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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.
From:Wallace, Chris D (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: UPDATE UNDER EVALUATION: Injector M-205 (PTD #2221270) AA submitted for anomalous IA re-
pressurization
Date:Sunday, November 10, 2024 3:56:19 PM
From: Wallace, Chris D (OGC)
Sent: Sunday, November 10, 2024 3:52 PM
To: 'PB Wells Integrity' <PBWellsIntegrity@hilcorp.com>
Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Regg, James B (OGC) <jim.regg@alaska.gov>;
Torin Roschinger <Torin.Roschinger@hilcorp.com>
Subject: RE: UPDATE UNDER EVALUATION: Injector M-205 (PTD #2221270) AA submitted for
anomalous IA re-pressurization
Ryan,
You are approved to keep the well on injection while we process the AA.
Thanks and Regards,
Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907)
793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska
Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended
recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure
of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please
delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you,
contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov.
From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>
Sent: Saturday, November 9, 2024 3:32 PM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Regg, James B (OGC) <jim.regg@alaska.gov>;
Torin Roschinger <Torin.Roschinger@hilcorp.com>
Subject: UPDATE UNDER EVALUATION: Injector M-205 (PTD #2221270) AA submitted for anomalous
IA re-pressurization
Mr. Wallace,
Injector M-205 (PTD #2221270) AA application for continued operation was submitted to AOGCC on
11/04. The current approved 28 day period expires on 11/13. With permission, we would like to
keep the well on injection as long as needed to process the AA request.
Please call with any questions or concerns.
Ryan Holt
Hilcorp Alaska LLC
Field Well Integrity / Compliance
Ryan.Holt@Hilcorp.com
P: (907) 659-5102
M: (907) 232-1005
From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>
Sent: Wednesday, October 16, 2024 9:55 AM
To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Aras Worthington
<Aras.Worthington@hilcorp.com>; Michael Hibbert <Michael.Hibbert@hilcorp.com>; PB EOC
Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers
<PBWellsOptimizationEngineers@hilcorp.com>; PBW GC2 Field Lead Operator
<PBWGC2FieldLeadOperator@hilcorp.com>; PBW GC2 Foreman <PBWGC2Foreman@hilcorp.com>;
PBW GC2 Wellpad HUQ <PBWGC2WellpadHUQ@hilcorp.com>; PBW GC2 Wellpad LV
<PBWGC2WellpadLV@hilcorp.com>; PBW GC2 Wellpad MN <PBWGC2WellpadMN@hilcorp.com>;
PBW GC2 Wellpad RJ <PBWGC2WellpadRJ@hilcorp.com>; PBW GC2 Wellpad S
<PBWGC2WellpadS@hilcorp.com>; PBW GC2 Wellpad W <PBWGC2WellpadW@hilcorp.com>; PBW
GC2 Wellpad Z <PBWGC2WellpadZ@hilcorp.com>; PBW GC2 West Field Lead Operator
<PBWGC2WestFieldLeadOperator@hilcorp.com>; PBW PCC Leads
<GC3ProdContCenterLeads@hilcorp.com>; Tyson Shriver <Tyson.Shriver@hilcorp.com>
Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie
Janowski <Carrie.Janowski@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Torin
Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>
Subject: UPDATE UNDER EVALUATION: Injector M-205 (PTD #2221270) anomalous IA re-
pressurization
All,
AOGCC has approved an additional 28-days of monitoring on Injector M-205 (PTD #2221270) to
evaluate for anomalous TxIA communication post extended packing DGLV set on 10/7/24. The under
evaluation clock has been reset.
Please respond with any questions.
Oliver Sternicki
Hilcorp Alaska, Hilcorp North Slope LLC
Well Integrity Supervisor
Office: (907) 564 4891
Cell: (907) 350 0759
Oliver.Sternicki@hilcorp.com
From: PB Wells Integrity
Sent: Wednesday, September 18, 2024 9:17 AM
To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Aras Worthington
<Aras.Worthington@hilcorp.com>; Michael Hibbert <Michael.Hibbert@hilcorp.com>; PB EOC
Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers
<PBWellsOptimizationEngineers@hilcorp.com>; PBW GC2 Field Lead Operator
<PBWGC2FieldLeadOperator@hilcorp.com>; PBW GC2 Foreman <PBWGC2Foreman@hilcorp.com>;
PBW GC2 Wellpad HUQ <PBWGC2WellpadHUQ@hilcorp.com>; PBW GC2 Wellpad LV
<PBWGC2WellpadLV@hilcorp.com>; PBW GC2 Wellpad MN <PBWGC2WellpadMN@hilcorp.com>;
PBW GC2 Wellpad RJ <PBWGC2WellpadRJ@hilcorp.com>; PBW GC2 Wellpad S
<PBWGC2WellpadS@hilcorp.com>; PBW GC2 Wellpad W <PBWGC2WellpadW@hilcorp.com>; PBW
GC2 Wellpad Z <PBWGC2WellpadZ@hilcorp.com>; PBW GC2 West Field Lead Operator
<PBWGC2WestFieldLeadOperator@hilcorp.com>; PBW PCC Leads
<GC3ProdContCenterLeads@hilcorp.com>; Tyson Shriver <Tyson.Shriver@hilcorp.com>
Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie
Janowski <Carrie.Janowski@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Torin
Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>
Subject: UNDER EVALUATION: Injector M-205 (PTD #2221270) anomalous IA re-pressurization
All,
Injector M-205 (PTD #2221270) had an IA bleed while on MI service on 09/14/24 due to the IA
pressure climbing. The increase in IA pressure was initially thought to be caused by an increase in MI
rate, but continued IA repressurization and a subsequent IA bleed on 9/17/24 indicate potential slow
TxIA communication. No gas was bled from the annulus in either event. The well will now be
classified as UNDER EVALUATION and is on the 28-day clock for further diagnostics.
Plan Forward:
1. DHD: PPPOT-T
2. Fullbore: AOGCC witnessed MIT-IA
3. Well Integrity: Additional diagnostics as needed and potential AA application
Please respond with any questions.
Oliver Sternicki
Hilcorp Alaska, Hilcorp North Slope LLC
Well Integrity Supervisor
Office: (907) 564 4891
Cell: (907) 350 0759
Oliver.Sternicki@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.
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Thursday, October 17, 2024
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Adam Earl
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
Hilcorp North Slope, LLC
M-205
PRUDHOE BAY UN POL M-205
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 10/17/2024
M-205
50-029-23733-00-00
222-127-0
G
SPT
5176
2221270 1500
2023 2024 2024 2023
0 0 0 0
OTHER P
Adam Earl
9/25/2024
MIT-IA test under evaluation for potential leak, T X IA, test didn’t show it, passing test
30 MinPretestInitial15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:PRUDHOE BAY UN POL M-205
Inspection Date:
Tubing
OA
Packer Depth
1636 3796 3711 3699IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitAGE240925185302
BBL Pumped:1.5 BBL Returned:1.2
Thursday, October 17, 2024 Page 1 of 1
9
9
9
9
99
999
99
9 9
9
9
9
MIT-IA test under evaluation for potential leak
James B. Regg Digitally signed by James B. Regg
Date: 2024.10.17 11:21:35 -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.
From:Wallace, Chris D (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: UPDATE UNDER EVALUATION: Injector M-205 (PTD #2221270) anomalous IA re-pressurization
Date:Monday, October 14, 2024 10:39:40 AM
From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Sent: Monday, October 14, 2024 9:20 AM
To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>
Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>;
Oliver Sternicki <Oliver.Sternicki@hilcorp.com>
Subject: Re: UPDATE UNDER EVALUATION: Injector M-205 (PTD #2221270) anomalous IA re-
pressurization
Ryan,
An additional 28 days monitoring and diagnostics is approved.
Chris
From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>
Sent: Monday, October 14, 2024 8:59:21 AM
To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Wallace, Chris D (OGC)
<chris.wallace@alaska.gov>
Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger
<Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>
Subject: UPDATE UNDER EVALUATION: Injector M-205 (PTD #2221270) anomalous IA re-
pressurization
Mr. Wallace,
Injector M-205 (PTD #2221270) extending packing DGLV was set on 10/07. During the week monitor,
no obvious re-pressurization was observed. With permission, we would like to continue diagnostics
for another 28 day starting 10/16 when the initial 28 day period expires.
Please call with any questions or concerns.
Ryan Holt
Hilcorp Alaska LLC
Field Well Integrity / Compliance
Ryan.Holt@Hilcorp.com
P: (907) 659-5102
M: (907) 232-1005
7. Property Designation (Lease Number):
1. Operations
Performed:
2. Operator Name:
3. Address:
4. Well Class Before Work:5. Permit to Drill Number:
6. API Number:
8. Well Name and Number:
9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s):
Susp Well Insp
Install Whipstock
Mod Artificial Lift Perforate New Pool
Perforate
Plug Perforations
Coiled Tubing Ops
Other Stimulate
Fracture Stimulate
Alter Casing
Pull Tubing
Repair Well Other:
Change Approved Program
Operations shutdown
11. Present Well Condition Summary:
Casing Length Size MD TVD Burst Collapse
Exploratory
Stratigraphic
Development
Service
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
16. Well Status after work:
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
OIL GAS
WINJ WAG GINJ
WDSPL
GSTOR Suspended SPLUG
Authorized Name and
Digital Signature with Date:
Authorized Title:
Contact Name:
Contact Email:
Contact Phone:
PBU M-205
Commence MI Injection per AIO 25A.023
Hilcorp North Slope, LLC
3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503
222-127
50-029-23733-00-00
17871
Conductor
Surface
Intermediate Tiebac
Production
Liner
5360
80
7652
6551
11305
17827
20"
9-5/8"
7"
7" x 4-1/2"
5362
26 - 106
25 - 7677
24 - 6575
6566 - 17871
26 - 106
25 - 5341
24 - 5115
5111 - 5360
None
4760 / 3090
5410
7020 / 7500
None
6870 / 5750
7240
8160 / 8430
7683 - 17776
4-1/2" 12.6# L-80 22 - 6953
5342 - 5364
Structural
4-1/2" HES TNT Perm Packer
6722
5176
Torin Roschinger
Operations Manager
Tyson Shriver
tyson.shriver@hilcorp.com
907-564-4542
PRUDHOE BAY, POLARIS OIL
Total Depth
Effective Depth
measured
true vertical
feet
feet
feet
feet
measured
true vertical
measured
measured
feet
feet
feet
feet
measured
true vertical
Plugs
Junk
Packer
Measured depth
True Vertical depth
feet
feet
Perforation depth
Tubing (size, grade, measured and true vertical depth)
Packers and SSSV
(type, measured and true vertical depth)
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
13a.Representative Daily Average Production or Injection Data
Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure
Prior to well operation:
Subsequent to operation:
15. Well Class after work:
Exploratory Development Service StratigraphicDaily Report of Well Operations
Copies of Logs and Surveys Run
Electronic Fracture Stimulation Data
Sundry Number or N/A if C.O. Exempt:
ADL 0028257, 0028260
22 - 5249
N/A
N/A
4993
3286 425
0
1810
2367
N/A
13b. Pools active after work:POLARIS OIL
No SSSV Installed
6722, 5176
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
Sr Pet Eng: Sr Pet Geo:
Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
Sr Res Eng:
Due Within 30 days of Operations
By Grace Christianson at 10:00 am, Aug 21, 2024
Digitally signed by Torin
Roschinger (4662)
DN: cn=Torin Roschinger (4662)
Date: 2024.08.21 06:21:52 -
08'00'
Torin
Roschinger
(4662)
DSR-8/21/24
RBDMS JSB 082824
WCB 10-3-2024
From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>
Sent: Wednesday, September 18, 2024 9:17 AM
To: chris.wallace@alaska.gov
Cc: jim.regg <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells
Integrity <PBWellsIntegrity@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>
Subject: UNDER EVALUATION: Injector M-205 (PTD #2221270) anomalous IA re-pressurization
Mr. Wallace,
Injector M-205 (PTD #2221270) had an IA bleed while on MI service on 09/14/24 due to the IA
pressure climbing. The increase in IA pressure was initially thought to be caused by an increase in MI
rate, but continued IA repressurization and a subsequent IA bleed on 9/17/24 indicate potential slow
TxIA communication. No gas was bled from the annulus in either event. The well will now be
classified as UNDER EVALUATION and is on the 28-day clock for further diagnostics.
Plan Forward:
1. DHD: PPPOT-T
2. Fullbore: AOGCC witnessed MIT-IA
3. Well Integrity: Additional diagnostics as needed and potential AA application
Please respond with any questions.
Oliver Sternicki
Hilcorp Alaska, Hilcorp North Slope LLC
Well Integrity Supervisor
Office: (907) 564 4891
Cell: (907) 350 0759
Oliver.Sternicki@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 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 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 the content
is safe.
From:Wallace, Chris D (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: UNDER EVALUATION: Injector M-205 (PTD #2221270) anomalous IA re-pressurization
Date:Wednesday, September 18, 2024 10:27:09 AM
Attachments:M-205.pdf
M-205 TIO.docx
From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>
Sent: Wednesday, September 18, 2024 9:17 AM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>;
PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>
Subject: UNDER EVALUATION: Injector M-205 (PTD #2221270) anomalous IA re-pressurization
Mr. Wallace,
Injector M-205 (PTD #2221270) had an IA bleed while on MI service on 09/14/24 due to the IA
pressure climbing. The increase in IA pressure was initially thought to be caused by an increase in MI
rate, but continued IA repressurization and a subsequent IA bleed on 9/17/24 indicate potential slow
TxIA communication. No gas was bled from the annulus in either event. The well will now be
classified as UNDER EVALUATION and is on the 28-day clock for further diagnostics.
Plan Forward:
1. DHD: PPPOT-T
2. Fullbore: AOGCC witnessed MIT-IA
3. Well Integrity: Additional diagnostics as needed and potential AA application
Please respond with any questions.
Oliver Sternicki
Hilcorp Alaska, Hilcorp North Slope LLC
Well Integrity Supervisor
Office: (907) 564 4891
Cell: (907) 350 0759
Oliver.Sternicki@hilcorp.com
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 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.
TREE =
30- X 20- COND,
2155#, A-5
WELLHEAD =
ACTUATOR =
OKB. ELEV = 52.T
REF ELEV = 52.T
BF. ELEV = -27.Z
KOP =
Max Angle = 93° 17737'
DaI MD =
Datum TVD= '_m0'
9-5/8- CSG, 47#, TXP BTC D = 8.681' H 2067'
Minimum ID = 3.805" @ 5501' SLM
TBG RESTRICTION
7- TEBACK, 26#, L-BO BTC, .0383 bpf, ID = 6.276' J 657V
7- LNR, 26#, LAO HYD563, .0383 bpf, D = 6276' —t 683V -
4-12' TBG, 12.6#, L-80 VT, .0152 bpf, ID = 3.958' 6953' '
7' LNR, 29#, L-80 HYD563, .0371 bpf, D = 6.184' 7OW
9518' CSG, 40#, L-80 TXP BTC, ID = 8.835' 767T
OPEN HOLE PACKERS
REF LOG: ON / /
ANGLE ATTOP SCRPt_-
Note:
BASE
PIPE
SET OR
SIZE
DESCRIPTION
DEPTH
NOTSET
4-12"
WELLTEC MECH OH PKR
10002
12/0122
4-12"
WELLTEC MECH OH PKR
12279
12/0122
4-12"
WELLTEC MECH OH PKR
12729'
12/0122
4-12"
WELLTEC MECH OH PKR
1499Z
12/0122
PBTD
4-12' LNR, 12.6#, L-80 JFE BEAR,
.0152 bpf, D = 3.958'
M—L 0 SAFETY NOTES: WELL ANGLE > -700 @ 6763'.
20M--195M- HES CEMENTER
2526' 4-1W HESX NIP, 1)=3.813'
GAS LIFT MANDRELS
MD ITVDIDEVI TYPE IVLVILATCHIPORTI DATE
— 6566' �� 95/8'X 7'SLZXP LTP W/TEBACK
SLEEVE, ID = 6.180'
6650' 4-12' HES X NP, D = 3.813'
6722' 7- X 4-1/2- TNT PKR, D
6798' I 4-12' HES X NIP, D = 3.813'
�4-12'MULESHOE,9)=3.958'
7040' 7' X 4-12' XO, D = 3.958'
4-12" INNOVUS MULTICYCLE FRAC SLV. ID = 3.870"
NO
DEPTH
O/C
DATE
23
768T
O
12/0122
22
8011'
O
1210122
21
8514'
O
12/01/22
20
9013'
O
12/0122
19
9597
O
11/30/22
18
10319
O
11/3022
17
10616
O
11/3022
16
1098T
O
1113022
15
1139T
O
11/30/22
14
11808'
O
1113022
13
121W
O
1113022
12
12997
O
11/30/22
11
13288'
O
1113022
10
13699
O
1113022
9
13994'
O
11/30/22
8
14409
O
11130M
7
14819
O
11/3022
6
15294'
O
11130/22
5
15818'
O
11/30/22
4
1619V
O
11/3022
3
16686'
O
11130/22
2
17211'
O
11/30/22
1
17772'
O
11130/22
O=OPEN C=CLOSED
DATE
REV BY
COMMENTS
DATE
REV BY
COMMENTS
1111722
FRIG
INITIALWELLBORE
05/0224
JKCMMD
SET FLO THRU SUB&GAUGES
112122
JMD
UPDATED WBS
051=4
JWJMD
PULLED GAUGES 05/0924
112222
WR/JMD
FINALAPPROVAL
112822
JJWJMD
GLV C/O 11/1922
112922
JJWJMD
TBG RESTRICTION 1126/22
12/0122
JNUJMD
SHIFTED FRAC SLEEVES 11
PRUDHOE BAY UNIT
WELL: M-205
PERMIT No: 222-127
API No: 50-029-23733-00
T11 N, R12E, 3378' FSL & 605
Hiloolp North Slope, LLC
Nolan Vlahovich Hilcorp Alaska, LLC
Geo Tech 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: 07/19/2023
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20230719
Well API #PTD #Log Date Log
Company Log Type AOGCC
Eset#
PBU 07-20C 50029209020300 218036 6/8/2023 HALLIBURTON RBT
PBU 13-19 50029206900000 181180 6/8/232 HALLIBURTON WFL-RMT3D
PBU 18-29C 50029223160300 209055 6/13/2023 HALLIBURTON CAST-CBL
PBU L-213 50029233080000 206053 6/12/2023 HALLIBURTON IPROF
PBU M-205 50029237330000 222127 6/6/2023 HALLIBURTON IPROF
PBU S-17c 50029211480300 202007 5/29/2023 HALLIBURTON RBT
Please include current contact information if different from above.
T37859
T37860
T37861
T37862
T37863
T37864
PBU M-205 50029237330000 222127 6/6/2023 HALLIBURTON IPROF
Kayla
Junke
Digitally signed by
Kayla Junke
Date: 2023.07.19
13:22:09 -08'00'
Post Office Box 244027
Anchorage, AK 99524-4027
3800 Centerpoint Drive
Suite 1400
Anchorage, AK 99503
Phone: (907) 564-4891
01/12/2023
Mr. Mel Rixse
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 4Q 2022.
Dear Mr. Rixse,
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 the end of 4Q
2022. 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 Engineer
Hilcorp North Slope, LLC
By Samantha Carlisle at 3:53 pm, Jan 12, 2023
Digitally signed by Oliver Sternicki
(4525)
DN: cn=Oliver Sternicki (4525),
ou=Users
Date: 2023.01.12 14:52:49 -09'00'
Oliver Sternicki
(4525)
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Thursday, January 26, 2023
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Brian Bixby
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
Hilcorp North Slope, LLC
M-205
PRUDHOE BAY UN POL M-205
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 01/26/2023
M-205
50-029-23733-00-00
222-127-0
W
SPT
5176
2221270 1500
1335 1334 1335 1337
382 1724 1698 1696
INITAL P
Brian Bixby
12/17/2022
MIT-OA
30 MinPretestInitial15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:PRUDHOE BAY UN POL M-205
Inspection Date:
Tubing
OA
Packer Depth
506 816 814 813IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitBDB221217153203
BBL Pumped:1.3 BBL Returned:1.4
Thursday, January 26, 2023 Page 1 of 1
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Thursday, January 26, 2023
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Brian Bixby
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
Hilcorp North Slope, LLC
M-205
PRUDHOE BAY UN POL M-205
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 01/26/2023
M-205
50-029-23733-00-00
222-127-0
W
SPT
5176
2221270 1500
1330 1332 1331 1334
371 609 601 600
INITAL P
Brian Bixby
12/17/2022
MIT-IA
30 MinPretest Initial 15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:
PRUDHOE BAY UN POL M-205
Inspection Date:
Tubing
OA
Packer Depth
421 2143 2087 2087IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitBDB221217152925
BBL Pumped:0.9 BBL Returned:1
Thursday, January 26, 2023 Page 1 of 1
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: 12/05/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL :
PBU M-205
PTD: 222-127
API: 50-029-23733-00-00
FINAL LWD FORMATION EVALUATION LOGS (10/27/2022 to 11/11/2022)
x ROP, AGR, DGR, ABG, EWR-M5, ADR, Horizontal Presentation (2” & 5” MD/TVD Color Logs)
x Final Definitive Directional Survey
x Geosteering and EOW Report
SFTP Transfer – Main Folders:
PBU M-205 LWD Subfolders:
PBU M-205 Geosteering Subfolders:
By Meredith Guhl at 8:26 am, Dec 06, 2022
222-127
T37362
Meredith Guhl Digitally signed by Meredith Guhl
Date: 2022.12.06 08:36:18 -09'00'
7" x 4-12"26#/29#/12.6#
26
2022
By James Brooks at 9:24 am, Dec 05, 2022
Completed
11/17/2022
JSB
RBDMS JSB 120622
G
MGR05JUN2023 DSR-12/12/22
12.2.2022
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: 2022.12.02 12:41:28 -09'00'
Monty M
Myers
Variance approved in PTD to set LTP > 200' above the top
perforation. -mgr
CASING AND LEAK-OFF FRACTURE TESTS
Well Name:PBW M-205 Date:11/7/2022
Csg Size/Wt/Grade:9.625" 40/47# L-80 Supervisor:Lott/ Amend
Csg Setting Depth:7677 TMD 5343 TVD
Mud Weight:9.2 ppg LOT / FIT Press =778 psi
LOT / FIT =12.00 ppg Hole Depth =7707 md
Fluid Pumped=2.6 Bbls Volume Back =2.3 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
->056 ->0
->4164 ->5187
->8270 ->10 375
->12 367 ->15 487
->16 451 ->20 640
->20 511 ->30 900
->24 566 ->40 1180
->28 617 ->50 1456
->32 657 ->60 1750
->36 712 ->70 2020
->40 775 ->75 2143
-> ->80 2307
-> ->85 2481
-> ->92 2657
Enter Holding Enter Holding Enter Holding Enter Holding
Time Here Pressure Here Time Here Pressure Here
->0775 ->02657
->1722 ->12656
->2698 ->22655
->3683 ->32655
->4669 ->42655
->5658 ->52655
->6645 ->10 2653
->7635 ->15 2652
->8625 ->20 2651
->9613 ->25 2649
->10 603 ->30 2648
-> ->
-> ->
-> ->
0
4
8
12
16
20
24
28 32
36
40
5
10
15
20
30
40
50
60
70
75
80
85
92
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 102030405060708090100
Pr
e
s
s
u
r
e
(
p
s
i
)
Strokes (# of)
LOT / FIT DATA CASING TEST DATA
775
722698683669658645635625613603
265726562655265526552655 2653 2652 2651 2649 2648
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
10/25/2022 Stomp sub over M-205. Set rig matts for catwalk. Set sub outriggers. Turn and retract stomper. Spot catwalk to sub. Spot pipe shed in V Blocks and leave on jacks
W/ wheel chalks. Spot mud mod & gen mod. Remove jeeps and release NES at 21:45. PJSM Lay Herculite and spot cutting box. Spot break shack and enviro vac.
Hook up interconnects. Run H2O and steam around rig. Swap to Gen power @ 23:00. Shut in all rig move hydraulics. Safe out stairs, walkways and rooftops. PJSM
Work on rig acceptance. Berm cutting box. Scope up derrick and bridle down. Hang rig tongs. Start putting MP's together. PJSM Remove RCD head from stack.
Install speed head and diverter tee. Set down stack on Tee and tighten flanges. Install 2 sections of 16" diverter. Cont working on assembling mud pumps.
10/26/2022 N/U Diverter System, continue working on Rig Acceptance Check list, install Trip nipple flange and Trip Nipple with spare 16 & 20 boots, install chains and binders
on Stack, install Knife Valve, continue installing vent line sections. SIMOPS: Start welding new 4 wing on HP Mud Line in Pits, reassemble MP #2, dress shakers
with 120s, tighten speed head. Continue work on Rig Acceptance Check List. Continue installing vent line sections, tighten flange bolts on same. Secure Vent line
to Stands. TQ bolts on Tee and Diverter Adapter. Center up BOP. Take on Spud Mud to Pits. NES Welder continue welding HP Mud Line in Mezz. C/O Elevators to
5 Hyd. Funct Function test all Rig Floor equipment and Top Drive. P/U and Rack Back 5", NC-50, 19.5# Drill Pipe making up stands in Mouse hole. P/U 71 stands
(142 jnts) drift OD 3.125". SIMOPS Weld on HP mud line in mezz. Use 5 D.P. Perform Annular closure 10 sec, knife 5 sec. Test H2S 10-20 ppm, LEL 20-40%,
PVT high/ low level alarms. Checked PVT sensors and return flow. Koomey draw drown Initial System 3,000 PSI, after System 1,950 PSI, 200 PSI increase 19 Sec,
full charge 60 sec. Nitrogen 6 bottle average 2,350 PSI. Witnessed by AOGCC Austin McLeod. Cont P/U and rack back 5", NC-50, 19.5# DP. Total 116 stands
(232 jnts) Drift OD 3.125". P/U rack back 5" 49.5# NC50 HWDP & SLB Jar. 9 stands (18 Jnts) Drift OD 2.75". SIMOPS welder completed HP mud line in mezz and
test to 5,000 psi, good. Rig accepted at 21:30 PJSM Cut and slip drilling line, ACCTM 14,251. Cut 14 warps (87') 1,073 TM. 1,941 left on spool. PJSM Service rig.
Grease TD, Crown, Blocks, Spinners, PH8, and washpipe. PJSM Stage 12.25" bit, handling tools, X/O and prep floor for M/U BHA. Hold Pre Spud meeting with all
personnel. Discussed broaching, rig evacuation, muster areas, new pad lay out and emergency responses. PJSM P/U M/U 12.25" Kymera Bybrid Bit (TFA 0.782),
8" TerraForce 1.5 Motor and 8" X/O. PJSM M/U 5" HWDP to BHA. Flood all lines and test HP lines to 3,000 psi, good. Wash down at 126 gpm 105 psi tag at 107'
MD. Drill ahead 12.25" Surface F/ 107' to 226' MD. 350 gpm 325 psi, 30 rpm, Trq 1-1.5k, WOB 2-3k. Jetting flow line. Seeing heavy gravel at shakers. Encountered
~160 bph dynamic losses at 162' MD.P/U 43k SLK 43k ROT43k. CBU BROOH 1 stand F/ 226' to 166' MD 350 gpm 335 psi 30 rpm TRQ 1k Pull on elevators F/
166' to BHA. P/U 43k SLK 43k ROT 43k. Cont seeing heavy gravel at shalers and ~160 bph dynamic losses. Daily Disposal = 0 bbls G&I total = 0 bbls. Daily H2O
F/ Lake 2 = 0 total = 0 bbls. Daily Metal: 0 lbs Total 0. Daily DH losses = 0 bbls Total DH = 0 bbls.
10/27/2022 Continue M/U BHA: 8 GWD, 8 DM Collar, EWR-M5 Collar, 8 TM Collar, PU and Upload MWD as Per Sperry MWD, M/U 2x NM Flex Collars and HWDP. C/O 3X14
jets to 3X15 jets on the bit. Wash Down @ 3 bpm, 110 PSI from 161 to 226 MD, tag fill @ 223MD w/5K, P/U off Bottom and Start drilling from 226 to 370', GPM
350, PSI 575, RPM 30, TQ 1-2K, ECD 10.3, Max Gas N/A, Rot 58K, P/U 59K, SO 56K. KOP 529' MD start 3/100 build turn as per WP07. Slide/ Rot 12.25"
Surface Hole F/ 370' to 782' MD (781' TVD) Total 412 (AROP 68.6') 425 GPM, PSI on 990/ off 900, 30 RPM, TRQ on 1-2k, TRQ off 1.5k, F/O 55%, WOB 3-6k.
ECD 9.75. Max Gas 16u BGG 0u. P/U 71K, SLK 69K, ROT 70K. At 465' drag chain packed W/ heavy. ~160 bph losses healing up around ~409' Cont 3/100 build
turn. Jet and pump through bleeder as needed. Slide/ Rot 12.25" Surface Hole F/ 782' to 1,291' MD (1,285' TVD) Total 509 (AROP 84.8') 450 GPM, PSI on 1250/
off 1050, 30 RPM, TRQ on 2-4k, TRQ off 1.5k, F/O 55%, WOB 6-10k. ECD 10.03. Max Gas 23u BGG 0u. P/U 78K, SLK 76K, ROT 78K. Final Gyro survey at
1,124' MD 1,118' TVD. Back 60' at 972' MD. Cont 3/100 build turn. Jet and pump through bleeder as needed. Slide/ Rot 12.25" Surface Hole F/ 1,291' to 1,608' MD
(1,578' TVD) Total 317' (AROP 52.8') 450 GPM, PSI on 1297/ off 1069, 30 RPM, TRQ on 2-4k, TRQ off 2k, F/O 55%, WOB 5-9k. ECD 10.05. Max Gas 25u BGG
0u. P/U 89K, SLK 82K, ROT 85K. Cont 3/100 build turn. Jet and pump through bleeder as needed. AT ~1,178' MD falling behind on build needing 4 DLS and only
getting 1-2 DLS. Sliding 45-60' per stand. Adjusting parameters to increase build rates. Distance to WP07: 16.19', 13.95' Low, 8.21' Left. Daily Disposal = 909 bbls
G&I total = 909 bbls. Daily H2O F/ Lake 2 = 830 total = 1510 bbls. Daily Metal: 0 lbs Total 0. Daily DH losses = 463 bbls Total DH = 463 bbls.
10/28/2022 Slide/ Rot 12.25" Surface Hole F/ 1,608' to 2,053' MD (1,965' TVD) Total 445' (AROP 74.2') 450 GPM, PSI on 1293/ off 1103, 30 RPM, TRQ on 3-5k, TRQ off 3k,
F/O 55%, WOB 5-10k. ECD 10.17. Max Gas 25u BGG 0u. P/U 96K, SLK 82K, ROT 89K. Cont 3/100 build turn. Log base of Permafrost @ 1924 MD, 1860' TVD.
Slide/ Rot 12.25" Surface Hole F/ 2,053' to 2,622' MD (2,346' TVD) Total 569' (AROP 94.8') 500 GPM, PSI on 1530/ off 1460, 65 RPM, TRQ on 4-6k, TRQ off 4.5k,
F/O 55%, WOB 2-4k. ECD 10.67. Max Gas 22u BGG 0u. P/U 102K, SLK 80K, ROT 90K. Cont 3/100 build turn. Start Tangent @ 2239' MD. Back ream 60'. Slide/
Rot 12.25" Surface Hole F/ 2,622' to 3,227' MD (2,755' TVD) Total 605' (AROP 100.8') 475 GPM, PSI on 1500/ off 1380, 65 RPM, TRQ on 6-8k, TRQ off 4-6k, F/O
58%, WOB 4-7k. ECD 10.54. Max Gas 18u P/U 114K, SLK 85K, ROT 98K. Perform maintenance slides as needed for tangent. Back ream 60'. Slide/ Rot 12.25"
Surface Hole F/ 3,227' to 3,704' MD (3,108' TVD) Total 481' (AROP 80.2') 475 GPM, PSI on 1,556/ off 1402, 65 RPM, TRQ on 7-9.5k, TRQ off 7k, F/O 59%, WOB
5-10k. ECD 10.2. Max Gas 116u P/U 126K, SLK 91K, ROT 101K. Perform maintenance slides as needed for tangent. Back ream 60' Jetting flowline as needed.
Distance to WP07: 13.72', 12.23' High 6.21' Right. ROT Hrs: 8.55. SLD Hrs: 4.99. Daily Disposal = 1083 bbls G&I total = 1992 bbls. Daily H2O F/ Lake 2 = 980
total = 2490 bbls. Daily Metal: 0 lbs Total 0. Daily DH losses = 0 bbls Total DH = 463 bbls.
10/29/2022 Slide/ Rot 12.25" Surface Hole F/ 3,704' to 4,187' MD (3,467' TVD) Total 483' (AROP 80.5') 475 GPM, PSI on 1,661/ off 1423, 65 RPM, TRQ on 8-9.5k, TRQ off
7k, F/O 59%, WOB 7-13k. ECD 10.48. Max Gas 173u P/U 136K, SLK 95K, ROT 103K. Perform maintenance slides as needed for tangent. Back ream 60' Slide/
Rot 12.25" Surface Hole F/ 4,187' to 4,571' MD (3,746' TVD) Total 384' (AROP 64') 500 GPM, PSI on 1,950/ off 1,760 65 RPM, TRQ on 8-10k, TRQ off 8k, F/O
59%, WOB 6-12k. ECD 10.4. Max Gas 1526u P/U 140K, SLK 96K, ROT 114K. Perform maintenance slides as needed for tangent. Back ream 60' Slide/ Rot 12.25"
Surface Hole F/ 4,571' to 5,069' MD (4,065' TVD) Total 498' (AROP 83') 500 GPM, PSI on 1,904/ off 1,640 65 RPM, TRQ on 11-13.5k, TRQ off 8-11k, F/O 65%,
WOB 7-11k. ECD 10.24. Max Gas 951u BGG 280u. P/U 155K, SLK 97K, ROT 122K. Encountered oil at shakers at 4,654' MD. (SB OA Sand). Perform
maintenance slides as needed for tangent. Back ream 60' Slide/ Rot 12.25" Surface Hole F/ 5,069' to 5,419' MD (4,351' TVD) Total 350' (AROP 58.') 500 GPM, PSI
on 1,913/ off 1,807 65 RPM, TRQ on 11-14k, TRQ off 12-13k, F/O 59%, WOB 9-13k. ECD 10.4. Max Gas 266u BGG 168u. P/U 166K, SLK 101K, ROT 126K.
Perform maintenance slides as needed for tangent. Back ream 60' Distance to WP07: 8.81', 5.88' High 6.55' Right. ROT Hrs: 11.11. SLD Hrs: 3.06 Daily Disposal
= 969 bbls G&I total = 2961 bbls. Daily H2O F/ Lake 2 =1260 total = 3750 bbls. Daily Metal: 0 lbs Total 0. Daily DH losses = 0 bbls Total DH = 463 bbls.
50-029-23733-00-00API #:
Well Name:
Field:
County/State:
PBW M-205
Prudhoe Bay West
Hilcorp Energy Company Composite Report
, Alaska
10/26/2022Spud Date:
10/30/2022 Slide/ Rot 12.25" Surface Hole F/ 5,419' to 5,737' MD (4,587' TVD) Total 318' (AROP 53.') 500 GPM, PSI on 1,926/ off 1,855 65 RPM, TRQ on 12-15k, TRQ off 13-
15k, F/O 59%, WOB 10-14k. ECD 10.24. Max Gas 282u BGG 168u. P/U 178K, SLK 103K, ROT 128K. Slide/ Rot 12.25" Surface Hole F/ 5,737' to 6,019' MD
(4,779' TVD) Total 282' (AROP 47.') 500 GPM, PSI on 2,120/ off 1,800 65 RPM, TRQ on 15-17k, TRQ off 13-17k, F/O 59%, WOB 8-12k. ECD 10.29. Max Gas
260u BGG 168u. P/U 183K, SLK 101K, ROT 134K. Slide/ Rot 12.25" Surface Hole F/ 6,019' to 6,404' MD (5,014' TVD) Total 385' (AROP 64.2') 500 GPM, PSI on
1,980/ off 1,780 80 RPM, TRQ on 16-18k, TRQ off 15-17k, F/O 54%, WOB 8-10k. ECD 10.38. Max Gas 340u BGG 180u. P/U 190K, SLK 101K, ROT 138K. End
tangent at 5,900' MD begin 4/100 build/turn Dump/ Dilute 250 bbls mud at 6,242' MD to control gel strengths and Temp. Cont jetting as needed and ream 60'.
Slide/ Rot 12.25" Surface Hole F/ 6,404' to 6,645' MD (5,144' TVD) Total 285' (AROP 47.5') 500 GPM, PSI on 2,044/ off 1,893 80 RPM, TRQ on 17-18.5k, TRQ off
15-17k, F/O 54%, WOB 7-11k. ECD 10.2. Max Gas 274u BGG 128u. P/U 193K, SLK 107K, ROT 138K. Cont 4/100 build/turn. jet as needed and ream 60'
Distance to WP07: 19.61', 19.6' High 0.55' Left. ROT Hrs: 8.55. SLD Hrs: 4.99 Daily Disposal = 969 bbls G&I total = 3930 bbls. Daily H2O F/ Lake 2 = 980 total =
47300 bbls. Daily Metal: 0 lbs Total 0. Daily DH losses = 0 bbls Total DH = 463 bbls.
10/31/2022 Slide/ Rot 12.25" Surface Hole F/ 6,645' to 6,880' MD (5,233' TVD) Total 235' (AROP 39.2') 500 GPM, PSI on 2,064/ off 1,892, 80 RPM, TRQ on 17-18.5k, TRQ off
15-17k, F/O 54%, WOB 7-11k. ECD 10.2. Max Gas 274u BGG 128u. P/U 193K, SLK 102K, ROT 138K. Cont 4/100 build/turn. Back ream 60' Slide/ Rot 12.25"
Surface Hole F/ 6,880' to 7,177' MD (5,299' TVD) Total 297' (AROP 49.5') 500 GPM, PSI on 2,160/ off 1,850, 80 RPM, TRQ on 18-20.5k, TRQ off 15-17k, F/O
54%, WOB 3-9k. ECD 10.3. Max Gas 390u BGG 128u. P/U 189K, SLK 99K, ROT 135K. Cont 4/100 build/turn. Back ream 60' Slide/ Rot 12.25" Surface Hole F/
7,177' to 7,421' MD (5,327' TVD) Total 244' (AROP 40.7') 500 GPM, PSI on 2,160/ off 1,870, 80 RPM, TRQ on 17-20.5k, TRQ off 16-17k, F/O 53%, WOB 7-12k.
ECD 10.35. Max Gas 409u BGG 110u. P/U 188K, SLK 96K, ROT 132K. Cont 4/100 build/turn. Back ream 60' Slide/ Rot 12.25" Surface Hole F/ 7,421' to 7,515'
MD (5,332' TVD) Total 94' (AROP 31.3') 500 GPM, PSI on 2,169/ off 1,890, 80 RPM, TRQ on 17-20k, TRQ off 16-19k, F/O 54%, WOB 6-10k. ECD 10.25. Max
Gas 140u BGG 35u. P/U 175K, SLK 100K, ROT 133K. Drill to TD as per GEO. Back ream 60' C/O Liner, Swab and wear plate on MP #2 Pod 2. Brought MP #2
online and had minimal pump press. Cleaned out suction screen and tried again to pump with minimal pump press. Took apart pod 2 and found pod washed out.
Prep and start changing out Pod 2. Rot/Rec 7,515' to 7,450' MD. 220 gpm 715 psi 75 rpm Trq 15-18k F/O 32%. Max Gas 133u BGG 32u. Rack back 1 stand and
continue Rot/ Rec 7,450' to 7,390' MD Distance to WP07: 27.86', 26.04' High 9.91' Right. ROT Hrs: 9.36. SLD Hrs: 5.77 Daily Disposal = 974 bbls G&I total = 4904
bbls. Daily H2O F/ Lake 2 = 1120 total = 5850 bbls. Daily Metal: 0 lbs Total 0. Daily DH losses = 0 bbls Total DH = 463 bbls.
11/1/2022 Continue to change out Pod #2 on MP #2. Dress with Liner, Wear Plate, Swab, and Seals while Rotate Reciprocate pipe from 7450 to 7188, 220 GPM, 75 RPM, Tq
16-18. Rack back 5 stands(~1 stand per hr). Wash and Ream to bottom from 7188 to 7515 with no issues. Slide/ Rot 12.25" Surface Hole F/ 7,515' to 7,529' MD
(5,329' TVD) Total 29' (AROP 28') 500 GPM, PSI on 2,308/ off 1,890, 80 RPM, TRQ on 18-21k, TRQ off 17-20k, F/O 54%, WOB 6-8k. ECD 10.04. Max Gas 140u
BGG 35u. P/U 188K, SLK 100K, ROT 133K. Drill to TD as per GEO. Back ream 60'. Slide/ Rot 12.25" Surface Hole F/ 7,529' to 7,687' MD (5,342 TVD) Total 158'
(AROP 52.6') 500 GPM, PSI on 2,080/ off 2,020, 80 RPM, TRQ on 18-20k, TRQ off 15-17k, F/O 54%, WOB 8-10k. ECD 10.3. Max Gas 305u BGG 35u. P/U 192K,
SLK 95K, ROT 132K. Geo Call TD @ 7,687 MD, 5,342 TVD. Obtain Final Survey: 7634.74' MD 5338.33 TVD 85.70 Azm, 320.76 Inc. Distance to plan: 37.25'.
36.29' Low. 8.39' Right BROOH while CBUx3 from TD to 7452' MD. 500 GPM, 1820 PSI, ECD 10.2, Max Gas 410u, RPM 80, TQ 18-21K, P/U 185K, SO 98K, Rot
133K. Pumped 40 bbls 9.6 ppg 300 vis nut plug sweep. Back 155 bbls early, with no increase in cuttings. No losses. Condition mud to ~30YP. Wash down F/
7,452' to TD 7,687' MD 450 gpm 1,465 psi 60 rpm Trq 13-16k F/O 53% P/U 188k SLK 97 ROT 129k. No Fill. Monitor well 10 min, static. Service rig. Grease
crown, blocks PH8 & TD. PJSM BROOH F/ 7,687' to 6,054' MD 500 gpm 1,770 psi 80 rpm Trq 15-19 F/O 45% ECD 10.3 Max Gas 208u. P/U 182k SLK 95k ROT
126k CBU at 6,100' MD over 2 stands prior to tangent. No losses. Pull speed 25-40 fpm as hole dictates. PJSM BROOH F/ 76,054' to 3,166' MD 500 gpm 1,610
psi 80 rpm Trq 8-10 F/O 48% ECD 10.3 Max Gas 91u. P/U 134k SLK 88k ROT 100k Pull speed 30-50 fpm as hole dictates. Dynamic loss 3-4 bph lost 19 bbls.
Distance to WP07: 37.25', 36.29' Low 8.39' Right. ROT Hrs: 0.81. SLD Hrs: 1.69. Daily Disposal = 746 bbls G&I total = 5650 bbls. Daily H2O F/ Lake 2 = 980 total
= 6830 bbls. Daily Metal: 0 lbs Total 0. Daily DH losses = 9 bbls Total DH = 472 bbls.
11/2/2022 Continue BROOH from 3,166' to 1,300'. 500 GPM, 1570 PSI, ECD 10.3, MW In/Out 9.7/9.8, Max Gas 85u, RPM 80, Tq 7-10K,. At 2,117' CBU over 3 stands to
BPF. At 1,455 Hole unloading, slow pulling speed and allow to clean up, heavy sands, clays and fluctuated Mud. See 2 bph Dynamic Loss rate. Continue BROOH
from 1,300' to 415'. 425 GPM, 860PSI, ECD 10.1 MW In/Out 9.5/9.5, Max Gas 18u, RPM 40, Tq 1-7K. P/U 76K, SO 74K, Rot 75K.. Pulling speed 2-15 fpm. No
Losses while BROOH. PJSM POOH rack back 5" HWDP & Jar F/ 415' to 161' MD, Electrician and mechanic trouble shoot skate, disarmed safety swing gate and
cont trouble shoot later. L/D 2 ea NM FC. Upload MWD tools as per Sperry MWD. L/D TM, EWR, DM and GWD tools. Drain mud motor and break off bit. PDC 2-2-
BT-G-X-1-WT-TD Cone 2-2-WT-G-E-1-NO-TD PJSM R/D 5" Hydraulic elevators. P/U M/U Volant CRT to TD. Install bail ext and 9.625" 250t side door elevators.
P/U M/U Power Tongs. Stage 9.625" handling Equip, 61 BS Centralizers. Monitor well on TT, no losses. PJSM P/U 9.625" 40# BTC Shoe track. P/U Shoe, blank
and FC (BakerLoc) Drop ByPass valve and check floats, good. P/U BFA jnt to 164' MD Trq average 9.5k. PJSM RIH 9.635" 40# L-80 BTC Csg F/ 164' to 1,329'
MD. Run Speed 30-50 fpm. Started encountering tight spots, washing, and reaming down F/ 1,329 to 1,410 MD 6 bpm 145 psi 5 rpm Trq stall set 7k using 35k
string weight. Seeing heavy sand W/ minimal wood at shakers. Cont RIH on elevators F/ 1,410 to 1,787' MD. Washed through tight spot at 1,563 MD. Filling every
5 jnts and topping off 10. Trq Average 9.8 k. Calc 23.2 Actual 27.3 Lost 4.1 bbls. P/U 94k SLK 78k. Daily Disposal = 746 bbls G&I total = 6396 bbls. Daily H2O F/
Lake 2 = 700 total = 7530 bbls. Daily Metal: 0 lbs Total 0. Daily DH losses = 32 bbls Total DH = 504 bbls.
11/3/2022 PJSM RIH 9.635" 40# L-80 BTC Csg F/ 1,78' to 2,127' MD. Run Speed 30-50 fpm. Started encountering tight spots, washing, and reaming down F/ 2,127 to 2,539
MD 6-7 bpm 149 psi 10-15 rpm Trq stall set 10k using 35k string weight. Seeing heavy sand W/ minimal wood at shakers. Cont RIH on elevators F/ 2,539 to to
2,997' MD. CBU at 2,997' MD. Rot/Rec F/ 2,955' to 2,997' MD 6 bpm 171 psi 5 rpm Trq 8k F/O 42% P/U 138k SLK 112k Filling every 5 jnts and topping off 10.
Trq Average 9.8k. Lost 8.2 bbls. PJSM Cont RIH 9.635" 40# L-80 BTC Csg F/ 2,997' to 5,933' MD. Switched to 9.625" 47# L-80 TXP at 5,450' MD. P/U M/U ES
(6 pins Open 3.3 k PSI) as per HES rep onsite. Run Speed 60 fpm. Trq BTC average 9.8k. Trq TXP 23820 ft/lb. P/U 245k SLK 118k. Fill every 4 top off 10 PJSM
CBU Wash down F/ 5,934' to 6,057' MD over 3 jnts staging up to 6 bpm, 2 bpm ICP 530 psi 6 bpm FCP 310 psi. Max Gas 38u. P/U 235 SLK 133k. Cont RIH
9.635" 47# L-80 TXP Csg F/ 6,057' to 7,677' MD. Staged pumps up to 3 bpm 700 psi washing down last 2 jnts (184 & 185) P/U Jnt 186 was down and tag on
depth (7,687' MD) L/D Jnt 186. Run Speed 60 fpm. Trq TXP 23820 ft/lb. P/U 260k SLK 128k. Lost 51 bbls for tour. Reciprocate F/ 7,677' to 7,632' MD stage up to
5 bpm 520 psi F/O 27%. Condition mud to <20 YP. Reciprocate F/ 7,677' to 7,632' MD stage up to bpm 520 psi F/O 27%. Condition mud to <20 YP. SIMOPS:
Remove remaining jnts from shed (3). R/D Parker power tongs, elevators & bail ext. L/D thread protectors. Release F/ CRT. R/U HP cement lines and LoTrq's. Blow
down air to HES unit. Blow down TD. Jet flow line through bleeder. M/U CRT and Circ at 7 bpm 520 psi started seeing over pull to 315k and drag. Park on depth
7,677' MD.. P/U 295k SLK 131k. SIMOPS unload excess mud F/ pits for cement job. PJSM W/ all personnel. Discuss rig evacuation, well control, man down, fire
control and HP job operations. HES pump 5 bbls H2O. PT low kick out 1,713 psi, high 4,298 psi, good. Pump 60 bbls 10 ppg 4# red dye & Poly E Flak 4.5 bpm
480 PSI. 150 bbls 12.0 ppg Lead Cement ( VeriCem) 2.347 YP (800 sx) 4.5 bpm 395 psi at report time. Daily Disposal = 228 bbls G&I total = 6624 bbls. Daily H2O
F/ Lake 2 = 340 total = 7870 bbls. Daily Metal: 0 lbs Total 0. Daily DH losses = 65 bbls Total DH = 569 bbls. Daily MPU G&I=114 Total 114 bbls.
11/4/2022 Cont Pump 94 bbls (334 total) (800 sx) 12 ppg EconoCem Type I II Lead cmt, 2.347 yld, 4.5 bpm, 380 psi. 82 bbls (400 sx) 15.8 ppg HalCem Type I II Tail cmt,
1.156 yld, 3.5 bpm, 790 PSI. Release F/ Volant, drop shutoff plug. Displace w/ 20 bbls H2O f/CMT Unit 6.7 bpm, 625 psi. Turn over to rig." Rig disp w/ 384.6 bbls
9.5 ppg spud mud, 7.5 bpm, ICP 360 psi, FCP 670 psi @ 6 BPM. HES pump 80 bbls 9.4 ppg spacer, 4.5 bpm, 580 ICP, 830 FCP, 22% flow. Rig displace w/ 99
bbls 5 bpm, 970 ICP, Maintain 5 BPM to Bump with FCP 1150. Bumped @ 569.96 bbls, 2.80 bbls over Calc 567.2 bbls. Hold 1750 psi (3 min). Bleed off psi,
Check floats (good). Psi up, open stage tool 6 bpm, shift @ 2400 psi. CIP @ 09:00 hrs. Parked in tension 230k up. No losses during job CBU x3 @ 4 BPM 400
psi. Dumped 218 bbls contaminated mud with trace cement. (73 bbls Green Cement) Total dumped 431 bbls. Continue to circulate and condition mud via stage
tool (2083' MD) 4 bpm, 428 psi, 34% flow. Drain stack and flush with black water, function annular x3.. Continue to circulate through ESCMTR @ 2083', stage
pumps to 6 bpm, thick mud at surface @ 1700 STKS after flushing stack. Over board 22 bbls until cleaned up. Continue to circulate and condition mud via stage
tool (2083' MD) 6 bpm, 460 psi, 34% flow. Prep Pits for 2nd stage cement. Hold PJSM for 2nd Stage Cement. Un-sting CRT and dope cup, re-sting CRT, pump
through bleeder while jetting flow line, clean dump line. HES begin batching cement. PJSM Pump 2nd stage cement job: HES Pump 5 bbls H2O. 60 bbls 10#
Tuned spacer w/ 4# red dye & .5 lb/bbl poly flake (1st 10 bbls) 8.809 yld 4.5 BPM ICP 330 psi. Cement wet @ 18:10. HES Pump 372 bbls (725 sx) 10.7# ArticCem
Lead cmt, 2.883 yld, 4.5 bpm, ICP 348 PSI FCP 591 PSI psi. 56 bbls (270 sx) 15.8# HalCem Tail cmt, 1.17 yld, 3.5 bpm, ICP 485 psi. Break out Volant, Drop
closing plug. Displace w/ 20 bbls H2O (HES) then turn over to rig. Rig disp w/ 130 bbls (132.79 Calc) 9.5# spud mud, 6 bpm, ICP 375 psi FCP 735 psi, reduced
rate last 10 bbls to 3 bpm, FCP 425 psi. Cont. Press up stage too tool shifted closed at 1,595 PSI, held 1,700 PSI for 3 minutes, check plug, good. CIP @ 20:42 hrs.
Full returns throughout job. Dumped 60 bbls spacer, 65 bbls mixed cement and 196 green cement. PJSM Drain stack and flush surface Equip W/ black water. R/U
Bridge cranes. Pull mouse hole. R/D 1 section of 16" diverter line. Drain stack, remove 4" conductor valve and plug. Vac out 9.625" Csg F/ rig floor. P/U Stack.
Center 9.625" Csg in conductor as per Vault rep onsite. Set ES W/ 50k. SIMOP: B/D cement lines. R/D CRT. R/U 9.625" elevators. Pull bushings. PJSM Vault
make rough cut 9.625" Csg (29.23') Set stack back on speed head. Johnny whack stack. B/D TD. Pull bushing and riser. Lift stack F/ diverter tee. L/D knife valve,
Tee and speed head. R/U RCD head to annular. Stage Csg/ tubing spool into cellar. SIMOPS Clean pits. L/D CRT and csg tools. Daily Disposal = 1561 bbls G&I
total = 8185 bbls. Daily H2O F/ Lake 2 = 1480 total = 9350 bbls. Daily Metal: 0 lbs Total 0. Daily DH losses = 0 bbls Total DH = 569 bbls. Daily MPU G&I=0 Total
114 bbls.
11/5/2022 Cont N/U BOPE. Inspect BOP cavities. C/O ODS blind ram seal due to rubber piece missing from face of seal and heavy scaring on bottom seal. Cont Trq RCD
head. SIMOPS Clean pits. R/U MPD 4" lines. Found broken flange head on pony rod for swab clamp MP #1 hole 2. Service rig. PJSM Dress 9 5/8" stump and
Install 11" X 13 5/8" casing spool as per Vault rep onsite. Test seal low/high 500/ 3,800 psi 5 / 10 min. Install test plug PJSM Install 11" 13 5/8" DSA. Set down
BOP and trq flanges. SIMOPS: Clean and inspect MP's suction manifold.. Clean Pits. Cont working on MP #1. PJSM Cont N/U BOPE. Trq DSA and BOP flanges.
Center and secure stack W/ chain and binders. Install drip pan, kill & choke lines. Hook up hole fill line and MPD return line. Install Koomey lines. Flood stack and
PT MPD lines to 1,200 psi for leaks, good. Pull RCD test cap. Install riser. SIMOPS: Continue work on MP #1 pony rod. PJSM Perform BOPE test W/ 4.5" & 5" to
250 PSI low and 3,000 PSI high for 5 Min. Tested Choke Manifold 4-15, 5" Dart, 2 ea 5" TIW, Upper and lower IBOP, Mez Kill, HCR Choke (F/P), HCR Kill and
manual Choke and Kill, Super Choke and manual to 2,000 PSI, lower VBR (2.875 X 5.5), Use 7 test jnt Upper VBR (4.5 X 7) & Annular. Test H2S 10-20 ppm, LEL
20-40%, Koomey draw drown initial System 3,000 PSI, Manifold 1,450 PSI, Annular 1,070 PSI, after System 1,550 PSI, Man 1,450 PSI, Annular 1,025 PSI. 200 PSI
increase 23 Sec, full charge 95 sec. Nitrogen 6 bottle average 2,333 PSI. Closing time Ann 13 sec, UPR & Blinds 8/8 sec, LPR 4 sec, HCR Choke & Kill 1/1 sec.
F/P HCR Choke greased/function. Fail blind rams. Shut in HCR choke and grease valves 1, 2 & 3 on choke manifold. SIMOPS: Finish C/O pony rod on MP #2.
Take on 870 bbls 9.2 ppg BaraDril to pits. RKB's. Witnessed waived Kam StJohn. PJSM Checked PVT sensors and return flow. PVT high/ low level alarms. Cont
testing CMV 1. 2. 3 and blinds 250/3000 psi 5 min failed. Flooded and cycled valves numerous times. CMV 1, 2,3 Fail, greased/ passed. While retesting found
CMV 15 leaking. Decision was made to C/O CMV 15. PJMS Drain stack Bleed down koomey. Break ram doors open. C/O DS blind ram seals. Reinstall rams and
button up doors. Recharge koomey. Flood stack and purge air. Attempted to test seals and found to be leaking. Daily Disposal = 1011 bbls G&I total = 9196 bbls.
Daily H2O F/ Lake 2 = 420 total = 9770 bbls. Daily Metal: 0 lbs Total 0. Daily DH losses = 0 bbls Total DH = bbls. Daily MPU G&I=57 Total 171 bbls. Surface loss
569 bbls.
11/6/2022 Continue trouble shoot Blind Rams not testing. Open Ram doors, remove Blind Rams, remove seal elements, wire wheel Ram Bodies, wire wheel, clean and grease
cavities. Grease and and redress Ram Bodies with elements. Re install Rams and button up doors. Energize, flood stack and resume testing. Test #10: CMV 1, 2,
3, 15 and Blind Rams. Low/High 250/3000 psi. Bleed off and start rigging down stest equipment. Pull Test Plug, drain stack, P/U Wear Bushing and running tool.
Set 10.75" OD x 9" ID x 37.875" L Wear Bushing. L/D Test Joint. R/D, L/D Test Equipment. Dart, Pump in Sub, Wear Ring Running Tool. Blow down Kill, Choke ,
Degasser, R/D Manual Elevators. R/U Hyd Elevators. Clean Cellar from Blind Ram Change. Install Mouse Hole. R/U Make Up Tongs for BHA. Check Verify Surface
Equip. Dog Collar, Slips, ID Elevators and Lift Sub. Stage 8.5" Tricone on Floor. M/U 8.5" Milltooth (Smith XR+CPS) w/ 6-3/4" 1.5 StrataForce mtr. 6x 5" NC50
49.3# HWDP, 6-1/2" Hydra Jar, 11x 5" NC50 49.3# HWDP. Total BHA length 590.7' MD. Continue Single in F/ 588' - T/ 2003' MD picking up 5" NC50, S-135,
19.5# DP (Drift 3.125"). Wash down F/ 2003', see tag @ 2075' MD. 350 gpm, 590 psi, 40 rpm, 4k tq. P/U 86k, S/O 78k, ROT 82k. Drill stringers/cmt and stage
tool F/ 2075' - T/ 2085' MD. Drill ESCMTR on Depth @ 2083'. 400 gpm, 700 psi, 40 rpm, 3.2k tq, 2-7k WOB, P/U 86k, S/O 78k, ROT 82k. Tripped thru stage tool
clean 2x without issue. Continue TIH picking up 5" out of shed F/ 2085' - T/ 5,032' MD. RIH W/ stands F/ derrick F/ 5,032' to 7,258' MD. P/U 207k SLK 88k. Wash
down F/ 7,258' to 7,540' MD' MD 252 gpm ICP 770 FCP 270 PSI 10-15 RPM TRQ 15-18k Cement stringers at 7,246' MD WOB 2-4k Tag cement at 7,532' MD
drilling down W/ 5-8k. CBU ROT/ REC F/ 7,540' to 7,410' MD 252 gpm 270 PSI 10-15 RPM TRQ 15-18k. Shut down B/D TD. PJSM R/U HP lines and head pin.
Flood CM, kill choke lines purging air. Close UPR. Attempted to test Csg and pumps had minimal charge pump press. Clean suction screens and attempted again
without success. Treated clabbered mud in pill pit 1 and circ through pump W/ good charge pump press. Perform 9.625" Csg test to 2,657 psi after 30 min 2,648
psi lost 9 psi over 30 min on chart. Bleed off Press. Pumped 3.8 bbls bled back 3.7 bbls. PJSM Open UPR. R/D HP line and head pin. Blow down choke, kill and
CM. PJSM Drill cement F/ 7,540' to 7,611' MD BFA 7,550' MD (On depth) FC on depth (7,591' MD) 400 gpm 1080 psi 40 rpm Trq 15k WOB 2-5k F/O 40%. P/U
212k SLK 88k ROT 130k. Daily Disposal = 399 bbls G&I total = 9595 bbls. Daily H2O F/ Lake 2 = 560 total = 10330 bbls. Daily Metal: 0 lbs Total 0. Daily DH
losses = 0 bbls Total DH = bbls. Daily MPU G&I=0 Total 171 bbls. Surface loss 569 bbls.
11/7/2022 Drill cement, shoe track and 20' of new hole from 7611' to 7707', tagging FE on depth. 400 gpm, 1040 psi, 40-60 rpms, 13Kft-lbs, WOB 1-5K. P/U 215K, S/O
92kK, ROT 130K. Ream and pass through float equipment without issue. Begin displacing to 9.2 ppg Baradril-N once in open hole. Continue to Displace well over
to 9.2 ppg BARADRIL System, 400 gpm, 900 psi, 20 rpm, 16K Tq, PU 198K, SO 99K, Rot 128K, POOH inside Shoe to 7650'. Rig up. Purge lines, close UPR and
perform FIT to 12.0 ppg EMW with 9.2 ppg drilling mud and 775 psi. Pump 2.6 bbls, bleed back 2.3 bbls. Blow down lines and rig down. Monitor Well for 10 min.
Static. POOH 5 stands to verify no swabbing to 7371'. P/U 198K, SO 98K Pump Dry Job. TOOH from 7371' to 588'. (BHA) P/U 73k SLK 70k No loss PJSM Rack
back 3 stands 5" HWDP. L/D 11 jnts %" HWDP, Jar, Mud Motor and 8.5" Tricone bit. Bit Grade 1-1-WT-A-E-I-NO-BHA. Clean and clear rig floor. PJSM Grease
crown, blocks and TD. Install bail angle sensor. PJSM P/U M/U BHA 3 8.5" RSS. P/U 8.5" Hycalog TK66 PDC (0.7777 TFS) 8.5" NRP, 7 5/8" 7600 XL GeoPilot, 6
3/4" ADR, 8 3/8" ILS, 6 3/4" DGR, 6 3/4" PWD, 6 3/4" DM, 6 3/4" TM HOC, 8 3/8" Integral Blade, 6 3/4" FS (Non Ported-Plunger) 6 3/4" NM FC,6 3/4" FS (Non
Ported-Plunger) 6 3/4" NM FC, 4 ea 5" HWDP, 6 1/2" Htdra Jar and 3 ea 5" HWDP. 401.78'. PJSM Single in hole BHA 3 W/ 5" D.P. F/ 402' to 6,755' MD. (28 jnts)
Drift 3.125 OD off skate. P/U 160k SLK 99k. No loss. Daily Disposal = 921 bbls G&I total = 10516 bbls. Daily H2O F/ Lake 2 = 280 total = 10610 bbls. Daily Metal:
0 lbs Total 0. Daily DH losses = 0 bbls Total DH = bbls. Daily MPU G&I=0 Total 171 bbls. Surface loss 569 bbls.
11/8/2022 RIH with 8.5" RSS drilling assembly from 6755' to 7645'. P/U 171K, S/O 95K. Calc displacement observed. Cut and slip 82' of drilling line. Check crown and floor
saver. Check brake tolerances on draw works. Service rig: grease crown, blocks, RLA, Link tilt, spinners. Check gear oil on top drive and rotary table. Pull bell
nipple. Install MPD RCD. Wash down from 7645' to 7707', no fill. Drill 8.5" hole from 7707' to 7833' (Total 126', AROP 84 fph) at 450 gpm, 1405 psi, WOB 5-8K,
60 rpms, 15Kft-lbs, ECD 10.2 ppg with 9.4 ppg mud. MPD chokes open. Max gas 74U. P/U 188K, S/O 92K, ROT 126K. Cont. drilling 8.5" hole from 7833' to 8657'
(Total 824', AROP 137 fph) at 450 gpm, 1495 psi, WOB 4-8K, 80-120 rpms (adjusting accordingly due to surface wobble), 16-19Kft-lbs, ECD 10.41 ppg with 9.4
ppg mud. Max gas 1296U, P/U 193K, S/O 83K, ROT 123K. MPD chokes open, backream full stands. Cont. drilling 8.5" hole from 8657' to 8763' (Total 106', AROP
71 fph) at 450 gpm, 1495 psi, WOB 4-8K, 80-120 rpms (adjusting accordingly due to surface wobble), 16-19Kft-lbs, ECD 10.26 ppg with 9.4 ppg mud. Max gas
1032U, P/U 194K, S/O 84K, ROT 123K. MPD chokes open, backream full stands. Service Rig: Draw works DSU overheated causing draw works and TD to shut
down. Open doors in drive house and propped fan to cool down DSU. Circulating hole at 420 gpm, 1325 psi. Cont. drilling 8.5" hole from 8763' to 9298' (Total
535', AROP 134 fph) at 500 gpm, 1875 psi, WOB 5-10K, 80-120 rpms (adjusting accordingly due to surface wobble), 13-15Kft-lbs, ECD 10.54 ppg with 9.4 ppg
mud. Max gas 942U, P/U 178K, S/O 83K, ROT 120K. MPD chokes open, backream full stands. Cont. drilling 8.5" hole from 9298' to 10,058' (Total 760', AROP 127
fph) at 500 gpm, 1990 psi, WOB 5-12K, 100-120 rpms (adjusting accordingly due to surface wobble), 14-15Kft-lbs, ECD 10.6 ppg with 9.4 ppg mud. Max gas
1235U, P/U 158K, S/O 92K, ROT 118K. MPD chokes open, backream full stands. No faults have been crossed so far in this lateral. 14 concretions have been
drilled, for a total footage of 27 (1.2% of the lateral). Total footage in OBd-sands 2317' total footage out of zone 0'. Distance to WP#7: 36.81', 35.46' Low, 9.87' Left
Daily Disposal = 513 bbls G&I total = 11,029 bbls. Daily MPU G&I=0 Total 171 bbls. Daily H2O F/ Lake 2 = 420 total = 11,030 bbls. Daily Metal: 0 lbs Total 0. Daily
DH losses = 6 bbls Total DH = 6 bbls. Surface loss 569 bbls.
11/9/2022 Cont. drilling 8.5" hole from 10,058' to 11,073' (Total 1015', AROP 169 fph) at 500 gpm, 2210 psi, WOB 5-12K, 120 rpms, 15Kft-lbs, ECD 11.0 ppg with 9.4 ppg
mud. Max gas 1409U, P/U 163K, S/O 83K, ROT 117K. MPD chokes open, backream full stands. Cont. drilling 8.5" hole from 11,073' to 12,094' (Total 1021', AROP
170 fph) at 500 gpm, 2335 psi, WOB 9-14K, 120 rpms, 13-17Kft-lbs, ECD 11.14 ppg with 9.4 ppg mud. Max gas 1316U, P/U 178K, S/O 77K, ROT 116K. MPD
chokes open, backream full stands. Cont. drilling 8.5" hole from 12,094' to 12,601' (Total 507', AROP 85 fph) at 515 gpm, 2250 psi, WOB 10-18K, 120 rpms, 14-
16Kft-lbs, ECD 11.23 ppg with 9.4 ppg mud. Max gas 397U, P/U 159K, S/O 81K, ROT 115K. MPD chokes open, backream full stands. Crossed fault at 12,343'
with 18 DTN throw. Faulting above OBd sands to OBd Clay Cont. drilling 8.5" hole from 12,601' to 13,298' (Total 697', AROP 116fph) at 515gpm, 2390psi, WOB
10-14K, 120rpms, 14-16Kft-lbs, ECD 11.7ppg w/ 9.4ppg mud. Max gas 1568U, P/U 159K, S/O 79K, ROT 110K. MPD chokes open, backream full stands. Re-
acquire OBd sands at 12678'. 275 bbls dilution at 13140'. 1 fault was crossed so far in the lateral: 12, 343'. We have drilled 28 concretions for a total thickness of 79
(1.4% of the lateral). Total footage in OBd-Sand 5188', Total footage out of zone: 335'. Distance to well plan #7: 32.63', 19.08' Low, 12.22'Right. Daily Disposal =
855 bbls G&I total = 11,884 bbls. Daily MPU G&I=0 Total 171 bbls. Daily H2O F/ Lake 2 = 1120 total = 12,150 bbls. Daily Metal: 10 lbs Total 10 lbs. Daily DH
losses = 0 bbls Total DH = 6 bbls. Surface loss 569 bbls.
11/10/2022 Cont. drilling 8.5" hole from 13,298' to 14,251' (Total 953', AROP 159fph) at 500gpm, 2545psi, WOB 10-15K, 120rpms, 19Kft-lbs, ECD 11.7ppg w/ 9.4ppg mud.
Max gas 886U, P/U 166K, S/O 70K, ROT 110K. MPD chokes open, backream full stands. Cont. drilling 8.5" hole from 14,251' to 15,131' (Total 880', AROP 160fph)
at 500gpm, 2590psi, WOB 10-14K, 120rpms, 18-19Kft-lbs, ECD 11.7ppg w/ 9.4ppg mud. Max gas 702U, P/U 171K, S/O 52K, ROT 112K. MPD chokes open,
backream full stands. Dynamic loss rate 10 bph. Rack back stand. Circulate at 275 gpm, 1100 psi. 100 rpms, 14.5Kft-lbs. Change out swab, liner, suction
seat/valve on pod 1, mud pump 2. Cont. drilling 8.5" hole from 15,131' to 15,903' (Total 772', AROP 129fph) at 500gpm, 2650psi, WOB 8-15K, 120rpms, 18-19Kft-
lbs, ECD 11.99ppg w/9.4ppg mud. Max gas 671U, P/U 165K, S/O 58K, ROT 110K. MPD chokes open, backream full stands. 200bbls whole mud dilution at
15534'. Dynamic loss rate 10 bph Cont. drilling 8.5" hole from 15,903' to 16,726' (Total 823', AROP 137fph) at 475gpm, 2650psi, WOB 8-15K, 120rpms, 18-19Kft-
lbs, ECD 11.8ppg w/ 9.4ppg mud. Max gas 610U, P/U 175K, S/O 48K, ROT 112K. MPD chokes open, backream full stands. Dynamic loss rate 8-10 bph. 1 fault
was crossed so far in the lateral: 12, 343'. We have drilled 37 concretions for a total thickness of 97 (1.1% of the lateral). Total footage in OBd-Sand 8652', Total
footage out of zone: 335'. Distance to WP#7: 21.99', 13.52' low, 17.35' Right. Daily Disposal = 1278 bbls G&I total = 13,162 bbls. Daily MPU G&I=0 Total 171 bbls.
Daily H2O F/ Lake 2 = 980 total = 13,130 bbls. Daily Metal: 1 lbs Total 11 lbs. Daily DH losses = 100 bbls Total DH = 106 bbls. Surface loss 569 bbls.
11/11/2022 Cont. drilling 8.5" hole from 16,726' to 17,426' (Total 700', AROP 117fph) at 500gpm, 2880psi, WOB 8-17K, 120rpms, 22-24Kft-lbs, ECD 11.9ppg w/ 9.35ppg
mud. Max gas 144U, P/U 185K, S/O N/A (lost S/O at 17,100), ROT 110K. MPD chokes open, backream full stands. 290 bbls dilution at 16975' Cont. drilling 8.5"
hole from 17,426' to TD at 17,871' (Total 445', AROP 99fph) at 500gpm, 2890psi, WOB 8-13K, 120rpms, 20-23Kft-lbs, ECD 11.74ppg w/ 9.35ppg mud. Max gas
307U, P/U 185K, S/O N/A, ROT 110K. MPD chokes open, backream full stands. Obtain final survey, SPR's and drop drift. Pump tandem low wt/vis and hight wt vis
and circulate hole clean 4x bottoms up at 500 gpm, 2675 psi, 120 rpms, 20Kft-lbs, ECD's 11.21 ppg EMW. Reciprocating pipe. Worley trucks were called out for
displacement at 21:00. Cont. circulating at 500 gpm, 2675 psi, 120 rpms, 20Kft-lbs torque. Trucks on location at 23:00. Spot in trucks. Pump SAPP train and
displace well to 9.3 ppg Quickdril-N at 500 gpm, 2675psi, 120 rpms, 21Kft-lbs. ECD's 10.9 ppg, reciprocating pipe. P/U 245K, S/O N/A, ROT 112K. Max gas 93U.
Rack back stand to 17,800'. Monitor well with MPD no pressure build. Obtain SPR's. BROOH from 17800' to 16480' at 500 gpm, 1950 psi, 120 rpms, 20-22Kft-lbs,
ECD's 10.7 ppg, max gas 276U. P/U 205K, S/O 39K, ROT 120K. Pull 15-20 fpm as hole dictates. 1 fault was crossed in the lateral: 12, 343'. We have drilled 40
concretions for a total thickness of 107 (1% of the lateral). Total footage in OBd-Pay sand 9070', Total footage above OBd-pay: 423', Total footage below OBd-pay:
701'. Distance to WP#7: 19.81', 19.21' low, 4.85' right Daily Disposal = 1264 bbls G&I total = 14,426 bbls. Daily MPU G&I=0 Total 171 bbls. Daily H2O F/ Lake 2 =
1260 total = 14,390 bbls. Daily Metal: 0 lbs Total 11 lbs. Daily DH losses = 93 bbls Total DH = 199 bbls. Surface loss 569 bbls.
11/12/2022 BROOH from 16480' - T/ 14220' MD. 10-20 fpm pulling speed as hole allows. 500 gpm, 1820 psi, 120 rpms, 20Kft-lbs, ECD's 10.1 , max gas 511u. P/U 182K,
S/O 72K, ROT 122K. Screen up 170/200's. 9.2 MW BROOH F/ 14220' - T/ 12150' MD. 10-20 fpm pulling speed as hole allows. 425-500 gpm, 1230 psi, 120
rpms, 15K ft-lbs, ECD's 10.1 , max gas 621u. P/U 165K, S/O 95K, ROT 123K. BROOH F/ 12150' - T/ 9540' MD. 5-20 fpm pulling speed as hole allows. 500 gpm,
1425 psi, 120 rpms, 15K ft-lbs, ECD's 10.0 PPG EMW , max gas 343u. P/U 160K, S/O 95K, ROT 120K. BROOH F/ 9540' - T/ 7645' MD. 5-20 fpm pulling speed
as hole allows. 500 gpm, 1350 psi, 120 rpms, 12K ft-lbs, ECD's 9.8 PPG EMW , max gas 22u. P/U 150K, S/O 108K, ROT 128K. Pump tandem sweeps (on time,
10% increase) and circulate hole clean (S-S) at 500 gpm, 1305 psi, 80 rpms, 9Kft-lbs. ECD 9.8 ppg EMW. Obtain passing PST test at possum belly. Monitor well,
static. BD top drive. Daily Disposal = 2424 bbls G&I total = 16,850 bbls. Daily MPU G&I=0 Total 171 bbls. Daily H2O F/ Lake 2 = 700 total = 15,090 bbls. Daily
Metal: 0 lbs Total 11 lbs. Daily DH losses = 157 bbls Total DH = 356 bbls. Surface loss 569 bbls.
11/13/2022 Remove RCD bearing and install trip nipple. Flood and check for leaks (no leaks). Clean and Demob bearing from floor. Service rig. Grease all traveling
equipment. Service handling equipment. Sym Ops - Pump dry job, B/D TDS. POOH F/ 7645' - T/ 850' MD laying down drill pipe. Inspect and cull out dp for hard
band and Cat V inspection. 6.5 bbl loss for trip. P/U 70k, S/O 69k. Continue POOH F/ 850' - T/ 90' MD laying down drill pipe, HWDP, NM flex DC's. Download
MWD. L/D MWD/LWD tools. B/O and L/D geopilot and bit. Bit graded 2,4,BT,A,X,I,ER,TD. 7 bbl total loss for trip. 1-2 bph static loss rate. ILS showed slight
damage and IBS showed moderate damage. RIH with 54 stands from derrick to create room on floor to 3428'. POOH laying down drill pipe to surface. Rig up to RIH
with 4-1/2" injection liner. Rig up 4-1/2" handling tools, P/U casing job box, power tongs. Verify pipe count in shed and mark location for jewelry. M/U and check
floats. RIH with 4-1/2", L-80, 12.6#, JFE Bear liners as per tally to 608'. Tq Turning connections to 5400 ft-lbs. Verify 3 pins in frac sleeves RIH with 4-1/2", L-80,
12.6#, JFE Bear liners as per tally from 608' to 5495'. Tq Turning connections to 5400 ft-lbs. Verify 3 pins in frac sleeves. P/U 60K, S/O 51K. Cacl disp 101.4 bbls,
Act 95.3 bbls. Daily Disposal = 288 bbls G&I total = 17,138 bbls. Daily MPU G&I=0 Total 171 bbls. Daily H2O F/ Lake 2 = 140 total = 15,230 bbls. Daily Metal: 0
lbs Total 11 lbs. Daily DH losses = 27 bbls Total DH = 383 bbls. Surface loss 569 bbls.
11/14/2022 RIH with 4-1/2", L-80, 12.6#, JFE Bear liners as per tally from 5495' to 10826'. Tq Turning connections to 5400 ft-lbs. Verify 3 pins in frac sleeves. P/U 70K, S/O
48K. Running speed 70fpm with Welltec packer in open hole as per Welltec hand. Cacl disp 198 bbls, Act 189 bbls. C/O pipe handling equip Cont. to RIH with
lower completion as per tally, M/U 11 joints of 7" casing to 11280'. C/O pipe handling to 5" drill pipe. M/U SLZXP to 11317'. P/U 80K, S/O 52K. RIH with lower
completion conveyed on drill pipe from 11, 317' to TD at 17871', set down 20K. Filling pipe every 5 stnads. P/U 175K, S/O 92K. Work though tight hole from
15450' to 15805' setting down 30-35K with little to no overpull. Observe slight bucking from 15,500' to TD. Pick up to set liner in tension at 175K (PUW). Bring
pumps on at 2 bpm and observe Airlock burst at 923 psi. Cont. circulating 1.5x liner volume to spot air in lateral. ICR 10 bpm, 400 psi, FCR 6 bpm, 1200 psi. Set
slips, break out TD. Drop 1.0" phenolic ball. Attempt to pick to 175K to ensure in tension, observe 30K loss in up wt (145K), indicating liner was released. Slack off
and tag ~5', setting 40K down observing a bobble (possibly setting packer with dog sub, possibly pulled out of TOL while attempting to set liner in tension). Attempt
to put ball on seat and shear out ball sub attempt to pump at 2 bpm with limiter set at 800 psi, pumps slowing to 0.5 bpm with no returns. Shut down pumps and
bleed off pressure. Pick up to 145K, establish rotary at 15 rpms, 6Kft-lbs. Slack off and ensure packer set with 67K down while rotating. Pick up to up weight, shut
down rotary. TOL at 6566' Rig up and PT SLZXP liner packer to 1500 psi for 10 minutes - good. L/D working single, pulling pack off out of top of liner. Pump at 6
bpm to set phenolic ball on seat and shear out ball sub, Pick up 30' to ensure clear of liner top and continue circulating a bottoms up at 9 bpm 850 psi. Monitor well,
static. Service rig: grease crown, TD, RLA, link tilt assembly, check oil on TD, grease spinners, install bail angle receiver in derrick and transmitter on TD bail. Pump
corrosion inhibited dry job. B/D top dirve, install stripping rubbers and air slips. POOH laying down drill pipe from 6511' to 2785', culling out pipe for Cat 5
inspection. P/U 85K. Daily Disposal = 0 bbls G&I total = 17,138 bbls. Daily MPU G&I=0 Total 171 bbls. Daily H2O F/ Lake 2 = 0 total = 15,230 bbls. Daily Metal: 0
lbs Total 11 lbs. Daily DH losses = 56 bbls Total DH = 439 bbls. Surface loss 569 bbls.
Activity Date Ops Summary
11/15/2022 Cont. to POOH with liner running tool from 2785' to surface laying down drill pipe and LRT. cull pipe for Cat 5 inspection. RIH with excess drill pipe from derrick to
880'. POOH laying down drill pipe.,Pull wear ring.,R/U to RIH with 7" tie back string. C/O pipe handling equipment. R/U power tongs. M/U Baker bullet seal
assembly. RIH with 7", 26#, L-80, BTC casing from surface to 382'. P/U 41K, S/O 41K. M/U first 10 joints to mark, then average of 9100 ft-lbs. Cont. to RIH with 7",
26#, L-80, BTC casing from 382' to No-Go at 6576'. P/U 168K, S/O 123K. Calculate space out (1.23' off no-go), L/D 3 joints, P/U 14.71' pup joint, p/u full joint
above. M/U hanger and landing joint. Land hanger and verify landed.,Close annular and pressure up to 400 psi, strip up until ports on Bullet seals are exposed as
indicated by pressure drop. R/U and reverse circulate 130 bbls of corrosion inhibited brine at 4 bpm, 230 psi followed by 53 bbls of diesel for freeze protect 2 bpm
350 psi. Strip through bag and land 7" tieback string. B/D top drive and hoses.,Clean and clear rig floor. Pull mouse hole, swap to 5" elevators. R/U LRS to PT.,Set
7" packoff, RILDS and test void 500/3000 psi for 10 min - good. MIT 9-5/8"x7" annulus to 1500 psi for 30 min, good. Pumped 2.3 bbls bled back 2.0 bbls.,Rig up to
RIH with upper completion. M/U 4-1/2" power tongs, C/O pipe handling equipment. Prep shed.,RIH with 4-1/2", 12.6#, L-80, VamTop upper completion as per tally
from surface to 1445'. BakerLok all connections below packer. Tq turn connections to 4440 ft-lbs. P/U 48K, S/O 48K.,Daily Disposal = 0 bbls G&I total = 17,138
bbls. Daily MPU G&I=0 Total 171 bbls. Daily H2O F/ Lake 2 = 80 total = 15,310 bbls. Daily Metal: 0 lbs Total 11 lbs. Daily DH losses = 0 bbls Total DH = 439 bbls.
Surface loss 569 bbls.
11/16/2022 Cont. to RIH with 4-1/2", 12.6, L-80, Vam top upper completion as per detail from 1445' to 6953'. Tq turn all connections to 4440 ft-lbs. M/U hanger and land tubing.
RILDS. P/U 99K, S/O 77K,R/U and reverse circulate 105 bbls of 9.2 bbls Neat brine followed by 122 bbls corrosion inhibited brine to cover 7"x4.5" annulus at 3
bpm, 310 psi.,R/U landing joint, drop ball and rod. L/D landing joint and close blinds. Pressure up to 3500 psi to set TNT packer. MIT-T to 3500 psi for 30
minutes, bleed to 2000 psi and MIT-IA to 3500 psi for 30 minutes. Bleed tubing and observe GLM shear. Pumped total of 4.65 bbls, bled back 3.2 bbls.,R/U, flush
and blow down stack, and all surface lines. Set TWC.,N/D BOPE. R/D Beyond lines. L/D drip pan. Install RCD test cap. N/D BOP's and rack back. Sim Ops:
clean pits.,N/D tree. Clean ring grooves. Instlal dry hole tree. PT tubing hanger void 500/5000 for 10 min - good. R/U and PT tree 500/5000 psi. SiOps: pull
suction and discharge valve and seats on MP 1 pods 1 and 2. Cont. cleaning pits.,Rig up and reverse circulate 88 bbls of diesel for freeze protect with Little Red
services at 2 bpm ICP 360 psi, FCP 280 psi. R/D and B/D lines.
11/17/2022 Scope down derrick. Finish cleaning pits. take apart mud pumps. Unhang rig tongs. Secure weight buckets for derrick climber. Unplug derrick wires. Secure cellar
for rig move. Final pressures: T=0, IA=0, OA=0. RDMO 06:00.
Well Name:
Field:
County/State:
PBW M-205
Prudhoe Bay West
Hilcorp Energy Company Composite Report
, Alaska
50-029-23733-00-00API #:
ACTIVITYDATE SUMMARY
11/18/2022
T/I/O=SI/0/0. RD Dry Hole Tree. RU Upper Tree. Torque to API specs. PT Upper
Tree against MV, 300 psi low & 5000 psi High (PASSED). JOB COMPLETE. Final
WHP's T/I/O= 0/0/0.
11/19/2022
***WELL S/I ON ARRIVAL***
RAN 4 1/2" BAITSUB W/ GUTTED 2" JD, SAT DOWN HIGH @ 5,808' SLM, GS
SHEARED
PULLED BEK-SHEAR VALVE FROM ST #1 @ 2,596' MD
SET BK-DGLV, IN ST #1 @ 2,596' MD (good drawdown test on ia)
PULLED BAITSUB W/ GUTTED 2" JD FROM 5,508' SLM
RAN 3.79" SWAGE TO 5,508' SLM (ring on swage indicates over torqued collar,
~3.65" id)
RAN 3.55" CENTRALIZER & 3" LIB TO BALL & ROD @ 6,798' MD (good impression
of fishing neck)
RAN REED CALIPER FROM 6,780' SLM TO SURFACE(over-torqued collar 5,513' /
3.65"id & 3.84"id damage directly above)
***CONTINUE 11/20/22***
11/20/2022
***CONTINUE FROM 11/19/22***
PULL BALL & ROD @ 6,780' SLM
SWAGE 3.65" RESTRICTION @ 5,507' SLM
RAN ASSORTED SWAGES FROM 3.69" UP TO 3.72"
3.72" FALLING THROUGH FREELY
***CONTINUE 11/21/22***
11/21/2022
***CONTINUE 11/20/22***
SWAGING TIGHT SPOT @ 5,507' SLM (3.76" swage passes)
WEATHER STANDBY
***CONTINUE 11/22/22***
11/22/2022
***CONTINUE FROM 11/21/22***
POLLARD UNIT #59 WEATHER HOLD HIGH WINDS
SWAGING TIGHT SPOT @ 5,507' SLM (3.78" swage)
***CONTINUE 11/23/22***
11/23/2022
***CONTINUE FROM 11/22/22***
SWAGE TIGHT SPOT @ 5,507' SLM
4 HOURS 13' X 2 5/8" STEM, (3.78" SWAGE WILL NOT PASS THROUGH)
10 HOURS 13' X 3" STEM, (3.77" WILL GO THROUGH)
RUN 3.75" SWAGE, 2' STEM, 3.75" CENT. 3.78" GAUGE RING S/D @ 5,507' SLM
***CONTINUE 11/24/22***
11/24/2022
***CONTINUE FROM 11/23/22***
SWAGE OUT OVER TORQUED COLLAR @ 5,502' SLM (3.78").
RAN 3.79" SWAGE TO 5501' SLM. JARRED 2 HOURS, AND UBALE TO PASS.
***WSR CONTINUED ON 11-25-22***
11/25/2022
***WSR CONTINUED FROM 11-24-22***
SWAGED OUT COLLAR @ 5501' SLM. OPEN TO 3.795".
***WSR CONTINUED ON 11-26-22***
11/26/2022
***WSR CONTINUED FROM 11-25-22***
SWAGED COLLAR @ 5501' SLM (OPEN 3.805").
PULLED 4 1/2" RHC BODY FROM X NIPPLE @ 6,798' MD
***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED OF STATUS***
Daily Report of Well Operations
PBU M-205
Daily Report of Well Operations
PBU M-205
11/27/2022
LRS CTU #2 1.5" Blue Coil
Planned Maintenance and Pipe Swap 1.5" coil to 2" coil .156".
***In progress***
11/28/2022
LRS CTU #2 2" .156" HT95 Blue Coil
Pipe Swap 1.5" coil to 2" coil .156" completed. LRS begin maintenance.
***Continued on maintenance AWGRS report***
11/29/2022
LRS CTU #2 - 2.0" Coil
Job Objective: Set Packers, Shift Sleeves
MIRU CTU. Load coil w/diesel and pump 1.375" drift ball through 2" coil. Complete
Weekly BOP test. RIH w/BOT milling BHA w/string mill & 3.79" parabolic mill. Made
passes through restriction @ 5,501' w/no issues. Drift down to 14,433' ctm, snubbing
stacking weight. Swap coil over to KCI w/safelube.
...Job in Progress...
11/30/2022
(Assist Coil) TFS U-3, Arrived to location, checked in with WSL. Coil had unit
standby. Released once coil reached bottom.
11/30/2022
LRS CTU #2 - 2.0" .156" Blue Coil
Job Objective: Set Packers, Shift Sleeves
Continue RIH w/BOT motor & 3.79" mills. Coil lock up @ 14,566' CTM. LRS online
down CTBS @ 6 bpm. Continue RIH 50 -100 fpm. Tagged PBTD, E-17,767', M-
17,840'. Weight off bottom = 30k. Pooh w/BHA, put 10 bbl MEOH cap on well and FP
coil w/60 bbls of diesel. M/U NCS BHA. RIH and drift to 15,150' before having to
pump coil to PBTD. Tagged TD at 17,777 CTMD and pick up to locate Sleeve #1 and
correct depth. Unable to set packers due to supercharged formation. Set NCS packer
at 17,676' and PT completion to 1900 psi and lose 52 psi in 5 mins. Pick up and shift
open NCS sleeves #1-6 while allowing formation pressure to bleed down. Set NCS
packer @ 15,113' Corrected MD. Pressure IA up to 1500 psi. Pressure up tubing
incrementally 600 psi to 5000 psi to set Welltec OH packers. Final OH PKR setting
pressure 5000 psi for 5 minutes @ .3 bpm. PUH shifting NCS sleeves #7 - 19 to the
open position.
...Job in Progress...
12/1/2022
LRS CTU #2 - 2.0" .156" Blue Coil
Job Objective: Set Welltec OH Packers, Shift NCS Sleeves Open
PUH and shift open NCS sleeves #20 - 23. Pooh w/NCS BHA. FP tubing w/45 bbls
diesel while Pooh. On surface w/NCS BHA, RDMO CTU #2.
***Job Completed***
TD Shoe Depth: PBTD:
No. Jts. Returned
RKB RKB to BHF RKB to THF
Jts.
1
2
3
51
Yes X No X Yes No 6.1
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? 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:
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
RKB
10
545 18446.47
SE
C
O
N
D
S
T
A
G
E
MP1
20:42
Surface
Rotate Csg Recip Csg Ft. Min. PPG9.6
Shoe @ 7677.41 FC @ Top of Liner7,592.14
Floats Held
30 844
299 545
Spud Mud
CASING RECORD
County State Alaska Supv.J Lott/ O Amned
Hilcorp Energy Company
CASING & CEMENTING REPORT
Lease & Well No.PBW M-205 Date Run 2-Nov-22
Setting Depths
Component Size Wt. Grade THD Make Length Bottom Top
TXP BTC Innovex 1.78 7,677.41 7,675.63
25.13
Csg Wt. On Hook:260,000 Type Float Collar:Standard No. Hrs to Run:21
9.5 5
1700
10
10.7 372 4.5
100
970
Bump Plug?
FI
R
S
T
S
T
A
G
E
10Tuned Spacer 60
15.8
425
3.5
9.5 6 130/132.8
569.9/567.2
1150
73
MP 1
15.8 82
Bump press
Calculation
Bump Plug?
Y
9:00 11/4/2022 2,084
2083.69
7,677.007,687.00
CEMENTING REPORT
Csg Wt. On Slips:50,000
Spud Mud
Tuned Spacer
725 2.88
Stage Collar @
60
Bump press
100
226
ES Closure OK
56
12 334
26.80 RKB to CHF
Type of Shoe:Conventional Casing Crew:Parker
No. Jts. Delivered 188 No. Jts. Run 185 3
Length Measurements W/O
Threads
Ftg. Delivered 7,614.00 Ftg. Run 7,677.00 Ftg. Returned 123.00
Ftg. Cut Jt. Ftg. Balance
www.wellez.net WellEz Information Management LLC ver_04818br
4
ArcticCem
Type
2 ea BS & 4 ea SR on shoe jnt, 1 ea BS Blank Jnt and FC jnt. 1 ea BS to jnt 25. Every other Jnt to Jnt 55. 5 ea BS
before ES, 1 ea BS & 1 ea SR on ES Pups, 5 ea BS after ES. Every third jnt F/ jnt 142 to jnt 181. Total 8 stop rings
and 67 Bow Spring Centralizers.
9.625" Csg 9 5/8 40.0 L-80 TXP BTC 82.03 7,675.63 7,593.60
FC 10 TXP BTC Innpvex 1.46 7,593.60 7,592.14
9.625" Csg 9 5/8 40.0 L-80 TXP BTC 40.06 7,592.14 7,552.08
Baffle Adapter 10 TXP BTC Halliburton 1.44 7,552.08 7,550.64
9.625" Csg 9 5/8 47.0 L-80 TXP BTC 5,446.03 7,550.64 2,104.61
Pup Jnt 9 5/8 40.0 L-80 TXP BTC 18.10 2,104.61 2,086.51
ES Cementer 10 TXP BTC Halliburton 2.82 2,086.51 2,083.69
Pup Jnt 9 5/8 40.0 L-80 TXP BTC 17.60 2,083.69 2,040.96
9.625" Csg 9 5/8 47.0 L-80 TXP BTC 2,040.96 2,040.96
EconoCem 800 2.35
HalCem 400 1.16
4.5
HalCem 270 1.17
11/4/2022 0
Spud Mud
1
Regg, James B (OGC)
From:PB Wells Integrity <PBWellsIntegrity@hilcorp.com>
Sent:Sunday, December 4, 2022 4:09 PM
To:Brooks, Phoebe L (OGC); Regg, James B (OGC); Wallace, Chris D (OGC)
Cc:Oliver Sternicki
Subject:Hilcorp (PBU) November 2022 MIT forms
Attachments:NOV 2022.zip
All,
Attached are the completed AOGCC MIT forms for the tests completed by Hilcorp in November 2022.
Well: PTD: Notes:
14‐14 1811020 MIT‐T per Sundry #322‐240
A‐17A 206125 4‐year MIT‐IA
M‐205 2221270 Initial MIT‐T, MIT‐IA & MIT‐OA
NK‐25 1970680 4‐year MIT‐IA
P‐10A 2150660 2‐year MIT‐IA per AA AIO 3.030
PSI‐06 2020790 4‐year MIT‐IA
V‐120 2041790 MIT‐T & MIT‐IA per Sundry #322‐568
Z‐25 1881590 MIT‐IA for AA Application
Z‐34 2120610 MIT‐T & MIT‐IA per Sundry #322‐277
Z‐34 2120610 Initial MIT‐IA per Sundry #322‐277
Z‐223 2220800 Initial MIT‐IA
Please reply with questions or concerns.
Ryan Holt
Hilcorp Alaska LLC
Field Well Integrity
Rayn.holt@hilcorp.com
P: (907) 659‐5102
M: (907) 232‐1005
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 M-205PTD 2221270
Submit to:
OPERATOR:
FIELD / UNIT / PAD:
DATE:
OPERATOR REP:
AOGCC REP:
Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min.
PTD 2221270 Type Inj N Tubing 0 3730 3700 3690 Type Test P
Packer TVD 5167 BBL Pump 1.7 IA 0 0 0 0 Interval I
Test psi 1500 BBL Return OA 0 10 10 10 Result P
Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min.
PTD 2221270 Type Inj N Tubing 2050 2676 2516 2325 Type Test P
Packer TVD 5167 BBL Pump 2.8 IA 0 3660 3600 3590 Interval I
Test psi 1500 BBL Return OA 10 620 600 595 Result P
Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min.
PTD 2221270 Type Inj N Tubing 0 0 0 Type Test P
Packer TVD BBL Pump 2.3 IA 0 0 0 Interval I
Test psi BBL Return 2.0 OA 0 1663 1631 1618 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
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:
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:Bleed Tubing to 2050 psi, PT IA. Pumped 4.5 bbls total between both tests. Bled back 3.2 bbls
PBU M-205
Notes:PT 9 5/8 x 7" OA.
Notes:
Hilcorp North Slope LLC
Prudhoe bay / PBU / M-Pad
Witness Waived by Sean Sullivan
James Lott
11/16/22
Notes:Set PKR, PT Tubing
Notes:
Notes:
Notes:
M-205
PBU M-205
Form 10-426 (Revised 01/2017)2022-1116_MIT_PBU_M-205_3tests
J. Regg; 4/13/2023
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner:Rig No.:Innovation DATE:11/6/22
Rig Rep.:Rig Email:
Operator:
Operator Rep.:Op. Rep Email:
Well Name:PTD #2221270 Sundry #
Operation:Drilling:x Workover:Explor.:
Test:Initial:x Weekly:Bi-Weekly:Other:
Rams:250/3000 Annular:250/3000 Valves:250/3000 MASP:1799
MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 1 P
Permit On Location P Hazard Sec.P Lower Kelly 1 P
Standing Order Posted P Misc.NA Ball Type 2 P
Test Fluid Water Inside BOP 1 P
FSV Misc 0 NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0 NA Trip Tank P P
Annular Preventer 1 13-5/8", 5K P Pit Level Indicators P P
#1 Rams 1 4-1/2"x7"P Flow Indicator P P
#2 Rams 1 Blinds FP Meth Gas Detector P P
#3 Rams 1 2-7/8"x5-1/2"P H2S Gas Detector P P
#4 Rams 0 NA MS Misc 0 NA
#5 Rams 0 NA
#6 Rams 0 NA ACCUMULATOR SYSTEM:
Choke Ln. Valves 1 3-1/8", 5K P Time/Pressure Test Result
HCR Valves 1 3-1/8", 5K P System Pressure (psi)3000 P
Kill Line Valves 1 3-1/8", 5K P Pressure After Closure (psi)1550 P
Check Valve 0 NA 200 psi Attained (sec)23 P
BOP Misc 0 NA Full Pressure Attained (sec)95 P
Blind Switch Covers:All stations Yes
CHOKE MANIFOLD:Bottle Precharge:P
Quantity Test Result Nitgn. Bottles # & psi (Avg.):6 @ 2340psi P
No. Valves 15 FP ACC Misc 0 NA
Manual Chokes 1 P
Hydraulic Chokes 1 FP Control System Response Time:Time (sec)Test Result
CH Misc 0 NA Annular Preventer 12.7 P
#1 Rams 8 P
Coiled Tubing Only:#2 Rams 8 P
Inside Reel valves 0 NA #3 Rams 4 P
#4 Rams 0 NA
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:3 Test Time:17.0 HCR Choke 1 P
Repair or replacement of equipment will be made within days. HCR Kill 1 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 11/4/22, 18:10
Waived By
Test Start Date/Time:11/5/2022 17:00
(date)(time)Witness
Test Finish Date/Time:11/6/2022 10:00
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Kam StJohn
Hilcorp
Tested with 4-1/2", 5" and 7" test joints. All test with fresh water. Failed test Choke HCR. Serviced and Retest Pass. Fail on
Choke Man Valve #15. Replace and retest Pass. Fail on Blind Rams.Remove and Redress with new Seals. Retest Pass.
Matt Vanhoose
Hilcorp
James Lott
PBU M-205
Test Pressure (psi):
nnovationtoolpusher@hilcorp.com
jlott@hilcorp.com
Form 10-424 (Revised 08/2022)2022-1106_BOP_Hilcorp_Innovation_PBU_M-205
North Slope LLC
J. Regg; 12/2/2022
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
DIVERTER Test Report for:
Reviewed By:
P.I. Suprv
Comm ________PRUDHOE BAY UN POL M-205
JBR 12/21/2022
MISC. INSPECTIONS:
GAS DETECTORS:
DIVERTER SYSTEM:MUD SYSTEM:
P/F
P/F
P/F
Alarm
Visual Alarm
Visual Time/Pressure
Size
Number of Failures:0
Remarks:5" joint
TEST DATA
Rig Rep:Billy SerafineOperator:Hilcorp North Slope, LLC Operator Rep:Oliver Amend
Contractor/Rig No.:Hilcorp Innovation PTD#:2221270 DATE:10/26/2022
Well Class:DEV Inspection No:divSAM221026184449
Inspector Austin McLeod
Inspector
Insp Source
Related Insp No:
Test Time:1
ACCUMULATOR SYSTEM:
Location Gen.:P
Housekeeping:P
Warning Sign P
24 hr Notice:P
Well Sign:P
Drlg. Rig.P
Misc:NA
Methane:P P
Hydrogen Sulfide:P P
Gas Detectors Misc:NA NA
Designed to Avoid Freeze-up?P
Remote Operated Diverter?P
No Threaded Connections?P
Vent line Below Diverter?P
Diverter Size:13.625 P
Hole Size:12.25 P
Vent Line(s) Size:16 P
Vent Line(s) Length:199 P
Closest Ignition Source:95 P
Outlet from Rig Substructure:190 P
Vent Line(s) Anchored:P
Turns Targeted / Long Radius:NA
Divert Valve(s) Full Opening:P
Valve(s) Auto & Simultaneous:
Annular Closed Time:10 P
Knife Valve Open Time:5 P
Diverter Misc:0 NA
Systems Pressure:P3000
Pressure After Closure:P1950
200 psi Recharge Time:P19
Full Recharge Time:P60
Nitrogen Bottles (Number of):P6
Avg. Pressure:P2350
Accumulator Misc:NA0
P PTrip Tank:
P PMud Pits:
P PFlow Monitor:
NA NAMud System Misc:
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
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Prudhoe Bay West
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Prudhoe Bay West
M-205 SB Injector
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Prudhoe Bay West
M-205 SB Injector
Drilling Procedure
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Prudhoe Bay West
M-205 SB Injector
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Prudhoe Bay West
M-205 SB Injector
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Prudhoe Bay West
M-205 SB Injector
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3800 Centerpoint Dr., Ste. 1400 | Anchorage | AK | 99503
Office: 907.777.8395 | Cell: 805.235.6265
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