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M.
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MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Thursday, December 22, 2022
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Bob Noble
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
Hilcorp Alaska, LLC
B-36
MILNE PT UNIT B-36
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 12/22/2022
B-36
50-029-23727-00-00
222-110-0
N
SPT
4341
2221100 3500
411 413 409 410
INITAL P
Bob Noble
11/5/2022
MIT-IA to 3500 psi as per PTD
30 MinPretest Initial 15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:
MILNE PT UNIT B-36
Inspection Date:
Tubing
OA
Packer Depth
762 3710 3589 3558IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitRCN221110154206
BBL Pumped:5.5 BBL Returned:5.2
Thursday, December 22, 2022 Page 1 of 1
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-36
PTD: 222-110
API: 50-029-23727-00-00
FINAL LWD FORMATION EVALUATION LOGS (08/29/2022 to 09/10/2022)
x EWR-M5, AGR, ABG, DGR, 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:222-110
T37167
Kayla Junke
Digitally signed by Kayla
Junke
Date: 2022.10.20 11:09:45
-08'00'
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: 23.2' 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 (ft MSL)
22.Logs Obtained:
23.
BOTTOM
20" X-52 123'
L-80 1882'
L-80 4391'
4-1/2" L-80 4496'
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
9-5/8"12-1/4"
9/9/2022
8/29/2022
ADL 047438, 047437 & 047433
81-054
2018' / 1768'
N/AN/A
None
13060' / 4496'
ROP, AGR, DGR, ABG, EWR, ADR MD & TVD
Sr Res EngSr Pet GeoSr Pet Eng
Oil-Bbl: Water-Bbl:
Oil-Bbl:
suspension, or abandonment, 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 if necessary
Water Injection
4-1/2" Frac Sleeve 9/12/2022
6356' - 6360' 4472' - 4473'
4-1/2" Drilled Liner 9/12/2022
6679' - 13018' 4507' - 4493'
Water-Bbl:
PRODUCTION TEST
*Pre-Produced, converted to Injector 10/14/22*
Date of Test:
Flow Tubing
129.5#
47#
123'
2161' 5970'
Gas-Oil Ratio:Choke Size:
Per 20 AAC 25.283 (i)(2) attach electronic information
40#
13060'
1882'
4342'
DEPTH SET (MD)
5777' / 4342'
PACKER SET (MD/TVD)
Liner Top Packer
Surface
CASING WT. PER
FT.GRADE
13.5#
568613
563549
TOP
SETTING DEPTH MD
Surface
SETTING DEPTH TVD
6030446
BOTTOM TOP
Surface
HOLE SIZE AMOUNT
PULLED
50-029-23727-00-00
MPU B-36
571812 6023788
1870' FNL, 2434' FEL, Sec. 13, T13N, R10E, UM, AK
CEMENTING RECORD
6026501
3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503
9/14/2022
667' FSL, 739' FWL, Sec. 18, T13N, R10E, UM, AK
2120' FSL, 2181' FEL, Sec. 11, T13N, R10E, UM, AK
222-110
Milne Point Field / Schrader Bluff Oil Pool
59.6'
13058' / 4496'
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Hilcorp Alaska, LLC
WAG
Gas
Driven
Surface 2161' Stg 1 L - 500sx / T - 400 sx
Stg 2 L - 870 sx / T - 270 sx
5777'
5785'3-1/2" 9.3# L-80
SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date Perfd):
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 Drilled Liner8-1/2"
TUBING RECORD
Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment
By James Brooks at 3:35 pm, Oct 17, 2022
Completed
9/14/2022
JSB
RBDMS JSB 110222
GDSR-11/3/22MGR12NOV2022
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
27' 27'
2045' 1795'
Top of Productive Interval 6619' 4504'
1959' 1728'
3064' 2532'
4962' 3904'
5913' 4379'
6619' 4504'
SB OA 6619' 4504'
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
Contact Email:joseph.lastufka@hilcorp.com
Authorized Contact Phone: 907-777-8400
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: 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.
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).
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment, 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.
Formation at total depth:
Ugnue LA3
LOT / FIT Data Sheet, Drilling and Completion Reports, Post-Rig Summary, Casing and Cement Report, Definitive Directional
Survey, Wellbore Schematic
Signature w/Date:
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.
INSTRUCTIONS
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).
Yes No
Well tested? Yes No
28. CORE DATA
If yes, list intervals and formations tested, briefly summarizing test results.
Attach separate pages to this form, if needed, and submit detailed test
information, including reports, per 20 AAC 25.071.
NAME
Schrader Bluff NA
SV5
SV1
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram
with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical
reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted.
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis,
paleontological report, production or well test results, per 20 AAC 25.070.
If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form,
if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071.
Authorized Name: Monty Myers
Authorized Title: Drilling Manager
Schrader Bluff OA
Permafrost - Base
29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS
Permafrost - Top
Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment
10.17.2022
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: 2022.10.17 15:15:43 -08'00'
Monty M
Myers
CASING AND LEAK-OFF FRACTURE TESTS
Well Name:MPU B-36 Date:9/5/2022
Csg Size/Wt/Grade:9.625"40# x 47#, L-80 Supervisor:Barber / Toomey
Csg Setting Depth:5969 TMD 4391 TVD
Mud Weight:9.45 ppg LOT / FIT Press =582 psi
.
LOT / FIT =12.00 Hole Depth =5996 md
Fluid Pumped=1.1 Bbls Volume Back =1.0 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
->175 ->4218
->2 125 ->8335
->3 195 ->12 493
->4 235 ->16 685
->5 275 ->20 871
->6 318 ->24 1055
->7 378 ->28 1312
->8 429 ->32 1512
->9 461 ->36 1756
->10 535 ->40 2013
->11 585 ->44 2274
->12 ->48 2487
->13 ->51 2610
Enter Holding Enter Holding Enter Holding Enter Holding
Time Here Pressure Here Time Here Pressure Here
->0 585 ->0 2610
->1 577 ->5 2600
->2 572 ->10 2600
->3 569 ->15 2600
->4 565 ->20 2600
->5 563 ->25 2600
->6 561 ->26 2600
->7 558 ->27 2597
->8 556 ->28 2597
->9 554 ->29 2595
->10 552 ->30 2595
->11 551 ->
->12 549 ->
->13 547 ->
->14 546
->15 544
->
0
1
2
3 4 5
6
7
8 9
10
11
0
4
8
12
16
20
24
28
32
36
40
44
48
51
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 102030405060
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
)
585577572569565563561558556554552551549547546544
2610 2600 2600 2600 2600 260026002597259725952595
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
_____________________________________________________________________________________
Revised By: TDF 9/27/2022
SCHEMATIC
Milne Point Unit
Well: MPU B-36
Last Completed: 9/14/2022
PTD: 222-110
CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm BPF
20" Conductor 129.5 / X-52 / Weld N/A Surface 124’ N/A
9-5/8" Surface 47 / L-80 / TXP 8.525” Surface 2,161’ 0.0732
9-5/8" Surface 40 / L-80 / TXP 8.679” 2,161’ 5,970’ 0.0758
4-1/2” Solid / Slotted Liner 13.5 / L-80 / Hyd 625 3.920” 5,777’ 13,060’ 0.0149
TUBING DETAIL
3-1/2" Tubing 9.3 / L-80 / EUE 8RD 2.992” Surface 5,785’ 0.0087
OPEN HOLE / CEMENT DETAIL
Driven 20” Conductor
12-1/4"Stg 1 –Lead 500 sx / Tail 400 sx
Stg 2 –Lead 870 sx / Tail 270 sx
8-1/2” Cementless Drilled Liner
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
GENERAL WELL INFO
API#: 50-029-23727-00-00
Completion Date: 9/14/2022
WELL INCLINATION DETAIL
KOP @ 396’
90° Hole Angle @ 6,779’ MD
TD =13,060’(MD) / TD =4,496’(TVD)
20”
Orig. KB Elev.: 56.9’ / GL Elev.: 23.2’
3-1/2”
9
2
9-5/8”
1
4/5
See
Slotted
Liner
Detail
PBTD =13,058’(MD) / PBTD =4,496’(TVD)
9-5/8” ‘ES’
Cementer @
2,179’
4-1/2”
6
3
7
8
JEWELRY DETAIL
No Top MD Item ID
Upper Completion
1 5,361’ Sliding Sleeve 2.813” X profile, covered ports (opens down) 2.813”
2 5,417’ Zenith Gauge Carrier 2.992”
3 5,470’ Nipple, 2.813” XN, 2.75” No-Go 2.753”
4 5,774’ 8.25” No Go Locater Sub (spaced out 1.25’) 6.170”
5 5,775’ Bullet Seals – TXP Top Box x Mule Shoe 6.170”
Lower Completion
6 5,777’ 9-5/8” SLZXP Liner Top Packer 6.190”
7 6,356’ 4-1/2” NCS Frac Sleeve 3.920”
8 6,377’ 4.5” Welltec ECP 3.958”
9 13,058’ Shoe
4-1/2” Frac Sleeve
Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD)
1 6356’ 4472’ 6360’ 4473’
4-1/2” Drilled Liner
Top (MD) Top (TVD) Btm (MD) Btm (TVD)
6679’ 4507’ 13018’ 4493’
Activity Date Ops Summary
8/27/2022 Set matting boards on B-36 and extra matting boards for jockeying the rig. Spot well head equipment on the matting boards behind the well. Back rig onto B-36. Too
tight to clear the cellar substructure. Pull forward and reposition. Spot over and center the rig over well B-36. Shim and level the rig. Secure the stair, handrails and
landings. PJSM. Skid the rig floor into drilling position. RU the rig floor. Break apart two diverter spacer spools. Lift the diverter annular and tee. Install the diverter
spacer spool. NU spacer spool and diverter tee. NU diverter riser. Spot auxiliary buildings. SimOps: Work on rig acceptance checklist. Load and strap 5" DP in
the ODS pipe shed.
8/28/2022 Begin NU diverter line. Install surface riser. Spot fuel trailer, cuttings box & rock washer. Install 90' mousehole. Processing 5" drill pipe on ODS of the pipe shed. On
highline power at 09:00. Roads & pads was busy moving ASR which delayed fuel trailer and rock washer. Suspended rig floor operations for Doyon field and drilling
superintendents to inspect top drive rails. Measured top drive torque tube for plumb. Identified shimming needed. Will perform shimming before spud. Finished
processing 201 joints of 5" drill pipe and continued with diverter line. Notified AOGCC of upcoming diverter test at 10:42 on 8/27/2022. AOGCC inspector Bob
Noble waived witness of diverter test at 13:34 on 8/27/2022. Finished RU diverter line. Installed Super Sucker extensions on the rockwasher. Spot electrical board,
mud lab, 5 star, smoke shack and envirovac. Load 17 joints of HWDP and BHA into the pipe shed. Take on 4,805 gallons of diesel fuel. SimOps: Loosen top drive
rail bolts and install shims. Continue shimming top drive rails. Tighten top drive rail bolts. Weld pad eyes for cross braces. Cleanup work area and inspect the
derrick for tools. SimOps: Load the pits with spud mud. Changeout the saver sub. Inspect the grabber dies. Service the top drive. All rig floor operations which were
suspended from 9AM for rig repair will be classified as rig repair time. Perform the diverter function test with 5"" HWDP. The states right to witness was waived by
AOGCC inspector Bob Noble via email on 8/28/22 at 13:34 hours. Knife valve opened in 16 seconds and the annular closed in 24 seconds. Accumulator Test:
System pressure = 3,000 psi. Pressure after closure = 1,825 psi. 200 psi attained in 39 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 = 209'.
Nearest ignition source is 76' way from the end of the diverter. Flush the flow line with the cement line. Blow down the cement line. Install 30' mouse hole in the
rotary table. MU 5 stands of 5" HWDP. Lay down 30' mouse hole. Pre-spud meeting with all parties involved. Discuss well objectives and surface hole hazards.
PU and MU 12-1/4" Kymera bit, 8" mud motor with 1.5° bend and crossover sub to 36'. Daily disposal to G&I = 0 bbls Total disposal to G&I = 204 bbls. Daily water
hauled from A-pad = 485 bbls Total water hauled from A-pad = 485 bbls. Daily fluid loss = 0 bbls Total fluid loss = 0 bbls.
8/29/2022 Fill lines with water and pressure test mud lines to 3500 PSI - good. Fill stack with water and check for leaks - none. Tag fill in conductor at 44'. Cleanout 20"
conductor from 44' to 124' with 475 GPM, 550 PSI, 30 RPM, 2K TQ. Drill 12-1/4" hole from 124' to 217', 93' drilled, 93'/hr AROP. 450 GPM, 580 PSI, 40 RPM, 2K
TQ, 3K WOB. 50K PU / 50K SO / 50K ROT. MW 9.0 in / 9.05 out, Vis 171 in / 194 out BROOH f/ 217' t/ 124' while circulating a bottom up. Rack back a stand to
35'. P/U and inspect bit. M/U MWD tools with Gyro While Drilling, directional, gamma, resistivity and PWD to 97'. Initialize MWD tools. M/U two NMDC & XO to
159'. Shallow pulse test MWD. Ream to bottom and resume drilling. Conveyor chain locked up in the sprocket, tighten chain. Drill 12-1/4" surface hole from 217' to
457' (457' TVD). Drilled 240' = 120'/hr AROP. 450 GPM = 1,000 psi, WOB = 5-10K, PU = 66K, SO = 70K. MW = 9.1 ppg, Vis = 285, ECD = 9.56 ppg. Begin
3°/100' build at 300'. Begin 4°/100' build at 600'. Drill 12-1/4" surface hole from 457' to 997' (976' TVD). Drilled 540' = 90'/hr AROP. 450 GPM = 1,420 psi, 40 RPM
= 4K ft-lbs torque, WOB = 5-15K, PU = 85K, SO = 84K, ROT = 85K. MW = 9.1 ppg, Vis = 300, ECD = 10.1 ppg. Last Gyro survey at 863'. First clean MWD survey
at 944', 117' from B-08 Drill 12-1/4" surface hole from 997' to 1,473' (1,345' TVD). Drilled 476' = 79.33'/hr AROP. 450 GPM = 1,410 psi, 40 RPM = 3-6K ft-lbs
torque, WOB = 5-10K, PU = 92K, SO = 86K, ROT = 90K. MW = 9.35 ppg, Vis = 186, ECD = 10.05 ppg. Begin 4.5°/100' build at 1,400'. Rig off highline power and
on generators at 03:00 hours. Last survey at 1,325.59’ MD / 1,248.14' TVD, 43.29° INC, 281.29° AZM, Distance from WP15 = 20.77’, 20.77’ high & 0.29’ right.
Daily disposal to G&I = 641 bbls Total disposal to G&I = 845 bbls. Daily water hauled from A-pad = 240 bbls Total water hauled from A-pad = 725 bbls. Daily fluid
loss = 0 bbls Total fluid loss = 0 bbls.
8/30/2022 Drill 12-1/4" hole from 1,473' to 1,960' (1,734' TVD). Drilled 487' = 81.17'/hr AROP. 450 GPM = 1,440 psi, 40 RPM = 3-6K ft-lbs TQ, WOB = 6-12K. PU= 101K, SO
= 90K, ROT = 95K. MW = 9.45 ppg, Vis = 173, ECD = 10.1 ppg. Drill 12-1/4" hole from 1,960' to 2,710' (2,274' TVD). Drilled 750' = 125'/hr AROP. 500 GPM =
1,660 psi, 60 RPM = 5K ft-lbs TQ, WOB = 5-10K. PU= 121K, SO = 91K, ROT = 104K. MW = 9.4 ppg, Vis = 150, ECD = 10.5 ppg, max gas units = 126 Pumped
36 bbl hi vis sweep at 2,094', not seen due to 300+ vis mud returns. Base of permafrost logged at 2,045' MD / 1,795' TVD. Began 44° tangent at 2,180'. Halliburton
delivered 870 sxs of ArcticCem. Drill 12-1/4" hole from 2,710' to 3,377' (2,760' TVD). Drilled 667' = 111.67'/hr AROP. 500 GPM = 1,720 psi, 80 RPM = 7K ft-lbs
TQ, WOB = 5-10K. PU= 137K, SO = 97K, ROT = 110K. MW = 9.3 ppg, Vis = 92, ECD = 10.3 ppg, max gas units = 177 Maintain 44° tangent. Pump 35 bbl hi vis
sweep at 3,090', back on time with 10% increase. Drill 12-1/4" hole from 3,377' to 4,043' (3,237' TVD). Drilled 666' = 111'/hr AROP. 500 GPM = 1,900 psi, 80 RPM
= 10K ft-lbs TQ, WOB = 10-12K. PU= 155K, SO = 102K, ROT = 123K. MW = 9.5 ppg, Vis = 103, ECD = 10.2 ppg, max gas units = 126 Maintain 44° tangent. Top
of the Ugnu at 3,469’ (2,826’ TVD). Last survey at 3,800.66’ MD / 3,067.34’ TVD, 44.98° INC, 321.00° AZM, Distance from WP15 = 7.70’, 0.80’ high & 7.65’ left.
Daily disposal to G&I = 1,389 bbls Total disposal to G&I = 2,234 bbls. Daily water hauled from A-pad = 455 bbls Total water hauled from A-pad = 940 bbls. Daily
fluid loss = 0 bbls Total fluid loss = 0 bbls.
8/31/2022 Drill 12-1/4" hole from 4,043' to 4,690' MD (3712' TVD). Drilled 647' = 108'/hr AROP. 550 GPM = 2350 psi, 80 RPM = 12.5K ft-lbs TQ, WOB = 10-15K. PU= 170K,
SO = 101K, ROT = 125K. MW = 9.3 ppg, Vis = 228, ECD = 10.7 ppg, max gas units = 202. Pumped 30 bbl sweep at 4233' back on time with 20% increase. Drill
12-1/4" hole from 4,690' to 5,139' MD (4,028' TVD). Drilled 449' = 75'/hr AROP. 550 GPM = 2,020 psi, 80 RPM = 12K ft-lbs TQ, WOB = 12K. PU= 188K, SO =
108K, ROT = 136K. MW = 9.4 ppg, Vis = 195, ECD = 10.3 ppg, max gas units = 201 Pumped 30 bbl sweep at 5,025' back on time with 40% increase. Begin
4°/100' build at 5,100'. Drill 12-1/4" hole from 5,139' to 5,566' MD (4,262' TVD). Drilled 427' = 71.17'/hr AROP. 550 GPM = 1,930 psi, 80 RPM = 13K ft-lbs TQ,
WOB = 10-15K. PU= 200K, SO = 105K, ROT = 140K. MW = 9.2 ppg, Vis = 67, ECD = 10.1 ppg, max gas units = 152 Drill 12-1/4" hole from 5,566' to TD at 5,976'
MD (4,393' TVD). Drilled 410' = 91.1'/hr AROP. 550 GPM = 2,250 psi, 80 RPM = 15K ft-lbs TQ, WOB = 15K. PU= 200K, SO = 104K, ROT = 139K. MW = 9.3 ppg,
Vis = 57, ECD = 10.0 ppg, max gas units = 277. Top of the SB_NA sand at 5,913' (4,379' TVD) Obtain final survey. BROOH to 5,883' and rack back 1 stand. Final
survey at 5,923.34’ MD / 4,381.2’ TVD, 77.45° INC, 298.96° AZM. Distance from WP15 = 6.90’, 6.90’ high & 0.07’ right. Pump 30 bbl hi-vis sweep and circulate out
of the well at 550 GPM = 2,100 psi, 80 RPM = 10-17K ft-lbs TQ reciprocating 94'. Back on time with 20% increase. Daily disposal to G&I = 1,087 bbls Total
disposal to G&I = 3,321 bbls. Daily water hauled from A-pad = 380 bbls Total water hauled from A-pad = 1,320 bbls. Daily fluid loss = 0 bbls Total fluid loss = 0
bbls.
8/29/2022Spud Date:
Well Name:
Field:
County/State:
MP B-36
Milne Point
Hilcorp Energy Company Composite Report
, Alaska
50-029-23727-00-00API #:
9/1/2022 Wash back to TD at 5976'. Observe the well for flow and the well is static. BROOH from 5,976' to 4,328' MD. 20-40 FPM as hole dictates. Reduced RPMs from
80 to 60 due to excessive vibration on MWD tools. Saw periodic minor torque and pressure spikes. Slowed pulling speed to mitigate. 550 GPM = 1,700 psi, 60
RPM = 13K ft-lbs TQ. PU = 202K, SO = 105K BROOH from 4,328' to 2,235' MD at 20-40 FPM. Slow pulling speed as hole dictates. 550 GPM = 1,470 psi, 60
RPM = 5K ft-lbs TQ, 22% flow. PU = 134K, SO = 87K, ROT = 120K. max gas units = 100 BROOH from 2,235' to 1,059' pulling 20-40 FPM slowing as needed to
clean up slides/tight spots. 550 GPM = 1,700 PSI, 80 RPM = 5K ft/lbs torque, max gas units = 0. PU = 115K, SO = 75K, ROT = 85K. B-pad power outage from
20:30 to 23:30 hours. BROOH from 1,059' to 766' (HWDP) pulling 20-40 FPM slowing as needed to clean up slides/tight spots. 550 GPM = 1,500 PSI, 80 RPM =
5K ft/lbs torque, max gas units = 0. Conveyor #1 packed off and the chain came off the sprocket. BROOH from 766' to 714' (HWDP). Observe the well for flow -
static. Attempt to POOH on elevators but unable to. BROOH from 714' to 446'. Pump out of hole from 446' to 375' then able to pull on elevators. B-pad lost power
at 01:30 hours. TOOH from 375' to 159'. PJSM. LD 2 NMFCs to 97'. Download MWD data. LD remaining BHA. B-pad power restored at 04:15 hours. Observed
slight wear on top edge of 10-3/8” ILS stabilizer – re-runnable. The 12” motor stabilizer showed considerable wear to the top 1/3 of the 4 ribs, consistent with back
reaming operations. PDC grade: 1-2-BT-G-X-1-NO-TD. Tri cone grade: 1-1-WT-A-E-1-NO-TD Daily disposal to G&I = 872 bbls Total disposal to G&I = 4,193 bbls.
Daily water hauled from A-pad = 1,100 bbls Total water hauled from A-pad = 2,420 bbls. Daily fluid loss = 48 bbls Total fluid loss = 48 bbls.
9/2/2022 Clean and clear rig floor. Mobilize DDI casing equipment to rig floor. R/U "Volant" CRT, bail extenstions w/ 350T side door elevators. Set BJ 350T spiders and
secure same. Flashlight shoe track (good). 72 ea bow spring centralizers on floor. R/U casing backup tongs. R/U 13-5/8 sgl stack pwr PJSM. MU 9-5/8", 40#, L-
80, TXP-BTC shoe track. Bakerlok 1-4 connections with 21-25k tq. HES rep installed "top hat" above float collar. Pump thru shoe track and check floats (good).
Continue RIH from 166' to 245' . TQ = 21K ft-lbs with Volant tool. Fill on the fly and top off every 10 joints. Installing centralizer per tally. RIH with 9-5/8", 40#, L-
80, TXP-BTC casing from 245' to 2,292'. TQ = 21K ft-lbs with Volant tool. Fill on the fly and top off every 10 joints. Installing centralizer per tally. Loss rate = 5
BPH. Circulate 1.5x BU at start of the tangent section, below the permafrost staging up to 6 BPM = 170 psi. MW = 9.4 ppg, Vis = 45. Lost 20 bbls while circulating.
RIH with 9-5/8", 40#, L-80, TXP-BTC casing from 2,292' to 3,605'. TQ = 21K ft-lbs with Volant tool. Fill on the fly and top off every 10 joints. Installing centralizer
per tally. Loss rate = 5 BPH Top drive started leaking hydraulic oil. Grease the RLA RIH with 9-5/8", 40#, L-80, TXP-BTC casing from 3,605' to 3,770'. TQ = 21K ft-
lbs with Volant tool. Fill on the fly and top off every 10 joints. Installing centralizer per tally. MU ES cementer and BakerLok the connections from 3,770' to 3,808'.
RIH with 9-5/8", 47#, L-80, TXP-BTC casing from 3,808' to 4,634'. TQ = 24K ft-lbs with Volant tool. Fill on the fly and top off every 10 joints. Installing centralizer
per tally. Loss rate = 5 BPH Circulate 1 casing volume staging up to 6 BPM = 280 psi. MW = 9.4+ ppg, Vis = 36. Lost 10 bbls while circulating. RIH with 9-5/8",
47#, L-80, TXP-BTC casing from 4,634' to 5,336'. TQ = 24K ft-lbs with Volant tool. Fill on the fly and top off every 10 joints. Installing centralizer per tally. Loss rate
= 5 BPH. Daily disposal to G&I = 549 bbls Total disposal to G&I = 4,742 bbls. Daily water hauled from A-pad = 460 bbls Total water hauled from A-pad = 2,880
bbls. Daily fluid loss = 165 bbls Total fluid loss = 213 bbls.
9/3/2022 RIH with 9-5/8", 47#, L-80, TXP-BTC casing from 5,336' to 5976' MD with 10K tag on depth'. PU = 350K & SO = 125K. TQ = 24K ft-lbs with Volant tool. Fill on the
fly and top off every 10 joints. Installing centralizer per tally. Loss rate = 5 BPH. LD tag jt (#53). Stage up to 8 BPM = 180 psi, 2-5 RPM = 17K ft-lbs TQ, Reduce
YP to ~15. MW in 9.35 / MW out 9.4. Pretreat last 50 bbls mud prior to shutting down for 1st stage cement job. RUHES cementers and stage support trucks. Prep
pits and cellar. PU = 275-300K, SO = 140K & ROT = 140K RU cement line to Volant tool. Stage up to 7 BPM = 240 psi, 19% flow out. PJSM, Wet lines with 5 bbls
H2O (HES). PT low kick out 1,100/4,000 psi. Pump 1st stage cement job as follows: 60 bbls 10 ppg Tuned spacer with 4# red dye & 5 lb/bbl poly flake (1st 10 bbls)
3.5 BPM = 320 psi. Drop bypass plug Mix & Pump 208 bbls (500 sxs, 2.347 ft^3/sk) 12 ppg EconoCem Type I II Lead cement, 2.347 yld, 3.5 BPM = 550 psi. 82
bbls (400 sx) 15.8 ppg HalCem Type I II Tail cmt, 1.156 yld, 3.5 BPM = 600 psi. Drop shutoff plug. Displace with 20 bbls H2O from cement Unit 5.5 BPM = 400 psi
Rig displaced (MP #2) with 247.6 bbls 9.4 ppg spud mud, 7 BPM = 210 psi. HES displaced 80 bbls 9.4 ppg spacer, 4.7 BPM = 500 psi. Rig displaced (MP #2)
89.2 bbls 9.4 ppg spud mud 6 BPM = 770 psi, Slowed last 10 bbls to 3 BPM = 750 FCP. Bump plugs at 3,335 stks (437.6 bbl calc / 436.8 bbls act). Pressure up to
1,120 psi and observe pressure breakover indicating we were pumping past plug. Shut down and check floats (good). Pressure up at 10 BPM, shift tool at 3,180
psi. Reduce rate to 3 BPM = 340 ICP thru ES tool at 2,181'. CIP @ 17:40 hrs. Lost 9 bbls during job. Rotate and reciprocate to 2960 stks. Work tq out and park in
tension 150K. Pump through ES cementer at 2,181 at 3 BPM = 430 psi. Pol-E-Flake was observed at 550 strokes Dump 75 bbls red dye spacer and interface, 25
bbls cement and 235 bbls tuned spacer & clabbored up mud to Rockwasher before taking good mud returns to pits & continue to circulate a total of 5 BU.
Disconnect knife valve from accumulator. Drain stack and flush with black water three times. Re-connect knife valve to the accumulator. Attempt to reestablish
circulation. Pressured up to 1,800 psi and then broke circulation. Circulate through the ES cement at 2,181' at 3 BPM = 450 psi ICP/170 psi FCP & 6 BPM = 690
psi ICP/340 psi FCP. PJSM with all parties involved for 2nd stage cement job. Blow air through the cement line to the cementers. Break out the Volant, clean, dope
the cup and reengage. Pump 5 bbls of water and PT lines to 1,000/3,500 psi (good test). Mix & pump 60 bbls of 10.0 ppg Tuned Spacer w/ 4# red dye & 5# Pol-E-
Flake in 1st 10 bbls at 3.8 BPM = 300 psi. Mix & pump 10.7 ppg Arctic Cem lead cement at 4 BPM = 575 psi ICP. 400 bbls of lead cement pumped as end of
report.
9/4/2022 Continue pumping 2nd stage cmt job. Pump a total of 446 bbls 10.7# lead, cement (870 sks, 2.833 ft^3/sk), 3.3 BPM = 400 psi. 56 bbls 15.8# tail cement (270 sks,
1.17 ft^3/sk) 3.3 BPM = 330 psi Drop closing plug HES pump 20 bbls water at 5.8 BPM = 700 psi. Rig (MP #2) displace and bump with 146.6 bbls 9.4# spud mud
(140 bbls calc) 4 BPM = 580 FCP. Pressure up and shift ES tool closed at 1,120 psi. 216 bbls green cement returned to surface. CIP at 07:22 hours. Check flow -
static Disconnect accumulator lines to the knife valve. Flush surface equipment with black water while functioning annular. BD surface lines and drain stack. ND
diverter stack from tee. RU bridge cranes to stack and lift same. Lift stack and set 9-5/8" "E" slips with 85K string weight. Vac out landing jt. Make rough cut
(32.49') LD landing jt. Pull riser, ND diverter tee. LD casing handling equipment. Make final cut and dress same. Install T-103 tubing head. PT lower seal to 3,800
psi (good). PT void to 5,000 psi (test good). Set BOP stack on Wellhead unbolt adapter flange from bottom of stack, and set stack back on moving pedestal. Install
2' spacer spool onto adapter flange and install bolts. Set BOP stack on the wellhead and NU. Install MPD riser. Install 90' mousehole. RU BOPE testing
equipment. Install the test plug. Flood the stack, choke manifold and lines with fresh water. Shell test the BOP stack to 250/3,000 psi (passed) Conduct initial
BOPE test to 250/3,000 psi: UPR & LPR (2-7/8” x 5” VBR’s) with 3-1/2” & 5” test joints, annular with 3-1/2” 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 Brian Bixby via email on 9/03/22 at 12:19
hours. Tests: 1. Annular with 3-1/2” test joint, 3” Demco kill, choke valves 1, 12, 13 & 14 (passed). 2. UPR with 3-1/2” test joint, HCR kill, 5” Dart valve choke valves
9 & 11 (passed). Note: Oteco connection leaked on the rig floor. Tighten and retest passed. 3. Upper IBOP, manual kill, 5” TIW, choke valves 5, 8 & 10 (passed). 4.
Lower IBOP, choke valves 4, 6 & 7 (passed). 5. Choke valve 2 (passed). 6. HCR choke (passed). 7. Manual choke (passed). Daily disposal to G&I = 1,701 bbls
Total disposal to G&I = 7,459 bbls. Daily water hauled from A-pad = 450 bbls Total water hauled from A-pad = 3,330 bbls. Daily fluid loss = 0 bbls Total fluid loss =
320 bbls.
9/5/2022 Conduct initial BOPE test to 250/3,000 psi: UPR & LPR (2-7/8” x 5” VBR’s) with 3-1/2” & 5” test joints, annular with 3-1/2” 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 Brian Bixby via email on 9/03/22
at 12:19 hours. Tests: 8. LPR with 3-1/2” test joint. 9. UPR with 5” test joint. 10. LPR with 5” test joint (passed). 11. Blind rams, choke valve 3 (passed). 12. Manual
adjustable choke (passed). 13. Hydraulic super choke (passed). F/P on Oteco connections (tighten and retest - Good), F/P on 5" TIW (function and retest - Good).
Accumulator Test: System pressure = 3025 psi. Pressure after closure = 1725 psi. 200 psi attained in 44 seconds. Full pressure attained in 195 seconds. Nitrogen
Bottles - 6 at 1975 psi RD test equipment. BD lines. Install 10" ID wear bushing. RILDS. LD test joint. Mobilize BHA components to rig floor. Prep pipe shed and
rig floor for handling BHA. MU 8-1/2" Smith XR+CPS tricone (.9419 TFA) with 14KTQ on 1.5° TerraForce motor. (6x) S-135 5" NC50 HWDP, 49.3#, SLB 6.5"
Hydra Jars (152.94 hrs), (11x) S-135 5" NC50 HWDP, 49.3#. Total BHA length = 587.63' TIH out of derrick from 587' to 2,110' MD on 5" DP. PU = 105K & SO =
80K Fill pipe. Wash down from 2,110' to 2,175' tagging stage tool on depth. Drill ES cementer from 2,175' to 2,183' MD. 380 GPM = 690 psi, 30 RPM = 4.5K ft-lbs
TQ, 24% flow, WOB = 3-7K. Washed down and chased debris from 2,183' to 2,390' before tripping clean. Continue TIH out of derrick from 2,390' to 5,724' MD on
5" DP. PU = 105K & SO = 80K Fill pipe. Wash down from 5,724' to tag on cement stringer at 5,800' at 2.5 BPM = 450 psi. Circulate and condition the mud at 430
GPM = 930 psi, 30 RPM = 15-19K ft-lbs TQ reciprocating 60'. RU testing equipment. PT the 9-5/8" casing to 2,500 psi for 30 minutes charted (good test). RD test
equipment and BD the cement line. Drill cement stringers from 5,800' to hard cement at 5,820'. Drill cement from 5,820' to 5,841'. Drill cement and 9-5/8" shoe
track from 5,841' to 5,969' (all equipment on depth) at 450 GPM = 1,130 psi, 30 RPM = 17K ft-lbs. PU = 225K, SO = 97K & ROT = 138K. Clean out the rat hole
from 5,969' to 5,976'. Ream through the baffle adapter, float collar and shoe 3 times each. Drill 20' of new formation from 5,976' to 5,996' (4,395' TVD) at 450 GPM
=1,240 psi, 30 RPM = 17K ft-lbs TQ, WOB = 15K. BR into the shoe and rack back 1 stand to 5,916'. Circulate and condition the mud for the FIT at 450 GPM =
1,190 psi, 30 RPM = 15-19K ft-lbs TQ reciprocating 90'. After 2 BU had good 9.45 ppg in/out. SO to 5,916'. RU testing equipment. Purge air from the choke/kill
line and choke manifold. Perform FIT to 12.0 ppg with casing shoe at 5,969' (4,391' TVD) with 9.45 ppg MW and 585 psi applied at surface. Pumped 1.1 bbls and
bled back 1.0 bbls. Blow down and RD testing equipment. Observe the well for flow - static. Pump 30 bbls dry job. TOOH with the cleanout assembly from 5,916'
to 3,154'. Daily disposal to G&I = 52 bbls Total disposal to G&I = 7,519 bbls. Daily water hauled from A-pad = 470 bbls Total water hauled from A-pad = 3,800
bbls. Daily fluid loss = 0 bbls Total fluid loss = 320 bbls. Daily metal recovered = 10 lbs Total metal recovered = 10 lbs.
9/6/2022 Continue POOH with the cleanout assembly from 3,154' to surface. L/D 15 jts excess 5" HWDP, Rack back 2 stds w/ jars. Drain mtr and B/O bit. L/D same. Bit
grade - 1,1,WT,A,X,I,NO,TD. Clean and clear rig floor. Mobilize BHA components to rig floor. Prep shed for picking up BHA. M/U 8.5" RSS assy w/ 8.5" NOV
(TK66), NRP, Geopilot assy, MWD with upper ILS. NM float (non ported), 3x NM flex DC, NM float (non ported), 1x 5"NC50 HWDP, SLB jars, 1x 5"NC50 HWDP.
Total BHA length 282.72'. TIH to 1232' MD w/ 5" NC50, S-135, 19.5# DP. Continue TIH F/ 1232' - T/ 5837' MD. Shallow pulse test (good) @ 2100' w/ 450 gpm,
1120 psi. Break in Geo Pilot as per DD @ 2100' MD. PJSM, Remove MPD trip nipple. Install bearing and pump thru lines (good). 2 bpm, 160 psi. PJSM for
displacing, pump 30 bbl hi vis spacer followed with 453 bbls new 8.8 ppg flo pro mud. 6 BPM, 480 psi, 15 rpm. Start 19k Tq,11k Tq final. Bit on bottom with new
mud making turn, then P/U into 9 5/8'' casing for remaining displacement. Dump spud mud returns and 50 bbls interface to rock Rack stand back & hang blocks.
PJSM, Slip and cut 72' drilling line. Inspect Drawworks brakes & linkage. Simops: Clean pit 4, and under shakers. Monitor MPD for pressure – No build. Service
Block & Topdrive and perform weekly Derrick inspection. MU stand drill pipe, Record SPRs, wash and ream to bottom at 5993' pumping 440 gpm, 1140 psi, 55
rpm, 11k torque Drill 8-1/2" lateral from 5996' to 6106’ (4420’ TVD.). 500 GPM = 1280 psi, 120 RPM = 14k Tq, WOB = 12k. MW = 8.9 ppg, Vis = 57, ECD = 9.9
ppg, max gas units = 201. PU = 170k, SO = 95k, ROT = 125k. MPD full open while drilling. Top of NB sand logged at 6040’ MD. Position tool joint at Rt. Shut
pumps down and bleed pressure off. Shut MPD choke and monitor pressures. Start with 41 psi, line hydrostatic pressure. Pressure build to 88 psi after 5 min
monitor. Trap 200 psi and monitor, pressure drop to 173 psi after 3 min and stabilize. Drill 8-1/2" lateral from 6106' to 6562' (4501' TVD). Drilled 456' = 114'/hr
AROP. 500 GPM = 1600 psi, 120 RPM = 13-15k Tq, WOB = 15-17k. MW = 9.1 ppg, Vis = 42, ECD = 10.36 ppg, max gas units = 352. PU = 170k, SO = 100k,
ROT = 130k Back ream 30' on connections. MPD full open while drilling and trap 230 PSI on connections. SB_NF sand logged at 6424' MD / 4483' TVD. Last
survey at 6398.63’ MD / 4479.05' TVD, 80.75° inc, 299.02° azm, 11.57' from plan, 6.9' high and 9.29’ right. Daily disposal to G&I = 776 bbls Total disposal to G&I
= 8295 bbls. Daily water hauled from A-pad = 250 bbls Total water hauled from A-pad = 6305 bbls. Daily fluid loss = 12 bbls Total fluid loss = 332 bbls. Daily
metal recovered = 4 lbs Total metal recovered = 14 lbs.
9/7/2022 Drill 8-1/2" lateral from 6562' to 7200' (4506' TVD). Drilled 638' = 106.3'/hr AROP. 500 GPM = 1520 psi, 120 RPM = 13-15k Tq, WOB = 7-15k. MW = 9.1 ppg, Vis
= 39, ECD = 10.36 ppg, max gas units = 428. PU = 170k, SO = 98k, ROT = 125k. Pump 30 bbl hi vis sweep @ 7134', back on time with 20% increase. Back ream
30' on connections. MPD full open while drilling and trap 185 PSI on connections. Enter the OA sand top @ 6619' md, 4447' tvd Drill 8-1/2" lateral from 7200' to
7800' (4500' TVD). Drilled 600' = 100'/hr AROP. 500 GPM = 1560 psi, 120 RPM = 13-16k Tq, WOB = 5-12k. MW = 9.1 ppg, Vis = 40, ECD = 10.34 ppg, Max Gas
= 252u. PU = 136k, SO = 96k, ROT = 125k Back ream 30' on connections. MPD full open while drilling and trap 150 PSI on connections. Maintain the OA sand
with 89-91° inc Drill 8-1/2" lateral from 7800' to 8181' (4498' TVD). Drilled 381' = 63.5'/hr AROP. 500 GPM = 1670 psi, 120 RPM = 14-16k Tq, WOB = 5-12k. MW
= 9.1 ppg, Vis = 37, ECD = 10.4 ppg, Max Gas = 278u. PU = 165k, SO = 93k, ROT = 125k. Back ream 30' on connections. MPD full open while drilling and trap
150 PSI on connections. Maintain the OA sand with 90-91° inc. Pump Hi Vis Sweep @ 7990'. Returned on time with a 20% increase in cuttings. Drill 8-1/2" lateral
from 8181' to 8790' (4497' TVD). Drilled 609' = 101/hr AROP. 500 GPM = 1660 psi, 120 RPM = 15-17k Tq, WOB = 5-18k. MW = 9.15 ppg, Vis = 41, ECD = 10.46
ppg, Max Gas = 328u. PU = 175k, SO = 90k, ROT = 130k. Maintain the OA sand with 89-91° inc Back ream 30' on connections. MPD full open while drilling and
trap 150 PSI on connections. Last survey at 8680.71’ MD / 4498.89' TVD, 90.49° inc, 315.74° azm, 4.65' from plan, 4.61' high and 0.63’ right. We have drilled 28
concretions for a total thickness of 209' (7.5% of the lateral). Daily disposal to G&I = 689 bbls Total disposal to G&I = 8984 bbls. Daily water hauled from A-pad =
785 bbls Total water hauled from A-pad = 7090 bbls. Daily fluid loss = 0 bbls Total fluid loss = 332 bbls. Daily metal recovered = 9 lbs Total metal recovered = 23
lbs.
9/8/2022 Drill 8-1/2" lateral from 8790' to 9325' (4498' TVD). Drilled 535' = 89.16/hr AROP. 490 GPM = 1690 psi, 120 RPM = 13-14k Tq, WOB = 8-10k. MW = 9.1 ppg, Vis
= 42, ECD = 10.61 ppg, Max Gas = 328u. PU = 170k, SO = 90k, ROT = 130k. Back ream 30' on connections. Pump 30 bbl hi vis sweep at 9037', back on time with
50% increase. Maintain the OA sand with 89-91° inc. MPD full open while drilling and trap 180 PSI on connections. Drill 8-1/2" lateral from 9325' to 9764' (4473'
TVD). Drilled 439' = 73/hr AROP. 500 GPM = 1920 psi, 120 RPM = 15-17k Tq, WOB = 10-15k. MW = 9.1 ppg, Vis = 40, ECD = 10.68 ppg, Max Gas = 328u. PU
= 175k, SO = 85k, ROT = 135k. Back ream 30' on connections. Maintain 91° in the OA sand , at 9520' turn up targeting 94° in anticipation of fault 1. MPD full open
while drilling and trap 180 PSI on connections. Note: at 9600' shut down 15 min, work pipe while C/O gasket on hardline swing to geo span. Drilled through fault #1
at 9565’, 39’ throw DTE. Drilled out the top of OA at 9456’ in anticipation of upcoming fault, reacquired the base of OA after the fault at 9708’ for a total of 252’ out of
zone. Drill 8-1/2" lateral from 9764' to 10321' (4466' TVD). Drilled 557' = 92.8/hr AROP. 500 GPM = 1830 psi, 120 RPM = 14-16k Tq, WOB = 7-14k. MW = 9.1
ppg, Vis = 42, ECD = 10.68 ppg, Max Gas = 352u. PU = 173k, SO = 85k, ROT = 125k. Back ream 30' on connections. MPD full open while drilling and trap 150
PSI on connections. Pump 30 bbl hi vis sweep @ 9990', back on time with 20% increase. Performed a 270 bbl whole mud dump and dilute at 10095’, dropping
MBTs from 6.5 to 5.0. Maintain the OA sand, building to center of OA and maintain with 89-91° inc. Drill 8-1/2" lateral from 10321' to 11036' (4483' TVD). Drilled
715' = 119’/hr AROP. 500 GPM = 1970 psi, 120 RPM = 15k Tq, WOB = 14-16k. MW = 9.2 ppg, Vis = 38, ECD = 10.95 ppg, Max Gas = 353u. PU = 164k, SO =
82k, ROT = 126k. Back ream 30' on connections. Pump 30 bbl hi vis sweep @ 10943', back 200 stks late with 50% increase. Maintain the OA sand. Last survey at
10967.68’ MD / 4477.16' TVD, 88.14° inc, 309.67° azm, 12.19' from plan, 12.19' high and 0.27’ right. We have drilled 48 concretions for a total thickness of 339'
(6.8% of the lateral). Daily disposal to G&I = 1392 bbls Total disposal to G&I = 10376 bbls. Daily water hauled from A-pad = 910 bbls Total water hauled from A-
pad = 8000 bbls. Daily fluid loss = 0 bbls Total fluid loss = 332 bbls. Daily metal recovered = 17.3 lbs Total metal recovered = 40.3 lbs.
9/9/2022 Drill 8-1/2" lateral from 11036' to 11705' (4489' TVD). Drilled 669 ' = 111.5’/hr AROP. 500 GPM = 2060 psi, 120 RPM = 14-16k Tq, WOB = 10-18k. MW = 9.2
ppg, Vis = 40, ECD = 11.09 ppg, Max Gas = 403u. PU = 172k, SO = 70k, ROT = 122k. Back ream 30' on connections. MPD full open while drilling and trap 150
PSI on connections. Maintain the OA sand targeting 88 to 90° Drill 8-1/2" lateral from 11705' to 12463' (4482' TVD). Drilled 758' = 126’/hr AROP. 500 GPM = 2100
psi, 120 RPM = 14-16k Tq, WOB = 8-10k. MW = 9.2 ppg, Vis = 40, ECD = 11.12 ppg, Max Gas = 402u. PU = 173k, SO = 73k, ROT = 124k. Back ream 30' on
connections. Pump 30 bbl hi vis sweep @ 11988', back 300 stks late, 40% increase. MPD full open while drilling and trap 150 PSI on connections. Maintain the OA
sand targeting 88 to 90° Drill 8-1/2" lateral from 12463' to 13030' (4494' TVD). Drilled 567' = 94.5’/hr AROP. 500 GPM = 2250 psi, 120 RPM = 13-17k Tq, WOB =
5-14k. MW = 9.2 ppg, Vis = 39, ECD = 11.26 ppg, Max Gas = 151u. PU = 172k, SO = 70k, ROT = 115k. Back ream 30' on connections. Drill 8-1/2" lateral from
13030' to TD @ 13060' (4496' TVD). Drilled 30' = 60’/hr AROP. 500 GPM = 2230 psi, 120 RPM = 15k Tq, WOB = 13k. MW = 9.2 ppg, Vis = 39+, ECD = 11.33
ppg, Max Gas = 352u. PU = 171k, SO = 66k, ROT = 120k. Drilled to 12900' within the OA then drop inc to 85° and logged the base of the OA with ABG before
calling TD. Take Final survey: 12991.36' MD, 4490.41' TVD 85.23° INC, 311.96° AZ, 4.66' from plan, 1.48' High, 4.42' left. Drilled 67 concretions for a total
thickness of 474' (6.7% of the lateral). Pump 30 bbl sweep around cleaning up the well, back 300 stks late, 30% increase. Circulate hole clean w/4x BU. 500 gpm,
2210 psi, 120 rpm, 14k torque, racking a stand back each BU to 12971'. Simops: Clean pits and prep for Vis brine displacement. Hold PJSM for Displacing. 173k
PU, 70k SO, 123k ROT Wash to bottom at 13060’. 300 GPM,1000 psi, 60 RPM, 10k Tq Displace the wellbore to 8.45 ppg viscosified brine: Pump 30 bbl high vis
spacer, 25 bbls vis brine, 30 bbls SAPP, 25 bbls vis brine, 30 bbls SAPP, 25 bbls vis brine, 30 bbls SAPP, 30 bbls high vis spacer. Daily disposal to G&I = 986
bbls Total disposal to G&I = 11362 bbls. Daily water hauled from A-pad = 1160 bbls Total water hauled from A-pad = 9160 bbls. Daily fluid loss = 0 bbls Total
fluid loss = 332 bbls. Daily metal recovered = 6.3 lbs Total metal recovered = 46.6 lbs.
9/10/2022 Continue to pump SAPP train around and displace the wellbore to 8.45 ppg viscosified brine 7 bpm, 1200 psi, 80 rpm, 12k torque working the pipe 90' from
13,060', see spacer returns at 843 bbls away. 1145 bbls pumped take clean 8.45 ppg brine returns to pits. 1245 total bbls dumped to rock washer, FCP 7 bpm,
940 psi, 100 rpm 12k torque. No losses recorded. Parked at 13,030', Monitor MPD for pressure build 3 times with the final building from 44 psi to 225 psi in 5 min,
Record new parameters and SPRs, wash to TD. In mud = PU 173K, SO 70K, ROT 123K, in brine=PU 180K, SO 90K, ROT 123K BROOH from 13,060' to 11832' at
5-10 min/stand slowing as needed, LD DP in the mouse hole. 500 GPM = 1,520 psi, 120 RPM = 11K ft-lbs TQ, max gas units = 1186. PU = 174K, SO = 90K &
ROT = 126K. MPD choke holding 220 psi BROOH and 280 psi on connections. 5.7 bph loss rate BROOH at this point BROOH from 11,832' to 9354' at 5-10
min/stand slowing as needed, L/D DP in the mouse hole. 500 GPM = 1580 psi, 120 RPM = 12K ft-lbs TQ, Max Gas = 151u
PU = 165K, SO = 85K & ROT = 123K. MPD choke holding 212 psi while BROOH and 275 psi on connections. 8 bph loss rate BROOH from 9354' to 7165' at 5-10
min/stand slowing as needed, L/D DP in the mouse hole. 500 GPM = 1450 psi, 120 RPM = 7K ft-lbs TQ, Max Gas = 151u. PU = 155K, SO = 115K & ROT = 130K.
MPD choke holding 200 psi while BROOH and 275 psi on connections. 7 bph loss rate BROOH from 9354' to 5930,' pulling in 9 5/8" shoe, pulling 5-10 min/stand
slowing as needed, L/D DP in the mouse hole. Slow to 400 GPM & 20 rpm, 5-10k tq pulling the BHA into the shoe. 500 GPM = 1430 psi, 120 RPM =9k ft-lbs Tq,
Max gas units = 0. Losses BR to shoe= 129 bbls Pump 30 bbl hi vis sweep and circulate the casing clean at 500 GPM = 1520 psi, 40 RPM = 5K ft-lbs TQ. Sweep
back on time with 30% increase. Monitor pressure with MPD choke closed with 8.9 ppg MW. 5 min built to 183 psi, bleed off, 5 min built to 181 psi, bleed off, 5 min
built to 181 psi = 9.7 ppg EMW. KWF = 9.9 ppg. Circulate 9.1 ppg while weighting up the returns on the fly to 9.1 ppg at 300 GPM = 580 psi, 60 RPM = 3-4K ft-lb
TQ reciprocating 90' Daily disposal to G&I = 1451 bbls Total disposal to G&I = 12813 bbls. Daily water hauled from A-pad = 245 bbls Total water hauled from A-
pad = 9405 bbls. Daily fluid loss = 84 bbls Total fluid loss = 416 bbls. Daily metal recovered = 6 lbs Total metal recovered = 52.6 lbs.
9/11/2022 Continue to wt up at the shoe from 9.3 ppg until a good 9.5 ppg in/out pumping 300 GPM = 580 psi, 60 RPM = 3-4K ft-lb TQ reciprocating 90' from 5960'. PU
147K, SO 118K, ROT 130K Shut down and monitor MPD for pressure build 3 times with the final building to 75 psi in 5 minutes, continue to weight up from 9.5 to
9.7 ppg. pumping 255 GPM = 520 psi, 60 RPM = 4-5K ft-lb TQ reciprocating 90' from 5960'. With a good 9.7 ppg in/out shut down. Monitor MPD for pressure build
3 times with final building to 42 psi in 5 min, which includes 40 psi static line pressure. continue to wt up from 9.7 to 9.8 ppg. pumping 250 GPM = 520 psi, 60 RPM
= 4-5K ft-lb TQ reciprocating 90' from 5960'. With good 9.8 ppg in/out shut down. Monitor MPD for pressure build, no pressure, monitor for flow at 2'' valve on the
MPD head, very slight flow going static in 10 min, watch for another 10 min, remains static, close valve. PJSM, remove RCD, C/O air boot and install trip nipple,
remove bouy from flow line, check for leaks, good, Simops: build dry job. Monitor well, on slight losses. Pump dry job, LD single joint DP, drop 2.45" drift on wire,
blow down TD TOOH from 5895' to 280' racking back stands of 5'' drill pipe. Observe the well for flow, well is on slight losses. Recover drift on wire. L/D jar stand,
float sub and 3 NM flex collars. Download MWD data. LD remaining BHA 3, bit grade= 1-1-CT-A-X-I-ER-TD. No abnormal wear observed on BHA components. 14
bbl losses TOOH from shoe. Clear and clean the rig floor. 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 2.5 BPH MU & RIH round nose float shoe/WIV with crossover
joint , RIH WITH 4-1/2", 13.5#, L-80, H625 pre-drilled injection liner as per tally installing a free floating stop ring & centralizer on every joint to 3723'. M/U to
optimum TQ @ 9,600 ft-lbs. PU = 78K, SO = 72K. Loss rate RIH= 2.5 BPH Daily disposal to G&I = 114 bbls Total disposal to G&I = 12927 bbls. Daily water hauled
from A-pad = 75 bbls Total water hauled from A-pad = 9480 bbls. Daily fluid loss = 46 bbls Total fluid loss = 462 bbls. Daily metal recovered = 4.2 lbs Total metal
recovered = 56.8 lbs.
9/12/2022 RIH with 4-1/2", 13.5#, L-80, H625 pre-drilled injection liner as per tally installing a free floating centralizer & stop ring on every joint from 3723' to 6670', verify liner
count. M/U to optimum TQ @ 9,600 ft-lbs. PU = 107K, SO = 86K. Loss rate RIH= 2- 2.5 BPH Notify Engineer that frac sliding sleeve in the open position, decision
was made to run sleeve in the open position, MU 8.12'' OD well tec packer assy as per Well tec rep, MU NCS 4 1/2'' frac sleeve assy to 6722' Continue RIH with 4-
1/2", 13.5#, L-80, H625 pre-drilled injection liner as per tally installing a free floating centralizer & stop ring on every joint from 6722' to 7257' @ jt #175, verify liner
count. M/U to optimum TQ @ 9,600 ft-lbs. Losses RIH with liner= 15 bbls. C/O elevators to 5" DP. P/U Baker 7" x 9-5/8" SLZXP liner top packer and running tool
assy to 7297'. MU stand drill pipe, pump 10 bbls @ 3 BPM, 230 PSI to ensure clear flow path. set TD torque limit to 7K. Obtain parameters : 112K PU, 85K SO,
90K ROT. 10 & 20 RPM = 4-5K TQ. Run 4-1/2" liner assembly on stands of 5" drill pipe from 7,389' to 12915', single in with 5 joints, tag TD on depth @ 13,060'
2 times with 5k set down. 26 bbls total losses running liner. PU 170K, SO 103K L/D joint of drill pipe, MU 20' and 5' pup joints, M/U pump in sub with FOSV and 10'
pup joint. RU cement line and test pump. Pump 5 bbls, ensure lines clear. 1 BPM, 160 psi Drop 1" phenolic ball and pump the ball down with 25 bbl hi-vis sweep.
Ball on seat at 900 strokes. Pressure up to 1900 psi and observed shear at 1,800 psi. Hold for 2 minutes and SO to 80K. Continue to pressure up with the rig
pumps, HRD sheared at 2,900 psi. Bleed pressure off. P/U string to 150k, observe break over - confirm release. Top of the SLZXP LTP at 5776' R/U testing
equipment and purge air from lines. Close the annular. PT the IA/LTP to 1,500 psi for 10 minutes charted (good test). Bleed off pressure and open the annular.
Pressure up string with Rig pumps, the ball seat sheared at 4100 psi. R/D the circulating equipment, FOSV and pup jt. Blow down the cement line. Pull the running
tool out of the SLZXP while circulating at 3 BPM = 300 psi. Continue to circulate a total of 1.7 BU at 420 GPM = 950 psi with reciprocating 40' (no rotation). Record
a 9.7 ppg MW returns. Monitor Well while bringing active system back up to a 9.8 ppg. Pump full circulation while weighting up to 9.8 ppg for sufficient trip margin.
256 GPM, 460 psi. Monitor Well – Static. TOOH laying down 5” DP singles f/ 5780’ t/ 5463’. Losses calculated @ 2 BPH. Pump a dry job and blow down the top
drive. Continue TOOH from 5463' to 859', laying down 5'' DP single to shed. Losses @ 3 BPH. Daily disposal to G&I = 114 bbls Total disposal to G&I = 13041
bbls. Daily water hauled from A-pad = 60 bbls Total water hauled from A-pad = 9540 bbls. Daily fluid loss = 34 bbls Total fluid loss = 496 bbls. Daily metal
recovered = 4.1 lbs Total metal recovered = 60.9 lbs.
Activity Date Ops Summary
9/13/2022 Continue to TOOH L/D 5'' DP from 859' to surface, LD liner running tool, inspect same, good. 15.4 bbl losses TOOH. Swap to completions AFE @ 06:00,Clean and
clear the rig floor, mobilize 3 1/2'' tubing tools and equipment to the rig floor. Pull the wear bushing, WHR make hanger dummy run. RU 3 1/2'' power tongs and
handling equipment. Centrilift RU spooler on rig floor, ready XO on FOSV. Monitor well, 1 bph loss rate,PJSM, PU bullet seal assembly and RIH on 3-1/2”, 9.3#, L-
80, EUE 8rd tubing as per tally to 302'. Torque to 2,800 ft-lbs with Doyon double stack tongs. Loss rate = 1 bph,PU XN nipple (2.75" no-go), tubing joint, Centrilift
Zenith gauge assy, tubing joint and Halliburton sliding sleeve assy to 423'. Continue to run tubing and installing Cannon clamps as per tally from 433' to 5797'.
Torque all connections to 2,800 ft/lbs with Doyon double stack tongs. Test bullet seals w/ 470 psi on AI - Good. PU = 87K & SO = 67K. 1-1.5 BPH loss rate,Space
out for Hanger, lay down joints #183 #182 and #181 MU 10.25’, 8.17', 6.07’ & 2.17 pup joints. MU joint #180.,Change elevators to 5" DP. P/U 5" DP landing joint.
M/U crossover to the landing joint and MU the tubing hanger. M/U the tubing hanger to the completion. Lost 16 bbls while running 3-1/2" 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. Purge air, close the annular and
pressure up to 400 psi on the IA. PU to expose the ports in the tie back seals. PJSM.,Pump 205 bbls corrosion inhibited source water down the IA taking returns
out tubing to the rock washer at 5 BPM = 1000 psi followed with 154 bbls diesel at 5 BPM = 1090 psi, freeze protecting the IA to 2500’.,Slack off closing the ports.
Drain the stack. Open the annular, flush out the stack with water and blow down lines. Land the tubing hanger with 27K on hanger, 1.25' off no-go RILDS.,Line up
to pump down the IA, Pressure up to 3,500 psi and perform MIT on the 9 -/8'' x 3-1/2'' annulus for 30 charted minutes,Daily disposal to G&I = 0 bbls Total disposal
to G&I = 13041 bbls. Daily water hauled from A-pad = 0 bbls Total water hauled from A-pad = 9540 bbls. Daily fluid loss = 30 bbls Total fluid loss = 526 bbls. Daily
metal recovered = 0.3 lbs Total metal recovered = 61.2 lbs.
9/14/2022 Purge air from system, pressure up and perform MIT IA on 9 5/8'' x 3 1/2'' IA to 3,600 psi for 30 charted min, good test, bleed off pressure, shut annulus valve. 6.4
bbls pumped and 6.4 bbls bled back. Test witness waived by AOGCC rep S. Sullivan on 9-12-22 @ 13:16 hrs,Blow down, RD lines and test equipment, LD landing
joint, WHR RU dry rod and install BPV, RD spooler and sheave, clear the rig floor, load out centrilift equipment. Empty pits and start cleaning same, cleanout cellar
box.,PJSM, Pull the trip nipple, remove kill line hose from mud cross, ND BOP stack, set on pedestal. Simops: clean in pits, RD 3rd party shacks. Remove #2 drag
chain. set in new drag chain,Cleanup around hanger, WHR install the CTS plug in BPV. NU the tubing head adapter and tree. Centrilift take final gauge reading:
2,123.4 tubing psi, 1,672.8 IA psi, tubing temp 79.8, IA temp 79.6, voltage 20.8. Simops: Clean in pits, install new drag chain sprockets, assemble new drag chain.
Take rig off hi line and on gen power @ 16:00,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.,RD test equipment. Pull CTS plug and BPV with dry rod,RU circulating equipment. Bullhead 27 bbls of diesel down the tubing at 1 BPM =
860 psi ICP & 1,060 psi FCP. Blow down and RD circulating lines. Shut in and secure the well. Final well pressures: tubing = 600 psi & IA = 0 psi,Rig welder cut
off the mouse hole and seal weld the bottom of the cellar box. SimOps: Prep for rig move,RD the rig floor. Pre to skid the floor and move the rig.,PJSM. Skid the rig
floor into move position.,PJSM. Attempt to jack up the rig but the power to the moving system keep tripping off. Rig electrician trouble shoot the moving system. Rig
released from well B-36 at midnight.
50-029-23727-00-00API #:
Well Name:
Field:
County/State:
MP B-36
Milne Point
Hilcorp Energy Company Composite Report
, Alaska
8/29/2022Spud Date:
Well Name Rig API Number Well Permit Number Start Date End Date
MP B-36 Eline / Fullbore 50-029-23727-00-00 222-110 9/15/2022 10/14/2022
10/14/2022
T/I=333/304 *** Load and Test MIT-IA to 2000 psi (PASSED) Load IA w/ 3 bbls 60/40, 158 bbls Inhib Brine and 190 bbls Dsl.
Pump 2.6 bbls Dsl to reach IA Test pressure. 1st 15 Min IA lost 56 psi. 2nd 15 Min IA lost 25 psi. Bleed IA down w/ 3 bbls Dsl
returned. FWHP=463/495
10/14/2022
***WELL S/I ON ARIVAL***
PULL 3'' JET PUMP (ser# HC-00046, ratio: 13A) @ 5362' SLM / 5362' MD
LRS DISPLACE IA
CLOSE SLEEVE @ 5362' SLM / 5362' MD
GOOD IA TEST FROM LRS
***WELL S/I ON DEPARTURE***
T/I=0/99 Temp=S/I ***Freeze Protect Tbg and IA*** Pump 183 bbls Dsl down IA and 26 bbls Dsl down Tbg.
9/15/2022
**WELL S/I ON ARRIVAL**
OPEN SLEEVE @ 5362' SLM / 5362' MD
SET W/3" JET PUMP (serial# HC-00046, ratio: 13A, screen, sec. loc., OAL=69") @ 5362' SLM / 5362' MD
**S/I ON DEPARTURE**
Hilcorp Alaska, LLC
Weekly Operations Summary
10/6/2022
Well shut in upon arrival. (Clear Flowline Hydrates) Pumped 10 bbls neat meth down B-36 Flowline over to B-07 Flowline.
Line clear. Turned over to Op's.
10/8/2022
T/I=85/150***Freeze Protect Tbg and Flush hardlines for rig down*** Pump 5 bbls 60/40 down Tbg. Pump 2 bbls 60/40 down
flowline iron. Bleed line to Zero. Pump 4 bbls 60/40 down PFL. Bleed line to Zero
10/7/2022
Test MIT-IA to 2000 psi (PASSED
TD Shoe Depth: PBTD:
No. Jts. Returned
RKB RKB to BHF RKB to THF
Jts.
1
1
1
1
1
92
1
1
1
58
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:
Preflush (Spacer)
Type: Density (ppg) Volume pumped (BBLs)
Lead Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Tail Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Post Flush (Spacer)
Type: Density (ppg) Rate (bpm): Volume:
Displacement:
Type: Density (ppg) Rate (bpm): Volume (actual / calculated):
FCP (psi): Pump used for disp:X Yes No
Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job
Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf:
Cement In Place At: Date: Estimated TOC:
Method Used To Determine TOC:
Post Job Calculations:
Calculated Cmt Vol @ 0% excess: Total Volume cmt Pumped:
Cmt returned to surface: Calculated cement left in wellbore:
OH volume Calculated: OH volume actual: Actual % Washout:
Casing (Or Liner) Detail
Shoe
Cut Joint
Doyon 14 RKB
10 3/4
508.97 55.78326.08
SE
C
O
N
D
S
T
A
G
E
Rig
7:22
Cement to Surface
Rotate Csg Recip Csg Ft. Min. PPG9.4
Shoe @ 5969.63 FC @ Top of Liner5,884.48
Floats Held
369.11 792
241 552
Spud Mud
CASING RECORD
County State Alaska Supv.S. Barber / I. Toomey
Hilcorp Energy Company
CASING & CEMENTING REPORT
Lease & Well No.MP B-36 Date Run 2-Sep-22
Setting Depths
Component Size Wt. Grade THD Make Length Bottom Top
TXP-BTC Innovex 1.59 5,969.63 5,968.04
25.37 57.86 32.49
32.4932.49
9 5/8 47.0 L-80 TXP-BTC
Csg Wt. On Hook:350 Type Float Collar: No. Hrs to Run:23
9.5 4.7
1120
10
10.7 446 3.3
99
750
Bump Plug?
FI
R
S
T
S
T
A
G
E
10Tuned Spacer 60
15.8
580
3.3
9.4 4 146.6/140
436.8/437.6
1120
25
Rig
15.8 82
Bump press
Cement to Surface
Bump Plug?
Y
17:40 9/3/2022 2,181
2178.96
5,969.635,976.00 5,843.68
CEMENTING REPORT
Csg Wt. On Slips:85,000
spud mud
Tuned Spacer
870 2.83
Stage Collar @
60
Bump press
100
216
ES Cementer Closure OK
56
12 208
RKB to CHF
Type of Shoe: Casing Crew:Doyon 14
No. Jts. Delivered No. Jts. Run 143
Length Measurements W/O
Threads
Ftg. Delivered Ftg. Run Ftg. Returned
Ftg. Cut Jt.25.37 Ftg. Balance
N/A
www.wellez.net WellEz Information Management LLC ver_04818br
3.5
ArcticCem cement
Type
77 total 9-5/8" x 12"1/4" bowspring centralizers ran. Two in shoe joint with stop rings 10' from each end. One floating on
joint #2. One each with stop rings mid-joint on joint #3 & #4.
One each on joints #5 to #24, every other joint to #40 then every third joint to #84. One each on joints #87 to #97. One
each with stop rings on pup joints above and below ES cementer. One each on every third joint #100 to #139.
Casing 9 5/8 40.0 L-80 TXP-BTC Tenaris 82.13 5,968.04 5,885.91
Float Collar 10 3/4 TXP-BTC Innovex 1.43 5,885.91 5,884.48
Casing 9 5/8 40.0 L-80 TXP-BTC Tenaris 39.39 5,884.48 5,845.09
Baffle Adapter 10 3/4 TXP-BTC Halliburton 1.41 5,845.09 5,843.68
Casing 9 5/8 40.0 L-80 TXP-BTC Tenaris 3,644.38 5,843.68 2,199.30
Casing Pup Joint 9 5/8 40.0 L-80 TXP-BTC 17.52 2,199.30 2,181.78
ES Cementer 10 3/4 TXP-BTC Halliburton 2.82 2,181.78 2,178.96
Casing Pup Joint 9 5/8 40.0 L-80 TXP-BTC 17.51 2,178.96 2,161.45
Casing 9 5/8 47.0 L-80 TXP-BTC Tenaris 2,103.59 2,161.45 57.86
TypeI/II cement 500 2.35
Premium G cement 400 1.16
3.5
Premium G cement 270 1.17
9/4/2022 36
Spud Mud
X
36
X
2,181
Cement to Surface
Cement to Surface
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Benjamin Hand Digitally signed by Benjamin Hand
Date: 2022.09.14 10:34:27 -08'00'Chelsea Wright Digitally signed by Chelsea
Wright
Date: 2022.09.14 11:11:28 -08'00'
Submit to:
OPERATOR:
FIELD /UNIT /PAD:
DATE:
OPERATOR REP:
AOGCC REP:
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD 222-110 Type Inj N Tubing 0 0 0 0 Type Test P
Packer TVD 4348 BBL Pump 6.4 IA 0 3610 3600 3595 Interval O
Test psi 3500 BBL Return 6.4 OA Result P
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes
W = Water P = Pressure Test I = Initial Test P = Pass
G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail
S = Slurry V = Required by Variance I = Inconclusive
I = Industrial Wastewater O = Other (describe in notes)
N = Not Injecting
Notes:
Hilcorp Alaska LLC
Milne Point , MPU, B Pad
Douglas Yessak
09/14/22
Notes:Pre-Injection MIT-IA on rig. Witness waived by Sean Sullivan on 9/12/22 at 1:16 pm. Monobore, No OA. Test to 3500 psi as per PTD.
Notes:
Notes:
Notes:
B-36
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Mechanical Integrity Test
jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov
Notes:
Notes:
Notes:
Form 10-426 (Revised 01/2017)2022-0914_MIT_MPU_B-36
Pre-Injection MIT-IA on rig.
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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.
&ƌŽŵ͗ůĂƐŬĂE^ͲŽLJŽŶϭϰͲ^DƐфůĂƐŬĂE^ͲŽLJŽŶϭϰͲ^DƐΛŚŝůĐŽƌƉ͘ĐŽŵх
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DERYH,I\RXDUHQRWDQLQWHQGHGUHFLSLHQWRULI\RXKDYHUHFHLYHGWKLVPHVVDJHLQHUURU\RXDUHKHUHE\QRWLILHGWKDWDQ\GLVVHPLQDWLRQGLVWULEXWLRQRUFRS\RIWKLV
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038%
37'
Date: 8/29/2022 Development: X Exploratory:
Drlg Contractor: Rig No. 14 AOGCC Rep:
Operator:Oper. Rep:
Field/Unit/Well No.:Rig Rep:
PTD No.: 2221100 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: 12 1/4 in.
Pressure After Closure: 1825 psig P Vent Line(s) Size: 16 in. P
200 psi Recharge Time: 39 Seconds P Vent Line(s) Length: 209 ft. P
Full Recharge Time:165 Seconds P Closest Ignition Source: 76 ft. P
Nitrogen Bottles (Number of): 6 Outlet from Rig Substructure: 195 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: 24 sec P
Mud System Misc: 0 NA Knife Valve Open Time: 16 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 / J.Charlie
phoebe.brooks@alaska.gov
Hilcorp
24 hr notice given at 10:42 on 8/27/22 and AOGCC rep. Bob Noble waived witness at 13:34 hrs on 8/28/22. Test performed on 5" DP. Test
H2S/LEL gas alarms. Test PVT and flow paddle alarms. Vent line looks good.
0
C.Demoski / I Toomey
0
907-670-3090
TTEST DETAILS
jim.regg@alaska.gov
AOGCC.Inspectors@alaska.gov
MPU B-36
Form 10-425 (Revised 04/2018)2022-0829_Diverter_Doyon14_ MPU_B-36
$ODVND//&
9
9
9
9
9
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CAUTION: This email originated from outside the State of Alaska mail system.
Do not click links or open attachments unless you recognize the sender and know
the content is safe.
From:Rixse, Melvin G (OGC)
To:AOGCC Records (CED sponsored)
Subject:20220929 1621 Approval MP B-36 AOGCC 10-403 Submittal_ PTD_ 222-110
Date:Thursday, September 29, 2022 4:21:58 PM
From: Rixse, Melvin G (OGC)
Sent: Thursday, September 29, 2022 4:20 PM
To: Joseph Lastufka <Joseph.Lastufka@hilcorp.com>
Subject: RE: MP B-36 AOGCC 10-403 Submittal, PTD: 222-110
Joe,
Hilcorp is approved to close out the 10-403 work on the 10-407 completion report.
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: Joseph Lastufka <Joseph.Lastufka@hilcorp.com>
Sent: Tuesday, September 27, 2022 3:47 PM
To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Subject: FW: MP B-36 AOGCC 10-403 Submittal, PTD: 222-110
Mel,
Are you OK with me closing out this 10-403 with the 10-407 Completion Report for MPU B-36? It
was finished on the 14th and I’m told that this work should be completed within the next 2 weeks
which keeps it on the 30 day clock. Plus it would eliminate any confusion on submitting the
completion report as a producer even though it was originally permitted as an injector. 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: Tom Fouts <tfouts@hilcorp.com>
Sent: Tuesday, September 27, 2022 2:58 PM
To: aogcc.permitting@alaska.gov
Cc: David Haakinson <dhaakinson@hilcorp.com>; Todd Sidoti <Todd.Sidoti@hilcorp.com>; Joseph
Lastufka <Joseph.Lastufka@hilcorp.com>; Darci Horner - (C) <dhorner@hilcorp.com>
Subject: MP B-36 AOGCC 10-403 Submittal, PTD: 222-110
Hello,
Please process the attached 10-403 submittal for MP B-36, PTD: 222-110
Thanks,
Tom Fouts | Senior Ops/ Reg Tech
Hilcorp Alaska, LLC
tfouts@hilcorp.com
Direct: (907) 777-8398
Mobile: (907) 351-5749
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.
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
SSu bm itt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner: Rig No.:14 DATE: 9/5/22
Rig Rep.: Rig Email:
Operator:
Operator Rep.: Op. Rep Email:
Well Name:PTD #2221100 Sundry #
Operation: Drilling: X Workover: Explor.:
Test: Initial: X Weekly: Bi-Weekly: Other:
Rams:250 / 3000 Annular:250 / 2500 Valves:250 / 3000 MASP:1534
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 1FP
Test Fluid Water Inside BOP 1P
FSV Misc 0NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0NATrip Tank PP
Annular Preventer 1 13-5/8" 5K P Pit Level Indicators PP
#1 Rams 1 2-7/8"X5" VBR P Flow Indicator PP
#2 Rams 1 Blind P Meth Gas Detector PP
#3 Rams 1 2-7/8"X5" VBR P H2S Gas Detector PP
#4 Rams 0NAMS Misc 0P
#5 Rams 0NA
#6 Rams 0NAACCUMULATOR SYSTEM:
Choke Ln. Valves 1 3-1/8" 5K P Time/Pressure Test Result
HCR Valves 1 3-1/8" 5K P System Pressure (psi)3025 P
Kill Line Valves 1 3-1/8" 5K P Pressure After Closure (psi)1725 P
Check Valve 0NA200 psi Attained (sec)44 P
BOP Misc 1 Oteco Flange FP Full Pressure Attained (sec)195 P
Blind Switch Covers: All stations Yes
CHOKE MANIFOLD:Bottle Precharge:P
Quantity Test Result Nitgn. Bottles # & psi (Avg.): 6 @ 1975 P
No. Valves 14 P ACC Misc 0P
Manual Chokes 1P
Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result
CH Misc 0NA Annular Preventer 13 P
#1 Rams 6 P
Coiled Tubing Only:#2 Rams 6 P
Inside Reel valves 0NA #3 Rams 6 P
#4 Rams 0 NA
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:2 Test Time:7hrs. HCR Choke 2 P
Repair or replacement of equipment will be made within 0 days. HCR Kill 2 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 9-3-22 @12:16
Waived By
Test Start Date/Time:9/5/2022 2:00
(date) (time)Witness
Test Finish Date/Time:9/5/2022 9:00
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Brian Bixby
Doyon
All test performed with test plug 250-3000psi ea. Annular with 3-1/2"test jt. Upper & Lower Rams 3-1/2' & 5" test jts., test both
FOSV & Dart. FP on test #2 Oteco Flange not properly torqued, Test #3 FP FOSV with 1 Function cycle. Test all Gas Alarms
Shones / Charlie
Hilcorp
Barber / Toomey
MPU B-36
Test Pressure (psi):
rig14@doyondrilling.com
sbarber@hilcorp.com
Form 10-424 (Revised 08/2022) 2022-0905_BOP_Doyon14_MPU_B-36
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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-36
Hilcorp Alaska, LLC
Permit to Drill Number: 222-110
Surface Location: 668' FSL, 4471' FEL, Sec. 18, T13N, R11E, UM, AK
Bottomhole Location: 2076' FSL, 2125' 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,
Jeremy M. Price
Chair
DATED this ___ day of August, 2022.
Jeremy
Price
Digitally signed by
Jeremy Price
Date: 2022.08.23
13:35:50 -08'00'
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8/23/22
Jeremy Price Digitally signed by Jeremy Price
Date: 2022.08.23 13:35:35
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Milne Point Unit
B-36 SB Injector
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Milne Point Unit
B-36 SB Injector
Drilling Procedure
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Milne Point Unit
B-36 SB Injector
Drilling Procedure
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Milne Point Unit
B-36 SB Injector
Drilling Procedure
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Send final “As-Run” casing tally & casing and cement report to nathan.sperry@hilcorp.com and
joseph.lastufka@hilcorp.com This will be included with the EOW documentation that goes to the
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Milne Point Unit
B-36 SB Injector
Drilling Procedure
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Milne Point Unit
B-36 SB Injector
Drilling Procedure
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Milne Point Unit
B-36 SB Injector
Drilling Procedure
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Milne Point Unit
B-36 SB Injector
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Milne Point Unit
B-36 SB Injector
Drilling Procedure
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