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Alaska Oil and Gas Conservation Commission
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Post Office Box 244027
Anchorage, AK 99524-4027
3800 Centerpoint Drive
Suite 1400
Anchorage, AK 99503
Phone: (907) 564-4891
06/09/2025
Mr. Jack Lau
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor
through 06/09/2025.
Dear Mr. Lau,
Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off
with cement, corrosion inhibitor in the surface casing by conductor annulus through 06/09/2025.
Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement
fallback during the primary surface casing by conductor cement job. The remaining void space
between the top of the cement and the top of the conductor is filled with a heavier than water
corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached
spreadsheets include the well names, API and PTD numbers, treatment dates and volumes.
As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that
the treatments took place and meet the requirements of form 10-404 Report of Sundry Operations.
If you have any additional questions, please contact me at 564-4891 or
oliver.sternicki@hilcorp.com.
Sincerely,
Oliver Sternicki
Well Integrity Supervisor
Hilcorp North Slope, LLC
Digitally signed by Oliver
Sternicki (4525)
DN: cn=Oliver Sternicki (4525)
Date: 2025.06.09 14:30:46 -
08'00'
Oliver Sternicki
(4525)
Hilcorp North Slope LLC.Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-offReport of Sundry Operations (10-404)06/09/2025Well NamePTD #API #Initial top of cement (ft)Vol. of cement pumped (gal)Final top of cement (ft)Cement top off date Corrosion inhibitor (gal)Corrosion inhibitor/ sealant dateF-10C21308650029204100365/29/25F-29B2111475002921627026.25/29/25F-33A20816350029226400145/29/25F-3619519650029226310035/29/25F-39190141500292210100175/29/25F-44A2051615002922130012.55/29/25F-47B21007950029222320215/29/25L-2512231065002923772001.8813/31/24117/29/24L-2532230485002923758004.1201.13/31/24127/29/24L-2542230305002923752003.8321.23/31/24137/29/24L-2922230255002923751003.3301.33/31/24147/29/24N-282141275002923524006.8504.711/19/242212/28/24N-302141245002923523003.5330.311/17/243.512/28/24PAVE1-122309450029237670019.910/27/24PWDW3-221908150029236340014.810/27/24S-40120607850029233130015.31130.511/15/24412/28/243.3301.33/31/247/29/24L-29222302550029237510014
Nolan Vlahovich Hilcorp Alaska, LLC
Geotech 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 564-4558
E-mail: nolan.vlahovich@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Date: 5/21/2024
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20240521
Well API #PTD #Log Date Log
Company Log Type AOGCC Eset#
END 3-07A 50029219110100 198147 5/11/2024 HALLIBURTON Coilflag
MPU E-19 50029227460000 197037 3/25/2024 READ CaliperSurvey
MPU F-66A 50029226970100 196162 5/8/2024 READ CaliperSurvey
MPI 1-27 50029216930000 187009 5/7/2024 READ PPROF
MPU L-17 50029225390000 194169 5/8/2024 READ CaliperSurvey
NCI A-12B 50883200320200 223053 5/2/2024 READ MAPP
NCI A-17 50883201880000 223031 5/3/2024 READ MAPP
PBU 11-41 50029237820000 224017 5/11/2024 HALLIBURTON RBT/Coilflag
PBU D-31B 50029226720200 212168 5/12/2024 HALLIBURTON RBT
PBU F-31A 50029216470100 212002 5/8/2024 READ CaliperSurvey
PBU J-19 50029216290000 186135 5/2/2024 HALLIBURTON RBT
PBU L-292 50029237510000 223025 5/6/2024 HALLIBURTON PPROF
Please include current contact information if different from above.
T38831
T38832
T38833
T38834
T38835
T38836
T38837
T38838
T38839
T38840
T38841
T38842PBU L-292 50029237510000 223025 5/6/2024 HALLIBURTON PPROF
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.05.22 09:57:50 -08'00'
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
August 1, 2023
Mr. Torin Roschinger
Prudhoe Bay West – Operations Manager
Hilcorp North Slope, LLC
3800 Centerpoint Dr. #1400
Anchorage, AK 99503
Re: Docket Number: CO-23-011
Request to vent gas during extended flow test of Prudhoe Bay Unit L-292 well (PTD
223-025)
Schrader Bluff Oil Pool, Orion Development Area
Prudhoe Bay Unit
Dear Mr. Roschinger:
By email dated July 14, 2023, Hilcorp North Slope, LLC (Hilcorp) requested authorization from
the Alaska Oil and Gas Conservation Commission (AOGCC) to allow the Prudhoe Bay Unit
(PBU) L-292 well to vent gas for up to 30 days while the well is flow tested to tanks instead of the
existing PBU processing systems. The AOGCC hereby conditionally APPROVES Hilcorp’s
request.
Hilcorp recently drilled and completed the PBU L-292 well into the Schrader Bluff Formation in
the Eileen West End (EWE) portion of the PBU. Initial testing indicated the well was producing
approximately 2,700 BOPD with trace water cut and formation gas, but this testing was suspect
due to oil carryover in the gas leg and system backpressure. More recent testing seems to have
mitigated the oil carryover issue and resulted in more accurate test results. These tests indicate the
well was producing approximately 4,200 BOPD and 800 MCFPD of formation gas along with 2.4
MMCFPD of lift gas. Despite the strong oil rates shown during the on-pad testing, the total
production from Gathering Center (GC) 2 has only increased by approximately 2,000 BOPD.
Facility modelling suggests that production from PBU L-292 could be causing backout from the
EWE pipeline from L-Pad to GC 2.
While modelling suggests the “loss” in production rate between the well and GC 2 is due to
backout in the EWE pipeline, there could be other reasons for the approximately 2,000 BOPD
difference, including that well tests may not accurately reflect actual reservoir performance since
the tests are snapshots in time. As such, Hilcorp would like to conduct a flow test for up to 30 days
(but will shut down earlier if conclusive results are achieved prior to the end of the 30 days) to
better quantify actual reservoir performance and allow the surface production facilities to stabilize
without PBU L-292 production. The information such a test could provide would be very valuable
in evaluating the potential performance of new drill wells as Hilcorp and its partners evaluate
Docket Number: CO-23-011
August 1, 2023
Page 2 of 2
expanded PBU L-Pad and/or developing a new PBU I-Pad to support additional drilling in this
portion of the field.
Between the gas lift gas and the formation gas the flow test would vent approximately 3 MMCFPD
for the duration of the test. Hilcorp has evaluated the differences between venting the gas from
this test and flaring it and states that venting will be the safer option. There are several reasons
why venting is the preferred option, including that flaring is not done at the pad level as part of
normal operations, the history of oil carryover in the gas leg of the separator when testing this well
and the potential for that to cause fire/environmental issues if it was diverted to a flare, the potential
for having to vent gas from other operations on L-Pad, and the danger having an open ignition
source on the pad could pose in that event. Hilcorp has indicated that it would have a monitor on
site around the clock to monitor the well and associated tanks, and it could shut in the well or divert
back into the pad’s production header if conditions change such that venting is no longer safe.
20 AAC 25.235(d)(6) allows the AOGCC, at its sole discretion, to approve the venting or flaring
of gas for the purpose of testing prior to regular production. While the PBU L-292 well can be
tied into the L-Pad production header and sent through GC 2 as regular production, data indicates
that doing so does not give an accurate assessment of the wells actual potential capabilities and
understanding that potential is important for determining whether or not the capital expenses
associated with expanding the L-Pad and/or developing an I-Pad can be justified based on the
potential performance of newly drilled wells in this portion of the field, which would likely
increase ultimate recovery from the PBU. Additionally, the AOGCC concurs with Hilcorp’s
assessment that in this case venting the gas is preferred over flaring. As such the AOGCC has
determined that allowing the venting of gas from producing the PBU L-292 well to tanks for up to
30 days is acceptable on the condition that should conclusive results be achieved prior to the end
of the 30 days, the testing will cease, and the well be routed back to the L-Pad production header.
Hilcorp is reminded to include the volume of gas vented during this test on the monthly Facility
Report of Produced Gas Disposition, Form 10-422.
Should you have any questions on this matter please contact Dave Roby at dave.roby@alaska.gov
or 907-793-1232.
Sincerely,
Brett W. Huber, Sr.
Chair, Commissioner
Brett W. Huber,
Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.08.01 15:33:56
-08'00'
CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders.
From:Torin Roschinger
To:Roby, David S (OGC)
Subject:RE: [EXTERNAL] RE: Evaluation of L-292 Flowback and EWE Pipeline Backout at GC2 Facility
Date:Friday, July 21, 2023 12:09:10 PM
Good morning Mr. Roby,
Hilcorp is requesting to vent gas for this evaluation. After talking with the Operations Team about
venting vs flaring the team isn’t comfortable with flaring for a multitude of reasons; flaring at the
pad level isn’t something that has ever been done conventionally in Prudhoe, the L-292 separation
has been challenging and we don’t want to have an environmental release from oil/fire onto the pad
due to poor separation with oil carryover in the gas and gas is regularly bled to tanks during
operations bleeds, integrity work and interventions work making it more in line with current
practices that Operations believes they can manage. It’s been discussed that in the event that
venting isn’t favorable due to a change in wind direction that the well will either be shut-in or
diverted back into the system until wind conditions warrant flowing back to tanks.
The SVS system will be monitored by an individual and remote panel similar to having a slickline,
eline or coiled tubing unit on location. As a secondary means of shutting the well in, the operator
will close the choke and block valves to isolate the well.
Please let me know if you have any other questions.
Thank you,
Torin Roschinger
Hilcorp Energy Alaska
Prudhoe Bay West - Operations Manager
c. 406 570 9630
Torin.roschinger@hilcorp.com
From: Roby, David S (OGC) <dave.roby@alaska.gov>
Sent: Thursday, July 20, 2023 12:38 PM
To: Torin Roschinger <Torin.Roschinger@hilcorp.com>
Subject: [EXTERNAL] RE: Evaluation of L-292 Flowback and EWE Pipeline Backout at GC2 Facility
Hi Torin,
I’m reviewing this request and have a couple questions for you. In your description below you say
you’ll be venting the gas during the proposed test. Under our gas disposition reporting flaring and
venting are reported together but they’re two different methods of release. Flared gas, obviously,
goes through a flare stack and is combusted and vented is simply released to the atmosphere un-
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Do not click links or open attachments unless you recognize the sender and know
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combusted. When you said the gas would be vented are you talking about actual venting or do you
mean the gas will be flared?
If you are planning to vent why aren’t you going to flare the gas instead?
Thanks,
Dave Roby
(907)793-1232
From: Torin Roschinger <Torin.Roschinger@hilcorp.com>
Sent: Friday, July 14, 2023 8:23 AM
To: Roby, David S (OGC) <dave.roby@alaska.gov>
Subject: Evaluation of L-292 Flowback and EWE Pipeline Backout at GC2 Facility
Mr. Roby,
Hilcorp recently drilled and completed L-292 (PTD 223-025) in June 2023 in the Schrader formation.
The well was placed on production in early June and initial welltests indicated 2,728bopd and a trace
% of both WC and formation gas with 2mmscfd of gas lift rate, but oil carryover in the gas stream
from the separator and backpressure from the system made validating the results challenging. After
mitigating the oil carryover in the gas stream and obtaining more accurate test results from both the
portable and pad separator, it appears the well is making closer to ~4,186bopd, trace % WC and
781mscfd formation gas with 2.4mmscfd gas lift rate. Though the results are encouraging, we only
appear to be seeing ~2,000bopd additional at the GC2 Facility. Modeling suggests that some of the
oil not showing up at the plant could be due to backout from the EWE pipeline that runs from L-Pad
to GC2. However, Hilcorp would like to confirm this to further evaluate the benefits of drilling
additional wells for an L-Pad Expansion or I-Pad Development Project which will require significant
capital investment. Due to L-292 having minimal gas production, Hilcorp would like to request
permission to flow the well to tanks to allow the GC2 Facility to stabilize to equivalent rates and
pressures prior to bringing L-292 online and flow L-292 independently of both the GC2 Facility and
EWE Pipeline to evaluate the rates and pressures against the modeling. This project will result in
venting approximately 3mmscf/d for a period of 30 days with the aim to let GC2 stabilize, reduce
variables that increase complexity and fully understand the modeling vs rate of existing and future
new drill wells.
We are anticipating the flowback period not to exceed 30 days. If the results are conclusive prior to
the 30 day flowback period, the well will be swapped back to the L-Pad header and EWE pipeline to
limit the volume of gas emissions vented.
The volume of gas vented will be reported to the AOGCC on the Facility Report of Produced Gas
Disposition Form (Form 10-422).
Please let us know if you have any questions or require additional information.
Thank you,
Torin Roschinger
Hilcorp Energy Alaska
Prudhoe Bay West - Operations Manager
c. 406 570 9630
Torin.roschinger@hilcorp.com
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message.
While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the
onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility
is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate.
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message.
While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate.
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
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From:Roby, David S (OGC)
To:Carlisle, Samantha J (OGC)
Subject:FW: Evaluation of L-292 Flowback and EWE Pipeline Backout at GC2 Facility
Date:Thursday, July 20, 2023 2:20:41 PM
Dave Roby
(907)793-1232
From: Torin Roschinger <Torin.Roschinger@hilcorp.com>
Sent: Friday, July 14, 2023 8:23 AM
To: Roby, David S (OGC) <dave.roby@alaska.gov>
Subject: Evaluation of L-292 Flowback and EWE Pipeline Backout at GC2 Facility
Mr. Roby,
Hilcorp recently drilled and completed L-292 (PTD 223-025) in June 2023 in the Schrader formation.
The well was placed on production in early June and initial welltests indicated 2,728bopd and a trace
% of both WC and formation gas with 2mmscfd of gas lift rate, but oil carryover in the gas stream
from the separator and backpressure from the system made validating the results challenging. After
mitigating the oil carryover in the gas stream and obtaining more accurate test results from both the
portable and pad separator, it appears the well is making closer to ~4,186bopd, trace % WC and
781mscfd formation gas with 2.4mmscfd gas lift rate. Though the results are encouraging, we only
appear to be seeing ~2,000bopd additional at the GC2 Facility. Modeling suggests that some of the
oil not showing up at the plant could be due to backout from the EWE pipeline that runs from L-Pad
to GC2. However, Hilcorp would like to confirm this to further evaluate the benefits of drilling
additional wells for an L-Pad Expansion or I-Pad Development Project which will require significant
capital investment. Due to L-292 having minimal gas production, Hilcorp would like to request
permission to flow the well to tanks to allow the GC2 Facility to stabilize to equivalent rates and
pressures prior to bringing L-292 online and flow L-292 independently of both the GC2 Facility and
EWE Pipeline to evaluate the rates and pressures against the modeling. This project will result in
venting approximately 3mmscf/d for a period of 30 days with the aim to let GC2 stabilize, reduce
variables that increase complexity and fully understand the modeling vs rate of existing and future
new drill wells.
We are anticipating the flowback period not to exceed 30 days. If the results are conclusive prior to
the 30 day flowback period, the well will be swapped back to the L-Pad header and EWE pipeline to
limit the volume of gas emissions vented.
The volume of gas vented will be reported to the AOGCC on the Facility Report of Produced Gas
Disposition Form (Form 10-422).
Please let us know if you have any questions or require additional information.
Thank you,
Torin Roschinger
Hilcorp Energy Alaska
Prudhoe Bay West - Operations Manager
c. 406 570 9630
Torin.roschinger@hilcorp.com
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message.
While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate.
1
Regg, James B (OGC)
From:PB Wells Integrity <PBWellsIntegrity@hilcorp.com>
Sent:Monday, July 3, 2023 4:27 PM
To:Brooks, Phoebe L (OGC); Regg, James B (OGC); Wallace, Chris D (OGC)
Cc:PB Wells Integrity
Subject:Hilcorp (PBU) June 2023 MIT Forms
Attachments:June 2023.zip
All,
AƩached are the completed AOGCC MIT forms for the tests performed in June 2023 by Hilcorp North Slope, LLC.
Well: PTD: Notes:
04‐11A 1931580 MIT‐IA to inform AA applicaƟon
04‐350 2111060 MIT‐T per Sundry #323‐120
13‐06 1972180 2‐year MIT‐T & MIT‐IA per AA AIO 4F.004
13‐19 1811800 2‐year MIT‐IA per CO 736
17‐19A 1970550 2‐year MIT‐T & CMIT‐TxIA per CO 736
A‐16A 1960980 4‐year MIT‐IA
C‐41B 2131040 2‐year MIT‐T & CMIT‐TxIA per CO 736
L‐292 2230250 MIT‐T & CMIT‐TxIA per PTD 223‐025
L‐293 2230200 IniƟal 4‐year MIT‐IA
M‐30 1920300 4‐year MIT‐IA
N‐01A 2041130 2‐year MIT‐IA per AA AIO 3C.003
V‐214 2051340 4‐year MIT‐IA
V‐218 2070400 MIT‐IA to verify barriers. Well is Under EvaluaƟon for possible TxIA communicaƟon.
W‐11 1891070 4‐year MIT‐IA
WGI‐03 1790490 4‐year MIT‐IA
WGI‐06 1900300 4‐year MIT‐IA
Please reply with quesƟons or concerns.
Andy Ogg
Hilcorp Alaska LLC
Field Well Integrity
andrew.ogg@hilcorp.com
P: (907) 659‐5102
M: (307)399‐3816
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named
above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this
email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed
above, then promptly and permanently delete this message.
While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission,
opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and
the recipient should carry out such virus and other checks as it considers appropriate.
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.
PBU L-292PTD 2230250
Submit to:
OPERATOR:
FIELD / UNIT / PAD:
DATE:
OPERATOR REP:
AOGCC REP:
Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min.
PTD 2230250 Type Inj N Tubing 0 3700 3663 3647 Type Test P
Packer TVD 4020 BBL Pump 2.5 IA 0 0 0 0 Interval O
Test psi 3500 BBL Return 2.4 OA 0 0 0 0 Result P
Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min.
PTD 2230250 Type Inj N Tubing 0 3650 3600 3581 Type Test P
Packer TVD 4020 BBL Pump 4.6 IA 0 3650 3600 3581 Interval O
Test psi 3500 BBL Return 4.6 OA 0 0 0 0 Result P
Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes
W = Water P = Pressure Test I = Initial Test P = Pass
G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail
S = Slurry V = Required by Variance I = Inconclusive
I = Industrial Wastewater O = Other (describe in notes)
N = Not Injecting
Notes:
Hilcorp North Slope LLC
Prudhoe Bay / PBU / L-Pad
Shane Barber
06/08/23
Notes:MIT-T per approved PTD 223-025. AOGCC witness waived by Brian Bixby.
Notes:
Notes:
Notes:
L-292
L-292
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Mechanical Integrity Test
jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov
Notes:CMIT-TxIA per approved PTD 223-025. AOGCC witness waived by Brian Bixby.
Notes:
Notes:
Form 10-426 (Revised 01/2017)2023-0608_MIT_PBU_L-292_2tests
1-Oil producer
J. Regg; 8/24/2023
David Douglas Hilcorp North Slope, LLC
Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 777-8337
E-mail: david.douglas@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Hilcorp North Slope, LLC
Date: 06/28/2023
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL :
WELL: PBU L-292
PTD: 223-025
API: 50-029-23751-00-00
FINAL LWD FORMATION EVALUATION + GEOSTEERING LOGS (05/01/2023 to 06/01/2023)
x EWR-M5, AGR, ABG, DGR, PCG, ADR, Horizontal Presentation (2” & 5” MD/TVD Color Logs)
x Final Definitive Directional Survey
x Final Geosteering and EOW Report/Plots
SFTP Transfer – Main Folders:
PBU L-292 LWD Subfolders:
PBU L-292 Geosteering Subfolders:g
Please include current contact information if different from above.
PTD:223-025
T37785
Kayla
Junke
Digitally signed by
Kayla Junke
Date: 2023.06.28
15:36:12 -08'00'
David Douglas Hilcorp North Slope, LLC
Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 777-8337
E-mail: david.douglas@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Hilcorp North Slope, LLC
WELL: PBU L-292PB1
PTD: 223-025
API: 50-029-23751-70-00
FINAL LWD FORMATION EVALUATION LOGS (05/01/2023 to 05/26/2023)
x EWR-M5, AGR, ABG, DGR, PCG, ADR, Horizontal Presentation (2” & 5” MD/TVD Color Logs)
x Final Definitive Directional Survey
PBU L-292PB1 LWD Subfolders:
Please include current contact information if different from above.
PTD: 223-025
T37786
Kayla Junke
Digitally signed by
Kayla Junke
Date: 2023.06.28
15:36:31 -08'00'
PRUDHOE BAY FIELD /
SCHRADER BLUFF OIL POOL, ORION DEV AREA
By Grace Christianson at 9:57 am, Jun 22, 2023
Completed
6/8/2023
JSB
RBDMS JSB 062223
DSR-6/28/23 GMGR08AUG2023
Digitally signed by Monty M Myers
DN: cn=Monty M Myers, c=US,
o=Hilcorp Alaska, LLC, ou=Technical
Services - AK Drilling,
email=mmyers@hilcorp.com
Reason: I am approving this document
Date: 2023.06.22 08:55:28 -08'00'
Monty M
Myers
Digitally signed by Torin
Roschinger (4662)
DN: cn=Torin Roschinger (4662),
ou=Users
Date: 2023.06.22 09:33:21 -08'00'
Torin
Roschinger
(4662)
CASING AND LEAK-OFF FRACTURE TESTS
Well Name:PBW L-292 Date:5/10/2023
Csg Size/Wt/Grade:9.625" 40/47# L-80 Supervisor:Barber/ Amend
Csg Setting Depth:6590 TMD 2662 TVD
Mud Weight:9.5 ppg LOT / FIT Press =277 psi
LOT / FIT =11.50 ppg Hole Depth =6620 md
Fluid Pumped=1.3 Bbls Volume Back =1.0 bbls
Estimated Pump Output:0.062 Barrels/Stroke
LOT / FIT DATA CASING TEST DATA
Enter Strokes Enter Pressure Enter Strokes Enter Pressure
Here Here Here Here
->00 ->0
->220 ->8308
->440 ->16 616
->680 ->24 925
->8 125 ->32 1233
->10 171 ->40 1540
->12 202 ->48 1848
->14 245 ->56 2156
->15 277 ->64 2464
-> ->68 2623
-> ->
-> ->
-> ->
-> ->
Enter Holding Enter Holding
Time Here Pressure Here Time Here Pressure Here
->0 235 ->0 2623
->1 212 ->1 2622
->2 208 ->2 2622
->3 202 ->3 2622
->4 194 ->4 2622
->5 191 ->5 2621
->6 189 ->10 2619
->7 187 ->15 2616
->8 183 ->20 2615
->9 180 ->25 2614
->10 178 ->30 2613
-> ->
-> ->
-> ->
0 2 4 6
8
10 12
14158
16
24
32
40
48
56
64
68
0
100
200
300
400
500
600
700
800
900
1000
1100
1200
1300
1400
1500
1600
1700
1800
1900
2000
2100
2200
2300
2400
2500
2600
2700
2800
2900
3000
0 1020304050607080
Pr
e
s
s
u
r
e
(
p
s
i
)
Strokes (# of)
LOT / FIT DATA CASING TEST DATA
235212208202194191189187183180178
262326222622262226222621 2619 2616 2615 2614 2613
0
100
200
300
400
500
600
700
800
900
1000
1100
1200
1300
1400
1500
1600
1700
1800
1900
2000
2100
2200
2300
2400
2500
2600
2700
2800
2900
3000
0 5 10 15 20 25 30
Pr
e
s
s
u
r
e
(
p
s
i
)
Time (Minutes)
LOT / FIT DATA CASING TEST DATA
CASING AND LEAK-OFF FRACTURE TESTS
Well Name:PBW L-292 Date:5/19/2023
Csg Size/Wt/Grade:7" 29# L-80 Supervisor:Lott/Amend
Csg Setting Depth:12584 TMD 4080 TVD
Mud Weight:9.2 ppg LOT / FIT Press =594 psi
LOT / FIT =12.00 ppg Hole Depth =12594 md
Fluid Pumped=1.2 Bbls Volume Back =1.2 bbls
Estimated Pump Output:0.062 Barrels/Stroke
LOT / FIT DATA CASING TEST DATA
Enter Strokes Enter Pressure Enter Strokes Enter Pressure
Here Here Here Here
->00 ->00
->257 ->8206
->4141 ->16 519
->6211 ->24 790
->8271 ->32 1160
->10 324 ->40 1443
->12 388 ->48 1740
->14 446 ->56 2101
->16 504 ->64 2553
->18 555 ->68 2711
->20 594 ->
-> ->
-> ->
-> ->
Enter Holding Enter Holding
Time Here Pressure Here Time Here Pressure Here
->0594 ->02680
->1526 ->12662
->2512 ->22656
->3498 ->32653
->4488 ->42651
->5478 ->52650
->6468 ->10 2641
->7460 ->15 2634
->8452 ->20 2629
->9442 ->25 2627
->10 434 ->30 2623
-> ->
-> ->
-> ->
0
2
4
6
8
10
12
14
16
18 20
0
8
16
24
32
40
48
56
64
68
0
100
200
300
400
500
600
700
800
900
1000
1100
1200
1300
1400
1500
1600
1700
1800
1900
2000
2100
2200
2300
2400
2500
2600
2700
2800
2900
3000
0 1020304050607080
Pr
e
s
s
u
r
e
(
p
s
i
)
Strokes (# of)
LOT / FIT DATA CASING TEST DATA
594
526512498488478468460452442434
268026622656265326512650 2641 2634 2629 2627 2623
0
100
200
300
400
500
600
700
800
900
1000
1100
1200
1300
1400
1500
1600
1700
1800
1900
2000
2100
2200
2300
2400
2500
2600
2700
2800
2900
3000
0 5 10 15 20 25 30
Pr
e
s
s
u
r
e
(
p
s
i
)
Time (Minutes)
LOT / FIT DATA CASING TEST DATA
Activity Date Ops Summary
4/29/2023 Walk sub base off L-293 and spot over L-292 conductor. Finish spotting and shimming sub base. Shuffle rig mats. Spot and shim cattle chute and pipeshed. Start
spotting mud mod.
4/30/2023 Cont spotting mud mod. Spot Gen mod. Cruz trucks released at 07:30. Spot auxillary equipment. Safe out walkways and stair landings. Swap to gen power at
09:00. Lay herculite and spot cuttings box and build containment. Rig up interconnects. Turn on steam and water to rig. Prep to scope derrick. Post rig move derrick
inspection. Scop up derrick and plug in. Hang rig tongs. Swap to 5" drill pipe inserts on hyd. elevators. C/O rollers on iron roughneck. Work on rig acceptance
checklist. Take on spud mud and dress out shakers. Start N/U diverter system, set stack on starter head. Obtain RKB's. Cont. working on rig acceptance checklist.
Cont. N/U diverter vent line. Center and chain stack. Install riser and air up boots. Energize accumulator system. Install drain hoses. Install mousehole. Rig accepted
at 23:00. Pick up, drift and rack back 36 joints of 5" drill pipe. Cont. to pick up, drift and rack back 194 joints drill pipe, HWDP and jars. Mobilize BHA components
5/1/2023 Cut and slip drilling line (75'). 683' left on spool. Calibrate crown and floor saver. Service traveling equipment. Perform diverter test. Knife valve open 8 secs,
Annular close 14 sec. Drawdown Test - 2950 psi initial, 2100 psi drawdown, 200 psi increase 18 secs, Full recovery 46 secs. N2O (6 bottle avg) 2316 psi. End of
diverter line to closest ignition 82', 245' length from sub, 265' total length. Test gas alarms. H2S 10/20 ppm, LEL 20/40% (visual/audible). M/U 12-1/4" Kymera w/
1.5 TerraForce mtr (non ported float installed in motor). XO and 2x stands 5" NC50, S-135 DP. Flood conductor and surface lines. P/T HP lines to 3500 psi (test
good). No leaks on stack or diverter system. Tag @ 106' MD. Spud well and drill 12-1/4" surface F/ 106' - T/ 217' MD. Start w/ 2-3K WOB, 20 rpm for first 30' then
increase rpm to 30 F/ 136' - T/ 217' MD. 250 gpm, 175 psi. 8.8 MW w/ 325 vis. P/U 44k, S/O 44k, Rot 44k. Mostly pea gravel w/ sand. 16 bbl loss. Pump out from
217' to 152' then pull on elevators to surface. Inspect bit (no damage). M/U MWD/LWD tools, XO. Gyro RFO 82.16, MWD RFO 221.79. Download MWD. 48K
Up/Dn. (Total length BHA #1 717.65' MD). Drill 12-1/4" surface from 216' to 310' (total 94' AROP 38 fph) at 400 gpm, 690 psi, WOB 5-10K, ECD 9.29 ppg EMW
with 8.8 ppg mud. P/U 68K, S/O 64K. Sliding 100% for 3/100'. KOP 216'. Drill 12-1/4" surface from 310' to 400' (total 90' AROP 90 fph) at 400 gpm, 810 psi, WOB
5-10K, ECD 9.29 ppg EMW with 8.8 ppg mud. P/U 68K, S/O 64K. Sliding 100% for 3/100'. KOP 216'. Jet flowline and pump through bleeder as needed. Parker
272 rig move blocking access to PB G&I and not sufficient time to utilize MP G&I without the supersuckers being captive on the MP side. all supersuckers full.
BROOH from 400' to 280'. POOH on elevators to 87' and wait for 272 to pass 'L' pad access road. call out additional trucks to use while contract trucks are travelling
to PB G&I. RIH, orientating high side and washing through tight spot at 257' and 360' to 400'. Drill 12-1/4" surface from 400' to 438' (total 38' AROP 38 fph) at 400
gpm, 895 psi, WOB 5-10K, ECD 9.41 ppg EMW with 8.9 ppg mud. P/U 68K, S/O 64K. Sliding 100% for 4.5/100' target. Jet flowline and pump through bleeder as
needed. Drill 12-1/4" surface from 438' to 908' (total 470' AROP 78 fph) at 400 gpm, 1020 psi, 40 rpms, 4Kft-lbs, WOB 5-10K, ECD 9.71 ppg EMW with 9.0 ppg
mud. P/U 71K, S/O 68K ROTW 70K. Sliding as needed for 4.5/100' target. Jet flowline and pump through bleeder as needed. Distance to WP6: 38.6', 8.32' high,
37.7' left.
5/2/2023 Drill 12-1/4" surface from 908' to 1447' (total 539' AROP 90 fph) at 450 gpm, 1200 psi, 40 rpms, 4.5Kft-lbs, WOB 8-10K, ECD 9.91 ppg EMW with 9.2 ppg mud.
P/U 77K, S/O 70K ROTW 74K. Sliding as needed for 4.5/100' target. Jet flowline and pump through bleeder as needed. Backream full stands. Last gyro survey at
1311', Clean MWD survey starting @ 1361' MD. Drill 12-1/4" surface from 1447' to 1924' (total 477' AROP 80 fph) at 475 gpm, 1253 psi, 50 rpms, 4-6Kft-lbs, WOB
8-11K, ECD 10.21 ppg EMW with 9.4 ppg mud. P/U 81K, S/O 68K ROTW 74K. Sliding as needed for 4.5/100' target. Jet flowline and pump through bleeder as
needed. Backream full stands. Drill 12-1/4" surface from 1924' to 2398' (total 474' AROP 79 fph) at 475 gpm, 1439 psi, 80 rpms, 4-6Kft-lbs, WOB 8-15K, ECD
10.21 ppg EMW with 9.5 ppg mud. P/U 86K, S/O 59K ROTW 69K. Max gas 128u Sliding as needed through tangent. Jet flowline, pump through bleeder as
needed. B/R full stands. Drill 12-1/4" surface from 2398' to 2886' (total 488' AROP 81 fph) at 475 gpm, 1320 psi, 80 rpms, 7.5Kft-lbs, WOB 4-8K, ECD 10.22 ppg
EMW with 9.5 ppg mud. P/U 92K, S/O 46K ROTW 71K. Max gas 373u Sliding as needed through tangent. Jet flowline, pump through bleeder as needed. B/R full
stands. Distance to WP6: 5.38', 1.12' low, 5.26' left.
5/3/2023 Drill 12-1/4" surface from 2886' to 3575' (total 689' AROP 115 fph) at 475 gpm, 1560 psi, 80 rpms, 7-9Kft-lbs, WOB 5-9K, ECD 10.73 ppg EMW with 9.55 ppg
mud. P/U 90K, S/O 50K ROTW 71K. Max gas 4163u (observe increase from 200-300u to 3000+u at 3015'MD) Sliding as needed through tangent. Jet flowline,
pump through bleeder as needed. B/R full stands. Drill 12-1/4" surface from 3575' to 4179' (total 604' AROP 101 fph) at 475 gpm, 1560 psi, 80 rpms, 7-10Kft-lbs,
WOB 6-15K, ECD 10.73 ppg EMW with 9.5 ppg mud. P/U 102K, S/O 44K ROTW 71K. Max gas 4187u. Sliding as needed through tangent. Jet flowline, pump
through bleeder as needed. B/R full stands. Drill 12-1/4" surface from 4179' to 4738' (total 559' AROP 93 fph) at 475 gpm, 1589 psi, 80 rpms, 10-13Kft-lbs, WOB 5-
15K, ECD 10.35 ppg EMW with 9.6 ppg mud. P/U 115K, S/O N/A ROTW 76K. Max gas 3921u. Sliding as needed through tangent. Jet flowline, pump through
bleeder as needed. B/R full stands. Drill 12-1/4" surface from 4738' to 5407' (total 669' AROP 111 fph) at 475 gpm, 1520 psi, 80 rpms, 10-12Kft-lbs, WOB 5-8K,
ECD 10.4 ppg EMW with 9.6 ppg mud. P/U 121K, S/O 47K ROTW 79K. Max gas 4633u. Sliding as needed through tangent. Jet flowline, pump through bleeder as
needed. B/R full stands. Distance to WP6: 18.11', 13.9' high, 11.53' left.
5/4/2023 Drill 12-1/4" surface from 5407' to 6085' (total 678' AROP 113 fph) at 475 gpm, 1680 psi, 80 rpms, 12-14Kft-lbs, WOB 6-10K, ECD 10.75 ppg EMW with 9.5 ppg
mud. P/U 130K, S/O 39K ROTW 83K. Max gas 4645u. Sliding as needed through tangent. Jet flowline, pump through bleeder as needed. B/R full stands. Drill 12-
1/4" surface from 6085' to 6498' (total 413' AROP 69 fph) at 475 gpm, 1683 psi, 80 rpms, 12-16Kft-lbs, WOB 6-15K, ECD 10.95 ppg EMW with 9.6 ppg mud. P/U
133K, S/O N/A ROTW 85K. Max gas 4074u. Sliding as needed through tangent. Jet flowline, pump through bleeder as needed. B/R full stands. Drill 12-1/4" surface
from 6498' to surface TD at 6600' (total 102' AROP 51 fph) at 475 gpm, 1528 psi, 80 rpms, 12-16Kft-lbs, WOB 6-15K, ECD 10.95 ppg EMW with 9.6 ppg mud. P/U
133K, S/O N/A ROTW 85K. Max gas 4521u. Sliding as needed through tangent. Jet flowline, pump through bleeder as needed. B/R full stands. Obtain final survey.
BROOH two stands to 6435'. Pump high vis sweep (on time, no increase in cuttings) and circulate hole clean 3.5xBU at 475 bpm, 1420 psi, ECD 10.18 ppg EMW,
80 rpms, 12-14Kft-lbs. Max gas 4562, reciprocating pipe. Monitor well, observe gas breaking out, but static. RIH on elevators from 6435' to 6600' washing last stand
to bottom at 474 gpm, 1345 psi, 60 rpms, 13Kft-lbs. BROOH from 6600' to 4337', pulling 20-30 fpm as hole dictates. 500 gpm, 1425 psi, 80 rpms, 13Kft-lbs, ECD's
10.3 ppg EMW with 9.5 ppg mud. Max gas 2266u. P/U 126K, S/O 40K, ROTW 73K. Distance to WP6 projected to TD: 3.08', 1.73' high, 2.55' right
50-029-23751-00-00API #:
Well Name:
Field:
County/State:
PBW L-292
Prudhoe Bay West
Hilcorp Energy Company Composite Report
, Alaska
5/1/2023Spud Date:
5/5/2023 BROOH from 4337' to 1855', pulling 20-30 fpm as hole dictates. 500 gpm, 1250 psi, 80 rpms, 8k ft-lbs, ECD's 10.5 ppg EMW with 9.5 ppg mud. Max gas 4458u.
P/U 95K, S/O 51K, ROT 68K. Saw minor tq and psi spikes @ base of permafrost then cleaned up. BROOH F/1855'-T/408' MD, 20-30 fpm as hole dictates. 450
gpm, 746 psi, 30-40 rpms, 3-5k ft-lbs, ECD's 10.2 ppg EMW W/ 9.5 ppg mud. Max gas 445u. P/U 56K, S/O 51K, ROT 55K. Monitor well @ BHA (static w/ hydrates
breaking out). Attempt to pull on elevators @ 593' MD, 15k overpull, cont BROOH T/ 408. B/D TDS. L/D NM Flex DC.s. Read MWD tools, B/O and L/D
MWD/LWD/GWD tools. Drain motor and L/D same. PDC Bit grade - 1-2-CT-A-I-X-BT-TD, Roller grade: 1-1-WT-A-I-E-NO-TD. Clean and clear rig floor of BHA
components. R/U to run casing. M/U volant tool, bail extensions, elevators. Mobilize job box, slips and centralizers to rig floor. Service rig: grease crown, inspect
skate, inspect top drive. M/U 9-5/8" shoe track and Bakerlok. Check floats - good, install baffle bypass. to 210'. RIH with 9-5/8", TXP, 40#, L-80 casing as per tally
from 210'. Tq connections to 20,960 ft-lbs. Set down at 1045', attempt to work through unable to. Establish circulation and rotary. Wash and ream casing from 1045'
to 1645', varying parameters from 3-5 bpm, 100-160 psi, 3-10 rpms 6-14Kft-lbs. P/U 115K, S/O 66K, ROTW 73K.
5/6/2023 Continue wash and ream 9-5/8", TXP, 40#, L-80 casing F/ 1645' - T/ 2748' MD. Tq connections to 20,960 ft-lbs. Vary parameters 3-6 bpm, 100-160 psi, 3-10 rpms
8-18Kft-lbs. Only minor issues once past build section 2050' MD. Wash and ream 9-5/8", TXP, 40# & CDC 47#, L-80 casing F/ 2748' - T/ 4143' MD. Vary
parameters 3-6 bpm, 130-190 psi, 3-10 rpms 8-18Kft-lbs. Work pipe 2hrs with string wt tags at base of permafrost (2725'-2800') then continue RIH w/ only minor to
moderate issues.. Cont. to RIH with 9-5/8", 47#, L-80, TXP & CDC casing as per detail from 4143' to 6306'. Observe up to 20K drag. Fill pipe every 5 and break
circulation every 10 to pits with ~50 bbls, observing less drag after breaking circulation. P/U 222K, S/O 55K. Cont. to RIH with 9-5/8", 47#, L-80, TXP casing as per
detail from 6306' to 6590'. Observe up to 20K drag. Fill pipe every 5 and break circulation every 10 to pits with ~50 bbls, observing less drag after breaking
circulation. P/U 222K, S/O 55K. Establish circulation. Stage pumps up to 7 bpm, 255 psi, max gas 801u, 0-2 rpms 18Kf-lbs (limiter). Condition mud to 15 YP. Rig
up cementers. Prep pits. Rig up cement lines and continue circulating stage pumps up to 7 bpm, 470 psi. Wait on CDR2 rig move to pass 'L' pad access road.
Pump 5 bbls water. PT lines 1000/4000 psi - good. Pump 53 bbls of tuned spacer at 2 bpm, 100 psi with 4# red dye and 5# polyflake. Drop bypass plug.
5/7/2023 Continue pumping 1st stage cement job with full details below: Pump 53 bbls of tuned spacer at 2 bpm, 100 psi with 4# red dye and 5# polyflake. Drop bypass
plug. HES pump LEAD EconoCem Type I/II 12# cmt 190 bbls (455 sx), 4.5 bpm, 360 psi, 2.347 yl. TAIL HalCem Type I/II15.8# cmt (Wet at 6:37) 80 bbls (390 sx),
1.152 yld, 3.9 bpm, 660 psi. Drop shutoff plug. HES Pump 20 bbls FW, 5 bpm, 225 psi. Rig disp (MP!) 237 bbls 9.5 ppg spud mud, 5 bpm, 380 psi. HES pump 80
bbls 9.4 ppg spacer, 2.6 bpm, 230 psi. Rig displace w/ 154.4 bbls Spud mud, 5 bpm, 515 ICP, reduce rate to 3 bpm, 625 FCP. Bumped @ 391.4 bbls, (Calc 382.5
bbls.) Hold 1250 psi (3 min). Bleed off psi, Psi up & open stage tool 4 bpm, shift @ 3180 psi (soft shift due to inclination and extended set depth). CIP @ 8:53 hrs.
Parked in tension 150k up. Lost 27 bbls during Displacement. Shift tool and saw minimal returns @ 4 bpm, with psi slowly dropping from 3100 psi to 2200 pumping
away 71 bbls total. Work pipe 150k up and down to blk wt while surging pump to 10 bpm. Re-establish full returns with increase in flow due to charged formation.
Cont circulate @ 6 bpm, 665 ICP. Saw trace of green cmt and spacer @ 1.5 btms up. Cmt indicated by smell and 10.3 PH. Circulate a total of 2x btms up. Flush
surface equipment with "Black Water" while working annular 2x (Knife valve disconnected). Hook up knife valve and cont circ 6 bpm surge pump 10 bpm every
hour (3-5 min). Clean suction screens both mud pumps. 2nd stage cement job as per detail: flood lines with 5 bbls water at 5 bpm, 250 psi. Pump 56 bbls 10 ppg
tuned spacer (with 4# red dye, 5# polyflake in first 10 bbls) at 4 bpm, 305 psi. pump 490 bbls 10.7 ppg ArcticCem lead cement at 4.5 bpm, 280 psi. Observe spacer
back 455 bbls into lead cement. Pump 56 bbls Type I/II 15.8 ppg tail cement at 3.7 bpm, 350 psi. Drop closing plug. HES displace with 20 bbls water at 5 bpm, 250
psi. Swap to rig pumps and bump plug with 201 bbls (195 calculated) of 9.6 ppg spud mud, slow rate to 3 bpm with 10 bbls calculated left, FCP 608 psi. Pressure
up and observe tool shift close at 2257 psi. Hold 1600 psi for 5 minutes. Bleed back 2 bbls to pits and confirm tool shifted close. CIP at 23:12. No losses. 195 bbls
cement to surface. R/D cement manifold from Volant. Pump black water through cement hose and flow line. De-energize accumulator and disconnect knife valve.
Fill stack with black water. Blow down cement hose and equipment. R/D and L/D Volant tool. Clean and clear rig floor. Start N/D diverter vent line. Split stack, pull
mousehole. Set 'E' slips with 50K on slips. suck out and cut casing. Set stack back down. L/D cut joint. C/O elevators to 5". C/O bushing. 4-bolt stack. Clean MP
suctions, flow line, shaker bed.
5/8/2023 P/U 5" joint of drill pipe and M/U 'Johhny Whacker' stack washing tool. Wash out stack x 3 with black water. R/D knife valve, break apart diverter 'T'. Set stack back
on pedestal. Dress and taper casing cut. Install casing/tubing spool. PT void 500/3800 psi - good. SimOps: install MPD head, cont. cleaning pits. Rebuild rig floor
bleeder valve. N/U BOPE. P/U DSA and clean bottom threads and ring groove. Set DSA and stack. hook up choke and kill lines. TQ DSA and BOP. 4-point stack
with chain binders. Connect accumulator lines. Install drip pan, drain hoses. Install trip nipple. Install bleeder manifold on MPD, hole file line. Obtain RKB's. Open
ram doors. Clean out and inspect. Install 5" solid rams in UPR, 7" in LPR, and blinds. Set test plug. M/U test joint, side entry, TIW and dart. Energize accumulator.
Fill stack. Observed MPD clamp was leaking. Adjust stack and re-clamp. Observed test plug leaking. Pull test plug, observed some scaring on seal. Replaced seal
and set test plug. Filled stack and purged lines. Perform body test 250/3000 psi. Test BOPE on 5" and 7" test joints 250/3000psi. Witnessed by AOGCC Austin
McLeod. Test gas alarms, PVT, flow paddle. Fail on lower IBOP - replace IBOP. F/P on Dart. reseat dart, CMV 1, 2, 3 function and re-test - good. Accumulator
drawdown: starting pressure 3000 psi, after functioning 1450 psi, first 200 psi recharge in 24 sec, full recharge 100 sec. 6 N2 bottles at 2350 psi average. Rig down
testing equipment. Break down test joint Pull test plug. Blow down choke and kill lines. Set wear bushing.
5/9/2023 Mobilize 8.5" BHA components to rig floor. Prep floor and pipeshed for picking up and handling BHA. Finish installing 9" ID wear bushing. 204 jts 5" NC50 DP
staged in shed. PJSM, M/U 8.5" Hyc PDC (.7777 TFA), NRP, 7600 GeoPilot, MWD and upload. Troubleshoot coms errors with tool. C/O cables, reset, re-upload
MWD without issue. M/U NM flex DC's (install corrosion ring on top NM Flex).1x non ported float. 9 stds 5" HWDP w/ jars. Total = 711.91'. Shallow test (good). RIH
w/ 8.5" RSS picking up 5" NC50, 19.5#, S-1235 dp w/ 3.125" drfit F/ 711' - T/ 2874' MD. P/U 88k, S/O 48k. Wash down F/ 2874' - T/ tag depth 3039' w/ 2k set
down. Drill ES stage tool on depth (2,938' MD) 400 gpm, 701 psi, 50-60 rpm, 5.5k tq, P/U 95k, S/O 48k, Rot 70k. Tripped thru stage tool clean. Chase junk from
3041' to 3160' MD w/ same parameters. Cont single in hole 5" 19.5# S-135 D.P. F/ 3,160' to 5,829' MD. Encountered hole drag 7-10k on elevators. Ream down
every 10th jnt to fill pipe for weight. At 5,479' MD pumped string volume due to float failing, float still not holding. PJSM Cont single in hole F/ 5,829' to 6,240' MD
POOH rack back 13 stands in derrick F/ 6,240' to 5,415' MD Cont single in hole F/ 5,415' to 6,368' MD. Drift 3.125" OD. P/U 160k SLK 39k. Circ 1.5 BU Rot/Rec F/
6,368' to 6,429' MD 400 gpm 690 psi 30 rpm Trq13-15k F/O 37% P/U 155k SLK 39k ROT 87k. 25% increase cement/clabber at BU. PJSM R/U head pin and 1502
HP lines. Circ and purge air F/ choke manifold. Close UPR's. Test 9.625" Csg to 2,623 psi for 30 min on chart. Lost 10 psi over 30 min. Pumped 3.5 bbls, bled 3.4
bbls. R/D test Equip. Daily disposal to G&I: 342 bbls, total: 7049 bbls.
5/10/2023 Wash down from 6429' - T/ 6462' tagging BA on depth. Drill shoe track & rathole F/ 6462' - T/ 6600' finding all jewelry on depth. 4.5k WOB, 400 gpm, 770 psi, 37%
flow, 50 rpm, 14-18k tq. P/U 156k, S/O 37k, Rot 84k. Drill formation F/ 6600' - T/ 6620' MD. Displace well from 9.5 spud mud to 9.5ppg Polymer 6% KCL mud @
6620' MD. 475 gpm, 1000 psi, 40% flow, 80 rpm, 15k tq. P/U 156k, S/O 37k, Rot 84k. 9.5 In/Out Polymer mud, Trip inside shoe to 6550' MD. B/D TDS. R/U FIT
test equipment. . Finish rigging up test equipment. Shoe @ 6590' MD, 2662' TVD. Pressure up to 280 psi. 1.3 bbls in / 1 bbl out. Record shut in psi 10 min with
final psi 178 psi. Chart and record same. Email FIT/Csg test to drilling engineer. AOGCC approved to proceed with drilling operations. R/D test equip. Grease TDS,
Check oil (good), grease traveling equipment, Iron Roughneck. Sym Ops - Continue to process 7" casing. Clear rig floor and prep for drilling operations. Drill 8.5"
Hole F/ 6,620'' to 6,902' MD (2,737' TVD) Total 282' (AROP 70.5') 400-450 gpm, 1,310 psi on, 1,225 psi off, 80 rpm, TRQ on 12-16k, TRQ off 12-13k, F/O 39%,
wob 5-12k. ECD 10.45, MW in/out 9.5, Max Gas 490u. P/U 141k, SLK 35k, ROT 83k. Maintain tangent 75.99 deg inc 306.72 deg azi. Drill 8.5" Hole F/ 6,902'' to
7,245' MD (2,817' TVD) Total 343' (AROP 57.2') 450-475 gpm, 1,663 psi on, 1,544 psi off, 100-120 rpm, TRQ on 12-16k, TRQ off 12-13k, F/O 39%, wob 5-12k.
ECD 10.99, MW in/out 9.5/9.45, Max Gas 379u. P/U 145k, SLK 35k, ROT 83k. Maintain tangent. Drill 8.5" Hole F/ 7,245'' to 7,762' MD (2,945' TVD) Total 517'
(AROP 86.2') 475 gpm, 1,430 psi on, 1,390 psi off, 100-120 rpm, TRQ on 12-16k, TRQ off 10-12k, F/O 39%, wob 5-14k. ECD 11.07, MW in/out 9.4/9.45, Max Gas
346u. P/U 122k, SLK 59k, ROT 85k. Maintain tangent. Distance to WP096 4.58', 3.46' High 3.01' Right.
5/11/2023 Drill 8.5" Hole F/ 7,762'' to 8,157' MD (3,055' TVD) Total 395' (AROP 65.8') 475 gpm, 1,425 psi on, 1,390 psi off, 80-100 rpm, TRQ on 13-17k, TRQ off 13-16k,
F/O 48%, wob 3-14k. ECD 10.63, MW in/out 9.4, Max Gas 376u. P/U 139k, SLK 52k, ROT 86k. Maintain tangent. Drill 8.5" Hole F/ 8,157' to 8,781' MD (3,193'
TVD) Total 624' (AROP 104') 475 gpm, 1,535 psi on, 1,460 psi off, 120 rpm, TRQ on 12-16.5k, TRQ off 10-12k, F/O 45%, wob 5-10k. ECD 11.02, MW in/out
9.2/9.3, Max Gas 394u. P/U 137k, SLK 58k, ROT 87k. Maintain tangent. Drill 8.5" Hole F/ 8,781' to 9,140' MD (3,260' TVD) Total 359' (AROP 59') 475 gpm, 1,670
psi on, 1,560 psi off, 120 rpm, TRQ on 12-18k, TRQ off 10-11k, F/O 45%, wob 5-14k. ECD 11.0, MW in/out 9.3/9.3, Max Gas 747u. P/U 137k, SLK 52k, ROT 87k.
Maintain tangent. Drill 8.5" Hole F/ 9,140' to 9,544' MD (3,376' TVD) Total 404' (AROP 67.3') 450 gpm, 1,655 psi on, 1,620 psi off, 120 rpm, TRQ on 15-17k, TRQ
off 15-16k, F/O 43%, wob 5-11k. ECD 11.24, MW in/out 9.3/9.3, Max Gas 452u. P/U 142k, SLK 49k, ROT 87k.
Maintain tangent. At 7,478' MD Pump 25 bbls 350+ Vis sweep due to ECD's. Returned on time W/ 20% increase in cuttings. Reduced ECD F/ 11.42 to 11.24.
Distance to WP06 2.86, 0.83' High 2.73' Right.
5/12/2023 Drill 8.5" Hole F/ 9,544' to 9,702' MD (3,417' TVD) Total 158' (AROP 26.4') 475 gpm, 1,725 psi on, 1,680 psi off, 120 rpm, TRQ on 15-19k, TRQ off 15-18k, F/O
43%, wob 5-14k. ECD 11.24, MW in/out 9.3/9.3, Max Gas 452u. P/U 142k, SLK 59k, ROT 89k. Maintain tangent. Back ream 60'. AT 9,653' MD Pumped 25 bbl
Condent/ Nit plug sweep to help bit balling. Drill 8.5" Hole F/ 9,702' to 10,138' MD (3,523' TVD) Total 426' (AROP 71') 475 gpm, 1,775 psi on, 1,685 psi off, 120
rpm, TRQ on 15-16k, TRQ off 15-16k, F/O 45%, wob 5-14k. ECD 11.18, MW in/out 9.3/9.3, Max Gas 1883u. P/U 142k, SLK 58k, ROT 88k. Maintain tangent. Back
ream 60'. Drill 8.5" Hole F/ 10,138' to 10,430' MD (3,595' TVD) Total 292' (AROP 48.7') 475 gpm, 1,820 psi on, 1,715 psi off, 120 rpm, TRQ on 16-17k, TRQ off 16-
17k, F/O 45%, wob 5-14k. ECD 11.33, MW in/out 9.25/9.3, Max Gas 712u. P/U 142k, SLK 59k, ROT 91k. Maintain tangent. Back ream 60'. At 10,253' encountered
high Trq (19.5K) and no pressure spikes, worked string and added Lube 776. At 10,376' MD pumped 54 bbl Condent/ Nut Plug sweep due to suspected bit balling.
ROP increased slightly, Trq fell to 16k. Sweep back on time. Drill 8.5" Hole F/ 10,430' to 10,712' MD (3,662' TVD) Total 282' (AROP 47') 450-475 gpm, 1,725 psi
on, 1,690 psi off, 120 rpm, TRQ on 15-17k, TRQ off 15-17k, F/O 45%, wob 5-14k. ECD 11.33, MW in/out 9.2/9.25, Max Gas 1439u. P/U 142k, SLK 59k, ROT 91k.
Maintain tangent. Back ream 60'. Distance to WP06 5.98', 1.13'' Low 5.87' Right.
5/13/2023 Drill 8.5" Hole F/ 10712' - T/ 11194' MD (3784' TVD) Total 482' (AROP 81') 450-500 gpm, 1775 psi on, 1700 psi off, 80-140 rpm, TRQ on 15-17k, TRQ off 15-17k,
F/O 45%, wob 5-28k. ECD 11.4, MW in/out 9.2/9.2, Max Gas 2775u.P/U 144k, S/O 62k, ROT 92k. BR 60'. ~10780' oil back @ shakers w/ gas increase. Worked
thru slow ROP with varying parameters. Incrementally increase WOB to max 28k with no increase in differential and only minor increase in tq (800-1200 ft/lb)
indicating non rotating housing bearing higher wt. Establish acceptable ROP and continued drilling ahead. Drill 8.5" Hole F/ 11194' - T/ 11758' MD (3912' TVD)
Total 564' (AROP 95') 475 gpm, 2010 psi on, 1870 psi off, 120 rpm, TRQ on 15-17k, TRQ off 15-17k, F/O 45%, wob 5-18k. ECD 11.3, MW in/out 9.25/9.25, Max
Gas 2847u.P/U 144k, S/O 62k, ROT 92k. BR 60'. ~ Dump and dilute 290 bbls @ 11632' MD. Close approach 33-29E 11686.18' CC 143.88' SF 0.54. Drill 8.5"
Hole F/ 11,758' to 11,862' MD (3,930' TVD) Total 104' (AROP 41.6') 475 gpm, 1,970 psi on, 1,915 psi off, 120 rpm, TRQ on 17k, TRQ off 15-17k, F/O 45%, wob 8-
16k. ECD 11.51, MW in/out 9.25, Max Gas 1927u. P/U 141k, SLK 60k, ROT 93k. Maintain tangent. Back ream 60'. F/ 11,832' to 11,836' encountered hard streak.
Worked string using differential F/ 50-280 psi, working WOB up to 16k gaining 6-8". At 11,836' MD had a drill break W/ 0k WOB and ROP 150 ft/hr. Drilled F/
11,836' to 11,862' MD. Encountered high Trq and stall (19.8k) P/U off bottom continue seeing. stalls and ~30k over pull to 11,817' MD with no Press increase. Was
able to keep string rotating while moving and over pull cleaned up. Pumped Lube 776 pill and worked string F/ 11,862' to 11,817' MD free trq dropped F/ 19.5k to
15.5k. Max BU Gas when drill break was encountered 508u. Rot/Rec F/ 11862 to 11,817 MD 475 gpm 1,950 psi 120 rpm Trq 19.5 F/O 46%, ECD 11.15, MW
in/out 9.3 ppg, Max Gas 508u. Drill 8.5" Hole F/ 11,862' to 11,956' MD (3,959' TVD) Total 94' (AROP 37.6') 475 gpm, 1,845 psi on, 1,715 psi off, 120 rpm, TRQ on
11-13k, TRQ off 12k, F/O 44%, wob 10-18k. ECD 11.15, MW in/out 9.3, Max Gas 1418u. P/U 141k, SLK 59k, ROT 94k. Back ream 60'. Cont working thru slow
ROP with varying parameters. When not seeing Diff while drilling, using 18k WOB to maintain ~75 ft/hr rop. Drill 8.5" Hole F/ 11,956' to 12,390' MD (4,062' TVD)
Total 434' (AROP 72.3') 475 gpm, 1,940 psi on, 1,920 psi off, 120 rpm, TRQ on 12-15k, TRQ off 12-13k, F/O 46%, wob 10-18k. ECD 11.38, MW in/out 9.4, Max
Gas 3209u. P/U 144k, SLK 68k, ROT 100k. 3 deg/100' build turn at 12,274' MD. Back ream 60'. Distance to WP06 14.72', 5.08' Low 13.2' Right.
5/14/2023 Drill 8.5" Hole F/ 12390' - T/ TD @ 12594' MD (4080' TVD) Total 204' (AROP 51') 475 gpm, 1980 psi on, 1965 psi off, 120 rpm, TRQ on 14-19k, TRQ off 14-19k,
F/O 46%, WOB 10-27k. ECD 11.4, MW in/out 9.4, Max Gas 3883u. P/U 146k, SLK 68k, ROT 102k. H/S @ 100% deflection building to 90 land in NB . Circulate 3x
btms up racking back 1x std ea btms up F/ 12594' - T/ 12339' MD. Pump 35 bbl tandem sweep @ TD. Back on time w/ 10% inc in cuttings. 475 gpm, 1975 psi,
46% flow, 11.6 ECD's, 120 rpm, 18.8k tq, P/U 146k, S/O 68k, Rot 102k. 3863u Max gas. RIH on elevators F/ 12339' - T/ TD depth 12594' MD. P/U 185k, S/O 58k
(no pumps). Monitored well (static). BROOH F/ 12594' - T/ 10945' MD. 475 gpm, 1910 psi, 44% flow, 120 rpm, 9-10k tq, P/U 144k, S/O 60k, Rot 92k. Pull 25-35
fpm. 184 max gas. No losses. BROOH F/ 10,945' to 9,452' MD 400-475 gpm 1,200-1,480 psi 120 rpm Trq 10.5-11k F/O 42% ECD 11.45 Max Gas 796u P/U 140k
SLK 67k ROT 89k. Speed 10-25 as hole dictates. F/ 9,846 to 9,803 MD encountered packing off ECD spike to 11.7 and Trq spikes. Worked thru W/ 400-420 gpm
1,200-1,480 psi 120 rpm Trq 10.5-12.7k pull speed 1-5 ft/min. CBU 2X initial BU 20% increase in coal/ sand and again at 1.5 BU. Continue seeing coal across
shakers. Having to manual send GeoPilot home every connection. BROOH F/ 9,452' to 8,333' MD 400-450 gpm 1,200-1,525 psi 120 rpm Trq 10.5-11k F/O 42%
ECD 11.15 Max Gas 367u P/U 136k SLK 72k ROT 86k. Speed 10-20 as hole dictates. F/ 9,309' to 8,983' MD Continue seeing intermittent packing off, Trq spikes
and mild over pull. Worked thru W/ 400-450 gpm 1,200-1,580 psi 120 rpm Trq 10.5-14.7k pull speed 1-5 ft/min adjusting parameters as needed. Continue seeing
coal at shakers. Lost 22 bbls. Distance to WP06 37.15', 32.98' Low 17.1' Right, in NB Sand.
5/15/2023 Continue BROOH F/ 8333' - T/ 7823' fighting tight hole with minimal returns. Saw 20k stalls w/ 15-20k overpulls. During significant packoffs with zero returns, we
saw 13.4 ECD's. 60-80 rpm, 13-20k tq, 375-425 gpm, 1400-1800 psi. Maintained free pipe throughout. P/U 134k, S/O 52k, Rot 84k. Establish partial returns @
7823' MD. Rot/Recip pipe 4x before establishing full returns @ 375 gpm. Stage pumps up to 500 gpm, 1650 psi, 46% flow, 80 rpm, 13k tq, 11.3 ECD's. Pump 35
bbl hi vis sweep w/ increase in cuttings. Hole unloaded with sand/slit & few quarter size coal. Max gas 540u. Wash and ream down F/ 7823' - T/ 8273' MD with
minimal issue. 500 gpm, 1685 psi, 80 rpm, 13.5k tq. P/U 132k, S/O 60k. BROOH F/ 8273' - T/ 7760' MD. Backream clean, 20-25 fpm pulling speed. 10.9 ECD's.
Continue BROOH F/ 7760' - T/ 6559' MD with 5-25 fpm as hole dictates, mitigate packoffs and tq spikes. Hole unloaded several times with no issues pulling into
shoe. 500 gpm, 1640 psi, 46% flow, 80 rpm, 13k tq, 11.15 ECD's, 460u max gas. P/U 124k, S/O 68k, Rot 83k. Reduce rpm T/60 pull BHA in shoe. Circulate hole
clean @ 6559' MD (Rot/Recip). 550 gpm, 1775 psi, 49% flow, 120 rpm, 11.9k tq, 10.8 ECD's. Pump 2x 35 bbl hi vis sweep w/ 1st coming back on time with 100%
ince, 2nd on time w/ 10% increase. Circulate 3x btms up. Max gas 84u. Monitor well 10 min, static. PJSM Service rig. Grease crown, blocks, TD, spinners & PH8.
Check oil in TD and rotary table. C/O short mouse hole to long. Attempted to POOH F/ 6,559' to 6,431' MD (4 jnts) observed swabbing. P/U 118k SLK 61k. CBU in
an attempt to clear BHA. Rot/Rec F/ 6,431' to 6,367' MD 550 gpm 1,750 psi 120 rpm Trq 12k ECD 10.8, F/O 48%.Max Gas 36u. Minimal cuttings seen at shakers.
Monitor well 15 min, static. Blow down GeoSpan. Attempted to POOH on elevators, still swabbing. Decision was made to pump out. Pump out of hole L/D 5" D.P. F/
6,431' to 5,120' MD 126 gpm 195 psi P/U 112k SLK 60k Calc 11.2 bbls Act 14 bbls Lost 3.8 bbls. PJSM Cont Pump out of hole L/D 5" D.P. F/ 5,120' to 3,524' MD
166 gpm 206 psi, checked for swabbing F/ 4,695 to 4,560 (5 Jnts), still swabbing. Checked again at 3,646 to 3,524 MD (5 jnts) W/ slight swabbing. CBU 550 gpm
1,480 psi 60 rpm Trq 5.4k shakers appeared clean. POOH on elevators F/ 3,524 to 2,142 MD. Pump corrosion inhibited dry job. Blow down TD. P/U 79k SLK 62k
Calc 25 bbls Act 29 bbls Lost 4 bbls.
5/16/2023 Continue POOH F/ 2142' - T/ 712' ()BHA laying down 5" DP. P/U 62k, S/O 60k. Monitor well @ BHA (static). 12 bbl loss for trip. L/D NM Flex DC's. Read MWD.
L/D smart tools and GeoPilot. BHA showed significant wear on ILS, MWD body. Reference housing was locked up. Cutters on reference housing showed significant
wear indicating drag from rotation (see pics in "O" drive). Bit graded 3,3,CT,A,I,X,LT,TD. Clean and clear rig floor. Pull wear bushing. Demobilize BHA components
from rig floor. R/U 5' bail extensions, 250T 7" side door elevators. Hook up double stack power tongs and function same (good). Stage 44 centralizers on floor. Load
pipeshed for a total of 324 joints 7" Vam (includes shoe track). R/U handling equipment. PJSM, M/U 7" BTC shoe track (Summit equipment) and check floats
(good). M/U BTC x Vam crossover = 205' MD. Bakerlok shoe track & XO. Pump thru without issue. Run 7" Vam Top, 29#, L-80 casing F/ 205' - T/ 2308'. M/U tq
9.4k ft/lbs. Fill every 5 jts. pu 79k 62k slk 61k. Calc 22.5 act 16.3 lost 6.2. Cont RIH 7" 29# L-80 VamTop F/ 2,308' to 5,385' MD Pump string volume at 3,300' MD 6
bpm 240 psi shakers clean. Trq Turn 9.4k Trq. Fill every 5 top off 10. P/U 105k Slk 62k. Run speed 30-40 ft/min. Calc 54 bbls Act 52.4 bbls Lost 1.6 bbls. Cont RIH
7" 29# L-80 VamTop F/ 5,385' to 8,706' MD Turn 9.4k Trq. Fill every 5 top off 10. P/U 140k Slk 59k. Run speed 30-40 ft/min. Calc 81 bbls Act 78 bbls Lost 3 bbls.
Pump string volume at 6,451' MD 7 bpm 415 psi, shakers clean at BU. At 6,451' obtain parameters 5 rpm TRQ 5.5k only while moving 20 fpm. P/U 112k SLK 62k
ROT 69k.
5/17/2023 Continue RIH F/8,716' - T/9,484' MD with 7" VAMTOP 29# L-80. TQ Turn connections to 9400 ft-lbs Encountered tight spot at 9,075' circulated at 5bpm while
rotating and reciprocating. Lost returns and reduced flow in to 2bpm. Washed down to 9,095' past tight spot. Continue RIH T/9,484' MD. P/U=160K, S/O=54K.
Running speed=30-50fpm.Filling every 10 joints. Circulate a string volume with 1/2 drum of 776-Lube. Rotate and Reciprocate F/9,430' - T/9,484' MD, staging up
to 5.5bpm, with a 60bph dynamic loss rate. Reduced pumps to 3bpm staging back up to 4bpm = 550psi w/ good returns. TQ stall at 7,250 ft-lbs achieving 1-2RPM.
Lost 60bbls during circulation. Continue to RIH with 7" Casing F/9,484' -T10,607' MD. TQ Turn Connection T/9,400 ft-lbs. Filling every 5 joints and circulated every
10 joints. P/U=190K, S/O=52K, running speed 30-50fpm. Continue RIH F/10,607' - T/12594'. RIH T/10,910' MD Losing down weight. Staged pumps up F/1.0BPM -
T/4.0BPM = 520psi. Working string and TQ stalling at 7,250 ft-lbs with 5-8 RPM. Reduced pump rate to 1.5BPM and worked thru tight spot. Continue RIH
F/10,910' - T/11,653' MD and Circulated Bottoms up. Staged pumps up from 1.0BPM - 5.5BPM encountering a 36BPH Dynamic loss, reduced pump rate to
5.0BPM = 655psi, losses reduced to 0BPH dynamic. No increase in cuttings observed with bottoms up. RIH T/12,413' MD and wash down last 3 joints at
2BPM=515psi. Picked up 2 additional tag joints. Tag bottom on depth 12,594' MD TD with 7" 29# Intermediate Casing. Lay down the 2 tag joints and Pick up the 7"
Hanger Landing joint per wellhead rep. Land hanger to 12,585' MD. PJSM Circ & Cond to <20YP. Stage pumps F/ 2-5 bpm 550-790 psi F/O 33% Max Gas 372u.
~2 BPH dynamic loss. SIMOPS R/D 7" handling Equip and power tongs. Clear rig floor. Blow down TD. R/U Cement lines. Blow down to HES. Prep Pits. PJSM,
Wet lines w/ 5 bbls H2O (HES) and P/T low kick out 920/ 3280 high. Failed high. Changed out 2 LoTrq valves F/ H/P line to Volant and retest (test good). Pump
cement job as follows: 60 bbls 10 ppg Tuned spacer w/ 4# red dye & 5 lb/bbl poly flake (1st 10 bbls) 3.4 bpm 620 psi. Release F/ Volant. & drop bottom plug. HES
Pump 90 bbls 15.8 ppg cmt, 1.155 yld (428 sx) 3.4 bpm 620 psi. Shut down release F/ Volant and drop top plug. HES pump 20 bbls H2O 5 bpm 425 psi. Rig
displaced W/ MP 1, 9.45 ppg 6% KCL/ Polymer Mud, initial rate 4.5 bpm 429 psi increased to 5.5 bpm 680 psi at 120 bbls away. decreased to 5 bpm 850 psi at
240 bbls away, decreased to 4.5 bpm 843 psi at 300 bbls away, decreased to 4 bpm 986 psi at 310 bbls away, decreased to 3.5 bpm 995 psi at 360 bbls away,
decreased to 3 bpm 1,020 psi at 380 bbls away, decreased to 2.5 bpm 1,020 psi at 410 bbls away. Plug bumped W/ 940 psi FCP, pressure up to 1,445 psi hold 5
min. Check Floats good. CIP at 02:20. Calc displacement 462.9 bbls, actual 465.4 bbls. Lost 17 bbls throughout job. PJSM R/D Bails, 7" elevators and Volant. L/D.
Back out and L/D landing joint. PJSM Install 5" elevator, P/.U 5" HWDP and install pack off. Pull bushings. RIH set pack off as per Vault rep onsite. RILDS. Test
pack off 500/3500 psi 5/10 min. L/D running tool and 5" HWDP. PJSM P/U M/U Johnny Wacker and flush stack L/D. Blow down. Install test plug.
5/18/2023 PJSM - Change out Upper Pipe Rams F/5" SBR T/2-7/8"x5-1/2" VBR. SIMOPS: Cleaning pits and process 4" XT-39 DP for 6-1/8" Production lateral. Change over
Saver sub from NC50 to XT-39. Change out Grabber dies and stabbing guides, Grease upper and lower IBOP's. PJSM R/U for Testing BOP's - P/U & M/U 3-1/2"
TJ and test Dart, TIW, 1502 Pump in sub. PJSM Testing BOP's - Test BOPE on 3-1/2" and 4-1/2" Test Joints, to 250/3000psi 5 min. Witnessed waived by Guy
Cook. Test LEL 20-40% H2S 10-20 ppm alarms, PVT and flow paddle. Test Annular, TWI #1, Upper IBOP, Kill #3, Dart and CMV's 11-15 - Good. Test 4" TIW #2,
CMV's1-10. Kill HCR/Manual and Choke HCR/Manual/Super T/1500psi, Lower IBOP. Accumulator Drawdown test: Initial psi ACC=300psi, Manual=1500psi,
ANN=1125. Final psi ACC=1550, Manual=1500, ANN=1125. 200 psi Recharge = 20s, Full recovery = 84s. N2 six bottle average = 2345psi. Tested W/ H2O. PJSM
- R/D Testing equipment. R/D Test joint and pull test plug. Shut Annulus and Blow down Choke, Kill and Top Drive. Clean and clear rig floor. Rig Service - Grease
Top Drive, RLA, Link Tilt assembly, Spinner and FH-80. Check Oil on rotary table and grease the crown. PJSM - L/D 5" DP. L/D 214 joints of 5" NC50 Drill pipe out
of derrick using the mousehole. Extracting Drill Pipe for Hardbanding and CATIV Inspections. SIMOPS Clean pits and take on 580 bbls 9.2 ppg BaraDril N. LRS FP
85 bbls 80 deg Diesel 9.625" X 7" OA 1.6 bpm 400 psi ICP 975 psi FCP. PJSM R/D 5" handling Equip and install 4" handling Equip. Stage 6.125" BHA
components on rig floor. Prep Pipe Shed for BHA and picking up 4" 14# S-135 XT39 D.P. Inspect TD for Hydraulic leak, still undetermined. PJSM P/U M/U 6.125"
XR+PS Tricone RR (TFA 0.5177), 1.5 Motor TerraForce Lobe 7/8-2.9, 4" HWDP and 4 3/4" SLB Jar to 279.44' MD. PJSM Single in hole BHA #3 W/ 4" 14# S-135
XT39 D.P. F/ 279' to 5,140' MD Drift OD 2.375". Fill pipe every 2,500'. P/U 72k SLK 52k.
5/19/2023 PJSM - Continue singling in the hole with Cleanout 6.125" BHA #3 conveyed on 4" XT-39 14# S-135 Drill Pipe F/5140' - T/12,152' MD. P/U=115K, S/O=48K. Filled
pipe every 2500' and dumped displacement to drag chain. Washed and Reamed F/12,152' - T/12,181 MD, 225gpm=1510psi, 7.0K TQ at 30RPM, RF=26%.
P/U=111K, S/O=55K, ROT=84K. No notable cement stringers when Reaming down. Making up Top Drive to 4" DP Single, Driller noticed a TQ variance when
making up - backed out of and found that Joint #373 had an indentation in the Box. Further inspection revealed that the Saver Sub was damaged and the decision
was made to change it out. Washed and Reamed F/12,181' - T/12,435' MD, CBU. 220gpm=1160psi, RF=26%, 7.5K TQ at 30RPM, P/U=112K, S/O=65K,
ROT=88K.Observed torque stall at 7.5K and an overpull of 30K, increased TQ to 12K and pulled 30K over worked pipe and TQ was released. Increased 250gpm,
no further issue. PJSM - Test 7" CSG. M/U Top Drive, flood lines and purge air from system pumping thru the Kill. Close UPR and pump down Kill/String to
2500psi and hold for 30mins - Good Test. Pumped 2.1bbls and bled back 2.1bbls. 9-5/8" x 7" OA Initial=110psi, During=300psi, Final=175psi. R/D Testing
Equipment. PJSM Blow down TD, kill & choke lines. R/D test lines. PJSM Cut and slip drilling line. Hang blocks. Cut 15 wraps (94') ACCTM 45,318. Left on spool
589'. Check brake tolerance. Tighten dead man. Calibrate drum and check crown saver. SIMOPS Inspect TD for leaking hydraulic hoses. PJSM Service rig. Grease
wash pipe, TD, spinners, check oil in TD & rotary table. Perform wobble EAM on crown and block sheaves. Replace Lube supply and brake hydraulic lines on TD.
Drill down 4" singles F/ 12,435' to 12,495' MD. Drill FC on depth at 12,455' MD. Observed rubber at shakers. Reamed thru FC 2X and 1X no pump or rotary, no
issue. 225 gpm 1,305 psi 30 rpm Trq 9.5-12k WOB 1-5k P/U 118k SLK 68k ROT 76k. Cont drill down 4" singles F/ 12,495' to 12,614' MD. Shoe on depth at
12,585' MD, reamed thru 2X and 1X no pump or rotary, no issue. Drilled 20 of new hole F/ 12,585' to 12,614' MD. Saw Trq spikes at 12,594', 12,599', 12,605' &
12,608' MD worked through W/ Trq stall set at 12.2k. 225-250 gpm 1,350-1620 psi 30-60 rpm Trq 9.5-12.2k WOB 1-5k P/U 118k SLK 68k ROT 76k. Rot/Rec F/
12,614' to 12,552' MD. Displace well F/ 9.25 ppg 6% KCL/ Polymer mud to 9.2 ppg BaraDril N 225 gpm 1,420 psi 60 rpm Trq 10.8-11.5k. Shut down when 9.2 ppg
MW in/out. Cont to see stalling F/ 12,608' to 12,614' MD coming off bottom. Max Gas 776u. L/D single and rack back stand to 12,525' MD. P/U 140k SLK 53k ROT
76k. SPR. Monitor well 10 min, static. PJSM Kelly up. Break circ thru kill line and DS. Close UPR's circ thru choke and flood/ purge air from choke manifold.
5/20/2023 Finish F.I.T. - UPR closed, Finish flooding and purging air out across mud cross. Performed F.I.T. with 9.2ppg BARADRIL-N Mud via MP#2 to Initial pressure
594psi (12.0ppg EMW) for 10 mins (charted), final pressure 434psi. pumped 1.2bbls and bled back 1.2bbls. R/D Equipment and B/D Choke. Remove 4" manual
elevators and install Hydraulic with 4" inserts. PJSM - POOH F/12,525' - T/3,849' MD Racking back 4" XT-39 DP. Pulled the initial 5 stands w/ some swabbing,
pulled another 5 and swabbing ceased. Pumped a 20bbl dry-job (11.1ppg), B/D top drive and POOH on elevators. P/U=140K, S/O=56K, Calculated displacement
45bbls, Actual 51bbls, Loss of 6 bbls. POOH F/3,849' - T/279' MD (BHA). P/U=40K, S/O=41K, Calculated Displacement 23.4bbls, Actual 32.1bbls, loss of 8.7bbls.
PJSM - L/D BHA F/279' - T/Surface. Rack back HWDP and Jars in the derrick. Flush and drain Motor - L/D. Bit Grade: 1-1-WT-A-E-I-NO-BHA. PJSM - M/U BHA.
P/U 6.125" MM54D PDC (0.4640 TFA), GEO-Pilot 5200, ADR, ILS, DM, GM, PWD, TM, NM Flex Collars, Jars and 7 joints of XT-39 HWDP (405.12'). Upload as
per MWD. Install Corrosion Ring on last NM Flex. P/U=42K, S/O=43K. PJSM Single in hole 4" 14# S-135 HT39 D.P F/ 405' to 5,095' MD At 2,495' MD broke in
GeoPilot staging up RPM's 10-60 rpm and shallow pulse test MWD. Drift OD 2.375" P/U 79k SLK 49k. PJSM Cont ingle in hole 4" 14# S-135 HT39 D.P F/ 5,095'
to 8,115' MD RIH F/ derrick F/ 8,115' to 12,539' MD. Filling D.P. every 3,000'. Drift OD 2.375" P/U 136k SLK 48k. Lost 15. PJSM Drain stack. Pull bushing's. Break
Grey Clamp and pull riser. Install RCD bearing onto stand.
5/21/2023 PJSM - Finish MPD Installation - Lower bearing into RCD, make up RCD Clamp, flood lines. Shut in Beyond Chokes and PT to 300/1200psi - Good. Grease and
inspect crown sheaves. Open coffin and inspect Top Drive gear oil lines and lube pump flow - Good. Washed down F/12,539' - T/12,614' MD and obtain SPR's
(4,081' TVD), before exiting the shoe (12,585' MD). 200gpm = 1150psi, beyond flow out = 176gpm, 7.5-9K TQ at 60RPM, P/U = 120K, S/O = 53K, ROT = 76
200gpm = 1150psi, beyond flow out = 176gpm, 7.5-9K TQ at 60RPM, P/U = 120K, S/O = 53K, ROT = 76K. Drill 6.125" Production Lateral F/12,614' - T/12,855'
MD (AROP = 61'/hr). 225gpm = 1620/1540psi on/off, Beyond flow out = 218gpm (full open), ECD = 11.51ppg, max gas = 1809u, WOB=3-6K, 11.5/10K on/off TQ
at 100RPM, P/U = 130K, S/O = 43K, ROT = 77K. Drill 6.125" Production Lateral F/12,855' - T/ 13410' MD (AROP = 92.5'/hr). 225gpm = 1630/1550psi on/off,
Beyond flow out = 216gpm (full open), ECD = 11.41ppg, max gas = 2350u, WOB=3-6K, 11.5/10.5K on/off TQ at 120RPM, P/U = 139K, S/O = 40K, ROT = 79K.
Ream 60'. Drill 6.125" Production Hole F/ 13,410' to 13,770' MD (4,073' TVD) Total 360' (AROP 60') 225 gpm/ mpd 218, 1,600 psi on, 1,540 psi off, 120 rpm, TRQ
on 12-12.5k, TRQ off 11.5k, wob 4-7k. ECD 11.37, MW in/out 9.15/9.2, Max Gas 2,607u. P/U 141k, SLK 36k, ROT 78k. MPD 100% open. Back ream 60'. At
13,507' MD Trq increased to 12.9k while drilling, added Lube 776 to control Trq. Lost SLK at 13,670' MD. Drill 6.125" Production Hole F/ 13,770' to 13,865' MD
(4,063' TVD) Total 95' (AROP 15.8') 225 gpm/ mpd 218, 1,585 psi on, 1,520 psi off, 140 rpm, TRQ on 11.5k, TRQ off 10-11k, wob 4-8k. ECD 11.26, MW in/out
9.1, Max Gas 267u. P/U 145k, SLK 35k, ROT 77k. MPD 100% open. Back ream 60'. At 13,776 MD while drilling, string started stalling out at 13.2k. Staged Trq
stall up to 14.5k to maintain rotation. Working string F/ 13,776 to 13,736 MD W/ 7-10k over pull and 7-10 down weight, set rotation at 100 rpm, stalled out while not
moving. Pumped 2 drums of Lube 776 while working. string. Working stalled out string at 60 rpm dropping to 20 rpm over time on the up stroke and 80-100 rpm on
down stroke. No changes in pressure 225 gpm 1,510 psi. Worked string until lube was around the back side. Was able to increase RPM up to 140 rpm W/ 13.9k
Trq cleaning up to 12.3k. working string W/ higher RPM. No hole unloading at shakers W/ 140 rpm at BU. Continue drilling ahead at 140 rpm Trq 11.7-12.2k. Went
out of zone at 13,722' MD into NB Clay targeting 94 deg inc to get back in NB. Distance to wp06: 18.08', 18.0' Low 0.76' Right. 6 concretions for a total thickness of
12' ( 0.9% of the lateral). Footage NB Sand: 1,137'. Out of zone:138'. Total: 1,275'.
5/22/2023 Drill 6.125" Production Hole F/13,865' - T/14,025' MD (4,066' TVD) Total 95' (AROP 44.7') 225/219gpm Flow In/MPD, 1,585/1,520psi on/off. TRQ 11.5/10-11K
on/off at 140RPM. WOB=9-12K. MW in/out 9.1ppg, ECD 11.26, MPD 100% open. Max Gas 2888u. P/U=145K, S/O=N/A, ROT=77K. Back reaming 60'. Back in
NB at 13,847' MD. Drilled ahead F/14,025' - T/14,044' (4054' TVD) Encountering back to back doglegs at 14,025' (14 degree) and 14,044' (16 degree). Decision
was made to wash and ream out the doglegs, eventually reducing them down to 8.5 degrees. Drill 6.125" Production Hole F/14,044' - T/14,134' MD (4,049' TVD)
Total 95' (AROP 60') 225/216gpm Flow In/MPD out, 1,567/1,528psi on/off. TRQ 11.9/10.8-11.2K on/off at 140RPM. WOB=10-12K. MW in/out 9.1ppg, ECD 11.15,
MPD 100% open. Max Gas 1618u. P/U=145K, S/O=N/A, ROT=77K. Back reaming 60'. Washed and Reamed out 14.75 degree at 14,134' MD (4049 TVD) dog leg.
Sent DeoPilot home and worked F/ 14,149' to 14,104' MD 45 fpm reducing it down to 8.5 deg DLS. 225 gpm 1,580 psi 80-100 rpm Trq 11.5k. Drill 6.125"
Production Hole F/ 14,149' to 14,215' MD (4,049' TVD) Total 66' (AROP 26.4') 225 gpm/ mpd 218, 1,620 psi on, 1,580 psi off, 80 rpm, TRQ on 11.5k, TRQ off 11.5-
12k, wob 6-12k. ECD 11.22, MW in/out 9.1, Max Gas 1,985u. P/U 135k, SLK 35k, ROT 77k. MPD 100% open. Back ream 60'. ABI showing 14.6 deg DLS
Wash/ream F/ 12,215' to 14,194' MD reduced down to 9.16 deg. 225 gpm 1,580 psi 80 rpm Trq 11.5k. Drill 6.125" Production Hole F/ 14,215' to 14,537' MD
(4,055' TVD) Total 322' (AROP 58.5') 225 gpm/ mpd 220, 1,640 psi on, 1,600 psi off, 80-100 rpm, TRQ on 11.5k, TRQ off 11kk, wob 6-12k. ECD 11.22, MW in/out
9.15, Max Gas 2,339u. P/U 135k, SLK 37k, ROT 77k. MPD 100% open. Back ream 60'. Down wt back at 14,434' MD. Drill 6.125" Production Hole F/ 14,537' to
14,686' MD (4,048' TVD) Total 149' (AROP 25') 225 gpm/ mpd 225, 1,580 psi on, 1,510 psi off, 80-140 rpm, TRQ on 8-10k, TRQ off 10kk, wob 2-10k. ECD 11.51,
MW in/out 9.05, Max Gas 1951u. P/U 141k, SLK 37k, ROT 76k. MPD 100% open. Back ream 60'. Control drill and adjusting parameters to reduce bit deflection
and high DLS. Distance to wp06: 12.10', 5.26' Low 10.9' Left. 23 concretions for a total thickness of 166' ( 8% of the lateral). Footage NB Sand: 1,948'. Out of
zone:125'. Total: 2,073'.
5/23/2023 Drill 6.125" Production Hole from 14,686' to 14,939' MD Total 253' (AROP 42fph) 225 gpm, 1,770 psi, 120 rpm, TRQ on 9K, TRQ off 10K, WOB 7-10k. ECD
11.53, MW in/out 9.05, Max Gas 1184u. P/U 128K, S/O 46K, ROT 72K. MPD 100% open. Back ream 60'. Re-acquired NB Sands at 14,854'. (Faulted out at
14610'. 15' DTN throw from NB sand to NA clay). Drill 6.125" Production Hole from 14,939' to 15,235' MD Total 296' (AROP 49fph) 225 gpm, 1,750 psi, 120 rpm,
TRQ on 9K, TRQ off 8.5K, WOB 6-10k. ECD 11.8, MW in/out 9.05, Max Gas 2261u. P/U 132K, S/O 45K, ROT 72K. MPD 100% open. Back ream 60'. Drill 6.125"
Production Hole from 15,235' to 15,475' MD Total 240' (AROP 40fph) 225 gpm, 1,820 psi, 120 rpm, TRQ on 8-9K, TRQ off 8K, WOB 6-10k. ECD 11.8, MW in/out
9.05, Max Gas 2162u. P/U 130K, S/O 44K, ROT 73K. MPD 100% open. Back ream 60'. Drill 6.125" Production Hole from 15,475' to 15,758' MD Total 283' (AROP
47fph) 225 gpm, 1,820 psi, 140 rpm, TRQ on 7-8K, TRQ off 6-8K, WOB 8-10k. ECD 11.76, MW in/out 9.1, Max Gas 2477u. P/U 119K, S/O 45K, ROT 78K. MPD
100% open. Back ream 60'. Distance to wp06: 37.15', 32.52' Low 17.97' Left. 33 concretions have been drilled so far for a total of 190 (6.0% of the lateral). 1 fault
has been crossed so far. 14610'. Total footage in NB sand 2796', above NB sand 244', below NB sand 125'.
5/24/2023 Drill 6.125" hole from 15,758' to 16,234' MD Total 476' (AROP 79fph) 225 gpm, 1,860 psi, 140 rpm, TRQ on 8K, WOB 4-7K. ECD 11.98, MW 9.1, Max Gas 2265u.
P/U 116K, S/O 44K, ROT 72K. MPD 100% open. Back ream 60'. Mitigate high DLS from deflecting off concretions with max ROP (150), max WOB 12K. Drill
6.125" hole from 16,234' to 16,599' MD Total 365' (AROP 61fph) 225 gpm, 1,855 psi, 140 rpm, TRQ on 8.5K, WOB 4-10K. ECD 11.93, MW 9.1, Max Gas 2296u.
P/U 118K, S/O 44K, ROT 72K. MPD 100% open. Back ream 60'. Mitigate high DLS from deflecting off concretions with max ROP (150), max WOB 12K. Crossed
Fault #2 at 16,402', with 6' throw DTS, faulting closer to NB base. Crossed Fault #3 at 16,455' with 8' throw DTS, faulting from NB sands to NC-sand. Exited base of
NC-sand into NC-clay at 16,540'. Drill 6.125" hole from 16,599' to 16,750' MD Total 151' (AROP 25fph) 225 gpm, 1,960 psi, 120 rpm, TRQ on 7K, WOB 4-10K.
ECD 11.8, MW 9.1, Max Gas 343u. P/U 117K, S/O 45K, ROT 74K. MPD 100% open. Back ream 60'. Mitigate high DLS from deflecting off concretions with max
ROP (150), max WOB 12K. Re-acquired NC-sand at 16,740'. Drill 6.125" hole from 16,750' to 17,087' MD Total 337' (AROP 56fph) 225 gpm, 2,060 psi, 140 rpm,
TRQ on 7.5K, WOB 3-8K. ECD 12.07, MW 9.05, Max Gas 2014u. P/U 110K, S/O 47K, ROT 70K. MPD 100% open. Back ream 60'. Mitigate high DLS from
deflecting off concretions with max ROP (150), max WOB 12K. Re-acquired NB sand base at 16,933'. Distance to wp06: 31.82', 22.13' low, 22.87' left. 46
concretions have been drilled so far for a total of 229 (5.1% of the lateral). 3 faults has been crossed so far. 14,610'. 16,402'. 16,455'. Total footage in NB sand
3628', above NB sand 244', below NB sand 603', in the NC-sand 153'.
5/25/2023 Drill 6.125" hole from 17,087' to 17,114' MD Total 277' (AROP 13fph) 225 gpm, 2,080 psi, 140 rpm, TRQ on 7.5K, WOB 5-9K. ECD 12.02, MW 9.05, Max Gas
1857u. P/U 110K, S/O 48K, ROT 71K. MPD 100% open. Back ream 60'. Mitigate high DLS from deflecting off concretions with max ROP (150), max WOB 12K.
Observed ABI short survey showing a 14.1/100 DLS at 17,114'. Wash and ream x 3 at 45 fph on down stroke to reduce to 11.95/100 DLS on ABI short survey. Drill
6.125" hole from 17,114' to 17,182' MD Total 68' (AROP 45fph) 225 gpm, 2,020 psi, 140 rpm, TRQ on 7.5K, WOB 5-10K. ECD 12.06, MW 9.05, Max Gas 175u.
P/U 109K, S/O 49K, ROT 72K. MPD 100% open. Back ream 60'. Mitigate high DLS from deflecting off concretions with max ROP (150), max WOB 12K. Drill
6.125" hole from 17,182' to 17,522' MD Total 340' (AROP 57fph) 225 gpm, 2,020 psi, 140 rpm, TRQ on 7-8K, WOB 5-12K. ECD 11.96, MW 9.05, Max Gas 965u.
P/U 107K, S/O 51K, ROT 73K. MPD 100% open. Back ream 60'. Mitigate high DLS from deflecting off concretions with max ROP (150), max WOB 12K. Drill
6.125" hole from 17,522' to 17,778' MD Total 256' (AROP 43fph) 225 gpm, 2,113 psi, 120 rpm, TRQ on 8-12K, WOB 6-12K. ECD 12.13, MW 9.05, Max Gas
1145u. P/U 117K, S/O 40K, ROT 73K. MPD 100% open. Back ream 60'. Mitigate high DLS from deflecting off concretions with max ROP (150), max WOB 12K.
Drill 6.125" hole from 17,778' to 17,896' MD Total 118' (AROP 20fph) 225 gpm, 2,130 psi, 140 rpm, TRQ on 8-12K, WOB 8-10K. ECD 12.29, MW 9.05, Max Gas
872u. P/U 114K, S/O 39K, ROT 72K. MPD 100% open. Back ream 60'. Mitigate high DLS from deflecting off concretions with max ROP (150), max WOB 12K.
Crossed fault #4 at 17,762' Throw undetermined DTS from NB sand to below NB sand. Distance to wp06: 23.89', 20.02' high, 13.03' left. 62 concretions have been
drilled so far for a total of 297 (5.6% of the lateral). 4 faults has been crossed so far. 14,610'. 16,402'. 16,455', 17,762'. Total footage in NB sand 4330', above NB
sand 244', below NB sand 737', in the NC-sand 143'.
5/26/2023 Drill 6.125" hole from 17,896' to 18,216' MD Total 320' (AROP 58fph) 225 gpm, 2,120 psi, 140 rpm, TRQ on 8-9K, WOB 6-10K. ECD 12.52, MW 9.05, Max Gas
2140u. P/U 108K, S/O N/A, ROT 69K. MPD 100% open. Back ream 60'. Mitigate high DLS from deflecting off concretions with max ROP (150), max WOB 12K.
Lost down wt at 17,969'. Re-acquired NB sand at 17,920' after fault #4 at 17762' faulted us to the NB clay with 6' DTS throw. Observe a 14.2/100' DLS over 10'.
Wash and ream one pass. Drill 6.125" hole from 18,216' to 18,354' MD Total 138' (AROP 28fph) 225 gpm, 2,153 psi, 140 rpm, TRQ on 7-9K, WOB 6-12K. ECD
12.64, MW 9.05, Max Gas 2289u. P/U 109K, S/O 39K, ROT 70K. MPD 100% open. Back ream 60'. Mitigate high DLS from deflecting off concretions with max
ROP (150), max WOB 12K. At 18,354' observed pressure spikes on hard spot and ECD spike to 13.0 ppg. Pick up off bottom to ream and observe losses down to
30% returns. Slow pumps down to 150gpm and re-establish 90% returns. Continue drilling from 18,354' to 18,384' at 150 gpm, 1398 psi with 94% returns,
140rpms, 7-9Kft-lb. ABI's showed at 18/100 DLS at 18,384'. Wash and ream x 4 at 45 fpm, 150-170 gpm,120-140 rpms, 7-8Kft-lbs. lowering DLS to 13.4/100 at
170 gpm observe returns diminish to ~70%. Pump LCM pill after third wash and ream increasing flow to 226 gpm to squeeze ~14 bbls of pill into formation.
Observe returns increase to 90% at 170 gpms. Drill 6.125" hole from 18,384' to 18,420' MD Total 36' (AROP 15fph) 175-190 gpm, return flow 145 gpm (76-83%
returns), 1,660 psi, 110-140 rpm, TRQ on 7-9K, WOB 8-12K. ECD 11.93, MW 9.05, Max Gas 138u. P/U 109K, S/O 51K, ROT 70K. MPD 100% open. Observe
well breathing on connection. At 18,420' ABI shows a 37.5/100' DLS over 10' (building with GP at 24% deflection at 180). Pick up and wash/ream x 1 and confirm at
180 gpm, 1580 psi, 100 rpms, 6.5Kft-lbs. Pick up to 18,400', conduct hard reset on Geo-Pilot to confirm no issues, and ABI's reading correctly - good. Rack back
stand and monitor well. Observe well breathing but flow out consistently falling. Shut in MPD x 3 for 5 minutes and show pressure build slowing down to 10 psi on
third shut in. BROOH from 18,382' to 18,150' at 150 gpm, 1330 psi, 80 rpms, 7-9Kft-lbs. P/U 112K, S/O N/A, ROT 73K. Trough from 18,150' to 18,170' x 2.
Sidetrack wellbore from 18,170 to 18,183' at 5-10fph, 185 gpm (83% returns), 1580 psi, 120 rpms, 7-9Kft-lbs. Max gas 395 psi, ECD 11.85 ppg. Pump 50 bbl 40
ppb LCM pill, increasing flow as exits the bit to attempt and dynamic squeeze. Distance to wp06: 61.16', 60.97' high, 4.84' left. 68 concretions have been drilled so
far for a total of 319 (6.0% of the lateral). 4 faults has been crossed so far. 14,610'. 16,402'. 16,455', 17,762'. Total footage in NB sand 4330', above NB sand 244',
below NB sand 761', in the NC-sand 143'.
5/27/2023 Geo-Pilot RPM sensor reading 0, indicating failure of GP. Attempt hard reset - unsuccessful. BROOH from 18,150' to 16,854' at 175 gpm (return flow 163 gpm),
1450 psi, 120 rpms, 6-9Kft-lbs. ECD 11.69 ppg, MW 9.05 ppg. Max gas 53u, P/U 123K, S/O 48K, ROT 73K. Observer erratic tq and slight packoff at. 16952'. wipe
through x 2 clean. BROOH from 16,854' to 14,497' at 175 gpm (return flow 156 gpm), 1250 psi, 120 rpms, 6-9Kft-lbs. ECD 11.55 ppg, MW 9.05 ppg. Max gas
102u, P/U 116K, S/O 60K, ROT 75K. Pull at 15-25 fpm as hole dictates. BROOH from 14,497' to 12,539' at 175 gpm (return flow 155 gpm), 1250 psi, 120 rpms, 6-
8Kft-lbs. ECD 11.29 ppg, MW 9.05 ppg. Max gas 152u, P/U 108K, S/O 65K, ROT 72K. Pull at 15-25 fpm as hole dictates. Slow rotation to 40 rpms as BHA pulls
into shoe. Pump tandem sweeps, low vis/wt (8.8 ppg, FV=37) followed by high vis/wt (10.1 ppg, FV=147), 10% increase in cuttings. and circulate hole clean at 200
gpm (return flow 190 gpm), 1480 psi, 64 rpms 7Kft-lbs, max gas 32u, ECD 11.76 ppg, MW 9.05. P/U 104K, S/O 60K, ROT 75K. Monitor well, slight breathing
consistently falling. Shut in with MPD x 3 for 5 min with consistent less pressure build. 12 psi third shut in. Pull MPD bearing, set trip nipple. Attempt to POOH on
elevators. Observe swabbing. Pump out of hole from 12,476' to 10,770' at 3.5 bpm, 750 psi. P/U 113K, S/O 62K. Calc disp 9 bbls, actual 10.2 bbls. Distance to
wp06: 61.16', 60.97' high, 4.84' left. 68 concretions have been drilled so far for a total of 319 (6.0% of the lateral). 4 faults has been crossed so far. 14,610'. 16,402'.
16,455', 17,762'. Total footage in NB sand 4330', above NB sand 244', below NB sand 761', in the NC-sand 143'. Daily downhole losses = 100 bbls, total lost
production hole= 382 bbls.
5/28/2023 Cont. to pump out of the hole from 10,770' to 10,205' at 3.5 bpm, 600 psi. POOH on elevators from 10,205' to 283'. Cacl disp 55.8, actual 62.9. L/D BHA. Rack
back HWDP/Jars. L/D flex collars. Download MWD. Rack back MWD. L/D Geo-Pilot - reference housing locked up. Bit grade 3-6-BT-A-X-I-LM-DTF.
Clean and clear rig floor of BHA components. Drain stack, pull wear bushing, install test plug. M/U testing equipment. Flood surface equipment. Attempt shell test
and observe leaking by test plug. Pull test plug and observed damaged seal and gravel/debris around seal. M/U Johnny whacker and wash out stack. Re-set test
plug, still washing. by. Pull test plug, re-measure and consult with wellhead rep. Install correct test plug. Flood stack and purge air. Test BOPE 250/3000 psi.
AOGCC right to witness waived by Austin McLeod. Test on 3-1/2" and 4-1/2" Test joints. Upper IBOP failed, replace IBOP while continuing to test . Lower IBOP F/P.
Test gas alarms, flow paddle, pit level G/L. .Accumulator drawdown: starting pressure 2950 psi, after functioning 1500 psi, first 200 psi recharge in 33 sec, full 107.
(6) N2 with 2325 psi average. Distance to wp06: 61.16', 60.97' high, 4.84' left. 68 concretions have been drilled so far for a total of 319 (6.0% of the lateral). 4 faults
has been crossed so far. 14,610'. 16,402'. 16,455', 17,762'. Total footage in NB sand 4330', above NB sand 244', below NB sand 761', in the NC-sand 143'. Daily
downhole losses 13 bbls. Total lost on production interval 395 bbls.
5/29/2023 Cont. to test BOPE 250/3000 psi on 3-1/2" and 4-1/2" test joints. AOGCC right to witness waived by Austin McLeod. Finish changing out upper IBOP and test -
good. Rig down testing equipment. Rig down test joint. Pull test plug. Install wear bushing. Finish install IBOP - install Tq ring bolts, bell guide. Wire tire all bolts.
Install secondary wires and cotter pins. Grease upper IBOP. Change out washpipe. M/U 6-1/8" RSS drilling BHA: NOV bit, Geo-Pilot, RIH from derrick with ADR,
ILS, DM, GM, PWD, ILS. Pick up NM flex collars. Upload MWD. RIH with HWDP and Jars to 405'. P/U 46K, S/O 45K. Calc displacement 11.6 bbls, actual 8.1 bbls.
RIH with 4" drill pipe from 405' to 12,412'. Fill pipe and break in Geo-Pilot, shallow pulse test at 2800'. P/U 110K, S/O 57K. Calc displacement 177.2 bbls, Actual
159 bbls. CBU at 225 gpm, 1415 psi, ECD 10.92 ppg. P/U 118K, S/O 62K. Monitor well 10 minutes slight loss. Cut and slip drilling line. Check drawworks brakes.
Calibrate blocks. Monitor well on trip tank, static loss 1.4 bph. Service rig. Grease and inspect crown sheaves. Perform sheave wobble monthly EAM. Service and
inspect TD. Check gear oil. Pull trip nipple, install MPD bearing. RIH on elevators from 12,412' to 14370'. P/U 122K, S/O 48K. Observe 5-10K drag. Calculated
displacement 40 bbls, actual 24.8 bbls. Distance to wp06: 61.16', 60.97' high, 4.84' left. 68 concretions have been drilled so far for a total of 319 (6.0% of the
lateral). 4 faults has been crossed so far. 14,610'. 16,402'. 16,455', 17,762'. Total footage in NB sand 4330', above NB sand 244', below NB sand 761', in the NC-
sand 143'. Daily downhole losses 22 bbls. Total lost on production interval 417 bbls.
5/30/2023 Cont. to RIH on elevators from 14,370' to 16,265'. P/U 144K, S/O 42K. Calculated disp 25 bbls, actual 22.3 bbls. Wash and ream in the hole from 16,256' to 18,150'
at 125 gpm, 1020 psi, ECD 12.0 ppg, max gas 520u, 30 rpms, 8-10Kft-lbs. P/U 148K, S/O 44K, ROT 83K. Sidetrack wellbore from 18,150' to 18,187' at 150-205
gpm, 1351 psi, WOB 2-7K, 80-120 rpms, 8-13Kft-lbs ECD 11.94 ppg with 9.05 ppg mud. P/U 136K, S/O N/A, ROT 73K. Observe losses at 18,182' with returns
falling from 90% to 10%. Pump 40ppg, 40 bbls LCM pill with no effect, and slow rate to 100 gpm. Cont. drilling 6-1/8" hole from 18,187' to 18534' (total 347' AROP
58 fph) at 160 gpm returns gradually increasing to 20%, 1266 psi, WOB 4-10K, 80-120 rpms, 8-15Kft-lbs. ECD 12.25 ppg, MW 9.05, mas gas 98u. P/U 141K, S/O
N/A, ROT 75K. Pumping (3) 40 bbls LCM pills. Run water at 70 bph, building mud and sweeps as able. Acquire drilling fluids from D142, D14 (via MP G&I). Note:
Spine road closed at 11:26am due to flooding. Cont. drilling 6-1/8" hole from 18,534' to 18598' (total 64' AROP 18 fph) at 160 gpm, 1520 psi, WOB 10-12K, 100
rpms, 13.5Kft-lbs. ECD 12.22 ppg, MW 8.9, mas gas 182u. P/U 140K, S/O N/A, ROT 75K. Backream 30' on connections. At 18,582' observe thick emulsified mud
coming back with returns increasing. from 22% to 113%. Increase pump rate to 225 gpm. Approximately 100 bbls of thick mud returned. CBU to ensure well bore
ballooning at 225 gpm (return flow 246 gpm), 1950 psi, 100 rpms, 8-10Kft-lbs, reciprocating pipe. ECD 12.22 ppg, max gas 1084. No significant change of returns
at bottoms up. Cont. drilling 6-1/8" hole from 18,598' to 18,620' (total 22' AROP 22 fph) at 225 gpm (return flow 231gpm), 2000 psi, WOB 8-10K, 100 rpms, 9.5Kft-
lbs. ECD 11.94 ppg, MW 8.9, mas gas 166u. P/U 148K, S/O N/A, ROT 75K. Backream 30' on connections. Observe well breathing on connection. Distance to
wp06:75.2', 73.48' high, 16.02' right. 70 concretions have been drilled so far, for a total footage of 328 (5.5% of the lateral). 4 faults (possibly 5) has been crossed so
far. 14,610'. 16,402'. 16,455', 17,762'. Total footage in NB sand 4933', above NB sand 318', below NB sand 761', in the NC-sand 143'. Daily downhole losses 1581
bbls. Total lost on production interval 1998 bbls.
5/31/2023 Cont. drilling 6-1/8" hole from 18,620' to 18,913' (total 293' AROP 49 fph) at 225 gpm, return flow 190 gpm, 1820 psi, WOB 1-6K, 120 rpms, 9Kft-lbs. ECD 11.81
ppg, MW 8.9, mas gas 769u. P/U 115K, S/O N/A, ROT 70K. Backream 30' on connections. Observe well breathing on connection. Cont. drilling 6-1/8" hole from
18,913' to 19,163' (total 250' AROP 42 fph) at 225 gpm, return flow 190 gpm, 1966 psi, WOB 1-6K, 120 rpms, 9-10Kft-lbs. ECD 11.91 ppg, MW 8.9, mas gas
956u. P/U 103K, S/O N/A, ROT 73K. Backream 30' on connections. Observe well breathing on connection. Cont. drilling 6-1/8" hole from 19,163' to 19,450' (total
287' AROP 48 fph) at 225 gpm, return flow 190 gpm, 1966 psi, WOB 1-6K, 120 rpms, 9-10Kft-lbs. ECD 12.0 ppg, MW 8.9, mas gas 1910u. P/U 103K, S/O N/A,
ROT 73K. Backream 30' on connections. Observe well breathing on connection. Re-acquired NB sands at 19,420' after faulting from NB to Ungu MF at 18,523' with
80' throw DTN. Cont. drilling 6-1/8" hole from 19,450' to final TD at 19,830' (total 380' AROP 63 fph) at 225 gpm, return flow 186 gpm, 1950 psi, WOB 2-7K, 120
rpms, 10Kft-lbs. ECD 12.12 ppg, MW 8.9, mas gas 2701u. P/U 118K, S/O N/A, ROT 71K. Backream 30' on conn. Well breathing on connection. Obtain final
survey. Distance to wp06: 8.38', 8.2' high, 1.71' right. 78 concretions have been drilled so far for a total footage of 351 (4.8% of the lateral). 5 faults has been
crossed so far. 14,610'. 16,402'. 16,455', 17,762', 18,523'. 1 plug back 18,150 - 18420'. Total footage in NB sand 5517', above NB sand 961', below NB sand 761',
in the NC-sand 143'. Daily downhole losses 809 bbls. Total lost on production interval 2807 bbls.
6/1/2023 BROOH one stand from 19,830' to 19,797'. Pump tandem sweeps (25% increase, 40 bbls late). Circulate total of 4 x BU at 225 gpm, 1990 psi, ECD 12.07 ppg, 8.9
ppg MW, 100 rpms 8.5K-ftlbs. Rack back stand every bottoms up after sweep is out of hole. Ream to TD. Pump SAPP train 3x 40 bbls SAPP pill followed by
QuickDril and displace to 9.1 ppg QuickDril at 200 gpm (flow out 145 gpm), 70-100 rpms, 14Kft-lbs, Max gas 109u, ECD 11.8 ppg. BROOH from 19,830 to 19,040'
at 200 gpm, 1540 psi, return flow 163 gpm, 50-70 rpms, 10-14Kft-lbs, max gas 87u, ECD 11.85 ppg. P/U 136K, S/O N/A, ROT 77K. Dropped 1.9" OD drift.
Observe well breathing on connections. BROOH from 19,040 to 16,917' at 200 gpm, 1332 psi, return flow 155 gpm, 100 rpms, 10-14Kft-lbs, max gas 96u, ECD
11.54 ppg. P/U 126K, S/O N/A, ROT 79K. Observe well breathing on connections. Cont. BROOH from 16,917 to 14,244' at 215 gpm, 1300 psi, return flow 180
gpm, 100 rpms, 13-14Kft-lbs, max gas 98u, ECD 11.01 ppg. P/U 136K, S/O 40K, ROT 76K. Observe well breathing on connections. at 18,120' trip back in hole to
18,220' and obtain survey to ensure in new hole - good. Distance to wp06 (Projected at TD): 6.64', 6.05' high, 2.72' right. 78 concretions have been drilled so far for
a total footage of 351 (4.8% of the lateral). 5 faults has been crossed so far. 14,610'. 16,402'. 16,455', 17,762', 18,523'. 1 plug back 18,150 - 18420'. 5 faults has
been crossed so far. 14,610'. 16,402'. 16,455', 17,762', 18,523'. 1 plug back 18,150 - 18420'. Daily downhole losses 224 bbls. Total lost on production interval
3031 bbls.
6/2/2023 Cont. BROOH F/14244' - T/ 12539' MD. 215/185 gpm In/Out, 1255 psi, 100 rpm, 13-14Kft-lbs tq, max gas 27u, ECD 10.9 ppg. P/U 128K, S/O 44K, ROT 77K.
Observe very slight breathing @ connections. Reduced RPMs to 40 @ 12897' MD. Pull clean into shoe. Circulate and condition mud (Rot/Recip) F/ 12539' - T/
12475' MD 2.5x btms up. 225 gpm in/out (full returns), 1360 psi, 10.9 ECD's, Max gas 27u, 80 rpm, 10k ft-lbs tq. P/U 128k, S/O 44k, Rot 77k. Pump tandem sweep
lo/hi. Back on time with 20% increase in cuttings. Obtain passing PST (250u). Monitor well (static). PJSM, Drain stack. Pull RCD bearing. Install trip nipple and
tighten graylock. Attempt to pull out of hole on elevators (swabbing). Pump out of hole F/ 12475' - T/ 9757' MD at 200 gpm, 825 psi, P/U 128K, S/O 60K. Cont. to
Pump out of hole F/ 9757' - T/ 6404' MD. at 200 gpm, 825 psi. P/U 101K, S/O 54K. Attempt to pull on elevators at 8580', 8000', and 7463', continues to swab. Cacl
disp 17.5 bbls, actual 28.9 bbls. Cont. to Pump out of hole F/ 6404' - T/ 4070' MD. at 125 gpm, 325 psi. P/U 66K, S/O 54K. Attempt to pull on elevators at 6390' and
4630', continues to swab. POOH on elevators from 4,070' to 3121' racking back drill pipe - no swabbing overserved. Cacl disp 20 bbls, actual 25 bbls. Pump
corrosion inhibited dry job. POOH laying down drill pipe from 3121' to 1099'. P/U 53, S/O 52. 5 faults has been crossed so far. 14,610'. 16,402'. 16,455', 17,762',
18,523'. 1 plug back 18,150 - 18420'. Daily downhole losses 14 bbls. Total lost on production interval 3045' bbls.
6/3/2023 Continue POOH laying down drill pipe F/ 1099' - T/ 404' (BHA). Monitor well (static0. L/D HWDP, jars and NM flex DC (retrieve 1.9" drift from float sub). Read
MWD. L/D MWD/LWD, Geo Pilot. Bit graded 1,1,WT,A,X,I,NO,TD. 3 bbl loss for trip on elevators. RIH w/ excess 4" dp out of derrick T/ 3474' MD. Monitor well
(static). Pull out of hole laying down 4" dp F/ 3474' to surface. P/U 66k, S/O 60k. Calc disp for trip. Clean and clear rig floor. Demobilize BHA components from floor.
Clear shed and prep for liner run. Mob casing equipment to rig lfoor and rig up same. Double stack pwr tongs, handling equipment and verify ID's, OD's. M/U safety
joint w/ XO. M/U solid AL eccentric 3-1/2" shoe jt. Run 3-1/2" JFE Bear, 9.2#, L-80, 250u screens w/ 1x 5-3/4" OD cent mid joint of screen jt. 3870 M/U tq. RIH T/
580' MD. P/U 39k, S/O 38k. Cont. to RIH from 580' to 5218' with 3-1/2" JFE Bear, 9.2#, L-80, 250u screens w/ 1x 5-3/4" OD cent mid joint of screen jt. 3870 M/U tq.
P/U 64K, S/O 49K. Calculated displacement 14.3 bbls, actual 13.3 bbls. Cont to RIH from 5218' with 3-1/2" JFE Bear, 9.2#, L-80, 250 screens. M/U ZXPN liner top
hanger/packer to 7442'. Mix and pour Pal mix. P/U 76K, S/O 52K. Change out pipe handling equipment. Cont. to RIH with 3-1/2" JFE Bear 250 screens conveyed
on drill pipe from 7442' to 10,430'. P/U 101K, S/O 55K. Pump through first stand drill pipe to ensure clear at 125 gpm, 170 psi. Daily downhole losses 13.5 bbls.
Total lost on production interval 3058.5 bbls.
6/4/2023 Cont. to RIH with 3-1/2" 250 screen lower completion from 10,430' to 16,795', conveyed on DP out of derrick. RIH with lower completion from 16,795' to 18,153'
picking up HWDP. P/U 166K, S/O39K. Calc. disp 62 bbls, actual 59.6 bbls. Cont. to RIH with lower completion on HWDP from 18,153' to 19,402' working pipe,
observing buckling. P/U 191K, S/O N/A. Cont. to RIH with lower completion on HWDP from 19,402' to 19,830' working pipe, observing buckling. P/U 193K, S/O
N/A. Drop 1-1/8 phenolic ball, pump down at 3bpm, 600 psi. Slow rate to 2bpm with 11 bbls to go. Observe ball on seat at 105 bbls. Pressure up to 2100 psi. Slack
off and set down. Cont to pressure up to 3500 psi to set liner hanger and release. Pick up to 190K, no indication hanger set. Set down and pressure up to 3700 psi.
Pick up to 200K indicating liner hanger set, but LRT not released. Work pipe 190K to 25K multiple times. Bleed off pressure, work pipe once and observe free at
154K up weight. Pressure up to 4422 psi and observe ball seat shear. Pick up and expose dog sub. Set down on liner top with 15k, Pick up and rotate 10 rpms
setting down 40K, repeat process with 5 rpms with indication packer set. PT liner top packer to 1500 psi for 10 minutes good. Clean and clear rig floor. Blow down
choke and kill lines. Monitor well, static. Service rig: top drive, grease blocks, crown. Service skate and iron roughneck. Replace dies in iron roughneck. POOH
laying down HWDP from 12,395' to 11803'. P/U 154K, S/O 73K. Pump dry job. Cont. POOH with LRT from 11,803' to 11,191'. Observe swabbing with a 9 bbl hole
fill discrepancy. Monitor well, static. Pump out of hole from 11,191' to 10,762'. P/U 143K S/O 66K. RIH out of derrick from 11,191' to 12,325'. P/U 146K, S/O 57K.
Circulate bottoms up at 268 gpm, 1000 psi. Max gas 28u. Monitor well, static. Reciprocate stand, still swabbing. Pump out of hole laying down drill pipe from
12,325' to 12,010'. 2 bpm, 280 psi. P/U 146K, S/O 57K Calculated displacement 1.8 bbls, actual 3.8 bbls. Daily downhole losses 7.3 bbls. Total lost on production
interval 3065.8 bbls.
PT liner top packer to 1500 psi for 10 minutes good
Activity Date Ops Summary
6/5/2023 Cont. to Pump out of hole with liner running tool from 12,010 to 9,273 at 2 bpm, 280 psi. Laying down DP and HWDP. Check for swabbing every 1000'. P/U 124K,
S/O 54K. Calc disp 20 bbls, actual 28 bbls.Cont. to Pump out of hole with liner running tool from 9,273 to 6,828 at 2 bpm, 183 psi. Laying down DP. Check for
swabbing every 1000'. P/U 121K, S/O 64K.Cont. to Pump out of hole with liner running tool from 6,828 to 5406 at 2 bpm, 96 psi. Laying down DP. Check for
swabbing every 1000'. P/U 88K, S/O 48K. Calc disp 21.6 bbls, actual 34 bbls.Cont. to Pump out of hole with liner running tool from 5406 to 4010 at 2 bpm, 96 psi.
Laying down DP. Check for swabbing every 1000'.Cont. to POOH on elevators laying down drill pipe from 4010' to 1817', no swabbing observed. P/U 54K S/O
51K. Calc disp 18 bbls, actual 22 bbls.Daily downhole losses 28 bbls. Total lost on production interval 3094 bbls.
6/6/2023 Cont. to POOH on elevators laying down 4" drill pipe F/ 1817' - T/ surface. Laydown LRT. LRT showed 44k tattletale shifted indicating good set on liner packer
assy. 11 bbl loss for trip out. Clean and clear rig floor.Trip in hole open ended w/ 48 stands 4" dp out of derrick T/ 3059' MD. Calc displacement. P/U 62k, S/O
52k.PJSM, Hang blocks. Cut and slip 69' drilling line. Inspect brake linkage (good). Calibrate crown and floor saver. 1 BPH static loss rate.POOH laying down all
4" dp F/ 3059' - T/ surface. Hole took proper displacement. Clean and clear rig floor. P/U 37k, S/O 36k.Pull wear bushing. Break and laydown 4" safety joint.
Stage 4.5" upper completion jewelry in shed and place in order. 300 total 4.5" jts in shed. Mob 4.5" casing equipment to floor. R/U 150T side doors, double stack
pwr tongs, air slips and safety collar. M/U FOSV w/ XO.PJSM RIH 4.5" 12.6# L-80 JFEBear completion. M/U Mule Shoe & install X Nipple W/ RHC-M (3.813"), 7" X
4.5" Baker S-3 Production Packer, X Nipple 3.813" bore and GLM's as per tally to 4,879' MD P/UI 64k SLK 50k. Trq Turn to 5.4k. Lost 3.9 bbls. Lost Replaced Jnt
93 & 94. Run speed 50 fpm.PJSM Cont RIH 4.5" 12.6# L-80 JFEBear completion as per tally F/ 4,879' to 9,299' MD P/UI 86k SLK 51k. Trq Turn to 5.4k. Lost 5
bbls. Run speed 50 fpm. Daily losses production: 11 bbls, total 3,105 bbls.
6/7/2023 Continue RIH w/4.5" JFE Bear L-80 Upper Completions F/9,299 - T/12,389.16' Tagging TOL (3' High). Tagged TOL 2-3x w/2-3k down and rotating pipe to have
WLEG lip progress past the TOL - No Go. Decision was made to not pursue any further.Laid down tag joint #293 along with #292, bringing the WLEG set depth to
12,358.48', WLEG is 30.68' off of the TOL. P/U=104K, S/O=56K,Make up the 4.5" Hanger to Joint #291 and land Hanger. RILDS. Shut the Annular and pressure
up T/1000 psi for 5 mins ensuring a good seal on hanger - Good. Hanger sitting with 21K string weight.L/D Hanger Landing joint. Wellhead Rep set BPV.R/D
Parker Wellbore Casing Equipment. Remove Airslips and 4.5" Elevators and hand slips. Clean and Clear Rig Floor.PJSM - N/D BOPE. Flush all surface equipment
and blow down same. Flush Stack and both pumps. Drain Stack, pull bushings and pull riser. Remove MPD Cap and Head. Bleed down koomey and R/D koomey
lines. Break bolts on stack. SIMOPS: Remove Mud from Pits and Clean/Flush.PJSM Install lift cap on Tree. P/U clean ring groove as per Vault rep onsite. Install
Tree and Trq nuts as per Vault rep. Test void 500 psi 5 min, 5000 psi 10 min, good. R/U test Equip and test Tree 500 psi 5 min, 5000 psi 10 min, good. SIMOPS
Build 100 bbls 9.0 ppg Brine.PJSM R/U Circ Equip and lines F/ 4.5" Tubing to IA 7" X 4.5" taking returns to cutting box. LRS on location 21:30. SS clean cellar box.
Spot and R/U LRS. SIMOPS clean pits. Daily losses production: 7 bbls, total 3,112 bbls.
6/8/2023 PJSM Displace well W/ FP & 8.9 corrosion inhibited brine. LRS pump down tubing 56 bbls 75 deg Diesel at 2 bpm ICP 415 psi FCP 544 psi. Shut down release
LRS. Use MP #2 pump 288 bbls 8.9 ppg Corrosion Inhibited Brine at 2 bpm ICP 534 psi FCP 83 psi. No losses.PJSM Bleed down tubing pressure. Remove 7" Otis
and HP lines. Drop Roller and 1,875" OD ball witnessed by Baker rep onsite. R/U 7" Otis HP line and test Equip.PJSM Flood lines. Set Baker S-3 Packer and MIT-
T. Pressured up to set packer and hold 3,600 psi using MP#2 1/2 bpm. Initial pressure 3,600 psi lost 43 psi in 15 min, 24 psi second 15 min, fail. Suspected ball
seat. Pumped at 3/4 bpm to 3,700 psi lost 37 psi 15 min, 16 psi second 15 min. Held for additional 10 min 7 psi lost on chart. Pumped 2.5 bbl bled 2.4 bbls.Started
to perform CMIT T-IA pressure up to 3,650 (Chart) psi. Lost 50psi first 15 minutes, lost 19psi last 15 minutes. Pumped 4.6bbls and bled back 4.6bbls. Blow down
and rig down lines. Tubing=0psi, 7"x4.5" IA=0psi. 9-5/8"x7" OA=108psi. RDMO. Rig released at 06:00.
50-029-23751-00-00API #:
Well Name:
Field:
County/State:
PBW L-292
Prudhoe Bay West
Hilcorp Energy Company Composite Report
, Alaska
Started
to perform CMIT T-IA pressure up to 3,650 (Chart) psi.
TD Shoe Depth: PBTD:
No. Jts. Returned
RKB RKB to BHF RKB to THF
Jts.
2
1
85
35
X Yes No X Yes No
Fluid Description:
Liner hanger Info (Make/Model): Liner top Packer?: Yes No
Liner hanger test pressure:X Yes No
Centralizer Placement:
Preflush (Spacer)
Type: Density (ppg) Volume pumped (BBLs)
Lead Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Tail Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Post Flush (Spacer)
Type: Density (ppg) Rate (bpm): Volume:
Displacement:
Type: Density (ppg) Rate (bpm): Volume (actual / calculated):
FCP (psi): Pump used for disp:X Yes No
Casing Rotated?X Yes No Reciprocated?X Yes No % Returns during job
Cement returns to surface?X Yes No Spacer returns ?X Yes No Vol to Surf:
Cement In Place At: Date: Estimated TOC:
Method Used To Determine TOC:
Preflush (Spacer)
Type: Density (ppg) Volume pumped (BBLs)
Lead Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Tail Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Post Flush (Spacer)
Type: Density (ppg) Rate (bpm): Volume:
Displacement:
Type: Density (ppg) Rate (bpm): Volume (actual / calculated):
FCP (psi): Pump used for disp:X Yes No
Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job
Cement returns to surface?X Yes No Spacer returns ?X Yes No Vol to Surf:
Cement In Place At: Date: Estimated TOC:
Method Used To Determine TOC:
Post Job Calculations:
Calculated Cmt Vol @ 0% excess: Total Volume cmt Pumped:
Cmt returned to surface: Calculated cement left in wellbore:
OH volume Calculated: OH volume actual: Actual % Washout:
Casing (Or Liner) Detail
Shoe
Cut Joint
10 40.0 L-80
582.3 1.6361.6
SE
C
O
N
D
S
T
A
G
E
Rig
23:12
Returns to Surface
Rotate Csg Recip Csg Ft. Min. PPG9.5
Shoe @ 6590.69 FC @ Top of Liner6,504.82
Floats Held
400.3 816
195 621
ud Mud/Tuned spac
CASING RECORD
County State Alaska Supv.S Barber / C Montague
Hilcorp Energy Company
CASING & CEMENTING REPORT
Lease & Well No.PBW L-292 Date Run 5-May-23
Setting Depths
Component Size Wt. Grade THD Make Length Bottom Top
TXP OSP 1.78 6,590.69 6,588.91
11.32 36.45 25.139 5/8 47.0 L-80 TXP Tenaris
Csg Wt. On Hook:222,000 Type Float Collar:Conventional No. Hrs to Run:26
9.6 3
1600
10
10.7 490 4.5
95
625
Bump Plug?
FI
R
S
T
S
T
A
G
E
10Tuned Spacer 53
15.8
608
3
9.6 3 201/195
471.4/462.5
1250
1
Rig/HES
15.8 80
Bump press
Returns
Bump Plug?
Yes
8:53 5/7/2023 2,938
2938.93
6,590.696,600.00
CEMENTING REPORT
Csg Wt. On Slips:50,000
Spud Mud
Tuned Spacer
964 2.85
Stage Collar @
56
Bump press
100
195
ES Cementer Closure OK
5208.34
56
12 190
Water
26.50 RKB to CHF
Type of Shoe:Bullnose Casing Crew:Parker
No. Jts. Delivered No. Jts. Run
Length Measurements W/O
Threads
Ftg. Delivered Ftg. Run Ftg. Returned
Ftg. Cut Jt. Ftg. Balance
www.wellez.net WellEz Information Management LLC ver_04818br
5208.34Water
3.9
Type I/II
Type
(2) on Jnt 1, (1) every joint to joint 25, (1) every other joint to joint 49, (1) 5 joints before/after ES cementer (joint #84-
104). (1) every third joint to joint 164
Casing 9 5/8 40.0 L-80 TXP Tenaris 82.70 6,588.91 6,506.21
Float 10 40.0 L-80 TXP OSP 1.39 6,506.21 6,504.82
Casing 9 5/8 40.0 L-80 TXP Tenaris/USS 41.38 6,504.82 6,463.44
Baffle Adapter 10 40.0 L-80 TXP HES 1.44 6,463.44 6,464.00
Casing 9 5/8 40.0 L-80 TXP Tenaris 3,500.63 6,464.00 2,961.37
Casing Pup Joint 9 5/8 40.0 L-80 TXP Tenaris 19.61 2,961.37 2,941.76
ES Cementer 10 40.0 L-80 TXP HES 2.83 2,941.76 2,938.93
Casing Pup Joint 9 5/8 40.0 L-80 TXP Tenaris 18.67 2,938.93 2,920.26
Casing 9 5/8 47.0 L-80 TXP Tenaris 2,842.49 2,920.26 36.45
Type I/II 455 2.35
Type I/II 438 1.16
4.5
Type I/II 270 1.16
5/7/2023 Surface
Spud Mud
2,938
100
X
X
Surface
95
TD Shoe Depth: PBTD:
No. Jts. Returned
RKB RKB to BHF RKB to THF
Jts.
3
286
Yes X No Yes X No 7.76
Fluid Description:
Liner hanger Info (Make/Model): Liner top Packer?: Yes X No
Liner hanger test pressure:X Yes No
Centralizer Placement:
Preflush (Spacer)
Type: Density (ppg) Volume pumped (BBLs)
Lead Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Tail Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Post Flush (Spacer)
Type: Density (ppg) Rate (bpm): Volume:
Displacement:
Type: Density (ppg) Rate (bpm): Volume (actual / calculated):
FCP (psi): Pump used for disp:X Yes No
Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job
Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Surf:
Cement In Place At: Date: Estimated TOC:
Method Used To Determine TOC:
Post Job Calculations:
Calculated Cmt Vol @ 0% excess: Total Volume cmt Pumped:
Cmt returned to surface: Calculated cement left in wellbore:
OH volume Calculated: OH volume actual: Actual % Washout:
Casing (Or Liner) Detail
Shoe 7 5/8
9090
Rotate Csg Recip Csg Ft. Min. PPG9.5
Shoe @ 12585 FC @ Top of Liner12,454.00
Floats Held
40 90
090
6% KCL/ Polymer
CASING RECORD
County State Alaska Supv.S Barber / O Amend
Hilcorp Energy Company
CASING & CEMENTING REPORT
Lease & Well No.PBW L-292 Date Run 16-May-23
Setting Depths
Component Size Wt. Grade THD Make Length Bottom Top
BTC Summit 2.42 12,584.63 12,582.21
Csg Wt. On Hook:190,000 Type Float Collar:Standard No. Hrs to Run:27
9.45 5
99.9
940
FI
R
S
T
S
T
A
G
E
10Tuned Spacer 60
465.4/462.9
1445
0
MP 1
15.8 90
Bump press
Calculated
Bump Plug?
2:20 5/18/2023 8,599
12,584.6312,594.00
CEMENTING REPORT
Csg Wt. On Slips:23,000
6% KCL/ Polymer
26.50 RKB to CHF
Type of Shoe:Float Shoe Casing Crew:Parker Wellbore
No. Jts. Delivered 324 No. Jts. Run 290 34
Length Measurements W/O Threads
Ftg. Delivered 13,932.00 Ftg. Run 12,470.00 Ftg. Returned 1,462.00
Ftg. Cut Jt. Ftg. Balance
www.wellez.net WellEz Information Management LLC ver_04818br
3.4
Bow Spring Centralizer 2 EA 4 SR on shoe jnt. 1 ea W/ 2 SR next 2 jnts. FC Jnt 1 ea Bow Spring and 2 SR. F/ Jnr 5 to
32 1 ea Solid Body, one every other jnt F/ 34 to 60. Total 47 centralizers 10 Stop Rings.
7" Csg 7 26.0 L-80 BTC 126.77 12,582.21 12,455.44
FC 6 5/8 BTC Summit 1.37 12,455.44 12,454.07
7" Csg 7 26.0 L-80 BTC 42.26 12,454.07 12,411.81
X/O Vam/BTC 7 26.0 L-80 VAM 32.07 12,411.81 12,379.74
7" Csg 7 29.0 L-80 VAM 12,345.50 12,379.74 34.24
Pup 7 29.0 L-80 VAM 9.11 34.24 25.13
Hanger 8 3/4 0.91 25.13 24.22
RKB 24.22
HalCem Type I/II 438 1.16
99.9
X
8,599
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________PRUDHOE BAY UN ORIN L-292
JBR 06/01/2023
MISC. INSPECTIONS:
FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK:
ACCUMULATOR SYSTEM:MUD SYSTEM:
P/F P/F
P/FP/FP/F
Visual Alarm
QuantityQuantity
Time/Pressure
SizeQuantity
Number of Failures:5
5"&7" joints. Bag on both. Lower kelly replaced for a pass. Dart cycled for a pass. CMVs 1, 2 & 3 cycled for a pass.
Test Results
TEST DATA
Rig Rep:Vanhoose/SerafineOperator:Hilcorp North Slope, LLC Operator Rep:Barber/Montague
Rig Owner/Rig No.:Hilcorp Innovation PTD#:2230250 DATE:5/9/2023
Type Operation:DRILL Annular:
250/3000Type Test:INIT
Valves:
250/3000
Rams:
250/3000
Test Pressures:Inspection No:bopSAM230509171426
Inspector Austin McLeod
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 7
MASP:
1382
Sundry No:
Control System Response Time (sec)
Time P/F
Housekeeping:P
PTD On Location P
Standing Order Posted P
Well Sign P
Hazard Sec.P
Test Fluid W
Misc NA
Upper Kelly 1 P
Lower Kelly 1 FP
Ball Type 1 P
Inside BOP 1 FP
FSV Misc 0 NA
15 FPNo. Valves
1 PManual Chokes
1 PHydraulic Chokes
0 NACH Misc
Stripper 0 NA
Annular Preventer 1 13-5/8"P
#1 Rams 1 5"P
#2 Rams 1 Blinds P
#3 Rams 1 7"P
#4 Rams 0 NA
#5 Rams 0 NA
#6 Rams 0 NA
Choke Ln. Valves 1 3-1/8"P
HCR Valves 2 3-1/8"P
Kill Line Valves 2 3-1/8"P
Check Valve 0 NA
BOP Misc 0 NA
System Pressure P3000
Pressure After Closure P1450
200 PSI Attained P24
Full Pressure Attained P100
Blind Switch Covers:PAll stations
Bottle precharge P
Nitgn Btls# &psi (avg)P6@2350
ACC Misc NA0
P PTrip Tank
P PPit Level Indicators
P PFlow Indicator
P PMeth Gas Detector
P PH2S Gas Detector
NA NAMS Misc
Inside Reel Valves 0 NA
Annular Preventer P11
#1 Rams P9
#2 Rams P9
#3 Rams P9
#4 Rams NA0
#5 Rams NA0
#6 Rams NA0
HCR Choke P1
HCR Kill P1
9
9999
9
9
9
9
9
9
FP
FP
FP
Lower kelly Bag CMVs 1, 2 & 3
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
Monty M. Myers
Drilling Manager
Hilcorp Alaska, LLC
3800 Centerpoint Dr., Suite 1400
Anchorage, AK, 99503
Re: Prudhoe Bay, Schrader Bluff, PBU L-292
Hilcorp Alaska, LLC
Permit to Drill Number: 223-025
Surface Location: 2460' FSL, 4126' FEL, Sec. 34, T12N, R11E, UM, AK
Bottomhole Location: 1891' FNL, 2077' FWL, Sec. 19, T12N, R11E, UM, AK
Dear Mr. Myers:
Enclosed is the approved application for the permit to drill the above referenced well.
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well
logs run must be submitted to the AOGCC within 90 days after completion, suspension, or
abandonment of this
well, or within 90 days of acquisition of the data, whichever occurs first.
This permit to drill does not exempt you from obtaining additional permits or an approval required
by law from other governmental agencies and does not authorize conducting drilling operations
until all other required permits and approvals have been issued. In addition, the AOGCC reserves
the right to withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska
Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply
with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code,
or an AOGCC order, or the terms and conditions of this permit may result in the revocation or
suspension of the permit.
Sincerely,
Brett W. Huber, Sr.
Chair, Commissioner
DATED this ___ day of April, 2023. 5
Brett W.
Huber, Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.04.05 12:02:08
-08'00'
GCW 04/04/23
04/05/2023Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr.
Date: 2023.04.05 12:02:41 -08'00'
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.
CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders.
From:Joseph Engel
To:Rixse, Melvin G (OGC); McLellan, Bryan J (OGC)
Subject:RE: [EXTERNAL] RE: PBU L-292 10-401 Permit to Drill (223-025) 7" x 9-5/8" Freeze protect
Date:Tuesday, April 4, 2023 2:01:15 PM
Attachments:image001.png
Thanks for the question, Bryan.
The previously sent OA freeze protect procedure is specific to 3 string Schrader Bluff wells. The planned 7” TOC is above all
significant hydrocarbon zones, the surface casing shoe is covering all gas hydrates, and we will wait until the cement has sufficient
strength before freeze protecting; the only formations open to freeze protect operations will be insignificant.
In order to ensure the annulus is sufficiently freeze protected to maintain well integrity, pump pressures may exceed FIT pressures.
Injection pressures will be established at ½ bpm, ensuring that the lowest pressure to bullhead fluid is used. Freeze protecting the
annulus is critical to well integrity, therefore there will be no pressure limitation with no significant hydrocarbon bearing zones open
on this well design.
On wells with deeper horizons open, FIT/LOT pressures will be taken into consideration during freeze protect operations.
Thank you for your time.
Joe
Joe Engel | Drilling Engineer | Hilcorp Alaska, LLC
3800 Centerpoint Dr., Ste. 1400 | Anchorage | AK | 99503
Office: 907.777.8395 | Cell: 805.235.6265
From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Sent: Tuesday, April 4, 2023 11:17 AM
To: Joseph Engel <jengel@hilcorp.com>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Subject: RE: [EXTERNAL] RE: PBU L-292 10-401 Permit to Drill (223-025) 7" x 9-5/8" Freeze protect
Joe,
The freeze protect procedure includes a rate limitation, but do you plan to impose any pressure limitations? The burst and collapse
limits are far above the pressure required to frac the shoe.
Thanks
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
333 W 7th Ave
Anchorage, AK 99501
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
From: Joseph Engel <jengel@hilcorp.com>
Sent: Friday, March 31, 2023 11:31 AM
To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Subject: RE: [EXTERNAL] RE: PBU L-292 10-401 Permit to Drill (223-025) 7" x 9-5/8" Freeze protect
Mel/Bryan –
Below is our procedure for freeze protecting the 9-5/8” x 7” OA on the Schrader Bluff well L-292. This should be appended after step
CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders.
16.23 of the program.
Please let me know if you have any questions. Thank you for your time.
Enjoy your time off, Mel.
Joe Engel | Drilling Engineer | Hilcorp Alaska, LLC
3800 Centerpoint Dr., Ste. 1400 | Anchorage | AK | 99503
Office: 907.777.8395 | Cell: 805.235.6265
From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Sent: Wednesday, March 29, 2023 5:04 PM
To: Joseph Engel <jengel@hilcorp.com>
Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Subject: [EXTERNAL] RE: PBU L-292 10-401 Permit to Drill (223-025) 7" x 9-5/8" Freeze protect
Joe,
Please forward your freeze protect procedure to Bryan McLellan. He can reference it and append it to the submitted PTD. I will be
out of office for the next 3 weeks.
Mel Rixse
Senior Petroleum Engineer (PE)
Alaska Oil and Gas Conservation Commission
907-793-1231 Office
907-297-8474 Cell
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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov).
cc. Bryan McLellan
From: Rixse, Melvin G (OGC)
Sent: Monday, March 27, 2023 10:23 AM
To: Joe Engel <jengel@hilcorp.com>
Subject: PBU L-292 10-401 Permit to Drill (223-025) 7" x 9-5/8" Freeze protect
Joe,
Since the CD1 gas release, it will become important to include the freeze protect procedure in the drilling program. Can you
write something up, email it to me so I can append to the drilling program?
Mel Rixse
Senior Petroleum Engineer (PE)
Alaska Oil and Gas Conservation Commission
907-793-1231 Office
907-297-8474 Cell
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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov).
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WELL PERMIT CHECKLISTCompanyHilcorp North Slope, LLCWell Name:PRUDHOE BAY UN ORIN L-292Initial Class/TypeDEV / PENDGeoArea890Unit11650On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2230250PRUDHOE BAY, SCHRADER BLUF OIL - 64013NA1 Permit fee attachedYes Surface Location lies within ADL0028239; Top Productive Interval lies in ADL0047449; TD lies in ADL0047446.2 Lease number appropriateYes3 Unique well name and numberYes PRUDHOE BAY, SCHRADER BLUFF OIL – 640135, governed by CO 505B.0044 Well located in a defined poolYes5 Well located proper distance from drilling unit boundaryYes6 Well located proper distance from other wellsYes7 Sufficient acreage available in drilling unitYes8 If deviated, is wellbore plat includedYes9 Operator only affected partyYes10 Operator has appropriate bond in forceYes11 Permit can be issued without conservation orderYes12 Permit can be issued without administrative approvalYes13 Can permit be approved before 15-day waitNA14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForNA15 All wells within 1/4 mile area of review identified (For service well only)NA16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes 20" 129.5# X-52 driven to 80'18 Conductor string providedYes 9-5/8" surface casing to SV1 shale interval19 Surface casing protects all known USDWsYes Fully cemented 9-5/8" casing20 CMT vol adequate to circulate on conductor & surf csgYes21 CMT vol adequate to tie-in long string to surf csgYes 7" cement to comply with zonal isoaltion. LWD logs to AOGCC to approve TOC22 CMT will cover all known productive horizonsYes 9-5/8" 47# L-80 from surface to BOPF, 9-5/8" 40# L-80 from BOPF to SV123 Casing designs adequate for C, T, B & permafrostYes Innovation rig has adequate tankage and good trucking support.24 Adequate tankage or reserve pitNA This is a grassroots well.25 If a re-drill, has a 10-403 for abandonment been approvedYes Halliburton collision scan identifies no close approaches.26 Adequate wellbore separation proposedYes 16" diverter below BOPE27 If diverter required, does it meet regulationsYes All fluids planned to be overbalance to pore pressure.28 Drilling fluid program schematic & equip list adequateYes 1 annular, 3 ram stack29 BOPEs, do they meet regulationYes 5M 13-5/8" stack pressure tested to 3000 psi.30 BOPE press rating appropriate; test to (put psig in comments)Yes31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownYes Monitoring will be required33 Is presence of H2S gas probableNA This is a development well.34 Mechanical condition of wells within AOR verified (For service well only)No H2S measures required: L-Pad wells are H2S bearing.35 Permit can be issued w/o hydrogen sulfide measuresYes Reservoir pressure gradient expected to be normal (0.44 psi/ft, 8.46 ppg EMW). Some potential36 Data presented on potential overpressure zonesNA for overpressure. MPD will be used to mitigate any abnormal pressure encountered.37 Seismic analysis of shallow gas zonesNA38 Seabed condition survey (if off-shore)NA39 Contact name/phone for weekly progress reports [exploratory only]ApprSFDDate3/24/2023ApprMGRDate3/26/2023ApprSFDDate3/24/2023AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateGCW 04/05/23
