50 PROD1, PLUG RURD P Break out XO's and R/U Tubing
equipment.
1,085.0 1,085.0
1/12/2023
07:00
1/12/2023
08:45
1.75 PROD1, PLUG PULD P L/D 3-1/2" tubing F/1,085'. 1,085.0 0.0
1/12/2023
08:45
1/12/2023
10:00
1.25 PROD1, PLUG RURD P R/D Tubing handling equipment. 0.0 0.0
1/12/2023
10:00
1/12/2023
11:00
1.00 PROD1, PLUG WWWH P M/U jet tool, flush BOP's and Function
while waiting on cement.
0.0 0.0
1/12/2023
11:00
1/12/2023
11:30
0.50 PROD1, PLUG CLEN P Clean rig floor while waiting on cement. 0.0 0.0
1/12/2023
11:30
1/12/2023
12:00
0.50 PROD1, PLUG SLPC P Prepare welding equipment for drill line
change out while waiting on cement.
0.0 0.0
1/12/2023
12:00
1/12/2023
18:00
6.00 PROD1, PLUG CLEN P Continue WOC F/ UCA 1000 psi Comp
strength while welding splice on old to
new drill line spool. Cleaning in pits, rig
floor drip pans/rotarty table,stream
tables, ready shed to L/D excess
HWDP, P/U tools and equip F/ BHA
components, Ready tools and
equipment for S&C drill line to new
spool.
0.0 0.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 32/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/12/2023
18:00
1/12/2023
22:30
4.50 PROD1, PLUG SLPC P PJSM. M/U top drive to stand 5" dp, RIH
to set point for S&C drlg line. Hang off
block. Prepare and slip new drlg line on
while spooling old line onto drum. Cut
off splice off between new and old line.
Spooled off all old line from drum,
Spooled on new line to drum. Total new
line used 1,750'. R/D tools and
equipment.
0.0 0.0
1/12/2023
22:30
1/12/2023
23:00
0.50 PROD1, PLUG SVRG P Rig service, calibrate block height and
weight indicator. Check COM.
0.0 0.0
1/12/2023
23:00
1/13/2023
00:00
1.00 PROD1, PLUG PULD P L/D 4 stands excess 5" HWDP from
derrick.
0.0 0.0
1/13/2023
00:00
1/13/2023
02:30
2.50 INTRM1, STK BHAH P PJSM. M/U 9-7/8" intermediate BHA
#10 as per SLB DD.
Note: Corrosion coupon installed in box
1st stand HWDP.
0.0 337.0
1/13/2023
02:30
1/13/2023
06:00
3.50 INTRM1, STK PULD P Single in p/u 72 joints 5" drill pipe to
2,609'.
337.0 2,609.0
1/13/2023
06:00
1/13/2023
09:00
3.00 INTRM1, STK CIRC P Establish circulation slowly staging up
pump rate and changing shakers
screens as required.
2,609.0 2,609.0
1/13/2023
09:00
1/13/2023
10:00
1.00 INTRM1, STK CIRC P Shallow hole test tools.
450-500 GPM
840-920 PSI
40 RPM
3K TQ
120K ROT
2,609.0 2,609.0
1/13/2023
10:00
1/13/2023
12:00
2.00 INTRM1, STK DRLG P Clean out and tag TOC at 2,806' w/5K.
Downlink and contiue drilling cement to
2,930' @ KOP depth.
450-500 GPM
840-970 PSI
60 RPM
5K TQ
119K ROT
2,609.0 2,930.0
1/13/2023
12:00
1/13/2023
16:00
4.00 INTRM1, DRILL DDRL P Sidetrack at 2,930' and directionally drill
to 3,126'. No problems getting off KOP
cement plug.
Obtain final KOP survey - good. Project
approx 8' seperation at bit.
450-500 GPM
840-970 PSI
60 RPM
5K TQ
118K ROT
2,930.0 3,126.0
1/13/2023
16:00
1/13/2023
17:00
1.00 INTRM1, DRILL BKRM P BROOH to 3080', Pump OOH to 2,887'
inside casing. Observed slight increase
in psi and hookload pulling into shoe.
Worked through 1 time then no issues.
500 GPM
970 PSI
60 RPM
5K TQ
118K ROT
124K P/U
115K S/O
3,126.0 2,887.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 33/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/13/2023
17:00
1/14/2023
00:00
7.00 INTRM1, DRILL CLEN P Circulate bottoms up until clean at
shakers. Stop pumping and OWFF -
static.
B/D top drive, continue monitoring well
while cleaning shakers and pits for
WBM displacement.
.
500 GPM
950 PSI
124K P/U
115K S/O
2,887.0 2,887.0
1/14/2023
00:00
1/14/2023
06:00
6.00 INTRM1, DRILL CLEN P Continue monitoring well while cleaning
shakers and pits for WBM displacement.
SIMOPS: Cleaning on rig floor, pipe
racks, service ST-80 and top drive.
2,887.0 2,887.0
1/14/2023
06:00
1/14/2023
12:00
6.00 INTRM1, DRILL COND P Continue monitoring well while cleaning
pits 1-5.Taking on 9.0 ppg LSND mud to
pits. SIMOPS: Adjust draworks brakes,
Mech and Elec worked on draworks
brake cooling alarm.
2,887.0 2,887.0
1/14/2023
12:00
1/14/2023
19:00
7.00 INTRM1, DRILL COND P Continue monitoring well while
preparing pits for WBM displacement.
Clean pill pits #1 & #2, Trip Tanks #1 &
#2. Build spacer train as per MI
displacement procedure.
SIMOPS: Check connections on stands
#16- #24 from derrick for cement rings
(no cement rings observed).
2,887.0 2,887.0
1/14/2023
19:00
1/14/2023
20:15
1.25 INTRM1, DRILL TRIP P PJSM for displacement. RIH and
precautionary wash down last 20' to
bottom at 3,126'. Note; At shoe took 5K
weight and at 2,920' (bottom of rat hole)
took 5K weight, rotated at 10 rpm and
worked past without any issues.
250 GPM
300 PSI
10 RPM
3K TQ
123K ROT
125K P/U
117K S/O
2,887.0 3,126.0
1/14/2023
20:15
1/14/2023
21:45
1.50 INTRM1, DRILL DISP P Displace well from NAF OBM to LSND
WBM. Pump pill train spacers consisting
of 20 bbl's LVT, 100 bbl's 11.0 ppg
transition spacer, 50 bbl's DeepClean
spacer, 35 bbl's Hi-Vis spacer.
Displaced with 9.1 ppg LSND WBM
taking OBM and spacer returns to
rockwasher. Shut down once LSND at
surface.
250-500 GPM
280-550 PSI
10-60 RPM
3-5K TQ
3,126.0 3,126.0
1/14/2023
21:45
1/14/2023
22:00
0.25 INTRM1, DRILL OWFF P OWFF - static. 3,126.0 3,126.0
1/14/2023
22:00
1/14/2023
22:30
0.50 INTRM1, DRILL TRIP P POOH on elevators with noraml drag to
shoe.
3,126.0 2,902.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 34/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/14/2023
22:30
1/15/2023
00:00
1.50 INTRM1, DRILL CLEN P Clean rig floor drip pan, flow box, pit #6
and mud pump #1 & #2 suctions.
Attempt to calibrate EcoScope with
WBM. Found Ultrasonic Caliper is
reading a stuck value. Note: Notified
WSG of tool problem. Checked with
team and decision made to go to bottom
and continue to drill without the sonic
caliper.
2,902.0 2,902.0
1/15/2023
00:00
1/15/2023
01:00
1.00 INTRM1, DRILL TRIP P RIH and precautionary wash down last
20' to bottom at 3,126'. Note; At
2,920' (bottom of rat hole) took 5K
weight, rotated at 20 rpm pumping
slowly and worked past without any
issues.
170 GPM
160 PSI
20 RPM
3K TQ
125K P/U
120K S/O
122K ROT
2,902.0 3,126.0
1/15/2023
01:00
1/15/2023
06:00
5.00 INTRM1, DRILL DDRL P Drill 9-7/8" Intermediate hole as per DD
F/3,126' T/3,695' - 2,955' TVD.
Pump Hi-Vis sweep every 500'.
700 GPM
1300 PSI
150 RPM
7K/3K TQ ON/OFF
5-10K WOB
128K P/U
120K S/O
125K ROT
10.45 ECD
ADT= 4.1
Bit HRS= 7.45
Jar HRS = 45.76
3,126.0 3,695.0
1/15/2023
06:00
1/15/2023
12:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8" Intermediate hole as per DD
F/3,695' T/4,238' - 3,098' TVD.
Pump Hi-Vis sweep every 500'.
700 GPM
1400 PSI
150 RPM
7K/3K TQ ON/OFF
8-10K WOB
132K P/U
120K S/O
125K ROT
10.67 ECD
ADT= 3.74
Bit HRS= 11.19
Jar HRS = 49.52
3,695.0 4,238.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 35/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/15/2023
12:00
1/15/2023
18:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8" Intermediate hole as per DD
F/4,238' T/4,879' - 3,264' TVD.
Pump Hi-Vis sweep every 500'.
700 GPM
1490 PSI
150 RPM
7K/3K TQ ON/OFF
8-15K WOB
137K P/U
120K S/O
125K ROT
10.67 ECD
ADT= 4.35
Bit HRS= 15.54
Jar HRS = 53.87
4,238.0 4,879.0
1/15/2023
18:00
1/16/2023
00:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8" Intermediate hole as per DD
F/4,879' T/5,535' - 3,421' TVD.
Pump Hi-Vis sweeps every 500'.
700 GPM
1560 PSI
150 RPM
7K/4K TQ ON/OFF
8-12K WOB
137K P/U
123K S/O
129K ROT
11.32 ECD
ADT= 4.66
Bit HRS= 20.2
Jar HRS = 58.53
4,879.0 5,535.0
1/16/2023
00:00
1/16/2023
06:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8" Intermediate hole as per DD
F/5,535' T/6,090' - 3,550' TVD.
Pump Hi-Vis sweeps every 500'.
700 GPM
1750 PSI
160 RPM
7K/3.5K TQ ON/OFF
10-15K WOB
143K P/U
117K S/O
132K ROT
11.8 ECD
ADT= 4.6
Bit HRS= 24.8
Jar HRS = 63.13
5,535.0 6,090.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 36/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/16/2023
06:00
1/16/2023
12:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8" Intermediate hole as per DD
F/6,090' T/6,661' - 3,687' TVD.
Pump Hi-Vis sweeps every 500'.
720 GPM
1880 PSI
150-170 RPM
7.5K/4K TQ ON/OFF
10-12K WOB
145K P/U
127K S/O
135K ROT
11.64 ECD
ADT= 4.4
Bit HRS= 29.2
Jar HRS = 67.53
6,090.0 6,661.0
1/16/2023
12:00
1/16/2023
18:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8" Intermediate hole as per DD
F/6,661' T/7,305' - 3,842' TVD.
Pump Hi-Vis sweeps every 500'.
720 GPM
1760 PSI
150-170 RPM
8K/4K TQ ON/OFF
7-12K WOB
149K P/U
129K S/O
137K ROT
11.41 ECD
ADT= 4.72
Bit HRS= 33.92
Jar HRS = 72.25
6,661.0 7,305.0
1/16/2023
18:00
1/17/2023
00:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8" Intermediate hole as per DD
F/7,305' T/8,012' - 4,008' TVD.
Pump Hi-Vis sweeps every 500'.
720 GPM
1900 PSI
150-170 RPM
8K/4K TQ ON/OFF
8-12K WOB
158K P/U
131K S/O
141K ROT
11.6 ECD
ADT= 4.75
Bit HRS= 38.67
Jar HRS = 77.0
7,305.0 8,012.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 37/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/17/2023
00:00
1/17/2023
05:30
5.50 INTRM1, DRILL DDRL P Drill 9-7/8" Intermediate hole as per DD
F/8,012' T/8,448' - 4,095' TVD at section
TD.
Pump Hi-Vis sweep every 500'.
715 GPM
2150 PSI
170 RPM
10K/5.5K TQ ON/OFF
10-15K WOB
164K P/U
129K S/O
143K ROT
11.6 ECD
ADT= 4.13
Bit HRS= 42.8
Jar HRS = 81.13
8,012.0 8,448.0
1/17/2023
05:30
1/17/2023
06:30
1.00 INTRM1, TRIPCAS CIRC P Obtain final T&D numbers, section TD
survey and SPR's.
8,448.0 8,448.0
1/17/2023
06:30
1/17/2023
08:30
2.00 INTRM1, TRIPCAS CIRC P Displace with 580 bbls clean 9.6 ppg
mud adding 4% lube staging up to 725
gpm at 1900 psi.
725 GPM
1900 PSI
150 RPM
6K TQ
8,448.0 8,448.0
1/17/2023
08:30
1/17/2023
08:45
0.25 INTRM1, TRIPCAS OWFF P OWFF - static. 8,448.0 8,448.0
1/17/2023
08:45
1/17/2023
12:00
3.25 INTRM1, TRIPCAS BKRM P BROOH circulating 1 B/U per stand for
1st 3 stands F/8,448' T/7,438'. Shakers
have had a light steady to moderate
load of cuttings and no unloading events
experienced
725 GPM
2150 PSI
1750 RPM
6K TQ
170K P/U
130K S/O
135K ROT
11.42 ECD
725 GPM
2150 PSI
1750 RPM
6K TQ
170K P/U
130K S/O
135K ROT
11.42 ECD
8,448.0 7,438.0
1/17/2023
12:00
1/17/2023
13:45
1.75 INTRM1, TRIPCAS BKRM P BROOH F/7,438' T/6,675' laying down
stands in mousehole. Cuttings
increasing at shakers.
725 GPM
1750 PSI
150 RPM
6K TQ
125K ROT
11.11 ECD
7,438.0 6,675.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 38/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/17/2023
13:45
1/17/2023
14:45
1.00 INTRM1, TRIPCAS CIRC P Circulate bottoms up until shakers
cleaned up. Hole unloaded.
725GPM
1750 PSI
150 RPM
6K TQ
125K ROT
10.98 ECD
6,675.0 6,675.0
1/17/2023
14:45
1/17/2023
18:30
3.75 INTRM1, TRIPCAS BKRM P BROOH F/6,675' T/5,410' laying down
stands in mousehole. MW in pits
decreased to 9.4 ppg. Shakers have
had a light steady to moderate load of
cuttings and no unloading events
experienced
725 GPM
1510 PSI
150 RPM
5K TQ
125K ROT
10.68 ECD
6,675.0 5,410.0
1/17/2023
18:30
1/17/2023
19:45
1.25 INTRM1, TRIPCAS CIRC P Circulate increasing MW to 9.6 ppg
in/out. Shakers had a light steady load
then cleaned up.
725GPM
1750 PSI
150 RPM
5K TQ
121K ROT
10.47 ECD
5,410.0 5,410.0
1/17/2023
19:45
1/18/2023
00:00
4.25 INTRM1, TRIPCAS BKRM P BROOH F/5,410' T/3,730' laying down
stands in mousehole. Shakers have
had a light steady to moderate load of
cuttings and no unloading events
experienced
725 GPM
1510 PSI
150 RPM
5K TQ
125K ROT
10.68 ECD
5,410.0 3,730.0
1/18/2023
00:00
1/18/2023
03:30
3.50 INTRM1, TRIPCAS BKRM P BROOH F/3,730' T/2,892' laying down
stands in mousehole. Pulled into shoe
slowly due seeing slight pack off and 5K
overpull (stabilizers and bit appear to be
balled up). Shakers have had a light
steady to moderate load of cuttings and
no unloading events experienced.
715 GPM
1200 PSI
30-150 RPM
3.5K TQ
115K ROT
10.2 ECD
3,730.0 2,892.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 39/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/18/2023
03:30
1/18/2023
04:30
1.00 INTRM1, TRIPCAS CIRC P Pump 40 BBL nut plug sweep , Circ 2
bottoms ups until shakers clean up,
observed 25% increase over shakers at
bottoms up (50% 3"-4" clay pies and
50% fines). SIMOPS: L/D 4 stands 5"
DP from derrick to shed.
725 GPM
1250 PSI
130 RPM
3.5K TQ
115K ROT
10.29 ECD
2,892.0 2,892.0
1/18/2023
04:30
1/18/2023
04:45
0.25 INTRM1, TRIPCAS OWFF P OWFF - static. 2,892.0 2,892.0
1/18/2023
04:45
1/18/2023
06:00
1.25 INTRM1, TRIPCAS PULD P POOH laying down 5" drill pipe F/2,892'
T/2,668'. Observed well swabbing.
2,892.0 2,668.0
1/18/2023
06:00
1/18/2023
08:30
2.50 INTRM1, TRIPCAS TRIP P Pumped OOH F/2,668' T/1,750' laying
down pipe in mousehole.
700 GPM
1120 PSI
115K P/U
105K S/O
2,668.0 1,750.0
1/18/2023
08:30
1/18/2023
09:45
1.25 INTRM1, TRIPCAS TRIP P POOH laying down 5" drill pipe F/1,750'
T/1,284'. Observed well swabbing.
1,750.0 1,284.0
1/18/2023
09:45
1/18/2023
12:00
2.25 INTRM1, TRIPCAS TRIP P Pumped OOH F/1,284' T/337' laying
down pipe in mousehole.
715 GPM
920 PSI
80K P/U
80K S/O
1,284.0 337.0
1/18/2023
12:00
1/18/2023
12:30
0.50 INTRM1, TRIPCAS OWFF P OWFF - Static. PJSM for laying down
BHA.
337.0 337.0
1/18/2023
12:30
1/18/2023
13:15
0.75 INTRM1, TRIPCAS BHAH P POOH laying down 5" HWDP and Jars. 337.0 152.0
1/18/2023
13:15
1/18/2023
15:00
1.75 INTRM1, TRIPCAS BHAH P Lay down BHA as per SLB DD. 152.0 0.0
1/18/2023
15:00
1/18/2023
15:30
0.50 INTRM1, TRIPCAS CLEN P Clean and clear excess tools and
equipment from floor.
0.0 0.0
1/18/2023
15:30
1/18/2023
17:15
1.75 INTRM1, CASING WWWH P Make up stack wash tool on single and
ran 2 stands from derrick to be flushed
from OBM, flush stack 400 GPM 100
PSI. B/D top drive, lay down pipe and
wash tool.
0.0 0.0
1/18/2023
17:15
1/18/2023
18:00
0.75 INTRM1, CASING BOPE P Pull wear bushing as per Cameron Rep.
L/D 2 joints 5" drill pipe.
0.0 0.0
1/18/2023
18:00
1/18/2023
19:45
1.75 INTRM1, CASING BOPE P Change out upper VBR rams to 7 5/8"
solid body rams. SIMOPS: P/U Sonic
Scopes (2 ea) and soft break crossovers
(received torqued from town) to allow
batteries to be loaded so tools can be
checked offline. P/U Cameron hanger
assy to floor - drifted to 6.75".
0.0 0.0
1/18/2023
19:45
1/18/2023
21:45
2.00 INTRM1, CASING BOPE P Set test plug as per Cameron Rep and
R/U 7-5/8" test joint to test. Test 7 5/8"
rams to 250/4000 PSI 5 min each.
Charted test. R/D test equipment.
Note: Test witnessed waived by AOGCC
Sean Sullivan on 1-17-23 @ 11:27 AM.
0.0 0.0
1/18/2023
21:45
1/18/2023
22:30
0.75 INTRM1, CASING BOPE P R/D 7-5/8" test equipment. L/D test joint,
xo, and pup joint.
0.0 0.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 40/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/18/2023
22:30
1/19/2023
00:00
1.50 INTRM1, CASING RURD P R/U 7-5/8" casing running tools and
equipment, 7-5/8" Volant CRT, bail
extensions, 7-5/8" side door elevators
and spider slips.
0.0 0.0
1/19/2023
00:00
1/19/2023
01:30
1.50 INTRM1, CASING RURD P Finish R/U 7-5/8" casing running tools
and equipment, 7-5/8" Volant CRT, bail
extensions, 7-5/8" side door elevators
and spider slips. PJSM for running
casing.
0.0 0.0
1/19/2023
01:30
1/19/2023
02:00
0.50 INTRM1, CASING PUTB P Run 7-5/8" shoe track jts and crossover
jts (baker loc connections), check floats
- ok.
39# HYD563 TQ - 19,300 ft/lbs
29.7# HYD563 TQ - 10,300 ft/lbs
0.0 171.0
1/19/2023
02:00
1/19/2023
07:45
5.75 INTRM1, CASING PUTB P Run 7-5/8" running casing as per detail
F/171' T/2,890'.
39# HYD563 TQ - 19,300 ft/lbs (total 13
jts + 2 XO jt's)
29.7# HYD563 TQ - 10,300 ft/lbs
171.0 2,890.0
1/19/2023
07:45
1/19/2023
09:00
1.25 INTRM1, CASING CIRC P CBU staging to 5 bpm at shoe. On
bottoms small amout of fines seen at
shakers.
210 GPM
175 PSI
130K P/U
125K S/O
2,890.0 2,890.0
1/19/2023
09:00
1/19/2023
10:00
1.00 INTRM1, CASING PUTB P Run 7-5/8" running casing as per detail
F/2,890' T/2,912'. Taking weight F/2,912
T/2,930' up to 15K (At KOP). Washed
at 2 bpm with 130 psi, worked through
staging WOB to 34K to get past (no psi
increase and no overpull when p/u).
29.7# HYD563 TQ - 10,300 ft/lbs
2,890.0 2,930.0
1/19/2023
10:00
1/19/2023
12:00
2.00 INTRM1, CASING PUTB P Run 7-5/8" running casing as per detail
F/2,930' T/3,689'.
29.7# HYD563 TQ - 10,300 ft/lbs
2,930.0 3,689.0
1/19/2023
12:00
1/19/2023
15:45
3.75 INTRM1, CASING PUTB P Run 7-5/8" running casing as per detail
F/3,689' T/5,405'.
29.7# HYD563 TQ - 10,300 ft/lbs
3,689.0 5,405.0
1/19/2023
15:45
1/19/2023
17:45
2.00 INTRM1, CASING CIRC P CBU x 2 staging up to 6 bpm at base
C50. On bottoms small amout of fines
seen at shakers.
252 GPM
170 PSI
147K P/U
128K S/O
5,405.0 5,405.0
1/19/2023
17:45
1/19/2023
23:30
5.75 INTRM1, CASING PUTB P Run 7-5/8" running casing as per detail
F/5,405' T/7,484'. Decreased running
speed and returns continued decreasing
on last 10 joints.
29.7# HYD563 TQ - 10,300 ft/lbs
5,405.0 7,484.0
1/19/2023
23:30
1/20/2023
00:00
0.50 INTRM1, CASING CIRC P CBU staging up to 4 bpm.
168 GPM
420 PSI
158K P/U
131K S/O
7,484.0 7,484.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 41/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/20/2023
00:00
1/20/2023
00:45
0.75 INTRM1, CASING CIRC P Finish CBU staging to 6 bpm. Shakers
clean on bottoms up.
252 GPM
467 PSI
158K P/U
131K S/O
7,484.0 7,484.0
1/20/2023
00:45
1/20/2023
03:15
2.50 INTRM1, CASING PUTB P Run 7-5/8" running casing as per detail
F/7,484' T/8,401'. Washed down last 2
joints pumping 2 bpm at 380 psi.
29.7# HYD563 TQ - 10,300 ft/lbs
7,484.0 8,401.0
1/20/2023
03:15
1/20/2023
04:00
0.75 INTRM1, CASING PUTB P P/U Cameron 7-5/8" Casing Hanger and
7-5/8" landing joint. RIH to setting depth
at 8,438' pumping 2 bpm and land in
wellhead.
135K S/O
8,401.0 8,438.0
1/20/2023
04:00
1/20/2023
06:15
2.25 INTRM1, CEMENT CIRC P Circulate staging up to 6 bpm while
reciprocating with no losses.
252 GPM
470 PSI
165K P/U
130K S/O
8,438.0 8,438.0
1/20/2023
06:15
1/20/2023
06:45
0.50 INTRM1, CEMENT OWFF P OWFF - static. SIMOPS: B/D top drive
and R/U cement lines and chart.
8,438.0 8,438.0
1/20/2023
06:45
1/20/2023
09:00
2.25 INTRM1, CEMENT CIRC P Circulate and condition mud at 6 bpm
with 570 psi while preparing to cement.
8,438.0 8,438.0
1/20/2023
09:00
1/20/2023
12:30
3.50 INTRM1, CEMENT CMNT P PJSM. Cement 7 5/8" casing as per
Halliburton program. Flood lines test
trips and test lines to 4000 psi. Drop 1st
bottom wiper plug , pump 62 bbls 12.5
ppg spacer with BMII @ 3 bpm 327 psi
while working pipe 174K P/U 140K S/O.
Drop 2nd bottom wiper plug, pump 46
bbls 15.3 ppg cement with BMII followed
by 23 bbls 15.3 ppg cement without
BMII at 2.3 bpm, 100 psi while working
pipe 182K P/U 151K S/O. Drop top plug,
Halliburton pumped 10 bbls water.
Displaced using rig pump with 375 bbls
9.6 ppg mud at 6 bpm, ICP 475 psi, FCP
815 psi, slowing to 3 bpm last 10 bbls.
Bump plugs and pressure up to 1315
psi, held for 5 min. bleed off and floats
held, CIP @ 11:50 hrs 1-20-23 Note:
Casing was worked until 360 bbls into
displacement, Shoe @ 8,438' ,Float
Collar @ 8,348'.
8,438.0 8,438.0
1/20/2023
12:30
1/20/2023
14:00
1.50 INTRM1, CEMENT PRTS P Test 7-5/8" casing to 4,000 psi w/9.6
ppg mud for 30 minutes. Charted test.
Pumped 5.9 bbls and bled off 5.9 bbls.
B/D and R/D lines.
8,438.0 8,438.0
1/20/2023
14:00
1/20/2023
15:00
1.00 INTRM1, CEMENT RURD P Pull 7-5/8" landing joint, drain stack and
M/U pack-off running tool.
8,438.0 8,438.0
1/20/2023
15:00
1/20/2023
16:00
1.00 INTRM1, CEMENT WWSP P Set 7 5/8" pack off as per Cameron
Rep , test to 5000 PSI F/10 min , good
test. SIMOPS: Clean valve on manifold,
L/D casing equipment, and loading 4"
DP in shed.
8,438.0 8,438.0
1/20/2023
16:00
1/20/2023
17:00
1.00 INTRM1, CEMENT PULD P L/D landing joint and 5" handling
equipment, preparing to change rams.
8,438.0 8,438.0
1/20/2023
17:00
1/20/2023
19:00
2.00 INTRM1, WHDBOP BOPE P Change out upper rams from 7 5/8" to 3
1/2" x 6" VBR SIMOPS: Off load and
cleaning pits and loading 4" DP in shed.
8,438.0 8,438.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 42/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/20/2023
19:00
1/20/2023
22:00
3.00 INTRM1, WHDBOP RURD P Change out handling equipment from 5"
to 4". Change out saver sub on top drive
to 4" XT39 and grabber dies to 4".
SIMOPS: loading 4" 14# drill pipe to
pipe shed.
8,438.0 8,438.0
1/20/2023
22:00
1/21/2023
00:00
2.00 INTRM1, WHDBOP PULD P L/D 25 stands 5" DP from derrick to pipe
shed. SIMOPS: Replaced MWD SPT
sensor on standpipe gooseneck.
8,438.0 8,438.0
1/21/2023
00:00
1/21/2023
01:30
1.50 INTRM1, WHDBOP PULD P Finish L/D 25 stands 5" DP from derrick
to pipe shed.
0.0 0.0
1/21/2023
01:30
1/21/2023
04:00
2.50 INTRM1, WHDBOP BOPE P Make up and set test plug as per
Cameron , fill stack , choke manifold ,
lines with water. Rig up testing
equipment , pump air our of system
shell test BOP good. SIMOPS: Cleaning
pits and working on mud pumps.
0.0 0.0
1/21/2023
04:00
1/21/2023
09:15
5.25 INTRM1, WHDBOP BOPE P All test BOPE with 4" and 4-1/2" test
joints to 250 PSI low 4,000 PSI for 5
minutes each test charted. Test annular
preventer with 4" test joint to 250 psi low
and 2,500 psi high for 5 minutes each.
Test 4" Demco kill, choke valves 1 to 14,
3.5" x 6" VBR top and bottom rams,
blind rams, auto IBOP, HCR kill valve,
manual choke valve, IBOP, FOSV to
250 psi low and 4,000 psi high for 5
minutes each. Test remote and hydraulic
chokes to 2,000 psi and observed
pressure drop when opening. Test all
gas alarms, remote panel, PVT
gain/loss, flow paddle
Accumulator drawdown: ISP = 2,850 psi
PSI after functioning = 1,450 psi 200 psi
rec = 32 seconds Full system recovery =
166 seconds 4 bottles back up average
= 2,325 psi Bottle precharge average =
1,000 psi Closing times: Annular = 22
seconds, UPR = 7 seconds, LPR = 7
seconds, Blinds = 15 seconds, Choke
HCR = 1 second, Kill HCR = 1 second.
Note: AOGCC, Austin McLeod waived
wittnessing BOP test on 1-20-2023 at
17:48 hrs.
0.0 0.0
1/21/2023
09:15
1/21/2023
12:00
2.75 INTRM1, WHDBOP MPDA P Test MPD lines to 300 psi / 1,250 psi -
held 5/5 minutes - good test. Pull test
plug.
0.0 0.0
1/21/2023
12:00
1/21/2023
12:45
0.75 INTRM1, WHDBOP MPDA P R/D MPD test equipment. Set trip
nipple. B/D choke skid, choke and kill
lines.
0.0 0.0
1/21/2023
12:45
1/21/2023
13:45
1.00 INTRM1, WHDBOP BOPE P Pull Cameron test plug and set wear
bushing as per Cameron rep. Wear
Bushing ID = 10".
0.0 0.0
1/21/2023
13:45
1/21/2023
15:00
1.25 INTRM1, WHDBOP BHAH P Mobolize BHA componets to rig floor,
strap and tally 4" DP.
0.0 0.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 43/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/21/2023
15:00
1/21/2023
16:15
1.25 INTRM1, WHDBOP FRZP P Freeze protect 10-3/4" X 7-5/8" annulus.
Pressure test lines to 2500 psi, good.
Pump 82 bbls of diesel. Initial annular
pressure 15 psi. Pump 3 bbls to observe
pressure break over at 749 psi, pumping
at 0.5 bpm. Continue pumping in at 0.5
bpm to 5 bbls away to observe injection.
Increase rate to 1-2 bpm continuing to
pump 82 bbls with a final injection
pressure of 779 psi. Final shut in
pressure 710 psi. Secure annulus & rig
down lines. SIMOPS pick up and rack
back 9 stands 4" DP in the derrick.
0.0 0.0
1/21/2023
16:15
1/21/2023
17:30
1.25 INTRM1, DRILLOUT SVRG P Service top drive while arranging BHA in
pipe shed.
0.0 0.0
1/21/2023
17:30
1/21/2023
21:15
3.75 INTRM1, DRILLOUT BHAH P Pick up and make up 6-1/2" production
drilling BHA #11 as per directional driller.
0.0 440.0
1/21/2023
21:15
1/22/2023
00:00
2.75 INTRM1, DRILLOUT PULD P Run in the hole with 6-1/2" production
BHA #11 picking up 4" drill pipe singles
to 1,574'. Filling every 15 stands with
mud. Drifting to 2.5".
80K S/O
440.0 1,574.0
1/22/2023
00:00
1/22/2023
03:45
3.75 INTRM1, DRILLOUT PULD P Run in the hole with 6-1/2" production
BHA #11 picking up 4" drill pipe singles
F/1,574' T/3,463'. Filling every 15 stands
with mud. Drifting to 2.5".
95K S/O
1,574.0 3,463.0
1/22/2023
03:45
1/22/2023
04:00
0.25 INTRM1, DRILLOUT CIRC P Shallow test MWD tools good test ,
down link turn on Sonic Scope for
MADD pass logging.
250 GPM
1660 PSI
3,463.0 3,463.0
1/22/2023
04:00
1/22/2023
12:00
8.00 INTRM1, DRILLOUT PULD P Run in the hole with 6-1/2" production
BHA #11 picking up 4" drill pipe singles
F/3,463' T/7,339' for MADD pass
logging with Sonic. Filling every 15
stands with mud. Drifting to 2.5".
3,463.0 7,339.0
1/22/2023
12:00
1/22/2023
14:45
2.75 INTRM1, DRILLOUT PULD P Run in the hole with 6-1/2" production
BHA #11 picking up 4" drill pipe singles
F/7,339' T/8,185' for MADD pass
logging with Sonic. Filling every 15
stands with mud. Drifting to 2.5".
7,339.0 8,185.0
1/22/2023
14:45
1/22/2023
15:00
0.25 INTRM1, DRILLOUT CIRC P Stage pump up and downlink to turn off
Sonic tool to preserve battery life.
8,185.0 8,185.0
1/22/2023
15:00
1/22/2023
17:45
2.75 INTRM1, DRILLOUT MPDA P Pull trip nipple, install RCD bearing.
Calibrate ramp schedule on both chokes
on MPD. Verify coriolis meter, rack back
stand with RCD bearing. Re-installed
trip nipple and B/D top drive. SIMOPS:
MPD blew down all lines.
8,185.0 8,185.0
1/22/2023
17:45
1/22/2023
19:30
1.75 INTRM1, DRILLOUT SLPC P Slip and cut 38' drlg line. Calibrate hook
load and block height.
8,185.0 8,185.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 44/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/22/2023
19:30
1/22/2023
20:45
1.25 INTRM1, DRILLOUT TRIP P Wash in the hole with 6-1/2" production
BHA #11 F/8,185' T/8,345' (tagged) for
MADD pass logging with Sonic.
220 GPM
1770 PSI
30 RPM
5K TQ
114K ROT
10.8 ECD
8,185.0 8,345.0
1/22/2023
20:45
1/23/2023
00:00
3.25 INTRM1, DRILLOUT DRLG P Drill cement, wiper plugs and float
equipment from 8,345' to 8,437' at shoe.
120-220 GPM
1800 PSI
40-60 RPM
6-7K TQ
5-10K WOB
130K P/U
100K S/O
114K ROT
8,345.0 8,437.0
1/23/2023
00:00
1/23/2023
01:00
1.00 INTRM1, DRILLOUT DRLG P Drill out shoe, clean out rat hole to
bottom at 8,448'.
220 GPM
1800 PSI
80 RPM
7K TQ
220 GPM
1800 PSI
80 RPM
7/5K TQ ON/OFF
1-5K WOB
8,437.0 8,448.0
1/23/2023
01:00
1/23/2023
01:30
0.50 INTRM1, DRILLOUT DDRL P Drill 20' new formation from 8,448' to
8,468'.
250 GPM
2250 PSI
80 RPM
5-8K TQ OFF/ON
8K WOB
10.87 ECD
ADT: 0.33 hrs
BIT: 0.33 hrs
8,448.0 8,468.0
1/23/2023
01:30
1/23/2023
03:00
1.50 INTRM1, DRILLOUT CIRC P Pull into shoe with no issues. Cleaned
out shoe with 3 passes. Circulate and
condition mud to 9.5 ppg in/out for
FIT/LOT. .
220 GPM
1800 PSI
80 RPM
6K TQ
10.56 ECD
8,374.0 8,374.0
1/23/2023
03:00
1/23/2023
03:30
0.50 INTRM1, DRILLOUT OWFF P OWFF - static. SIMOPS: B/D top drive
and R/U for FIT.
8,374.0 8,374.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 45/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/23/2023
03:30
1/23/2023
04:00
0.50 INTRM1, DRILLOUT FIT P Rig up for FIT/ LOT testing equipment,
circulate through lines to purge air, close
UPR rams Perform FIT/LOT test as per
procedure. Used #1 mud pump pumping
0.5 bbl increments to test pressure of
723 psi, 12.9 ppg EMW. Note: Observed
leak off and pumped 2 bbls additional.
total 3.2 bbls pumped Initial SIP: 411
psi, Final SIP: 213 psi, 198 psi loss over
10 minutes. Bled off and record 0.9 bbls
bled back.
8,374.0 8,374.0
1/23/2023
04:00
1/23/2023
06:45
2.75 PROD1, DRILL CIRC P Pumped 35 bbls 9.6 ppg spacer and
displaced to 9.5 ppg Kla-Shield mud at
220 gpm.
220 GPM
80 RPM
6K TQ
131K P/U
100K S/O
115K ROT
8,374.0 8,374.0
1/23/2023
06:45
1/23/2023
07:15
0.50 PROD1, DRILL OWFF P OWFF - static. SIMOPS: PJSM on
installing RCD bearing.
8,374.0 8,374.0
1/23/2023
07:15
1/23/2023
08:00
0.75 PROD1, DRILL MPDA P Pull trip nipple and install RCD bearing. 8,374.0 8,374.0
1/23/2023
08:00
1/23/2023
09:00
1.00 PROD1, DRILL WASH P Precautionary wash and ream F/8,374'
T/8,468'.
220 GPM
1550 PSI
80 RPM
8K TQ
8,374.0 8,468.0
1/23/2023
09:00
1/23/2023
12:00
3.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole
F/8,468' T/8,637' while maintaining
drilling EMW on connections with MPD.
250 GPM
1880 PSI
80 RPM
7/5K TQ ON/OFF
5K WOB
132K P/U
85K S/O
117K ROT
10.72 ECD
168 units MAX GAS
ADT= 2.7
Bit HRS= 2.7
8,468.0 8,637.0
1/23/2023
12:00
1/23/2023
18:00
6.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole
F/8,637' T/9,065' while maintaining
drilling EMW on connections with MPD.
262 GPM
2155 PSI
80 RPM
7/5K TQ ON/OFF
5K WOB
140K P/U
90K S/O
113K ROT
10.86 ECD
1465 units MAX GAS
ADT= 4.99
Bit HRS= 7.69
8,637.0 9,065.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 46/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/23/2023
18:00
1/24/2023
00:00
6.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole
F/9,065' T/9,512' while maintaining
drilling EMW on connections with MPD.
262 GPM
2250 PSI
80 RPM
7/5K TQ ON/OFF
8K WOB
140K P/U
86K S/O
109K ROT
10.86 ECD
971 units MAX GAS
ADT= 4.9
Bit HRS= 12.59
9,065.0 9,512.0
1/24/2023
00:00
1/24/2023
06:00
6.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole at
100 fph for log data F/9,512'
T/9,967'MD / 4,209'TVD while
maintaining drilling EMW on
connections with MPD.
260 GPM
2320 PSI
150 RPM
7.5/5K TQ ON/OFF
7K WOB
141K P/U
85K S/O
114K ROT
11.26 ECD
635 units MAX GAS
ADT= 4.43
Bit HRS= 17.02
9,512.0 9,967.0
1/24/2023
06:00
1/24/2023
12:00
6.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole at
100 fph for log data F/9,967'
T/10,417'MD / 4,207'TVD while
maintaining drilling EMW on
connections with MPD.
260 GPM
2390 PSI
150 RPM
7/5K TQ ON/OFF
6K WOB
142K P/U
80K S/O
114K ROT
11.3 ECD
974 units MAX GAS
ADT= 4.8
Bit HRS= 21.82
9,967.0 10,417.0
1/24/2023
12:00
1/24/2023
14:00
2.00 PROD1, DRILL RGRP T While on bottom drilling rig lost power.
Trouble shoot and re-energize power on
generators while monitoring well. Found
fuses to PFC blown.
Note: Rig Off Hi-Line Power at 12:00
hrs.
10,417.0 10,417.0
1/24/2023
14:00
1/24/2023
16:00
2.00 PROD1, DRILL RGRP T Establish circulation and reciprocate
pipe while rebooting MWD
communications.
262 GPM
2375 PSI
150 RPM
5K TQ
114K ROT
10,417.0 10,417.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 47/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/24/2023
16:00
1/24/2023
18:00
2.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole at
100 fph for log data F/10,417'
T/10,705'MD / 4,202'TVD while
maintaining drilling EMW on
connections with MPD.
262 GPM
2375 PSI
150 RPM
6.5/5K TQ ON/OFF
4-8K WOB
141K P/U
80K S/O
112K ROT
11.43 ECD
630 units MAX GAS
ADT= 2.94
Bit HRS= 24.76
10,417.0 10,705.0
1/24/2023
18:00
1/25/2023
00:00
6.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole at
100 fph for log data F/10,705'
T/11,113'MD / 4,208'TVD while
maintaining drilling EMW on
connections with MPD.
262 GPM
2380 PSI
150 RPM
6.5/5K TQ ON/OFF
4-8K WOB
142K P/U
80K S/O
110K ROT
11.37 ECD
885 units MAX GAS
ADT= 4.22
Bit HRS= 28.98
10,705.0 11,113.0
1/25/2023
00:00
1/25/2023
06:00
6.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole at
100 fph for log data F/11,113'
T/11,576'MD / 4,191'TVD while
maintaining drilling EMW on
connections with MPD.
Note: MicroScope gamma ray started
working again at 11,272'.
260 GPM
2470 PSI
150 RPM
7/5K TQ ON/OFF
5-10K WOB
140K P/U
85K S/O
114K ROT
11.59 ECD
855 units MAX GAS
ADT= 4.92
Bit HRS= 33.9
11,113.0 11,576.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 48/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/25/2023
06:00
1/25/2023
12:00
6.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole at
100 fph for log data F/11,576'
T/11,993'MD / 4,190'TVD while
maintaining drilling EMW on
connections with MPD.
Note: ODS top drive blower motor
tripped off just prior to swapping back to
Hi-Line power at 10:30 hrs. Ambient
temperature keeping temperature within
operating range.
260 GPM
2530 PSI
150 RPM
7/5.5K TQ ON/OFF
7K WOB
140K P/U
80K S/O
114K ROT
11.64 ECD
960 units MAX GAS
ADT= 4.36
Bit HRS= 38.26
11,576.0 11,993.0
1/25/2023
12:00
1/25/2023
18:00
6.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole at
100 fph for log data F/11,993'
T/12,447'MD / 4,188'TVD while
maintaining drilling EMW on
connections with MPD.
262 GPM
2505 PSI
130 RPM
6.8/6K TQ ON/OFF
5K WOB
138K P/U
83K S/O
108K ROT
11.58 ECD
704 units MAX GAS
ADT= 5.02
Bit HRS= 43.28
11,993.0 12,447.0
1/25/2023
18:00
1/26/2023
00:00
6.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole at
100 fph for log data F/12,447'
T/12,921'MD / 4,190'TVD while
maintaining drilling EMW on
connections with MPD.
262 GPM
2560 PSI
130 RPM
7.2/6K TQ ON/OFF
8K WOB
138K P/U
82K S/O
109K ROT
11.7 ECD
810 units MAX GAS
ADT= 4.8
Bit HRS= 48.08
12,447.0 12,921.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 49/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/26/2023
00:00
1/26/2023
03:15
3.25 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole at
100 fph for log data F/12,921'
T/13,195'MD / 4,194'TVD while
maintaining drilling EMW on
connections with MPD.
260 GPM
2650 PSI
130 RPM
7/6.5K TQ ON/OFF
7K WOB
140K P/U
95K S/O
115K ROT
11.86 ECD
650 units MAX GAS
ADT= 3.8
Bit HRS= 50.8
12,921.0 13,195.0
1/26/2023
03:15
1/26/2023
04:15
1.00 PROD1, DRILL CIRC T Circulate and reciropicate rotating 15
rpm letting ODS top drive motor
temperature decrease. Note: Blower not
working.
260 GPM
2650 PSI
15 RPM
7/5K TQ ON/OFF
13,195.0 13,195.0
1/26/2023
04:15
1/26/2023
06:00
1.75 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole at
100 fph for log data F/13,195'
T/13,338'MD / 4,196'TVD while
maintaining drilling EMW on
connections with MPD.
260 GPM
2650 PSI
130 RPM
7/6.5K TQ ON/OFF
7K WOB
140K P/U
95K S/O
115K ROT
11.86 ECD
650 units MAX GAS
ADT= 1.49
Bit HRS= 52.37
13,195.0 13,338.0
1/26/2023
06:00
1/26/2023
09:00
3.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole at
100 fph for log data F/13,338'
T/13,500'MD / 4,197'TVD while
maintaining drilling EMW on
connections with MPD.
260 GPM
2670 PSI
130 RPM
7/6K TQ ON/OFF
10K WOB
140K P/U
90K S/O
114K ROT
11.88 ECD
943 units MAX GAS
ADT= 2.02
Bit HRS= 54.39
13,338.0 13,500.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 50/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/26/2023
09:00
1/26/2023
10:00
1.00 PROD1, DRILL CIRC T Circulate b/u. SIMOPS: Preparing to
change out ODS top drive blower motor.
260 GPM
2670 PSI
120 RPM
7K TQ
13,500.0 13,478.0
1/26/2023
10:00
1/26/2023
10:30
0.50 PROD1, DRILL SVRG P Service rig. SIMOPS: Changing out
ODS top drive blower motor that is
seized up.
260 GPM
2670 PSI
13,478.0 13,478.0
1/26/2023
10:30
1/26/2023
11:45
1.25 PROD1, DRILL RGRP T Changing out ODS top drive blower
motor.
90 GPM
750 PSI
10 RPM
6.5K TQ
113K ROT
13,478.0 13,478.0
1/26/2023
11:45
1/26/2023
12:00
0.25 PROD1, DRILL CIRC P Precautionary wash and ream F/13,478'
T/13,500'
260 GPM
2630 PSI
130 RPM
6.5K TQ
13,478.0 13,500.0
1/26/2023
12:00
1/26/2023
18:00
6.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole at
100 fph for log data F/13,500'
T/13,923'MD / 4,204'TVD while
maintaining drilling EMW on
connections with MPD.
262 GPM
2780 PSI
150 RPM
8/7K TQ ON/OFF
5/6K WOB
143K P/U
88K S/O
115K ROT
11.96 ECD
925 units MAX GAS
ADT= 4.3
Bit HRS= 59.02
13,500.0 13,923.0
1/26/2023
18:00
1/27/2023
00:00
6.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole at
100 fph for log data F/13,923'
T/14,408'MD / 4,215'TVD while
maintaining drilling EMW on
connections with MPD.
262 GPM
2780 PSI
150 RPM
8/7K TQ ON/OFF
5/6K WOB
148K P/U
91K S/O
117K ROT
11.98 ECD
892 units MAX GAS
ADT= 4.94
Bit HRS= 63.96
13,923.0 14,408.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 51/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/27/2023
00:00
1/27/2023
06:00
6.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole at
100 fph for log data F/14,408'
T/14,865'MD / 4,224'TVD while
maintaining drilling EMW on
connections with MPD.
260 GPM
3000 PSI
150 RPM
7/6.5K TQ ON/OFF
5K WOB
153K P/U
100K S/O
125K ROT
12.1 ECD
700 units MAX GAS
ADT= 4.68
Bit HRS= 68.64
14,408.0 14,865.0
1/27/2023
06:00
1/27/2023
12:00
6.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole at
100 fph for log data F/14,865'
T/15,315'MD / 4,231'TVD while
maintaining drilling EMW on
connections with MPD.
262 GPM
3020 PSI
150 RPM
8/7K TQ ON/OFF
5K WOB
158K P/U
100K S/O
127K ROT
12.17 ECD
875 units MAX GAS
ADT= 4.62
Bit HRS= 73.26
14,865.0 15,315.0
1/27/2023
12:00
1/27/2023
18:00
6.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole at
100 fph for log data F/15,315'
T/15,806'MD / 4,238'TVD while
maintaining drilling EMW on
connections with MPD.
262 GPM
3113 PSI
150 RPM
9/8K TQ ON/OFF
5K WOB
162K P/U
102K S/O
131K ROT
12.20 ECD
1000 units MAX GAS
ADT= 4.95
Bit HRS= 78.21
15,315.0 15,806.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 52/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/27/2023
18:00
1/28/2023
00:00
6.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole at
100 fph for log data F/15,806'
T/16,237'MD / 4,242'TVD while
maintaining drilling EMW on
connections with MPD.
Note: Decreased rop from 100 fph to 50
fph from 16,200' to 16,237' for log data.
262 GPM
3262 PSI
150 RPM
9/8K TQ ON/OFF
5K WOB
170K P/U
105K S/O
135K ROT
12.36 ECD
579 units MAX GAS
ADT= 5.07
Bit HRS= 83.28
15,806.0 16,237.0
1/28/2023
00:00
1/28/2023
04:45
4.75 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole at
100 fph for log data F/16,237'
T/16,400'MD / 4,242'TVD while
maintaining drilling EMW on
connections with MPD.
Note: Decreased rop from 100 fph to 50
fph from 16,200' to 16,400' for log data.
266 GPM
3260 PSI
150 RPM
9.9/8K TQ ON/OFF
5K WOB
168K P/U
105K S/O
142K ROT
12.51 ECD
339 units MAX GAS
ADT= 3.35
Bit HRS= 86.63
16,237.0 16,400.0
1/28/2023
04:45
1/28/2023
06:00
1.25 PROD1, DRILL MPDA T Observed pressure increasing on MPD
choke gauge. B/D top drive.
Troubleshoot choke manifold lines and
sensors. Found pressure sensor #3
froze up. Replaced sensor.
16,400.0 16,400.0
1/28/2023
06:00
1/28/2023
12:00
6.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole at
100 fph for log data F/16,400'
T/16,804'MD / 4,253'TVD while
maintaining drilling EMW on
connections with MPD.
262 GPM
3260 PSI
150 RPM
10.5/8.2K TQ ON/OFF
10K WOB
172K P/U
106K S/O
142K ROT
12.55 ECD
209 units MAX GAS
ADT= 4.61
Bit HRS= 91.24
16,400.0 16,804.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 53/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/28/2023
12:00
1/28/2023
18:00
6.00 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole at
100 fph for log data F/16,804'
T/17,215'MD / 4,264'TVD while
maintaining drilling EMW on
connections with MPD.
Note: Decreased rop from 100 fph to 50
fph from 17,150' to TD for log data.
254 GPM
3204 PSI
150 RPM
9/8K TQ ON/OFF
5K WOB
175K P/U
108K S/O
140K ROT
12.48 ECD
380 units MAX GAS
ADT= 4.99
Bit HRS= 96.23
16,804.0 17,215.0
1/28/2023
18:00
1/28/2023
21:15
3.25 PROD1, DRILL DDRL P Directional drill 6-1/2" production hole at
50 fph for log data F/17,215'
T/17,340'MD / 4,267'TVD at TD while
maintaining drilling EMW on
connections with MPD.
254 GPM
3213 PSI
150 RPM
10/8K TQ ON/OFF
5K WOB
178K P/U
107K S/O
142K ROT
12.16 ECD
576 units MAX GAS
ADT= 2.72
Bit HRS= 98.95
17,215.0 17,340.0
1/28/2023
21:15
1/28/2023
21:30
0.25 PROD1, TRIPCAS CIRC P Obtain final T&D numbers, well TD
survey and SPR's.
17,340.0 17,340.0
1/28/2023
21:30
1/28/2023
22:15
0.75 PROD1, TRIPCAS CIRC P Circulate B/U while reciprocating and
rotating pipe.
254 GPM
3123 PSI
150 RPM
9K TQ
178K P/U
107K S/O
140K ROT
17,340.0 17,340.0
1/28/2023
22:15
1/28/2023
23:30
1.25 PROD1, TRIPCAS OWFF P Perform MPD static drawdown as per
Beyond rep.
Initial SIP: 423 psi, Final SIP: 21 psi, 4.4
bbls bled back with no gains on last 2
steps. Performed 5 times opening choke
to 50% for 15 seconds, closing in for 5
minutes between each step.
Note: GeoLog started rigging down.
17,340.0 17,340.0
1/28/2023
23:30
1/28/2023
23:45
0.25 PROD1, TRIPCAS BOPE P Function tested annular, top and bottom
rams and hcr's,
17,340.0 17,340.0
1/28/2023
23:45
1/29/2023
00:00
0.25 PROD1, TRIPCAS CIRC P BROOH while circulating b/u. 17,340.0 17,310.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 54/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/29/2023
00:00
1/29/2023
03:00
3.00 PROD1, TRIPCAS BKRM P BROOH circulating 1 b/u per stand for 2
stands T/17,100' as per Beyond
schedule.
258 GPM
3340 PSI
130 RPM
8.5K TQ
180 P/U
17,310.0 17,100.0
1/29/2023
03:00
1/29/2023
12:00
9.00 PROD1, TRIPCAS BKRM P BROOH as per Beyond schedule
F/17,100' T/14,090' racking back HWDP.
258 GPM
2710 PSI
120 RPM
7 K TQ
11.8 ECD
17,100.0 14,090.0
1/29/2023
12:00
1/29/2023
14:00
2.00 PROD1, TRIPCAS BKRM P BROOH as per Beyond schedule
F/14,090 T/13,481' racking back HWDP.
258 GPM
2710 PSI
120 RPM
7K TQ
11.88 ECD
113K ROT
14,090.0 13,481.0
1/29/2023
14:00
1/29/2023
18:00
4.00 PROD1, TRIPCAS BKRM P BROOH as per Beyond schedule
F/13,481 T/12,066' laying down 4" DP
out of mousehole.
258 GPM
2335 PSI
120 RPM
6K TQ
11.39 ECD
113K ROT
13,481.0 12,066.0
1/29/2023
18:00
1/30/2023
00:00
6.00 PROD1, TRIPCAS BKRM P BROOH as per Beyond schedule
F/12,066' T/9,984' laying down 4" DP
out of mousehole.
258 GPM
2136 PSI
120 RPM
5.6K TQ
10.95 ECD
113K ROT
12,066.0 9,984.0
1/30/2023
00:00
1/30/2023
04:30
4.50 PROD1, TRIPCAS BKRM P BROOH as per Beyond schedule
F/9,984' T/8,378' laying down 4" DP out
of mousehole.
258 GPM
2136 PSI
120 RPM
5.6K TQ
10.95 ECD
113K ROT
9,984.0 8,378.0
1/30/2023
04:30
1/30/2023
07:30
3.00 PROD1, TRIPCAS CIRC P Circulate 3x b/u while rotating and
reciprocating.
258 GPM
2050 PSI
60 RPM
4K TQ
110K ROT
8,378.0 8,378.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 55/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/30/2023
07:30
1/30/2023
08:00
0.50 PROD1, TRIPCAS OWFF P Exhale test as per MPD rep. Initial
pressure: 249 psi, FInal pressure: 25
psi. Total pit gain 1.9 bbls. Average
wellbore pressure 25 psi = to hydrostatic
pressure at sensor.
8,378.0 8,378.0
1/30/2023
08:00
1/30/2023
12:00
4.00 PROD1, TRIPCAS OWFF P OWFF, observed slight flow, continue
monitoring until static. SIMOPS: Service
top drive, draworks, and ST-80.
8,378.0 8,378.0
1/30/2023
12:00
1/30/2023
13:30
1.50 PROD1, TRIPCAS OWFF P Continue OWFF. monitoring additional
30 minutes once static.
8,378.0 8,378.0
1/30/2023
13:30
1/30/2023
22:30
9.00 PROD1, TRIPCAS TRIP P SOOH F/8,378' T/4,692' as per Beyond
stripping schedule L/D 4" DP in
mousehole. Monitoring displacement on
pit #4.
112K P/U
8,378.0 4,692.0
1/30/2023
22:30
1/31/2023
00:00
1.50 PROD1, TRIPCAS TRIP P Drop 2.35" hollow drift with tail wire.
Continue SOOH F/4,692' T/3,463' as
per Beyond stripping schedule racking
back 4" DP. Monitoring displacement on
pit #4.
4,692.0 3,463.0
1/31/2023
00:00
1/31/2023
03:00
3.00 PROD1, TRIPCAS TRIP P Continue SOOH F/3,463' T/535' as per
Beyond stripping schedule racking back
4" DP. Monitoring displacement on pit
#4.
3,463.0 535.0
1/31/2023
03:00
1/31/2023
04:30
1.50 PROD1, TRIPCAS OWFF P OWFF - monitored through MPD fully
open chokes to Pill Pit #2. Gained 0.8
bbls in 20 minutes then no gain for 20
minutes. Monitored at RCD side outlet
for 15 minutes - well static.
535.0 535.0
1/31/2023
04:30
1/31/2023
05:30
1.00 PROD1, TRIPCAS MPDA P Pull MPD bearing and install trip nipple
and check for leaks.
535.0 535.0
1/31/2023
05:30
1/31/2023
05:45
0.25 PROD1, TRIPCAS BHAH P L/D jars , pick single 4" HWDP , stand
back 2 stands 4" HWDP
535.0 262.0
1/31/2023
05:45
1/31/2023
09:30
3.75 PROD1, TRIPCAS BHAH P PJSM - flow check static , lay down 6
1/2" BHA as per DD.
262.0 0.0
1/31/2023
09:30
1/31/2023
11:00
1.50 COMPZN, CASING CLEN P Clean clear rig floor , L/D SLB tools, bit,
source transport shield, xo's and lift
subs.
0.0 0.0
1/31/2023
11:00
1/31/2023
11:30
0.50 COMPZN, CASING WWWH P P/U stack washer , flush stack at 350
gpm at 50 psi with mud, lay down same.
0.0 0.0
1/31/2023
11:30
1/31/2023
12:00
0.50 COMPZN, CASING WWWH P Drain BOP and pull wear bushing as per
Cameron rep.
0.0 0.0
1/31/2023
12:00
1/31/2023
13:00
1.00 COMPZN, CASING BOPE P B/D top drive, set test plug as per
Cameron rep.
0.0 0.0
1/31/2023
13:00
1/31/2023
14:30
1.50 COMPZN, CASING BOPE P R/U BOP test equipment and purge air.
Grease IBOP.
0.0 0.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 56/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
1/31/2023
14:30
1/31/2023
20:00
5.50 COMPZN, CASING BOPE P All test BOPE with 4" & 4-1/2" test joints
to 250 PSI low 4,000 PSI for 5 minutes
each test charted. Test annular
Preventer with 4" test joint to 250 psi
low and 2,500 psi high for 5 minutes
each. Test 4" Demco kill , choke valves
1 to 14 , 3.5" x 6" VBR top and bottom
rams , blind rams , auto/manual IBOP ,
HCR kill/choke valve , manual kill/choke
valve , Dart valve , FOSV to 250 psi low
and 4,000 psi high for 5 minutes each.
Test remote and hydraulic chokes to
2,000 psi and observed pressure drop
when opening. Accumulator drawdown:
ISP = 2900 psi PSI after functioning =
1400 psi, 200 psi rec = 13 seconds, Full
system recovery = 151 seconds, 4
bottles back up average = 2225 psi,
Bottle pre-charge average = 1000 psi,
Closing times: Annular = 16 seconds,
UPR = 7 seconds, Blind rams = 14
seconds, LPR = 7 seconds, Choke HCR
= 1 second, Kill HCR = 1 second. Test
all gas alarms, PVT gain/loss, Flow
paddle.
Note: Witness waived by Brian Bixby on
1-29-2023 @ 16:17 hrs.
0.0 0.0
1/31/2023
20:00
1/31/2023
21:00
1.00 COMPZN, CASING WWWH P Pull test plug and set 10" ID wear
bushing as per Cameron rep. Locked in
with 2 lock down pins. B/D choke and
kill lines.
0.0 0.0
1/31/2023
21:00
1/31/2023
23:00
2.00 COMPZN, CASING RURD P R/U 4-1/2" casing handling equipment.
PJSM.
0.0 0.0
1/31/2023
23:00
2/1/2023
00:00
1.00 COMPZN, CASING PULD P RIH w/4-1/2" lower completion as per
detail T/514'.
73K S/O
0.0 514.0
2/1/2023
00:00
2/1/2023
09:00
9.00 COMPZN, CASING PULD P RIH w/4-1/2" lower completion as per
detail F/514' T/8,380'.
94K S/O
514.0 8,380.0
2/1/2023
09:00
2/1/2023
11:00
2.00 COMPZN, CASING RURD P M/U XO, C/O elevators to 4" DP. Obtain
T&D parameters prior to exiting shoe.
115k P/U
94K S/O
112K ROT
25 RPM
4K TQ
8,380.0 8,380.0
2/1/2023
11:00
2/1/2023
12:00
1.00 COMPZN, CASING RCST P Continue RIH w/4-1/2" lower completion
as per detail on 4" DP stands F/8,380'
T/9,055''.
95K S/O
8,380.0 9,055.0
2/1/2023
12:00
2/1/2023
12:30
0.50 COMPZN, CASING RUNL P Make up Baker Flexlock liner hanger
assy w/ZXP packer, Install RS packoff
seal nipple.
9,055.0 9,100.0
2/1/2023
12:30
2/1/2023
13:30
1.00 COMPZN, CASING CIRC P M/U 1st stand 4" DP and xo. CIrculate
liner volume at 4 bpm with 615 psi.
9,100.0 9,181.0
2/1/2023
13:30
2/1/2023
18:00
4.50 COMPZN, CASING RUNL P Continue RIH w/4-1/2" lower completion
as per detail on 4" DP stands F/9,181'
T/13,153'.
92K S/O
9,181.0 13,153.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 57/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/1/2023
18:00
2/2/2023
00:00
6.00 COMPZN, CASING RUNL P Continue RIH w/4-1/2" lower completion
as per detail on 4" HWDDP stands (drift
to 2.3") F/13,153' T/15,573'.
115K S/O
13,153.0 15,573.0
2/2/2023
00:00
2/2/2023
04:00
4.00 COMPZN, CASING RUNL P Continue RIH w/4-1/2" lower completion
as per detail on 4" HWDP stands (drift to
2.3") F/15,573' T/17,285' taking weight.
Experiencing difficulty drifting HWDP
due to frost build up in top half of
stands.
115K S/O
15,573.0 17,285.0
2/2/2023
04:00
2/2/2023
06:00
2.00 COMPZN, CASING CIRC P Establish circulation and wash down to
setting depth F/17,242' T/17,332' at 157
GPM 1290 PSI , pump 10 bbl Hi-Vis pill
and circulate string volume staging up
flow rate. Prior to ball drop
17,285.0 17,332.0
2/2/2023
06:00
2/2/2023
07:00
1.00 COMPZN, CASING CIRC P Pump 10 BBL Hi Vis pill drop 1.5" ball ,
pump 10 BBL Hi Vis pill chase with 9.5
mud
ICP = 127 GPM 1030 PSI
FCP = 47 GPM 570 PSI
Ball on seat @ 604 STKS
17,332.0 17,332.0
2/2/2023
07:00
2/2/2023
07:30
0.50 COMPZN, CASING PACK P Set liner hanger and SLZXP as per
baker rep , PSI up to 3850 , S/O 50K
confirm set , bleed off PSI , pick up 5'
confirm release 150K UP 30K loss in up
WT
LTP @ 8,254'
17,332.0 17,332.0
2/2/2023
07:30
2/2/2023
08:00
0.50 COMPZN, CASING PRTS P Test LTP to 3850 PSI F/15 minutes 17,332.0 17,332.0
2/2/2023
08:00
2/2/2023
10:00
2.00 COMPZN, WELLPR DISP P P/U pull pack off assy out of LTP , start
pumping at 1487 GPM 600 PSI , cont
picking up 60' T/8,151' , displace well
from 9.5 PPG mud to 9.2 PPG CI NaCI
brine @ 258 GPM 1790 PSI
155K UP
8,254.0 8,151.0
2/2/2023
10:00
2/2/2023
11:00
1.00 COMPZN, WELLPR OWFF P Flow check 30 min , static , obtain SPR ,
blow down top drive
8,151.0 8,151.0
2/2/2023
11:00
2/2/2023
22:00
11.00 COMPZN, WELLPR PULD P POOH laying down 4" DP to pipe shed
F/8,151'
8,151.0 46.0
2/2/2023
22:00
2/2/2023
23:00
1.00 COMPZN, WELLPR OTHR P Inspect and lay down baker liner running
tool
46.0 0.0
2/2/2023
23:00
2/3/2023
00:00
1.00 COMPZN, RPCOMP OTHR P Drain stack , pull wear ring , flush stack 0.0 0.0
2/3/2023
00:00
2/3/2023
00:30
0.50 COMPZN, RPCOMP OTHR P Blow down top drive , L/D 2 STDS 4" DP
from derrick , install 4 1/2" elevators ,
drift TBG hanger with 3.84" drift
0.0 0.0
2/3/2023
00:30
2/3/2023
06:00
5.50 COMPZN, RPCOMP RURD P Rig up to run 4 1/2" tubing , bring up
power tongs , bring spooling unit
assemble on rig floor , bring up cable
clamps to rig floor , prep pipe shed for
running tubing , make up floor valve to
cross over
0.0 0.0
2/3/2023
06:00
2/3/2023
08:45
2.75 COMPZN, RPCOMP PUTB P PJSM , run 4 1/2" TBG as per detail
T/256
0.0 256.0
2/3/2023
08:45
2/3/2023
10:15
1.50 COMPZN, RPCOMP PRTS P Hook up Tec wire to gauge and test to
5000 PSI F/5 min , good test
256.0 256.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 58/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/3/2023
10:15
2/3/2023
22:30
12.25 COMPZN, RPCOMP PUTB P RIH with 4 1/2" TBG as per detail,
F/256' T/8,220'
113K UP
97K DN
Test Tec wire evry 2000'
Make up TQ in TBG = 3800 FT/LBS
256.0 8,220.0
2/3/2023
22:30
2/4/2023
00:00
1.50 COMPZN, RPCOMP PUTB P Locate no go on top of LTP , tag up on
shear screws set DN 12K shear
screws , cont slack off T/8,263' tag no
go on LTP set DN 5K , pick up confirm
no go with 10K DN
Lay DN 3 JTS TBG , pick up space out
pups 3.86' , 9.74' , 9.51' for 23.11' total ,
make up JT# 194 , make up hanger
and landing JT T/8,222'
113K UP
97K DN
8,220.0 8,222.0
2/4/2023
00:00
2/4/2023
01:45
1.75 COMPZN, RPCOMP THGR P Terminate TEC wire thru hanger , make
up swagelok fittings and test to 5000
PSI for 5 min
SimOps - rig up to set packer and test
TBG and IA
OWFF - slight drop
Drain stack
8,222.0 8,222.0
2/4/2023
01:45
2/4/2023
03:15
1.50 COMPZN, RPCOMP THGR P Land out TBG in well head , RILDS ,
test hanger seals to 5000 PSI for 15 min
Use 196 full clamps and 8 half clamps
for Tec wire
M/S @ 8260.68' , No Go sub @
8252.15' , 1.95' from fully located
113K UP
97K DN
TBG WT = 53K
8,222.0 8,260.0
2/4/2023
03:15
2/4/2023
04:15
1.00 COMPZN, RPCOMP PRTS P Fill lines and PSI test lines to 4500 PSI ,
PSI up to 4550 PSI to set TNT packer
hold for 15 min
8,260.0 8,260.0
2/4/2023
04:15
2/4/2023
05:15
1.00 COMPZN, RPCOMP PRTS P Bleed TBG to 2650 PSI , PSI test IA
T/3850 PSI for 30 min
SOV shear out while PSI up on ANN
Bleed off IA , Bleed off TBG PSI to zero
Pump down ANN up TBG @ 1.3 BPM
310 PSI
Pump down TBG up ANN @ 1.3 BPM
350 PSI
Flow check
8,260.0 8,260.0
2/4/2023
05:15
2/4/2023
06:00
0.75 COMPZN, RPCOMP MPSP P R/D lines , L/D landing JT
Install HP-BPV , R/U test in direction of
flow to 2500 PSI F/10 Min
8,260.0 0.0
2/4/2023
06:00
2/4/2023
07:00
1.00 COMPZN, RPCOMP RURD P Blow down , rig down lines and squeeze
manifold and mud line
0.0 0.0
2/4/2023
07:00
2/4/2023
12:00
5.00 COMPZN, WHDBOP NUND P N/D MPD equipment , pull mouse hole ,
remove flow line , disconnect choke
line , L/D flow box , orbit valve , remove
13 5/8" x 11" adaptor and stand back
BOP
0.0 0.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 59/59
3S-701
Report Printed: 2/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
2/4/2023
12:00
2/4/2023
18:45
6.75 COMPZN, WHDBOP NUND P Install seal assy and TBG head
adapter , terminate Tec wire thru well
head as per Cameron and HES rep ,
orient DHG , install tree test dart , test
hanger void to 250/5000 PSI , N/U 10K
frac tree
SimOps - Ready rig for move to 3S-
704 , clean clear rig floor of excess tools
and equipment , finish pit cleaning ,
drain mud pumps , C/O drag chain in
rockwasher , replace upper skate hinge
0.0 0.0
2/4/2023
18:45
2/4/2023
21:00
2.25 COMPZN, WHDBOP NUND P R/U test 10K frac tree to 250 F/5 min
and 5000 PSI F/15 min , R/D lines and
equipment , pull tree test dart and HP-
BPV
0.0 0.0
2/4/2023
21:00
2/5/2023
00:00
3.00 COMPZN, WHDBOP FRZP P R/U lines for LRS to freeze protect well ,
test lines T/3,000 PSI , pump 90 BBLS
diesel down IA , line up let diesel U-tube
ICR 1.25 BPM 310 PSI
FCR 1.25 BPM 550 PSI
PSI on TBG/ANN at start = 175/210 PSI
0.0 0.0
2/5/2023
00:00
2/5/2023
01:15
1.25 COMPZN, WHDBOP FRZP P Cont to U-tube diesel from IA to TBG
PSI on TBG/ANN at start = 175/210 PSI
PSI on TBG/ANN at end = 110/110 PSI
Open bleeder bleed off to zero , shut in
PSI stay at zero
Suck back lines R/D freeze protect
equipment
0.0 0.0
2/5/2023
01:15
2/5/2023
01:30
0.25 COMPZN, WHDBOP MPSP P Set 4" H-BPV 0.0 0.0
2/5/2023
01:30
2/5/2023
03:00
1.50 DEMOB, MOVE MOB P Fill tree with diesel , secure well
Final pressures
OA = 250 PSI
IA = 0 PSI
TBG = 0 PSI
Rig released @ 03:00 HRS
0.0 0.0
Rig: DOYON 19
RIG RELEASE DATE 2/5/2023
Page 1/1
3S-701
Report Printed: 2/21/2023
Cement Detail Report
Cement Details
Description
Intermediate String 1 Cement
Cementing Start Date
1/20/2023 09:00
Cementing End Date
1/20/2023 12:00
Wellbore Name
3S-701A
Comment
PJSM. Cement 7 5/8" casing as per Halliburton program. Flood lines test trips and test lines to 4000 psi. Drop 1st bottom wiper plug , pump 62 bbls 12.5 ppg
spacer with BMII @ 3 bpm 327 psi while working pipe 174K P/U 140K S/O. Drop 2nd bottom wiper plug, pump 45 bbls 15.3 ppg cement with BMII followed by 22
bbls 15.3 ppg cement without BMII at 2.3 bpm, 100 psi while working pipe 182K P/U 151K S/O. Drop top plug, Halliburton pumped 10 bbls water. Displaced
using rig pump with 375 bbls 9.6 ppg mud at 6 bpm, ICP 475 psi, FCP 815 psi, slowing to 3 bpm last 10 bbls. Bump plugs and pressure up to 1315 psi, held for 5
min. bleed off and floats held, CIP @ 11:50 hrs 1-20-23 Note: Casing was worked until 360 bbls into displacement, Shoe @ 8,438' ,Float Collar @ 8,348'.
Cement Stages
Stage # 1
Description
Intermediate String 1
Cement
Objective Top Depth (ftKB)
7,262.0
Bottom Depth (ftKB)
8,438.0
Full Return?
Yes
Vol Cement …
0.0
Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
3
Q Pump Final (bbl/…
3
Q Pump Avg (bbl/…
3
P Pump Final (psi)
825.0
P Plug Bump (psi)
1,325.0
Recip?
Yes
Stroke (ft)
20.00
Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
6 1/2
Comment
Cement Fluids & Additives
Fluid
Fluid Type
Tail Cement
Fluid Description Estimated Top (ftKB)
7,280.0
Est Btm (ftKB)
8,438.0
Amount (sacks)
307
Class
G
Volume Pumped (bbl)
67.0
Yield (ft³/sack)
1.25
Mix H20 Ratio (gal/sa…
5.58
Free Water (%) Density (lb/gal)
15.30
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
String: Intermediate String 1 Cement
Job: DRILLING ORIGINAL-<jobsubtyp> 12/17/…
ConocoPhillips
Definitive Survey Report
06 February, 2023
NADConversion
Kuparuk River Unit_2
Kuparuk 3S Pad
3S-701A
Digitally signed by Vincent Osara
DN: C=US, OU=Schlumberger,
O=Schlumberger, CN=Vincent Osara,
E=vosara@slb.com
Reason: I am the author of this document
Location: your signing location here
Date: 2023.02.06 13:11:48-09'00'
Foxit PhantomPDF Version: 10.1.4
Vincent
Osara
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
NADConversion
Kuparuk River Unit_2
Kuparuk 3S Pad
ConocoPhillips
Definitive Survey Report
Well:
Wellbore:
3S-701
3S-701A Survey Calculation Method:Minimum Curvature
3S-701 Actual @ 64.5usft (D19)
Design:3S-701A Database:EDT 17 Alaska Prod
MD Reference:3S-701 Actual @ 64.5usft (D19)
North Reference:
Well 3S-701
True
Map System:
Geo Datum:
Project
Map Zone:
System Datum:US State Plane 1927 (Exact solution)
NAD 1927 (NADCON CONUS)
Kuparuk River Unit_2, North Slope Alaska, United States
Alaska Zone 04
Mean Sea Level
Using Well Reference Point
Using geodetic scale factor
Well
Well Position
Longitude:
Latitude:
Easting:
Northing:
usft
+E/-W
+N/-S
Position Uncertainty
usft
usft
usftGround Level:
3S-701
usft
usft
0.0
0.0
5,993,955.06
476,441.80
27.7Wellhead Elevation:usft0.0
70° 23' 40.621 N
150° 11' 30.043 W
Wellbore
Declination
(°)
Field Strength
(nT)
Sample Date Dip Angle
(°)
3S-701A
Model NameMagnetics
BGGM2022 12/10/2022 14.92 80.67 57,256.15392258
Phase:Version:
Audit Notes:
Design 3S-701A
1.0 ACTUAL
Vertical Section: Depth From (TVD)
(usft)
+N/-S
(usft)
Direction
(°)
+E/-W
(usft)
Tie On Depth:2,880.3
172.000.00.036.8
From
(usft)
Survey Program
DescriptionTool NameSurvey (Wellbore)
To
(usft)
Date 2/6/2023
Survey Date
SDI_URSA1_I4 SDI URSA-1 gyroMWD (ISCWSA Rev 4)117.2 1,051.8 3S-701 Srvy 1 - SDI_Ursa 1 gyro (3S-701 12/20/2022 8:48
MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi-Station Correct1,101.3 2,805.4 3S-701 Srvy 2 - SLB_GMAG (3S-701)12/20/2022 8:56
INC+TREND Inclinometer + known azi trend2,880.3 2,880.3 3S-701 Srvy 3 - SLB_MWD-Inc_only_fille 12/29/2022 8:56
INC+TREND Inclinometer + known azi trend2,919.2 2,919.2 3S-307A Srvy 1 - SLB MWD-Inc_only_fill 1/13/2023 11:09:
MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi-Station Correct3,012.5 8,383.2 3S-701A Srvy 2 - SLB MWD-GMAG (3S-1/13/2023 11:12:
MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi-Station Correct8,481.4 17,256.7 3S-701A Srvy 3 - SLB MWD-GMAG (3S-1/22/2023 11:12:
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
36.8 0.00 0.00 36.8 0.0 0.0-27.7 5,993,955.1 476,441.8 0.0 0.00 UNDEFINED
117.2 0.61 49.04 117.2 0.3 0.352.7 5,993,955.3 476,442.1 0.8 -0.23 SDI_URSA1_I4 (1)
216.7 0.81 50.34 216.7 1.1 1.3152.3 5,993,956.1 476,443.1 0.2 -0.89 SDI_URSA1_I4 (1)
308.4 0.39 302.28 308.4 1.7 1.5243.9 5,993,956.7 476,443.3 1.1 -1.43 SDI_URSA1_I4 (1)
399.4 2.50 259.33 399.4 1.5 -0.7334.9 5,993,956.5 476,441.1 2.5 -1.54 SDI_URSA1_I4 (1)
491.8 3.52 256.38 491.7 0.4 -5.4427.2 5,993,955.5 476,436.4 1.1 -1.17 SDI_URSA1_I4 (1)
583.9 5.29 248.48 583.4 -1.8 -12.1519.0 5,993,953.3 476,429.7 2.0 0.10 SDI_URSA1_I4 (1)
672.9 7.77 244.52 671.8 -5.9 -21.4607.3 5,993,949.2 476,420.4 2.8 2.87 SDI_URSA1_I4 (1)
769.8 8.80 247.13 767.7 -11.6 -34.1703.2 5,993,943.6 476,407.6 1.1 6.74 SDI_URSA1_I4 (1)
865.0 10.95 256.99 861.5 -16.5 -49.7797.1 5,993,938.8 476,392.1 2.9 9.40 SDI_URSA1_I4 (1)
2/6/2023 12:58:51PM COMPASS 5000.17 Build Page 2
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
NADConversion
Kuparuk River Unit_2
Kuparuk 3S Pad
ConocoPhillips
Definitive Survey Report
Well:
Wellbore:
3S-701
3S-701A Survey Calculation Method:Minimum Curvature
3S-701 Actual @ 64.5usft (D19)
Design:3S-701A Database:EDT 17 Alaska Prod
MD Reference:3S-701 Actual @ 64.5usft (D19)
North Reference:
Well 3S-701
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
958.4 13.12 257.10 952.9 -20.8 -68.6888.4 5,993,934.4 476,373.1 2.3 11.08 SDI_URSA1_I4 (1)
1,051.8 12.87 254.84 1,043.9 -25.9 -89.0979.4 5,993,929.4 476,352.7 0.6 13.28 SDI_URSA1_I4 (1)
1,101.3 13.52 252.42 1,092.1 -29.1 -99.91,027.6 5,993,926.3 476,341.9 1.7 14.93 MWD+IFR2+SAG+MS (2)
1,196.3 17.04 252.35 1,183.8 -36.7 -123.71,119.3 5,993,918.8 476,318.0 3.7 19.11 MWD+IFR2+SAG+MS (2)
1,290.0 16.49 254.02 1,273.4 -44.5 -149.61,208.9 5,993,911.0 476,292.1 0.8 23.26 MWD+IFR2+SAG+MS (2)
1,386.0 19.59 253.27 1,364.7 -52.9 -178.11,300.3 5,993,902.7 476,263.6 3.2 27.60 MWD+IFR2+SAG+MS (2)
1,481.0 20.43 252.67 1,453.9 -62.4 -209.21,389.5 5,993,893.3 476,232.5 0.9 32.70 MWD+IFR2+SAG+MS (2)
1,575.8 23.77 250.24 1,541.8 -73.8 -243.01,477.3 5,993,882.0 476,198.6 3.7 39.28 MWD+IFR2+SAG+MS (2)
1,669.2 25.55 249.07 1,626.6 -87.4 -279.51,562.2 5,993,868.6 476,162.1 2.0 47.62 MWD+IFR2+SAG+MS (2)
1,764.2 28.96 253.07 1,711.2 -101.4 -320.71,646.7 5,993,854.7 476,120.8 4.1 55.78 MWD+IFR2+SAG+MS (2)
1,859.0 30.39 255.11 1,793.5 -114.2 -365.81,729.0 5,993,842.0 476,075.7 1.8 62.22 MWD+IFR2+SAG+MS (2)
1,953.2 31.28 254.43 1,874.4 -126.9 -412.41,809.9 5,993,829.4 476,029.1 1.0 68.30 MWD+IFR2+SAG+MS (2)
2,047.8 34.16 252.94 1,953.9 -141.3 -461.41,889.5 5,993,815.2 475,980.0 3.2 75.72 MWD+IFR2+SAG+MS (2)
2,143.1 37.23 247.70 2,031.3 -160.1 -513.71,966.8 5,993,796.6 475,927.7 4.5 87.05 MWD+IFR2+SAG+MS (2)
2,237.5 39.41 241.64 2,105.5 -185.2 -566.52,041.0 5,993,771.7 475,874.8 4.6 104.55 MWD+IFR2+SAG+MS (2)
2,332.3 41.32 235.59 2,177.7 -217.2 -618.82,113.2 5,993,739.8 475,822.3 4.6 128.95 MWD+IFR2+SAG+MS (2)
2,426.7 42.27 236.30 2,248.1 -252.4 -671.02,183.6 5,993,704.8 475,770.1 1.1 156.57 MWD+IFR2+SAG+MS (2)
2,522.4 45.32 238.10 2,317.2 -288.3 -726.72,252.7 5,993,669.1 475,714.3 3.4 184.34 MWD+IFR2+SAG+MS (2)
2,615.8 46.70 238.19 2,382.0 -323.7 -783.72,317.5 5,993,633.9 475,657.2 1.5 211.49 MWD+IFR2+SAG+MS (2)
2,709.9 48.57 238.07 2,445.4 -360.4 -842.82,380.9 5,993,597.3 475,598.0 2.0 239.64 MWD+IFR2+SAG+MS (2)
2,805.4 50.85 238.52 2,507.2 -398.7 -904.72,442.7 5,993,559.3 475,535.9 2.4 268.91 MWD+IFR2+SAG+MS (2)
2,880.3 50.73 238.41 2,554.5 -429.1 -954.22,490.1 5,993,529.0 475,486.3 0.2 292.10 INC+TREND (3)
2,919.2 50.56 238.50 2,579.2 -444.8 -979.82,514.7 5,993,513.4 475,460.7 0.5 304.11 INC+TREND (4)
2,940.0 51.09 238.61 2,592.3 -453.2 -993.62,527.8 5,993,505.0 475,446.9 2.6 310.52 MWD+IFR2+SAG+MS (5)
Sidetrack Point
3,012.5 52.95 238.97 2,636.9 -482.8 -1,042.42,572.4 5,993,475.6 475,397.9 2.6 333.04 MWD+IFR2+SAG+MS (5)
3,062.6 54.41 239.79 2,666.6 -503.4 -1,077.22,602.1 5,993,455.1 475,363.1 3.2 348.56 MWD+IFR2+SAG+MS (5)
3,108.2 55.99 240.23 2,692.6 -522.1 -1,109.62,628.2 5,993,436.5 475,330.6 3.6 362.59 MWD+IFR2+SAG+MS (5)
3,204.1 58.54 241.39 2,744.5 -561.4 -1,180.02,680.0 5,993,397.4 475,260.1 2.8 391.72 MWD+IFR2+SAG+MS (5)
3,298.3 60.64 241.98 2,792.2 -599.9 -1,251.52,727.7 5,993,359.1 475,188.5 2.3 419.92 MWD+IFR2+SAG+MS (5)
3,392.3 62.77 241.76 2,836.7 -639.0 -1,324.62,772.3 5,993,320.3 475,115.3 2.3 448.42 MWD+IFR2+SAG+MS (5)
3,487.0 65.22 241.80 2,878.2 -679.2 -1,399.62,813.8 5,993,280.3 475,040.2 2.6 477.83 MWD+IFR2+SAG+MS (5)
3,582.5 68.54 242.31 2,915.7 -720.4 -1,477.12,851.3 5,993,239.4 474,962.6 3.5 507.78 MWD+IFR2+SAG+MS (5)
3,677.2 70.99 242.60 2,948.5 -761.5 -1,555.92,884.0 5,993,198.6 474,883.6 2.6 537.51 MWD+IFR2+SAG+MS (5)
3,771.1 72.59 243.30 2,977.8 -802.0 -1,635.32,913.3 5,993,158.3 474,804.1 1.8 566.60 MWD+IFR2+SAG+MS (5)
3,865.9 73.63 244.77 3,005.4 -841.7 -1,716.92,940.9 5,993,118.8 474,722.4 1.8 594.59 MWD+IFR2+SAG+MS (5)
3,961.0 74.30 245.42 3,031.7 -880.2 -1,799.82,967.2 5,993,080.6 474,639.4 1.0 621.17 MWD+IFR2+SAG+MS (5)
4,055.8 75.25 246.05 3,056.5 -917.8 -1,883.22,992.1 5,993,043.3 474,555.9 1.2 646.78 MWD+IFR2+SAG+MS (5)
4,150.3 75.21 246.17 3,080.6 -954.8 -1,966.83,016.2 5,993,006.5 474,472.2 0.1 671.81 MWD+IFR2+SAG+MS (5)
4,244.7 75.10 247.24 3,104.8 -990.9 -2,050.53,040.3 5,992,970.7 474,388.4 1.1 695.87 MWD+IFR2+SAG+MS (5)
2/6/2023 12:58:51PM COMPASS 5000.17 Build Page 3
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
NADConversion
Kuparuk River Unit_2
Kuparuk 3S Pad
ConocoPhillips
Definitive Survey Report
Well:
Wellbore:
3S-701
3S-701A Survey Calculation Method:Minimum Curvature
3S-701 Actual @ 64.5usft (D19)
Design:3S-701A Database:EDT 17 Alaska Prod
MD Reference:3S-701 Actual @ 64.5usft (D19)
North Reference:
Well 3S-701
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
4,339.9 75.28 247.97 3,129.2 -1,026.0 -2,135.73,064.7 5,992,935.9 474,303.1 0.8 718.76 MWD+IFR2+SAG+MS (5)
4,434.4 75.25 249.13 3,153.2 -1,059.4 -2,220.73,088.7 5,992,902.8 474,218.0 1.2 740.02 MWD+IFR2+SAG+MS (5)
4,530.1 74.86 249.35 3,177.9 -1,092.2 -2,307.23,113.4 5,992,870.3 474,131.4 0.5 760.43 MWD+IFR2+SAG+MS (5)
4,623.2 75.37 249.46 3,201.8 -1,123.8 -2,391.43,137.3 5,992,838.9 474,047.1 0.6 780.05 MWD+IFR2+SAG+MS (5)
4,718.8 75.87 247.71 3,225.5 -1,157.6 -2,477.63,161.0 5,992,805.4 473,960.8 1.8 801.54 MWD+IFR2+SAG+MS (5)
4,814.6 75.84 247.56 3,248.9 -1,193.0 -2,563.53,184.5 5,992,770.3 473,874.8 0.2 824.58 MWD+IFR2+SAG+MS (5)
4,908.9 76.25 247.24 3,271.7 -1,228.1 -2,648.03,207.2 5,992,735.4 473,790.2 0.5 847.66 MWD+IFR2+SAG+MS (5)
5,002.4 76.31 247.05 3,293.9 -1,263.4 -2,731.73,229.4 5,992,700.4 473,706.4 0.2 870.94 MWD+IFR2+SAG+MS (5)
5,097.7 75.96 247.44 3,316.7 -1,299.2 -2,817.13,252.2 5,992,664.9 473,620.9 0.5 894.52 MWD+IFR2+SAG+MS (5)
5,192.9 76.37 248.57 3,339.5 -1,333.8 -2,902.73,275.0 5,992,630.5 473,535.2 1.2 916.86 MWD+IFR2+SAG+MS (5)
5,286.7 76.19 248.62 3,361.7 -1,367.1 -2,987.63,297.2 5,992,597.5 473,450.2 0.2 937.99 MWD+IFR2+SAG+MS (5)
5,382.0 76.22 249.02 3,384.4 -1,400.5 -3,073.93,320.0 5,992,564.4 473,363.8 0.4 959.09 MWD+IFR2+SAG+MS (5)
5,475.4 76.19 248.88 3,406.7 -1,433.1 -3,158.53,342.2 5,992,532.1 473,279.1 0.1 979.56 MWD+IFR2+SAG+MS (5)
5,570.0 76.08 247.46 3,429.4 -1,467.3 -3,243.83,364.9 5,992,498.2 473,193.7 1.5 1,001.53 MWD+IFR2+SAG+MS (5)
5,665.2 76.31 247.17 3,452.1 -1,502.9 -3,329.13,387.6 5,992,462.8 473,108.4 0.4 1,024.96 MWD+IFR2+SAG+MS (5)
5,759.6 76.17 247.53 3,474.5 -1,538.2 -3,413.63,410.1 5,992,427.8 473,023.7 0.4 1,048.14 MWD+IFR2+SAG+MS (5)
5,854.3 76.29 246.77 3,497.1 -1,573.9 -3,498.53,432.6 5,992,392.3 472,938.7 0.8 1,071.73 MWD+IFR2+SAG+MS (5)
5,950.0 76.08 246.49 3,519.9 -1,610.8 -3,583.73,455.5 5,992,355.7 472,853.4 0.4 1,096.35 MWD+IFR2+SAG+MS (5)
6,043.2 76.23 246.30 3,542.2 -1,647.0 -3,666.73,477.8 5,992,319.8 472,770.3 0.3 1,120.70 MWD+IFR2+SAG+MS (5)
6,138.5 76.14 246.22 3,565.0 -1,684.3 -3,751.43,500.5 5,992,282.8 472,685.5 0.1 1,145.81 MWD+IFR2+SAG+MS (5)
6,232.9 76.31 247.28 3,587.5 -1,720.5 -3,835.63,523.0 5,992,246.9 472,601.2 1.1 1,169.90 MWD+IFR2+SAG+MS (5)
6,327.6 76.28 249.05 3,609.9 -1,754.7 -3,921.03,545.4 5,992,212.9 472,515.7 1.8 1,191.91 MWD+IFR2+SAG+MS (5)
6,422.4 76.05 250.54 3,632.6 -1,786.5 -4,007.43,568.1 5,992,181.4 472,429.2 1.5 1,211.37 MWD+IFR2+SAG+MS (5)
6,516.2 76.23 249.94 3,655.1 -1,817.3 -4,093.13,590.6 5,992,150.9 472,343.4 0.6 1,229.94 MWD+IFR2+SAG+MS (5)
6,611.8 76.22 249.65 3,677.8 -1,849.3 -4,180.23,613.3 5,992,119.1 472,256.2 0.3 1,249.56 MWD+IFR2+SAG+MS (5)
6,707.1 76.05 248.71 3,700.7 -1,882.2 -4,266.73,636.2 5,992,086.5 472,169.6 1.0 1,270.10 MWD+IFR2+SAG+MS (5)
6,802.0 75.88 247.60 3,723.7 -1,916.5 -4,352.23,659.2 5,992,052.5 472,084.0 1.1 1,292.13 MWD+IFR2+SAG+MS (5)
6,897.1 76.08 246.12 3,746.7 -1,952.7 -4,437.03,682.2 5,992,016.5 471,999.1 1.5 1,316.22 MWD+IFR2+SAG+MS (5)
6,991.7 76.55 244.70 3,769.1 -1,991.0 -4,520.63,704.6 5,991,978.5 471,915.4 1.5 1,342.48 MWD+IFR2+SAG+MS (5)
7,085.2 76.79 243.69 3,790.6 -2,030.6 -4,602.53,726.2 5,991,939.2 471,833.4 1.1 1,370.28 MWD+IFR2+SAG+MS (5)
7,179.9 76.58 243.22 3,812.5 -2,071.8 -4,684.93,748.0 5,991,898.3 471,750.8 0.5 1,399.58 MWD+IFR2+SAG+MS (5)
7,274.2 75.70 243.31 3,835.1 -2,113.0 -4,766.83,770.6 5,991,857.3 471,668.9 0.9 1,429.01 MWD+IFR2+SAG+MS (5)
7,369.6 76.31 240.97 3,858.1 -2,156.2 -4,848.53,793.6 5,991,814.4 471,587.0 2.5 1,460.43 MWD+IFR2+SAG+MS (5)
7,464.6 76.37 236.98 3,880.6 -2,203.8 -4,927.73,816.1 5,991,767.0 471,507.7 4.1 1,496.57 MWD+IFR2+SAG+MS (5)
7,559.0 76.02 234.14 3,903.1 -2,255.6 -5,003.23,838.6 5,991,715.4 471,432.0 2.9 1,537.36 MWD+IFR2+SAG+MS (5)
7,653.6 76.07 230.83 3,925.9 -2,311.5 -5,076.13,861.4 5,991,659.8 471,359.0 3.4 1,582.59 MWD+IFR2+SAG+MS (5)
7,747.7 76.66 227.70 3,948.1 -2,371.2 -5,145.33,883.6 5,991,600.3 471,289.5 3.3 1,632.04 MWD+IFR2+SAG+MS (5)
7,843.0 76.72 225.02 3,970.1 -2,435.2 -5,212.53,905.6 5,991,536.5 471,222.2 2.7 1,686.08 MWD+IFR2+SAG+MS (5)
7,937.3 77.14 221.40 3,991.4 -2,502.2 -5,275.33,926.9 5,991,469.8 471,159.1 3.8 1,743.62 MWD+IFR2+SAG+MS (5)
8,031.9 77.78 216.90 4,011.9 -2,573.7 -5,333.63,947.5 5,991,398.4 471,100.6 4.7 1,806.38 MWD+IFR2+SAG+MS (5)
2/6/2023 12:58:51PM COMPASS 5000.17 Build Page 4
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
NADConversion
Kuparuk River Unit_2
Kuparuk 3S Pad
ConocoPhillips
Definitive Survey Report
Well:
Wellbore:
3S-701
3S-701A Survey Calculation Method:Minimum Curvature
3S-701 Actual @ 64.5usft (D19)
Design:3S-701A Database:EDT 17 Alaska Prod
MD Reference:3S-701 Actual @ 64.5usft (D19)
North Reference:
Well 3S-701
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
8,127.8 78.63 213.15 4,031.5 -2,650.6 -5,387.53,967.1 5,991,321.7 471,046.5 3.9 1,875.00 MWD+IFR2+SAG+MS (5)
8,222.1 78.42 209.50 4,050.3 -2,729.5 -5,435.53,985.8 5,991,242.9 470,998.3 3.8 1,946.49 MWD+IFR2+SAG+MS (5)
8,317.1 78.10 206.01 4,069.6 -2,811.8 -5,478.84,005.2 5,991,160.8 470,954.7 3.6 2,021.96 MWD+IFR2+SAG+MS (5)
8,383.2 78.54 203.39 4,083.0 -2,870.6 -5,505.94,018.5 5,991,102.1 470,927.5 3.9 2,076.40 MWD+IFR2+SAG+MS (5)
8,481.4 78.91 199.73 4,102.2 -2,960.2 -5,541.34,037.8 5,991,012.6 470,891.8 3.7 2,160.19 MWD+IFR2+SAG+MS (6)
8,573.2 79.96 197.19 4,119.1 -3,045.8 -5,569.84,054.6 5,990,927.2 470,863.0 3.0 2,240.95 MWD+IFR2+SAG+MS (6)
8,671.5 80.48 193.62 4,135.8 -3,139.1 -5,595.54,071.3 5,990,833.9 470,837.0 3.6 2,329.84 MWD+IFR2+SAG+MS (6)
8,766.0 81.17 190.07 4,150.8 -3,230.4 -5,614.74,086.4 5,990,742.6 470,817.5 3.8 2,417.60 MWD+IFR2+SAG+MS (6)
8,860.4 82.35 185.82 4,164.4 -3,322.9 -5,627.64,099.9 5,990,650.3 470,804.3 4.6 2,507.33 MWD+IFR2+SAG+MS (6)
8,954.7 82.80 182.01 4,176.6 -3,416.2 -5,634.04,112.1 5,990,557.0 470,797.7 4.0 2,598.82 MWD+IFR2+SAG+MS (6)
9,049.4 83.66 178.19 4,187.7 -3,510.2 -5,634.14,123.3 5,990,463.0 470,797.2 4.1 2,691.92 MWD+IFR2+SAG+MS (6)
9,143.9 84.25 173.88 4,197.7 -3,603.9 -5,627.64,133.2 5,990,369.2 470,803.4 4.6 2,785.65 MWD+IFR2+SAG+MS (6)
9,237.0 85.08 171.28 4,206.4 -3,695.9 -5,615.74,141.9 5,990,277.3 470,815.1 2.9 2,878.36 MWD+IFR2+SAG+MS (6)
9,331.6 87.79 171.51 4,212.2 -3,789.2 -5,601.54,147.8 5,990,183.9 470,828.9 2.9 2,972.78 MWD+IFR2+SAG+MS (6)
9,426.7 90.84 169.87 4,213.4 -3,883.1 -5,586.14,148.9 5,990,090.0 470,844.0 3.6 3,067.83 MWD+IFR2+SAG+MS (6)
9,520.5 90.49 169.02 4,212.3 -3,975.2 -5,569.04,147.8 5,989,997.8 470,860.9 1.0 3,161.51 MWD+IFR2+SAG+MS (6)
9,613.8 90.46 169.88 4,211.5 -4,066.9 -5,551.94,147.0 5,989,906.1 470,877.7 0.9 3,254.67 MWD+IFR2+SAG+MS (6)
9,707.2 90.46 169.83 4,210.8 -4,158.9 -5,535.44,146.3 5,989,814.0 470,893.8 0.1 3,348.05 MWD+IFR2+SAG+MS (6)
9,802.3 90.26 170.22 4,210.2 -4,252.5 -5,519.04,145.7 5,989,720.4 470,910.0 0.5 3,443.04 MWD+IFR2+SAG+MS (6)
9,895.1 90.22 170.85 4,209.8 -4,344.1 -5,503.74,145.3 5,989,628.8 470,925.0 0.7 3,535.84 MWD+IFR2+SAG+MS (6)
9,989.5 90.22 171.04 4,209.4 -4,437.3 -5,488.84,144.9 5,989,535.5 470,939.6 0.2 3,630.25 MWD+IFR2+SAG+MS (6)
10,087.7 90.29 171.41 4,209.0 -4,534.3 -5,473.94,144.5 5,989,438.5 470,954.2 0.4 3,728.38 MWD+IFR2+SAG+MS (6)
10,182.1 90.12 172.49 4,208.6 -4,627.8 -5,460.64,144.2 5,989,344.9 470,967.1 1.2 3,822.80 MWD+IFR2+SAG+MS (6)
10,276.5 90.40 172.91 4,208.2 -4,721.4 -5,448.74,143.7 5,989,251.3 470,978.8 0.5 3,917.14 MWD+IFR2+SAG+MS (6)
10,371.7 90.91 173.17 4,207.1 -4,816.0 -5,437.14,142.6 5,989,156.7 470,990.1 0.6 4,012.38 MWD+IFR2+SAG+MS (6)
10,465.9 90.67 173.37 4,205.8 -4,909.5 -5,426.14,141.3 5,989,063.2 471,000.8 0.3 4,106.57 MWD+IFR2+SAG+MS (6)
10,561.1 90.77 172.90 4,204.6 -5,004.0 -5,414.74,140.1 5,988,968.7 471,011.9 0.5 4,201.70 MWD+IFR2+SAG+MS (6)
10,656.1 90.98 172.86 4,203.2 -5,098.3 -5,402.94,138.7 5,988,874.3 471,023.4 0.2 4,296.72 MWD+IFR2+SAG+MS (6)
10,750.4 90.88 173.30 4,201.6 -5,191.8 -5,391.64,137.2 5,988,780.7 471,034.4 0.5 4,390.96 MWD+IFR2+SAG+MS (6)
10,845.1 90.77 173.06 4,200.3 -5,285.9 -5,380.34,135.8 5,988,686.7 471,045.4 0.3 4,485.64 MWD+IFR2+SAG+MS (6)
10,940.0 90.91 172.42 4,198.9 -5,380.0 -5,368.34,134.4 5,988,592.5 471,057.1 0.7 4,580.53 MWD+IFR2+SAG+MS (6)
11,033.6 90.78 171.67 4,197.5 -5,472.7 -5,355.44,133.0 5,988,499.8 471,069.7 0.8 4,674.14 MWD+IFR2+SAG+MS (6)
11,128.0 90.71 172.46 4,196.3 -5,566.2 -5,342.34,131.8 5,988,406.3 471,082.5 0.8 4,768.49 MWD+IFR2+SAG+MS (6)
11,222.3 91.02 172.91 4,194.9 -5,659.7 -5,330.34,130.4 5,988,312.8 471,094.2 0.6 4,862.74 MWD+IFR2+SAG+MS (6)
11,316.9 90.64 172.62 4,193.5 -5,753.6 -5,318.44,129.0 5,988,218.9 471,105.8 0.5 4,957.38 MWD+IFR2+SAG+MS (6)
11,412.0 90.50 170.98 4,192.5 -5,847.7 -5,304.94,128.1 5,988,124.7 471,119.1 1.7 5,052.45 MWD+IFR2+SAG+MS (6)
11,505.3 90.23 170.84 4,191.9 -5,939.8 -5,290.14,127.5 5,988,032.5 471,133.5 0.3 5,145.78 MWD+IFR2+SAG+MS (6)
11,599.6 90.13 170.59 4,191.6 -6,032.9 -5,274.94,127.2 5,987,939.4 471,148.4 0.3 5,240.03 MWD+IFR2+SAG+MS (6)
11,694.1 89.89 169.47 4,191.6 -6,126.0 -5,258.54,127.2 5,987,846.3 471,164.5 1.2 5,334.49 MWD+IFR2+SAG+MS (6)
11,789.3 90.43 169.99 4,191.4 -6,219.6 -5,241.64,126.9 5,987,752.7 471,181.2 0.8 5,429.54 MWD+IFR2+SAG+MS (6)
2/6/2023 12:58:51PM COMPASS 5000.17 Build Page 5
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
NADConversion
Kuparuk River Unit_2
Kuparuk 3S Pad
ConocoPhillips
Definitive Survey Report
Well:
Wellbore:
3S-701
3S-701A Survey Calculation Method:Minimum Curvature
3S-701 Actual @ 64.5usft (D19)
Design:3S-701A Database:EDT 17 Alaska Prod
MD Reference:3S-701 Actual @ 64.5usft (D19)
North Reference:
Well 3S-701
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
11,883.6 90.23 170.72 4,190.8 -6,312.5 -5,225.84,126.3 5,987,659.7 471,196.7 0.8 5,523.79 MWD+IFR2+SAG+MS (6)
11,977.9 90.33 171.63 4,190.4 -6,405.7 -5,211.34,125.9 5,987,566.4 471,210.8 1.0 5,618.11 MWD+IFR2+SAG+MS (6)
12,073.0 90.20 172.08 4,189.9 -6,499.9 -5,197.84,125.4 5,987,472.2 471,224.0 0.5 5,713.25 MWD+IFR2+SAG+MS (6)
12,169.1 90.33 172.14 4,189.5 -6,595.0 -5,184.74,125.0 5,987,377.1 471,236.9 0.1 5,809.29 MWD+IFR2+SAG+MS (6)
12,262.0 90.50 172.30 4,188.8 -6,687.1 -5,172.14,124.3 5,987,285.0 471,249.2 0.3 5,902.19 MWD+IFR2+SAG+MS (6)
12,357.5 90.12 172.99 4,188.3 -6,781.8 -5,159.94,123.8 5,987,190.2 471,261.1 0.8 5,997.68 MWD+IFR2+SAG+MS (6)
12,452.6 90.23 172.55 4,188.0 -6,876.2 -5,147.94,123.5 5,987,095.8 471,272.8 0.5 6,092.79 MWD+IFR2+SAG+MS (6)
12,544.6 89.98 172.86 4,187.8 -6,967.4 -5,136.24,123.4 5,987,004.6 471,284.2 0.4 6,184.76 MWD+IFR2+SAG+MS (6)
12,640.0 89.85 173.17 4,188.0 -7,062.2 -5,124.64,123.5 5,986,909.8 471,295.5 0.4 6,280.22 MWD+IFR2+SAG+MS (6)
12,733.2 89.54 173.48 4,188.5 -7,154.7 -5,113.84,124.0 5,986,817.2 471,306.0 0.5 6,373.35 MWD+IFR2+SAG+MS (6)
12,826.0 89.13 173.62 4,189.5 -7,246.9 -5,103.34,125.1 5,986,725.0 471,316.2 0.5 6,466.13 MWD+IFR2+SAG+MS (6)
12,923.3 89.44 173.55 4,190.8 -7,343.6 -5,092.54,126.3 5,986,628.3 471,326.7 0.3 6,563.41 MWD+IFR2+SAG+MS (6)
13,018.7 89.23 173.44 4,191.9 -7,438.4 -5,081.74,127.4 5,986,533.5 471,337.2 0.2 6,658.73 MWD+IFR2+SAG+MS (6)
13,111.9 89.23 172.45 4,193.1 -7,530.8 -5,070.24,128.6 5,986,441.0 471,348.4 1.1 6,751.89 MWD+IFR2+SAG+MS (6)
13,206.3 89.13 171.43 4,194.5 -7,624.3 -5,057.04,130.0 5,986,347.5 471,361.3 1.1 6,846.31 MWD+IFR2+SAG+MS (6)
13,301.5 89.41 170.03 4,195.7 -7,718.2 -5,041.74,131.2 5,986,253.5 471,376.4 1.5 6,941.44 MWD+IFR2+SAG+MS (6)
13,395.3 89.34 170.24 4,196.7 -7,810.7 -5,025.64,132.2 5,986,161.1 471,392.1 0.2 7,035.22 MWD+IFR2+SAG+MS (6)
13,489.2 89.30 169.64 4,197.8 -7,903.0 -5,009.24,133.3 5,986,068.6 471,408.2 0.6 7,128.99 MWD+IFR2+SAG+MS (6)
13,583.3 89.13 170.11 4,199.1 -7,995.8 -4,992.64,134.6 5,985,975.9 471,424.5 0.5 7,223.10 MWD+IFR2+SAG+MS (6)
13,676.5 89.24 170.30 4,200.4 -8,087.5 -4,976.84,136.0 5,985,884.1 471,440.0 0.2 7,316.19 MWD+IFR2+SAG+MS (6)
13,771.4 89.06 170.72 4,201.8 -8,181.1 -4,961.14,137.4 5,985,790.5 471,455.4 0.5 7,411.02 MWD+IFR2+SAG+MS (6)
13,865.2 89.10 171.09 4,203.3 -8,273.8 -4,946.34,138.9 5,985,697.8 471,469.9 0.4 7,504.84 MWD+IFR2+SAG+MS (6)
13,958.0 88.89 171.26 4,205.0 -8,365.4 -4,932.14,140.5 5,985,606.0 471,483.9 0.3 7,597.62 MWD+IFR2+SAG+MS (6)
14,050.6 88.96 171.47 4,206.7 -8,457.0 -4,918.24,142.2 5,985,514.5 471,497.5 0.2 7,690.20 MWD+IFR2+SAG+MS (6)
14,145.0 88.65 171.49 4,208.7 -8,550.3 -4,904.24,144.2 5,985,421.1 471,511.2 0.3 7,784.54 MWD+IFR2+SAG+MS (6)
14,237.5 88.58 171.12 4,210.9 -8,641.7 -4,890.24,146.4 5,985,329.7 471,524.9 0.4 7,877.02 MWD+IFR2+SAG+MS (6)
14,329.8 88.96 170.28 4,212.9 -8,732.8 -4,875.34,148.4 5,985,238.6 471,539.5 1.0 7,969.27 MWD+IFR2+SAG+MS (6)
14,421.0 88.72 171.45 4,214.7 -8,822.8 -4,860.84,150.3 5,985,148.5 471,553.7 1.3 8,060.47 MWD+IFR2+SAG+MS (6)
14,513.2 88.62 171.77 4,216.9 -8,914.0 -4,847.44,152.4 5,985,057.3 471,566.8 0.4 8,152.57 MWD+IFR2+SAG+MS (6)
14,606.5 88.89 171.59 4,218.9 -9,006.3 -4,833.94,154.4 5,984,964.9 471,580.0 0.3 8,245.91 MWD+IFR2+SAG+MS (6)
14,698.8 88.86 171.93 4,220.7 -9,097.6 -4,820.64,156.2 5,984,873.6 471,593.0 0.4 8,338.20 MWD+IFR2+SAG+MS (6)
14,792.8 88.65 172.86 4,222.8 -9,190.8 -4,808.24,158.3 5,984,780.4 471,605.1 1.0 8,432.14 MWD+IFR2+SAG+MS (6)
14,885.2 88.93 172.98 4,224.7 -9,282.5 -4,796.84,160.2 5,984,688.7 471,616.2 0.3 8,524.54 MWD+IFR2+SAG+MS (6)
14,979.1 89.24 173.82 4,226.2 -9,375.7 -4,786.04,161.7 5,984,595.4 471,626.7 1.0 8,618.40 MWD+IFR2+SAG+MS (6)
15,072.5 89.20 173.10 4,227.5 -9,468.5 -4,775.44,163.0 5,984,502.6 471,637.1 0.8 8,711.71 MWD+IFR2+SAG+MS (6)
15,165.0 89.00 172.14 4,228.9 -9,560.2 -4,763.54,164.5 5,984,410.9 471,648.6 1.1 8,804.22 MWD+IFR2+SAG+MS (6)
15,256.6 89.13 172.05 4,230.4 -9,650.9 -4,750.94,166.0 5,984,320.1 471,661.0 0.2 8,895.80 MWD+IFR2+SAG+MS (6)
15,350.2 88.93 171.21 4,232.0 -9,743.5 -4,737.34,167.5 5,984,227.5 471,674.3 0.9 8,989.36 MWD+IFR2+SAG+MS (6)
15,443.8 89.17 171.29 4,233.6 -9,836.0 -4,723.14,169.1 5,984,135.0 471,688.2 0.3 9,082.93 MWD+IFR2+SAG+MS (6)
15,537.5 89.44 170.54 4,234.7 -9,928.5 -4,708.34,170.2 5,984,042.4 471,702.7 0.9 9,176.62 MWD+IFR2+SAG+MS (6)
2/6/2023 12:58:51PM COMPASS 5000.17 Build Page 6
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
NADConversion
Kuparuk River Unit_2
Kuparuk 3S Pad
ConocoPhillips
Definitive Survey Report
Well:
Wellbore:
3S-701
3S-701A Survey Calculation Method:Minimum Curvature
3S-701 Actual @ 64.5usft (D19)
Design:3S-701A Database:EDT 17 Alaska Prod
MD Reference:3S-701 Actual @ 64.5usft (D19)
North Reference:
Well 3S-701
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
15,630.4 89.37 170.97 4,235.7 -10,020.2 -4,693.34,171.2 5,983,950.7 471,717.4 0.5 9,269.53 MWD+IFR2+SAG+MS (6)
15,722.1 89.24 171.54 4,236.8 -10,110.8 -4,679.44,172.3 5,983,860.1 471,731.0 0.6 9,361.16 MWD+IFR2+SAG+MS (6)
15,812.9 89.20 172.00 4,238.0 -10,200.7 -4,666.44,173.5 5,983,770.1 471,743.7 0.5 9,452.03 MWD+IFR2+SAG+MS (6)
15,905.6 89.44 171.30 4,239.1 -10,292.4 -4,652.94,174.6 5,983,678.4 471,756.9 0.8 9,544.70 MWD+IFR2+SAG+MS (6)
15,998.9 89.48 171.92 4,240.0 -10,384.7 -4,639.34,175.5 5,983,586.1 471,770.2 0.7 9,637.94 MWD+IFR2+SAG+MS (6)
16,090.9 89.41 172.63 4,240.9 -10,475.9 -4,627.04,176.4 5,983,494.9 471,782.3 0.8 9,729.97 MWD+IFR2+SAG+MS (6)
16,181.2 89.37 173.14 4,241.9 -10,565.5 -4,615.84,177.4 5,983,405.2 471,793.2 0.6 9,820.26 MWD+IFR2+SAG+MS (6)
16,274.8 88.65 173.85 4,243.5 -10,658.5 -4,605.24,179.0 5,983,312.2 471,803.5 1.1 9,913.82 MWD+IFR2+SAG+MS (6)
16,367.3 88.72 173.62 4,245.6 -10,750.4 -4,595.14,181.1 5,983,220.3 471,813.3 0.3 10,006.23 MWD+IFR2+SAG+MS (6)
16,460.9 88.93 172.79 4,247.5 -10,843.3 -4,584.04,183.0 5,983,127.3 471,824.1 0.9 10,099.84 MWD+IFR2+SAG+MS (6)
16,554.7 88.66 173.46 4,249.5 -10,936.4 -4,572.84,185.0 5,983,034.2 471,835.0 0.8 10,193.57 MWD+IFR2+SAG+MS (6)
16,645.7 88.48 173.29 4,251.8 -11,026.7 -4,562.34,187.3 5,982,943.9 471,845.2 0.3 10,284.45 MWD+IFR2+SAG+MS (6)
16,739.2 88.86 172.19 4,253.9 -11,119.5 -4,550.54,189.4 5,982,851.1 471,856.7 1.2 10,377.95 MWD+IFR2+SAG+MS (6)
16,831.4 88.55 171.85 4,256.0 -11,210.8 -4,537.74,191.5 5,982,759.8 471,869.3 0.5 10,470.13 MWD+IFR2+SAG+MS (6)
16,923.5 88.55 171.78 4,258.3 -11,301.9 -4,524.64,193.9 5,982,668.6 471,882.1 0.1 10,562.20 MWD+IFR2+SAG+MS (6)
17,017.8 88.52 170.96 4,260.8 -11,395.1 -4,510.44,196.3 5,982,575.3 471,895.9 0.9 10,656.49 MWD+IFR2+SAG+MS (6)
17,111.8 88.76 169.61 4,263.0 -11,487.8 -4,494.64,198.5 5,982,482.7 471,911.5 1.5 10,750.45 MWD+IFR2+SAG+MS (6)
17,204.2 88.55 169.48 4,265.2 -11,578.6 -4,477.84,200.7 5,982,391.8 471,928.0 0.3 10,842.73 MWD+IFR2+SAG+MS (6)
17,256.7 89.41 168.53 4,266.1 -11,630.1 -4,467.84,201.6 5,982,340.2 471,937.8 2.4 10,895.14 MWD+IFR2+SAG+MS (6)
17,340.0 89.41 168.53 4,266.9 -11,711.7 -4,451.24,202.5 5,982,258.6 471,954.1 0.0 10,978.26 PROJECTED to TD
Projection to TD
2/6/2023 12:58:51PM COMPASS 5000.17 Build Page 7
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
February 28, 2023
CERTIFIED MAIL –
RETURN RECEIPT REQUESTED
7018 0680 0002 2052 7996
Mr. Greg Hobbs
Regulatory Engineer ConocoPhillips
Alaska, Inc.
P. O. Box 100360
Anchorage, AK 99510-0360
Re: Docket Number: OTH-23-
Notice of Violation – Failure to Test BOPE
Doyon 19
Kuparuk River Unit 3S-701 (PTD 2221330)
KRU 3S-701A (PTD 2221340)
Dear Mr. Hobbs:
ConocoPhillips Alaska, Inc. (CPAI) recently completed drilling operations at Kuparuk River Unit
(KRU) Well 3S-701 pursuant to Permit-to-Drill (PTD) 2221330, approved on October 26, 2022,
and KRU Well 3S-701A pursuant to PTD 2221340, approved on October 27, 2022. Both wells are
classified as exploration wells.1 Doyon Rig 19 was used to drill both wells. During exploration
drilling operations, testing of blowout prevention equipment (BOPE) must be completed at
intervals not to exceed 7 days between tests. See 20 AAC 25.035(e)(10)(B).
The initial BOPE test for KRU 3S-701 occurred on December 25, 2022, and a subsequent test was
performed 14 days later, on January 8, 2023. KRU 3S-701 was drilled as a pilot hole and plugged
back to redrill as KRU 3S-701A. The initial BOPE test on KRU 3S-701A occurred January 21,
2023, and a subsequent test occurred 10 days later, on January 31, 2023. AOGCC records show
the next Doyon Rig 19 BOPE test occurred at KRU 3S-704 (PTD 2221420) on February 16, 2023.
Failure to test BOPE within 7 days for exploration wells is a violation of Alaska Oil and Gas
Conservation Commission (AOGCC) regulations.
CPAI met with AOGCC on February 22, 2023, to discuss BOPE testing. Discussions included the
BOPE Between Wells Maintenance Program and continuation of a test frequency waiver affecting
several rigs operated by CPAI. AOGCC requirements for exploration wells were reiterated as part
of the discussion, and specifically that there are no blanket approvals allowing BOPE on rigs
1 CPAI proposed well class for KRU 3S-701 was “Stratigraphic Test”; KRU 3S-701A proposed well class was
“Service – Water Injector”. AOGCC changed both to “Exploratory – Oil” when approved.
Docket Number: OTH-23-002
Notice of Violation – Failure to Test BOPE
February 28, 2023
Page 2 of 2
conducting exploration (or stratigraphic test) drilling to be tested at 14-day intervals. While
AOGCC has previously allowed a 14-day BOPE test interval for drilling one exploratory well. In
that instance CPAI included a request for the extended test interval in the permit to drill with
supporting justification.2 CPAI did not request extended BOPE test intervals in either PTD
2221330 or PTD 2221340.
Within 14 days of receipt of this letter, you are requested to provide the AOGCC with what has or
will be done in the future to prevent this violation’s recurrence on CPAI operated rigs in Alaska.
This information request is made pursuant to 20 AAC 25.300. Failure to comply with this request
will be an additional violation. The AOGCC reserves the right to pursue an enforcement action
in this matter according to 20 AAC 25.535. Questions regarding this notice should be directed to
Jim Regg at 907-793-1236.
Sincerely,
Brett W. Huber, Sr. Jessie L. Chmielowski
Chair, Commissioner Commissioner
cc: AOGCC Inspectors
Phoebe Brooks
RECONSIDERATION AND APPEAL NOTICE
As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the
AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter
determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the
respect in which the order or decision is believed to be erroneous.
The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act
on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the
denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date
on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS
the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for
reconsideration was filed.
If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on
reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be
filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision
on reconsideration.
In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in
the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00
p.m. on the next day that does not fall on a weekend or state holiday.
2 Colville River Unit CD4-594 (PTD 2191150).
Jessie L.
Chmielowski
Digitally signed by Jessie
L. Chmielowski
Date: 2023.02.28
11:22:10 -09'00'
Brett W.
Huber, Sr.
Digitally signed by Brett
W. Huber, Sr.
Date: 2023.02.28
11:33:08 -09'00'
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-701A
Will planned perforations require a spacing exception? Yes No
9. Property Designation (Lease Number): 10. Field: Current Pools:
Kuparuk River Field Exploratory Oil Pool
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD):
17340 4267 4263 1420 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:Dustin Morrow
Contact Email:dustin.w.morrow@cop.com
Contact Phone: 832-493-9141
Authorized Title: Staff Completions Engineer
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other:
Post Initial Injection MIT Req'd? Yes No
Spacing Exception Required? Yes No Subsequent Form Required:
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
AOGCC USE ONLY
11590
Tubing Grade: Tubing MD (ft):
TNT Packer @ 8,078' MD/ 4,023' TVD
LTP set at 8,270'MD / 4,061' TVD
Perforation Depth TVD (ft): Tubing Size:
L-80 8,261'
26-Feb-23
HAL TNT Prod Packer, Baker SLZXP
Packer/Hanger, No SSSV
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL380107/ADL025544/ADL025551
222-134
P.O. Box 100360 Anchorage, Alaska, 99510-0360 50-103-20847-01-00
ConocoPhillips
Length Size
Proposed Pools:
TVD Burst
PRESENT WELL CONDITION SUMMARY
17094
10860
MD
6890
5210
115
2573
3955
115
2910
40948438
7778
20"
10-3/4"
78
2873.3
Perforation Depth MD (ft):
7-5/8"7742.9
660
4-1/2" 173324639.6
4-1/2"
4267
7-5/8"
Perforate
Repair Wepair Well
Exploratory Stratigraphic Development Service
BOP TestMechanical Integrity Test Location Clearance
No
No
Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
By Samantha Carlisle at 10:49 am, Feb 14, 2023
323-092
X
VTL 02/22/2023
CDW 02/21/2023
10-404
DSR-2/15/23DLB 02/17/2023
X
GCW 02/23/23
JLC 2/23/2023
2/23/23
Brett W. Huber,
Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.02.23 14:32:07
-09'00'
RBDMS JSB 022423
Section 1 - Affidavit 10 AAC 25.283 (a)(1)
Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators
within one-half mile radius of the current or proposed wellbore trajectory have been provided
notice of operations in compliance with 20 AAC 25.283(a)(1).
Section 2 – Plat 20 AAC 25.283 (2)(A)
Plat 1: Wells within 1/2 mile
Table 1: Wells within 1/2 miles (2)(C)
3S-701A Frac sundry
wells that intersect well track buffer
Business Unit ID Business Area ID Field Name API * Well Name Well Type Status Symbology
KUP KRU KUPARUK RIVER UNIT 501032036100 PALM 1 EXPLOR PA Plugged and Abandoned
KUP KRU KUPARUK RIVER UNIT 501032036101 3S-26 INJ ACTIVE Injector Miscible Water Alternating Gas
KUP KRU KUPARUK RIVER UNIT 501032043000 3S-07 PROD ACTIVE Oil
KUP KRU KUPARUK RIVER UNIT 501032043200 3S-09 INJ ACTIVE Injector Miscible Water Alternating Gas
KUP KRU KUPARUK RIVER UNIT 501032043300 3S-18 PROD ACTIVE Oil
KUP KRU KUPARUK RIVER UNIT 501032043900 3S-14 INJ ACTIVE Injector Miscible Water Alternating Gas
KUP KRU KUPARUK RIVER UNIT 501032044000 3S-10 PROD ACTIVE Oil
KUP KRU KUPARUK RIVER UNIT 501032044400 3S-15 PROD PA Plugged and Abandoned
KUP KRU KUPARUK RIVER UNIT 501032044500 3S-16 INJ ACTIVE Injector Miscible Water Alternating Gas
KUP KRU KUPARUK RIVER UNIT 501032044600 3S-22 INJ ACTIVE Injector Miscible Water Alternating Gas
KUP KRU KUPARUK RIVER UNIT 501032044800 3S-17 INJ PA Plugged and Abandoned
KUP KRU KUPARUK RIVER UNIT 501032044801 3S-17A INJ ACTIVE Injector Miscible Water Alternating Gas
KUP KRU KUPARUK RIVER UNIT 501032045000 3S-08 PROD PA Plugged and Abandoned
KUP KRU KUPARUK RIVER UNIT 501032045001 3S-08A PROD PA Plugged and Abandoned
KUP KRU KUPARUK RIVER UNIT 501032045002 3S-08B PROD PA Plugged and Abandoned
KUP KRU KUPARUK RIVER UNIT 501032045003 3S-08C PROD ACTIVE Oil
KUP KRU KUPARUK RIVER UNIT 501032045060 3S-08CL1 PROD ACTIVE Oil
KUP KRU KUPARUK RIVER UNIT 501032045070 3S-08CL1PB1 EXPEND PA Plugged and Abandoned
KUP KRU KUPARUK RIVER UNIT 501032045200 3S-21 INJ ACTIVE Injector Miscible Water Alternating Gas
KUP KRU KUPARUK RIVER UNIT 501032045300 3S-23 PROD PA Plugged and Abandoned
KUP KRU KUPARUK RIVER UNIT 501032045301 3S-23A PROD ACTIVE Oil
KUP KRU KUPARUK RIVER UNIT 501032045400 3S-06 INJ PA Plugged and Abandoned
KUP KRU KUPARUK RIVER UNIT 501032045401 3S-06A INJ ACTIVE Injector Miscible Water Alternating Gas
KUP KRU KUPARUK RIVER UNIT 501032045600 3S-24 PROD PA Plugged and Abandoned
KUP KRU KUPARUK RIVER UNIT 501032045601 3S-24A PROD PA Plugged and Abandoned
KUP COYOTR01 TRACT OPERATION COYOTR01 501032045602 3S-24B PROD ACTIVE Oil
KUP KRU KUPARUK RIVER UNIT 501032045800 3S-03 PROD ACTIVE Oil
KUP KRU KUPARUK RIVER UNIT 501032046000 3S-19 PROD ACTIVE Oil
KUP COYOTR02 TRACT OPERATION COYOTR02 501032084700 3S-701 EXPLOR PROP Proposed
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 on12/23/2022 shows that the original job pumped as
designed. The cement job was pumped with 460 barrels of 10.7 ppg lead cement and 57
barrels 15.6 ppg tail cement, displaced with 9.7ppg mud. The plug was bumped and the
floats held. Cement returns came to surface.
The 7-5/8” casing cement report on 1/20/2023 shows that the job was pumped as designed,
indicating competent cementing operations. The first stage cement job was pumped with 77
barrels of 15.3 ppg. The plug was bumped and the floats held. A cement bond log indicates
competent cement with a cement top @ 6,800’ MD (3,723’ TVD).
Summary
All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone
penetrated by the well is isolated.
Based on engineering evaluation of the wells referenced in this application, ConocoPhillips
has determined that this well can be successfully fractured within its design limits.
SECTION 7 – PRESSURE TEST INFORMATION AND PLANS TO PRESSURE-TEST
CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7)
On 12/25/2022 the 10-3/4” casing was pressure tested to 3,000 psi for 30 minutes
On 1/20/2023 the 7-5/8” casing was pressure tested to 4,000 psi for 30 minutes.
On 2/4/2022 the 4-1/2” tubing was pressure tested to 4,450 psi. Good Test
On 2/4/2022 the 7-5/8” casing by 4.5 tubing annulus was pressure tested to 3,850 psi. Good
Test
AOGCC Required Pressures [all in psi]
Maximum Allowable Working Pressure (MPTP) 8,900
Maximum Predicted Treating Pressure (MPTP) 7,450
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 4,450
Electronic PRV 8,455
Highest pump trip 7,955
Does not meet 110% testing
requirement of tubing CDW 2/21/2023
SECTION 8 – PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE,
WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8)
Section Pipe OD
(in.)
Pipe
Weight
(ppf)
Pipe Grade API Burst
(psi)
API
Collapse
(psi)
API Axial
(klb)
Surface 10-3/4 45.5 L-80 5,210 2,470 1,040
Intermediate 7-5/8 29.7 L-80 6,890 4,790 683
Intermediate* 7-5/8 39.0 TN110SS 12,620 11,080 1,231
Prod. Liner 4-1/2 12.6 P-110S 11,590 9,210 396
Tubing 4-1/2 12.6 L-80 8,430 7,500 288
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 Coyote reservoir, has an average gross thickness of approximately
650 ft TVD over the course of the lateral section of well 3S-701A, from where it intersects the
top formation at ~8,379’ MD to TD of the well. The Coyote is comprised of thinly interbedded
sandstone, and siltstone layers. The sandstone and siltstone components are litharenites to
feldspathic litharenites, moderately to well sorted, and very fine grained. The estimated
fracture pressure for the Coyote interval is approximately 12.0 ppg.
The overlying confining interval of the Seabee Formation consists of mudstone and siltstone
with an average thickness of approximately 350’ TVD. The top of the Coyote confining
interval starts at ~3,739 ft. TVDSS (5,890’ MD). The estimated fracture gradient of the
overlying Seabee formation is approximately 0.65 psi/ft.
The lower confining zone consists of slope mudstones associated with the Torok formation.
They are present in thicknesses greater than 300’ TVD across the area. This same interval
forms the upper confining layer of the Kuparuk River, Torok Oil Pool. The estimated fracture
gradient for this section is approximately 16 ppg.
The estimated formation pressure is 1830 psi at a depth of 4150’ TVD (0.44 psi/ft gradient).
SECTION 10 – LOCATION, ORIENTATION AND A REPORT ON
MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT
CONFINING ZONE 20 AAC 25.283(a)(10)
The plat shows the location and orientation of each well that transects the confining zone.
ConocoPhillips has formed the opinion, based on following assessments for each well and
seismic, well, and other subsurface information currently available that none of these wells
will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius
of the proposed wellbore trajectory.
Casing & Cement assessments for all wells that transect the confining zone:
3S-03: The 7” production liner was cemented 53.3 bbls (256 sxs) 15.8ppg Class “G”. Plug
was bumped and the floats held. Calculated cement top at 2,805’ KB
3S-21: The 7” intermediate was cemented on 3/31/2003 with 36 bbls 15.8 ppg Class “G”,
plug was bumped, slight returns. Calculated cement top at 7,719’ MD.
The well was P&A’d in 2022:
8/12/2022, Set retainer at 9,200’, pumped 25.4 bbls of 15.8 ppg cement. 16.4 bbls below
retainer, 9 bbls above
9/12/2022, Casing perforated at 6,332’-6,482’, cement with 36 bbls 15.8 ppg
10/14/2022, 90 bbls 15.8 ppg Class “G” was pumped in OA with the cement top at surface.
10/17/2022, 250 BBLs of 15.8 ppg Class G Cement laid from 6500' to surface in production
casing.
3S-23: The 7” casing cement report on 4/18/2003 shows 53.5 bbls 15.8 ppg Class “G” was
pumped. Good returns throughout job.
3S-23A: This well was a sidetrack from the 3S-23, sidetracked at 4,090’ MD. The 7” casing
cement report on 5/9/2006 shows the 43 bbls of 15.8 ppg Class “G” cement was pumped.
Approximately 10-15% returns during the job and the plug did not bump. Calculated top of
cement at 9,471’ (10,491’ TD).
3S-24: The 7” casing cement report on 6/3/2003 shows a lead of 75 bbls of Lite Crete
cement was pumped at 4 bpm. Full returns throughout the job and the floats held. A 3-1/2”
production liner was run and cemented 198 bbls of 15.8ppg cement, full returns until 52 bbls
from end of cement job. Bumped the plug and floats held.
3S-24A: This well was a sidetrack from the 3S-24, sidetracked at 10,509’ MD in 2004. A 3-
1/2” liner was run and cemented with 88 bbls of 15.8ppg Clas “G”. Full returns throughout
job, the plug bumped and the floats held.
3S-24B: This well was a sidetrack from the 3S-24A, sidetracked at 7,301’ MD in 2021, drilled
to a TD of 8,724’ / 4,944’ TVD. A 4-1/2” liner was run and cemented with 37.8 bbls of
15.8ppg Clas “G”. The plug was bumped and the floats held. 5 bbls cement washed off the
linertop packer.
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 small offset fault transects the top of the Coyote interval within one half mile
radius of the wellbore trajectory of well 3S-701A. The fault is of small displacement and is present near
the heel of the future 3S-704 offset producer. The fault trend is oriented northwest to southeast, with
dip to the northeast. It has a maximum displacement of approximately 30’, and a length from tip to tip
of approximately 2000’. It cuts the Top Coyote and extends ~300’ into the overburden where it loses
throw and extends into the coyote reservoir by ~200’ where it also loses throw.
If there is any indication that a fracture has intersected a fault during fracturing operations,
ConocoPhillips will go to flush and terminate the stage immediately.
SECTION 12 – PROPOSED HYDRAULIC FRACTURING PROGRAM
20 AAC 25.283(a)(12)
3S-701A was completed in 2023 as a horizontal producer in the Coyote formation. The well
was completed with a 4.5” tubing upper completion and a 4.5” liner with a dart actuated
sliding sleeve lower completion. The first stage will be pumped through a slotted pup in the
toe of the lateral. After the 1st stage a frac dart will be dropped to shift open the 2nd stage
sleeve and isolate the first stage. The 2nd stage will then be pumped and a frac dart will be
dropped, the dart are all the same size and are electronically activated after counting the
sleeves passed en-route to the programed sleeve. This process is continued to the heel of
the well, the darts will provide isolation from the previous stage and allow fracturing across
the lateral section. Oil and water chemical tracers as well as radioactive proppant tracers are
planned for this stimulation.
Proposed Procedure:
Halliburton Pumping Services: (Coyote Frac)
1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition
to identify any pre-existing conditions.
2. Ensure all Pre-frac Well work has been completed and confirm the tubing and
annulus are filled with a freeze protect fluid to 2,000’ TVD.
3. Pressure test the rig installed frac tree to 10,000 psi.
4. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC.
5. MIRU 30 clean insulated Frac tanks, with a berm surrounding the tanks that can
hold a single tank volume plus 10%. Load tanks with 100º F seawater (approx.
2,200 barrels are required for each stage with breakdown, maximum pad and
pumping down the next ball. (450 bbls usable volume per tank).
6. MIRU HES Frac Equipment.
7. PT Surface lines to 10,000 psi using a Pressure test fluid.
8. Test IA Pop off system to ensure lines are clear and all components are functioning
properly.
9. Bring up pumps and increase annulus pressure from 2,500 psi to 3,500 psi as the
tubing pressures up.
10. Pump the breakdown stage (30# Hybor G) according to the attached excel HES
pump schedule. Bring pumps up to maximum rate of 25 BPM as quick as possible,
pressure permitting. Ensure sufficient volume is pumped to load the well with Frac
fluid, prior to shut down.
11. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates.
12. Pump the 16 stage Frac job by following attached HES schedule @ ~25bpm with a
maximum expected treating pressure of 7,450 psi.
13. RDMO HES Equipment. Freeze Protect the tubing and wellhead if not able to
complete following the flush.
14. Well is ready for Post Frac well prep/production tree installation and flowback
(Slickline and possibly CTU).
f 7,450 psi.
SECTION 13 – POST-FRACTURE WELLBORE CLEANUP AND FLUID
RECOVERY PLAN 20 AAC 25.283(a)(13)
Flowback will be initiated through a de-sander unit until the fluids clean up at which time it will
be turned over to production for initial clean up production before conversion to injection.
Hydraulic Fracturing Fluid Product Component Information Disclosure
2023-02-06
Alaska
HARRISON BAY
50-103-20847
CONOCOPHILLIPS
3S 701
-150.1948
70.3943
NAD83
none
Oil
4267
1323181
Hydraulic Fracturing Fluid Composition:
Trade Name Supplier Purpose Ingredients
Chemical
Abstract
Service
Number
(CAS #)
Maximum Ingredient
Concentration in
Additive (% by mass)**
Maximum
Ingredient
Concentration
in HF Fluid (%
by mass)**
Ingredient Mass
lbs Comments Company First Name Last Name Email Phone
SEAWATER (SG
8.52)Halliburton Base Fluid Water 7732-18-5 100.00%69.65449%11273503 Density = 8.52 Halliburton
BC-140 X2 Halliburton Initiator Listed Below Listed Below 0
BE-6(TM)
Bactericide Halliburton Microbiocide Listed Below Listed Below 0
CAT-3
ACTIVATOR Halliburton Activator Listed Below Listed Below 0
LoSurf-300D Halliburton Non-ionic Surfactant Listed Below Listed Below 0
LVT-200
Baker
Hughes Additive Listed Below Listed Below 0 NA
MO-67 Halliburton pH Control Listed Below Listed Below 0
OPTIFLO-II
DELAYED
RELEASE
BREAKER Halliburton Breaker Listed Below Listed Below 0
WG-36 GELLING
AGENT Halliburton Gelling Agent Listed Below Listed Below 0
Ceramic
Proppant - Wanli Wanli Proppant Listed Below Listed Below 0 NA
Sand-Common
White-100 Mesh,
SSA-2 Halliburton Proppant Listed Below Listed Below 0
Ingredients
Listed
Above Listed Above 1,2,4 Trimethylbenzene 95-63-6 1.00%0.00062%101
2,7-Naphthalenedisulfonic acid, 3-
hydroxy-4-[(4-sulfor-1-
naphthalenyl) azo] -, trisodium
salt 915-67-3 0.10%0.00004%7
2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00%0.00123%199
Ammonia 7664-41-7 1.00%0.00123%200
Ammonium chloride 12125-02-9 5.00%0.00616%998
Ammonium persulfate 7727-54-0 100.00%0.01453%2352
C.I. pigment Orange 5 3468-63-1 1.00%0.00015%24
Corundum 1302-74-5 65.00%18.89777%3058583
Crystalline silica, quartz 14808-60-7 100.00%0.40835%66092
Distillates (petroleum),
hydrotreated light 64742-47-8 100.00%0.34205%55360
EDTA/Copper chelate Proprietary 30.00%0.03698%5985
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%0.03727%6033
Ethylene glycol 107-21-1 30.00%0.01126%1823
Guar gum 9000-30-0 100.00%0.24526%39695
Heavy aromatic petroleum
naphtha 64742-94-5 30.00%0.01864%3017
Monoethanolamine borate 26038-87-9 100.00%0.03754%6076
Mullite 1302-93-8 45.00%13.08307%2117481
Naphthalene 91-20-3 5.00%0.00311%503
Oxyalkylated nonyl phenolic resin Proprietary 30.00%0.01864%3017 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Oxyalkylated phenolic resin Proprietary 10.00%0.00621%1006 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Oxylated phenolic resin Proprietary 30.00%0.00436%706 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Poly(oxy-1,2-ethanediyl), alpha-(4-
nonylphenyl)-omega-hydroxy-,
branched 127087-87-0 5.00%0.00311%503
Sodium chloride 7647-14-5 5.00%3.48312%563739
Sodium hydroxide 1310-73-2 30.00%0.01174%1900
Water 7732-18-5 100.00%0.17365%28105
* Total Water Volume sources may include fresh water, produced water, and/or recycled water _
** Information is based on the maximum potential for concentration and thus the total may be over 100%
Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided.Version web 1.3
All component information listed was obtained from the supplier’s 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 Administration’s (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:
CUSTOMERConoco Phillips FALSEAPIBFD (lb/gal)8.54LAT 70.3943093LEASE3S-701SALES ORDERBHST (°F)105LONG-150.194818FORMATIONCoyoteDATE Max Pressure (psi)9000*Exceeds 80% of burst pressure*Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval BC-140X2 Losurf-300D MO-67 CAT-3 LVT-200 WG-36 OPTIFLO-IIBE-6TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer Catalyst Freeze ProtectInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt)1-1 Shut-In Shut-In2:33:45 1-2 Freeze Protect Prime Up Pressure Test 5 1,260 30 30 0:06:00 2:33:45 1000.001-3 Shut-In Shut-In2:27:45 1-4 25# Linear Load Well 10 1,050 25 25 0:02:30 2:27:45 1.00 25.00 1.00 0.151-5 25# Linear Displacement 10 10,926 260 260 0:26:01 2:25:15 1.00 25.00 1.00 0.151-6 25# Linear Step Rate Test 15 4,200 100 100 0:06:40 1:59:14 1.00 25.00 1.00 0.151-7 25# Delta Frac Establish Stable Fluid 15 4,200 100 100 0:06:40 1:52:34 0.50 1.00 0.50 1.00 25.00 1.00 0.151-8 25# Delta Frac Minifrac 25 6,300 150 150 0:06:00 1:45:54 0.50 1.00 0.50 1.00 25.00 1.00 0.151-9 25# Linear Flush 25 10,926 260 260 0:10:24 1:39:54 1.00 25.00 1.00 0.151-10 Shut-In Shut-In1:29:30 1-11 25# Linear Establish Stable Fluid 25 4,200 100 100 0:04:00 1:29:30 1.00 25.00 1.00 0.151-12 25# Delta Frac Pad 25 21,000 500 500 0:20:00 1:25:30 0.50 1.00 0.50 1.00 25.00 1.00 0.151-13 25# Delta Frac Proppant Laden Fluid 100M 0.50 25 8,232 196 200 4,116 0:08:01 1:05:30 0.50 1.00 0.50 1.00 25.00 1.00 0.151-14 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 25 3,864 92 100 7,728 0:04:01 0:57:29 0.50 1.00 0.50 1.00 25.00 1.00 0.151-15 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 25 6,426 153 180 25,704 0:07:14 0:53:28 0.50 1.00 0.50 1.00 25.00 1.00 0.151-16 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 25 6,132 146 185 36,792 0:07:26 0:46:13 0.50 1.00 0.50 1.00 25.00 1.00 0.151-17 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 25 9,618 229 300 67,326 0:12:05 0:38:47 0.50 1.00 0.50 1.00 25.00 1.00 0.151-18 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 25 8,694 207 281 69,552 0:11:18 0:26:42 0.50 1.00 0.50 1.00 25.00 1.00 0.151-19 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 25 6,006 143 200 54,054 0:08:04 0:15:24 0.50 1.00 0.50 1.00 25.00 1.00 0.151-20 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 25 3,486 83 120 34,860 0:04:50 0:07:20 0.50 1.00 0.50 1.00 25.00 1.00 0.151-21 25# Delta Frac Spacer and Dart Drop 12 1,260 30 30 0:02:30 0:02:30 0.50 1.00 0.50 1.00 25.00 1.00 0.152-1 25# Delta Frac Pad 25 21,000 500 500 0:20:00 1:37:15 0.50 1.00 0.50 1.00 25.00 1.00 0.152-2 25# Delta Frac Proppant Laden Fluid 100M 0.50 25 8,232 196 200 4,116 0:08:01 1:17:15 0.50 1.0000 0.50 1.00 25.00 1.00 0.152-3 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 25 3,864 92 100 7,728 0:04:01 1:09:14 0.50 1.00 0.50 1.00 25.00 1.00 0.152-4 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 25 6,426 153 180 25,704 0:07:14 1:05:13 0.50 1.00 0.50 1.00 25.00 1.00 0.152-5 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 25 6,132 146 185 36,792 0:07:26 0:57:59 0.50 1.00 0.50 1.00 25.00 1.00 0.152-6 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 25 9,618 229 300 67,326 0:12:05 0:50:32 0.50 1.00 0.50 1.00 25.00 1.00 0.152-7 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 25 8,694 207 281 69,552 0:11:18 0:38:27 0.50 1.00 0.50 1.00 25.00 1.00 0.152-8 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 25 6,006 143 200 54,054 0:08:04 0:27:09 0.50 1.00 0.50 1.00 25.00 1.00 0.152-9 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 25 3,486 83 120 34,860 0:04:50 0:19:05 0.50 1.00 0.50 1.00 25.00 1.00 0.152-10 25# Linear Flush 25 10,591 252 252 0:10:05 0:14:15 1.00 25.00 1.00 0.152-11 Freeze Protect Freeze Protect 12 2,100 50 50 0:04:10 0:04:10 1000.003-1 Shut-In Shut-In1:34:12 3-2 Freeze Protect Prime Up Pressure Test 5 1,260 30 30 0:06:00 1:34:12 1000.003-3 Shut-In Shut-In1:28:12 3-4 25# Linear Establish Stable Fluid 25 4,200 100 100 0:04:00 1:28:12 1.00 25.00 1.00 0.153-5 25# Delta Frac Pad 25 21,000 500 500 0:20:00 1:24:12 0.50 1.00 0.50 1.00 25.00 1.00 0.153-6 25# Delta Frac Proppant Laden Fluid 100M 0.50 25 8,232 196 200 4,116 0:08:01 1:04:12 0.50 1.00 0.50 1.00 25.00 1.00 0.153-7 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 25 3,864 92 100 7,728 0:04:01 0:56:11 0.50 1.00 0.50 1.00 25.00 1.00 0.153-8 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 25 6,426 153 180 25,704 0:07:14 0:52:10 0.50 1.00 0.50 1.00 25.00 1.00 0.153-9 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 25 6,132 146 185 36,792 0:07:26 0:44:55 0.50 1.00 0.50 1.00 25.00 1.00 0.153-10 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 25 9,618 229 300 67,326 0:12:05 0:37:29 0.50 1.00 0.50 1.00 25.00 1.00 0.153-11 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 25 8,694 207 281 69,552 0:11:18 0:25:24 0.50 1.00 0.50 1.00 25.00 1.00 0.153-12 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 25 6,006 143 200 54,054 0:08:04 0:14:06 0.50 1.00 0.50 1.00 25.00 1.00 0.153-13 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 25 3,486 83 120 34,860 0:04:50 0:06:02 0.50 1.00 0.50 1.00 25.00 1.00 0.153-14 25# Delta Frac Spacer and Dart Drop 25 1,260 30 30 0:01:12 0:01:12 0.50 1.00 0.50 1.00 25.00 1.00 0.154-1 25# Delta Frac Pad 25 21,000 500 100 0:20:00 1:36:36 0.50 1.00 0.50 1.00 25.00 0.154-2 25# Delta Frac Proppant Laden Fluid 100M 0.50 25 8,232 196 500 4,116 0:08:01 1:16:36 0.50 1.00 0.50 1.00 25.00 1.00 0.154-3 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 25 3,864 92 200 7,728 0:04:01 1:08:35 0.50 1.00 0.50 1.00 25.00 1.00 0.154-4 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 25 6,426 153 100 25,704 0:07:14 1:04:34 0.50 1.00 0.50 1.00 25.00 1.00 0.154-5 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 25 6,132 146 180 36,792 0:07:26 0:57:20 0.50 1.00 0.50 1.00 25.00 1.00 0.154-6 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 25 9,618 229 185 67,326 0:12:05 0:49:54 0.50 1.00 0.50 1.00 25.00 1.00 0.154-7 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 25 8,694 207 300 69,552 0:11:18 0:37:49 0.50 1.00 0.50 1.00 25.00 1.00 0.154-8 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 25 6,006 143 281 54,054 0:08:04 0:26:31 0.50 1.00 0.50 1.00 25.00 1.00 0.154-9 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 25 3,486 83 200 34,860 0:04:50 0:18:27 0.50 1.00 0.50 1.00 25.00 1.00 0.154-10 25# Linear Flush 25 9,916 236 120 0:09:27 0:13:37 1.00 25.00 1.00 0.154-11 Freeze Protect Freeze Protect 12 2,100 50 30 0:04:10 0:04:10 1000.004-12 Shut-In Shut-In2/28/23Liquid AdditivesDry Additives50-103-20847Interval 1Coyote@ 17094 - 17096.78 ft 104.8 °FInterval 2Coyote@ 16569 - 16571.78 ft 104.6 °FInterval 3Coyote@ 16042 - 16044.78 ft 104.5 °FInterval 4Coyote@ 15513 - 15515.78 ft 104.5 °FConoco Phillips - MT7-05Planned Design1
CUSTOMERConoco Phillips FALSEAPIBFD (lb/gal)8.54LAT 70.3943093LEASE3S-701SALES ORDERBHST (°F)105LONG-150.194818FORMATIONCoyoteDATE Max Pressure (psi)9000*Exceeds 80% of burst pressure*Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval BC-140X2 Losurf-300D MO-67 CAT-3 LVT-200 WG-36 OPTIFLO-IIBE-6TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer Catalyst Freeze ProtectInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt)2/28/23Liquid AdditivesDry Additives50-103-208475-1 Shut-In Shut-In1:34:12 5-2 Freeze Protect Prime Up Pressure Test 5 1,260 30 30 0:06:00 1:34:12 1000.005-3 Shut-In Shut-In1:28:12 5-4 25# Linear Establish Stable Fluid 25 4,200 100 100 0:04:00 1:28:12 1.00 25.00 1.00 0.155-5 25# Delta Frac Pad 25 21,000 500 500 0:20:00 1:24:12 0.50 1.00 0.50 1.00 25.00 1.00 0.155-6 25# Delta Frac Proppant Laden Fluid 100M 0.50 25 8,232 196 200 4,116 0:08:01 1:04:12 0.50 1.00 0.50 1.00 25.00 1.00 0.155-7 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 25 3,864 92 100 7,728 0:04:01 0:56:11 0.50 1.00 0.50 1.00 25.00 1.00 0.155-8 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 25 6,426 153 180 25,704 0:07:14 0:52:10 0.50 1.00 0.50 1.00 25.00 1.00 0.155-9 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 25 6,132 146 185 36,792 0:07:26 0:44:55 0.50 1.00 0.50 1.00 25.00 1.00 0.155-10 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 25 9,618 229 300 67,326 0:12:05 0:37:29 0.50 1.00 0.50 1.00 25.00 1.00 0.155-11 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 25 8,694 207 281 69,552 0:11:18 0:25:24 0.50 1.00 0.50 1.00 25.00 1.00 0.155-12 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 25 6,006 143 200 54,054 0:08:04 0:14:06 0.50 1.00 0.50 1.00 25.00 1.00 0.155-13 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 25 3,486 83 120 34,860 0:04:50 0:06:02 0.50 1.00 0.50 1.00 25.00 1.00 0.155-14 25# Delta Frac Spacer and Dart Drop 25 1,260 30 30 0:01:12 0:01:12 0.50 1.00 0.50 1.00 25.00 1.00 0.156-1 25# Delta Frac Pad 25 21,000 500 500 0:20:00 1:35:59 0.50 1.00 0.50 1.00 25.00 0.156-2 25# Delta Frac Proppant Laden Fluid 100M 0.50 25 8,232 196 200 4,116 0:08:01 1:15:59 0.50 1.00 0.50 1.00 25.00 1.00 0.156-3 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 25 3,864 92 100 7,728 0:04:01 1:07:58 0.50 1.00 0.50 1.00 25.00 1.00 0.156-4 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 25 6,426 153 180 25,704 0:07:14 1:03:57 0.50 1.00 0.50 1.00 25.00 1.00 0.156-5 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 25 6,132 146 185 36,792 0:07:26 0:56:43 0.50 1.00 0.50 1.00 25.00 1.00 0.156-6 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 25 9,618 229 300 67,326 0:12:05 0:49:17 0.50 1.00 0.50 1.00 25.00 1.00 0.156-7 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 25 8,694 207 281 69,552 0:11:18 0:37:12 0.50 1.00 0.50 1.00 25.00 1.00 0.156-8 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 25 6,006 143 200 54,054 0:08:04 0:25:54 0.50 1.00 0.50 1.00 25.00 1.00 0.156-9 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 25 3,486 83 120 34,860 0:04:50 0:17:50 0.50 1.00 0.50 1.00 25.00 1.00 0.156-10 25# Linear Flush 25 9,268 221 221 0:08:50 0:13:00 1.00 25.00 1.00 0.156-11 Freeze Protect Freeze Protect 12 2,100 50 50 0:04:10 0:04:10 1000.006-12 Shut-In Shut-In7-1 Shut-In Shut-In1:34:12 7-2 Freeze Protect Prime Up Pressure Test 5 1,260 30 30 0:06:00 1:34:12 1000.007-3 Shut-In Shut-In1:28:12 7-4 25# Linear Establish Stable Fluid 25 4,200 100 100 0:04:00 1:28:12 1.00 25.00 1.00 0.157-5 25# Delta Frac Pad 25 21,000 500 500 0:20:00 1:24:12 0.50 1.00 0.50 1.00 25.00 1.00 0.157-6 25# Delta Frac Proppant Laden Fluid 100M 0.50 25 8,232 196 200 4,116 0:08:01 1:04:12 0.50 1.00 0.50 1.00 25.00 1.00 0.157-7 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 25 3,864 92 100 7,728 0:04:01 0:56:11 0.50 1.00 0.50 1.00 25.00 1.00 0.157-8 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 25 6,426 153 180 25,704 0:07:14 0:52:10 0.50 1.00 0.50 1.00 25.00 1.00 0.157-9 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 25 6,132 146 185 36,792 0:07:26 0:44:55 0.50 1.00 0.50 1.00 25.00 1.00 0.157-10 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 25 9,618 229 300 67,326 0:12:05 0:37:29 0.50 1.00 0.50 1.00 25.00 1.00 0.157-11 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 25 8,694 207 281 69,552 0:11:18 0:25:24 0.50 1.00 0.50 1.00 25.00 1.00 0.157-12 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 25 6,006 143 200 54,054 0:08:04 0:14:06 0.50 1.00 0.50 1.00 25.00 1.00 0.157-13 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 25 3,486 83 120 34,860 0:04:50 0:06:02 0.50 1.00 0.50 1.00 25.00 1.00 0.157-14 25# Delta Frac Spacer and Dart Drop 25 1,260 30 30 0:01:12 0:01:12 0.50 1.00 0.50 1.00 25.00 1.00 0.158-1 25# Delta Frac Pad 25 21,000 500 500 0:20:00 1:35:24 0.50 1.00 0.50 1.00 25.00 0.158-2 25# Delta Frac Proppant Laden Fluid 100M 0.50 25 8,232 196 200 4,116 0:08:01 1:15:24 0.50 1.00 0.50 1.00 25.00 1.00 0.158-3 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 25 3,864 92 100 7,728 0:04:01 1:07:23 0.50 1.00 0.50 1.00 25.00 1.00 0.158-4 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 25 6,426 153 180 25,704 0:07:14 1:03:22 0.50 1.00 0.50 1.00 25.00 1.00 0.158-5 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 25 6,132 146 185 36,792 0:07:26 0:56:08 0.50 1.00 0.50 1.00 25.00 1.00 0.158-6 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 25 9,618 229 300 67,326 0:12:05 0:48:41 0.50 1.00 0.50 1.00 25.00 1.00 0.158-7 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 25 8,694 207 281 69,552 0:11:18 0:36:36 0.50 1.00 0.50 1.00 25.00 1.00 0.158-8 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 25 6,006 143 200 54,054 0:08:04 0:25:18 0.50 1.00 0.50 1.00 25.00 1.00 0.158-9 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 25 3,486 83 120 34,860 0:04:50 0:17:14 0.50 1.00 0.50 1.00 25.00 1.00 0.158-10 25# Linear Flush 25 8,649 206 206 0:08:14 0:12:24 1.00 25.00 1.00 0.158-11 Freeze Protect Freeze Protect 12 2,100 50 50 0:04:10 0:04:10 1000.008-12 Shut-In Shut-InInterval 5Coyote@ 14987 - 14989.78 ft 104.4 °FInterval 6Coyote@ 14500 - 14502.78 ft 104.3 °FInterval 7Coyote@ 14015 - 14017.78 ft 104.2 °FInterval 8Coyote@ 13531 - 13533.78 ft 104.1 °FConoco Phillips - MT7-05Planned Design2
CUSTOMERConoco Phillips FALSEAPIBFD (lb/gal)8.54LAT 70.3943093LEASE3S-701SALES ORDERBHST (°F)105LONG-150.194818FORMATIONCoyoteDATE Max Pressure (psi)9000*Exceeds 80% of burst pressure*Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval BC-140X2 Losurf-300D MO-67 CAT-3 LVT-200 WG-36 OPTIFLO-IIBE-6TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer Catalyst Freeze ProtectInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt)2/28/23Liquid AdditivesDry Additives50-103-208479-1 Shut-In Shut-In1:34:12 9-2 Freeze Protect Prime Up Pressure Test 5 1,260 30 30 0:06:00 1:34:12 1000.009-3 Shut-In Shut-In1:28:12 9-4 25# Linear Establish Stable Fluid 25 4,200 100 100 0:04:00 1:28:12 1.00 25.00 1.00 0.159-5 25# Delta Frac Pad 25 21,000 500 500 0:20:00 1:24:12 0.50 1.00 0.50 1.00 25.00 1.00 0.159-6 25# Delta Frac Proppant Laden Fluid 100M 0.50 25 8,232 196 200 4,116 0:08:01 1:04:12 0.50 1.00 0.50 1.00 25.00 1.00 0.159-7 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 25 3,864 92 100 7,728 0:04:01 0:56:11 0.50 1.00 0.50 1.00 25.00 1.00 0.159-8 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 25 6,426 153 180 25,704 0:07:14 0:52:10 0.50 1.00 0.50 1.00 25.00 1.00 0.159-9 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 25 6,132 146 185 36,792 0:07:26 0:44:55 0.50 1.00 0.50 1.00 25.00 1.00 0.159-10 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 25 9,618 229 300 67,326 0:12:05 0:37:29 0.50 1.00 0.50 1.00 25.00 1.00 0.159-11 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 25 8,694 207 281 69,552 0:11:18 0:25:24 0.50 1.00 0.50 1.00 25.00 1.00 0.159-12 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 25 6,006 143 200 54,054 0:08:04 0:14:06 0.50 1.00 0.50 1.00 25.00 1.00 0.159-13 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 25 3,486 83 120 34,860 0:04:50 0:06:02 0.50 1.00 0.50 1.00 25.00 1.00 0.159-14 25# Delta Frac Spacer and Dart Drop 25 1,260 30 30 0:01:12 0:01:12 0.50 1.00 0.50 1.00 25.00 1.00 0.1510-1 25# Delta Frac Pad 25 21,000 500 500 0:20:00 1:34:48 0.50 1.00 0.50 1.00 25.00 0.1510-2 25# Delta Frac Proppant Laden Fluid 100M 0.50 25 8,232 196 200 4,116 0:08:01 1:14:48 0.50 1.00 0.50 1.00 25.00 1.00 0.1510-3 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 25 3,864 92 100 7,728 0:04:01 1:06:47 0.50 1.00 0.50 1.00 25.00 1.00 0.1510-4 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 25 6,426 153 180 25,704 0:07:14 1:02:46 0.50 1.00 0.50 1.00 25.00 1.00 0.1510-5 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 25 6,132 146 185 36,792 0:07:26 0:55:32 0.50 1.00 0.50 1.00 25.00 1.00 0.1510-6 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 25 9,618 229 300 67,326 0:12:05 0:48:06 0.50 1.00 0.50 1.00 25.00 1.00 0.1510-7 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 25 8,694 207 281 69,552 0:11:18 0:36:01 0.50 1.00 0.50 1.00 25.00 1.00 0.1510-8 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 25 6,006 143 200 54,054 0:08:04 0:24:43 0.50 1.00 0.50 1.00 25.00 1.00 0.1510-9 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 25 3,486 83 120 34,860 0:04:50 0:16:39 0.50 1.00 0.50 1.00 25.00 1.00 0.1510-10 25# Linear Flush 25 8,026 191 191 0:07:39 0:11:49 1.00 25.00 1.00 0.1510-11 Freeze Protect Freeze Protect 12 2,100 50 50 0:04:10 0:04:10 1000.0010-12 Shut-In Shut-In11-1 Shut-In Shut-In1:34:12 11-2 Freeze Protect Prime Up Pressure Test 5 1,260 30 30 0:06:00 1:34:12 1000.0011-3 Shut-In Shut-In1:28:12 11-4 25# Linear Establish Stable Fluid 25 4,200 100 100 0:04:00 1:28:12 1.00 25.00 1.00 0.1511-5 25# Delta Frac Pad 25 21,000 500 500 0:20:00 1:24:12 0.50 1.00 0.50 1.00 25.00 1.00 0.1511-6 25# Delta Frac Proppant Laden Fluid 100M 0.50 25 8,232 196 200 4,116 0:08:01 1:04:12 0.50 1.00 0.50 1.00 25.00 1.00 0.1511-7 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 25 3,864 92 100 7,728 0:04:01 0:56:11 0.50 1.00 0.50 1.00 25.00 1.00 0.1511-8 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 25 6,426 153 180 25,704 0:07:14 0:52:10 0.50 1.00 0.50 1.00 25.00 1.00 0.1511-9 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 25 6,132 146 185 36,792 0:07:26 0:44:55 0.50 1.00 0.50 1.00 25.00 1.00 0.1511-10 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 25 9,618 229 300 67,326 0:12:05 0:37:29 0.50 1.00 0.50 1.00 25.00 1.00 0.1511-11 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 25 8,694 207 281 69,552 0:11:18 0:25:24 0.50 1.00 0.50 1.00 25.00 1.00 0.1511-12 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 25 6,006 143 200 54,054 0:08:04 0:14:06 0.50 1.00 0.50 1.00 25.00 1.00 0.1511-13 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 25 3,486 83 120 34,860 0:04:50 0:06:02 0.50 1.00 0.50 1.00 25.00 1.00 0.1511-14 25# Delta Frac Spacer and Dart Drop 25 1,260 30 30 0:01:12 0:01:12 0.50 1.00 0.50 1.00 25.00 1.00 0.1512-1 25# Delta Frac Pad 25 21,000 500 500 0:20:00 1:34:11 0.50 1.00 0.50 1.00 25.00 0.1512-2 25# Delta Frac Proppant Laden Fluid 100M 0.50 25 8,232 196 200 4,116 0:08:01 1:14:11 0.50 1.00 0.50 1.00 25.00 1.00 0.1512-3 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 25 3,864 92 100 7,728 0:04:01 1:06:10 0.50 1.00 0.50 1.00 25.00 1.00 0.1512-4 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 25 6,426 153 180 25,704 0:07:14 1:02:09 0.50 1.00 0.50 1.00 25.00 1.00 0.1512-5 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 25 6,132 146 185 36,792 0:07:26 0:54:55 0.50 1.00 0.50 1.00 25.00 1.00 0.1512-6 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 25 9,618 229 300 67,326 0:12:05 0:47:29 0.50 1.00 0.50 1.00 25.00 1.00 0.1512-7 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 25 8,694 207 281 69,552 0:11:18 0:35:24 0.50 1.00 0.50 1.00 25.00 1.00 0.1512-8 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 25 6,006 143 200 54,054 0:08:04 0:24:06 0.50 1.00 0.50 1.00 25.00 1.00 0.1512-9 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 25 3,486 83 120 34,860 0:04:50 0:16:02 0.50 1.00 0.50 1.00 25.00 1.00 0.1512-10 25# Linear Flush 25 7,380 176 176 0:07:02 0:11:12 1.00 25.00 1.00 0.1512-11 Freeze Protect Freeze Protect 12 2,100 50 50 0:04:10 0:04:10 1000.0012-12 Shut-In Shut-InInterval 12Coyote@ 11546 - 11548.78 ft 104 °FInterval 9Coyote@ 13044 - 13046.78 ft 104 °FInterval 10Coyote@ 12557 - 12559.78 ft 104 °FInterval 11Coyote@ 12071 - 12073.78 ft 104 °FConoco Phillips - MT7-05Planned Design3
CUSTOMERConoco Phillips FALSEAPIBFD (lb/gal)8.54LAT 70.3943093LEASE3S-701SALES ORDERBHST (°F)105LONG-150.194818FORMATIONCoyoteDATE Max Pressure (psi)9000*Exceeds 80% of burst pressure*Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval BC-140X2 Losurf-300D MO-67 CAT-3 LVT-200 WG-36 OPTIFLO-IIBE-6TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer Catalyst Freeze ProtectInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt)2/28/23Liquid AdditivesDry Additives50-103-2084713-1 Shut-In Shut-In1:34:12 13-2 Freeze Protect Prime Up Pressure Test 5 1,260 30 30 0:06:00 1:34:12 1000.0013-3 Shut-In Shut-In1:28:12 13-4 25# Linear Establish Stable Fluid 25 4,200 100 100 0:04:00 1:28:12 1.00 25.00 1.00 0.1513-5 25# Delta Frac Pad 25 21,000 500 500 0:20:00 1:24:12 0.50 1.00 0.50 1.00 25.00 1.00 0.1513-6 25# Delta Frac Proppant Laden Fluid 100M 0.50 25 8,232 196 200 4,116 0:08:01 1:04:12 0.50 1.00 0.50 1.00 25.00 1.00 0.1513-7 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 25 3,864 92 100 7,728 0:04:01 0:56:11 0.50 1.00 0.50 1.00 25.00 1.00 0.1513-8 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 25 6,426 153 180 25,704 0:07:14 0:52:10 0.50 1.00 0.50 1.00 25.00 1.00 0.1513-9 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 25 6,132 146 185 36,792 0:07:26 0:44:55 0.50 1.00 0.50 1.00 25.00 1.00 0.1513-10 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 25 9,618 229 300 67,326 0:12:05 0:37:29 0.50 1.00 0.50 1.00 25.00 1.00 0.1513-11 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 25 8,694 207 281 69,552 0:11:18 0:25:24 0.50 1.00 0.50 1.00 25.00 1.00 0.1513-12 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 25 6,006 143 200 54,054 0:08:04 0:14:06 0.50 1.00 0.50 1.00 25.00 1.00 0.1513-13 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 25 3,486 83 120 34,860 0:04:50 0:06:02 0.50 1.00 0.50 1.00 25.00 1.00 0.1513-14 25# Delta Frac Spacer and Dart Drop 25 1,260 30 30 0:01:12 0:01:12 0.50 1.00 0.50 1.00 25.00 1.00 0.1514-1 25# Delta Frac Pad 25 21,000 500 500 0:20:00 1:33:33 0.50 1.00 0.50 1.00 25.00 0.1514-2 25# Delta Frac Proppant Laden Fluid 100M 0.50 25 8,232 196 200 4,116 0:08:01 1:13:33 0.50 1.00 0.50 1.00 25.00 1.00 0.1514-3 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 25 3,864 92 100 7,728 0:04:01 1:05:32 0.50 1.00 0.50 1.00 25.00 1.00 0.1514-4 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 25 6,426 153 180 25,704 0:07:14 1:01:31 0.50 1.00 0.50 1.00 25.00 1.00 0.1514-5 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 25 6,132 146 185 36,792 0:07:26 0:54:17 0.50 1.00 0.50 1.00 25.00 1.00 0.1514-6 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 25 9,618 229 300 67,326 0:12:05 0:46:50 0.50 1.00 0.50 1.00 25.00 1.00 0.1514-7 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 25 8,694 207 281 69,552 0:11:18 0:34:45 0.50 1.00 0.50 1.00 25.00 1.00 0.1514-8 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 25 6,006 143 200 54,054 0:08:04 0:23:27 0.50 1.00 0.50 1.00 25.00 1.00 0.1514-9 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 25 3,486 83 120 34,860 0:04:50 0:15:23 0.50 1.00 0.50 1.00 25.00 1.00 0.1514-10 25# Linear Flush 25 6,706 160 160 0:06:23 0:10:33 1.00 25.00 1.00 0.1514-11 Freeze Protect Freeze Protect 12 2,100 50 50 0:04:10 0:04:10 1000.0014-12 Shut-In Shut-In15-1 Shut-In Shut-In1:34:12 15-2 Freeze Protect Prime Up Pressure Test 5 1,260 30 30 0:06:00 1:34:12 1000.0015-3 Shut-In Shut-In1:28:12 15-4 25# Linear Establish Stable Fluid 25 4,200 100 100 0:04:00 1:28:12 1.00 25.00 1.00 0.1515-5 25# Delta Frac Pad 25 21,000 500 500 0:20:00 1:24:12 0.50 1.00 0.50 1.00 25.00 1.00 0.1515-6 25# Delta Frac Proppant Laden Fluid 100M 0.50 25 8,232 196 200 4,116 0:08:01 1:04:12 0.50 1.00 0.50 1.00 25.00 1.00 0.1515-7 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 25 3,864 92 100 7,728 0:04:01 0:56:11 0.50 1.00 0.50 1.00 25.00 1.00 0.1515-8 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 25 6,426 153 180 25,704 0:07:14 0:52:10 0.50 1.00 0.50 1.00 25.00 1.00 0.1515-9 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 25 6,132 146 185 36,792 0:07:26 0:44:55 0.50 1.00 0.50 1.00 25.00 1.00 0.1515-10 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 25 9,618 229 300 67,326 0:12:05 0:37:29 0.50 1.00 0.50 1.00 25.00 1.00 0.1515-11 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 25 8,694 207 281 69,552 0:11:18 0:25:24 0.50 1.00 0.50 1.00 25.00 1.00 0.1515-12 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 25 6,006 143 200 54,054 0:08:04 0:14:06 0.50 1.00 0.50 1.00 25.00 1.00 0.1515-13 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 25 3,486 83 120 34,860 0:04:50 0:06:02 0.50 1.00 0.50 1.00 25.00 1.00 0.1515-14 25# Delta Frac Spacer and Dart Drop 25 1,260 30 30 0:01:12 0:01:12 0.50 1.00 0.50 1.00 25.00 1.00 0.1516-1 25# Delta Frac Pad 25 21,000 500 500 0:20:00 1:32:54 0.50 1.00 0.50 1.00 25.00 0.1516-2 25# Delta Frac Proppant Laden Fluid 100M 0.50 25 8,232 196 200 4,116 0:08:01 1:12:54 0.50 1.00 0.50 1.00 25.00 1.00 0.1516-3 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 25 3,864 92 100 7,728 0:04:01 1:04:53 0.50 1.00 0.50 1.00 25.00 1.00 0.1516-4 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 25 6,426 153 180 25,704 0:07:14 1:00:52 0.50 1.00 0.50 1.00 25.00 1.00 0.1516-5 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 25 6,132 146 185 36,792 0:07:26 0:53:38 0.50 1.00 0.50 1.00 25.00 1.00 0.1516-6 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 25 9,618 229 300 67,326 0:12:05 0:46:12 0.50 1.00 0.50 1.00 25.00 1.00 0.1516-7 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 25 8,694 207 281 69,552 0:11:18 0:34:07 0.50 1.00 0.50 1.00 25.00 1.00 0.1516-8 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 25 6,006 143 200 54,054 0:08:04 0:22:49 0.50 1.00 0.50 1.00 25.00 1.00 0.1516-9 25# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 25 3,486 83 120 34,860 0:04:50 0:14:45 0.50 1.00 0.50 1.00 25.00 1.00 0.1516-10 25# Linear Flush 25 6,033 144 144 0:05:45 0:09:55 1.00 25.00 1.00 0.1516-11 Freeze Protect Freeze Protect 12 2,100 50 50 0:04:10 0:04:10 1000.0016-12 Shut-In Shut-In1,350,061 32,144 37,089 4,802,112Design Total (gal)Design Total (lbs)BC-140X2 Losurf-300D MO-67 CAT-3 LVT-200 WG-36 OPTIFLO-II BE-61,195,9084,736,256(gal) (gal) (gal) (gal) (gal) (lbs) (lbs) (lbs)127,27365,856Initial Design Material Volume 598.0 1,323.2 598.0 1,195.9 26,880.0 33,079.5 1,176.2 198.5-26,880-Whole Units to be ordered--BC-140X2 Losurf-300D MO-67 CAT-3 LVT-200 WG-36 OPTIFLO-II BE-6-(gpm) (gpm) (gpm) (gpm) (gpm) ppm ppm ppm-Max Additive Rate 0.5 1.1 0.5 1.1 1,050.0 26.3 1.1 0.2-Min Additive RateFluid Type25# Delta Frac25# LinearSeawaterFreeze Protect----Proppant TypeWanli 16/20 Ceramic100M---Interval 13Coyote@ 11019 - 11021.78 ft 104.1 °FInterval 14Coyote@ 10491 - 10493.78 ft 104.2 °FInterval 15Coyote@ 9962 - 9964.78 ft 104.2 °FInterval 16Coyote@ 9439 - 9441.78 ft 104.2 °F2:13:48 Conoco Phillips - MT7-05Planned Design4
SAFETY DATA SHEET
Date-Issued: 05-2015
SDS Ref. No: CFT
Date-Revised: 7/26/16
Revision No:005
1. PRODUCT AND COMPANY IDENTIFICATION
1.1 Product Identifiers
Product name : Chemical Frac Tracer
Product number : 1000, 1100, 1200, 1300, 1400, 1500, 1600, 1700, 1900, 2000, 2100,
2200, 2300, 2400, 2500, 2800, 2900, 3000, 3700, 3900, 4000, 4800,
10100, 10200, 10250, 10300, 10350, 10400, 10450, 10500, 10550,
10600, 10650, 10700, 10750, 10800, 10850, 10900
Generic name : CFT-1000, CFT-1100, CFT-1200, CFT-1300, CFT-1400, CFT-1500,
CFT-1600, CFT-1700, CFT-1900, CFT-2000, CFT-2100, CFT-2200,
CFT-2300, CFT-2400, CFT-2500, CFT-2800, CFT-2900, CFT-3000,
CFT-3700, CFT-3900, CFT-4000, CFT-4800, CFT-10100,
CFT-10200, CFT10250, CFT-10300, CFT-10350, CFT-10400,
CFT-10450, CFT-10500, CFT-10550, CFT-10600, CFT-10650,
CFT-10700, CFT-10750, CFT-10800, CFT-10850, CFT-10900
1.2 Relevant identified used of the substance or mixture and uses advised against
Identified uses : Diagnostic
Uses advised against : Not available
1.3 Details of the supplier of the safety data sheet
Company : ProTechnics
Division of Core Laboratories
6510 W. Sam Houston Parkway N.
Houston, Texas 77041
Telephone : 713-328-2320
1.4 Emergency telephone number
Emergency phone number : 713-328-2320
Transportation emergency : 1-800-535-5053 (inside US)
1-352-323-3500 collect (outside US)
2. HAZARDS IDENTIFICATION
2.1 Classification of the substance or mixture
GHS classification in accordance with 29 CFR 1910 (OSHA HCS)
Skin irritation (Category 2), H315
Eye irritation (Category 2), H319
Specific target organ toxicity – single exposure (Category 3), Respiratory system, H335
2.2 GHS Label elements, including precautionary statements
Pictogram
Signal word Warning
Hazard statement(s)
H315 Causes skin irritation.
H319 Causes serious eye irritation.
H335 May cause respiratory irritation.
Precautionary statement(s)
P261 Avoid breathing dust/ fume/ gas/ mist/ vapours/ spray.
P264 Wash skin thoroughly after handling.
P280 Wear protective gloves.
P302 + P352 IF ON SKIN: Wash with plenty of soap and water.
P304 + P340 IF INHALED: Remove affected person into fresh air and keep at rest
in a position comfortable for breathing.
P332 + P313 If skin irritation occurs: Get medical advice/ attention.
2.3 Hazards not otherwise classified (HNOC) or not covered by GHS - none
3. COMPOSITION / INFORMATION ON INGREDIENTS
3.1 Substances
Substance/ mixture Mixture
4. FIRST AID MEASURES
4.1 Description of first aid measures
General advice
Consult a physician. Show this safety data sheet to the doctor in attendance. Move out of dangerous area.
If inhaled
Move person into fresh air. If cough or other symptoms develop, consult a physician.
In case of skin contact
Remove contaminated clothing including shoes and immediately wash affected area with plenty of soap and
water. If irritation continues, consult a physician. Wash contaminated clothing and shoes before reuse.
In case of eye contact
Immediately flush eyes with plenty of water for two to three minutes. Remove any contact lenses and
continue flushing for 15 minutes. If irritation continues, consult a physician.
If swallowed
Wash out mouth with water and keep at rest. Consult a physician.
Ingredient CAS/Exempt No Percent Hazardous
Proprietary Ingredient supplied as 10% w/v
Aqueous Solution Proprietary 10 No
Water 7732-18-5 90 No
4.2 Most important symptoms and effects, both acute and delayed
The most important known symptoms and effects are described in the labeling (see Section
2.2) and/or in Section 11.
4.3 Indication of any immediate medical attention and special treatment needed
No data available.
5. FIRE FIGHTING MEASURES
5.1 Extinguishing media
Suitable extinguishing media
Use fire-extinguishing media appropriate for surrounding materials.
5.2 Special hazards arising from the substance or mixture
Carbon oxides, halogenated hydrogen gas.
5.3 Advice for firefighters
As in any fire, wear full protective clothing and equipment.
5.4 Further information
No data available.
6. ACCIDENTAL RELEASE MEASURES
6.1 Personal precautions, protective equipment and emergency procedures
Use personal protective equipment. Avoid breathing vapours or mist. Evacuate personnel to safe areas.
6.2 Environmental precautions
Do not let product enter drains, if safe to do so.
6.3 Methods and materials for containment and cleanup
Construct temporary dikes of dirt or any appropriate readily available material to prevent spreading of the
material. Cover with appropriate absorbent and sweep or shovel into an appropriate container.
6.4 Reference to other sections
For protective clothing, see Section 8. For disposal, see Section 13.
7. HANDLING AND STORAGE
7.1 Precautions for safe handling
Avoid contact with skin and eyes. Avoid formation of aerosols. Provide adequate exhaust ventilation at
places where aerosols are formed. For precautions, see Section 2.2. Handle and use in a manner consistent
with good industrial/manufacturing techniques and practices.
7.2 Conditions for safe storage
Keep container tightly closed in a dry, cool, and well-ventilated place. Do not store with, or close to, strong
acids.
7.3 Specific end uses(s)
Apart from the uses mentioned in Section 1.2, no other specific uses are stipulated.
8. EXPOSURE CONTROLS / PERSONAL PROTECTION
8.1 Control parameters
Components with workplace control parameters
No PELs, TLVs, or OELs for this product or its ingredients are listed in the current issue of ACGIH's Guide
to Occupational Exposure Values, nor have they been determined by the manufacturer.
8.2 Exposure controls
Appropriate engineering controls
Handle in accordance with good industrial hygiene and safety practice. Wash hands before breaks and at the
end of the workday.
Personal protective equipment
Eye/face protection
Safety glasses with side-shields conforming to EN166. Use equipment for eye protection tested
and approved under appropriate government standards such as NIOSH (US) or EN166 (EU).
Skin protection
Handle with chemical-resistant gloves. Gloves must be inspected prior to use. Use proper glove
removal technique (without touching glove’s outer surface) to avoid skin contact with this product.
Dispose of contaminated gloves after use in accordance with applicable laws and good laboratory
practices. Wash and dry hands.
Body protection
Impervious clothing. The type of protective equipment must be selected according to the amount
of dangerous substance at the specific workplace.
Control of environmental exposure
Do not let product enter drains.
9. PHYSICAL AND CHEMICAL PROPERTIES
9.1 Information on basic physical and chemical properties
a) Appearance Form: aqueous liquid
Color: translucent
b) Odor Odorless
c) Boiling point Approximately 100°C
d) Freeze point 0°C
e) Density 1.05 g/mL
f) Flash point Not flammable
g) pH Approximately 9
h) Evaporation factor Not determined
i) Solubility Soluble in water
j) Vapor pressure Not determined
k) Oxidizing properties Not determined
l) Vapor density Not determined
m) Viscosity Not determined
9.2 Other safety information
No data available.
10. STABILITY AND REACTIVITY
10.1 Reactivity
Strong acids. Oxidizing materials.
10.2 Chemical stability
The product is stable under normal ambient conditions of temperature and pressure.
10.3 Possibility of hazardous reactions
Will not polymerize.
10.4 Conditions to avoid
Extreme cold.
10.5 Incompatible materials
Strong acids. Oxidizing materials.
10.6 Hazardous decomposition products
None.
11. TOXICOLOGICAL INFORMATION
11.1 Information on toxicological effects
Acute toxicity – oral
Based on available data the classification criteria are not met.
Acute toxicity – dermal
Based on available data the classification criteria are not met.
Acute toxicity – inhalation
Based on available data the classification criteria are not met.
Skin corrosion/irritation
Skin irritant 2 – H315 Causes skin irritation.
Serious eye damage/irritation
Eye irritant 2 – H319 May cause severe eye irritation.
Respiratory sensitization
Based on available data the classification criteria are not met.
Skin sensitization
Based on available data the classification criteria are not met.
Germ cell mutagenicity
Genotoxicity – in vitro
Based on available data the classification criteria are not met.
Genotoxicity- in vivo
Based on available data the classification criteria are not met.
Carcinogenicity
IARC: No component of this product present at levels greater than or equal to 0.1% is identified as
probable, possible, or confirmed human carcinogen by IARC.
ACGIH: No component of this product present at levels greater than or equal to 0.1% is identified as a
carcinogen or potential carcinogen by ACGIH.
NTP: No component of this product present at levels greater than or equal to 0.1% is identified as a
known or anticipated carcinogen by NTP
OSHA: No component of this product present at levels greater than or equal to 0.1% is identified as a
carcinogen or potential carcinogen by OSHA.
Reproductive toxicity
Reproductive toxicity – fertility
Based on available data the classification criteria are not met.
Reproductive toxicity – development
Based on available data the classification criteria are not met.
Specific target organ toxicity – single exposure
STOT SE 3 – H335 May cause respiratory irritation.
Specific target organ toxicity – repeated exposure
Based on available data the classification criteria are not met.
Aspiration hazard
Not anticipated to present an aspiration hazard, based on chemical structure.
Additional information
RTECS: Not available.
To the best of our knowledge, the chemical, physical, and toxicological properties have not been thoroughly
investigated.
12. ECOLOGICAL INFORMATION
12.1 Toxicity
No data available.
12.2 Persistence and degradability
Presumed to be persistent.
12.3 Bioaccumulative potential
No data available.
12.4 Mobility in soil
No data available.
12.5 Results of PBT and vPvB assessment
PBT/vPvB assessment are not available as chemical safety assessment not required/ not
conducted.
12.6 Other adverse effects
No data available.
13. DISPOSAL CONSIDERATIONS
13.1 Waste treatment methods
Product
Dispose of at a supervised appropriate waste disposal facility according to current applicable laws and
regulations and product characteristics at time of disposal.
Contaminated packaging
Contaminated containers should be cleaned and disposed of in the same manner as the product in accordance
with applicable regulations.
14. TRANSPORT INFORMATION
DOT (US)
Not dangerous goods.
IMDG
Not dangerous goods.
IATA
Not dangerous goods.
15. REGULATORY INFORMATION
SARA 302 Components
SARA 302: No chemicals in this material are subject to the reporting requirements of SARA Title III,
Section 302.
SARA 313 Components
SARA 313: This material does not contain any chemical components with known CAS numbers that exceed
the threshold (De Minimis) reporting levels established by SARA Title III, Section 313.
SARA 311/312 Hazards
SAR 311/312: No chemicals in this material are subject to the reporting requirements of SARA Title III,
Section 311/312.
CERCLA (Comprehensive Response, Compensation, and Liability Act)
Not Applicable.
TSCA (Toxic Substance Control Act)
The components of this product are in compliance with the chemical notification requirements of TSCA.
German Water Endangerment Class
WGK: 1
16. OTHER INFORMATION
HMIS Rating
Health Hazard: 1
Chronic Health Hazard:
Flammability: 0
Physical Hazard: 0
NFPA Rating
Health Hazard: 1
Fire Hazard: 0
Reactivity Hazard: 0
MANUFACTURER DISCLAIMER: Information given herein is offered in good faith as accurate, but
without guarantee. Conditions of use and suitability of the product for particular uses are beyond our control;
all risks of use of the product are therefore assumed by the user. Nothing is intended as a recommendation for
uses which infringe valid patents or as extending license under valid patents. Appropriate warnings and safe
handling procedures should be provided to handlers and users.
Prepared by: ProTechnics Environmental Compliance Department
Date of revision: 07/26/2016
Contact information: 713-328-2320
SAFETY DATA SHEET
Date-Issued: 05-2015
SDS Ref. No: ZW
Date-Revised: 5/31/15
Revision No:001
1. PRODUCT AND COMPANY IDENTIFICATION
1.1 Product Identifiers
Product name : Zero Wash Tracer
Product number : NA
Generic name : IRZW, SCZW, SBZW, and low Density (LD)
1.2 Relevant identified used of the substance or mixture and uses advised against
Identified uses : Diagnostic
Uses advised against : Not available
1.3 Details of the supplier of the safety data sheet
Company : ProTechnics
Division of Core Laboratories
6510 W. Sam Houston Parkway N.
Houston, Texas 77041
Telephone : 713-328-2320
1.4 Emergency telephone number
Emergency phone number : 713-328-2320
Transportation emergency : 1-800-535-5053 (inside US)
1-352-323-3500 collect (outside US)
2. HAZARDS IDENTIFICATION
2.1 Classification of the substance or mixture
GHS classification in accordance with 29 CFR 1910 (OSHA HCS)
Not Classified- Radioactive Material
2.2 GHS Label elements, including precautionary statements
Pictogram
Signal word None Associated Radioactive Material
Hazard statement(s)
No hazard statement associated- Radioactive Material. Zero Wash is a small bead that emits low gamma
radiation in small quantities
Precautionary statement(s)
2.3 Hazards not otherwise classified (HNOC) or not covered by GHS - Radioactive Material
3. COMPOSITION / INFORMATION ON INGREDIENTS
3.1 Substances
Substance/ mixture Mixture
4. FIRST AID MEASURES
4.1 Description of first aid measures
General advice
Move away from source. Use ALARA- Time, Distance, Shielding
If inhaled
Not respirable
In case of skin contact
Remove from contact with skin. Keep distance
In case of eye contact
Immediately flush eyes with plenty of water for two to three minutes. Remove any contact lenses and
continue flushing for 15 minutes. If irritation continues, consult a physician.
If swallowed
Consult a physician.
4.2 Most important symptoms and effects, both acute and delayed
No side effects known with short term, avoid long term exposure.
4.3 Indication of any immediate medical attention and special treatment needed
Remove bead and place in shielding or create distance.
5. FIRE FIGHTING MEASURES
5.1 Extinguishing media
Suitable extinguishing media
Carbon Dioxide or Halon (This reduces the spread of Zero Wash material).
5.2 Special hazards arising from the substance or mixture
NA
5.3 Advice for firefighters
Low activity Gamma emitting radioactive material-low exposure
Ingredient CAS/Exempt No Percent Hazardous
Ceramic Proppant Proprietary 100 Yes
6. ACCIDENTAL RELEASE MEASURES
6.1 Personal precautions, protective equipment and emergency procedures
6.2 Environmental precautions
. CONTROL THE AREA. Rubber gloves, boots and safety glasses should be worn when handling.
6.3 Methods and materials for containment and cleanup
Clean up spill area by scooping up spilled material and transfer to a container. If clothing indicates the
presence of Zero Wash material, remove the bead with adhesive tape, hold tape containing bead for decay in proper
storage area. If numerous beads are found on clothing, remove clothing and place in a container for later cleaning or
disposal. When any spill or release occurs, ProTechnics should be notified (713-328-2320) to supervise clean-up
efforts.
7. HANDLING AND STORAGE
7.1 Precautions for safe handling
Only ProTechnics Trained tracer supervisors should handle this material as they are trained in how to
contain, remove and find the material.
7.2 Conditions for safe storage
Normal
7.3 Specific end uses(s)
Diagnostic.
8. EXPOSURE CONTROLS / PERSONAL PROTECTION
8.1 Control parameters
Components with workplace control parameters
Non radiation workers should avoid any contact with material. Restricted area for use should be set at 2mR/hr
and prevent any unintentional exposure
8.2 Exposure controls
Appropriate engineering controls
Material stored in lead lined containers and used in restricted areas only. Only trained Tracing supervisors
have access and control of the material
Personal protective equipment
Eye/face protection
Safety glasses with side-shields conforming to EN166. Use equipment for eye protection tested
and approved under appropriate government standards such as NIOSH (US) or EN166 (EU).
Skin protection
Handle with chemical-resistant gloves. Gloves must be inspected prior to use. Use proper glove
removal technique (without touching glove’s outer surface) to avoid skin contact with this product.
Dispose of contaminated gloves after use in accordance with applicable laws and good laboratory
practices. Wash and dry hands.
Body protection
Standard FRC should be adequate and use of proper surveying techniques used when material is
being used.
Control of environmental exposure
All material should be captured and managed by ProTechnics, if material is noticed by survey please
contact ProTechnics at 713-328-2320
9. PHYSICAL AND CHEMICAL PROPERTIES
9.1 Information on basic physical and chemical properties
a) Appearance Form: Small grey colored ceramic bead
Color: grey
b) Odor Odorless
c) Boiling point NA
d) Freeze point NA
e) Density/Specific Gravity 2.6 g/mL
f) Flash point Not flammable
g) pH Not available
h) Evaporation factor Not determined
i) Solubility not Soluble in water
j) Vapor pressure Not determined
k) Oxidizing properties Not determined
l) Vapor density Not determined
m) Viscosity Not determined
9.2 Other safety information
No data available.
10. STABILITY AND REACTIVITY
10.1 Reactivity
NA
10.2 Chemical stability
The product is stable under normal ambient conditions of temperature and pressure.
10.3 Possibility of hazardous reactions
Will not polymerize.
10.4 Conditions to avoid
Combination of material with more like material could increase exposure levels. The smaller the amount the
lower the exposure rates should be.
10.5 Incompatible materials
NA
10.6 Hazardous decomposition products
None. All ZW material decay to stable state.
11. TOXICOLOGICAL INFORMATION
11.1 Information on toxicological effects
Acute toxicity – oral
May cause Eye and Mucous membrane irritation.
. Ingestion is the only method of internal consumption.
Acute toxicity – dermal
Irritation or itching of the skin.
Acute toxicity – inhalation
ZERO WASH particle is too large to inhale.
Skin corrosion/irritation
NA.
Serious eye damage/irritation
NA
Respiratory sensitization
ZERO WASH particle is too large to inhale
Skin sensitization
Irritation or itching of the skin.
Germ cell mutagenicity
Genotoxicity – in vitro
Based on available data the classification criteria are not met.
Genotoxicity- in vivo
Based on available data the classification criteria are not met.
Carcinogenicity
IARC: No component of this product present at levels greater than or equal to 0.1% is identified as
probable, possible, or confirmed human carcinogen by IARC.
ACGIH: No component of this product present at levels greater than or equal to 0.1% is identified as a
carcinogen or potential carcinogen by ACGIH.
NTP: No component of this product present at levels greater than or equal to 0.1% is identified as a
known or anticipated carcinogen by NTP
OSHA: No component of this product present at levels greater than or equal to 0.1% is identified as a
carcinogen or potential carcinogen by OSHA.
Reproductive toxicity
Reproductive toxicity – fertility
Based on available data the classification criteria are not met.
Reproductive toxicity – development
Based on available data the classification criteria are not met.
Specific target organ toxicity – single exposure
Low doses not applicable
Specific target organ toxicity – repeated exposure
Internal-possible gamma exposure
Aspiration hazard
Not anticipated to present an aspiration hazard, based on Physical structure.
To the best of our knowledge, the chemical, physical, and toxicological properties have not been thoroughly
investigated.
12. ECOLOGICAL INFORMATION
12.1 Toxicity
NA.
12.2 Persistence and degradability
Half life: IRZW-74 days, SCZW-84 days, SBZW-60 days
12.3 Bioaccumulative potential
No data available.
12.4 Mobility in soil
Zero Wash does not plate and will not breakdown in soil.
12.5 Results of PBT and vPvB assessment
PBT/vPvB assessment are not available as chemical safety assessment not required/ not
conducted.
12.6 Other adverse effects
No data available.
13. DISPOSAL CONSIDERATIONS
13.1 Waste treatment methods
Product
DISPOSAL METHOD: Dispose of waste at an appropriate waste disposal facility according to current applicable
laws and regulations.
PRODUCT DISPOSAL: Dispose of at a supervised appropriate waste disposal facility according to current applicable
laws and regulations and product characteristics at time of disposal.
EMPTY CONTAINER: Contaminated containers should be cleaned and disposed of in the same manner as the
product in accordance with applicable regulations.
GENERAL COMMENTS: Refer to Section 6, Accidental Release Measures for additional information.
Contaminated packaging
Contaminated containers should be cleaned and disposed of in the same manner as the product in accordance
with applicable regulations. Please contact ProTechnics for Disposal guidance at 713-328-2320
14. TRANSPORT INFORMATION
DOT (US)
DOT (DEPARTMENT OF TRANSPORTATION)
PROPER SHIPPING NAME: Radioactive material, type A package
TECHNICAL NAME: Zero Wash Tracer
LABEL: Diamond.
Hazard Class/Division: 7
United Nations number: 2915
IMDG
VESSEL (IMO/IMDG)
PROPER SHIPPING NAME: Radioactive material, type A package
TECHNICAL NAME: Zero Wash Tracer
LABEL: Diamond.
United Nations number:2915
IATA
AIR -Forbidden on Passenger carrying aircraft.
PROPER SHIPPING NAME: Radioactive material, type A package
TECHNICAL NAME: Zero Wash Tracer
LABEL: Diamond
Hazard Class/Division: 7
United Nations number:2915
.
15. REGULATORY INFORMATION
SARA 302 Components
SARA 302: No chemicals in this material are subject to the reporting requirements of SARA Title III,
Section 302.
SARA 313 Components
SARA 313: This material does not contain any chemical components with known CAS numbers that exceed
the threshold (De Minimis) reporting levels established by SARA Title III, Section 313.
SARA 311/312 Hazards
SAR 311/312: No chemicals in this material are subject to the reporting requirements of SARA Title III,
Section 311/312.
CERCLA (Comprehensive Response, Compensation, and Liability Act)
Not Applicable.
TSCA (Toxic Substance Control Act)
Not Applicable.
.
16. OTHER INFORMATION
HMIS Rating
Health Hazard: 1
Chronic Health Hazard: 1
Flammability: 0
Physical Hazard: 0
NFPA Rating
Health Hazard: 1
Fire Hazard: 0
Reactivity Hazard: 0
MANUFACTURER DISCLAIMER: Information given herein is offered in good faith as accurate, but
without guarantee. Conditions of use and suitability of the product for particular uses are beyond our control;
all risks of use of the product are therefore assumed by the user. Nothing is intended as a recommendation for
uses which infringe valid patents or as extending license under valid patents. Appropriate warnings and safe
handling procedures should be provided to handlers and users.
Prepared by: ProTechnics Environmental Compliance Department
Date of revision: 05/31/2015
Contact information: 713-328-2320
Coyote @ 4794' MD / 4094' TVD West Sak 2139' MD / 2026' TVDBase Permafrost 1772' MD / 1714’ TVD3S-701A Coyote Pilot Hole / Horizontal InjectorWell Schematic13-1/2" Surface Hole9.8 ppg Spud Mud16" Insulated Conductor10-3/4" Surface Casing 2910' MD / 2573' TVD9-7/8" Intermediate Hole 9.0 – 9.5 ppg LSND7-5/8" Intermediate Casing 8549' MD / 4119' TVD 800' 39# Heavy Heel6-1/2" Hole9.0-9.5 ppg KLASHIELD4-1/2" Reservoir Liner15 Frac Sleeves (for 8,000 ft lateral) +1 Trigger Sleeve4.5" x 7-5/8" Liner Top Packer / Hanger 8,270.3' MDProd Packer 4.5" x 7-5/8" 8,078.5' MD Downhole Gauge (Tubing Side Only)Perf PupTop of Cement at 6800' MD / 3723' TVD - 1537' MD / 354' TVD above Top Coyote on path3.813" X NippleGas Lift Mandrel (4-1/2" x 1")Gas Lift Mandrel (4-1/2" x 1")3.813" X profile (70 deg inclination max)16 Prop Frac StagesWellhead / Tubing Hanger / TreeCement Kickoff Plug @ 2806' - 3406' MD3S-701 TD @ 5,600' MD / 4905' TVD3S-701 Abandonment Plug with 3-½” sacrificial string @ 3406' - 5597' MD8-3/4” Pilot Hole9.0 ppg OBMProduction TD 17340' MD / 4267' TVD3S-701A sidetrack @ 2930' MDBase Coyote @ 5370' MD / 4671' TVD
Casing/Liner OverviewDrift Nom.Size Weight Grade Conn. ID ID(in) (lb/ft) (-) (-) (in) (in)20 94.0 H-40 ER 18.936 19.12410-3/4 45.5L-80Hyd5639.950 9.7947-5/8 29.7 L-80 Hyd563 6.750 6.87533.7 P-110S Hyd563 6.640 6.7654-1/2 12.6 P-110S Hyd563 3.833 3.958Tubing Overview
RECEIVED
TO: AOGCC
333 WEST 7T" SUITE 100
ANCH. AK. 99501
279-1433
OPERATOR: CPAI
SAMPLE TYPE: Dry Cuttings
SAMPLES SENT:
2 3S-701
3 2950-5600
1 u Q 4 Boxes
SENT BY: M. McCRACKEN
FEB 10 2023
SAMPLE TRANSMITTAL n
AOG
DATE: February 10, 2023
AIR BILL: N/A
CPAI: 2023021001
CHARGE CODE: N/A
NAME: 3S-701, 3S-701A
NUMBER OF BOXES: 7 Boxes
3S-701A
3120 - 17340
3 Boxes (Gt 1
UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND RETURN A SIGNED COPY
OF THIS FORM TO:
RECEIVED:
CONOCOPHILLIPS, ALASKA
700 G ST
ATO-380
ANCHORAGE, AK. 99510
ATTN: MIKE McCRACKEN
Mike.mccracken@conocophillips.com
V3Ws zll5
1
Regg, James B (OGC)
From:Brooks, Phoebe L (OGC)
Sent:Wednesday, February 22, 2023 3:22 PM
To:Rig 19
Cc:Regg, James B (OGC)
Subject:RE: Doyon Rig 19 BOPE Test Chart and Report
Attachments:Doyon 19 01-21-23 Revised.xlsx; Doyon 19 01-31-23 Revised.xlsx
Attached are revised reports for KRU 3S‐701A – reports Doyon 19 01‐21‐23 and 01‐31‐23. The Operation was changed to
Exploratory on both reports per PTD #2221340 with the Test interval as Initial on the 01/21/23 report and Weekly on the
01/31/23 report. Additional remarks were added to the Weekly report stating Exploratory well testing is required every
7 days; 10 day testing was conducted without approval. Please review and update your copies.
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 19 <rig19@doyondrilling.com>
Sent: Tuesday, January 31, 2023 9:17 PM
To: DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Ben Wedin <bwedin@doyondrilling.com>; D19
Company Man <d19cm@conocophillips.com>; Drilling Engineer <Doyon19.OperationsEngineer@conocophillips.com>;
Regg, James B (OGC) <jim.regg@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Rig 19
<rig19@doyondrilling.com>; Rig Adviser <wscrigadvisor@conocophillips.com>
Cc: Bixby, Brian D (OGC) <brian.bixby@alaska.gov>
Subject: Doyon Rig 19 BOPE Test Chart and Report
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open
attachments unless you recognize the sender and know the content is safe.
KRU 3S-701APTD 2221340
2
Thank You,
Sean Tower
Doyon Drilling Rig 19 Tour Pusher
Cell: (907) 301-7832
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner:Rig No.:19 DATE:1/31/23
Rig Rep.:Rig Email:
Operator:
Operator Rep.:Op. Rep Email:
Well Name:PTD #2221340 Sundry #
Operation:Drilling:Workover:Explor.:X
Test:Initial:Weekly:X Bi-Weekly:Other:
Rams:250/4000 Annular:250/2500 Valves:250/4000 MASP:1556
MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 1 P
Permit On Location P Hazard Sec.P Lower Kelly 1 P
Standing Order Posted P Misc.NA Ball Type 1 P
Test Fluid Water Inside BOP 1 P
FSV Misc 0 NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0 NA Trip Tank P P
Annular Preventer 1 13-5/8"P Pit Level Indicators P P
#1 Rams 1 3.5" X 6"P Flow Indicator P P
#2 Rams 1 Blinds P Meth Gas Detector P P
#3 Rams 1 3.5" X 6"P H2S Gas Detector P P
#4 Rams 0 NA MS Misc 0 NA
#5 Rams 0 NA
#6 Rams 0 NA ACCUMULATOR SYSTEM:
Choke Ln. Valves 1 3.125 P Time/Pressure Test Result
HCR Valves 2 3.125 P System Pressure (psi)2900 P
Kill Line Valves 1 3.125 P Pressure After Closure (psi)1400 P
Check Valve 0 NA 200 psi Attained (sec)13 P
BOP Misc 1 4" Kill line Demco P Full Pressure Attained (sec)151 P
Blind Switch Covers:All stations Yes
CHOKE MANIFOLD:Bottle Precharge:P
Quantity Test Result Nitgn. Bottles # & psi (Avg.):4 @ 2225 P
No. Valves 14 P ACC Misc 0 NA
Manual Chokes 1 P
Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result
CH Misc 0 NA Annular Preventer 16 P
#1 Rams 7 P
Coiled Tubing Only:#2 Rams 14 P
Inside Reel valves 0 NA #3 Rams 7 P
#4 Rams 0 NA
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:0 Test Time:5.5 HCR Choke 1 P
Repair or replacement of equipment will be made within days. HCR Kill 1 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 1/29/23 16:17
Waived By
Test Start Date/Time:1/31/2023 14:30
(date)(time)Witness
Test Finish Date/Time:1/31/2023 20:00
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Brian Bixby
Doyon
Tested Annular with a 4" test joint 250/2500psi low/high 5 min each. Tested 3.5" x 6" UPR, LPR with 4.5 ''and 4" test joints.
250/4000psi low/high 5 min each. Tested all other componets 250/4000psi low/high 5 min each. Tested hydraulic choke &
manual choke at 2000 psi. Bottle Precharge=1000 psi. Exploratory well testing is required every 7 days; 10 day testing was
conducted without approval (initial test for 701A on 01/21/23).
G.Neuharth / S.Tower
Conoco Phillips
Kenny Harding /Charlie Brown
KRU 3S-701A
Test Pressure (psi):
rig19@doyondrilling.com
d19cm@conocophillips.com
Form 10-424 (Revised 08/2022)2023-0131_BOP_Doyon19_KRU_3S-701A
J. Regg; 5/31/2023
1
Regg, James B (OGC)
From:Brooks, Phoebe L (OGC)
Sent:Wednesday, February 22, 2023 3:22 PM
To:Rig 19
Cc:Regg, James B (OGC)
Subject:RE: Doyon Rig 19 BOPE Test Chart and Report
Attachments:Doyon 19 01-21-23 Revised.xlsx; Doyon 19 01-31-23 Revised.xlsx
Attached are revised reports for KRU 3S‐701A – reports Doyon 19 01‐21‐23 and 01‐31‐23. The Operation was changed to
Exploratory on both reports per PTD #2221340 with the Test interval as Initial on the 01/21/23 report and Weekly on the
01/31/23 report. Additional remarks were added to the Weekly report stating Exploratory well testing is required every
7 days; 10 day testing was conducted without approval. Please review and update your copies.
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 19 <rig19@doyondrilling.com>
Sent: Tuesday, January 31, 2023 9:17 PM
To: DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Ben Wedin <bwedin@doyondrilling.com>; D19
Company Man <d19cm@conocophillips.com>; Drilling Engineer <Doyon19.OperationsEngineer@conocophillips.com>;
Regg, James B (OGC) <jim.regg@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Rig 19
<rig19@doyondrilling.com>; Rig Adviser <wscrigadvisor@conocophillips.com>
Cc: Bixby, Brian D (OGC) <brian.bixby@alaska.gov>
Subject: Doyon Rig 19 BOPE Test Chart and Report
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.
KREU 3S-701APTD 2221340
2
Thank You,
Sean Tower
Doyon Drilling Rig 19 Tour Pusher
Cell: (907) 301-7832
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner:Rig No.:19 DATE:1/21/23
Rig Rep.:Rig Email:
Operator:
Operator Rep.:Op. Rep Email:
Well Name:PTD #2221340 Sundry #
Operation:Drilling:Workover:Explor.:X
Test:Initial:X Weekly:Bi-Weekly:Other:
Rams:250/4000 Annular:250/2500 Valves:250/4000 MASP:1556
MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 1 P
Permit On Location P Hazard Sec.P Lower Kelly 1 P
Standing Order Posted P Misc.NA Ball Type 1 P
Test Fluid Water Inside BOP 1 P
FSV Misc 0 NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0 NA Trip Tank P P
Annular Preventer 1 13-5/8"P Pit Level Indicators P P
#1 Rams 1 3.5" X 6"P Flow Indicator P P
#2 Rams 1 Blinds P Meth Gas Detector P P
#3 Rams 1 3.5" X 6"P H2S Gas Detector P P
#4 Rams 0 NA MS Misc 0 NA
#5 Rams 0 NA
#6 Rams 0 NA ACCUMULATOR SYSTEM:
Choke Ln. Valves 1 3.125 P Time/Pressure Test Result
HCR Valves 2 3.125 P System Pressure (psi)2850 P
Kill Line Valves 1 3.125 P Pressure After Closure (psi)1450 P
Check Valve 0 NA 200 psi Attained (sec)32 P
BOP Misc 1 4" Kill line Demco P Full Pressure Attained (sec)166 P
Blind Switch Covers:All stations Yes
CHOKE MANIFOLD:Bottle Precharge:P
Quantity Test Result Nitgn. Bottles # & psi (Avg.):4 @ 2325 P
No. Valves 14 P ACC Misc 0 NA
Manual Chokes 1 P
Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result
CH Misc 0 NA Annular Preventer 22 P
#1 Rams 7 P
Coiled Tubing Only:#2 Rams 15 P
Inside Reel valves 0 NA #3 Rams 7 P
#4 Rams 0 NA
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:0 Test Time:5.0 HCR Choke 1 P
Repair or replacement of equipment will be made within days. HCR Kill 1 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 1/19/23 17:03
Waived By
Test Start Date/Time:1/21/2023 4:00
(date)(time)Witness
Test Finish Date/Time:1/21/2023 9:00
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Austin McLeod
Doyon
Tested Annular with a 4" test joint 250/2500psi low/high 5 min each. Tested 3.5" x 6" UPR, LPR with 4.5 ''and 4" test joints.
250/4000psi low/high 5 min each. Tested all other componets 250/4000psi low/high 5 min each. Tested hydraulic choke &
manual choke at 2000 psi. Bottle Precharge=1000 psi. Tested Upper and Lower Kelly Valves at 250/4000 psi low/high 5 min
each.
G.Neuharth/ S.Michael
Conoco Phillips
A.Lundale/C.Brown
KRU 3S-701A
Test Pressure (psi):
rig19@doyondrilling.com
d19cm@conocophillips.com
Form 10-424 (Revised 08/2022)2023-0121_BOP_Doyon19_KRU_3S-701A
J. Regg; 5/31/2023
J. Regg; 5/31/2023
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
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1
Prysunka, Anne E (OGC)
From:Davies, Stephen F (OGC)
Sent:Monday, October 31, 2022 3:42 PM
To:chris.brillion@conocophillips.com; McCracken, Shane M
Cc:Prysunka, Anne E (OGC)
Subject:KRU 3S-701A (PTD 222-134) - Incorrect API Number
Chris and Shane,
I mistakenly entered an incorrect API number on the Permit to Drill form for KRU 3S‐701A (PTD 222‐134) that was issued
earlier today. On that form, and in CPAI’s records, please change the API number from 50‐103‐20848‐00‐00 to 50‐103‐
20847‐01‐00, as this well will be a redrill of KRU 3S‐701. AOGCC’s records will be updated accordingly, and a copy of this
email will be placed in the Well History File to minimize any confusion.
Please accept my apologies for this mistake.
Thanks and stay safe,
Steve Davies
Senior Petroleum Geologist
Alaska Oil and Gas Conservation Commission (AOGCC)
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 Steve Davies at 907‐793‐1224 or steve.davies@alaska.gov.
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