Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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Hilcorp Alaska, LLC Post Office Box 244027
Anchorage, AK 99524-4027
3800 Centerpoint Drive
Suite 1400
Anchorage, AK 99503
Phone: 907/777-8547
September 29, 2023
Mr. Mel Rixse
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
Re: Milne Point Conductor Annulus Corrosion Inhibitor Treatments 6/9 to 9/27/2023
Dear Mr. Rixse,
Enclosed please a copy of a spreadsheet with a list of thirteen Milne Point wells that were treated
with corrosion inhibiting casing filler in the surface casing by conductor annulus. The heavier than
water “grease-like” filler displaces water to prevent external casing corrosion that could result in
a surface casing leak. The attached spreadsheets include the well names, field, API and PTD
numbers, treatment dates and volumes.
If you have any additional questions, please contact me at 907-777-8406 or
dhorner@hilcorp.com.
Sincerely,
Darci Horner
Regulatory Tech
Hilcorp Alaska, LLC
Digitally signed by Darci Horner
(c-100048)
DN: cn=Darci Horner (c-100048)
Date: 2023.09.29 09:45:20 -
08'00'
Darci Horner
(c-100048)
Well Field API PTD
Initial Top
of Cement
(ft.)
Volume of
Cement
Pumped
(bbls)
Final Top of
Cement (ft.)
Cement
Pump Date
Corrosion
Inhibitor
Fill Volume
(gal)
Final CI Top
(ft.)
Corrosion
Inhibitor
Treatment
Date
Comments
MPB-35 MPU 50029237240000 2220850 14' 0 14' N/A 50 surface 9/27/2023 Drilled Sept/Oct 2022.
MPB-39 MPU 50029237470000 2230120 1'6" 0 1'6" N/A 10 surface 6/10/2023 Drilled Mar 2023.
MPI-20 MPU 50029236790000 2200490 10' 1 1 7/2/2023 5 surface 9/27/2023 Completed Apr 8, 2021.
MPI-29 MPU 50029237080000 2220060 6' 0.5 3 7/2/2023 15 surfce 9/27/2023
Drilled in March 2022. Completeted
on 4/30/22.
MPL-60 MPU 50029236780000 2200480 1' 0 1' N/A 10 surface 6/26/2023 Drilled in 2020.
MPL-62 MPU 50029236850000 2200590 1' 0 1' N/A 10 surface 6/26/2023 Drilled in 2020.
MPM-13 MPU 50029236380000 2190870 20' 3.5 2' 8/2/2023 10 surface 9/27/2023 Drilled in 2019.
MPM-27 MPU 50029237160000 2220490 2' 0 2' N/A 20 surface 6/11/2023 Monobore. Drilled June 2022.
MPM-30 MPU 50029237300000 2221180 1' 0 1' N/A 10 surface 6/11/2023 Drilled in Oct 2022.
MPM-43 MPU 50029236710000 2200200 1' 0 1' N/A 10 surface 6/11/2023 Drilled in 2020.
MPM-62 MPU 50029237440000 2230060 1' 0 1' N/A 10 surface 6/11/2023 Completed May 2023.
MPS-45 MPU 50029236930000 2210420 1' 0 1' N/A 10 surface 6/12/2023 Drilled in June 2021.
MPS-47 MPU 50029236960000 2210470 4' 0 4' N/A 20 surface 6/12/2023 Drilled in August 2021.
Notes:
The 4" conductor outlets are any where from 1 to 3' down from the top of the conductor
Surface Casing by Conductor Annulus Cement Top Job and Fill Coat Corrosion Inhibitor (CI) Applications
Cement to surface means cement is up to the 4" outlets below the wellhead. From the 4" outlets up to the top of conductor was filled with Fill Coat #7
Initial top of cement footage measurement was taken from the 4" outlet down to the TOC
RBDMS JSB 100323
MPB-35 MPU 50029237240000 2220850 14'0 14'N/A 50 surface 9/27/2023 Drilled Sept/Oct 2022.
Kyle Wiseman Hilcorp Alaska, LLC
Geotechnician 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 777-8337
E-mail: Kyle.Wiseman@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Date: 11/4/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20221104
Well API #PTD #Log Date Log
Company Log Type AOGCC Eset#
MPU H-18 50029232240000 204174 10/2/2022 READ COILFLAG
MPU F-01 50029225520000 195045 10/9/2022 READ CaliperSurvey
MPU F-62A 50029226090100 220066 10/12/2022 READ CaliperSurvey
MPU B-35 50029237240000 222085 10/17/2022 READ CaliperSurvey
Please include current contact information if different from above.
T37230
T37231
T27239
T37232MPU B-35 50029237240000 222085 10/17/2022 READ CaliperSurvey
Kayla Junke
Digitally signed by
Kayla Junke
Date: 2022.11.07
16:21:15 -09'00'
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:Rixse, Melvin G (OGC)
To:AOGCC Records (CED sponsored)
Subject:20221102 1410 MPU B-35 (PTD 222-085) New Producer No MIT-T APPROVED
Date:Wednesday, November 2, 2022 2:08:20 PM
From: Rixse, Melvin G (OGC)
Sent: Wednesday, November 2, 2022 2:07 PM
To: Todd Sidoti <Todd.Sidoti@hilcorp.com>
Subject: 20221102 1410 MPU B-35 (PTD 222-085) New Producer No MIT-T APPROVED
Todd,
No action necessary. As you note, the MIT-IA demonstrated tubing integrity.
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).
From: Todd Sidoti <Todd.Sidoti@hilcorp.com>
Sent: Wednesday, November 2, 2022 11:24 AM
To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Subject: MPU B-35 (PTD 222-085) New Producer
Hi Mel,
We recently completed the work approved in Sundry 322-603, which was an ASR tubing swap due to
over-torqued connections from the drilling rig. In this sundry we specified an MIT-IA to 3650 psi to
demonstrate tubing, packer and casing competency. This test was performed and passed. This well
was completed as a three string design where the production tubing with seals stings directly into
the liner hanger. Since no packer was installed (and no ball and rod dropped) we did not perform a
MIT-T. I wanted to be transparent as the original drilling 10-401 for a completion including a packer
also included a MIT-T. Please let me know if you have any questions or if any action is required on
my end.
Thanks,
Todd
Todd Sidoti | Operations Engineer | Hilcorp Alaska | 907-632-4113
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 responsibility
is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate.
1a. Well Status:Oil SPLUG Other Abandoned Suspended
1b. Well Class:
20AAC 25.105 20AAC 25.110 Development Exploratory
GINJ WINJ WDSPL No. of Completions: _1 Service Stratigraphic Test
2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry:
Aband.:
3. Address: 7. Date Spudded: 15. API Number:
4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number:
Surface:
Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s):
GL: 22.9' BF:
Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation:
4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number:
Surface: x- y- Zone- 4
TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD:
Total Depth: x- y- Zone- 4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 N/A (ft MSL)
22.Logs Obtained:
23.
BOTTOM
20" X-56 173'
10-3/4" L-80 2629'
7-5/8" L-80 4494'
4-1/2" L-80 4481'
24. Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr):
Press. 24-Hour Rate
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date perf'd or liner run):
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
CASING, LINER AND CEMENTING RECORD
List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion,
Uncemented Screen Liner6-3/4"
TUBING RECORD
Type I/II9-7/8"
Liner Top Packer
6732'4-1/2" 12.6# L-80
ROP, AGR, DGR, PCG, ABG, EWR, ADR MD & TVD
BOTTOM
13-1/2"
7 yds Concrete
Surface Lead - 912 sx / Tail - 270 sx
13.5#
Surface
6746'
3408'
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Hilcorp Alaska, LLC
WAG
Gas
10/6/2022 222-085 / 322-510 & 322-603
ADL 047438, 047437 & 047433
12' FSL, 4308' FEL, Sec. 18, T13N, R11E, UM, AK
880' FSL, 1940' FEL, Sec. 11, T13N, R10E, UM, AK
12418' / 4481'
12416' / 4481'
56.78'
3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503
571984 6023135
2623' FSL, 2423' FEL, Sec. 13, T13N, R10E, UM, AK Milne Point Field, Schrader Bluff Oil Pool
81-054
50-029-23724-00-00
MPU B-35
9/16/2022
10/1/2022
CASING WT. PER
FT.GRADE CEMENTING RECORD
6025711
SETTING DEPTH TVD
6029208
TOP HOLE SIZE AMOUNT
PULLED
568198
563801
TOP
SETTING DEPTH MD
suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud
log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing
collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary.
N/A
None 2097' / 1792'
Surface
Surface
Per 20 AAC 25.283 (i)(2) attach electronic information
29.7#
12418'
Surface
4485'
129.5#
45.5#
173'
Surface 6898'
SIZE DEPTH SET (MD)
6746' / 4485'
PACKER SET (MD/TVD)
24"/Driven
Flow Tubing
N/A
4-1/2" Screen Liner 10/4/2022
6906' - 7724' 4495' - 4497'
7845' - 8829' 4495' - 4494'
9035' - 9710' 4492' - 4483'
10161' - 12215' 4459' - 4499'
Gas-Oil Ratio:Choke Size:
Sr Res EngSr Pet GeoSr Pet Eng
Oil-Bbl: Water-Bbl:
Water-Bbl:
PRODUCTION TEST
Not on Production
Date of Test: Oil-Bbl:
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
By James Brooks at 9:58 am, Nov 01, 2022
FWL
Completed
10/6/2022
JSB
RBDMS JSB 110222
GDSR-11/3/22MGR12NOV2022
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
27' 27'
2124' 1819'
Top of Productive Interval 6782' 4488'
2521' 2070'
3255' 2532'
5382' 3888'
6185' 4356'
6782' 4488'
6782' 4488'
31. List of Attachments:
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Joe Lastufka
Digital Signature with Date: Monty Myers Contact Email:joseph.lastufka@hilcorp.com
Contact Phone:907-777-8400
Drilling Manager
General:
Item 1a:
Item 1b:
Item 4b:
Item 9:
Item 15:
Item 19:
Item 20:
Item 22:
Item 23:
Item 24:
Item 27:
Item 28:
Item 30:
Item 31:
Schrader Bluff OA
LOT / FIT Data Sheet, Drilling and Completion Reports, Post-Rig Workover Summary, Casing and Cement Reports, Definitive
Directional Surveys, Wellbore Schematic
SV3
SV1
Formation Name at TD:
If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if
needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired.
Schrader Bluff OA
Yes No
Well tested? Yes No
28. CORE DATA
If Yes, list intervals and formations tested, briefly summarizing test results for
each. Attach separate pages if needed and submit detailed test info including
reports and Excel or ASCII tables per 20 AAC 25.071.
NAME
Permafrost - Top
Permafrost - Base
29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment; or 90 days after log acquisition, whichever occurs first.
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Ugnu LA3
Schrader Bluff NA
Authorized Title:
Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic
diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from
a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071.
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core
analysis, paleontological report, production or well test results, per 20 AAC 25.070.
Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
TPI (Top of Producing Interval).
Authorized Name and
INSTRUCTIONS
Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
11.1.2022
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: 2022.11.01 09:40:15 -08'00'
Monty M
Myers
CASING AND LEAK-OFF FRACTURE TESTS
Well Name:MPU B-35 Date:9/22/2022
Csg Size/Wt/Grade:10.75"45.5#, L-80 Supervisor:Demoski / Toomey
Csg Setting Depth:3408 TMD 2629 TVD
Mud Weight:9.5 ppg LOT / FIT Press =342 psi
.
LOT / FIT =12.00 Hole Depth =3433 md
Fluid Pumped=0.8 Bbls Volume Back =0.8 bbls
Estimated Pump Output:0.101 Barrels/Stroke
LOT / FIT DATA CASING TEST DATA
Enter Strokes Enter Pressure Enter Strokes Enter Pressure
Here Here Here Here
->00 ->00
->150 ->4116
->2102 ->8382
->3162 ->12 631
->4220 ->16 892
->5279 ->20 1148
->6310 ->24 1461
->7340 ->26 1600
->8354 ->28 1774
->9 ->30 1905
->10 ->32 2082
->11 ->34 2263
->12 ->36 2420
->13 ->38 2615
Enter Holding Enter Holding Enter Holding Enter Holding
Time Here Pressure Here Time Here Pressure Here
->0354 ->02615
->1319 ->52605
->2303 ->10 2611
->3290 ->15 2607
->4278 ->20 2607
->5268 ->25 2605
->6256 ->30 2603
->7250 ->31 2603
->8241 ->32 2603
->9234 ->33 2603
->10 227 ->34 2603
->11 220 ->35 2603
->12 213 ->
->13 207 ->
->14 201
->15 196
->
0
1
2
3
4
5 6 7 8
0
4
8
12
16
20
24
26
28
30
32
34
36
38
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
010203040
Pr
e
s
s
u
r
e
(
p
s
i
)
Strokes (# of)
LOT / FIT DATA CASING TEST DATA
Pr
e
s
s
u
r
e
(
p
s
i
)
354319303290278268256250241234227220213207201196
2615 2605 2611 2607 2607 2605 260326032603260326032603
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 35
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:MPU B-35 Date:9/27/2022
Csg Size/Wt/Grade:7.625"45.5#, L-80 Supervisor:Demoski / Toomey
Csg Setting Depth:6897.51 TMD 4494 TVD
Mud Weight:9.5 ppg LOT / FIT Press =584 psi
.
LOT / FIT =12.00 Hole Depth =6927 md
Fluid Pumped=0.9 Bbls Volume Back =0.7 bbls
Estimated Pump Output:0.101 Barrels/Stroke
LOT / FIT DATA CASING TEST DATA
Enter Strokes Enter Pressure Enter Strokes Enter Pressure
Here Here Here Here
->00 ->00
->1 131 ->2164
->2 176 ->4299
->3 220 ->6478
->4 260 ->8644
->5 321 ->10 781
->6 375 ->13 1070
->7 438 ->16 1262
->8 515 ->19 1558
->9 587 ->22 1803
->10 ->25 2078
->11 ->27 2213
->12 ->29 2386
->13 ->32 2655
Enter Holding Enter Holding Enter Holding Enter Holding
Time Here Pressure Here Time Here Pressure Here
->0 587 ->0 2667
->1 541 ->1 2658
->2 538 ->2 2652
->3 535 ->3 2646
->4 531 ->4 2642
->5 530 ->5 2639
->6 529 ->10 2626
->7 527 ->15 2617
->8 525 ->20 2609
->9 524 ->25 2603
->10 523 ->30 2600
->11 522 ->
->12 521 ->
->13 519 ->
->14 514
->15 512
->
0
1
2
3 4
5
6
7
8
9
0
2
4
6
8
10
13
16
19
22
25
27
29
32
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 10203040
Pr
e
s
s
u
r
e
(
p
s
i
)
Strokes (# of)
LOT / FIT DATA CASING TEST DATA
Pr
e
s
s
u
r
e
(
p
s
i
)
587
541538535531530529527525524523522521519514512
266726582652264626422639 2626 2617 2609 2603 2600
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 35
Pr
e
s
s
u
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(p
s
i
)
Time (Minutes)
LOT / FIT DATA CASING TEST DATA
_____________________________________________________________________________________
Revised By: JNL 10/31/2022
SCHEMATIC
Milne Point Unit
Well: MPU B-35
Last Completed: 10/6/2022
PTD: 222-085
TD =12,418’(MD) / TD =4,481’(TVD)
4
20”
Orig. KB Elev.: 56.6’ / GL Elev.: 22.9’
7-5/8”
5
4
7
10-3/4”
1
2
3
See
Screen/
Solid
Liner
Detail
PBTD =12,416’(MD) / PBTD = 4,481’(TVD)
7 5, 612
4-1/2”
3
2
7-5/8”
JEWELRY DETAIL
No. MD Item ID
1 Surface 4-1/2” TC-II Tubing Hanger 4.500”
2 6,077’ Haliburton X-Line Sliding Sleeve, 3.813” X Profile (opens down) 3.813”
3 6,144’ Baker Gauge Carrier 3.865”
4 6,211’ XN Nipple, 3.813” with 3.725” No-Go 3.725”
5 6,746’ 7-5/8” x 5-1/2” ZXP Liner Top Packer 4.890”
6 6,769’ Flex-Lock V Liner Hanger 6.180”
7 12,416’ Shoe 3.800”
TREE & WELLHEAD
Tree Cameron 3-1/8" 5M w/ 3-1/8” 5M Cameron Wing
Wellhead FMC 11” 5K x sliplock bottom w/ (2) 2-1/16” 5K outs
OPEN HOLE / CEMENT DETAIL
24”/Driven 7 yds Concrete
13-1/2" Lead – 912 sx / Tail – 270 sx
9-7/8” Tail – 346 sx
6-3/4” Uncemented Screen Liner
CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm BPF
20" Conductor 129.5 / X56 / Weld N/A Surface 173’ N/A
10-3/4" Surface 45.5 / L-80 / TXP 9.950 Surface 3,408’ 0.0962
7-5/8” Intermediate 29.7 / L-80 / TXP 6.875 Surface 6,898’ 0.0459
4-1/2” Liner 100ђ Screens 13.5 / L-80 / Hyd 625 3.920 6,746’ 12,418’ 0.0149
TUBING DETAIL
4-1/2" Tubing 12.6# / L-80 / TXP 3.958 Surface 6,732’ 0.0152
WELL INCLINATION DETAIL
KOP @ 250’
90° Hole Angle = @ 7,075’
4-1/2”SCREENS LINER DETAIL
Jts Top
(MD)
Top
(TVD)
Btm
(MD)
Btm
(TVD)
20 6906’ 4495’ 7724’ 4497’
24 7845’ 4495’ 8829’ 4494’
17 9035’ 4492’ 9710’ 4483’
51 10161’ 4459’ 12215’ 4499’
GENERAL WELL INFO
API: 50-029-23724-00-00
Completion Date: 10/6/2022
TOC 5685' MD
Activity Date Ops Summary
9/15/2022 Pull the rig onto the mat boards, jockey and align the rig into position, notify the DSO, back and spot the rig over B-35. Remove additional mats from around 36,
perform B-36 post pad inspection with DSO. Shim and level the rig. Secure the stair handrails and landings. Roads and pads build up the end of the pad on DS
front of the rig to allow egress off the front stairs. PJSM. Skid the rig floor into drilling position. RU the rig floor. Spot auxiliary buildings. Start loading the ODS pipe
shed with 5" DP. Rig on highline power at 16:00 hours. Begin to NU the diverter line. Install the 90' mouse hole. Spot the slop tank, rock washer and fuel trailer.
Load the surface hole BHA into the DS pipe shed. NU the diverter tee and annular. NU the diverter riser on top of the annular. Install riser extension. SimOps:
Continue to load and process 5" DP on the ODS pipe shed. Set pump house, up right water tanks and cement silos.
9/16/2022 Continue to RU and work on inspection checklist. Continue to NU the diverter line. Inspect saver sub and grabber dies (good). Inspect and service top drive. Take
on water to upright tank. Circulate lines in pits with water. Take on 580 bbls 8.8 ppg spud mud into the pits. Power up accumulator. Get totco up and running in
Sperry and MI shacks. Continue and finish NU diverter line. Set spill containment at EOD and place warning signs. Strap and tally HWDP. Work on acceptance
checklist. MU and rack back 6 stands 5" HWDP including jar stand. Perform the diverter function test with 5" HWDP. The states right to witness was waived by
AOGCC inspector Austin McLeod on 9/14/22 at 19:17 hours. Knife valve opened in 21 seconds and the annular closed in 28 seconds. Accumulator Test: System
pressure = 3,000 psi. Pressure after closure = 1,800 psi. 200 psi attained in 35 seconds. Full pressure attained in 165 seconds. Nitrogen Bottles - 6 at 2,000 psi
(average). Rig electrician calibrated and tested the rig gas alarms (passed). Test Totco PVT sensors and alarms (passed). Diverter length = 198'. Nearest ignition
source is Sperry shack light at 78' way from the end of the diverter. PJSM. Slip and cut 60' drilling line. Calibrate the blocks. Mobilize bit and crossover to the rig
floor. Pre-spud meeting with all parties involved. Discuss well objectives and surface hole hazards. PJSM for PU BHA. PU and MU 13-1/2" Kymera bit, 8" mud
motor with 1.5° bend and crossover to 35'. Fill stack with water and check for leaks (none). Fill lines with water and PT mud lines to 3,500 psi (good test). Tag fill in
conductor at 58'. Rig accepted at 21:30 hours Cleanout the 20" conductor from 58' to 173' at 400 GPM = 380 psi, 30 RPM = 1-2K ft-lbs TQ Drill 13-1/2" surface
hole from 173' to 197' (197' TVD). Drilled 24' = 48'/hr AROP. 400 GPM = 410 psi, 30 RPM = 1-3K ft-lbs torque, WOB = 4-6K, PU = 50K, SO = 50K, ROT = 48K.
MW = 8.8 ppg, Vis = 255, Drag chain #1 stopped operating and packed off with cuttings. Decision was made to TOOH since we had enough footage drilled to be
able to MU the remaining BHA while a super sucker cleaned out the drain chain and got it operational again. TOOH from 197' to surface. The bit balled up with clay.
Clean and inspect the bit (good). MU MWD tools with GWD, directional, gamma, resistivity and PWD to 97'. Initialize MWD tools. MU 2 NMFC and crossover to
159'. Shallow pulse test MWD (good). Wash and ream down to 197'. Drill 13-1/2" surface hole from 197' to 290' (290' TVD). Drilled 93' = 62'/hr AROP. 400 GPM =
810 psi, 30 RPM = 2-3K ft-lbs torque, WOB = 1-5K, PU = 65K, SO = 63K, ROT = 63K. MW = 9.0+ ppg, Vis = 304, ECD = 9.7 ppg Daily disposal to G&I = 57 bbls
Total disposal to G&I = 57 bbls. Daily water hauled from A-pad = 165 bbls Total water hauled from A-pad = 165 bbls. Daily fluid loss = 0 bbls Total fluid loss = 0
bbls. Daily metal recovered = 0 lbs Total metal recovered = 0 lbs.
9/17/2022 Drill 13-1/2" surface hole from 290' to 712' (708' TVD). Drilled 422' = 105.5'/hr AROP. 450 GPM = 1225 psi, 40 RPM = 4K ft-lbs TQ, WOB = 8-13K, PU = 80K, SO
= 80K, ROT = 80K. MW = 9.2+ ppg, Vis = 95, ECD = 10.1 ppg, max gas units = 0. At 500' build 3 deg/100'. #1 drag chain rolled off the front sprocket, CBU, shut
down pumps and work pipe while Rig mechanic re-installed the chain back on the sprocket and adjust the chain tension, test run same, good. Drill 13-1/2" surface
hole from 712' to 1,257' (1,234' TVD). Drilled 545' = 77.86'/hr AROP. 450 GPM =1,260 psi, 40 RPM = 5K ft-lbs TQ, WOB = 10-12K, PU = 87K, SO = 87K, ROT =
86K. MW = 9.2+ ppg, Vis = 82, ECD = 10.09 ppg, max gas units = 0 At 750' build 4°/100'. Last Gyro survey at 1,052'. First clean MWD at 1,134'. Drill 13-1/2"
surface hole from 1,257' to 1,663' (1,533' TVD). Drilled 76' = 62.67'/hr AROP. 450 GPM =1,450 psi, 40 RPM = 3-6K ft-lbs TQ, WOB = 15-18K, PU = 95K, SO =
86K, ROT = 91K. MW = 9.2 ppg, Vis = 99, ECD = 10.39 ppg, max gas units = 0. Maintain build 4°/100' Drill 13-1/2" surface hole from 1,663' to 2,233' (1,887'
TVD). Drilled 570' = 95'/hr AROP. 500 GPM =1 ,710 psi, 60 RPM = 5K ft-lbs TQ, WOB = 8K, PU = 105K, SO = 87K, ROT = 97K. MW = 9..4+ ppg, Vis = 69, ECD
= 10.43 ppg, max gas units = 0 Maintain build 4°/100' to 1,800'. Hold 51° tangent. Pump 30 bbl hi-vis sweep at 2,044' sweep back on time with 20% increase. Last
survey at 1,991.93’ MD / 1,736.12’ TVD, 50.91° INC, 303.66° AZM. Distance from WP15 = 11.62’, 11.24’ high & 2.95’ left. Daily disposal to G&I = 1,653 bbls Total
disposal to G&I = 1,710 bbls. Daily water hauled from A-pad = 1,285 bbls Total water hauled from A-pad = 1,450 bbls. Daily fluid loss = 0 bbls Total fluid loss = 0
bbls. Daily metal recovered = 0 lbs Total metal recovered = 0 lbs.
9/18/2022 Drill 13-1/2" surface hole from 2,233' to 2,518' (2,068' TVD). Drilled 285' = 114'/hr AROP. 532 GPM =1 ,840 psi, 60 RPM = 5-7K ft-lbs TQ, WOB = 5-10-K, PU =
115K, SO = 82K, ROT = 100K. MW = 9.5, ppg, Vis = 62, ECD = 10.89 ppg, max gas units = 0. Continue to hold 51° tangent. Note: the Geo reports BOPF logged at
2,124' (1,818' TVD). Perform cleanup cycle. Pump 30 bbl hi vis sweep around 540 gpm, 1800 psi, 60 rpm, 5-7k torque, working the pipe 90' cleaning up the
wellbore. Sweep back 300 stks early at 100% increase and lowering the ECD from 10.9 to 10.46 ppg. Drill 13-1/2" surface hole from 2,518' to 2,804' (2,249' TVD).
Drilled 286' = 95.3'/hr AROP. 525 GPM =1890 psi, 60 RPM = 6-8K ft-lbs TQ, WOB = 5-11K, PU = 118K, SO = 95K, ROT = 102K. MW = 9.6, ppg, Vis = 82, ECD
= 10.72 ppg, max gas units = 479. Continue to hold 51° tangent. Crossed Fault #1 at 2,511' (2,063' TVD) with 40' throw DTE, SV3 logged at 2,521' (2,071' TVD)
and the SV2 at 2,799' (2,248' TVD) Drill 13-1/2" surface hole from 2,804' to TD at 3,413' (2,632' TVD). Drilled 609' = 93.7'/hr AROP. 525 GPM =1,810 psi, 80 RPM
= 7-9K ft-lbs TQ, WOB = 6-8K, PU = 133K, SO = 92K, ROT = 108K. MW = 9.5 ppg, Vis = 93, ECD =10.18 ppg, max gas units = 51 Obtain final survey at
3,413.00’ MD / 2,632.65’ TVD, 50.67° INC, 302.79° AZM. Distance from WP15 = 13.36’, 12.33’ high & 5.14’ left. SV1 logged at 3,255' (2,532' TVD) Pump 30 bbl hi-
vis sweep and circulate out of the well at 530 GPM = 1,620 psi, 60 RPM = 6-9K ft-lbs TQ reciprocating 50'. Back on time with 0% increase. Continue to circulate
and condition the mud at 530 GPM = 1,600 psi, 60 RPM = 6-11K ft-lbs TQ reciprocating 93'. Wash back to TD at 3,413' (no fill). Observe the well for flow (static).
SimOps: Mobilize 49 centralizers (13-1/2" x 10-3/4") and crossover (10-3/4" BTC x 4-1/2" IF) to the rig floor. BROOH from 3,413' to 2,626' pulling 5-10
minutes/stand slowing as needed to clean up slides/tight spots. 500 GPM = 1,400 psi, 60 RPM = 7-10K ft-bs TQ, max gas units = 0. PU = 128K, SO = 85K, ROT =
102K BROOH from 2,626' to 714' (HWDP) pulling 5-10 minutes/stand slowing as needed to clean up slides/tight spots. 500 GPM = 1,400 psi, 60 RPM = 7-10K ft-
bs TQ, max gas units = 25. PU = 128K, SO = 85K, ROT = 102K. Observe the well for flow (static). TOOH on elevator from 714' to 159'. Daily disposal to G&I =
1,844 bbls Total disposal to G&I = 3,554 bbls. Daily water hauled from A-pad = 1,770 bbls Total water hauled from A-pad = 3,220 bbls. Daily fluid loss = 0 bbls
Total fluid loss = 0 bbls. Daily metal recovered = 0 lbs Total metal recovered = 0 lbs.
50-029-23724-00-00API #:
Well Name:
Field:
County/State:
MP B-35
Milne Point
Hilcorp Energy Company Composite Report
, Alaska
9/16/2022Spud Date:
9/19/2022 LD BHA #1, LD BN XO, 2 NMFCs from 159' to 97', read MWD, LD remaining BHA,.13 1/2'' Kymera bit grade: cones= 1-1-BU-A-E-I-WT-TD & cutters= 1-2-BT-G-X-
I-BU-TD. Normal wear on ILS and motor stab from BR and drilling. 65 bbl losses BROOH. Clear BHA components and clean the rig floor. Monitor well, Loss rate 0.5
BPH loss rate. RU the volante tool, bail extensions, 10 3/4'' handling equipment and DDI casing tongs. Ready FOSV and XO. Loss rate 0.5 BPH loss rate. PJSM.
PJSM. MU 10 3/4", 45.5#, L-80, TXP-BTC shoe track. Bakerlok 1-4 connections with 22,600 ft/lbs tq. Pump thru shoe track and check floats (good). RIH with 10-
3/4", 45.5#, L-80, TXP-BTC casing from 204' to 2,910' (PU = 173K & SO = 95K). TQ = 22,600 ft-lbs with Volant tool. Fill on the fly and top off every 10 joints.
Installing centralizer per tally. Loss rate = 4 BPH RIH with 10-3/4", 45.5#, L-80, TXP-BTC casing from 2,910' to 3,409' washing the last 2 joints down at 3 BPM =
200 psi (no fill observed). TQ = 22,600 ft-lbs with Volant tool. Fill on the fly and top off every 10 joints. Installing centralizer per tally. PU = 180K & SO = 80K Stage
the pumps to 7 BPM = 310 psi (ICP). Set the TQ at 20K ft-lbs and establish rotation at 2 RPM reciprocating 30'. Continue to circulate and condition the mud for
cementing at 7 BPM = 170 psi FCP. MW = 9.5 ppg in/out & YP = 13. SimOps: Spot and RU cementers. Blow air to the cement unit. PJSM. Shut down, break out
the Volant tool, re-dope cup and blow down top drive. Make back up to casing. Blow down the top drive. RU cement lines. Close upper and lower IBOP. Continue
to circulate at 7 BPM =. Empty pits 1, 2 & 3. Pre-treat last 50 bbls pumped from the rig ahead of the cement with CF Desco/SAPP/Bicarb. HES pump 5 bbls of
fresh at 3 BPM and PT lines to 1,000/4,000 psi (good test). Daily disposal to G&I = 492 bbls Total disposal to G&I = 4,046 bbls. Daily water hauled from A-pad =
265 bbls Total water hauled from A-pad = 3,485 bbls. Daily fluid loss = 54 bbls Total fluid loss = 54 bbls. Daily metal recovered = 0 lbs Total metal recovered = 0
lbs.
9/20/2022 Pump cement job as follows: 60 bbls 10 ppg Tuned spacer with 4# red dye & 5 lb/bbl poly flake (1st 10 bbls) 4.5 BPM = 250 psi. Drop bottom plug Mix & Pump 463
bbls (912 sxs, 2.883 ft^3/sk) 10.7 ppg Arctic Cem Lead cement, 5.5 BPM = 550 psi. 56 bbls (270 sx) 15.8 ppg HalCem Type I II Tail cmt, 1.17 yld, 4.2 BPM = 500
psi. Drop shutoff plug. Displace with 20 bbls H2O from cement Unit 5 BPM = 320 psi Rig displaced (MP #2) with 292.3 bbls 9.5 ppg spud mud, 5 BPM = 190 psi
ICP, Slowed last 10 bbls to 3 BPM = 440 FCP. Bumped the plug 3.7 BBLS early, pressure up to 950 psi, hold 5 minutes, float held. CIP @ 09:09 HRS. 60 BBLS
spacer and 126 BBLS good cement returned to surface, no losses. Rotate and reciprocate the entire job parking on depth at 3408' Disconnect accumulator lines to
the knife valve. Flush surface equipment with black water while functioning annular. BD surface lines and drain stack. Set slips, breakout and L/D volante, RD
casing equipment. ND diverter stack. Lift the stack and set 10-3/4" casing slips as per WHR with 100K set on slips. Vac out landing jt. Make rough cut and dress
stump (18.89') LD cut joint. SimOps: Empty and clean in the pits, load out casing equipment. ND diverter riser, annular and tee with knife valve. ND the diverter
line. Remove riser and tee with knife valve from the cellar. SimOps: Continue to clean pits. Mobilize the wellhead into the cellar. NU the slip lock casing head. PT
the void to 500 psi for 5 minutes and 2,000 psi for 10 minutes (good test). NU the tubing head. Set the BOP stack on the wellhead. Unbolt the spacer spool from
the bottom of the stack. Set the stack back onto the pedestal. Unbolt the spacer spool from the adapter spool and remove the spacer spool from the cellar. NU the
adapter spool to the well head and NU the BOP stack to the adapter spool. Install MPD riser. Obtain RKB's. SimOps: Load the pits with 9.5 ppg LSND mud.
Mobilize test plug, long wear ring and wear ring running tool to the rig floor. Install the test plug in the casing head. Change UPR from 2-7/8" x 5" VBR's to 7-5/8"
solid body.
9/21/2022 Install 4" test joint and R/U test equipment. Fill stack with water, close annular and purge lines. Perform shell test to 250 PSI low / 3,000 PSI high - good. Conduct
initial BOPE test to 250/3,000 psi: UPR (7-5/8” solid body) with 7-5/8” test joint. LPR (2-7/8” x 5” VBR’s) with 4” & 5” test joints, annular with 4” test joint,
accumulator drawdown test and test gas alarms. All tests performed with fresh water against test plug. The states right to witness was waived by AOGCC inspector
Kam St. John via email on 9/19/22 at 18:17 hours. Tests: #1) Annular on 4" test joint, choke valves 1, 12, 13, 14 & 20. #2) Lower 2-7/8"x5" VBR on 4" test joint &
dart valve. #3) Upper 7-5/8" FBR on 7-5/8" test joint, choke valves 9 & 11, HCR kill & FOSV. #4) Choke valves 5, 8, 10, manual kill & upper IBOP. #5) Choke valves
4, 6, 7 & lower IBOP. #6) Choke valve 2. #7) HCR choke. #8) Manual choke #9) Lower 2-7/8"x5" VBR on 5" test joint. #10) Blind rams & choke valve #3. #11)
Manual choke "B". #12) Super choke "A". Accumulator Test: System pressure = 3,050 psi. Pressure after closure = 1,700 psi. 200 psi attained in 37 seconds. Full
pressure attained in 182 seconds. Nitrogen Bottles - 6 at 1,983 psi RD BOP testing equipment. Pull test plug and install 10" I.D. wear bushing. Install 5" elevators.
Break down FOSV and dart valve from test stand. Clear rig floor. Install Mobilize BHA components to the rig floor. Install 90' mousehole extension and short
mousehole. PJSM for making up BHA with all parties involved. MU 9-7/8" intermediate drilling assembly. PU 9-7/8" Kymera bit, 6.75" mud motor with 1.5° AKO,
MWD DM, DGR, ADR, ILS, PWD and TM to 99'. Plug in, test and initialize MWD tools. PU 3 flex collars to 187'. TIH with 6 stands of 5" HWDP including jar to
742'. TIH with intermediate BHA on 5" DP from 742' to 2,166'. Shallow pulse test MWD at 430 GPM = 840 psi. Blow down the top drive TIH with BHA on 5" DP from
2,166' to 3,216'. Wash down from 3,216' to tag on TOC at 3,268' at 4 BPM = 410 psi. PU = 145K, SO = 85K & ROT = 105K. Circulate and condition the mud at
300 GPM = 700 psi, 20 RPM = 5-10K ft-lbs TQ reciprocating 50'. Stand back 1 stand. RU testing equipment. PU to 3,279' to space out for the LPR Purge air from
the lines. Close LPR. PT the 10-3/4" casing to 2,500 psi for 30 minutes charted (good test). Open LPR. RD and blow down testing equipment. Drill cement from
3,268' to 3,282' at 400 GPM = 1,220 psi, 40 RPM = 9K ft-lbs TQ, WOB = 4-10K. Drill 9-5/8" shoe track and cement from 3,282' to 3,408' (all equipment on depth)
at 450 GPM = 1,410 psi, 40 RPM = 5-10K ft-lbs TQ, WOB =10K Cleanout the rat hole from 3,408 to 3,413'. Ream through the float collar and shoe 3 times each.
Drill 20' of new formation from 3,413' to 3,433' (2,644' TVD) at 450 GPM =1,380 psi, 50 RPM = 7-10K ft-lbs TQ, WOB = 5K. Daily disposal to G&I = 57 bbls Total
disposal to G&I = 5,917 bbls. Daily water hauled from A-pad = 145 bbls Total water hauled from A-pad = 4,070 bbls. Daily fluid loss = 0 bbls Total fluid loss = 54
bbls. Daily metal recovered = 0 lbs Total metal recovered = 0 lbs.
9/22/2022 PJSM. Perform flow check - static. Pump 30 bbl high vis spacer. Displace with new 9.5 ppg LSND mud. Dump returns to the rock washer. After new mud out bit and
in the open hole, rack back stand to 3,404' then finish displacement in the 10-3/4" casing. Perform flow check - static. Blow down top drive. Space out and close
lower 2-7/8" x 5" VBR on 5" drill pipe. Rig up and purge lines. Pump through cement line to OA and down drill pipe. Attempt FIT to 12.0 ppg with 9.5 ppg MW at
3,408' MD / 2,629' TVD shoe depth. 342 PSI applied at surface. Perform test twice, first test looked like air in the system. Pumped 0.8 bbls and bled back 0.8 bbls.
Pressure began to deviate at 279 PSI = 11.5 ppg FIT. Sent to engineer and AOGCC approved proceeding with 11.5 ppg FIT. Obtain new slow pump rates. Drill 9-
7/8" intermediate hole from 3,433' to 3,688' (2,807' TVD). Drilled 255' = 102'/hr AROP. 575 GPM = 1,590 psi, 60 RPM = 8K ft-lbs TQ, WOB = 8K, PU = 145K, SO
= 88K & ROT = 110K. MW= 9.5 ppg, Vis = 43, ECD = 10.24 ppg, max gas units = 26. Maintain 51° tangent. Drill 9-7/8" intermediate hole from 3,688' to 4,530'
(3,345' TVD). Drilled 842' = 140.33'/hr AROP. 575 GPM = 1,690 psi, 80 RPM = 7-10K ft-lbs TQ, WOB = 8K, PU = 155K, SO = 99K & ROT = 119K. MW= 9.4+
ppg, Vis = 40, ECD = 10.27 ppg, max gas units = 26. Maintain 51° tangent. Pumped 30 bbls hi-vis sweep at 4,451' back 100 strokes early with 80% increase. Drill
9-7/8" intermediate hole from 4,530' to 4,737' (3,477' TVD). Drilled 207' = 103.5'/hr AROP. 575 GPM = 1,830 psi, 80 RPM = 10-12K ft-lbs TQ, WOB = 10-12K, PU
= 162K, SO = 99K & ROT = 124K. MW= 9.4 ppg, Vis = 40, ECD = 10.34 ppg, max gas units = 0. Maintain 51° tangent. Greased the wash pipe at 4,546'.
Changeout the wash pipe. Drill 9-7/8" intermediate hole from 4,737' to 5,022' (3,658' TVD). Drilled 285' = 95'/hr AROP. 570 GPM = 1,870 psi, 80 RPM = 10-12K ft-
lbs TQ, WOB = 10-15K, PU = 163K, SO = 100K & ROT = 124K. MW= 9.4 ppg, Vis = 39, ECD = 10.32 ppg, max gas units = 50. Maintain 51° tangent. Drill 9-7/8"
intermediate hole from 5,022' to 5,689' (4,079' TVD). Drilled 667' = 111.17'/hr AROP. 565 GPM = 1,980 psi, 80 RPM = 11-13K ft-lbs TQ, WOB = 5-15K, PU =
183K, SO = 104K & ROT = 130K. MW= 9.7 ppg, Vis = 40, ECD = 10.55 ppg, max gas units = 227. Maintain 51° tangent. Pump 30 bbl hi-vis sweep at 5,308', back
on time with 100% increase. Top of Ugnu L-sands logged at 5,382' (3,904' TVD). Last survey at 5,548.90’ MD / 3,992.48’ TVD, 51.71° INC, 309.25° AZM. Distance
from WP15 = 4.1’, 3.92’ high & 1.2’ right. Daily disposal to G&I = 839 bbls Total disposal to G&I = 6,756 bbls. Daily water hauled from A-pad = 495 bbls Total
water hauled from A-pad = 4,565 bbls. Daily fluid loss = 0 bbls Total fluid loss = 54 bbls. Daily metal recovered = 0 lbs Total metal recovered = 0 lbs.
9/23/2022 Drill 9-7/8" intermediate hole from 5,689' to 6,205' (4,356' TVD), Drilled 516' = 86'/hr AROP. 575 GPM = 1,970 PSI, 80 RPM = 11-15K ft-lbs TQ, WOB = 15K. PU=
205K, SO = 100K & ROT = 130K. MW = 9.6 ppg, Vis = 38 vis, ECD = 10.20 ppg, max gas units = 227 . Began 4°/100' build at 5,890'. Drill 9-7/8" intermediate hole
from 6,205' to 6,545' (4,467' TVD), Drilled 340' = 56.67'/hr AROP. 565 GPM = 2,160 PSI, 80 RPM = 14-16K ft-lbs TQ, WOB = 14K. PU= 205K, SO = 102K & ROT
= 137K. MW = 9.6 ppg, Vis = 42 vis, ECD = 10.52 ppg, max gas units = 352 Continue to build at 4°/100'. Top of the NB sand at 6,240' (4,379' TVD). Top of the NC
sand at 6,286' (4,396' TVD) Drill 9-7/8" intermediate hole from 6,545' to 6,830' (4,493' TVD), Drilled 285' = 47.5'/hr AROP. 569 GPM = 2,220 PSI, 80 RPM = 15-
16K ft-lbs TQ, WOB = 4-5K. PU= 205K, SO = 97K & ROT = 132K. MW = 9.8 ppg, Vis = 41 vis, ECD = 10.77 ppg, max gas units = 50 Continue to build at 4°/100'.
Top of the OA sand at 6,782' (4,488' TVD) Drill 9-7/8" intermediate hole from 6,830' to TD at 6,907' (4,494' TVD), Drilled 77' = 77'/hr AROP. 500 GPM = 1,920 PSI,
80 RPM = 15-16K ft-lbs TQ, WOB = 4-5K. PU= 205K, SO = 100K & ROT = 132K. MW = 9.8 ppg, Vis = 41 vis, ECD = 10.6 ppg, max gas units = 277 Obtain final
survey. BROOH racking back 2 stands from 6,907' to 6,735'. Final survey at 6,860.53’ MD / 4,492.58’ TVD, 87.08° INC, 311.56° AZM. Distance from WP15 =
10.51’, 8.29’ low & 6.46’ left. Pump 30 bbl hi-vis sweep and circulate out the well at 575 GPM = 2,150 psi, 80 RPM = 15-16K ft-lbs TQ reciprocating 93'. Sweep
back 500 strokes early with 80% increase. Wash back to TD at 6,907'. Observe the well for flow and the well is static. BROOH from 6,907' to 6,259' pulling 5-10
minutes/stand slowing as needed to clean up slides/tight spots. 575 GPM = 2,050 psi, 80 RPM = 16K ft-bs TQ, max gas units = 50. PU = 205K, SO = 100K, ROT
= 130K Daily disposal to G&I = 808 bbls Total disposal to G&I = 7,564 bbls. Daily water hauled from A-pad = 680 bbls Total water hauled from A-pad = 5,245 bbls.
Daily fluid loss = 0 bbls Total fluid loss = 54 bbls. Daily metal recovered = 0 lbs Total metal recovered = 0 lbs.
9/24/2022 BROOH from 6,259' to 3,404' pulling 5-10 minutes/stand slowing as needed to clean up slides/tight spots. Laying down drill pipe from the mousehole. 575 GPM =
1,950 PSI, 80 RPM = 12-15K TQ, max gas units = 50, MW = 9.65, Vis =42 Vis, ECD = 10.72. PU = 145 = 82K, ROT = 104K. 8 BPH avg losses, 94.8 bbls total lost
BROOH. Pump 30 bbl high vis sweep to clean the 10-3/4" casing. 575 GPM = 1850 PSI, 40 RPM = 5-9K TQ. 9.7 MW, 40 Vis, 10.52 ECD. Sweep back 200
strokes early with 50% increase. Perform flow check (static) then pump dry job and blow down the top drive. POOH laying down 5" drill pipe, HWDP and jar from
3,404' to 184'. Lost 17.2 bbls while laying down DP/HWDP. Average loss rate = 3.44 BPH Lay down 3 NMFC to 98'. Download MWD data. Lay down remaining
BHA. PDC grade: 1-2-LT-G-X-1-CT-TD. Tri-cone grade: 1-1 WT-A-E-1-NO-TD. Observed wear on top/bottom edge of ADR stabilizer - 1/16” under. Observe wear
on top/bottom edge of Integral Blade Stabilizer. Clean and clear the floor. MU the wear ring pulling tool to a joint of DP and pull the wear ring. Lay down the wear
ring pulling tool and wear ring. Jet the BOP stack. Mobilize casing running equipment and 30 bow spring centralizers to the rig floor. RU Volant CRT, bail
extensions with side door elevator and spider slips. RU strap backup tongs. RU single stack casing tongs. Static loss rate = 3 BPH PJSM. MU 7-5/8", 29.7#, L-80,
TXP-BTC shoe track to 163'. Pump through the shoe track and check floats (good). RIH with 7-5/8", 29.7#, L-80, TXP-BTC casing from 163' to 685'. TQ = 17,740
ft-lbs with the Volant CRT. Fill on the fly and top off every 10 joints. Installing centralizers per tally. Loss rate = 3 BPH Daily disposal to G&I = 517 bbls Total
disposal to G&I = 8,081 bbls. Daily water hauled from A-pad = 375 bbls Total water hauled from A-pad = 5,620 bbls. Daily fluid loss = 112 bbls Total fluid loss =
166 bbls. Daily metal recovered = 0 lbs Total metal recovered = 0 lbs.
9/25/2022 RIH with 7-5/8", 29.7#, L-80, TXP-BTC casing from 685' to 3,404'. TQ = 17,740 ft-lbs with the Volant CRT. Fill on the fly and top off every 10 joints. PU = 100K,
SO = 45K. Losses running csg to this depth = 42.2 bbls Circulate and condition the mud at the 10-3/4" casing shoe. Observe higher than expected pressure, 580
PSI at 1 BPM. Start rotary at 10 RPM = 8k TQ. Observing 50% losses, increase to 3 BPM = 550 PSI in 1/2 bbl increments. Reciprocating pipe slowly. At 1020 stks
began to see clabbered up mud with 12.5 pH. Start treating mud and adding water at 60 BPH. Returns cleaned up then staged up to 6.0 BPM = 140 PSI. MW = 9.6,
Vis = 42, pH = 9.3, YP = 14. Losses stabilized at 8 BPH. 44 bbls lost while circulating. Added 0.5% 776 lube. RIH with 7-5/8", 29.7#, L-80, TXP-BTC casing from
3,404' to 4,418'. TQ = 17,740 ft-lbs with the Volant CRT. Fill on the fly and top off every 10 joints. PU = 145K, SO = 85K. Losses running csg to this depth = 46.4
bbls. Circulate and condition the mud at 4,418'. Stage up pumps to 6 BPM = 190 PSI. Rotate 10 RPM = 10k. Saw thick clabbered mud with 11.7 pH which cleaned
up after bottoms up. Mud in MW = 9.65, vis = 41, pH = 9.3, mud out MW = 9.75, vis = 212, pH = 10.8. PU = 162K, SO = 104K. 12 BPH losses. RIH with 7-5/8",
29.7#, L-80, TXP-BTC casing from 4,418' to 5,817'. TQ = 17,740 ft-lbs with the Volant CRT. Fill on the fly and top off every 10 joints. Break circulation at 2 BPM =
240 psi. Circulate and condition the mud staging the pumps up to 6 BPM = 300 psi (ICP) & 270 psi (FCP), 5 RPM = 11K ft-lbs TQ. Mud in MW = 9.7+, Vis = 48,
pH = 9.3, mud out MW = 9.7, vis = 46, pH = 9.3. PU = 208K, SO = 114K. No losses while circulating. RIH with 7-5/8", 29.7#, L-80, TXP-BTC casing from 5,817' to
6,860'. (joint #171) TQ = 17,740 ft-lbs with the Volant CRT. Fill on the fly and top off every 10 joints. Lost 52.8 bbls while running casing MU joint #172. Break
circulation at 2 BPM = 240 psi. Circulate and condition the mud staging the pumps up to 6 BPM = 360 psi (ICP) & 240 psi (FCP), 5 RPM = 11K ft-lbs TQ.
Reciprocating from 6,860' to 6,898'. PJSM with all parties involved. Break out the volant and dope the cup. Lay down joint #172. PU and MU the casing mandrel
hanger with landing joint. Pump 5 bbls of water and PT lines to 1,000/4,000 psi. On the high PT the cement line chiksan swivel began leaking. Changeout cement
line chiksan swivel.
9/26/2022 Finish changing out chiksan swivel on cement line. RU cement line to Volant tool. Pump 5 bbls water & pressure test lines to 1000 psi low and 4000 psi high - good
test. Mix and pump 60 bbls of 11.0 ppg Tuned Spacer, 4.3 BPM = 200 psi ICP, 370 psi FCP. Drop bottom plug. Mix and pump 71 bbls of 15.8 ppg Type I/II cement
(346 sxs at 1.154 ft^3/sk), 3.5 BPM = 470 psi ICP, 400 spi FCP Drop top plug. Chase with 20 bbls water, 5 BPM = 250 psi. Displace from rig with 290.48 bbls 9.7
ppg LSND mud, 6 BPM = 170 psi ICP, 610 psi FCP before slowing to 3 BPM. Reciprocate pipe 23', PU = 245K, SO = 115K. Land on hanger and slow pumps to 3
BPM = 450 psi ICP, bump pressure 580 psi. Plug bumped 0.7 bbls early. CIP at 08:43. Pressure up to 1,150 psi and hold for 5 min - good. Bleed off and check
floats - holding. 24.8 bbls lost during the cement job. RD circulating lines. Back out landing joint and lay down. RD Volant tool, elevators and bail extensions. MU 7-
5/8" x 11" pack-off & running tool on 5" drill pipe. Pack-off did not seat on first attempt. Pull and inspect seal - good. Flush top of hanger with water. Pack-off did not
seat on second attempt. Flush top of hanger with 10 bbls water through the kill line. Seat hanger. Run in lockdown screws. Test 7-5/8" x 11" pack-off to 500 psi low
for 5 min and 5,000 psi high for 10 min. Remove pack-off running tool. M/U upper test plug and in tubing hanger. Change upper pipe rams from 7-5/8" FBR to 2-
7/8" x 5" VBR. SimOps: Change top drive saver sub to HT-38 and grabber dies. Dress drill collar slips and dog collar for 4-3/4" BHA. Mobilize 4" elevators, drill pipe
slips and single joint elevators to the rig floor. Install 4" test joint and RU test equipment. Fill stack with fresh water and purge lines. PT UPR (2-7/8" x 5" VBR) to
250/3,000 psi with 4" & 4-1/2" test joints. PT HT-38 FOSV and dart valves to 250/3,000 psi. All tests performed with fresh water against test plug. RD testing
equipment. Pull the test plug. Change bell guide to 4" drill pipe. Mobilize 4" crossovers to the rig floor. Jet the flow line with the cement line. MU the stack jetting
tool, jet the BOP stack and lay down the jetting tool. MU wear ring running tool, install the wear ring and lay down the wear ring running tool. Mobilize BHA
component to the rig floor. PJSM for MU BHA. PU and MU 6-3/4" tri-cone bit, 4-3/4" mud motor with 1.5° AKO, 3 NMFC, 2 stands 4" HWDP with jar to 316'. RIH
with cleanout BHA on 4" DP from the pipe shed from 315' to 2,685'. Daily disposal to G&I = 1,137 bbls Total disposal to G&I = 9,524 bbls. Daily water hauled from
A-pad = 265 bbls Total water hauled from A-pad = 5,885 bbls. Daily fluid loss = 25 bbls Total fluid loss = 316 bbls. Daily metal recovered = 0 lbs Total metal
recovered = 0 lbs.
9/27/2022 Continue to single in the hole with cleanout BHA on 4" drill pipe from 2,685' to 6,667', PU = 150K, SO = 70K. Fill pipe every 2,500'. While filling pipe at 5,505'
observed 3,000 psi pressure spike. Bleed off pressure. Resume circulation at 1/2 BPM with normal pressure. Circulated a drill pipe volume at 250 GPM, 1,160 PSI
to ensure drill pipe was clear. Sim-ops: Little Red pumped 91 bbls of diesel freeze protection down the 7-5/8" x 10-3/4" annulus at 1.6 BPM = 890 PSI. Wash down
from 6,667' with 140 GPM = 730 ps. Observe cement stringers from 6,730' and tagged with 10K at 6,739'. Rack stand back to 6,667' and circulate and condition
mud. Circulated surface to surface at 250 GPM = 1,040 psi, 40 RPM = 7K TQ. PU = 140K, SO = 75K, ROT = 104K. Rack back stand to 6,667' Rig up test
equipment. Close upper 2-7/8"x5" VBR on 4" drill pipe. Pump down drill pipe and kill line. Pressure test 7-5/8" casing to 2,600 psi for 30 minutes charted (good
test). Pumped 3.2 bbls, bled back 3.2 bbls. RD test equipment and blow down lines. Obtain new slow pump rates. Ream down from 6,667' and drill cement from
6,739', 250 GPM = 1280 psi, 40 RPM = 8K ft-lbs TQ, WOB = 6K. Drilled float collar 6,770 to 6,772', reamed one time. Drill cement and float shoe from 6,772' to
6,897' (all equipment on depth). Cleanout rat hole from 6,897' to 6,907'. Ream through the shoe 3 times then drift without rotary/pumps. Drill 20' of new formation
from 6,907' to 6,927' at 250 GPM = 1,310 psi, 50 RPM = 8K ft-lbs TQ. PU = 145K, SO = 75K, ROT =102K. Pump 30 bbls hi-vis sweep and circulate out the well at
250 GPM = 1,210 psi, 40 RPM = 8K ft-lbs TQ. Sweep back 150 strokes late with 20% increase. Circulate and condition the mud. Good 9.5 ppg in/out. Stand one
stand back to 6,856'. RU testing equipment and purge air. Perform FIT to 12.0 ppg with casing shoe at 6,897' (4,494' TVD) with 9.5 ppg MW and 584 psi applied at
surface. Pump 0.9 bbls and bled back 0.7 bbls. Blow down and RD testing equipment. Observe the well for flow (static). TOOH from 6,856' to 6,380'. Pump 30 bbl
dry job and blow down the top drive. TOOH from 6,380' to 316'. Stand back 2 stands of 4” HWDP with jar and 1 stand of NM flex collars from 316’ to 31’. Lost 9 bbls
while TOOH. Average loss rate = 2.25 BPH. Lay down 4-3/4" motor and 6-3/4" tri-cone bit. Bit grade = 1-1-WT-A-E-I-NO-BHA Clean and clear the rig floor. Install
split master bushings. PJSM. MU 6.75" NOV (TKC63) PDC and Geo-Pilot. MU ADR with ILS, DM, GM, PWD and TM collars and NM integral blade. to 92'. Plug
in and initialize MWD tools. Daily disposal to G&I = 171 bbls Total disposal to G&I = 9,695 bbls. Daily water hauled from A-pad = 165 bbls Total water hauled from
A-pad = 6,050 bbls. Daily fluid loss = 9 bbls Total fluid loss = 325 bbls. Daily metal recovered = 0 lbs Total metal recovered = 0 lbs. OA = 260 psi.
9/28/2022 Trip in hole with 6-3/4" rotary steerable drilling assembly from 92' to 2,745' Fill pipe. Shallow pulse test MWD tools and break-in Geo-Pilot seals, 220 GPM = 915
PSI. Blow down top drive. Continue TIH from 2,745' to 6,728', PU = 155K, SO = 75K. 2.4 bbls lost on trip in the hole. PJSM. Remove trip nipple. Install MPD RCD
with stand #68 to 6,822'. Fill drill pipe and flood MPD lines. PJSM. TIH f/ 6,822' to 6,927'. Pump 30 bbl high vis spacer. Displace wellbore to 8.75 ppg Flo-Pro mud
with 0.5% 776 lube. Rack stand back to 6,854' and blow down top drive. Monitor pressure with MPD choke closed - no pressure build. Sim-ops: clean surface
equipment in the mud pits & pit #4. Slip and cut 54' drilling line. Service Top Drive. Monitor pressure with shut in MPD choke - No pressure build observed. Lay
down single of DP. Wash to bottom at 6927'. 145k PUW, 80k SOW, 103k ROT. Drill 6-3/4" lateral from 6927' to 7202' (4495' TVD). Drilled 275' = 45.83'/hr AROP.
230 GPM = 1130 PSI, 80 RPM = 6k Tq until BHA exit shoe then increase to 120 RPM = 8K Tq, WOB = 12k. MW = 8.8 ppg, 42 vis, ECD = 9.68 ppg, Max Gas =
75u. PU = 122k, SO = 78k, ROT = 97k MPD choke open while drilling, Closed with no pressure build observed during connections. Drill 6-3/4" lateral from 7202' to
7626' (4499' TVD). Drilled 424' = 70.67'/hr AROP. 250 GPM = 1280 PSI, 120 RPM = 7-8K Tq, WOB = 7-11k. MW = 8.9 ppg, 43 vis, ECD = 9.8 ppg, Max Gas =
126u. PU = 125k, SO = 75k, ROT = 100k. MPD choke open while drilling, Closed with no pressure build during conn. Last survey at 7527.48’ MD / 4499.52' TVD,
90.22° inc, 311.66° azm, 12.19' from plan, 12.19' high and 0.27’ right. We have drilled 11 concretions for a total thickness of 79’ (12.5% of the lateral). Daily
disposal to G&I = 553 bbls Total disposal to G&I = 10248 bbls. Daily water hauled from A-pad = 140 bbls Total water hauled from A-pad = 6765 bbls. Daily fluid
loss = 9 bbls Total fluid loss = 334 bbls. Daily metal recovered = 7.5 lbs Total metal recovered = 7.5 lbs. OA = 200 psi.
9/29/2022 Drill 6-3/4" lateral from 7,626' to 7,960' (4,493' TVD). Drilled 334' = 55.67'/hr AROP. 250 GPM = 1290 PSI, 90-140 RPM = 6K Tq, WOB = 7-11k. MW = 9.0 ppg, 41
vis, ECD = 9.8 ppg, Max Gas = 177u. PU = 125k, SO = 75k, ROT = 100k. MPD choke open while drilling, Closed with no pressure build during conn. Pumped 20
bbl high vis sweep at 7,960', back on time with 30% increase. Drill 6-3/4" lateral from 7,960' to 8,326' (4,493' TVD). Drilled 366' = 61'/hr AROP. 250 GPM = 1290
PSI, 80-140 RPM = 5-7k Tq, WOB = 5-12k. MW = 9.0 ppg, 41 vis, ECD = 10.05, Max Gas = 277u. PU = 117k, SO = 83K, ROT = 102k. MPD choke open while
drilling, Closed with no pressure build during conn. Drill 6-3/4" lateral from 8326' to 8435' (4489' TVD). Drilled 109' = 18.17'/hr AROP. 200-250 GPM = 1240-1360
PSI, 40-120 RPM = 4-8K Tq, WOB = 7-18k. MW = 8.9 ppg, 39 vis, ECD = 9.89 ppg, Max Gas = 252u. PU = 120k, SO = 80k, ROT = 100k. MPD choke open while
drlg, Closed during conn w/ no psi build Several very hard concretions encountered, varying RPM, WOB, Flow, and GP Deflection does not show any
improvement in ROP (2-5' hr) while engaged on hard formation. Drill 6-3/4" lateral from 8435' to 8814' (4497' TVD). Drilled 379' = 63.17'/hr AROP. 220-250 GPM =
1320-1430 PSI, 90-140 RPM = 6-8K Tq, WOB = 5-18k. MW = 9.1ppg, 37 vis, ECD = 10.09 ppg, Max Gas = 302u. PU = 125k, SO = 80k, ROT = 100k. MPD choke
open while drlg, Closed during conn w/ no psi build Last survey at 8666.23’ MD / 4489.50' TVD, 88.13° inc, 309.75° azm, 7.33' from plan, 3.54' Low and 6.42’ Left.
We have drilled 39 concretions for a total thickness of 323’ (17.4% of the lateral). Daily disposal to G&I = 285 bbls Total disposal to G&I = 10533 bbls. Daily water
hauled from A-pad = 375 bbls Total water hauled from A-pad = 7210 bbls. Daily fluid loss = 0 bbls Total fluid loss = 334 bbls. Daily metal recovered = 10.8 lbs
Total metal recovered = 18.3 lbs. OA = 280 psi.
9/30/2022 Drill 6-3/4" lateral from 8,814' to 9,193' (4,490' TVD). Drilled 379' = '63.17/hr AROP. 200-250 GPM = 1350 PSI, 80-140 RPM = 6-7K Tq, WOB = 7-18k. MW =
9.0ppg, 37 vis, ECD = 9.9 ppg, Max Gas = 252u. PU = 123k, SO = 75k, ROT = 98k. MPD choke open while drlg, Closed during conn w/ no psi build Pumped 20
bbls high vis sweep at 9,003', back on time with 100% increase. Drill 6-3/4" lateral from 9193' to 9747' (4481' TVD). Drilled 554' = 92.33'/hr AROP. 250 GPM =
1410 PSI, 80-120 RPM = 7-8K Tq, WOB = 7-13k. MW = 8.9 ppg, 40 vis, ECD = 10.16 ppg, Max Gas = 226u. PU = 127k, SO = 72k, ROT = 100k. MPD choke
open while drlg, Closed during conn w/ no psi build Drill 6-3/4" lateral from 9747' to 10141' (4459' TVD). Drilled 394' = 65.67'/hr AROP. 250 GPM = 1570 PSI, 120
RPM = 7K Tq, WOB = 8-15k. MW = 8.9 ppg, 39 vis, ECD = 10.25 ppg, Max Gas = 152u. PU = 127k, SO = 72k, ROT = 100k. MPD choke open while drlg, Closed
during conn w/ no psi build Drilled through fault #1 at 9768’, 22’ throw DTE. Build to 96° inc and reacquire the OA at 9872’ then drop to 92° inc. Total of 104' drilled
below OA sand. Increase inc to 94°, at 10030’ to find better (higher Res) sand higher in OA. Pump 20 bbl hi vis sweep @ 9951', back on time w/ 80% increase. Drill
6-3/4" lateral from 10141' to 10805' (4462' TVD). Drilled 664' = 110.67'/hr AROP. 250 GPM = 1620 PSI, 120 RPM = 8K Tq, WOB = 7-11k. MW = 9.05 ppg, 41 vis,
ECD = 10.56 ppg, Max Gas = 303u. PU = 125k, SO = 64k, ROT = 95k. MPD choke open while drlg, Closed during conn w/ 5 psi build With good sand being
logged, level off at 10195’ and start targeting OA dip with 89-89.5° Inc. Last survey at 10657.97’ MD / 4461.84' TVD, 89.60° inc, 313.37° azm, 9.10' from plan, 4.39'
Low and 7.97’ Left. We have drilled 74 concretions for a total thickness of 579’ (15.2% of the lateral). Daily disposal to G&I = 456 bbls Total disposal to G&I =
10989 bbls. Daily water hauled from A-pad = 385 bbls Total water hauled from A-pad = 7595 bbls. Daily fluid loss = 63.5 bbls Total fluid loss = 397.5 bbls. Daily
metal recovered = 8.6 lbs Total metal recovered = 26.9 lbs. OA = 290 psi.
10/1/2022 Drill 6-3/4" lateral from 10,805' to 11,279' (4,479' TVD). Drilled 474' = 79'/hr AROP. 250 GPM = 1650 PSI, 160 RPM = 7-9K TQ, WOB = 8-15K. MW = 9.0 ppg, Vis
= 40, ECD = 10.43, Max Gas = 328u. MPD choke open while drilling, Closed during connection w/ 5 PSI build. Pumped 20 bbl high vis sweep at 10,805', back on
time with 60% increase. Drill 6-3/4" lateral from 11279' to 11722' (4497' TVD). Drilled 443' = 73.83'/hr AROP. 250 GPM = 1650 PSI, 140 RPM = 8-10K TQ, WOB =
5-13K. MW = 8.9 ppg, Vis = 41, ECD = 10.40, Max Gas = 202u. PU = 137k, SO = 40k, ROT = 100k. MPD choke open while drilling, Closed during connection w/ 5
PSI build. Drill 6-3/4" lateral from 11722' to 12119' (4499' TVD). Drilled 397' = 66.17'/hr AROP. 250 GPM = 1600 PSI, 80-140 RPM = 8-10K TQ, WOB = 5-14K.
MW = 8.9 ppg, Vis = 39, ECD = 10.44, Max Gas = 327u. PU = 140k, SO = 40k, ROT = 99k. MPD choke open while drilling, Closed during connection w/ 3 PSI
build. Maintain the OA sand, following formation dip @ 88-89° inc. Level trajectory to 90° @ 11850' to avoid OWC Drill 6-3/4" lateral from 12119' to TD @ 12418'
(4480' TVD). Drilled 299' = 99.67'/hr AROP. 250 GPM = 1600 PSI, 150 RPM = 8K TQ, WOB = 7-14K. MW = 9.0 ppg, Vis = 39, ECD = 10.60, Max Gas = 177u. PU
= 140k, SO = 37k, ROT = 95k. MPD choke open while drilling, Closed during connection w/ 5 PSI build. Exit the top of the OA @ 12190’, Start building @ 12205’,
target 3.5° BUR. Drill until the base of the NF sand was confirmed on logs. Take Final survey: 12365.86' MD, 4487.40' TVD 97.64° INC, 308.24° AZ, 19.44' from
plan. 14.59' low, 12.85' right. Drilled 94 concretions for a total thickness of 856' (15.5% of the lateral). Pump 20 bbl sweep around cleaning up the well, back on
time, 10% increase. Circulate at 250 gpm, 1750 psi, 150 rpm, 8k torque, racking a stand back each BU to 12175'. Simops: Clean pits and prep for Vis brine
displacement. Daily disposal to G&I = 803 bbls Total disposal to G&I = 11792 bbls. Daily water hauled from A-pad = 525 bbls Total water hauled from A-pad =
8120 bbls. Daily fluid loss = 0 bbls Total fluid loss = 397.5 bbls. Daily metal recovered = 5.7 lbs Total metal recovered = 32.6 lbs. OA = 310 psi.
10/2/2022 Finish circulating 4 bottoms up while reciprocating from 12,134' to 12,229' at 250 GPM, 1750 PSI, 150 RPM, 8K TQ. 9.0 ppg MW, 43 vis, 10.56 ECD. PJSM with
all parties for displacement. Ream back to bottom from 12,134' to 12,418' due to no slack off weight. 200 GPM, 1125 PSI, 60 RPM, 6K TQ. 135K PU / 45K SO /
95K ROT Pump 30 bbls high vis spacer, 25 bbls 8.45 ppg vis brine, 30 bbls SAPP pill #1, 25 bbls brine, 30 bbls SAPP pill #2, 25 bbls brine, 30 bbls SAPP pill #3
then 30 bbls high vis spacer. Displace with 8.45 ppg viscosified brine with 3% lubes (1.5% 776 and 1.5% LoTorq) 250 GPM, 1740 PSI ICP, 1270 PSI FCP, 150
RPM, 7-8K TQ. No losses during displacement. Shut down with MPD chokes closed. Built 57 PSI over 5 minutes = 8.7 ppg EMW. 125K PU / 73K SO / 100K ROT.
Circulate a bottoms up after displacing while BROOH from 12,418' to 12,323', 265 GPM, 1460 PSI, 160 RPM, 5-6K TQ. 125K PU / 73K SO / 100K ROT. Perform
PST = 4.2 sec for each 350 mL sample - passing. BROOH from 12,323' to 9,952' with 250 GPM, 1250 PSI, 140 GPM, 5K TQ at 5-10 minutes/stand, slowing as
needed for torque or pressure spikes. 8.45 ppg MW, 42 vis, 9.55 ECD, 76u max gas. PU = 125K, SO = 80K, ROT = 100K. MPD choke open while reaming and
trapping 140 PSI on connections = 9.0 ppg EMW. BROOH from 9952' to 7289' at 5-10 min/stand slowing as needed, L/D DP via 90’ mouse hole. 250 GPM = 1050
psi, 140 RPM = 3K ft-lbs Tq, Max Gas = 25u. PU = 115K, SO = 80K, ROT = 100K. 1.6 bph loss rate. MPD choke open while reaming and trapping 140 PSI on
connections = 9.0 ppg EMW. BROOH from 7289' to 6822' pulling in 7 5/8" shoe, pulling 5-10 min/stand slowing as needed, L/D DP in the mouse hole. 250 GPM =
1050 psi, 140 RPM =3k ft-lbs Tq, Max gas units = 0. Total losses BROOH to shoe= 21 bbls Pump 20 bbl hi vis sweep and circulate the casing clean at 250 GPM =
1080 psi, 50 RPM = 1-3K ft-lbs Tq. Total of 2x BU pumped. Sweep back on time with no increase in cuttings observed. Monitor pressure with MPD choke closed
with 8.6 ppg MW. 3x 5 min builds 22 psi, = 8.7 ppg EMW. KWF = 8.9 ppg. SimOps: Weight up the active pits to 8.9 ppg. Circulate 8.9 ppg vis brine while
weighting up the returns on the fly to 8.9 ppg at 250 GPM = 1000 psi, 60 RPM = 4K ft-lb Tq recip string 60' Good 8.9 ppg in/out. Shut down and monitor pressure
with MPD choke closed, no psi build. Rack stand back, blow down Top Drive . SimOps: Monitor for flow at 2'' valve on the MPD head - static Daily disposal to G&I =
1477 bbls Total disposal to G&I = 13269 bbls. Daily water hauled from A-pad = 475 bbls Total water hauled from A-pad = 8595 bbls. Daily fluid loss = 15 bbls
Total fluid loss = 412.5 bbls. Daily metal recovered = 2.4 lbs Total metal recovered = 35.0 lbs. OA = 290 psi.
10/3/2022 Blow down top drive. PJSM. Remove MPD RCD and install trip nipple. Fill stack and check for leaks - none. Wellbore static. Pump dry job. Blow down top drive.
Drop 2.438" O.D drift with 125' wire tail. Trip out of the hole from 6,822' to 377' racking back 4" drill pipe in the derrick. 11.5 bbls lost on trip out. L/D 5 joints of 4"
HWDP, jars, 3 NM flex drill collars and float subs to 92'. Plug in a read MWD tools. L/D remainder of BHA from 92'. Bit grade: 1-1-WT-A-X-I-NO-TD. Minor wear on
leading edge of Integral Blade Stabilizer. No noticeable wear on remainder of BHA. 2 BPH losses. Provided 24 hour BOP test notification to AOGCC at 13:01. Bi-
weekly test may be necessary 10-5-2022 if problems running liner. Clean rig floor and clear of BHA components. Pull split bushings and install master bushing.
Mobilize handling equipment and power tongs to the rig floor. RU to run 4-1/2" liner. MU crossover on the FOSV. Monitor well on the trip tank, Static loss rate 1.5
BPH. PJSM on running liner. 19:22 – Code 99 Red in field. Secure well and muster at primary safety area – all personnel accounted for. Cease non essential rig
operations until “all clear” in field called @ 20:14. MU & RIH round nose float shoe/WIV with crossover joint, RIH with 4-1/2", 13.5#, L-80, H625, 100 micron
production screen liner as per tally to 2269'. M/U to optimum Tq @ 9,600 ft-lbs with Doyon double stack tongs. PU = 80K, SO = 70K. Loss rate RIH= 1.5 BPH
Continue RIH with 4-1/2", 13.5#, L-80, H625, 100 micron production screen liner from 2269' to 5635'. M/U to optimum Tq @ 9,600 ft-lbs. Losses RIH with liner=
18.6 bbls. Verify pipe count. Total of 26 blank jts & 112 Pro Mesh Cal Iv screen jts, C/O elevators to 4" DP. P/U Baker 4-1/2" x 7-5/8" ZXP liner top packer and Flex
Lock Hanger assembly to 5863'. MU stand drill pipe to 5776', pump 2 bbls @ 1.5BPM, 80 PSI to ensure clear flow path. 110K PU, 93K SO. Blow down TopDrive.
Clear rig floor of casing handling equipment and install airslips. Daily disposal to G&I = 114 bbls Total disposal to G&I = 13383 bbls. Daily water hauled from A-pad
= 75 bbls Total water hauled from A-pad = 8670 bbls. Daily fluid loss = 27.5 bbls Total fluid loss = 440 bbls. Daily metal recovered = 2.7 lbs Total metal recovered
= 37.7 lbs. OA = 280 psi.
10/4/2022 RIH w/ 4.5” liner on 4” drill pipe from 5,776’ to 6,820', just inside the 7-5/8" casing shoe. Obtain parameters at 7-5/8" casing shoe. 120K PU / 100K SO / 110K ROT.
3 BPM = 250 PSI, 15 & 20 RPM = 4K TQ. Continue to TIH w/ 4.5" liner on 4" drill pipe from 6,820' to 12,417'. 145K PU / 75K SO. 8.6 bbls lost running liner on drill
pipe, 1.5 BPH. M/U side entry pump in sub, P/U working single and M/U top drive. Tag bottom at 12,418' with 10K then P/U to set depth at 12,394'. Pump down
1.5” phenolic ball with 20 bbl high vis sweep at 3 BPM and slow to 2 BPM after 45 bbls. Ball on seat 201 strokes early (allowed to free fall). Pressure up to 1900 PSI
and attempt to set hanger multiple times. Bleed off pressure then pressure up to 1900 PSI - 4 more attempts. Bleed off then pressure up to 1800 PSI. Rotate 10
RPM = 7K TQ. Slack off but no set. Bleed pressure to 500 PSI then set down to 50K hookload, but observing slips slide. P/U and set down again observing slips
slide at 65K. P/U, pressure up to 1900 PSI and hold for 5 min. Slack off and observe hanger set. Pressure up to 3000 PSI, hold for 5 minutes to set packer.
Continue to pressure up and observe pusher tool neutralize at 3400 PSI. Continue up to 4800 PSI and observe ball seat sear. P/U and observe travel at 115K
confirming release. Top of liner at 6,746.39' R/U test pump. Pressure test Baker SLZXP packer. Close upper pipe rams and pressure test 4" x 7-5/8" annulus to
1600 PSI for 10 minutes on chart - good test. Bleed off, rig down test equipment and blow down lines. P/U and pull running tool out of liner tie-back to 6,699'.
Circulate the 7-5/8" casing clean 6 BPM, 570 PSI while reciprocating pipe. 120K PU / 90K SO. No losses. Observe well - static. Pump dry job. POOH L/D 4'' DP
from 6699' to surface, L/D liner running tool & inspect same, good. 1.5 BPH loss rate. 11.2 bbl total losses. Daily disposal to G&I = 0 bbls Total disposal to G&I =
13383 bbls. Daily water hauled from A-pad = 215 bbls Total water hauled from A-pad = 8885 bbls. Daily fluid loss = 39 bbls Total fluid loss = 479 bbls. Daily metal
recovered = 0 lbs Total metal recovered = 37.7 lbs. OA = 260 psi.
Activity Date Ops Summary
10/4/2022 Blow down TopDrive. Clean and clear the rig floor, Pull the wear bushing. RU 4 1/2'' power tongs and handling equipment. Centrilift R/U spooler on rig floor, ready
XO on FOSV. Monitor well, 1 bph loss rate,PJSM, P/U bullet seal assembly and RIH on 4-1/2”, 12.6#, L-80, TXP tubing as per tally to 466'. Torque to 6,500 ft-lbs
with Doyon double stack tongs. PU XN nipple (3.725" no-go), tubing joint, Centrilift Zenith gauge assembly, tubing joint and Halliburton sliding sleeve to 622'.
Orient I wire across blank ports in sliding sleeve.,Continue to run tubing and installing Cannon clamps as per tally from 622' to 2321'. Torque all connections to
6,500 ft/lbs with Doyon double stack tongs. PU = 65K & SO = 60K. 1 BPH loss rate. Daily disposal to G&I = 0 bbls Total disposal to G&I = 13383 bbls. Daily water
hauled from A-pad = 215 bbls Total water hauled from A-pad = 8885 bbls. Daily fluid loss = 39 bbls Total fluid loss = 479 bbls. Daily metal recovered = 0 lbs Total
metal recovered = 37.7 lbs. OA = 260 psi.
10/5/2022 Continue to run 4-1/2" 12.6# L-80 TXP-BTC tubing and installing Cannon clamps as per tally from 2,321' to 6706'. Torque all connections to 6,500 ft/lbs with Doyon
double stack tongs. PU = 100K & SO = 80K. 8.9 bbls lost during tubing run, 0.8 BPH loss rate.,RIH with joint #163. Observe seal drag at 6728' and no-go at 6735'.
Set 10K down. L/D joints #161 to 163. M/U eight space out pups (1.88', 1.89', 3.89', 3.9', 3.86', 3.87', 7.85' and 7.87' = 35.01' total). M/U joint #161.,Change
elevators to 5" DP. M/U crossovers, FOSV and pup to the landing joint and M/U the tubing hanger. M/U the tubing hanger to the completion. Terminate the Tec
wire, feed through the tubing hanger and secure. Drain the BOP stack. Land the tubing hanger. R/U to reverse circulate.,PJSM. Close the annular and pressure up
to 370 psi on the IA. P/U to expose the mule shoe on the tie back seals. Pump 113 bbls corrosion inhibited source water down the IA at 4 BPM = 1000 psi followed
with 60 bbls diesel at 3 BPM = 780 psi, freeze protecting the IA to 2300’.,Slack off, engage seals on bullet assembly into seal bore receptacle. Bleed pressure and
drain the stack. Open the annular, flush out the stack with water and blow down lines.,Land the tubing hanger with 40K on hanger, 1.71' off no-go RILDS.,Line up to
pump down the IA, pressure up to 3,650 psi on the 7 5-/8'' x 4-1/2'' annulus for 30 charted minutes – Good test. 3.6 bbls pumped, 3.6 bbls led back. Blow down
injection line,Blow down, R/U “T” Bar and L/D landing joint. WHR install BPV.,R/D circulating lines and test equipment. R/D spooler and sheave, clear the rig floor of
4-1/2" & 4" tools, XOs and equipment. Load out centrilift equipment. Remove 90' mouse hole. Clear rotary table drip pan. Empty pits and start cleaning same,Pull
trip nipple, remove MPD orbit valve & RCD clamp from MPD in preparation for BOP stack removal during upcoming rig move. Remove drip pan and start N/D BOP
stack. Daily disposal to G&I = 513 bbls Total disposal to G&I = 13869 bbls. Daily water hauled from A-pad = 130 bbls Total water hauled from A-pad = 9015 bbls.
Daily fluid loss = 9 bbls Total fluid loss = 488 bbls. Daily metal recovered = 0 lbs Total metal recovered = 37.7 lbs. OA = 220 psi.
10/6/2022 Continue to remove RCD head clamp, Rack BOP stack on stump. Remove MPD equipment. RD and move office trailers from E-Pad to M-Pad. Take rig off hi line
power @ 08:00 and put on gen power.,Cleanup around hanger, WHR install the CTS plug in BPV. Clear path behind rig, load tree into cellar, NU the tubing head
adapter and tree. Centrilift take final gauge reading: 1956.3 tubing psi, 1757 IA psi, tubing temp 85, IA temp 85, voltage 20.7. Simops: Clean in pits, setup office
trailers on M-Pad,WHR pressure test the tubing hanger void to 500/5,000 psi for 10 minutes each, good. RU and test the tree to 250/5,000 psi, good. Welder cut
and cap mousehole in cellar box.,RD test equipment. Pull CTS plug and BPV with dry rod.,RU circulating equipment. Bullhead 35 bbls of diesel down the tubing at
2 BPM = 860 psi ICP & 960 psi FCP, freeze protecting the tubing to 2300'. Blow down and RD circulating lines. Shut in and secure the well. Final well pressures:
tubing = 0 psi & IA = 0 psi, OA = 190 psi. Release Rig at 19:00.
9/16/2022Spud Date:
Well Name:
Field:
County/State:
MP B-35
Milne Point
Hilcorp Energy Company Composite Report
, Alaska
50-029-23724-00-00API #:
Activity Date Ops Summary
10/23/2022 Made State Notification for upcoming BOPE Test for B-35,Lay Down the Mast. Move rig from well and transport to A Pad shop for routine maintenance. With Crane
Support Fly the Koomy Hoses out, R/D Flow Spool. Fly the Rig Floor onto transport trailer and secure. N/D BOP's , N/U Tree. Test Void to 500psi low / 5000psi
high. for 5/10 min. Good Test. ESP Rep. Perform final checks on wellhead. Good Test. Fly the Well House onto transport trailer and move to B-35. Move Pit Module
to B-35
10/24/2022 MIRU. Spotted Crane and set the Cellar and Rig Floor over well. Install Staircase to the back of the rig floor. Install the Spacer and flow spools onto BOP Stack, Set
portable heaters in position around the rig. Layed out Accumulator lines.,Spotted the pit module into position. Leveled and Cribbed up Pit Module. Took on 150
BBLS of 8.9 ppg. Brine into Pit System. Hooked up Accumulator lines. Spotted the rig into position. Hooked up all Ancillary equipment and lines. Spotted the Pusher
and Company Mans Shack. Hooked up all Services.,Level and secure the Rig to the mud boat. PJSM on Raising the derrick. Raise the derrick and secure. Hook up
Glycol heat system and install winterization around the rig. Install Bird Bath and 6" Flow Line. Install the staircase to the front of the rig floor.,Off Load 40 BBLS Fresh
water into pit #4 for testing. R/U Rig Floor Power Tongs and Tubular Handling Equipment. Hook up Circulating lines and pump 7 BBLS of 8.9 ppg. Brine down the
annulus & Caught pressure. Check later and on a vac. P/U 4.5" Test Joint. Function test BOPE. Flood the BOPE and purge the system with test fluid.,Test BOPE as
per State Approved Sundry. 250 psi low / 2500 psi high. All tests charted for 5 minutes each. Witness of the test was waived by AOGCC Rep. Sully Sullivan. Rig
Accepted at 04:30 Hours. on 10-25-2022. 24 Hour Fluid loss to the hole = 7 BBLS. Total Fluid loss = 7 BBLS.
10/25/2022 Testing BOPE as per approved state Sundry. 25 psi low / 2500 psi high. All tests charted for 5 minutes each. Kelly Valve Failed. Changed out and re-tested good.
Tested Gas Alarms and PVT System. Witness of the test was waived by AOGCC Rep. Sully Sullivan.,Rig down test equipment. Blow down stack and testing
equipment.,Check for Pressure, Pull CTS Plug, Pull BPV,M/U Landing Joint, BOLDS, Pull Hanger to the Floor, Unseat at 65K . PUW= 63K. L/D Landing joint and
Tubing Hanger. Pumped in 6 bbl.. of 8.9 ppg. Brine to fill the hole.,POOH laying down 4.5" Completion F/ 6733' T/ 4600 . Visually Inspect all Tubulars as we Break
the Connections, checking the Make Up Diamond for proper torque Markings. Found the connection between joint # 124 & 123 to be over torqued as suspected on
the caliper logs. Adding 4 bbl. of 8.9 ppg. Brine per / hour for hole fill. 24 Hour Fluid loss to the hole = 33 bbl. Total fluid loss for the Work Over = 40 bbl.
10/26/2022 Organize pipe on location. pull bad pipe off rack. Drift pipe on rack. Continue POOH w/ 4-1/2 TXP and tech wire from 4,600' to 4,000'. finding slightly over torqued
pins @4,400',Found coolant leak on rig. mechanic drain radiator, replace hose and connections. filled radiator back up and tested connections. Continue to POOH
w/ 4-1/2 TXP and tech wire from 4,000' to 3,090 finding multiple joints that were slightly over torqued and at 3,090' connection between #74 and #73 extremely
over torqued as suspected on caliper log. Continue to POOH w/ 4-1/2 TXP and tech wire from 3,090'' to 2,800' and at 2,800' connection between #67 and #66
extremely over torqued as suspected on caliper log.,Continue to POOH w/ 4-1/2 TXP and tech wire from 2,800' to 662' finding multiple joints that were slightly
over torqued and at 2,000' connection between #47 and #46 extremely suspected on caliper log.,Continue to POOH laying down the 4.5" Jewelry. Sliding Sleeve,
Zenith Gauge, XN Nipple, Bullet Seals. Baker Rep. Inspected the bullet seals good as new. Recovered a total of 161 Joints of tubing and 85 Cannon Clamps. 103 re-
usable joints. 37 Joints of Over Torqued Damaged Thread. 20 Joints that showed Thread Galled damage. 1 Joint was Perforated,Clean and clear rig floor. Prepare
rig floor for Completion Run. Rack and Tally new 4.5 Completion. Change out all 4.5" TXP Connection Seal Rings. Drifted all used pipe on the Rack with 3.833 "
Drift.,RIH with 4.5" , 12.6#, L-80, TXP Completion F/ Surface T/ 1000' at report time. Make up Torque as per Diamond Detail for 10 Joints. Calculate the Average for
the optimum Make Up of 6170 ft./lbs. M/U Zenith Gauge with Tech Wire. Test Good. Adding 4 bbl/hr. for hole fill. 24 HR. Fluid Loss to The Hole = 69 bbl. Total
Fluid Loss for The Work Over = 109 bbl.
10/27/2022 Continue RIH w/ 4-1/2 TXP and jet pump completion from 1,000' to 1,650',Baker rep test tech wire. rig service, change bearings on tong rack. rack and tally pipe on
pipe racks.,Continue RIH w/ 4-1/2 TXP and jet pump completion from 1,650' to 6,700'. Testing cable every 1000',Obtain PUW = 63K, SOW = 37K. Slack of and
Observe Bullet Seals Enter LTP at 6733'. Verify with 4K DN. Drag. Also set down 10K to Verify NO-GO out LTP at 6733',Space out and make up tubing hanger and
Landing Joint. Terminate I-Wire Cap String to Hanger. Test I-Wire Good.,R/U Circulating Lines and Pump 50 bbl. Inhibited Brine at 3.3 BPM at 300 psi. down the
tubing taking returns up the Annulus. Chase with 97 bbl. of 8.9 Brine to Spot the inhibited brine across the bullet seals and the Sliding sleeve. R/D circulating lines
and blow down.,Land Tubing Hanger with 37K Down. Again verifying 4K down hole drag as the Bullet Seals interred the Liner Top. RILDS,,Perform MIT-IA
pressure test to 3650 psi for 30 Charted Minutes. Good Test. Install BPV. Start Rigging Down. Rig Released at 06:00 HRS. on 10-28-2022. 24 hour fluid loss to
hole 16 bbl. Total fluid loss for the Work Over = 125 bbl.
50-029-23724-00-00API #:
Well Name:
Field:
County/State:
MP B-35
Milne Point
Hilcorp Energy Company Composite Report
, Alaska
9/16/2022Spud Date:
TD Shoe Depth: PBTD:
No. Jts. Returned
RKB RKB to BHF RKB to THF
Jts.
1
1
1
80
1
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:
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:
ArcticCem Cement 912 2.88
Premium G cement 270 1.17
5.5
32.36
3,283.69 54.06
Cut Joint 9 5/8 40.0 L-80 TXP-BTC 21.70 54.06
1.60 3,285.29 3,283.69
Casing 10 3/4 40.0 L-80 TXP-BTC Tenaris 3,229.63
Float Collar 11 7/8 TXP-BTC Innovex
48 total 10-3/4" x 13"1/2" bowspring centralizers ran. Two in shoe joint w/ stop rings 10' from each end. One each with
stop rings mid-joint on joint #2 & 3. One each on joints 4 to 25, every other joint to #49 then every third joint to #79.
Casing 10 3/4 41.0 L-80 TXP-BTC Tenaris 121.05 3,406.34 3,285.29
www.wellez.net WellEz Information Management LLC ver_04818br
4.2
Ftg. Returned
Ftg. Cut Jt.18.83 Ftg. Balance
No. Jts. Delivered 90 No. Jts. Run 84 6
Length Measurements W/O Threads
Ftg. Delivered Ftg. Run
33.88 RKB to CHF
Type of Shoe:Innovex Casing Crew:Doyon
10.7 463
3,408.173,413.00
CEMENTING REPORT
Csg Wt. On Slips:100,000
Spud Mud
9:09 9/20/2022 38
15.8 56
Bump press
Cement to surface
Bump Plug?
292.3/296
950
126
Rig
FI
R
S
T
S
T
A
G
E
10Tuned Spacer 60
9.5 5
100
440
Csg Wt. On Hook:180,000 Type Float Collar:Innovex No. Hrs to Run:13
TXP-BTC Innovex 1.83 3,408.17 3,406.34
Setting Depths
Component Size Wt. Grade THD Make Length Bottom Top
Hilcorp Energy Company
CASING & CEMENTING REPORT
Lease & Well No.MP B-35 Date Run 19-Sep-22
CASING RECORD
County State Alaska Supv.D. Yessak / I. Toomey
3,283.69
Floats Held
252.43 519
126 393
Spud Mud
Rotate Csg Recip Csg Ft. Min. PPG9.5
Shoe @ 3408.17 FC @ Top of Liner
209.57 350.14 67.08
Casing (Or Liner) Detail
Shoe 11 7/8
Cement to surface
X
TD Shoe Depth: PBTD:
No. Jts. Returned
RKB RKB to BHF RKB to THF
Jts.
1
3
1
168
1
1
1
X Yes No X Yes No 5
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? 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:
Type I/II 346 1.15
0.67 32.09 31.42ad Shoulder to LLD 7 5/8
33.00
andrel Casing Hang 10 3/4 TXP-BTC 0.91 33.00 32.09
6,773.14 37.02
Casing Pup Joint 7 5/8 29.7 L-80 TXP-BTC 4.02 37.02
1.62 6,774.76 6,773.14
Casing 7 5/8 29.7 L-80 TXP-BTC 6,736.12
Float Collar 8 5/8 L-80 Buttess Forum
34 total 7-5/8"x9-7/8" TEKSTAR centralizers ran.
Two centralizers with stop rings 10' from each end of joint #1.
One centralizer free floating on joints #2 & 3.
Two centralizers with stop rings 10' from each end of joint #4.
One centralizer free floating on joints #5 to 34.
Casing 7 5/8 29.7 L-80 TXP-BTC 120.88 6,895.64 6,774.76
www.wellez.net WellEz Information Management LLC ver_04818br
3.5
Ftg. Returned
Ftg. Cut Jt. Ftg. Balance
No. Jts. Delivered No. Jts. Run
Length Measurements W/O Threads
Ftg. Delivered Ftg. Run
33.88 RKB to CHF
Type of Shoe:Forum Casing Crew:Doyon
6,897.516,907.00
CEMENTING REPORT
Csg Wt. On Slips:75,000
LSND
8:43 9/26/2022 5,685
15.8 71
Bump press
Calculated w/ 40% WO
Bump Plug?
310.48/311.15
580
0
Rig #2
FI
R
S
T
S
T
A
G
E
11Tuned Spacer 60
9.7 6
99
580
Csg Wt. On Hook:245,000 Type Float Collar:Forum No. Hrs to Run:21
Buttress Forum 1.87 6,897.51 6,895.64
Setting Depths
Component Size Wt. Grade THD Make Length Bottom Top
Hilcorp Energy Company
CASING & CEMENTING REPORT
Lease & Well No.MP B-35 Date Run 25-Sep-22
CASING RECORD
County State Alaska Supv.C.A. Demoski / I. Toomey
6,873.14
Floats Held
52.1 71
071
LSND Mud
Rotate Csg Recip Csg Ft. Min. PPG9.7
Shoe @ 6897.51 FC @ Top of Liner
46.4 65.3 40
Casing (Or Liner) Detail
Shoe 8 5/8 L-80
X
5,685
CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders.
From:Joseph Lastufka
To:Brooks, James S (OGC)
Subject:RE: [EXTERNAL] FW: MPU B-35 (PTD #222-085) 10-407 Completion Report
Date:Wednesday, November 2, 2022 11:03:00 AM
Attachments:MPU B-35 10-407_11-2-22.pdf
James,
The offset for TPI should have been FWL, not FEL… Thanks for catching that! Please let me know if
you need anything else.
Thanks,
Joe Lastufka
Sr. Drilling Technologist
Hilcorp North Slope, LLC
Office: (907)777-8400, Cell:(907)227-8496
From: Brooks, James S (OGC) <james.brooks@alaska.gov>
Sent: Wednesday, November 2, 2022 10:58 AM
To: Joseph Lastufka <Joseph.Lastufka@hilcorp.com>
Subject: [EXTERNAL] FW: MPU B-35 (PTD #222-085) 10-407 Completion Report
Hi,
The coordinates are somewhat off: see attachment.
thanx
-$0(6%522.6
5(6($5&+$1$/<67,,E$/$6.$2,/$1'*$6&216(59$7,21&200,66,21
'(3$570(172)&200(5&(&20081,7<$1'(&2120,&'(9(/230(17
E-$0(6%522.6#$/$6.$*29
From: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov>
Sent: Tuesday, November 1, 2022 9:55 AM
To: Brooks, James S (OGC) <james.brooks@alaska.gov>
Subject: FW: MPU B-35 (PTD #222-085) 10-407 Completion Report
CAUTION: This email originated from outside the State of Alaska mail system.
Do not click links or open attachments unless you recognize the sender and know
the content is safe.
From: Joseph Lastufka <Joseph.Lastufka@hilcorp.com>
Sent: Tuesday, November 1, 2022 9:48 AM
To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov>
Subject: RE: MPU B-35 (PTD #222-085) 10-407 Completion Report
Hello,
Attempted to recall, missed an additional sundry # (there are 2 to close on this 10-407). Please let
me know if you have any questions. Thanks!
Thanks,
Joe Lastufka
Sr. Drilling Technologist
Hilcorp North Slope, LLC
Office: (907)777-8400, Cell:(907)227-8496
From: Joseph Lastufka
Sent: Tuesday, November 1, 2022 9:44 AM
To: 'AOGCC Permitting (CED sponsored)' <aogcc.permitting@alaska.gov>
Subject: MPU B-35 (PTD #222-085) 10-407 Completion Report
Hello,
Please see attached for electronic distribution for MPU B-35 (PTD #222-085). Please let me know if
you have any questions. Thanks!
Thanks,
Joe Lastufka
Sr. Drilling Technologist
Hilcorp North Slope, LLC
Office: (907)777-8400, Cell:(907)227-8496
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.
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.
1
Regg, James B (OGC)
From:Alaska NS - ASR - Well Site Managers <AlaskaNS-ASRWellSiteManagers@hilcorp.com>
Sent:Tuesday, October 25, 2022 7:15 PM
To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC)
Cc:Charles Huntington - (C); Aaron Haberthur - (C)
Subject:ASR Test report B-35 10-25-22
Attachments:B-35 BOPE test report 10-25-22.xlsx
ASR DSM’s
Hilcorp DSM: 907‐685‐1266
Hilcorp Alaska, LLC
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.
Milne Pt Unit
PTD 2220850
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.:ASR 1 DATE:10/25/22
Rig Rep.:Rig Email:
Operator:
Operator Rep.:Op. Rep Email:
Well Name:PTD #2220850 Sundry #322-603
Operation:Drilling:Workover:x Explor.:
Test:Initial:X Weekly:Bi-Weekly:Other:
Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:1616
MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 1 FP
Permit On Location P Hazard Sec.P Lower Kelly 0 NA
Standing Order Posted P Misc.NA Ball Type 1 P
Test Fluid Water Inside BOP 1 P
FSV Misc 0 NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0 NA Trip Tank NA NA
Annular Preventer 1 11"P Pit Level Indicators P P
#1 Rams 1 2 7/8" x 5"P Flow Indicator P P
#2 Rams 1 Blinds P Meth Gas Detector P P
#3 Rams 0 NA 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 2 1/16"P Time/Pressure Test Result
HCR Valves 1 2 1/16"P System Pressure (psi)3050 P
Kill Line Valves 2 2 1/16"P Pressure After Closure (psi)1850 P
Check Valve 0 NA 200 psi Attained (sec)17 P
BOP Misc 0 NA Full Pressure Attained (sec)53 P
Blind Switch Covers:All stations Yes
CHOKE MANIFOLD:Bottle Precharge:P
Quantity Test Result Nitgn. Bottles # & psi (Avg.):4 / 2237 PSI P
No. Valves 16 P ACC Misc 0 NA
Manual Chokes 1 P
Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result
CH Misc 0 NA Annular Preventer 25 P
#1 Rams 5 P
Coiled Tubing Only:#2 Rams 6 P
Inside Reel valves 0 NA #3 Rams 0 NA
#4 Rams 0 NA
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:1 Test Time:14.0 HCR Choke 1 P
Repair or replacement of equipment will be made within days. HCR Kill 0 NA
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 10/23/2022 1:38
Waived By
Test Start Date/Time:10/25/2022 4:30
(date)(time)Witness
Test Finish Date/Time:10/25/2022 18:30
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Sully Sullivan
Hilcorp
Test#4 F/P for the the upper kelly valve. Isolated kelly valve and continued testing. Test # 7 found the bleed valve on the test
pump was leaking. Changed out bleeder. good test. Changed out Upper Kelly valve. Tested Kelly valve after all other test done.
good test. Test preformed w/ 4-1/2" test joint. Bottle precharge pressure 1000 psi.
J.Haberthur / C. Greub
Hilcorp Alaska LLC
A.Haberthur/ C. Huntington
MPU B-35
Test Pressure (psi):
askans-asr-toolpushers@hilcorp.co
ans-asrwellsitemanagers@hilcorp
Form 10-424 (Revised 08/2022)2022-1025_BOP_Hilcorp_ASR1_MPU_B-35
J. Regg; 11/28/2022
From:Regg, James B (OGC)
To:AOGCC Records (CED sponsored)
Subject:BOP - Hilcorp ASR1
Date:Monday, November 28, 2022 11:42:21 AM
Attachments:2022-1025_BOP_Hilcorp_ASR1_MPU_B-35.pdf
MPU B-35 (PTD 2220850)
Jim Regg
Supervisor, Inspections
AOGCC
333 W. 7th Ave, Suite 100
Anchorage, AK 99501
907-793-1236
David Douglas Hilcorp Alaska, 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:
Date: 10/18/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL :
WELL: MPU B-35
PTD: 222-085
API: 50-029-23724-00-00
FINAL LWD FORMATION EVALUATION LOGS (09/16/2022 to 10/02/2022)
x ROP, AGR, DGR, PCG, ABG, EWR-M5, 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:
FINAL LWD Subfolders:
FINAL Geosteering Subfolders:
Please include current contact information if different from above.
PTD:222-085
T37166
Kayla Junke
Digitally signed by
Kayla Junke
Date: 2022.10.20
11:12:34 -08'00'
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STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
SSu b m i tt to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner: Rig No.:14 DATE: 9/21/22
Rig Rep.: Rig Email:
Operator:
Operator Rep.: Op. Rep Email:
Well Name:PTD #22220850 Sundry #322-510
Operation: Drilling: X Workover: Explor.:
Test: Initial: X Weekly: Bi-Weekly: Other:
Rams:250 / 3000 Annular:250 / 3000 Valves:250 / 3000 MASP:1523
MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 1P
Permit On Location P Hazard Sec.P Lower Kelly 1P
Standing Order Posted P Misc.NA Ball Type 1P
Test Fluid Water Inside BOP 1P
FSV Misc 0NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0 N/A NA Trip Tank PP
Annular Preventer 1 13-5/8"P Pit Level Indicators PP
#1 Rams 1 7-5/8"P Flow Indicator PP
#2 Rams 1 Blind P Meth Gas Detector PP
#3 Rams 1 2-7/8"x5"P H2S Gas Detector PP
#4 Rams 0NAMS Misc 0NA
#5 Rams 0NA
#6 Rams 0NAACCUMULATOR SYSTEM:
Choke Ln. Valves 1 3-1/8x5000 P Time/Pressure Test Result
HCR Valves 2 3-1/8x5000 P System Pressure (psi)3050 P
Kill Line Valves 2 3-1/8x5000 P Pressure After Closure (psi)1700 P
Check Valve 0NA200 psi Attained (sec)37 P
BOP Misc 0NAFull Pressure Attained (sec)182 P
Blind Switch Covers: All stations Yes
CHOKE MANIFOLD:Bottle Precharge:P
Quantity Test Result Nitgn. Bottles # & psi (Avg.): 6 @1983 P
No. Valves 14 P ACC Misc 0NA
Manual Chokes 1P
Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result
CH Misc 0NA Annular Preventer 13 P
#1 Rams 7 P
Coiled Tubing Only:#2 Rams 7 P
Inside Reel valves 0NA #3 Rams 7 P
#4 Rams 0 NA
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:0 Test Time:6.5 HCR Choke 2 P
Repair or replacement of equipment will be made within days. HCR Kill 2 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 9-19-22 18:14
Waived By
Test Start Date/Time:9/21/2022 8:00
(date) (time)Witness
Test Finish Date/Time:9/21/2022 14:30
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Kam StJohn
Doyon
Preformed BOP test with 4", 5" & 7-5/8' test joints 250 low and 3000 high 5 Min. apiece all tests preformed against test plug.
Test 1ea 4.5' IF FOSV & 1ea 4.5" IF DART vavle. Tested gas alarms both audio & visual. Tested PVT'S & flow paddle preform
draw downs on super choke & manual choke @ 1500 psi.
Hansen / Carlo
Hilcorp Alaska LLC
Demoski / Toomey
MPU B-35
Test Pressure (psi):
rig14@doyondrilling.com
cdemoski@hilcorp.com
Form 10-424 (Revised 08/2022) 2022-0921_BOP_Doyon14_MPU_B-35
9
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9
9
9 999
9
9
9
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CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas
Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential
and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you
are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the
mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov.
&ƌŽŵ͗ŽƵŐzĞƐƐĂŬͲ;ͿфĚLJĞƐƐĂŬΛŚŝůĐŽƌƉ͘ĐŽŵх
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038%
37'
ƌĞǀŝƐĞĚƌĞƉŽƌƚĐŚĂŶŐŝŶŐƚŚĞK'ZĞƉƚŽtĂŝǀĞĚ
Date: 9/16/2022 Development: X Exploratory:
Drlg Contractor: Rig No. 14 AOGCC Rep:
Operator:Oper. Rep:
Field/Unit/Well No.:Rig Rep:
PTD No.: 2220850 Rig Phone:
Rig Email:
MMISCELLANEOUS:DIVERTER SYSTEM:
Location Gen.: P Well Sign: P Designed to Avoid Freeze-up? P
Housekeeping: P Drlg. Rig. P Remote Operated Diverter? P
Warning Sign P Misc: NA No Threaded Connections? P
24 hr Notice: P Vent line Below Diverter? P
AACCUMULATOR SYSTEM:Diverter Size: 21 1/4 in.
Systems Pressure: 3000 psig P Hole Size: 13 1/2 in.
Pressure After Closure: 1800 psig P Vent Line(s) Size: 16 in. P
200 psi Recharge Time: 35 Seconds P Vent Line(s) Length: 198 ft. P
Full Recharge Time:165 Seconds P Closest Ignition Source: 78 ft. P
Nitrogen Bottles (Number of): 6 Outlet from Rig Substructure: 108 ft. P
Avg. Pressure: 2000 psig P
Accumulator Misc: NA
Vent Line(s) Anchored: P
MMUD SYSTEM:Visual Alarm Turns Targeted / Long Radius: P
Trip Tank: P P Divert Valve(s) Full Opening: P
Mud Pits: P P Valve(s) Auto & Simultaneous:
Flow Monitor: P P Annular Closed Time: 28 sec P
Mud System Misc: 0 NA Knife Valve Open Time: 21 sec P
Diverter Misc: NA
GGAS DETECTORS:Visual Alarm
Methane: P P
Hydrogen Sulfide: P P
Gas Detectors Misc: 0 NA
Total Test Time: 1 hrs Non-Compliance Items: 0
Remarks:
Submit to:
SSTATE OF AL ASK A
AAL ASK A OIL AND GAS CONSERVATION COMMISSION
DDi v er t er Sys t em s In s p ec t i o n Rep o r t
GGENERAL INFORMATION
WaivedDoyon
**Al l Di ver t er r epor t s ar e due t o t h e ag enc y w i t h i n 5 days of t est i n g *
AlaskaNS-Doyon14-DSMs@hilcorp.co
TTEST DATA
J Hansen / A. Carlo
phoebe.brooks@alaska.gov
Hilcorp Alaska LLC
24 hr notice given at 18:30 on 9/14/22 and AOGCC rep. Austin Mcleod waived witness at 16:55 hrs on 9/15/22. Test perfromed on 5" DP. Test
H2S/LEL gas alarms. Test PVT and flow paddle alarms. Vent line looks good.
0
D Yessak / I Toomey
0
907-670-3096
TTEST DETAILS
jim.regg@alaska.gov
AOGCC.Inspectors@alaska.gov
MPU B-35
Form 10-425 (Revised 04/2018)2022-0916_Diverter_Doyon14_MPU_B-35
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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 Drive, Suite 1400
Anchorage, AK 99503
Re: Milne Point Field, Schrader Bluff Oil Pool, MPU B-35
Hilcorp Alaska, LLC
Permit to Drill Number: 222-085
Surface Location: 12' FSL, 4307' FEL, Sec. 18, T13N, R11E, UM, AK
Bottomhole Location: 1037' FSL, 2030' FEL, Sec. 11, T13N, R10E, 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,
Jessie L. Chmielowski
Commissioner
DATED this ___ day of August, 2022. 5
Jessie L.
Chmielowski
Digitally signed by Jessie L. Chmielowski
Date: 2022.08.05 12:58:25 -08'00'
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-1500
-750
0
750
1500
2250
3000
3750
4500
5250
6000True Vertical Depth (1500 usft/in)0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500
Vertical Section at 310.00° (1500 usft/in)
MPU B-35 wp05 tgt1 MPU B-35 wp05 tgt3MPU B-35 wp05 tgt2
MPU B-35 wp05 tgt4
MPU B-35 wp05 tgt5
MPU B-35 wp05 tgt6
9 5/8" x 12 1/4"
4 1/2" x 8 1/2"
5 00
1 0 0 0
1500200025003000350040004500500055006000650070007500800085009000950010000105001100011500120001250012576MPU B-35 wp10
Start Dir 2º/100' : 250' MD, 250'TVD
Start Dir 3º/100' : 500.2' MD, 499.88'TVD
Start Dir 4º/100' : 750.2' MD, 746.82'TVD
End Dir : 1804.44' MD, 1621.74' TVD
Fault 1 DTE (40' Throw)Start Dir 4º/100' : 5815.5' MD, 4153.69'TVDEnd Dir : 6729.52' MD, 4477.15' TVDStart Dir 2º/100' : 6879.52' MD, 4485'TVDEnd Dir : 7075.5' MD, 4488.88' TVDStart Dir 2º/100' : 8054.89' MD, 4476.4'TVDEnd Dir : 8205.32' MD, 4476.86' TVDStart Dir 2º/100' : 8655.51' MD, 4485.35'TVDEnd Dir : 8736.64' MD, 4485.76' TVDStart Dir 2º/100' : 9236.64' MD, 4481.4'TVDEnd Dir : 9572.79' MD, 4467.41' TVDStart Dir 2º/100' : 9616.86' MD, 4464.13'TVDFault 2 DTE (10' - 40' Throw)End Dir : 10099.43' MD, 4452.47' TVDStart Dir 2º/100' : 10249.43' MD, 4456.4'TVDFault 3 DTE (20' - 50' Throw)End Dir : 10384.04' MD, 4456.76' TVDFault 4 DTE (10' - 50' Throw)Start Dir 2º/100' : 10802.25' MD, 4448.06'TVDEnd Dir : 10961.86' MD, 4449.19' TVDStart Dir 2º/100' : 11311.86' MD, 4461.4'TVDEnd Dir : 11402.94' MD, 4463.3' TVDTotal Depth : 12576.41' MD, 4471.4' TVDBPRF
SV3
UG4
UG3
LA3
LA2
UG MB
UG MC SB NA
SB NB
SB NCSB ND
SB NE
SB OA
Hilcorp Alaska, LLC
Calculation Method:Minimum Curvature
Error System:ISCWSA
Scan Method: Closest Approach 3D
Error Surface: Ellipsoid Separation
Warning Method: Error Ratio
WELL DETAILS: Plan: MPU B-35
22.70
+N/-S +E/-W
Northing Easting Latitude Longitude
0.00 0.00 6023135.70 571984.03 70° 28' 24.577 N
149° 24' 43.315 W
SURVEY PROGRAM
Date: 2022-02-23T00:00:00 Validated: Yes Version:
Depth From Depth To Survey/Plan Tool
33.70 1200.00 MPU B-35 wp10 (MPU B-35) GYD_Quest GWD
1200.00 6880.00 MPU B-35 wp10 (MPU B-35) 3_MWD+IFR2+MS+Sag
6880.00 12576.41 MPU B-35 wp10 (MPU B-35) 3_MWD+IFR2+MS+Sag
FORMATION TOP DETAILS
TVDPath TVDssPath MDPath Formation
1758.30 1701.90 2020.78 BPRF
2120.30 2063.90 2594.25 SV3
2814.30 2757.90 3693.67 UG4
3224.30 3167.90 4343.18 UG3
3880.30 3823.90 5382.39 LA3
3896.30 3839.90 5407.74 LA2
4134.30 4077.90 5784.77 UG MB
4184.30 4127.90 5865.03 UG MC
4356.30 4299.90 6204.82 SB NA
4376.30 4319.90 6256.54 SB NB
4396.30 4339.90 6313.37 SB NC
4406.30 4349.90 6344.30 SB ND
4424.30 4367.90 6405.72 SB NE
4478.30 4421.90 6751.50 SB OA
REFERENCE INFORMATION
Co-ordinate (N/E) Reference:Well Plan: MPU B-35, True North
Vertical (TVD) Reference:MPU B-35 As staked RKB @ 56.40usft
Measured Depth Reference:MPU B-35 As staked RKB @ 56.40usft
Calculation Method:Minimum Curvature Project:Milne Point
Site:M Pt B Pad
Well:Plan: MPU B-35
Wellbore:MPU B-35
Design:MPU B-35 wp10
CASING DETAILS
TVD TVDSS MD Size Name
4485.02 4428.62 6880.00 9-5/8 9 5/8" x 12 1/4"
4471.40 4415.00 12576.41 4-1/2 4 1/2" x 8 1/2"
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 33.70 0.00 0.00 33.70 0.00 0.00 0.00 0.00 0.00
2 250.00 0.00 0.00 250.00 0.00 0.00 0.00 0.00 0.00 Start Dir 2º/100' : 250' MD, 250'TVD
3 500.20 5.00 270.00 499.88 0.00 -10.92 2.00 270.00 8.36 Start Dir 3º/100' : 500.2' MD, 499.88'TVD
4 750.20 12.46 276.03 746.82 2.84 -48.69 3.00 10.00 39.12 Start Dir 4º/100' : 750.2' MD, 746.82'TVD
5 1300.20 33.96 289.29 1249.62 60.53 -255.23 4.00 20.00 234.43
6 1804.44 50.86 305.94 1621.74 223.50 -549.54 4.00 40.12 564.64 End Dir : 1804.44' MD, 1621.74' TVD
7 5815.50 50.86 305.94 4153.69 2049.21 -3068.38 0.00 0.00 3667.72 Start Dir 4º/100' : 5815.5' MD, 4153.69'TVD
8 6729.52 87.00 312.00 4477.15 2580.77 -3716.68 4.00 10.20 4506.03 End Dir : 6729.52' MD, 4477.15' TVD
9 6879.52 87.00 312.00 4485.00 2681.00 -3828.00 0.00 0.00 4655.73 Start Dir 2º/100' : 6879.52' MD, 4485'TVD
10 7075.50 90.73 310.80 4488.88 2810.54 -3974.95 2.00 -17.90 4851.57 End Dir : 7075.5' MD, 4488.88' TVD
11 8054.89 90.73 310.80 4476.40 3450.40 -4716.33 0.00 0.00 5830.79 MPU B-35 wp05 tgt2 Start Dir 2º/100' : 8054.89' MD, 4476.4'TVD
12 8205.32 88.92 308.39 4476.86 3546.27 -4832.23 2.00 -127.01 5981.20 End Dir : 8205.32' MD, 4476.86' TVD
13 8655.51 88.92 308.39 4485.35 3825.81 -5185.01 0.00 0.00 6431.13 Start Dir 2º/100' : 8655.51' MD, 4485.35'TVD
14 8736.64 90.50 308.76 4485.76 3876.40 -5248.44 2.00 13.05 6512.24 End Dir : 8736.64' MD, 4485.76' TVD
15 9236.64 90.50 308.76 4481.40 4189.42 -5638.31 0.00 0.00 7012.10 MPU B-35 wp05 tgt3 Start Dir 2º/100' : 9236.64' MD, 4481.4'TVD
16 9572.79 94.27 303.19 4467.41 4386.61 -5909.95 2.00 -55.84 7346.94 End Dir : 9572.79' MD, 4467.41' TVD
17 9616.86 94.27 303.19 4464.13 4410.66 -5946.73 0.00 0.00 7390.58 Start Dir 2º/100' : 9616.86' MD, 4464.13'TVD
18 10099.43 88.50 310.93 4452.47 4701.06 -6331.24 2.00 126.53 7871.79 End Dir : 10099.43' MD, 4452.47' TVD
19 10249.43 88.50 310.93 4456.40 4799.30 -6444.52 0.00 0.00 8021.72 MPU B-35 wp05 tgt4 Start Dir 2º/100' : 10249.43' MD, 4456.4'TVD
20 10384.04 91.19 310.94 4456.76 4887.49 -6546.21 2.00 0.12 8156.30 End Dir : 10384.04' MD, 4456.76' TVD
21 10802.25 91.19 310.94 4448.06 5161.44 -6862.08 0.00 0.00 8574.37 Start Dir 2º/100' : 10802.25' MD, 4448.06'TVD
22 10961.86 88.00 310.93 4449.19 5266.00 -6982.64 2.00 -179.90 8733.93 End Dir : 10961.86' MD, 4449.19' TVD
23 11311.86 88.00 310.93 4461.40 5495.16 -7246.91 0.00 0.00 9083.67 MPU B-35 wp05 tgt5 Start Dir 2º/100' : 11311.86' MD, 4461.4'TVD
24 11402.94 89.60 310.07 4463.30 5554.29 -7316.15 2.00 -28.26 9174.73 End Dir : 11402.94' MD, 4463.3' TVD
25 12576.41 89.60 310.07 4471.40 6309.63 -8214.17 0.00 0.00 10348.17 MPU B-35 wp05 tgt6 Total Depth : 12576.41' MD, 4471.4' TVD
0450900135018002250270031503600405045004950540058506300South(-)/North(+) (900 usft/in)-8100 -7650 -7200 -6750 -6300 -5850 -5400 -4950 -4500 -4050 -3600 -3150 -2700 -2250 -1800 -1350 -900 -450 0West(-)/East(+) (900 usft/in)MPU B-35 wp05 tgt6MPU B-35 wp05 tgt5MPU B-35 wp05 tgt4MPU B-35 wp05 tgt2MPU B-35 wp05 tgt3MPU B-35 wp05 tgt19 5/8" x 12 1/4"4 1/2" x 8 1/2"75012501500175020002250250027503000325035003750400042504471MPU B-35 wp10Start Dir 2º/100' : 250' MD, 250'TVDStart Dir 3º/100' : 500.2' MD, 499.88'TVDStart Dir 4º/100' : 750.2' MD, 746.82'TVDEnd Dir : 1804.44' MD, 1621.74' TVDFault 1 DTE (40' Throw)Start Dir 4º/100' : 5815.5' MD, 4153.69'TVDEnd Dir : 6729.52' MD, 4477.15' TVDStart Dir 2º/100' : 6879.52' MD, 4485'TVDEnd Dir : 7075.5' MD, 4488.88' TVDStart Dir 2º/100' : 8054.89' MD, 4476.4'TVDEnd Dir : 8205.32' MD, 4476.86' TVDStart Dir 2º/100' : 8655.51' MD, 4485.35'TVDEnd Dir : 8736.64' MD, 4485.76' TVDStart Dir 2º/100' : 9236.64' MD, 4481.4'TVDEnd Dir : 9572.79' MD, 4467.41' TVDStart Dir 2º/100' : 9616.86' MD, 4464.13'TVDFault 2 DTE (10' - 40' Throw)End Dir : 10099.43' MD, 4452.47' TVDStart Dir 2º/100' : 10249.43' MD, 4456.4'TVDFault 3 DTE (20' - 50' Throw)End Dir : 10384.04' MD, 4456.76' TVDFault 4 DTE (10' - 50' Throw)Start Dir 2º/100' : 10802.25' MD, 4448.06'TVDEnd Dir : 10961.86' MD, 4449.19' TVDStart Dir 2º/100' : 11311.86' MD, 4461.4'TVDEnd Dir : 11402.94' MD, 4463.3' TVDTotal Depth : 12576.41' MD, 4471.4' TVDCASING DETAILSTVDTVDSS MDSize Name4485.02 4428.62 6880.00 9-5/8 9 5/8" x 12 1/4"4471.40 4415.00 12576.41 4-1/2 4 1/2" x 8 1/2"Project: Milne PointSite: M Pt B PadWell: Plan: MPU B-35Wellbore: MPU B-35Plan: MPU B-35 wp10WELL DETAILS: Plan: MPU B-3522.70+N/-S +E/-W Northing Easting Latitude Longitude0.00 0.00 6023135.70 571984.0370° 28' 24.577 N149° 24' 43.315 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU B-35, True NorthVertical (TVD) Reference:MPU B-35 As staked RKB @ 56.40usftMeasured Depth Reference:MPU B-35 As staked RKB @ 56.40usftCalculation Method:Minimum Curvature
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0.001.002.003.004.00Separation Factor0 375 750 1125 1500 1875 2250 2625 3000 3375 3750 4125 4500 4875 5250 5625 6000 6375 6750 7125Measured Depth (750 usft/in)MPU B-31 wp08MPB-18MPU B-33MPB-29MPB-02MPU B-32No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.NOERRORSWELL DETAILS:Plan: MPU B-35 NAD 1927 (NADCON CONUS)Alaska Zone 0422.70+N/-S +E/-W Northing EastingLatitudeLongitude0.000.006023135.70 571984.03 70° 28' 24.577 N149° 24' 43.315 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU B-35, True NorthVertical (TVD) Reference:MPU B-35 As staked RKB @ 56.40usftMeasured Depth Reference:MPU B-35 As staked RKB @ 56.40usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2022-02-23T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool33.70 1200.00 MPU B-35 wp10 (MPU B-35) GYD_Quest GWD1200.00 6880.00 MPU B-35 wp10 (MPU B-35) 3_MWD+IFR2+MS+Sag6880.00 12576.41 MPU B-35 wp10 (MPU B-35) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)0 375 750 1125 1500 1875 2250 2625 3000 3375 3750 4125 4500 4875 5250 5625 6000 6375 6750 7125Measured Depth (750 usft/in)MPU B-31 wp08MPB-27MPB-23MPB-06MPU B-30MPB-17MPB-25MPU B-33MPB-29MPB-02MPU B-32GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference33.70 To 12576.41Project: Milne PointSite: M Pt B PadWell: Plan: MPU B-35Wellbore: MPU B-35Plan: MPU B-35 wp10Ladder / S.F. Plots1 of 2CASING DETAILSTVD TVDSS MD Size Name4485.02 4428.62 6880.00 9-5/8 9 5/8" x 12 1/4"4471.40 4415.00 12576.41 4-1/2 4 1/2" x 8 1/2"
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0.001.002.003.004.00Separation Factor6825 7150 7475 7800 8125 8450 8775 9100 9425 9750 10075 10400 10725 11050 11375 11700 12025 12350 12675 13000Measured Depth (650 usft/in)MPD-02AMPU B-31 wp08MPB-18MPU B-33MPB-29No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:Plan: MPU B-35 NAD 1927 (NADCON CONUS)Alaska Zone 0422.70+N/-S +E/-W Northing EastingLatitudeLongitude0.000.006023135.70571984.0370° 28' 24.577 N149° 24' 43.315 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU B-35, True NorthVertical (TVD) Reference:MPU B-35 As staked RKB @ 56.40usftMeasured Depth Reference:MPU B-35 As staked RKB @ 56.40usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2022-02-23T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool33.70 1200.00 MPU B-35 wp10 (MPU B-35) GYD_Quest GWD1200.00 6880.00 MPU B-35 wp10 (MPU B-35) 3_MWD+IFR2+MS+Sag6880.00 12576.41 MPU B-35 wp10 (MPU B-35) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)6825 7150 7475 7800 8125 8450 8775 9100 9425 9750 10075 10400 10725 11050 11375 11700 12025 12350 12675 13000Measured Depth (650 usft/in)GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference33.70 To 12576.41Project: Milne PointSite: M Pt B PadWell: Plan: MPU B-35Wellbore: MPU B-35Plan: MPU B-35 wp10Ladder / S.F. Plots2 of 2CASING DETAILSTVD TVDSS MD Size Name4485.02 4428.62 6880.00 9-5/8 9 5/8" x 12 1/4"4471.40 4415.00 12576.41 4-1/2 4 1/2" x 8 1/2"
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