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
MPM-27 MPU 50029237160000 2220490 2'0 2'N/A 20 surface 6/11/2023 Monobore. Drilled June 2022.
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Monday, August 29, 2022
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Adam Earl
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
Hilcorp Alaska, LLC
M-27
MILNE PT UNIT M-27
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 08/29/2022
M-27
50-029-23716-00-00
222-049-0
W
SPT
3665
2220490 1500
470 470 470 470
INITAL P
Adam Earl
7/29/2022
MIT IA / mono-bore well
30 MinPretestInitial15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:MILNE PT UNIT M-27
Inspection Date:
Tubing
OA
Packer Depth
0 1665 1568 1534IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitAGE220802134323
BBL Pumped:5.3 BBL Returned:4
Monday, August 29, 2022 Page 1 of 1
9
9
9 9
9
9
9
9
9
9
mono-bore well
James B. Regg Digitally signed by James B. Regg
Date: 2022.08.29 15:17:13 -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: 24.7' BF:
Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation:
4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number:
Surface: x- y- Zone- 4
TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD:
Total Depth: x- y- Zone- 4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 (ft MSL)
22.Logs Obtained:
23.
BOTTOM
20" X-52 114'
L-80 1961'
L-80 3735'
4-1/2" L-80 3960'
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"
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 / Drilled8-1/2"
TUBING RECORD
Liner
Liner Top Packer
5153'3-1/2" 9.3# L-80
SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date Perfd):
Stg 2 L - 811 sx / T - 270 sx
42"
Surface 2414' Stg 1 L - 378 sx / T - 400 sx
14 yds Concrete
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Hilcorp Alaska, LLC
WAG
Gas
3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503
6/13/2022
4914' FSL, 140' FEL, Sec. 14, T13N, R09E, UM, AK
2570' FSL, 1568' FEL, Sec. 02, T13N, R09E, UM, AK
222-049 / 322-354
Milne Point Field / Schrader Bluff Oil Pool
58.58'
14596' / 3960'
HOLE SIZE AMOUNT
PULLED
50-029-23716-00-00
MPU M-27
534025 6027767
486' FNL, 2397' FWL, Sec. 13, T13N, R09E, UM, AK
CEMENTING RECORD
6027658
SETTING DEPTH TVD
6035975
BOTTOM TOP
Surface
Surface
CASING WT. PER
FT.GRADE
13.5#
536563
532554
TOP
SETTING DEPTH MD
Surface
5137'
Per 20 AAC 25.283 (i)(2) attach electronic information
40#
14596'
1961'
3665'
DEPTH SET (MD)
5137' / 3665'
PACKER SET (MD/TVD)
129.5#
47#
114'
2414' 5301'
Gas-Oil Ratio:Choke Size:Water-Bbl:
PRODUCTION TEST
*Pre-Produced, on Injection July 17, 2022*
Date of Test:
Flow Tubing
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" Screen Liner, 4-1/2" Drilled Liner 6/11/2022
***Please see Schematic for Detail***
ROP, AGR, DGR, ABG, EWR, ADR MD & TVD
Sr Res EngSr Pet GeoSr Pet Eng
Oil-Bbl: Water-Bbl:
6/7/2022
5/25/2022
ADL 025514 & 388235
16-004
2230' / 1846'
N/ANone
N/A
14596' / 3960'
Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment
By Meredith Guhl at 2:59 pm, Jul 22, 2022
Completed
6/13/2022
JSB
RBDMS JSB 072822
GMGR30AUG2022DSR-8/1/22
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
28' 28'
2258' 1874'
Top of Productive Interval 5290' 3730'
1435' 1336'
2305' 1901'
4393' 3202'
5290' 3730'
6162' 3933'
SB OA 6162' 3933'
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:
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
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.
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
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:
Ugnu 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
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).
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.
Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment
7.22.2022
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: 2022.07.22 14:49:01 -08'00'
Monty M
Myers
_____________________________________________________________________________________
Revised By: JNL 6/13/2022
SCHEMATIC
Milne Point Unit
Well: MPU M-27
Last Completed: 6/13/2022
PTD: 222-049
CASING DETAIL
Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF
20" Conductor 129.5 / X-52 / Weld N/A Surface 114’ N/A
9-5/8" Surface 47 / L-80 / TXP 8.525” Surface 2,414’ 0.0732
9-5/8" Surface 40 / L-80 / TXP 8.679” 2,414’ 5,301’ 0.0758
4-1/2” Liner - Drilled 13.5 / L-80 / Hyd 625 3.920” 5,137’ 14,596’ 0.0149
TUBING DETAIL
3-1/2" Tubing 9.3 / L-80 / EUE 8RD 2.867” Surface 5,153’ 0.0087
OPEN HOLE / CEMENT DETAIL
42” 14 yds Concrete
12-1/4"Stg 1 –Lead 378 sx / Tail 400 sx
Stg 2 –Lead 811 sx / Tail 270 sx
8-1/2” Cementless Injection Liner
TREE & WELLHEAD
Tree Cameron 3 1/8" 5M w/ 3-1/8” 5M Cameron Wing
Wellhead Cameron 11” 5K x sliplock bottom w/ (2) 2-1/16” 5K outs
GENERAL WELL INFO
API#: 50-029-23716-00-00
Completion Date: 6/13/2022
WELL INCLINATION DETAIL
KOP @ 289’
Max Hole Angle = 96° @ 12,114’ MD
TD =14,596’ (MD) / TD =3,960’ (TVD)
20”
Orig. KB Elev.:58.58’/ GL Elev.: 24.7’
3-1/2”
6
2
9-5/8”
1
3
See
Drilled
Liner
Detail
7
PBTD =14,596’ (MD) / PBTD =3,960’ (TVD)
9-5/8” ‘ES’
Cementer @
2,471’
4-1/2”
4/5
JEWELRY DETAIL
No Top MD Item
ID
Upper Completion
1 4,921’ Sliding Sleeve 2.813”
2 4,977’ SGM-FS XDPG Gauge
3 5,030’ XN Nipple, 2.813”, 2.75” No-Go 2.750”
4 5,143’ Locator Sub, 8.25” No-Go (bottom of locater spaced out 2’) 6.170”
5 5,144’ Bullet Seals – TXP Top Box x Mule Shoe 6.170”
Lower Completion
6 5,137’ 9-5/8” SLZXP Liner Top Packer 6.220”
7 14,594’ Shoe
Revised By: JNL 6/13/2022
4-1/2” Screen Liner
4-1/2” Drilled Liner
Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD)
3 5366’ 3760’ 5489’ 3805’
Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD)
1 6185’ 3935’ 6226’ 3939’
1 6308’ 3948’ 6349’ 3952’
1 6430’ 3961’ 6470’ 3964’
1 6553’ 3969’ 6591’ 3971’
1 6672’ 3971’ 6754’ 3968’
1 6795’ 3966’ 6835’ 3964’
1 6917’ 3960’ 6958’ 3958’
1 7039’ 3956’ 7080’ 3955’
1 7160’ 3951’ 7201’ 3949’
1 7284’ 3943’ 7325’ 3941’
1 7407’ 3938’ 7448’ 3937’
1 7531’ 3937’ 7571’ 3938’
1 7653’ 3941’ 7694’ 3944’
1 7775’ 3950’ 7815’ 3953’
1 7898’ 3959’ 7938’ 3962’
1 8021’ 3967’ 8061’ 3968’
1 8143’ 3971’ 8184’ 3971’
1 8265’ 3972’ 8305’ 3972’
1 8388’ 3972’ 8427’ 3972’
1 8510’ 3972’ 8550’ 3972’
1 8632’ 3974’ 8673’ 3975’
1 8755’ 3975’ 8796’ 3975’
1 8879’ 3972’ 8919’ 3970’
1 9001’ 3966’ 9042’ 3964’
1 9124’ 391’ 9165’ 3960’
1 9247’ 3959’ 9289’ 3959’
1 9371’ 3959’ 9412’ 3960’
1 9490’ 3962’ 9531’ 3963’
1 9613’ 3964’ 9653’ 3964’
1 9736’ 3963’ 9775’ 3964’
1 9858’ 3966’ 9899’ 3968’
1 9981’ 3973’ 10022’ 3975’
1 10104’ 3981’ 10145’ 3983’
1 10227’ 3987’ 10268’ 3988’
1 10351’ 3990’ 10391’ 3990’
1 10474’ 3992’ 10515’ 3992’
Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD)
1 10598’ 3993’ 10637’ 3994’
1 10718’ 3994’ 10758’ 3994’
1 10839’ 3994’ 10879’ 3994’
1 10961’ 3995’ 11002’ 3995’
1 11084’ 3996’ 11121’ 3997’
1 11204’ 3999’ 11245’ 3999’
1 11327’ 3999’ 11367’ 3998’
1 11448’ 3994’ 11489’ 3993’
1 11571’ 3990’ 11612’ 3989’
1 11694’ 3988’ 11735’ 3987’
1 11818’ 3987’ 11858’ 3987’
1 12271’ 3959’ 12312’ 3956’
1 12558’ 3934’ 12599’ 3931’
1 12679’ 3924’ 12720’ 3921’
1 12803’ 3915’ 12843’ 3913’
1 12925’ 3910’ 12966’ 3909’
1 13048’ 3908’ 13088’ 3908’
1 13170’ 3908’ 13211’ 3908’
1 13293’ 3908’ 13334’ 3908’
1 13417’ 3910’ 13455’ 3912’
1 13537’ 3918’ 13577’ 3912’
1 13660’ 3927’ 13699’ 3929’
1 13782’ 3936’ 13820’ 3939’
1 13900’ 3945’ 13940’ 3948’
1 14023’ 3952’ 14063’ 3954’
1 14144’ 3956’ 14185’ 3957’
1 14268’ 3959’ 14309’ 3960’
1 14389’ 3961’ 14430’ 3961’
1 14512’ 3961’ 14552’ 3961’
CASING AND LEAK-OFF FRACTURE TESTS
Well Name:MPU M-27 Date:6/1/2022
Csg Size/Wt/Grade:9.625"40# x 47#, L-80 Supervisor:Demoski/Toomey
Csg Setting Depth:5301 TMD 3756 TVD
Mud Weight:9.3 ppg LOT / FIT Press =527 psi
.
LOT / FIT =12.00 Hole Depth =5327 md
Fluid Pumped=1.5 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
->141 ->279
->277 ->4132
->389 ->6250
->4 109 ->8386
->5 196 ->10 539
->6 248 ->14 835
->7 307 ->18 1083
->8 366 ->22 1393
->9 432 ->26 1644
->10 477 ->30 1951
->11 527 ->34 2268
->12 ->38 2577
->13 ->40 2674
Enter Holding Enter Holding Enter Holding Enter Holding
Time Here Pressure Here Time Here Pressure Here
->0 527 ->0 2674
->1 505 ->5 2663
->2 490 ->10 2657
->3 478 ->15 2650
->4 468 ->20 2643
->5 465 ->25 2638
->6 463 ->26 2638
->7 461 ->27 2637
->8 460 ->28 2635
->9 459 ->29 2635
->10 458 ->30 2634
->11 457 ->
->12 433 ->
->13 432 ->
->14 431
->15 430
->
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527505490478468465463461460459458457433432431430
2674 2663 2657 2650 2643 263826382637263526352634
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LOT / FIT DATA CASING TEST DATA
Activity Date Ops Summary
5/23/2022 Continue with rig move from I-pad, Mobilize the rig from track 14 turning left onto MP spine, left onto L and M access road, left onto M-Pad access road arriving at
M-pad, stage the rig on the pad. Set rig mat under rear booster, prep booster for removal and remove same. Simops: welder installing cleanouts in pits 1 & 2, clear
mats from FL crossings. Submit 24 hr diverter test notification to AOGCC Spot Rig over BOP Stack, uncradle Stack and install spacer spool & adapter. Rack stack
onto moving stump and secure. SimOps: Installing diverter Tee and Annular preventer. Setting matting boards around Well. Finish pit #1 & 2 clean out lines. Finish
spotting mats for Rig footprint. Move the rig over M-27 and center over the well. Shim and level the rig Skid the rig floor into drilling position. Set mats for the rock
washer, slop tank and MPD shack. Hook up interconnects under the rig floor. Get steam, air and H2O going to the rig floor. Start acceptance checklist. Secure
landing around rig and start nippling up diverter system. Skid conveyor #2 into drilling position. Spot support buildings, rockwasher and fuel trailer. Load Sperry
tools in shed.
5/24/2022 Continue to RU on M-27, install diverter line, finish setting MI and Sperry shacks, install riser, with the pits ready offload 580 bbls spud mud, load remaining BHA
into the pipe shed, WHR torque speed head bolts, install riser. Put rig on hi line power @ 11:30 Continue to haul equipment from I-Pad, set enviro vac. Install plug
on MI shack, power up shacks, Set water pump house, Spot cement silos and upright water tanks. Simops: welder install wall panel between koomey and gen
room. Start loading 5'' DP and 17 jts HWDP into shed, Post diverter warning signs, power up accumulator and check for leaks, good. RU water pump house lines,
fill water tank. Set and plug in 5 star. Complete acceptance checklist. Accept rig @ 17:00 Utilizing a joint 5'' DP, Perform diverter function test. AOGCC rep A. Earl
waived witness on 5-24-22 @ 16:05, Bag closed in 24 sec, knife valve opened in 22 sec. Perform accumulator draw down and PVT alarm test. Diverter 305',
closest ignition source 95' away- wellhouse light. Test rig gas alarms Accumulator Test: System pressure = 3000 psi. Pressure after closure = 1800 psi. 200 psi
attained in 39 seconds. Full pressure attained in 158 seconds. Nitrogen Bottles - 6 at 1925 psi. PU and MU 3 stands of 5" HWDP, 1 stand of 5" HWDP with jar and
2 stands of 5" HWDP for the BHA. Mobilize BHA components to the rig floor. Pre-spud meeting with all parties involved. Discussed well objectives and surface hole
hazards. Table top diverter drill. M/U 12-1/4" Kymera bit, 8" mud motor with 1.5° AKO and XO sub to 36'. M/U stand of 5" HWDP to top drive. RIH with stand and
tag up @ 112' MD. Fill Riser with H2O Fill standpipe with water and pressure test high pressure mud line & MWD Geo-Span to 3000 PSI. Tighten blind flange on
Kill line. Obtain good test. Flood system to pits. Engage pumps and rotary clean, out conductor to 114' pumping 375 gpm, 440 psi, 30 rpm, 1k tq, 1-2k WOB.
5/25/2022 Drill 12-1/4" surface hole from 114' to 219'. Swap to Spud Mud @ 124’. 400 GPM, 460 PSI, 40 RPM, 1-2K ft/lbs TQ, 10K WOB. 49K PU / 49K SO / 49K ROT. 9.0
ppg MW, 230 vis Pump out of hole f/ 219' t/ 124' then pull out on elevators to surface. Inspect bit - No damage, cones rotate freely. RIH with bit and motor. M/U
remaining BHA with GyroWhileDrilling, directional, gamma and resistivity and flex collar to 126'. Initialize MWD tools. Finish initializing MWD tools. PU and MU NM
flex collars to 159'. MU first stand of HWDP. Obtain gyro survey at 159', Gyro tool face 90° off motor scribe. POOH to mud motor. DD, MWD and Gyro
troubleshoot scribe discrepancy. Check scribe, Gyro to motor= 293.14, MWD to motor= 130.47 and MWD to Gyro = 201.84, Gyro to motor offset @ 295.24°, no
discrepancies found. RIH, MU stand HW, Obtain Gyro survey at 175', still reading 40° off, Consult w/ town engineer, decision made to drill 2 stands down to
confirm tool face, wash down & tag bttm with no fill. Drill 12-1/4" surface hole from 219' to 249' (249' TVD). attempt to survey, no response from EWR-M5 tool. 400
GPM = 780 psi, 40 RPM = 1-2K ft/lbs torque, WOB = 5-10K, MW = 9.0 ppg, Vis = 146, PU = 60K, SO = 61K, ROT = 60K. Troubleshoot survey, no response from
M-5 tool- cycle pump several times. POOH from 249' to 47’. Changeout the EWR-M5 collar and Quest GWD probe with backup tools to 97'. Orient tools and
download MWD. Parked at 97'. Changeout the saver sub, inspect grabber dies and service the top drive. MU 2 NM Flex collars with crossover to 160'. MU a stand
of 5" HWDP and MU the top drive Initialize the MWD tool and obtain a gyro survey at 160' (good data). Wash down to 249' without difficulty (no fill observed). Drill
12-1/4" surface hole from 249' to 339' (339' TVD). Drilled 90' = 45'/hr AROP. 425 GPM = 1,010 psi, 40 RPM = 2K ft/lbs torque, WOB = 7K, PU = 65K, SO = 60K,
ROT = 60K. MW = 9.0 ppg, Vis = 122, ECD = 9.4 ppg, max gas units = 0 Drill 12-1/4" surface hole from 339' to 902' (892' TVD). Drilled 563' = 93.83'/hr AROP.
398 GPM = 1,140 psi, 40 RPM = 2-3K ft/lbs torque, WOB = 8-12K, PU = 80K, SO = 82K, ROT = 80K. MW = 9.1 ppg, Vis = 96, ECD = 9.8 ppg, max gas units = 0
Last survey at 671.31' MD / 669.09' TVD, 11.93° INC, 143.37° AZM, Distance from WP08 = 1.92', 0.7' high, 1.78' left.
5/26/2022 Drill 12-1/4" surface hole from 902' to 1,569' (1,436' TVD). Drilled 667' = 111.16'/hr AROP. 475 GPM = 1640 psi, 60 RPM = 4-7K ft/lbs torque, WOB = 7-12K, PU
= 90K, SO = 85K, ROT = 90K. MW = 9.3 ppg, Vis = 224, ECD = 10.5 ppg, max gas units = 479. Build 4°/100'. Drill 12-1/4" surface hole from 1,569' to 2,160'
(1,822' TVD). Drilled 591' = 98.5'/hr AROP. 450 GPM = 1,320 psi, 60 RPM = 4K ft/lbs torque, WOB = 10K, PU =102K, SO =85K, ROT = 86K. MW = 9.3 ppg, Vis
= 90, ECD = 9.9 ppg, max gas units = 561. Build 4°/100' to 1805' then hold 54° Drill 12-1/4" surface hole from 2,160' to 2,710' (2,133' TVD). Drilled 550' =
91.67'/hr AROP. 450 GPM = 1,480 psi, 80 RPM = 5K ft/lbs torque, WOB = 5-10K, PU =109K, SO =82K, ROT = 92K. MW = 9.2 ppg, Vis = 67, ECD = 10.0 ppg,
max gas units = 514. Hold 54° tangent. Base of the permafrost at 2,258’ (1,882’ TVD). Pumped a 25 bbl hi-vis sweep at 2,424' but did not see it at surface over the
shakers. Drill 12-1/4" surface hole from 2,710' to 3,280' (2,453' TVD). Drilled 570' = 95'/hr AROP. 550 GPM = 2,030 psi, 80 RPM = 7K ft/lbs torque, WOB = 4-5K,
PU =119K, SO =89K, ROT = 100K. MW = 9.3 ppg, Vis = 134, ECD = 10.25 ppg, max gas units = 514 Last survey at 3,146.9' MD / 2,368.8' TVD, 52.85° INC,
109.36° AZM, Distance from WP08 = 38.93', 5' high, 38' right.
5/27/2022 Drill 12-1/4" surface hole from 3,280' to 3,947' (2,910' TVD). Drilled 667' = 111.17'/hr AROP. 500 GPM = 1,860 psi, 80 RPM = 9-10K ft/lbs torque, WOB = 5K, PU
=145K, SO =96K, ROT = 111K. MW = 9.2 ppg, Vis = 102, ECD = 9.87 ppg, max gas units = 559 Pumped 25 bbl hi-vis sweep at 3,520', back 400 strokes late with
20% increase. Add 1/2% screen kleen to system preparing for Ugnu L & M sands Drill 12-1/4" surface hole from 3,947' to 4,422' (3,236' TVD). Drilled 475' =
79.17'/hr AROP. 500 GPM = 1,820 psi, 80 RPM = 10-15K ft/lbs torque, WOB = 10K, PU =157K, SO =95K, ROT = 115K. MW =9.2 ppg, Vis = 78, ECD =9.8 ppg,
max gas units = 512 Drill 12-1/4" surface hole from 4,422' to 4,802' (3,490' TVD). Drilled 380' = 63.33'/hr AROP. 450 GPM = 1,520 psi, 80 RPM = 13K ft/lbs
torque, WOB = 5K, PU =173K, SO =100K, ROT = 125K. MW =9.3 ppg, Vis = 70, ECD =9.7 ppg, max gas units = 478 Pumped a 21 bbl hi-vis sweep at 4,518',
back 250 strokes late with a 10% increase in cuttings. Drill 12-1/4" surface hole from 4,802' to 5,088' (3,661' TVD). Drilled 286' = 47.67'/hr AROP. 494 GPM =
1,920 psi, 80 RPM = 12-17K ft/lbs torque, WOB = 12-20K, PU =185K, SO = 95K, ROT = 130K. MW =9.2 ppg, Vis = 50, ECD =9.6 ppg, max gas units = 747 Last
survey at 5,048.53' MD / 3,639.86' TVD, 57.26° INC, 7.86° AZM, Distance from WP08 = 62.99', 14.18' low, 61.37' right.
Well Name:
Field:
County/State:
MP M-27
Milne Point
Hilcorp Energy Company Composite Report
, Alaska
5/25/2022Spud Date:
5/28/2022 Drill 12-1/4" surface hole from 5,088' to 5,307' at TD (3,757' TVD). Drilled 219' = 36.5 '/hr AROP. 553 GPM = 2,040 psi, 80 RPM = 17-18K ft/lbs torque, WOB = 5-
13K, PU =185K, SO = 95K, ROT = 130K. MW =9.3 ppg, Vis = 81, ECD =9.91 ppg, max gas units = 630 Limit ROP to to 50-70 fph @ 5,150', TD surface hole in
the top NA sand as per Geo. Top NA sand logged at 5286' MD (3,749' TVD). Last survey at 5240.39' MD / 3730.74' TVD, 65.64° INC, 357.29° AZM. TD projected
survey at 5307.0' MD / 3758.22' TVD, 65.64° INC, 357.29° AZM, Distance from WP08 = 43.57', 10.89' low, 42.18’ right BROOH to 5217' racking back 1 stand.
Pump 30 bbl hi-vis sweep and circulate out at 548 GPM = 2,000 psi, 60 RPM = 15-18K ft-lbs torque reciprocating pipe slowly 95'. Did not see the sweep and no
increase in cuttings observed. Wash back to 5,307' (no fill observed). BROOH from 5,307' to 5,090'. Flow check the well (static). Continue BROOH from 5,090 to
4,450' pulling 5-10 minutes/stand slowing as needed to clean up slides/tight spots. 550 GPM = 1,900 PSI, 80 RPM = 15K ft/lbs torque, max gas units = 283. PU =
175K, SO = 90K, ROT = 115K Continue BROOH from 4,450' to 2,808' pulling 5-10 minutes/stand slowing as needed to clean up slides/tight spots. 550 GPM =
1,800 PSI, 80 RPM = 7K ft/lbs torque, max gas units = 337. PU = 117K, SO = 81K, ROT = 95K Continue BROOH from 2.808' to 1,091' pulling 5-10 minutes/stand
slowing as needed to clean up slides/tight spots. 550 GPM = 1,450 PSI, 80 RPM = 5-7K ft/lbs torque, max gas units = 1123. PU = 80K, SO = 81K, ROT = 80K
Daily disposal to G&I = 789 bbls Total disposal to G&I = 4,230 bbls. Daily fluid loss = 0 bbls Total fluid loss = 0 bbls.
5/29/2022 Continue BROOH from 1091' to 714' to the HWDP pulling 5-10 minutes/stand. 550 GPM = 1,450 PSI, 80 RPM = 5K ft/lbs torque, Flow check well - static. TOOH
stand back 5" HWDP from 714' to 159'. BD the top drive. LD BHA #2, LD 2 NMFCs to 97', read MWD. Note: found 3'' x 2 1/2'' rock and piece of 1/4'' x 6 1/2" hose
on top of baffle plate in top of the TM collar. LD remaining BHA. Correct displacement TOOH. 12 1/4'' bit grade: PDC cutters = 1-1- WT-A-X-I-NO-TD and cones =
1-1- WT-A-E-I-NO-TD. M5 stabilizer and wear bands were in good shape. Motor stabilizer showed damage on all four blades, with the blade opposite the bend
being most damaged. Clear and clean the rig floor, load tools to the rig floor, RU volant tool and 9 5/8" handling equipment, hold PJSM with all parties involved.
P/U and M/U 9-5/8" shoe track using ForumLok on each connection. Round nose float shoe joint, spacer joint, float collar joint. Fill shoe track and install the top hat.
M/U baffle adapter joint to 164'. Pump through shoe track at 3.5 BPM to ensure float equipment operating correctly - good. RIH with 9-5/8"", 40# casing from 164' to
2,445' at 30'/min running speed. Torque to 21,000 ft/lbs with the Volant tool. Fill casing on the fly and top off every 10 joints. Centralizers installed as per tally.
Circulate bottoms up below the permafrost at 4 BPM = 190 psi. Lost 13 bbls while circulating. RIH with 9-5/8"", 40# casing from 2,445' to 2,809' at 30'/min running
speed. Torque to 21,000 ft/lbs with the Volant tool. Fill casing on the fly and top off every 10 joints. Centralizers installed as per tally. MU the ES cementer and
Baker Lok top/bottom connections. RIH with 9-5/8"", 40# casing 2,809' to 2,887' at 30'/min running speed. Torque to 21,000 ft/lbs with the Volant tool. PU = 150K
and SO = 92K. RIH with 9-5/8"", 47# casing from 2,887' to 5,145' at 30'/min running speed. Torque to 24,000 ft/lbs with the Volant tool. Fill casing on the fly and
top off every 10 joints. Centralizers installed as per tally. Daily disposal to G&I = 719 bbls Total disposal to G&I = 4,949 bbls. Daily fluid loss = 54 bbls Total fluid
loss = 54 bbls.
5/30/2022 RIH with 9-5/8", 47# casing from 5,145' to 5,303' washing the last 2 jts down at 2 BPM = 340 psi. Torque to 24,000 ft/lbs with the Volant tool. Fill casing on the fly
and top off every 10 joints. Centralizers installed as per tally. 68 bbl losses circulating and RIH. PU 260K, SO 110K Stage pumps to 6 bpm, 410 psi, while working
the string from 5,303' to 5,288', set TD torque @ 20k, establish rotation @2 rpm and 20k TQ while working pipe. Condition the mud for cementing, Spot and RU
cementers. Final 6 BPM = 170 psi with MW 9.5, YP = 10 Shut down, break out the Volant tool, re-dope cup and blow down top drive. Make back up to casing. RU
cement lines. Close upper and lower IBOP. Continue to circulate at 6 BPM = 170 psi while holding PJSM. Submit BOP test notification to the AOGCC at 10:00 HES
filled lines with 5 bbls fresh water. PT surface lines to 1,000/4,000 psi. good Pump 1st stage cement job: Mix & pump 60 bbls of 10 ppg tuned spacer with 4# red
dye & 5# Pol-E-Flake in 1st 10 bbls, 4 BPM = 200 PSI. Drop bypass plug. Mix and pump 132.5 bbls of 12.0 ppg lead cement (Type I/II cement, 2.347ft^3/sk yield,
378 sks total) ) at 4.5 BPM = 395 psi. Mix & pump 82 bbls 15.8 ppg Premium G tail cement (1.156 ft^3/sk yield, 400 sks total) @ 3 BPM, 470 PSI. Rotate 2-3 RPM,
20K TQ & reciprocate 20'. Drop shutoff plug. HES pump 20 bbls water @ 5.8 BPM, 250 psi. Displace with 174.9 bbls (1,732 strokes) 9.5 ppg spud mud from rig at
6 BPM, 190 PSI. Displace with 80 bbls 9.4 ppg Tuned Spacer form HES at 5.3 BPM, 260 PSI, continue to displace with 111.8 bbls 9.5 ppg mud from the rig at 6
BPM, 480 PSI ICP, slow to 3 BPM for last 10 bbls, FCP 580 PSI. Bump plug 1,107 stks at 10 stks(1 bbl) early. CIP at 13:55 Pressure to 1,150 psi, hold 3 min,
bleed off and check floats, good, Pressure to 2,880 psi shifting open ESC at 33 stks. Rotate and reciprocate entire job, no losses Pump through ES cementer at
2,472' at 6 BPM, 1,160 PSI ICP and 480 PSI FCP. Pol-E-Flake was observed at 550 stks. Dumped 66 bbls of spacer & interface. 25 bbls of cement observed back
to surface. Take returns back to the pits & continue to circulate total 5 BU. Disconnect knife valve from accumulator. Drain stack and flush with black water three
times. Re-connect knife valve to the accumulator. Continue to circulate through the ES cementer at 2,472' at 3-6 BPM = 150-460 psi. Prep for second stage
cement job. Continue to circulate through the ESC at 3 BPM = 150 psi. PJSM. Halliburton warming up equipment. Clean the suction screens. Break out, inspect
and MU the Volant tool. Pump 2nd stage cement job: Pump 5 bbls fresh water. Mix & pump 60 bbls of 10.0 ppg Tuned Spacer w/ 4# red dye & 5# Pol-E-Flake in
1st 10 bbls at 2.75 BPM= 110 psi. Mix & pump 416 bbl of 10.7 ppg ArcticCem lead cement (811 sxs at 2.883 ft^3/sk yield) at 5.2 BPM = 255 psi ICP / 600 psi
FCP. Mix & pump 56 bbls 15.8 ppg Premium G tail cement (270 sxs @ 1.17 ft^3/sk yield) at 3.4 BPM = 430 psi. Drop closing plug. Pump 20 bbls 8.34 ppg fresh
water at 6 BPM = 450 psi. Displace with 9.4 ppg spud mud at 5 BPM = 370 psi ICP / 740 psi FCP. Slow to 2 BPM = 390 psi for last 15 bbls Bumped plug 2.0 bbl
late. CIP at 01:55. 116 bbls of interface and 240 bbls of good 10.7 ppg cement returned. 100% returns during job. Pressure up and observe ES cementer shift
close at 1,720 psi. Pressure up to 2,100 psi and hold for 5 minutes. Bleed off and open the block valve to the casing (no flow). Disconnect the accumulator lines
from the knife valve. Drain the cement from the stack into the cellar box. Flush the stack with black water three times. Jet the flow line with black water. Power
down the accumulator and disconnect the lines from the diverter annular. RD the Volant tool. Vacuum out the casing to below ground level. Remove the
turnbuckles. Clear the rig floor of casing running equipment. Back out the grub screws from the starting head. Hoist the diverter stack. Prep to set casing slips.
5/31/2022 Center up the 9 5/8'' casing, WHR install casing slips with 100k set on the slips. Welder make casing cut, LD cut joint, length on cut joint= 19.79', pull the riser,
reposition the annular, welder dress the casing stump ND diverter stack, pull starter head, WHR install the slip lock tubing head and T103 connection, packed with
plastic, PT to 500/3800 psi for 5/10 min each (good test). Test the tubing spool void to 500/5000 psi 5/10 min each (good test). NU, install orbit valve on MPD
head, set stack and NU the BOPs. Simops: RD and move cement silos and water tank. NU the BOP stack with adapter flange and spacer spool. NU choke and kill
lines. Install turn buckles and MPD riser. RU BOPE testing equipment. MU TIW and dart valve. Install the test plug. RU 3-1/2" test joint. Flood the choke
manifold and stack. Shell test the BOP stack (passed). Conduct initial BOPE test to 250/3,000 psi: LPR (2-7/8” x 5” VBR’s) and UPR (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 Guy Cook via email on 5/31/22 at 14:54 hours. Tests: 1. Annular with 3-1/2” test joint, 3” Demco kill, 5” TIW,
choke valves 1, 12, 13 & 14 (passed). 2. UPR with 4-1/2” test joint, HCR kill, 5” Dart valve, choke valves 9 & 11 (passed) 3. LPR with 3-1/2” test joint (passed). 4.
UPR with 5” test joint manual kill, upper IBOP, choke valves 5, 8 & 10 (passed). 5. Lower IBOP, choke valves 4, 6 & 7 (passed). 6. Choke valve 2 (passed). 7. HCR
choke (passed). 8. Manual choke (passed). 9. LPR with 5” test joint (passed). 10. Blind rams (passed) 11. Manual adjustable choke (passed). 12. Hydraulic super
choke (passed). System pressure = 3000 psi. Pressure after closure = 1600 psi. 200 psi attained in 45 seconds. Full pressure attained in 194 seconds. Nitrogen
Bottles - 6 at 1850 psi RD BOP testing equipment. Blow down the choke manifold, kill lines and top drive. Pull the test plug. MU the wear ring running tool. Install
the wear ring (ID = 10.12"). Lay down the wear ring running tool. Install mouse hole. RU 5" handling equipment. Mobilize BHA components to the rig floor. Daily
disposal to G&I = 1,532 bbls Total disposal to G&I = 7,119 bbls. Daily fluid loss = 0 bbls Total fluid loss = 54 bbls.
RIH with 9-5/8", 47# casing from 5,145' to 5,303'
Drill 12-1/4" surface hole from 5,088' to 5,307' at TD (3,757' TVD).
6/1/2022 M/U 8-1/2" cleanout BHA to 586': 8-1/2" mill tooth bit, 6.75" mud motor with 1.5° AKO, 17 joints HWDP and hydraulic jars. TIH with stands of DP from 586' to
2,395'. Wash down from 2,395' with 450 GPM, 40 RPM =3-8K TQ & tag ES cementer at 2,472' with 5K WOB. Drill ES cementer on depth and clean up to 2,490'.
Ream 3x and trip through clean. 102K PU / 75K SO / 88K ROT. Observe drag from 2,490', ream down to 2,581' w/ 400 GPM, 390 PSI, 40 RPM, 6-9K TQ, 10-15K
WOB. TIH out of the derrick from 2,581' to 5,154'. Wash down with 125 GPM, 340 PSI and tag cement at 5,156' with 5K twice. Rack stand back to 5,154'. Circulate
a bottoms up at 450 GPM = 1130 psi, 30 RPM = 14K TQ while reciprocating 95'. Blow down top drive and rig up test equipment. Close upper 2-7/8" x 5" VBR on
5" drill pipe. Perform 2,650 psi casing test for 30 minutes, charted (good test). RD test equipment and blow down lines. Wash/ream down from 5,154' to 5,173' at
450 GPM = 1,150 psi, 40 RPM = 15K ft-lbs torque, WOB 3-5K. Drill cement and 9-5/8" shoe track from 5,173'. Equipment on depth: Baffle adapter = 5,175', float
collar = 5,216' and shoe 5,299' to 5,301'. Clean out rat hole to 5,307'. Ream through baffle adapter and float collar four times without difficulty. Drill 20' of new
formation from 5,307' to 5,327' at 500 GPM = 1,330 psi, 40 RPM = 15K ft-lbs torque, WOB = 10-20K. Ream through the shoe four times with/without pump/rotary.
Stand back the stand to 5,248' Circulate and condition the mud. After 2 BU good 9.3 ppg in/out and well cleaned up at 450 GPM = 1,020 psi, 30 RPM = 15K ft-lb
torque reciprocating 95'. RU testing equipment. Purge air from the choke/kill line and choke manifold. Perform FIT to 12.0 ppg at 5,301' MD / 3,756' TVD with 9.3
ppg MW and 527 psi applied at surface. Pumped 1.5 bbls and bled back 1.0 bbls. Blow down and RD testing equipment. Observe the well for flow (static). TOOH
with cleanout assembly from 5,248' to 586'. Observe the well for flow (static). Lay down 5" HWDP from 586' to 278'. Stand back jar stand from 278' to 185'. Lay
down remaining five 5" HWDP, motor and tricone bit. Bit grade: 1-1-WT-A-E-2/16-NO-BHA Clear and clean the rig floor. Remove the master bushing and install
the split bushings. Simops: PT the MPD surface lines to ,1300 psi (good test). MU 8-1/2" NOV SK616M bit, NRP-A2 bit sleeve, 7600 Geo-Pilot, LWD (ADR &
DGR), MWD (PWD & GWD), directional tools, stabilizer and float sub to 104'. Plug in and initialize MWD tools.
6/2/2022 Finish making up BHA #4. P/U non-mag drill collars, HWDP and jars to 291'. TIH out of derrick to 2195' Shallow pulse test MWD and verify GWD working
correctly. Break-in Geo-Pilot seals and verify operation - good. 450 GPM, 970 PSI, 10-30 RPM, 3-4K TQ. Continue to TIH out of the derrick from 2,195' to 5,049'
then single in the hole from 5,049' to 5,239'. M/U stand to be able to tag bottom. PJSM. Drain stack, pull trip nipple and install MPD RCD. Flow through lines 170
GPM, 400 PSI. Shut down and perform PJSM for mud displacement. Pump 35 bbl 9.0 ppg high vis spacer then displace wellbore to 8.8 ppg Flo-Pro NT. 295 GPM,
500 PSI, 30 RPM, 11K TQ. Reciprocate pipe 95'. 190K PU / 93K SO. Blow down top drive. Flush #1 mud pump with new mud. Slip and cut 80' of drilling line.
Service the top drive. Inspect and adjust brakes. Sim-ops: Clean mud pit #4 and surface equipment. Monitor for pressure build against closed MPD choke - no
pressure observed. Clean and inspect the saver sub/grabber dies. Calibrate the block height. SPR's at 5,327' (3,756' TVD). MP #1: 20/30 SPM = 180/200 psi.
MP #2: 20/30 SPM = 170/220 psi. Drill 8-1/2" lateral from 5,327' to 5,427' (3,783' TVD). Drilled 100' = 50'/hr AROP. 450 GPM = 960 psi, 80 RPM = 13K ft-lbs
torque, WOB = 5-8K, PU = 182K, SO = 88K, ROT = 116K. MW = 8.8 ppg, Vis = 41, ECD = 9.7 ppg, max gas units = 1454 While back reaming the stand at 5,398'
the string stalled out and overpulled 40K. SO and attempt to work pipe free without success. Determined that BHA stabilizer is stuck in the shoe at 5,301'. Begin
jarring operations. Notify town Engineer. Jarred 3 times up and 60 times down. Derrick inspection. Pump 70 bbls of 8.8 ppg FloPro with 5% lube (776) and spot
35 bbls on the back side at 377 GPM = 780 psi. Resume jarring operations. Jar 29 times down. Bring the pumps on at 167 GPM = 260 psi to bring the entire mud
system up to 3% lube. Continue jarring 49 times down (total = 138 down) Derrick inspection. Resume jarring operations. Jar down 35 times and the pipe became
free (total jar hit = 173 down & 3 up). MWD still getting detection. Post jarring derrick inspection. CBU at 450 GPM = 1,060 psi, 40 RPM = 5-7K ft-lbs torque
reciprocating 15'. Place the geo pilot into the home position. Slowly pulling BHA up into the shoe from 5,427' to 5,398'.
6/3/2022 Continue to pull BHA into the 9-5/8" shoe from 5,398'. Observe 10k overpull at 5317', work down then observe 15k drag the second time. 8-3/8" OD stabilizer at
float collar @ 5217' (99.76' from bit to stabilizer center). Observe 10k drag at 5285' then 20k overpull at 5272'. Slack off and pull 25k. S/O to 5294', observe 10
overpull at 5285'. S/O then begin reaming with 400 GPM, 850 PSI, 60 RPM, 7k TQ. Work 5,285' 2x with 7k drag and 2k TQ increase. Overpull 40k at 5,273' and
stall top drive at 10k TQ. Stabilizer at baffle adapter @ 5,176'. Suspect part of shoe track around stabilizer. Ream from 5,234' to 5,295' observing overpull & torque
@ 5,285' & 5,273' diminish. Pump high vis sweep @ concentrate reaming from 5,260' to 5,290'. Sweep back with a small amount of thin metal flakes about 1/2'
diameter back. Not observing any torque or drag. Ream back to bottom at 5,427'. Drill 8-1/2" lateral from 5,427' to 5,720' (3,866' TVD). Drilled 293' = 117.2'/hr
AROP. 500 GPM = 1,200 PSI, 120 RPM = 9K TQ, 10K WOB = 10K. PU = 143K, SO = 95K & ROT=115K. 8.9 ppg MW, 47 vis, 10.0 ppg ECD, 1149u max gas.
MPD choke open while drilling, observed pressure built to 50, 60 then 80 PSI. SB NB @ 5,394' MD / 3,771' TVD. SB NC @ 5,464' MD / 3,797' TVD. SB ND @
5,494' MD / 3,807' TVD. SB NE @ 5,563' MD / 3,829' TVD Drill 8-1/2" lateral from 5,720' to 6,285' (3,945' TVD). Drilled 565' = 94.17'/hr AROP. 500 GPM = 1,280
psi, 120 RPM = 11K ft-lb TQ, WOB = 12K, PU = 135K, SO = 90K & ROT = 112K. MW = 8.8 ppg, Vis = 40, ECD = 10.2, max gas units = 1765. MPD choke open
while drilling, began holding 100 psi on connections at 5,713'. Pumped high vis sweep at 6,000', back on time with 50% increase. SB NF @ 5,787' MD / 3,884'
TVD. Fault #A @ 5,920' MD / 3,906' TVD, 5' DTW throw. SB OA @ 6,162' MD / 3,933' TVD Drill 8-1/2" lateral from 6,285' to 6,951' (3,953' TVD). Drilled 666' =
111'/hr AROP. 500 GPM = 1,400 psi, 120 RPM = 11K ft-ls TQ, WOB = 12K, PU = 135K, SO = 90K & ROT = 112K. MW = 8.8 ppg, Vis = 40, ECD = 10.94, max
gas units = 1815. MPD choke open while drilling, holding 100 psi on connections Drill 8-1/2" lateral from 6,951' to 7,426' (3,926' TVD). Drilled 475' = 79.17'/hr
AROP. 500 GPM = 1,400 psi, 120 RPM = 11K ft-ls TQ, WOB = 137K, PU = 135K, SO = 86K & ROT = 115K. MW = 8.9+ ppg, Vis = 46, ECD = 10.4, max gas
units = 1,954. MPD choke open while drilling, holding 100 psi on connections Fault #1 @ 6,937' MD / 3,960' TVD, 20' DTE throw. Moved the wellbore from the
upper OA-2 to upper OA-4. Pump hi-vis sweep at 7,065', back on time with 50% increase Drilled 5 concretions for a total thickness of 28' (1.3% of the lateral). Last
survey at 7,260.7' MD / 3,944.57' TVD, 94.84° INC, 333.50° AZM, Distance from WP08 = 15.86', 0.21' low, 15.81’ Daily disposal to G&I = 570 bbls Total disposal
to G&I = 8,544 bbls. Daily fluid loss = 0 bbls Total fluid loss = 54 bbls. Daily metal recovered = 21.8 lbs Total metal recovered = 21.8 lbs.
6/4/2022 Drill 8-1/2" lateral from 7,426' to 7,997' (3962' TVD), 571' drilled, 95.17'/hr AROP. 500 GPM, 1500 PSI, 120 RPM< 15K TQ, 7K WOB, 145K PU / 80K SO / 115K
ROT. 8.8 MW, 42 vis, 10.69 ECD, 2,515u max gas. MPD chokes open while drilling, holding 140 PSI on connections. Performed planned undulation from OA-1 to
OA-3 at 7,521’ & entered OA-3 at 7,805’. Drill 8-1/2" lateral from 7,997' to 8,664' (3,972' TVD). Drilled 667' = 111.17'/hr AROP. 500 GPM = 1,460 psi, 120 RPM =
17K ft-lbs TQ, WOB = 5-14K, PU = 162K, SO = 70K & ROT = 115K. MW = 8.8 ppg, Vis = 41, ECD = 10.1, max gas units = 2474. MPD chokes open while drilling,
holding 180 psi on connections Pumped hi-vis sweep at 7,997', back on time with 10% increase Drill 8-1/2" lateral from 8,664' to 9,045' (3,963' TVD). Drilled 381' =
63.5'/hr AROP. 500 GPM = 1,540 psi, 120 RPM = 16K ft-lbs TQ, WOB = 5-12K, PU = 152K, SO = 75K & ROT = 112K. MW = 8.8 ppg, Vis = 40, ECD = 10.3, max
gas units = 1,882. MPD chokes open while drilling, holding 180 psi on connections Pumped hi-vis sweep at 9,045', back on time with 30% increase Drill 8-1/2"
lateral from 9,045' to 9,616' (3,967' TVD). Drilled 571' = 95.17'/hr AROP. 500 GPM = 1,580 psi, 120 RPM = 15K ft-lbs TQ, WOB = 5-6K, PU = 153K, SO = 72K &
ROT = 105K. MW = 8.8+ ppg, Vis = 41, ECD = 10.5, max gas units = 2,284. MPD chokes open while drilling, holding 180 psi on connections Performed planned
undulation from OA-3 to OA-1 at 8,690’ & entered OA-1 at 9,027’.
Drilled 22 concretions for a total thickness of 108' (2.6% of the lateral). Last survey at 9,451.13' MD / 3,961.24' TVD, 88.77° INC, 328.5° AZM, Distance from WP08
= 23.48', 6.5' low, 22.5’ left Daily disposal to G&I = 1,073 bbls Total disposal to G&I = 9,617 bbls. Daily fluid loss = 0 bbls Total fluid loss = 54 bbls. Daily metal
recovered = 24.8 lbs Total metal recovered = 46.6 lbs.
Perform 2,650 psi casing test for 30 minutes, charted (good test).
Perform FIT to 12.0 ppg at 5,301
6/5/2022 Drill 8-1/2" lateral from 9,616' to 10,092' (3,999' TVD) 476' drilled, 79.33'/hr AROP. 500 GPM, 1580 PSI, 120 RPM, 16-17K TQ, 5-10K WOB, 155K PU / 75K SO /
110K WOB. 8.85 MW, 40 vis, 10.49 ECD, 2447u max gas. MPD choke open while drilling, hold 180 PSI on connections. High vis sweep at 9,996' back on time
with 25% increase. Begin steering down at 9,750'. OA-2 at 10,057' and entered the OA-3 at 10,128'. Drill 8-1/2" lateral from 10,092' to 10,544' (3,993' TVD). Drilled
452' = 75.33'/hr AROP. 500 GPM = 1,690 psi, 120 RPM = 18K ft-lbs TQ, WOB = 5-15K, PU = 170K, SO = 60K & ROT = 112K. MW = 8.8 ppg, Vis = 41, ECD =
10.7, max gas units = 1,455. MPD choke open while drilling, hold 180 PSI on connections. Drill 8-1/2" lateral from 10,544' to 10,949' (3,996' TVD). Drilled 405' =
67.5'/hr AROP. 500 GPM = 1,720 psi, 120 RPM = 17K ft-lbs TQ, WOB = 5-15K, PU = 163K, SO = 40K & ROT = 115K. MW = 8.8 ppg, Vis = 42, ECD = 10.5, max
gas units = 1,596. MPD choke open while drilling, hold 180 PSI on connections. Drill 8-1/2" lateral from 10,949' to 11,300' (4,004' TVD). Drilled 351' = 58.5'/hr
AROP. 500 GPM = 1,700 psi, 120 RPM = 17K ft-lbs TQ, WOB = 5-20K, PU = 175K, SO = 55K & ROT = 105K. MW = 8.8+ ppg, Vis = 42, ECD = 10.67, max gas
units = 1,549. MPD choke open while drilling, hold 180 PSI on connections. Pumped hi-vis sweep at, 11,045', back 400 strokes late with 25% increase. Started
planned undulation up towards the OA-1 at 11,175’. Drilled 44 concretions for a total thickness of 249' (4.2% of the lateral). Last survey at 11,162.18' MD /
3,998.21' TVD, 88.26° INC, 332.08° AZM, Distance from WP08 = 23.48', 6.5' low, 22.5’ left" Daily disposal to G&I = 1,199 bbls Total disposal to G&I = 10,816
bbls. Daily fluid loss = 0 bbls Total fluid loss = 54 bbls. Daily metal recovered = 15.5 lbs Total metal recovered = 62.1 lbs.
6/6/2022 Drill 8-1/2" lateral from 11,300' to 11,709' (3,989' TVD) 409' drilled, 68.17'/hr AROP. 500 GPM, 1700 PSI, 120 RPM, 18-20K TQ, 7-18K WOB, 172K PU / 40K SO /
106K ROT. 8.85 MW, 43 vis, 10.78 ECD, 1549u max gas. MPD chokes open while drilling, trapping 180 PSI on connections. Performed planned undulation to OA-
1 and entered OA-1 at 11,466’. Drill 8-1/2" lateral from 11,709' to 12,278' (3,951' TVD). Drilled 569' = 94.8'/hr AROP. 500 GPM = 1,800 psi, 120 RPM = 19K ft-lbs
TQ, WOB = 5-12K, PU = 169K, SO = 40K, ROT = 105K. MW = 8.9 ppg, Vis = 44, ECD = 11.3, max gas units = 1,170. MPD chokes open while drilling trapping
180 psi on connections. Encountered fault #3 at 11,890’ (60' DTE). Build to 95° inclination to reacquire the OA sands. Pumped high vis sweep at 11,993', back 200
strokes late with 50% increase. Drill 8-1/2" lateral from 12,278' to 12,693' (3,931' TVD). Drilled 415' = 69.2'/hr AROP. 500 GPM = 2,080 psi, 120 RPM = 18K ft-lbs
TQ, WOB = 5-15K, PU = 167K, SO = 40K, ROT = 101K. MW = 8.9+ ppg Vis = 44, ECD = 11.6, max gas units = 1,359. MPD chokes open while drilling trapping
180 psi on connections. Encountered fault #4 at 12,326' (27' DTE). At 12,681' start 580 bbls dump and dilute. MBT prior to dilution = 7.5 & after = 5. Drill 8-1/2"
lateral from 12,693' to 13,136' (3,905' TVD). Drilled 443' = 73.8'/hr AROP. 500 GPM = 2,080 psi, 120 RPM = 19K ft-lbs TQ, WOB = 5-15K, PU = 167K, SO = 40K,
ROT = 101K. MW = 8.95 ppg Vis = 39, ECD = 10.9, max gas units = 1,383. MPD chokes open while drilling trapping 180 psi on connections. Pumped a hi-vis
sweep at 13,041', back 250 strokes late with 50% increase. Entered the OA-2 at 12,743' and entered the OA-1 at 12,893'. Drilled 56 concretions for a total
thickness of 330' (4.3% of the lateral). Last survey at 12,970.99' MD / 3,909.21' TVD, 91.49° INC, 332.27° AZM, Distance from WP08 = 22.02', 21.7' low, 3.6’ right
Daily disposal to G&I = 1,487 bbls Total disposal to G&I = 12,303 bbls. Daily fluid loss = 0 bbls Total fluid loss = 54 bbls. Daily metal recovered = 17.5 lbs Total
metal recovered = 79.6 lbs.
6/7/2022 Drill 8-1/2" lateral from 13,136' to 13,555' (3,922' TVD), 419' drilled, 69.83'/hr AROP. 500 GPM, 1870 PSI, 120 RPM, 18K TQ, 4-8K WOB, 170K PU / no SO /
105K ROT. 8.8 MW, 38 vis, 11.0 ECD, max gas 1999u MPD choke open while drilling, trapping 180 PSI on connections. Pump high vis sweep at 13,040' back
250 stks late w/ 50% increase. Drill 8-1/2" lateral from 13,555' to 13,992' (3,956' TVD). Drilled 437' = 72.8'/hr AROP. 500 GPM = 1,750 psi, 120 RPM = 18K ft-lbs
TQ, WOB = 5-15K, PU = 170K, SO = 40K & ROT = 112K. MW - 8.8 ppg ,ECD = 10.7, Vis = 40, max gas units = 1,430 MPD choke open while drilling, trapping
180 PSI on connections. Perform 580 bbl new mud dump and dilute at 13,707'. MBT dropped from 6.5 ppb to 5.2 ppb. ECD dropped from 10.93 to 10.81. Drill 8-
1/2" lateral from 13,992' to TD at 14,468' (3,959' TVD). Drilled 476' = 79.33'/hr AROP. 500 GPM = 1,820 psi, 120 RPM = 20K ft-lbs TQ, WOB = 5-15K, PU =
175K, SO = 40K & ROT = 110K. MW - 8.8 ppg , ECD = 11.0, Vis = 38, max gas units = 1,431 MPD choke open while drilling, trapping 180 PSI on connections.
Pump hi-vis sweep at 13,992', back 350 strokes late with 25% increase. Drill 8-1/2" lateral from 14,468' to TD at 14,596' (3,960' TVD). Drilled 128' = 51.2'/hr
AROP. 500 GPM = 1,820 psi, 120 RPM = 22K ft-lbs TQ, WOB = 5-15K, PU = 180K, SO = 40K & ROT = 105K. MW - 8.8+ ppg , ECD = 10.81, Vis = 46, max gas
units = 1,383 MPD choke open while drilling, trapping 180 PSI on connections. Drilled 67 concretions for a total thickness of 456' (4.9% of the lateral). Last survey
at 14,596.00' MD / 3,960.13' TVD, 90.52° INC, 330.16° AZM, Distance from WP08 = 56.21', 55.83' low, 6.5’ left Pump 30 bbls hi-vis sweep and circulate out of the
well at 500 GPM = 1760 psi, 120 RPM = 20K ft-lbs TQ reciprocating 60'. Back 400 strokes late with 25% increase. Continue to circulate bottoms up while racking
back a stand each bottoms up from 14596' to Daily disposal to G&I = 1,673 bbls Total disposal to G&I = 13,976 bbls. Daily fluid loss = 0 bbls Total fluid loss = 54
bbls. Daily metal recovered = 14.3 lbs Total metal recovered = 93.9 lbs.
6/8/2022 Continue to circulate the wellbore clean at 500 GPM, 1750 PSI, 120 RPM, 18-20K TQ while preparing mud pits. Reciprocate pipe, alternating end point. Racked
back stands to 14,201' each bottoms up for 6.4 bottoms up. Ream back to bottom with 500 GPM, 1720 PSI, 120 RPM, 18K TQ. PJSM. Perform displacement to
8.45 ppg as per M-I procedure. Pump 30 bbl high vis spacer, 25 bbls vis brine, 30 bbls SAPP pill #1, 25 bbls vis brine, 30 bbls SAPP pill #2, 25 bbls vis brine, 30
bbls SAPP pill #3, 30 bbls high vis spacer. Pump 8.45 ppg 2% KCl 3% lube (1.5% 776 and 1.5% Lo-Torq) at 295-335 GPM, 800-850 PSI, 100 RPM, 20K TQ,
torque reduced to 17K at end. PU 185K / 65K SO / 106K ROT. Shut down and monitor pressure with MPD chokes closed. Built to 105 PSI in 10 min then stabilized
(9.0 ppg EMW). Trapped 280 PSI after slow pump rates and pressure bled down to 172 PSI in 10 min then stabilized (9.4 ppg EMW). Sim-ops: Clean mud pits
#3&4. Service top drive. Obtain slow pump rates. BROOH from 14596 to 13288'. 500 GPM, 1330 PSI, 120 RPM, 17k Tq. Max Gas - 675u. 5 min/stand, laying
down stands in the mousehole. MPD choke open when reaming, trapping 180 PSI on connections (9.6 EMW). 178k PUW, 70k SOW, 110k ROT BROOH f/ 13288'
t/ 11045' at 5-10 mins a stand. 500 GPM, 1300 PSI, 120 RPM, 15k TQ, Max Gas 535u. MPD full open choke while BROOH & trapping 180 psi on connection.
157k PU, 70k SO, 110k ROT. Dynamic losses @ 2-5 BPH BROOH f/ 11045' t/ 9044' at 5-10 mins a stand. 500 GPM, 1350 PSI, 120 RPM, 10k TQ, Max Gas
512u. MPD full open choke while BROOH & trapping 180 psi on connection. 150k PU, 80k SO, 115k ROT. Dynamic losses @ 2-5 BPH Daily disposal to G&I =
1487 bbls Total disposal to G&I = 13976 bbls. Daily fluid loss = 68 bbls Total fluid loss = 122 bbls. Daily metal recovered = 8 lbs Total metal recovered = 101.9
lbs.
TD at 14,596
6/9/2022 While BROOH at 9,044' the elevators contacted the derrick board when laying down a stand in the 90' mousehole, bending the board down about 1.5'. Secure area
and make initial notifications. Apply additional restraint with tugger line. Doyon welder inspected damage, estimate 12-18 hours to repair. Two additional straps
were attached to the main frame of the derrick board & secured to the bull rail to provide additional secondary restraint & the tugger removed. Consulted w/ Hilcorp
supervisors & Doyon management. Derrick board is secure and will continue to BROOH & L/D drill pipe. Circulate 120 GPM, 425 PSI with 150 PSI backpressure
applied with MPD. Break string over every 30 minutes. PJSM. Continue to BROOH from 9,044' to 8,094' at 5-10 min/stand, slowing for tight spots. 500 GPM, 1340
PSI, 120 RPM, 8-10K TQ. 150K PU / 95K SO / 120K ROT. 8.65 MW, 43 vis, 9.96 ECD, 151u max gas. BROOH from 8,094' to 6100' at 5-10 min/stand, slowing for
tight spots. 500 GPM, 1220 PSI, 120 RPM, 8-10K TQ. 145K PU / 98K SO / 116K ROT. 8.70 MW, 42 vis, 9.95 ECD, 653u max gas. Experience 300 psi pressure
spike and packing off @ 6100'. Slow pumps t/ 200 GPM, RIH w/ 6174'. Stage pumps back up to 500 GPM as flow allows. Continue backream stand. Hole
unloaded sand and clay @ BU. Max gas - 1479u BROOH from 6100' to 5664' at 10-20 min/stand, slowing for tight spots. 475 GPM, 1120 PSI, 120 RPM, 5-7K TQ.
142K PU / 95K SO / 116K ROT. 8.70 MW, 42 vis, 9.95 ECD, 653u max gas. BROOH from 5664' to 5299' with reduced pulling speed 10-20 min/stand, to mitigate
intermittent packing off. 500 GPM, 1184 PSI, 120 RPM, 5-7K TQ. 142K PU / 95K SO / 114K ROT. 9.05 MW, 47 vis, 10.34 ECD, 817u max gas. Experienced 30k
overpull with bit entering shoe then hanging up & stall string. Work string several times with no rotary, 40k up/dn. Jars firing 2x before slacking off and free up with
50k dn. Pull back into shoe with no resistance. Lay down stand DP to 5235’ Pump 30 bbls Hi vis sweep around plus 2x bottoms up to clean casing. 10% increase
in returns with sweep at surface. 1/4"-1/2" sized coal pieces mixed in with sand and clay. Rot & Recip f/ 5235’ t/ 5135’ 40 RPM,4-6k Tq. 500 GPM 1120 psi. 9.05
MW, 49 Vis, 10.25 ECD, 290u Max Gas Monitor psi build with MPD, 3 min build to 62 psi, 53 psi, 47 psi. Final 10 min monitor stabilized @ 46 psi. Weight up mud
system from 9.05 ppg to 9.45 ppg. Target increase weight to 9.5 ppg. 450 GPM, 940 psi. 30 RPM, 5k Tq. Reciprocating string 95’. 130k PU, 105k SO, 118k ROT
Daily disposal to G&I = 114 bbls Total disposal to G&I = 14090 bbls. Daily fluid loss = 122 bbls Total fluid loss = 244 bbls. Daily metal recovered = 6.5 lbs Total
metal recovered = 108.4 lbs.
6/10/2022 Continue to weight up from 9.45 ppg to 9.5 ppg in and out. 450 GPM, 1050 PSI, 30 RPM, 4-6K TQ, 10.51 ECD, reciprocate 90'. 4 total circulations. 130K PUW /
105K SO / 118K ROT. Check for pressure build. MPD close chokes, built 13 PSI in 3 min, bleed off close choke & built 2 PSI in 3 min, bleed off close choke & no
pressure build in 3 min. Open 2" line below RCD. Initial 0.41 BPH flow slowed to static in 15 min. Lost high line power at 07:40 Start rig generator, restart air
compressors, cooling pumps, etc. Check pressure at MPD, no pressure. Open chokes. PJSM. Remove MPD RCD and install trip nipple. Inflate air boots, fill stack
and check for leaks - good. Clean and clear MPD equipment from the rig floor. Blow down MPD lines and begin rigging down. POOH laying down 5" drill pipe from
5,235' to 291'. Pumped 25 bbl 9.95 ppg dry job. Utilize trip tank for hole fill. Observe 15K bobble at 2828', work through again with nothing observed. Back on high
line power at 16:30. Flow check before pulling BHA, slight losses. Hold PJSM while monitor Well. L/D jar stand, float subs, NMFCs, Download MWD data, L/D
remaining BHA. RSS shipping/dust seal found above ADR collar. No abnormal wear or damage observed on BHA. Bit grade= 2-1-BT-C-X-I-NO-TD. 29 bbl losses
TOOH from shoe Clear rig floor of BHA accessories and tools. Load tools, stop rings & centralizers to rig floor. R/U 4 1/2'' handling equipment and power tongs.
M/U XO to FOSV. Monitoring well via TT, static loss rate @ 2 BPH Run 4-1/2'', 13.5#, L-80 H625 drilled lower completion as per tally to 2572'. Torque to optimum
@ 9600 ft/lbs with Doyon double stack tongs. 63k PU / 62k SO. 5.5 bbls loss while RIH w/ liner Daily disposal to G&I = 242 bbls Total disposal to G&I = 14332
bbls. Daily fluid loss = 72 bbls Total fluid loss = 316 bbls. Daily metal recovered = 0 lbs Total metal recovered = 108.4 lbs.
6/11/2022 Run 4-1/2" 13.5# L-80 Hydril 625 liner from 2,572' to 5,294'. 90K PU / 75K SO. Torque to optimum @ 9600 ft/lbs with Doyon double stack tongs. 1.7 BPH loss
rate. Service rig. Slip new line on pipe skate counterweight. Run 4-1/2" 13.5# L-80 Hydril 625 liner from 5,294' to 9,432'. 108K PU / 72K SO. Torque to optimum @
9600 ft/lbs with Doyon double stack tongs. 1.6 BPH loss rate. 24.1 bbls total losses while picking up liner. C/O elevators to 5" drill pipe. P/U Baker 7" x 9-5/8"
SLZXP liner top packer and M/U ITTS running tool assy.to 9,469'. P/U 3 joints of 5" drill pipe to 9,564'. Pump 10 bbls @ 3 BPM, 220 PSI to ensure clear flow path.
Obtain parameters : 112K PU / 72K SO / 85K ROT. 10 & 20 RPM = 4.5K TQ. Run 4-1/2" liner assembly on 5" drill pipe picked up from the shed from 9,564' to
13,275' @ 30-40 fpm. Drift pipe with 2.18". Loss rate continues at 1-2 BPH. PU 143K, SO 77K Continue Run 4-1/2" liner assembly on 5" drill pipe picked up from
the shed from 13,275', tag bottom with 10k Wt 2x @ 14596’. Verify pipe count in shed. Loss rate continues at 1-2 BPH, 16 bbls total loss while running liner
assembly. PU 160K, SO 85K Rig up to circulate via cement line. Rig up test manifold and line for shearing out ball seat. Test lines t/ 3700 psi. Break circulation,
pump 8 bbls @ 4 BPM, 580 psi. Drop 1” phenolic ball. Set string on depth, in tension with 160k PU. Pump ball down with 35 bbl hi-vis sweep. Ball on seat @ 830
stks. Pressure up t/ 2700 psi, observed shear @ 2450 psi. Hold pressure for 3 min. Slack off t/ 50k. Pressure up to 3800 psi with rig pump then swap to test pump.
Continue pressure up, shear ball seat @ 5000 psi. P/U and confirm release w/ 125k PUW. Rig up test equipment. Close annular, purge air from system. Test LTP
to 1500 psi for 10min charted - good test. bleed pressure off. 1.8 bbls pumped, 1.7 bbls returned. Rig down test equipment. Blow down surface lines. LTP @
5137.49’ Pressure to 300 psi, unsting from LTP, Increase flow to 600 GPM – 500 psi when pressure dump, PU 17' above TOL. Lay down 2x jts DP. Trouble shoot
erratic pump pressure with pumps back on, find MP #1 Charge pump switch in off position. Continue circulating casing clean at 500 GPM, 2100 psi Submit 24 hr
notification to AOGCC for MIT @ 05:27, state rep Brian Bixby waived witness at 05:39 Daily disposal to G&I = 57 bbls Total disposal to G&I = 14389 bbls. Daily
fluid loss = 26 bbls Total fluid loss = 342 bbls. Daily metal recovered = 4 lbs Total metal recovered = 112.4 lbs.
6/12/2022 Finish circulating the 9-5/8" casing clean, 500 GPM, 2150 PSI. Circulated a total of 2x bottoms up at 5,115'. Reciprocate pipe from 5,115' to 5,025'. 125K PU /
105K SO. Perform flow check - static. Slip and cut 67.5' of drilling line, inspect brakes, drawworks, brass and torque all bolts to specs. Service top drive and
perform weekly derrick inspection POOH from 5,115' laying down 5" drill pipe to 39'. 16 bbls loss while POOH.
tag bottom with 10k Wt 2x @ 14596’.
Test LTP
to 1500 psi for 10min charted - good test
Activity Date Ops Summary
6/12/2022 Inspect and L/D liner running tool, All components in good shape with no abnormalities observed.,Pull Wear bushing & C/O Split Master Bushings,Clean and clean
rig floor. Mobilize Centrilift tools, 100 cannon clamps, tech line spool and 3-1/2” handling equipment to rig floor. R/U to run upper completion. M/U XO’s to FOSV.
Static losses @ 2 BPH,P/U bullet seal assembly and proceed to RIH picking up 3-1/2” 9.3# L-80 EUE tubing to 81'’ MD. Hold Well Control Drill and discussion on
lessons learned. RIH picking up upper completion assembly with 3-1/2” 9.3# L-80 EUE tubing to 3065’ MD. Torque to 2800 ft/lbs with Doyon double stack tongs.
Test TEC wire every 1000'. Losses @ 0.5-1 BPH. Daily disposal to G&I = 0 bbls Total disposal to G&I = 14389 bbls. Daily fluid loss = 33 bbls Total fluid loss =
375 bbls. Daily metal recovered = 1.6 lbs Total metal recovered = 114 lbs.
6/13/2022 Run 3-1/2” 9.3# L-80 EUE tubing from 3,065' to 5,155'. Torque to 2800 ft/lbs with Doyon double stack tongs. Test TEC wire every 1000'. Losses @ 0.5-1 BPH.
12.0 bbls total lost while running tubing.,Locate no-go on liner top with 15k set down. Pick up and set down again to verify. L/D 3 joints of tubing and P/U 4.09' &
8.18' pup joint. M/U joint #160, hanger with pup joint and landing joint. Perform hanger penetration with TEC wire. Land tubing on hanger, 75K PU / 65K SO.
RILDS.,Rig up lines to pressure test IA. Utilize injection line from #1 mud pump with 9.5 ppg lubricated brine. Pumped 4.1 bbls to 3600 PSI, held for 30 min on
chart - good and bled back 4.1 bbls. Pressure test to 3600 PSI as per operation engineer for pre-production.,Wellhead rep install BPV in hanger with tee bar.
Remove 10' and 90' mouseholes. Clear Centrilift, casing and wellhead equipment from the rig floor. Sim-ops: begin cleaning pits and install diverter on M-28. On
Rig Gen Power at 14:30,Remove the MPD drip pan and bell nipple. Remove the kill line hose off the mud cross. N/D BOP stack, and set on the moving pedestal.
Install CTS plug in BPV. SimOps: Cleaning mud pits. Mobilize man basket & welding equipment to rig floor. Welder start prep Derrick board for removal. Mobilize
tree into cellar and set on Wellhead. Terminate tec wire at adapter flange. Torque adapter flange bolts. PT the tubing hanger void to 500 psi for 5 minutes and
5,000 psi for 10 minutes (good test). SimOps: Continue cleaning pits. Pick up landings & secure pipe shed. Inspect tires for move, R/D and move rock washer &
fuel trailer,RU to test the tree. Fill the tree with diesel. PT the tree to 250/5,000 psi (good test). RD testing equipment. Pull the CTS plug with the dry rod. shut in
and secure the tree, install gauges - tubing 0 psi, IA 0 psi. Centrilift final readings: tubing pressure = 1707 psi, IA pressure = 1808 psi, tubing/IA temp = 73°F. Rig
Released at 00:00.
Well Name:
Field:
County/State:
MP M-27
Milne Point
Hilcorp Energy Company Composite Report
, Alaska
5/22/2022Spud Date:
Pumped 4.1 bbls to 3600 PSI, held for 30 min on
chart - good and bled back 4.1 bbls. Pressure test to 3600 PSI as per operation engineer for pre-production.,W
Well Name Rig API Number Well Permit Number Start Date End Date
MP M-27 Eline / Fullbore 50-029-23716-00-00 222-0549 5/22/2022 7/16/2022
6/15/2022
Hilcorp Alaska, LLC
Weekly Operations Summary
MPU Well Support tied well into process with 2" 1502 hardline,with divert to tanks for clean up. PT'd temporary surface lines.
6/14/2022
Wellhead: M/U hanger to string, terminate one 1/4" Tech wire through hanger. land with 75K up and 65K SOW, RILDS.
Standby for testing, set 3" BPV from floor. Clean void, install CTS plug, RX-54, terminate Tech wire through adaptor. Test void
500/5 5K/10 Good test. Rig test tree, Good. Pull CTS plug through tree. Company man request to leave BPV in well. Secure
well and hang BPV sign.
ELine:
PT PCE 250L / 2500H. SHIFT XD-SS AT 4,921' MD (No issues). SET 3" JETPUMP (serial# - HC-00022, ratio: 12B) IN XD-SS AT
4,921' MD. WELL SHUT-IN ON DEPARTURE, NOTIFIED PAD OP.
Fullbore:
Displace IA (Convert well back to Injector) (Pressure test equipment to 250/3000 psi) Pump 107 bbls 8.3 Inhib. Brine and 220
bbls Dsl down IA.
ELine:
PULL JET PUMP (serial# HC-00022, ratio: 12A) @ 4908' SLM / 4921' MD. CLOSE SLEEVE @ 4908' SLM / 4908' MD. WELL S/I ON
DEPARTURE.
7/15/2022
7/16/2022
Support Techs set foundation and wellhouse and installed injection piping. Pressure tested injection lines to 3650 psi.
Fullbore:
Pre AOGCC MIT-IA to 2000 psi (PASSED)(Pressure test equipment to 250/2500 psi) Pump 21.9 bbls Dsl down IA to reach Test
pressure. 1st 15 Min IA lost 96 psi. 2nd 15 Min IA lost 33 psi. Bleed IA down w/ 4 bbls Dsl returned.
Pre AOGCC MIT-IA to 2000 psi (PASSED)(Pressure test equipment to 250/2500 psi) Pump 21.9 bbls Dsl down IA to reach Test
pressure. 1st 15 Min IA lost 96 psi. 2nd 15 Min IA lost 33 psi. Bleed IA down w/ 4 bbls Dsl returned
TD Shoe Depth: PBTD:
No. Jts. Returned
RKB RKB to BHF RKB to THF
Jts.
1
1
1
1
1
92
1
1
1
57
1
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? 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:
1.17
5/31/2022 38
Spud Mud
Type I/II cement 378 2.47
Premium G cement 400 1.16
4.5
2,453.98
Casing 9 5/8 47.0 L-80 TXP-BTC Tenaris 2,381.17 2,453.98 72.81
2,474.27 2,471.45
Casing Pup Joint 9 5/8 40.0 L-80 TXP-BTC 17.47 2,471.45
17.52 2,491.79 2,474.27
ES Cementer 10 3/4 TXP-BTC Halliburton 2.82
Casing Pup Joint 9 5/8 40.0 L-80 TXP-BTC
5,175.14
Casing 9 5/8 40.0 L-80 TXP-BTC Tenaris 2,683.35 5,175.14 2,491.79
5,215.74 5,176.54
Baffle Adapter 10 3/4 TXP-BTC Halliburton 1.40 5,176.54
1.31 5,217.05 5,215.74
Casing 9 5/8 40.0 L-80 TXP-BTC Tenaris 39.20
Float Collar 10 3/4 TXP-BTC Innovex
71 total 9-5/8" x 12"1/4" bowspring centralizers ran. Two in shoe joint w/ 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 25, every other joint to #49 then every third joint to #64. One each on joints #66 to 75. One each
with stop rings on pup joints above and below ES cementer.
One each on every third joint #78 to #126.
Casing 9 5/8 40.0 L-80 TXP-BTC Tenaris 81.77 5,298.82 5,217.05
www.wellez.net WellEz Information Management LLC ver_04818br
3
Ftg. Returned
Ftg. Cut Jt.19.79 Ftg. Balance
No. Jts. Delivered No. Jts. Run 129
Length Measurements W/O
Threads
Ftg. Delivered Ftg. Run 5,207.02
RKB to CHF
Type of Shoe:Innovex Casing Crew:Doyon
12 132.5
ES Cementer Closure OK
56
ArcticCem cement
Type
Premium G cement 270
Tuned Spacer
811 2.88
Stage Collar @
60
Bump press
100
240
5,301.005,307.00 5,176.54
CEMENTING REPORT
Csg Wt. On Slips:100,000
Spud Mud
13:55 5/30/2022 2,474
2474
15.8 82
Bump press
Cement to surface
Bump Plug?
Y
3.4
9.4 5 183.6/181.6
386.7/387.7
1150
25
Rig
FI
R
S
T
S
T
A
G
E
10Tuned Spacer 60
15.8
740
9.5 6
1720
10
10.7 416 5.2
100
580
Bump Plug?
Csg Wt. On Hook:260,000 Type Float Collar:Innovex No. Hrs to Run:16.5
32.39
9 5/8 47.0 L-81 TXP-BTC
53.929 5/8 47.0 L-82 TXP-BTC 21.53
TXP-BTC Innovex 2.18 5,301.00 5,298.82
18.89 72.81 53.92
Setting Depths
Component Size Wt. Grade THD Make Length Bottom Top
Hilcorp Energy Company
CASING & CEMENTING REPORT
Lease & Well No.MP M-27 Date Run 29-May-22
CASING RECORD
County State Alaska Supv.D. Yessak / I. Toomey
5,217.00
Floats Held
328.42 686.5
265 421.5
Spud mud
Rotate Csg Recip Csg Ft. Min. PPG9.4
Shoe @ 5301 FC @ Top of Liner
SE
C
O
N
D
S
T
A
G
E
Rig
1:55
Cement to surface
289.34 382.42 32.17
Casing (Or Liner) Detail
Shoe
Pup Joint
Cut Joint
10 3/4
Cement to surface
X
38
X
Cement to surface
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Chelsea Wright Digitally signed by Chelsea Wright
Date: 2022.06.13 11:27:04 -08'00'Benjamin Hand Digitally signed by Benjamin Hand
Date: 2022.06.13 12:02:28 -08'00'
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: 07/06/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL :
WELL: MPU M-27
PTD: 222-049
API: 50-029-23716-00-00
FINAL LWD FORMATION EVALUATION LOGS (05/25/2022 to 06/08/2022)
x AGR, DGR, 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:g
Please include current contact information if different from above.
PTD:222-049
T36738
Kayla Junke
Digitally signed by Kayla
Junke
Date: 2022.07.08 09:02:51
-08'00'
CAUTION: This email originated from outside the State of Alaska mail system.
Do not click links or open attachments unless you recognize the sender and know
the content is safe.
From:Rixse, Melvin G (OGC)
To:AOGCC Records (CED sponsored)
Subject:20220623 1353 Extension approved MPU M-27 (PTD #222-049 10-403 sundry #322-354) 10-407 request
Date:Monday, July 18, 2022 3:24:09 PM
From: Rixse, Melvin G (OGC)
Sent: Thursday, June 23, 2022 1:53 PM
To: 'Joseph Lastufka' <Joseph.Lastufka@hilcorp.com>
Subject: RE: MPU M-27 (PTD #222-049 10-403 sundry #322-354) 10-407 request
Joe,
Extension approved.
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: Thursday, June 23, 2022 10:12 AM
To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Subject: MPU M-27 (PTD #222-049 10-403 sundry #322-354) 10-407 request
Mel,
MPU M-27 (PTD #222-049) was completed on 6/13/22 and was requested to pre-produce up to 30
days (10-403 #322-354). The plan is to place the well on injection as soon as MPU M-28 is
completed. I’m requesting to hold off on submitting the 10-407 Completion Report until the well is
placed on its intended well status 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
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby
notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please
immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete
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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.
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ϯ ϱ͕ϬϯϬ͛ yEEŝƉƉůĞ͕Ϯ͘ϴϭϯ͕͟Ϯ͘ϳϱ͟EŽͲ'Ž Ϯ͘ϳϱϬ͟
ϰ ϱ͕ϭϰϯ͛ >ŽĐĂƚŽƌ^Ƶď͕ϴ͘Ϯϱ͟EŽͲ'Ž;ďŽƚƚŽŵŽĨůŽĐĂƚĞƌƐƉĂĐĞĚŽƵƚϮ͛Ϳ ϲ͘ϭϳϬ͟
ϱ ϱ͕ϭϰϰ͛ ƵůůĞƚ^ĞĂůƐʹdyWdŽƉŽdždžDƵůĞ^ŚŽĞ ϲ͘ϭϳϬ͟
>ŽǁĞƌŽŵƉůĞƚŝŽŶ
ϲ ϱ͕ϭϯϳ͛ ϵͲϱͬϴ͟^>yW>ŝŶĞƌdŽƉWĂĐŬĞƌ ϲ͘ϮϮϬ͟
ϳ ϭϰ͕ϱϵϰ͛ ^ŚŽĞ
ZĞǀŝƐĞĚLJ͗:E>ϲͬϭϯͬϮϬϮϮ
´6FUHHQ/LQHU
´'ULOOHG/LQHU
:ƚƐ dŽƉ;DͿ dŽƉ;dsͿ ƚŵ;DͿ ƚŵ;dsͿ
ϯ ϱϯϲϲ͛ ϯϳϲϬ͛ ϱϰϴϵ͛ ϯϴϬϱ͛
:ƚƐ dŽƉ;DͿ dŽƉ;dsͿ ƚŵ;DͿ ƚŵ;dsͿ
ϭ ϲϭϴϱ͛ ϯϵϯϱ͛ ϲϮϮϲ͛ ϯϵϯϵ͛
ϭ ϲϯϬϴ͛ ϯϵϰϴ͛ ϲϯϰϵ͛ ϯϵϱϮ͛
ϭ ϲϰϯϬ͛ ϯϵϲϭ͛ ϲϰϳϬ͛ ϯϵϲϰ͛
ϭ ϲϱϱϯ͛ ϯϵϲϵ͛ ϲϱϵϭ͛ ϯϵϳϭ͛
ϭ ϲϲϳϮ͛ ϯϵϳϭ͛ ϲϳϱϰ͛ ϯϵϲϴ͛
ϭ ϲϳϵϱ͛ ϯϵϲϲ͛ ϲϴϯϱ͛ ϯϵϲϰ͛
ϭ ϲϵϭϳ͛ ϯϵϲϬ͛ ϲϵϱϴ͛ ϯϵϱϴ͛
ϭ ϳϬϯϵ͛ ϯϵϱϲ͛ ϳϬϴϬ͛ ϯϵϱϱ͛
ϭ ϳϭϲϬ͛ ϯϵϱϭ͛ ϳϮϬϭ͛ ϯϵϰϵ͛
ϭ ϳϮϴϰ͛ ϯϵϰϯ͛ ϳϯϮϱ͛ ϯϵϰϭ͛
ϭ ϳϰϬϳ͛ ϯϵϯϴ͛ ϳϰϰϴ͛ ϯϵϯϳ͛
ϭ ϳϱϯϭ͛ ϯϵϯϳ͛ ϳϱϳϭ͛ ϯϵϯϴ͛
ϭ ϳϲϱϯ͛ ϯϵϰϭ͛ ϳϲϵϰ͛ ϯϵϰϰ͛
ϭ ϳϳϳϱ͛ ϯϵϱϬ͛ ϳϴϭϱ͛ ϯϵϱϯ͛
ϭ ϳϴϵϴ͛ ϯϵϱϵ͛ ϳϵϯϴ͛ ϯϵϲϮ͛
ϭ ϴϬϮϭ͛ ϯϵϲϳ͛ ϴϬϲϭ͛ ϯϵϲϴ͛
ϭ ϴϭϰϯ͛ ϯϵϳϭ͛ ϴϭϴϰ͛ ϯϵϳϭ͛
ϭ ϴϮϲϱ͛ ϯϵϳϮ͛ ϴϯϬϱ͛ ϯϵϳϮ͛
ϭ ϴϯϴϴ͛ ϯϵϳϮ͛ ϴϰϮϳ͛ ϯϵϳϮ͛
ϭ ϴϱϭϬ͛ ϯϵϳϮ͛ ϴϱϱϬ͛ ϯϵϳϮ͛
ϭ ϴϲϯϮ͛ ϯϵϳϰ͛ ϴϲϳϯ͛ ϯϵϳϱ͛
ϭ ϴϳϱϱ͛ ϯϵϳϱ͛ ϴϳϵϲ͛ ϯϵϳϱ͛
ϭ ϴϴϳϵ͛ ϯϵϳϮ͛ ϴϵϭϵ͛ ϯϵϳϬ͛
ϭ ϵϬϬϭ͛ ϯϵϲϲ͛ ϵϬϰϮ͛ ϯϵϲϰ͛
ϭ ϵϭϮϰ͛ ϯϵϭ͛ ϵϭϲϱ͛ ϯϵϲϬ͛
ϭ ϵϮϰϳ͛ ϯϵϱϵ͛ ϵϮϴϵ͛ ϯϵϱϵ͛
ϭ ϵϯϳϭ͛ ϯϵϱϵ͛ ϵϰϭϮ͛ ϯϵϲϬ͛
ϭ ϵϰϵϬ͛ ϯϵϲϮ͛ ϵϱϯϭ͛ ϯϵϲϯ͛
ϭ ϵϲϭϯ͛ ϯϵϲϰ͛ ϵϲϱϯ͛ ϯϵϲϰ͛
ϭ ϵϳϯϲ͛ ϯϵϲϯ͛ ϵϳϳϱ͛ ϯϵϲϰ͛
ϭ ϵϴϱϴ͛ ϯϵϲϲ͛ ϵϴϵϵ͛ ϯϵϲϴ͛
ϭ ϵϵϴϭ͛ ϯϵϳϯ͛ ϭϬϬϮϮ͛ ϯϵϳϱ͛
ϭ ϭϬϭϬϰ͛ ϯϵϴϭ͛ ϭϬϭϰϱ͛ ϯϵϴϯ͛
ϭ ϭϬϮϮϳ͛ ϯϵϴϳ͛ ϭϬϮϲϴ͛ ϯϵϴϴ͛
ϭ ϭϬϯϱϭ͛ ϯϵϵϬ͛ ϭϬϯϵϭ͛ ϯϵϵϬ͛
ϭ ϭϬϰϳϰ͛ ϯϵϵϮ͛ ϭϬϱϭϱ͛ ϯϵϵϮ͛
:ƚƐ dŽƉ;DͿ dŽƉ;dsͿ ƚŵ;DͿ ƚŵ;dsͿ
ϭ ϭϬϱϵϴ͛ ϯϵϵϯ͛ ϭϬϲϯϳ͛ ϯϵϵϰ͛
ϭ ϭϬϳϭϴ͛ ϯϵϵϰ͛ ϭϬϳϱϴ͛ ϯϵϵϰ͛
ϭ ϭϬϴϯϵ͛ ϯϵϵϰ͛ ϭϬϴϳϵ͛ ϯϵϵϰ͛
ϭ ϭϬϵϲϭ͛ ϯϵϵϱ͛ ϭϭϬϬϮ͛ ϯϵϵϱ͛
ϭ ϭϭϬϴϰ͛ ϯϵϵϲ͛ ϭϭϭϮϭ͛ ϯϵϵϳ͛
ϭ ϭϭϮϬϰ͛ ϯϵϵϵ͛ ϭϭϮϰϱ͛ ϯϵϵϵ͛
ϭ ϭϭϯϮϳ͛ ϯϵϵϵ͛ ϭϭϯϲϳ͛ ϯϵϵϴ͛
ϭ ϭϭϰϰϴ͛ ϯϵϵϰ͛ ϭϭϰϴϵ͛ ϯϵϵϯ͛
ϭ ϭϭϱϳϭ͛ ϯϵϵϬ͛ ϭϭϲϭϮ͛ ϯϵϴϵ͛
ϭ ϭϭϲϵϰ͛ ϯϵϴϴ͛ ϭϭϳϯϱ͛ ϯϵϴϳ͛
ϭ ϭϭϴϭϴ͛ ϯϵϴϳ͛ ϭϭϴϱϴ͛ ϯϵϴϳ͛
ϭ ϭϮϮϳϭ͛ ϯϵϱϵ͛ ϭϮϯϭϮ͛ ϯϵϱϲ͛
ϭ ϭϮϱϱϴ͛ ϯϵϯϰ͛ ϭϮϱϵϵ͛ ϯϵϯϭ͛
ϭ ϭϮϲϳϵ͛ ϯϵϮϰ͛ ϭϮϳϮϬ͛ ϯϵϮϭ͛
ϭ ϭϮϴϬϯ͛ ϯϵϭϱ͛ ϭϮϴϰϯ͛ ϯϵϭϯ͛
ϭ ϭϮϵϮϱ͛ ϯϵϭϬ͛ ϭϮϵϲϲ͛ ϯϵϬϵ͛
ϭ ϭϯϬϰϴ͛ ϯϵϬϴ͛ ϭϯϬϴϴ͛ ϯϵϬϴ͛
ϭ ϭϯϭϳϬ͛ ϯϵϬϴ͛ ϭϯϮϭϭ͛ ϯϵϬϴ͛
ϭ ϭϯϮϵϯ͛ ϯϵϬϴ͛ ϭϯϯϯϰ͛ ϯϵϬϴ͛
ϭ ϭϯϰϭϳ͛ ϯϵϭϬ͛ ϭϯϰϱϱ͛ ϯϵϭϮ͛
ϭ ϭϯϱϯϳ͛ ϯϵϭϴ͛ ϭϯϱϳϳ͛ ϯϵϭϮ͛
ϭ ϭϯϲϲϬ͛ ϯϵϮϳ͛ ϭϯϲϵϵ͛ ϯϵϮϵ͛
ϭ ϭϯϳϴϮ͛ ϯϵϯϲ͛ ϭϯϴϮϬ͛ ϯϵϯϵ͛
ϭ ϭϯϵϬϬ͛ ϯϵϰϱ͛ ϭϯϵϰϬ͛ ϯϵϰϴ͛
ϭ ϭϰϬϮϯ͛ ϯϵϱϮ͛ ϭϰϬϲϯ͛ ϯϵϱϰ͛
ϭ ϭϰϭϰϰ͛ ϯϵϱϲ͛ ϭϰϭϴϱ͛ ϯϵϱϳ͛
ϭ ϭϰϮϲϴ͛ ϯϵϱϵ͛ ϭϰϯϬϵ͛ ϯϵϲϬ͛
ϭ ϭϰϯϴϵ͛ ϯϵϲϭ͛ ϭϰϰϯϬ͛ ϯϵϲϭ͛
ϭ ϭϰϱϭϮ͛ ϯϵϲϭ͛ ϭϰϱϱϮ͛ ϯϵϲϭ͛
BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB
ZĞǀŝƐĞĚLJ͗:E>ϲͬϭϯͬϮϬϮϮ
WZKWK^ ^, Dd/
DŝůŶĞWŽŝŶƚhŶŝƚ
tĞůů͗DWhDͲϮϳ
>ĂƐƚŽŵƉůĞƚĞĚ͗d
Wd͗ϮϮϮͲϬϰϵ
^/E' d/>
^ŝnjĞ dLJƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ ƌŝĨƚ/ dŽƉ ƚŵ W&
ϮϬΗ ŽŶĚƵĐƚŽƌ ϭϮϵ͘ϱͬyͲϱϮͬtĞůĚ Eͬ ^ƵƌĨĂĐĞ ϭϭϰ͛ Eͬ
ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϳͬ>ͲϴϬͬdyW ϴ͘ϱϮϱ͟ ^ƵƌĨĂĐĞ Ϯ͕ϰϭϰ͛ Ϭ͘ϬϳϯϮ
ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬdyW ϴ͘ϲϳϵ͟ Ϯ͕ϰϭϰ͛ ϱ͕ϯϬϭ͛ Ϭ͘Ϭϳϱϴ
ϰͲϭͬϮ͟ >ŝŶĞƌͲƌŝůůĞĚ ϭϯ͘ϱͬ>ͲϴϬͬ,LJĚϲϮϱ ϯ͘ϵϮϬ͟ ϱ͕ϭϯϳ͛ ϭϰ͕ϱϵϲ͛Ϭ͘Ϭϭϰϵ
dh/E' d/>
ϯͲϭͬϮΗ dƵďŝŶŐ ϵ͘ϯͬ>ͲϴϬͬ h ϴZ Ϯ͘ϴϲϳ͟ ^ƵƌĨĂĐĞ ϱ͕ϭϱϯ͛ Ϭ͘ϬϬϴϳ
KW E,K> ͬ D Ed d/>
ϰϮ͟ ϭϰLJĚƐŽŶĐƌĞƚĞ
ϭϮͲϭͬϰΗ ^ƚŐϭʹ>ĞĂĚϯϳϴƐdžͬdĂŝůϰϬϬƐdž
^ƚŐϮʹ>ĞĂĚϴϭϭƐdžͬdĂŝůϮϳϬƐdž
ϴͲϭͬϮ͟ ĞŵĞŶƚůĞƐƐ/ŶũĞĐƚŝŽŶ>ŝŶĞƌ
dZ Θt >>,
dƌĞĞ ĂŵĞƌŽŶϯϭͬϴΗϱDǁͬϯͲϭͬϴ͟ϱDĂŵĞƌŽŶtŝŶŐ
tĞůůŚĞĂĚ ĂŵĞƌŽŶϭϭ͟ϱ<džƐůŝƉůŽĐŬďŽƚƚŽŵǁͬ;ϮͿϮͲϭͬϭϲ͟ϱ<ŽƵƚƐ
' E Z>t >>/E&K
W/η͗ϱϬͲϬϮϵͲϮϯϳϭϲͲϬϬͲϬϬ
ŽŵƉůĞƚŝŽŶĂƚĞ͗d
t >>/E>/Ed/KE d/>
<KWΛϮϴϵ͛
DĂdž,ŽůĞŶŐůĞсϵϲΣΛϭϮ͕ϭϭϰ͛D
dсϭϰ͕ϱϵϲ͛;DͿͬdсϯ͕ϵϲϬ͛;dsͿ
ϮϬ͟
KƌŝŐ͘< ůĞǀ͗͘ϱϴ͘ϱϴ͛ͬ'> ůĞǀ͗͘ Ϯϰ͘ϳ͛
ϯͲϭͬϮ͟
ϵͲϱͬϴ͟
6HH
'ULOOHG
/LQHU
'HWDLO
Wdсϭϰ͕ϱϵϲ͛ ;DͿͬWdсϯ͕ϵϲϬ͛ ;dsͿ
´µ(6¶
&HPHQWHU#
¶
ϰͲϭͬϮ͟
: t >Zz d/>
EŽ dŽƉD /ƚĞŵ
/
hƉƉĞƌŽŵƉůĞƚŝŽŶ
ϭ ϰ͕ϵϮϭ͛ ^ůŝĚŝŶŐ^ůĞĞǀĞǁͬϭϮ:ĞƚWƵŵƉ Ϯ͘ϴϭϯ͟
Ϯ ϰ͕ϵϳϳ͛ ĞŶŝƚŚ'ĂƵŐĞ͕ĂŬĞƌ
ϯ ϱ͕ϬϯϬ͛ yEEŝƉƉůĞ͕Ϯ͘ϴϭϯ͕Ϯ͘ϳϱ͟EŽͲ'Ž Ϯ͘ϳϱϬ͟
ϰ ϱ͕ϭϰϯ͛ >ŽĐĂƚŽƌ^Ƶď͕ϴ͘Ϯϱ͟EŽͲ'Ž;ďŽƚƚŽŵŽĨůŽĐĂƚĞƌƐƉĂĐĞĚŽƵƚϮ͛Ϳ ϲ͘ϭϳϬ͟
ϱ ϱ͕ϭϰϰ͛ ƵůůĞƚ^ĞĂůƐʹdyWdŽƉŽdždžDƵůĞ^ŚŽĞ ϲ͘ϭϳϬ͟
>ŽǁĞƌŽŵƉůĞƚŝŽŶ
ϲ ϱ͕ϭϯϳ͛ ϵͲϱͬϴ͟^>yW>ŝŶĞƌdŽƉWĂĐŬĞƌ ϲ͘ϮϮϬ͟
ϳ ϭϰ͕ϱϵϰ͛ ^ŚŽĞ
ZĞǀŝƐĞĚLJ͗:E>ϲͬϭϯͬϮϬϮϮ
´6FUHHQ/LQHU
´'ULOOHG/LQHU
:ƚƐ dŽƉ;DͿ dŽƉ;dsͿ ƚŵ;DͿ ƚŵ;dsͿ
ϯ ϱϯϲϲ͛ ϯϳϲϬ͛ ϱϰϴϵ͛ ϯϴϬϱ͛
:ƚƐ dŽƉ;DͿ dŽƉ;dsͿ ƚŵ;DͿ ƚŵ;dsͿ
ϭ ϲϭϴϱ͛ ϯϵϯϱ͛ ϲϮϮϲ͛ ϯϵϯϵ͛
ϭ ϲϯϬϴ͛ ϯϵϰϴ͛ ϲϯϰϵ͛ ϯϵϱϮ͛
ϭ ϲϰϯϬ͛ ϯϵϲϭ͛ ϲϰϳϬ͛ ϯϵϲϰ͛
ϭ ϲϱϱϯ͛ ϯϵϲϵ͛ ϲϱϵϭ͛ ϯϵϳϭ͛
ϭ ϲϲϳϮ͛ ϯϵϳϭ͛ ϲϳϱϰ͛ ϯϵϲϴ͛
ϭ ϲϳϵϱ͛ ϯϵϲϲ͛ ϲϴϯϱ͛ ϯϵϲϰ͛
ϭ ϲϵϭϳ͛ ϯϵϲϬ͛ ϲϵϱϴ͛ ϯϵϱϴ͛
ϭ ϳϬϯϵ͛ ϯϵϱϲ͛ ϳϬϴϬ͛ ϯϵϱϱ͛
ϭ ϳϭϲϬ͛ ϯϵϱϭ͛ ϳϮϬϭ͛ ϯϵϰϵ͛
ϭ ϳϮϴϰ͛ ϯϵϰϯ͛ ϳϯϮϱ͛ ϯϵϰϭ͛
ϭ ϳϰϬϳ͛ ϯϵϯϴ͛ ϳϰϰϴ͛ ϯϵϯϳ͛
ϭ ϳϱϯϭ͛ ϯϵϯϳ͛ ϳϱϳϭ͛ ϯϵϯϴ͛
ϭ ϳϲϱϯ͛ ϯϵϰϭ͛ ϳϲϵϰ͛ ϯϵϰϰ͛
ϭ ϳϳϳϱ͛ ϯϵϱϬ͛ ϳϴϭϱ͛ ϯϵϱϯ͛
ϭ ϳϴϵϴ͛ ϯϵϱϵ͛ ϳϵϯϴ͛ ϯϵϲϮ͛
ϭ ϴϬϮϭ͛ ϯϵϲϳ͛ ϴϬϲϭ͛ ϯϵϲϴ͛
ϭ ϴϭϰϯ͛ ϯϵϳϭ͛ ϴϭϴϰ͛ ϯϵϳϭ͛
ϭ ϴϮϲϱ͛ ϯϵϳϮ͛ ϴϯϬϱ͛ ϯϵϳϮ͛
ϭ ϴϯϴϴ͛ ϯϵϳϮ͛ ϴϰϮϳ͛ ϯϵϳϮ͛
ϭ ϴϱϭϬ͛ ϯϵϳϮ͛ ϴϱϱϬ͛ ϯϵϳϮ͛
ϭ ϴϲϯϮ͛ ϯϵϳϰ͛ ϴϲϳϯ͛ ϯϵϳϱ͛
ϭ ϴϳϱϱ͛ ϯϵϳϱ͛ ϴϳϵϲ͛ ϯϵϳϱ͛
ϭ ϴϴϳϵ͛ ϯϵϳϮ͛ ϴϵϭϵ͛ ϯϵϳϬ͛
ϭ ϵϬϬϭ͛ ϯϵϲϲ͛ ϵϬϰϮ͛ ϯϵϲϰ͛
ϭ ϵϭϮϰ͛ ϯϵϭ͛ ϵϭϲϱ͛ ϯϵϲϬ͛
ϭ ϵϮϰϳ͛ ϯϵϱϵ͛ ϵϮϴϵ͛ ϯϵϱϵ͛
ϭ ϵϯϳϭ͛ ϯϵϱϵ͛ ϵϰϭϮ͛ ϯϵϲϬ͛
ϭ ϵϰϵϬ͛ ϯϵϲϮ͛ ϵϱϯϭ͛ ϯϵϲϯ͛
ϭ ϵϲϭϯ͛ ϯϵϲϰ͛ ϵϲϱϯ͛ ϯϵϲϰ͛
ϭ ϵϳϯϲ͛ ϯϵϲϯ͛ ϵϳϳϱ͛ ϯϵϲϰ͛
ϭ ϵϴϱϴ͛ ϯϵϲϲ͛ ϵϴϵϵ͛ ϯϵϲϴ͛
ϭ ϵϵϴϭ͛ ϯϵϳϯ͛ ϭϬϬϮϮ͛ ϯϵϳϱ͛
ϭ ϭϬϭϬϰ͛ ϯϵϴϭ͛ ϭϬϭϰϱ͛ ϯϵϴϯ͛
ϭ ϭϬϮϮϳ͛ ϯϵϴϳ͛ ϭϬϮϲϴ͛ ϯϵϴϴ͛
ϭ ϭϬϯϱϭ͛ ϯϵϵϬ͛ ϭϬϯϵϭ͛ ϯϵϵϬ͛
ϭ ϭϬϰϳϰ͛ ϯϵϵϮ͛ ϭϬϱϭϱ͛ ϯϵϵϮ͛
:ƚƐ dŽƉ;DͿ dŽƉ;dsͿ ƚŵ;DͿ ƚŵ;dsͿ
ϭ ϭϬϱϵϴ͛ ϯϵϵϯ͛ ϭϬϲϯϳ͛ ϯϵϵϰ͛
ϭ ϭϬϳϭϴ͛ ϯϵϵϰ͛ ϭϬϳϱϴ͛ ϯϵϵϰ͛
ϭ ϭϬϴϯϵ͛ ϯϵϵϰ͛ ϭϬϴϳϵ͛ ϯϵϵϰ͛
ϭ ϭϬϵϲϭ͛ ϯϵϵϱ͛ ϭϭϬϬϮ͛ ϯϵϵϱ͛
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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 t t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Owner/Contractor: Rig No.:14 DATE: 6/1/22
Rig Rep.: Rig Phone: 670-3096
Operator: Op. Phone:670-3090
Rep.: E-Mail
Well Name: PTD #22220490 Sundry #
Operation: Drilling: x Workover: Explor.:
Test: Initial: x Weekly: Bi-Weekly: Other:
Rams:250-3000 Annular:250-3000 Valves:250-3000 MASP:1352
MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES:
Test Result Test Result Quantity Test Result
Location Gen.P Well Sign P Upper Kelly 1P
Housekeeping P Rig P Lower Kelly 1P
PTD On Location P Hazard Sec.P Ball Type 1P
Standing Order Posted P Misc.NA 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" X 5" VBR P Flow Indicator PP
#2 Rams 1 Blinds P Meth Gas Detector PP
#3 Rams 1 2-7/8" X 5" VBR P H2S Gas Detector PP
#4 Rams 0NAMS Misc 0NA
#5 Rams 0NA
#6 Rams 0NA Quantity Test Result
Choke Ln. Valves 1 3-1/8" 5K P Inside Reel valves 0NA
HCR Valves 2 3-1/8" 5K P
Kill Line Valves 2 3-1/8" 5K P
Check Valve 0NAACCUMULATOR SYSTEM:
BOP Misc 0 NA Time/Pressure Test Result
System Pressure (psi)3000 P
CHOKE MANIFOLD:Pressure After Closure (psi)1600 P
Quantity Test Result 200 psi Attained (sec)45 P
No. Valves 14 P Full Pressure Attained (sec)194 P
Manual Chokes 1P Blind Switch Covers: All stations Yes
Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 6 @ 1850 P
CH Misc 0NA ACC Misc 0NA
Test Results
Number of Failures:0 Test Time:6.0 Hours
Repair or replacement of equipment will be made within days.
Remarks:
AOGCC Inspection
24 hr Notice YES Date/Time 5/30/22 9:56 AM
Waived By
Test Start Date/Time:5/31/2022 22:30
(date) (time)Witness
Test Finish Date/Time:6/1/2022 4:30 AM
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Guy Cook
Doyon
Test Annular with 3-1/2" test joint to 250-3000 psi. Upper & Lower rams with 3-1/2" & 5" test joint. draw down on BOP
functioned from both primary & remote controls. Tested gas alarms and All tests preformed against Test plug.
J. Hansen / A. Carlo
Hilcorp
D Yessak/ I. Toomey
MPU M-27
Test Pressure (psi):
dyessak@hilcorp.com
Form 10-424 (Revised 02/2022) 2022-0601_BOP_Doyon14_MPU_M-27
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37'
Date: 5/24/2022 Development: X Exploratory:
Drlg Contractor: Rig No. 14 AOGCC Rep:
Operator:Oper. Rep:
Field/Unit/Well No.:Rig Rep:
PTD No.: 2220490 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: 1800 psig P Vent Line(s) Size: 16 in. P
200 psi Recharge Time: 38 Seconds P Vent Line(s) Length: 305 ft. P
Full Recharge Time:158 Seconds P Closest Ignition Source: 95 ft. P
Nitrogen Bottles (Number of): 6 Outlet from Rig Substructure: 270 ft. P
Avg. Pressure: 1925 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: 22 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:
phoebe.brooks@alaska.gov
Hilcorp Alaska LLC
AOGCC Adam Earl waived witness on 5-24-2022 @ 16:05 hrs. Function test performed utilizing a joint 5'' drill pipe, Rig electrician calibrated and
tested the gas alarms. Test PVT gain/loss and flow alarm.
0
Yessak / Vanderpool
Milne Point Unit M-27
AOGCC.Inspectors@alaska.gov
0
Doyon
TTEST DATA
TTEST DETAILS
jim.regg@alaska.gov
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
Waived
ULJ#GR\RQGULOOLQJFRP
670-3096
Shones / Carlo
Form 10-425 (Revised 11/2015)2022-0524_Diverter_Doyon14_MPU_M-27
9
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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 M-27
Hilcorp Alaska, LLC
Permit to Drill Number: 222-049
Surface Location: 4913' FSL, 141' FEL, Sec. 14, T13N, R09E, UM, AK
Bottomhole Location: 2623' FNL, 1604' FEL, Sec. 02, T13N, R09E, 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 well logs
run must be submitted to the AOGCCwithin 90 days after completion, suspension or abandonment
of this well.
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 April, 2022.
Jeremy Price
Digitally signed by
Jeremy Price
Date: 2022.05.10
09:57:48 -08'00'
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Jeremy Price Digitally signed by Jeremy Price
Date: 2022.05.10 09:58:10 -08'00'
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Milne Point Unit
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Milne Point Unit
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Drilling Procedure
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Milne Point Unit
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Milne Point Unit
M-27 SB Injector
Drilling Procedure
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Milne Point Unit
M-27 SB Injector
Drilling Procedure
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1 25 0 0
1300013500140001450014570MPU M-27 wp06Start Dir 3º/100' : 300' MD, 300'TVDStart Dir 4º/100' : 600' MD, 598.77'TVDEnd Dir : 1805.88' MD, 1594.05' TVDStart Dir 4.5º/100' : 3169.83' MD, 2391.99'TVDEnd Dir : 5872.01' MD, 3923.27' TVDStart Dir 2.5º/100' : 6072.01' MD, 3940.7'TVDEnd Dir : 6371.19' MD, 3950.29' TVDStart Dir 2.5º/100' : 6647.1' MD, 3943.92'TVDEnd Dir : 6700.36' MD, 3943.3' TVDStart Dir 2º/100' : 7175.36' MD, 3943.3'TVDEnd Dir : 7518.1' MD, 3956.46' TVDStart Dir 2º/100' : 7616.1' MD, 3963.98'TVDEnd Dir : 7882.08' MD, 3974.86' TVDStart Dir 4º/100' : 8562.08' MD, 3978.3'TVDEnd Dir : 8663.4' MD, 3975.23' TVDStart Dir 3º/100' : 8932.26' MD, 3957.59'TVDEnd Dir : 9064.03' MD, 3953.48' TVDStart Dir 2º/100' : 9914.03' MD, 3956.3'TVDEnd Dir : 10113.43' MD, 3963.89' TVDStart Dir 2º/100' : 10206.71' MD, 3970.69'TVDEnd Dir : 10415.78' MD, 3978.3' TVDStart Dir 2º/100' : 11465.78' MD, 3978.3'TVDEnd Dir : 11773.16' MD, 3961.83' TVDStart Dir 2º/100' : 11945.42' MD, 3943.39'TVDEnd Dir : 12032.81' MD, 3935.36' TVDStart Dir 2.5º/100' : 12532.81' MD, 3897'TVDEnd Dir : 12702.82' MD, 3890.25' TVDStart Dir 2º/100' : 13449' MD, 3888.3'TVDEnd Dir : 13656.53' MD, 3895.26' TVDStart Dir 2º/100' : 13738.61' MD, 3900.99'TVDEnd Dir : 13960.11' MD, 3907.88' TVDTotal Depth : 14570.11' MD, 3903.3' TVDSV6EOCUSV5SV4SV3SV2Base PermafrostSV1UG4UG4AUG3UG Coal 2UG Coal 1LA3LA2LA1LDLEUG_MBUG MDUG MEUG MFSB NASB NBSB NCSB NDSB NESB NFSB OAHilcorp Alaska, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: Plan: MPU M-27Ground Level: 24.60+N/-S +E/-WNorthingEastingLatitudeLongitude0.000.006027766.00534024.00 70° 29' 12.778 N 149° 43' 18.878 WSURVEY PROGRAMDate: 2016-07-15T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool33.70 6072.00 MPU M-27 wp06 (M-27) GYD_Quest GWD6072.00 14570.11 MPU M-27 wp06 (M-27) GYD_Quest GWDFORMATION TOP DETAILSTVDPath TVDssPath MDPath Formation844.39 786.09 853.33 SV61068.30 1010.00 1098.13 EOCU1340.30 1282.00 1430.18 SV51445.30 1387.00 1574.36 SV41529.30 1471.00 1700.06 SV31634.30 1576.00 1874.67 SV21888.30 1830.00 2308.85 Base Permafrost1918.30 1860.00 2360.13 SV12162.30 2104.00 2777.21 UG42204.30 2146.00 2849.00 UG4A2553.30 2495.00 3426.88 UG32645.30 2587.00 3561.72 UG Coal 22826.30 2768.00 3813.47 UG Coal 13215.40 3157.10 4339.58 LA33247.44 3189.14 4384.14 LA23271.85 3213.55 4418.40 LA13379.64 3321.34 4573.74 LD3416.27 3357.97 4628.45 LE3481.25 3422.95 4728.70 UG_MB3536.53 3478.23 4817.99 UG MD3632.30 3574.00 4984.84 UG ME3672.30 3614.00 5060.82 UG MF3753.30 3695.00 5232.26 SB NA3792.42 3734.12 5327.72 SB NB3812.30 3754.00 5381.04 SB NC3820.30 3762.00 5403.67 SB ND3836.30 3778.00 5451.41 SB NE3886.30 3828.00 5634.36 SB NF3926.30 3868.00 5906.79 SB OAREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU M-27, True NorthVertical (TVD) Reference:M-27 as staked RKB @ 58.30usftMeasured Depth Reference:M-27 as staked RKB @ 58.30usftCalculation Method: Minimum CurvatureProject:Milne PointSite:M Pt Moose PadWell:Plan: MPU M-27Wellbore:M-27Design:MPU M-27 wp06CASING DETAILSTVD TVDSS MD SizeName3940.70 3882.40 6072.00 9-5/8 9 5/8" x 12 1/4"3903.30 3845.00 14570.11 4-1/2 4 1/2" x 8 1/2"SECTION DETAILSSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation1 33.70 0.00 0.00 33.70 0.00 0.00 0.00 0.00 0.002 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 Start Dir 3º/100' : 300' MD, 300'TVD3 600.00 9.00 145.00 598.77 -19.26 13.49 3.00 145.00 -23.28 Start Dir 4º/100' : 600' MD, 598.77'TVD4 1250.00 34.58 129.68 1197.65 -181.50 187.62 4.00 -20.00 -246.895 1805.88 54.20 114.37 1594.05 -377.71 518.52 4.00 -34.48 -571.95 End Dir : 1805.88' MD, 1594.05' TVD6 3169.83 54.20 114.37 2391.99 -834.12 1526.18 0.00 0.00 -1436.07 Start Dir 4.5º/100' : 3169.83' MD, 2391.99'TVD7 5872.01 85.00 339.00 3923.27 522.30 2395.90 4.50 -124.74 -622.34 End Dir : 5872.01' MD, 3923.27' TVD8 6072.01 85.00 339.00 3940.70 708.31 2324.50 0.00 0.00 -424.19 Start Dir 2.5º/100' : 6072.01' MD, 3940.7'TVD9 6371.19 91.32 335.00 3950.29 983.36 2207.73 2.50 -32.37 -126.11 End Dir : 6371.19' MD, 3950.29' TVD10 6647.10 91.32 335.00 3943.92 1233.35 2091.18 0.00 0.00 149.55 Start Dir 2.5º/100' : 6647.1' MD, 3943.92'TVD11 6700.36 90.00 335.14 3943.30 1281.65 2068.73 2.50 174.10 202.78 End Dir : 6700.36' MD, 3943.3' TVD12 7175.36 90.00 335.14 3943.30 1712.64 1869.04 0.00 0.00 677.45 M-27 wp06 tgt2 Start Dir 2º/100' : 7175.36' MD, 3943.3'TVD13 7518.10 85.60 329.88 3956.46 2016.28 1711.06 2.00 -129.99 1019.72 End Dir : 7518.1' MD, 3956.46' TVD14 7616.10 85.60 329.88 3963.98 2100.79 1662.02 0.00 0.00 1117.28 Start Dir 2º/100' : 7616.1' MD, 3963.98'TVD15 7882.08 89.71 333.26 3974.86 2334.43 1535.55 2.00 39.52 1382.86 End Dir : 7882.08' MD, 3974.86' TVD16 8562.08 89.71 333.26 3978.30 2941.70 1229.59 0.00 0.00 2062.85 M-27 wp06 tgt4 Start Dir 4º/100' : 8562.08' MD, 3978.3'TVD17 8663.40 93.76 333.23 3975.23 3032.11 1184.01 4.00 -0.36 2164.10 End Dir : 8663.4' MD, 3975.23' TVD18 8932.26 93.76 333.23 3957.59 3271.64 1063.20 0.00 0.00 2432.37 Start Dir 3º/100' : 8932.26' MD, 3957.59'TVD19 9064.03 89.81 333.30 3953.48 3389.25 1003.96 3.00 179.05 2564.05 End Dir : 9064.03' MD, 3953.48' TVD20 9914.03 89.81 333.30 3956.30 4148.61 622.05 0.00 0.00 3414.03 M-27 wp06 tgt6 Start Dir 2º/100' : 9914.03' MD, 3956.3'TVD21 10113.43 85.82 333.44 3963.89 4326.69 532.75 2.00 177.97 3613.25 End Dir : 10113.43' MD, 3963.89' TVD22 10206.71 85.82 333.44 3970.69 4409.91 491.16 0.00 0.00 3706.27 Start Dir 2º/100' : 10206.71' MD, 3970.69'TVD23 10415.78 90.00 333.22 3978.30 4596.57 397.40 2.00 -3.04 3915.16 End Dir : 10415.78' MD, 3978.3' TVD24 11465.78 90.00 333.22 3978.30 5533.95 -75.69 0.00 0.00 4965.15 M-27 wp06 tgt8 Start Dir 2º/100' : 11465.78' MD, 3978.3'TVD25 11773.16 96.15 333.38 3961.83 5808.03 -213.54 2.00 1.50 5271.94 End Dir : 11773.16' MD, 3961.83' TVD26 11945.42 96.15 333.38 3943.39 5961.14 -290.27 0.00 0.00 5443.20 Start Dir 2º/100' : 11945.42' MD, 3943.39'TVD27 12032.81 94.40 333.29 3935.36 6038.91 -329.32 2.00 -177.01 5530.22 End Dir : 12032.81' MD, 3935.36' TVD28 12532.81 94.40 333.29 3897.00 6484.24 -553.40 0.00 0.00 6028.74 Start Dir 2.5º/100' : 12532.81' MD, 3897'TVD29 12702.82 90.15 333.25 3890.25 6635.93 -629.80 2.50 -179.40 6198.57 End Dir : 12702.82' MD, 3890.25' TVD30 13449.00 90.15 333.25 3888.30 7302.21 -965.70 0.00 0.00 6944.74 M-27 wp06 tgt11 Start Dir 2º/100' : 13449' MD, 3888.3'TVD31 13656.53 86.00 333.42 3895.26 7487.53 -1058.77 2.00 177.59 7152.11 End Dir : 13656.53' MD, 3895.26' TVD32 13738.61 86.00 333.42 3900.99 7560.75 -1095.41 0.00 0.00 7233.98 Start Dir 2º/100' : 13738.61' MD, 3900.99'TVD33 13960.11 90.43 333.26 3907.88 7758.56 -1194.72 2.00 -2.08 7455.32 End Dir : 13960.11' MD, 3907.88' TVD34 14570.11 90.43 333.26 3903.30 8303.31 -1469.18 0.00 0.00 8065.29 M-27 wp06 tgt13 Total Depth : 14570.11' MD, 3903.3' TVD
-1050
-525
0
525
1050
1575
2100
2625
3150
3675
4200
4725
5250
5775
6300
6825
7350
7875
8400
South(-)/North(+) (1050 usft/in)-2100 -1575 -1050 -525 0 525 1050 1575 2100 2625 3150 3675 4200 4725
West(-)/East(+) (1050 usft/in)
M-27 wp06 tgt13
M-27 wp06 tgt12
M-27 wp06 tgt11
M-27 wp06 tgt10
M-27 wp06 tgt9
M-27 wp06 tgt8
M-27 wp06 tgt7
M-27 wp06 tgt6
M-27 wp06 tgt5
M-27 wp06 tgt4
M-27 wp06 tgt3
M-27 wp06 tgt1
M-27 wp06 tgt2
9 5/8" x 12 1/4"
4 1/2" x 8 1/2"750125015001750200022502500275030003
2
5
0
3500
3750
3 9 0 3
MPU M-27 wp06
Start Dir 3º/100' : 300' MD, 300'TVD
Start Dir 4º/100' : 600' MD, 598.77'TVD
End Dir : 1805.88' MD, 1594.05' TVD
Start Dir 4.5º/100' : 3169.83' MD, 2391.99'TVD
End Dir : 5872.01' MD, 3923.27' TVD
Start Dir 2.5º/100' : 6072.01' MD, 3940.7'TVD
End Dir : 6371.19' MD, 3950.29' TVD
Start Dir 2.5º/100' : 6647.1' MD, 3943.92'TVD
End Dir : 6700.36' MD, 3943.3' TVD
Start Dir 2º/100' : 7175.36' MD, 3943.3'TVD
End Dir : 7518.1' MD, 3956.46' TVD
Start Dir 2º/100' : 7616.1' MD, 3963.98'TVD
End Dir : 7882.08' MD, 3974.86' TVD
Start Dir 4º/100' : 8562.08' MD, 3978.3'TVD
End Dir : 8663.4' MD, 3975.23' TVD
Start Dir 3º/100' : 8932.26' MD, 3957.59'TVD
End Dir : 9064.03' MD, 3953.48' TVD
Start Dir 2º/100' : 9914.03' MD, 3956.3'TVD
End Dir : 10113.43' MD, 3963.89' TVD
Start Dir 2º/100' : 10206.71' MD, 3970.69'TVD
End Dir : 10415.78' MD, 3978.3' TVD
Start Dir 2º/100' : 11465.78' MD, 3978.3'TVD
End Dir : 11773.16' MD, 3961.83' TVD
Start Dir 2º/100' : 11945.42' MD, 3943.39'TVD
End Dir : 12032.81' MD, 3935.36' TVD
Start Dir 2.5º/100' : 12532.81' MD, 3897'TVD
End Dir : 12702.82' MD, 3890.25' TVD
Start Dir 2º/100' : 13449' MD, 3888.3'TVD
End Dir : 13656.53' MD, 3895.26' TVD
Start Dir 2º/100' : 13738.61' MD, 3900.99'TVD
End Dir : 13960.11' MD, 3907.88' TVD
Total Depth : 14570.11' MD, 3903.3' TVD
CASING DETAILS
TVD TVDSS MD Size Name
3940.70 3882.40 6072.00 9-5/8 9 5/8" x 12 1/4"
3903.30 3845.00 14570.11 4-1/2 4 1/2" x 8 1/2"
Project: Milne Point
Site: M Pt Moose Pad
Well:Plan: MPU M-27
Wellbore: M-27
Plan: MPU M-27 wp06
WELL DETAILS: Plan: MPU M-27
Ground Level: 24.60
+N/-S +E/-W Northing Easting Latitude Longitude
0.00 0.00
6027766.00 534024.00 70° 29' 12.778 N 149° 43' 18.878 W
REFERENCE INFORMATION
Co-ordinate (N/E) Reference:Well Plan: MPU M-27, True North
Vertical (TVD) Reference: M-27 as staked RKB @ 58.30usft
Measured Depth Reference:M-27 as staked RKB @ 58.30usft
Calculation Method:Minimum Curvature
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0.001.002.003.004.00Separation Factor0 325 650 975 1300 1625 1950 2275 2600 2925 3250 3575 3900 4225 4550 4875 5200 5525 5850 6175Measured Depth (650 usft/in)MPU M-11MPU M-44iNo-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:Plan: MPU M-27 NAD 1927 (NADCON CONUS)Alaska Zone 04Ground Level: 24.60+N/-S +E/-W Northing EastingLatitudeLongitude0.000.006027766.00534024.0070° 29' 12.778 N149° 43' 18.878 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU M-27, True NorthVertical (TVD) Reference: M-27 as staked RKB @ 58.30usftMeasured Depth Reference:M-27 as staked RKB @ 58.30usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2016-07-15T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool33.70 6072.00 MPU M-27 wp06 (M-27) GYD_Quest GWD6072.00 14570.11 MPU M-27 wp06 (M-27) GYD_Quest GWD0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)0 325 650 975 1300 1625 1950 2275 2600 2925 3250 3575 3900 4225 4550 4875 5200 5525 5850 6175Measured Depth (650 usft/in)MPU M-13MPU M-28 wp06MPU M-29 wp06M-30i wp02GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference33.70 To 14570.11Project: Milne PointSite: M Pt Moose PadWell: Plan: MPU M-27Wellbore: M-27Plan: MPU M-27 wp06Ladder / S.F. Plots1 of 2CASING DETAILSTVD TVDSS MD Size Name3940.70 3882.40 6072.00 9-5/8 9 5/8" x 12 1/4"3903.30 3845.00 14570.11 4-1/2 4 1/2" x 8 1/2"
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0.001.002.003.004.00Separation Factor6300 6750 7200 7650 8100 8550 9000 9450 9900 10350 10800 11250 11700 12150 12600 13050 13500 13950 14400Measured Depth (900 usft/in)MPU M-11MPU M-28 wp06MPU M-29 wp06No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:Plan: MPU M-27 NAD 1927 (NADCON CONUS)Alaska Zone 04Ground Level: 24.60+N/-S +E/-W Northing EastingLatitudeLongitude0.000.006027766.00534024.0070° 29' 12.778 N149° 43' 18.878 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU M-27, True NorthVertical (TVD) Reference: M-27 as staked RKB @ 58.30usftMeasured Depth Reference:M-27 as staked RKB @ 58.30usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2016-07-15T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool33.70 6072.00 MPU M-27 wp06 (M-27) GYD_Quest GWD6072.00 14570.11 MPU M-27 wp06 (M-27) GYD_Quest GWD0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)6300 6750 7200 7650 8100 8550 9000 9450 9900 10350 10800 11250 11700 12150 12600 13050 13500 13950 14400Measured Depth (900 usft/in)GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference33.70 To 14570.11Project: Milne PointSite: M Pt Moose PadWell: Plan: MPU M-27Wellbore: M-27Plan: MPU M-27 wp06Ladder / S.F. Plots2 of 2CASING DETAILSTVD TVDSS MD Size Name3940.70 3882.40 6072.00 9-5/8 9 5/8" x 12 1/4"3903.30 3845.00 14570.11 4-1/2 4 1/2" x 8 1/2"
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