Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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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 1972'
L-80 3954'
4-1/2" L-80 4044'
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 Drilled Liner8-1/2"
TUBING RECORD
Liner Top Packer
6882'3-1/2" 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 - 856 sx / T - 270 sx
42"
Surface 2522' Stg 1 L - 516 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
7/29/2022
4914' FSL, 80' FEL, Sec. 14, T13N, R09E, UM, AK
1465' FNL, 1278' FEL, Sec. 02, T13N, R09E, UM, AK
222-072 / 322-410
Milne Point Field / Schrader Bluff Oil Pool
58.83'
16528' / 4043'
7/23/2022
7/8/2022
HOLE SIZE AMOUNT
PULLED
50-029-23719-00-00
MPU M-29
534085 6027767
581' FSL, 2279' FEL, Sec. 12, T13N, R09E, UM, AK
CEMENTING RECORD
6028729
SETTING DEPTH TVD
6037221
BOTTOM TOP
Surface
Surface
ROP, AGR, DGR, ABG, EWR, ADR MD & TVD
CASING WT. PER
FT.GRADE
13.5#
537160
532837
TOP
SETTING DEPTH MD
Surface
6877'
Per 20 AAC 25.283 (i)(2) attach electronic information
40#
16530'
1972'
3943'
DEPTH SET (MD)
6877' / 3943'
PACKER SET (MD/TVD)
129.5#
47#
114'
2522' 7075'
Gas-Oil Ratio:Choke Size:Water-Bbl:
PRODUCTION TEST
*Pre-Produced, converted to Injector 8/29/2022*
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" Drilled Liner 7/26/2022
***Please see Schematic for Detail***
Sr Res EngSr Pet GeoSr Pet Eng
Oil-Bbl: Water-Bbl:
ADL 025514 & 388235
16-004
2262' / 1850'
N/AN/A
None
16530' / 4044'
Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment
RECEIVED by James Brooks at 12:08 pm, 9/6/2022
Completed
7/29/2022
JSB
RBDMS JSB 101122
GMGR12NOV2022DSR-10/12/22
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
28' 28'
2290' 1878'
Top of Productive Interval 6970' 3949'
1437' 1338'
2381' 1913'
5033' 3227'
6117' 3767'
6970' 3949'
SB OA 6970' 3949'
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:
FORMATION TESTS
Permafrost - Top
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram
with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical
reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted.
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis,
paleontological report, production or well test results, per 20 AAC 25.070.
If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form,
if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071.
Authorized Name: Monty Myers
Authorized Title: Drilling Manager
Schrader Bluff OA
Permafrost - Base
29. GEOLOGIC MARKERS (List all formations and markers encountered):
Yes No
Well tested? Yes No
28. CORE DATA
If yes, list intervals and formations tested, briefly summarizing test results.
Attach separate pages to this form, if needed, and submit detailed test
information, including reports, per 20 AAC 25.071.
NAME
Schrader Bluff NA
SV5
SV1
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
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).
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.
Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment
9.6.2022
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: 2022.09.06 10:46:07 -08'00'
Monty M
Myers
CASING AND LEAK-OFF FRACTURE TESTS
Well Name:MPU M-29 Date:7/17/2022
Csg Size/Wt/Grade:9.625"40# x 47#, L-80 Supervisor:Yessak/Vanderpool
Csg Setting Depth:7075 TMD 3953 TVD
Mud Weight:9.2 ppg LOT / FIT Press =576 psi
.
LOT / FIT =12.00 Hole Depth =7104 md
Fluid Pumped=1.0 Bbls Volume Back =0.9 bbls
Estimated Pump Output:0.101 Barrels/Stroke
LOT / FIT DATA CASING TEST DATA
Enter Strokes Enter Pressure Enter Strokes Enter Pressure
Here Here Here Here
->00 ->00
->1 125 ->266
->2 179 ->6212
->3 221 ->10 408
->4 266 ->14 637
->5 336 ->18 809
->6 386 ->20 889
->7 432 ->24 1058
->8 493 ->28 1310
->9 543 ->32 1450
->10 573 ->36 1653
->11 ->40 1873
->12 ->44 2082
->13 ->54 2607
Enter Holding Enter Holding Enter Holding Enter Holding
Time Here Pressure Here Time Here Pressure Here
->0 576 ->0 2607
->1 555 ->5 2601
->2 552 ->10 2597
->3 550 ->15 2593
->4 548 ->20 2591
->5 547 ->25 2591
->6 546 ->26 2590
->7 545 ->27 2589
->8 544 ->28 2589
->9 543 ->29 2589
->10 542 ->30 2589
->11 541 ->
->12 540 ->
->13 539 ->
->14 539
->15 538
->
0
1
2
3
4
5
6
7
8
9 10
0
2
6
10
14
18
20
24
28
32
36
40
44
54
0
100
200
300
400
500
600
700
800
900
1000
1100
1200
1300
1400
1500
1600
1700
1800
1900
2000
2100
2200
2300
2400
2500
2600
2700
2800
2900
3000
0 102030405060
Pr
e
s
s
u
r
e
(
p
s
i
)
Strokes (# of)
LOT / FIT DATA CASING TEST DATA
Pr
e
s
s
u
r
e
(
p
s
i
)
576555552550548547546545544543542541540539539538
2607 2601 2597 2593 2591 259125902589258925892589
0
100
200
300
400
500
600
700
800
900
1000
1100
1200
1300
1400
1500
1600
1700
1800
1900
2000
2100
2200
2300
2400
2500
2600
2700
2800
2900
3000
0 5 10 15 20 25 30 35
Pr
e
s
s
u
r
e
(p
s
i
)
Time (Minutes)
LOT / FIT DATA CASING TEST DATA
_____________________________________________________________________________________
Revised By: JNL 8/1/2022
SCHEMATIC
Milne Point Unit
Well: MPU M-29
Last Completed: 7/29/2022
PTD: 222-072
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 2,522’ 0.0732
9-5/8" Surface 40 / L-80 / TXP 8.679” 2,522’ 7,075’ 0.0758
4-1/2” Liner solid/slotted 13.5 / L-80 / Hyd 625 3.920” 6,877’ 16,530’ 0.0149
TUBING DETAIL
3-1/2" Tubing 9.3 / L-80 / EUE 8RD 2.867” Surface 6,882’ 0.0087
OPEN HOLE / CEMENT DETAIL
42” 14 yds Concrete
12-1/4"Stg 1 –Lead 516 sx / Tail 400 sx
Stg 2 –Lead 856 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 FMC 11” 5K x sliplock bottom w/ (2) 2-1/16” 5K outs
GENERAL WELL INFO
API#: 50-029-23719-00-00
Completion Date: 7/29/2022
WELL INCLINATION DETAIL
KOP @ 427’
90° Hole Angle = @ 7,073’ MD
TD =16,530’(MD) / TD =4,044’(TVD)
20”
Orig. KB Elev.:58.83’ / GL Elev.:24.7’
3-1/2”
6
2
9-5/8”
1
3
See
Drilled
Liner
Detail
7
PBTD = 16,528’(MD) / PBTD = 4,044’(TVD)
9-5/8” ‘ES’
Cementer @
2,539’
4-1/2”
4/5
JEWELRY DETAIL
No Top MD Item
ID
Upper Completion
1 5,900’ Sliding Sleeve 2.813” X profile, covered ports (opens down) 2.813”
2 5,955’ Zenith Gauge Carrier 2.992”
3 6,005’ XN Nipple, 2.813”, 2.75” No-Go 2.750”
4 6,871’ No Go Locater Sub (1.75’ off No-go) 6.170”
5 6,872’ Bullet Seals – TXP Top Box x Mule Shoe 6.170”
Lower Completion
6 6,877’ 9-5/8” SLZXP Liner Top Packer 6.200”
7 16,528’ Shoe
4-1/2” Drilled Liner
Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD)
1 7065’ 3953’ 7106’ 3954’
1 7189’ 3956’ 7230’ 3957’
1 7313’ 3959’ 7353’ 3960’
1 7436’ 3961’ 7477’ 3961’
1 7560’ 3962’ 7600’ 3962’
1 7682’ 3962’ 7723’ 3956’
1 7805’ 3962’ 7845’ 3962’
1 7928’ 3963’ 7969’ 3964’
1 8051’ 3967’ 8092’ 3969’
1 8173’ 3973’ 8214’ 3975’
1 8296’ 3979’ 8336’ 3981’
1 8419’ 3984’ 8460’ 3986’
1 8542’ 3990’ 8583’ 3992’
1 8664’ 3995’ 8705’ 3996’
1 8783’ 3996’ 8828’ 3996’
1 8910’ 3996’ 8951’ 3996’
1 9033’ 3997’ 9074’ 3998’
1 9156’ 3966’ 9194’ 3995’
1 9276’ 3994’ 9317’ 3995’
1 9400’ 3997’ 9440’ 3997’
1 9523’ 3997’ 9563’ 3996’
1 9644’ 3994’ 9684’ 3992’
1 9767’ 3989’ 9807’ 3987’
1 9890’ 3984’ 9930’ 3982’
1 10013’ 3978’ 10053’ 3977’
1 10136’ 3975’ 10175’ 3974’
1 10258’ 3975’ 10298’ 3975’
1 10381’ 3976’ 10420’ 3977’
1 10503’ 3978’ 10544’ 3978’
1 10626’ 3979’ 10667’ 3980’
1 10750’ 3981’ 10790’ 3982’
1 10870’ 3983’ 10911’ 3984’
1 10994’ 3985’ 11033’ 3985’
1 11115’ 3986’ 11156’ 3987’
1 11238’ 3990’ 11279’ 3992’
1 11360’ 3997’ 11400’ 3999’
1 11480’ 4002’ 11521’ 4003’
1 11604’ 4005’ 11644’ 4006’
1 11726’ 4009’ 11766’ 4010’
1 11849’ 4014’ 11888’ 4016’
Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD)
1 11970’ 4020’ 12011’ 4022’
1 12093’ 4026’ 12133’ 4027’
1 12213’ 4028’ 12253’ 4028’
1 12335’ 4027’ 12376’ 4025’
1 12458’ 4021’ 12498’ 4019’
1 12581’ 4014’ 12621’ 4011’
1 12702’ 4006’ 12743’ 4004’
1 12825’ 3999’ 12866’ 3998’
1 12949’ 3998’ 12989’ 3999’
1 13072’ 4002’ 13110’ 4002’
1 13193’ 4002’ 13231’ 4002’
1 13313’ 3998’ 13354’ 3996’
1 13434’ 3989’ 13475’ 3984’
1 13557’ 3976’ 13598’ 3972’
1 13681’ 3965’ 13722’ 3962’
1 13804’ 3956’ 13845’ 3953’
1 13927’ 3950’ 13968’ 3949’
1 14050’ 3947’ 14090’ 3947’
1 14173’ 3946’ 14214’ 3945’
1 14296’ 3944’ 14334’ 3943’
1 14415’ 3942’ 14455’ 3942’
1 14534’ 3942’ 14574’ 3942’
1 14656’ 3946’ 14697’ 3947’
1 14779’ 3950’ 14819’ 3952’
1 14902’ 3956’ 14942’ 3958’
1 15025’ 3961’ 15066’ 3962’
1 15148’ 3963’ 15189’ 3964’
1 15271’ 3967’ 15311’ 3968’
1 15392’ 3971’ 15433’ 3972’
1 15515’ 3972’ 15555’ 3973’
1 15638’ 3973’ 15678’ 3974’
1 15760’ 3975’ 15800’ 3976’
1 16002’ 3980’ 16043’ 3982’
1 16125’ 3989’ 16164’ 3994’
1 16247’ 4004’ 16287’ 4009’
1 16369’ 4021’ 16410’ 4027’
Activity Date Ops Summary
7/6/2022 24hr Notice for Diverter test submitted to AOGCC @ 20:33, 7/6/22. Prep to Jack up rig for move. Wait on R&P winch truck to move Rockwasher. Truck at A pad to
repair a hose. SimOps: Finish welding TopDrive rail, cross beam pad eye & prep for inspection. Move Rockwasher, Jack up rig and pull off M-28. Shuffle rig matts
around M-29 for rig footprint. Move and spot rig over M-29. Shim Rig level. Skid Rig Floor. Secure landings and walkways. Rig up steam & H2O to rig floor. Set 90'
mousehole. Spot support shacks, 5 star trailer. Set Rig matts for Rock Washer. Work on acceptance checklist.
7/7/2022 Spot rock washer and fuel trailer. Set cuttings box and build containment berm. Install surface riser on diverter. Orient diverter and tee. Install diverter line. C/O top
drive saver sub. Load BHA into the pipe shed. Adjust rock washer 3" away from rig. Totco calibrate gas detection and PVT sensors Sim-ops: Repair mud pump
suction valves. Replace sprocket on #2 conveyor. Wells group performing slickline work on M-28. Unable to access beaverslide & spot water tank until work
completed. On highline power at 09:00. AOGCC inspector Adam Earl waived witness of diverter test at 17:36. Perform Pre-Spud Derrick inspection. Load 330 bbls
Spud Mud to Pits. Rig Accepted @ 19:00. SimOps: Perform testing of rig H2S & LEL gas alarms, PVT and flow sensors - good. C/O Valves and seats on MP#1.
Clean and service rotary table. Mobilize scaffolding off rig floor. P/U and install Riser. Center Annular with turnbuckles. Perform diverter function and accumulator
test. Close annular on 5" drill pipe. Knife valve open 12 sec and annular close in 25 sec - passing. System pressure = 3000 psi. Psi after closure = 1825 psi. 200
psi attained in 42 seconds. Full pressure attained in 167 seconds. Nitrogen Bottles - 6 at 2025 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 bit and XO to Rig floor. Hold 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 35'.
7/8/2022 Tag at 113'. Fill lines & conductor w/ fresh water. Pressure test high pressure mud lines to 3500 PSI. Perform unannounced rig evacuation drill. Personnel arrived at
primary muster area in 2 min & roll call completed in 3.5 min - all accounted for. Review drill & discuss actual emergency procedures. Drill 12-1/4" surface hole from
114' to 219', 105' drilled, 30'/hr AROP. Begin with 350 GPM, 380 PSI, 40 RPM , 1K TQ, 5K WOB. Increase to 400 GPM, 500 PSI with no increase in ROP. 50K PU
/ 53K SO / 50K ROT. MW 8.8, vis 244 BROOH from 219' to 124' with 400 GPM, 500 PSI, 40 RPM, 1K TQ. Pull on elevators from 124'. Inspect bit - good, no
balling. M/U Gyro While Drilling and MWD directional, gamma and resistivity tools to 96'. P/U 1 NM flex collar to 127'. Test and initialize MWD tools. P/U 2 NM flex
collar to 186'. Perform shallow pulse test, 450 GPM, 1000 PSI. Drill 12-1/4" surface hole from 219' to 391' (391' TVD). Drilled 172' = 57.33'/hr AROP. 450 GPM,
860 psi, 40 RPM, 1-2K ft/lbs torque, WOB 5K, PU 71K, SO 72K, ROT 62K. MW = 9 ppg, Vis 240, ECD 9.54 ppg. Start 3° /100' build at 350' Drill 12-1/4" surface
hole from 391' to 806' (801' TVD). Drilled 415' = 69'/hr AROP. 450 GPM, 1200 psi, 40 RPM, 1-2K ft/lbs torque, WOB 5K, PU 80K, SO 82K, ROT 82K. MW = 9
ppg, Vis 164, ECD 9.73 ppg. Start 4°/100' build at 750' Drill 12-1/4" surface hole from 806' to 1390' (1302' TVD). Drilled 584' = 97'/hr AROP. 500 GPM, 1530 psi,
60 RPM, 3-6K ft/lbs torque, WOB 10K, PU 91K, SO 87K, ROT 90K. MW = 8.9 ppg, Vis 127 , ECD 9.8 ppg. Continue with 4°/100' BUR Swap to MWD surveys,
with last GWD survey @ 894.76’. Last survey at 1262.28’ MD / 1203.92' TVD, 38.11° inc, 118.56° azm, 7.25’ from plan, 6.42’ High and 3.38’ Left. Daily disposal to
G&I = 518 bbls Total disposal to G&I = 538 bbls. Daily water hauled from A-Pad Res = 705 bbls Total water hauled from A-Pad Res = 795 bbls. Daily fluid loss = 0
bbls Total fluid loss = 0 bbls. Daily metal recovered = 0 lbs Total metal recovered = 0 lbs.
7/9/2022 Drill 12-1/4" surface hole from 1,390' to 1,966', 576' drilled, 96'/hr AROP. 500 GPM, 1660 PSI, 60 RPM, 5K TQ, 10K WOB. 90K PU / 84K SO / 83K ROT. 9.15
MW, 300 Vis, 10.25 ECD. Drill 12-1/4" surface hole from 1966' to 2544' (2006' TVD). Drilled 578' = 96'/hr AROP. 450 GPM, 1480 psi, 60 RPM, 6K ft/lbs torque,
WOB 7K, PU 100K, SO 78K, ROT 88K. MW = 9.2 ppg, Vis 285, ECD 10.22 ppg. EOB @ 2300'. Start maintain ~67° tangent Directional build rates fell off when the
SV3 was entered at 1,695'. Lowered flow rate to 410 GPM at 1,981' to achieve directional needs. Increased to 450 GPM at 2,267'. Changed out #2 mud pump
charge pump while drilling with one pump at lower rates. Base of permafrost at 2,290' MD / 1,878' TVD Drill 12-1/4" surface hole from 2544' to 3126' (2206' TVD).
Drilled 582' = 97'/hr AROP. 500 GPM, 1810 psi, 80 RPM, 6K ft/lbs torque, WOB 4K, PU 105K, SO 77K, ROT 90K. MW = 9.2 ppg, Vis 181, ECD 10.34 ppg. Hi vis
sweep @ 2553’ back on time with a 10% increase. Drill 12-1/4" surface hole from 3126' to 3694' (2440' TVD). Drilled 568' = 95'/hr AROP. 550 GPM, 2090 psi, 80
RPM, 7-8K ft/lbs torque, WOB 5-7K, PU 112K, SO 82K, ROT 95K. MW = 9.2 ppg, Vis 121, ECD 10.25 ppg. Hi vis sweep @ 3503’ back on time with a 25%
increase in cuttings returns. Top of the Ugnu logged at 3032' MD / 2168' TVD. Last survey at 3546.12’ MD / 2374.59' TVD, 65.27° inc, 108.51° azm, 23.07’ from
plan, 22.33’ Low and 5.80’ Right. Daily disposal to G&I = 1787 bbls Total disposal to G&I = 2325 bbls. Daily water hauled from A-Pad Res = 1650 bbls Total water
hauled from A-Pad Res = 2445 bbls. Daily fluid loss = 0 bbls Total fluid loss = 0 bbls. Daily metal recovered = 0 lbs Total metal recovered = 0 lbs.
7/10/2022 Drill 12-1/4" surface hole from 3,694' to 4,231', 537' drilled, 89.5'/hr AROP. 550 GPM, 2230 PSI, 80 RPM, 8-12K TQ, 3K WOB. 140K PU / 85K SO / 107K ROT.
9.15 ppg MW, 127 vis, 9.99 ECD, max gas 102u. Drill 12-1/4" surface hole from 4231' to 4656' (3016' TVD). 425' drilled, 71'/hr AROP. 550 GPM, 2240 PSI, 80
RPM, 10-14K TQ, 10K WOB. 153K PU / 85K SO / 112K ROT. 9.0 ppg MW, 193 vis, 10.07 ECD, max gas 101u Hi vis sweep @ 4550' back on-time with 10%
increase. Began treating mud w/ ScreenKleen @ 4550' Drill 12-1/4" surface hole from 4656' to 5025' (3220' TVD). 369' drilled, 61.5'/hr AROP. 550 GPM, 2180
PSI, 80 RPM, 13-15K TQ, 3-10K WOB. 173K PU / 88K SO / 116K ROT. 9.1 ppg MW, 119 vis, 9.97 ECD, max gas 101u. Experiencing some difficulty getting
consistent weight to bit transfer while sliding through Ugnu coals. Continue with drop and left turn at 4° DLR to 5025’, then start building for landing while continue
with left turn, target 4°/100’ DLR. Drill 12-1/4" surface hole from 5025' to 5560' (3527' TVD). 535' drilled, 89'/hr AROP. 550 GPM, 2200 PSI, 80 RPM, 16-18K TQ,
3-10K WOB. 185K PU / 90K SO / 125K ROT. 9.3 ppg MW, 160 vis, 10.27 ECD, max gas 252u. Top of the Ugnu_LA3 logged at 5033' MD / 3226' TVD. Last survey
at 5449.20’ MD / 3464.38' TVD, 56.74° inc, 20.77° azm, 22.85’ from plan, 11.14’ High and 19.95’ Right. Daily disposal to G&I = 1093 bbls Total disposal to G&I =
3418 bbls. Daily water hauled from A-Pad Res = 1205 bbls Total water hauled from A-Pad Res = 3650 bbls. Daily fluid loss = 0 bbls Total fluid loss = 0 bbls. Daily
metal recovered = 0 lbs Total metal recovered = 0 lbs.
50-029-23719-00-00API #:
Well Name:
Field:
County/State:
MP M-29
Milne Point
Hilcorp Energy Company Composite Report
, Alaska
7/8/2022Spud Date:
7/11/2022 Drill 12-1/4" surface hole from 5,560' to 5,882' MD (3,674' TVD), 322' drilled, 53.67'/hr AROP. 550 GPM, 2150 PSI, 80 RPM, 14-19K TQ, 3-6K WOB. 200K PU /
83K SO / 120K ROT. 9.25 ppg MW, 99 vis, 10.2 ECD, 151u max gas. High vis sweep at 5,568' was not observed at the shakers. Ugnu MB at 5,520' MD / 3,502'
TVD. Performing 4°/100' build and left turn with 70'-85' slides. Halliburton delivered 400 sxs of 1st stage tail cement. Drill 12-1/4" surface hole from 5882' to 6340'
MD (3838' TVD), 458' drilled, 76.33'/hr AROP. 550 GPM, 2200 PSI, 80 RPM, 17K TQ, 5K WOB. 190K PU / 85K SO / 122K ROT. 9.3 ppg MW, 87 vis, 10.47 ECD,
529u max gas. 4°/100' build and left turn with 70'-85' slides. Drill 12-1/4" surface hole from 6340' to 6790' MD (3935' TVD), 450' drilled, 75’/hr AROP. 550 GPM,
2380 PSI, 80 RPM, 16-18K TQ, 13K WOB. 190K PU / 82K SO / 120K ROT. 9.4 ppg MW, 100 vis, 10.60 ECD, 403u max gas. 4°/100' build and left turn. High vis
sweep at 6622', on time , 30% increase. Drill 12-1/4" surface hole from 6790' to TD @ 7084' (3954' TVD) in the SB_OA1 sand. 550 GPM, 2350 psi, 80 RPM, 16-
18k Tq, WOB 7-13k, PU 190k, SO 82k, ROT 120k. MW 9.35 ppg, Vis = 64, ECD 10.60 ppg, Max Gas = 277u Obtain final survey, backream stand out to 7023' and
rack in Derrick. 80 RPM,15-18k Tq. 550 GPM, 2050 psi Pump 30 bbl hi vis sweep, 550 gpm, 2050 psi, 80 rpm, 15-18k torque, back on time with 10% increase.
Condition mud, mw 9.35 ppg in, 9.5 ppg out, vis 52 with YP @ 24 working pipe 94’. Wash to back to bottom, no fill. Top of the SB_OA1 logged at 6970' MD / 3949'
TVD. Last survey at 7031.24’ MD / 3952.43' TVD, 86.84° inc, 332.63° azm, 16.88’ from plan, 16.87’ High and 0.67’ Right. Daily disposal to G&I = 922 bbls Total
disposal to G&I = 4340 bbls. Daily water hauled from A-Pad Res = 835 bbls Total water hauled from A-Pad Res = 4485 bbls. Daily fluid loss = 0 bbls Total fluid
loss = 0 bbls. Daily metal recovered = 0 lbs Total metal recovered = 0 lbs.
7/12/2022 Downlink and place gyro in outrun survey mode. Perform flow check, wellbore static. BROOH from 7,084' to 5,787' with 550 GPM, 2050 PSI, 80 RPM, 16-20K TQ.
205K PU / 83K SO / 125K ROT. Max gas 101u. Utilize 5-10 min per stand pulling speed, slowing through tight spots and slide intervals when pressure or torque
spikes observed. BROOH from 5787' to 4046' pulling 5-10 minutes/stand slowing as needed to clean up slides intervals & tight spots. 550 GPM - 1640 PSI, 80
RPM, 5-12K ft/lbs torque, max gas units =76. PU = 140K, SO =80K, ROT = 110K BROOH from 4046' to 2354' pulling 5-10 minutes/stand slowing as needed to
clean up slides intervals & tight spots. 550 GPM - 1640 PSI, 80 RPM, 5-12K ft/lbs torque, max gas units =76. PU = 125K, SO =75K, ROT = 90K Pull stand slow
while CBU f/ 2354’ t/ 2267’. 550 GPM, 1540 psi, 80 RPM, 5-10k Tq. BROOH from 2267' to 745' pulling 5-10 min/std. Slow pulling speed from 2079’-1900’ as hole
unload sand. Circ 2x BU while backream last stand drillpipe. 475-550 GPM - 1640 PSI, 80 RPM, 5-12K ft/lbs torque, max gas units = 303u. PU = 80K, SO =80K,
ROT = 80K Daily disposal to G&I = 984 bbls Total disposal to G&I = 5324 bbls. Daily water hauled from A-Pad Res = 1140 bbls Total water hauled from A-Pad
Res = 5625 bbls. Daily fluid loss = 0 bbls Total fluid loss = 0 bbls. Daily metal recovered = 0 lbs Total metal recovered = 0 lbs.
7/13/2022 Flow check at 745' - static. Rack back HWDP and jars from 745'to 190'. L/D NMDC from 190' to 96'. Read MWD tools. L/D remainder of BHA, 12 1/4'' bit grade tri
cone = 1-1-WT-A-F-I-NO-TD, PDC grade= 1-2-CT-G-X-I-NO-TD. Excessive wear on top edge ILS stab blades and mtr stab blades. 2 .5 bbl losses TOOH. Clear
and clean the rig floor, load tools to the rig floor, RU volant tool and 9 5/8" handling equipment, ready FOSV and XO, hold PJSM with all parties involved. Monitor
well, 2 BPH loss rate. P/U and M/U 9-5/8" shoe track using Forum Lok 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 163'. Ensure float equipment operating correctly - good. RIH with 9-5/8", 40# casing from 163' to 1400' 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. Losses @ 1-2BPH.
90K PUW, 85K SOW Tight spot / ledge at 1400' MD. Set down 15k while attempt to work through 3x. Engage pump and rotary, stage up to 3.5 bpm - 100 psi. 5
RPM - 4k tq. Attempt to rotate through, set 15k dn - no success. Pull up and CBU, work string 30', staying 15' off tight spot. Lost Hi-Line Power to Rig @ 21:20 H2O
observed on SCR room floor, coming from Hi-Line breaker panel. Rig electrician called out to troubleshoot and verify safety of energizing system with Rig gens.
Remove all moisture from Hi-Line breaker box, control boards and surrounding area. Put 2 Rig gens on-line. Monitor Well visually from RT With Rig on Gen power,
establish circulation at 2.5 BPM - 100 psi. Set 5k down at 1400’, rotate 0.25-0.5turns and apply 5k dn wt. String work through tight spot after 3’ of turn and stack. No
differential increase or signs of packing off. Continue to RIH with 9-5/8”, 40# casing from 1400’ to 2690’ 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. Losses @ 4-8 BPH. 130K PUW, 90K SOW Circulate bottoms up
below the permafrost staging up to 6 BPM = 170 psi. Mw in 9.35, Vis 45. Mw out 9.5, Vis 83. Lost 22 bbls while circulating. Continue to RIH with 9-5/8”, 40# casing
from 2690’ to 3140’ 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. Cent installed as per tally.
Losses @ 6-8 BPH. 140K PUW, 90K SO. Total of 41 bbls loss while RIH with 9-5/8” casing. Daily disposal to G&I = 917 bbls Total disposal to G&I = 6241 bbls.
Daily water hauled from A-Pad Res = 750 bbls Total water hauled from A-Pad Res = 6375 bbls. Daily fluid loss = 14 bbls Total fluid loss = 14 bbls. Daily metal
recovered = 0 lbs Total metal recovered = 0 lbs.
7/14/2022 Continue RIH 30 FPM with 9-5/8”, 40# casing from 3140’ to 4514' @ jt #111. Torque to 21,000 ft/lbs with the Volant tool. Fill casing on the fly and top off every 10
joints. Cent installed as per tally. Losses @ 6-8 BPH. 225K PUW, 83K SO. MU the ES cementer w/ pup jts Top & Btm t/ 4553'. ForumLok top/bottom connections.
RIH 20-30 FPM with 9-5/8", 47# casing f/ 4553' to 7022' . Torque to 24,000 ft/lbs with the Volant tool. Fill casing on the fly, top off every 10 jts. Centralizers installed
as per tally. Losses @ 6-7 BPH Wash last 2 joints to 7075' on depth pumping 2 bpm, 450 psi. Verify pipe count. Remove air slips, bail extensions and elevators.
Total Losses running casing = 94.5 bbls. PU = 325K and SO = 90K. Stage pumps to 6 bpm, 240 psi, while working the string from 7075’ to 7045', set TD Tq @
20k, establish rotation @ 2 rpm and 20k TQ while working pipe. Condition the mud for cementing, Final 6 BPM = 190 psi with MW 9.4, YP = 13. Submit BOP test
notification to the AOGCC at 18:50 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 = 320 psi while holding PJSM. 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 53 bbls of 10 ppg tuned spacer with 4# red dye & 5# Pol-E-Flake in 1st 10 bbls, 4 BPM = 220 PSI. Drop bypass
plug. Mix and pump 12.0 ppg lead cement (Type I/II cement, 2.347ft^3/sk yield) ICP of 5.5 BPM = 435 psi. HES experience trouble getting full cmt delivery from silo
@ 140 bbls pumped. Pump at reduced rate – 1 BPM, 45 psi until no cmt available from silo with 217 bbls lead cmt pumped. Discuss with town Engineer, decision
made to swap to tail and continue with the 1st stg cmt job Mix & pump 82 bbls 15.8 ppg tail (Type I/II tail cement 1.156 ft^3/sk yield, 400 sks total) @ 4 BPM, 500
PSI. Rotate 2-3 RPM, 20K TQ & reciprocate 20'. Drop shutoff plug. HES pump 20 bbls water @ 7.5 BPM, 550 psi. Displace with 305.3 bbls (3023 strokes) 9.4 ppg
spud mud from rig at 7.5 BPM, 360 PSI. Displace with 80 bbls 9.4 ppg Tuned Spacer form HES at 5.5 BPM, 460 PSI, continue to displace with 114.2 bbls 9.4 ppg
mud from the rig at 6 BPM, 640 PSI ICP, slow to 3 BPM for last 17 bbls, FCP 600 PSI. Bump plug 1131 stks at 11 stks(1 bbl) early. CIP at 01:57 Pressure to 1,150
psi, hold 3 min, bleed off and check floats, good, Pressure to 2,250 psi shifting open ESC at 49 stks. Rotate and reciprocate entire job, 53 bbls total losses. Pump
through ES cementer at 2539' at 8 BPM -1,170 PSI ICP and 7 BPM - 500 PSI FCP. Trace Pol-E-Flake was observed at 750 stks. Tuned spacer back 25 bbls late,
dumped to rock washer. No red dye spacer or cement observed back to surface. Take returns back to the pits & continue to circ total 5 BU. Disconnect knife valve
from accumulator. Drain stack and flush with black water three times. Re-connect knife valve to the accumulator. Clean cement line valves. Continue to circulate
through the ES cementer at 2539' at 5 BPM , 240 psi. Daily disposal to G&I = 285 bbls Total disposal to G&I = 6526 bbls. Daily water hauled from A-Pad Res = 100
bbls Total water hauled from A-Pad Res = 6475 bbls. Daily fluid loss = 95 bbls Total fluid loss = 109 bbls. Daily metal recovered = 0 lbs Total metal recovered = 0
lbs.
7/15/2022 Continue to circulate through the ES cementer at 2539' at 5 BPM , 240 psi while prepping for the 2nd stage. Hold PJSM with all parties involved for 2nd stage,
break out volante tool, clean dies and re-dope cup, blow air thru cement line to ensure clear. pump 5 bbls water, test lines to 1000 psi and 4000 psi, good Pump 2nd
stage cement job: Mix & pump 60 bbls of 10.0 ppg Tuned Spacer w/ 4# red dye & 5# Pol-E-Flake in 1st 10 bbls at 4.2 BPM= 250 psi. Mix & pump 436 bbl of 10.7
ppg Arctic Cem lead cement (856 sxs at 2.883 ft^3/sk yield) at 6.5 BPM = 640 psi ICP / 850 psi FCP. See good cement at surface with 436 bbls lead pumped. Mix
& pump 56 bbls 15.8 ppg Premium G tail cement (270 sxs @ 1.17 ft^3/sk yield) at 4.2 BPM = 650 psi. Drop closing plug. Pump 20 bbls 8.34 ppg fresh water at 6.5
BPM = 420 psi. Displace with 9.4 ppg spud mud at 6 BPM = 420 psi ICP / 730 psi FCP. Slow to 3 BPM = 450 psi FCP for last 10 bbls Bumped plug 1624 stks, 2
bbls early. CIP at 12:25. 90 bbls of interface and 190 bbls of good 10.7 ppg cement returned. 100% returns during job. Pressure up and observe ES cementer shift
close at 1580 psi. Pressure up to 1800 psi and hold for 5 minutes. Bleed off and open the block valve to the casing (no flow). Disconnect the accumulator lines from
knife valve. Drain the cement from the stack into the cellar box. Flush the stack with black water 3 times. Jet flow line with black water. Power down the
accumulator and disconnect the lines from the diverter annular. L/D volante tool, offload mud f/ pits Shut down rig gens putting the rig in the dark, Rig electrician
install new upper high line breaker in SCR room, C/O 3 fuses and install circuit board, make checks, with Hilcorp electrician attempt to put the rig on high line
power. Electrician remove circuit board, Put rig back on gen power. RD and load out casing equipment, empty and cleaning pits, load out cement silos, ND diverter
tee, un-flange and PU stack. Simops: Electrician troubleshoot undercurrent circuit on hi line board, re-install same. Put rig on high line power @ 17:00 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= 21.39'. N/D riser and Mob riser and
surface annular & diverter Tee out of cellar. Welder dress the casing stump. WHR install the slip lock tubing head and T103 conn, packed with plastic, PT to
500/3800 psi for 5/10 min each (good test). Orient and test the tubing spool void to 500/5000 psi 5/10 min each (good test). SimOps: Clear rig floor of csg tools &
equip. Cleaning mud pits and C/O MP #2 liners & swabs. N/U adapter flange, spacer spool and BOP stack. Hook up kill line and annular hyd lines. Install turn
buckles. SimOps: Change out charge pump #2, continue cleaning mud pits. Change out UPR to 2-7/8" x 5" VBR. Daily disposal to G&I = 2052 bbls Total disposal
to G&I = 8578 bbls. Daily water hauled from A-Pad Res = 340 bbls Total water hauled from A-Pad Res = 8615 bbls. Daily fluid loss = 24 bbls Total fluid loss = 133
bbls. Daily metal recovered = 0 lbs Total metal recovered = 0 lbs.
7/16/2022 Finish C/O UPR to 2-7/8" x 5" VBR. Install the trip nipple, center up the stack, service the choke and mud cross valves. Simops: Finish cleaning pits. Pull 2 links
adjusting drag chain, welder install. 580 bbls new 8.8 ppg flow pro on location. R/U test equipment, install the test plug, flood stack and lines with fresh water,
perform shell test to 250/3000 psi, good. Simops: Spot and RU MPD shack and lines. 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, UPR with 4 1/2'' test. annular with 3-1/2” test joint, All tests performed w/ fresh water against test plug. Test
witness was waived by AOGCC inspector Lou Laubenstein on 7/15/22 at 18:04 hrs. Test: 1. Annular with 3-1/2” test joint, 5” TIW, choke valves 1, 12, 13, 14, kill
valve 20 (passed). 2. UPR with 3 1/2” test joint, choke valves 9, 11, HCR kill, 5" dart valve. (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. UPR with 4 1/2'' test joint (passed). 11.Blind rams, choke valve 3 (passed). 12. Manual adjustable
choke (passed). 13. Hydraulic super choke (passed) Accumulator drawdown test: System pressure = 3000 psi. Pressure after closure = 1775 psi. 200 psi attained
in 38 seconds. Full pressure attained in 172 seconds. 6 N2 Bottle average at 2025 psi. Test rig gas alarms R/D BOP testing equipment. Blow down the choke
manifold, kill lines and top drive. Pull the test plug. M/U the wear ring running tool. I28Install the wear ring (ID = 10.063"). Lay down the wear ring running tool. Install
90’ mouse hole. R/U 5" handling equipment & mobilize BHA components to the rig floor. M/U 8-1/2" cleanout BHA to 585': 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 585' to 2488'. Wash down from 2488' with 380 GPM – 540 PSI, 30 RPM - 4K Tq &
tag ES cementer at 2539' with 5K WOB. Drill ES cementer, dress 3x and pass through clean. 105K PU / 90K SO / 75K ROT. Clean up cement stringers to 2682' w/
375-500 GPM, 600-920 PSI, 40 RPM, 4-7K TQ, 3-12K WOB. TIH out of the Derrick from 2682' to 6868'. Wash down with 400 GPM, 1070 PSI and tag cement at
6924'. Circulate 2x bottoms up at 490 GPM = 1250 psi, 30 RPM = 18K TQ while reciprocating 60’. 210k PUW, 71k SOW, 125k ROT Daily disposal to G&I = 57
bbls Total disposal to G&I = 8635 bbls. Daily water hauled from A-Pad Res = 120 bbls Total water hauled from A-Pad Res = 6935 bbls. Daily fluid loss = 0 bbls
Total fluid loss = 133 bbls. Daily metal recovered = 0 lbs Total metal recovered = 0 lbs.
7/17/2022 Parked @ 6868', RU to test the 9 5/8'' casing, purge lines, shut in the UPR, pressure to 2600 psi for 30 charted minutes, good test, bleed off pressure, open UPR.
5.4 pumped, 5.4 bbls bled back Wash & ream from 6868' to 6924' at 450 GPM = 1180 psi, 40 RPM = 18K ft-lbs TQ, WOB = 6-8K. Drill cement and 9-5/8" shoe
track from 6924' to 7075'. All equipment on depth. Cleanout the rat hole from 7075' to 7084'. Ream through the BA and FC 3 times ea. Drill 20' of new formation
from 7084' to 7104' at 436 GPM = 950 psi, 40 RPM = 19K ft-lbs TQ, WOB = 10K. Ream through the shoe 3 times with/without pump/rotary. Rack back stand to
7055' Circulate and condition the mud. After 2 1/2 BU good 9.2 ppg in/out and well cleaned up at 450 GPM, 1160 psi, 40 RPM = 18K ft-lb torque reciprocating 90'.
RU testing equipment. Purge air from the choke/kill line and choke manifold. Perform FIT to 12.0 ppg EMW using existing 9.2 ppg MW and 576 psi applied at
surface. good test RD test equipment, blow down lines. Pumped 1 bbl and bled back .9 bbl. Flow check the well, static. Mix and pump dry job, blow down the top
drive. Simops, Quadco C/O weight indicator due to stuck needle for bit weight indicator. TOOH with cleanout assembly from 7055' to 587'. Observe the well for flow
(static). Lay down 15 jts, 5" HWDP and rack back jar stand from. Lay down motor and tricone bit. Bit grade: 1-1-WT-A-E-I-NO-BHA Clear and clean the rig floor.
Remove the master bushing and install the split bushings. 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 107'. Plug in and initialize MWD tools. Finish making up BHA #3. P/U 3x Non-Mag drill collars, HWDP and jars to
291'. TIH with 5" DP out of derrick to 2290' Shallow pulse test MWD and break-in Geo-Pilot seals, 550 GPM, 1300 PSI, 30-70 RPM, 4-5k Tq. Not receiving an INC
from the Geo-Pilot. Troubleshoot with mode switching and tool cycling. No Success with shallow test. Decision made to POOH and C/O tools. POOH on elevators
from 2290' to 310' Daily disposal to G&I = 342 bbls Total disposal to G&I = 8977 bbls. Daily water hauled from A-Pad Res = 155 bbls Total water hauled from A-
Pad Res = 7090 bbls. Daily fluid loss interval = 6 bbls Total fluid loss interval = 6 bbls. Daily metal recovered = 11 lbs Total metal recovered = 11 lbs.
7/18/2022 Rack back the HW and flex collars, Plug in and verify geo pilot is the only tool with an issue,, no gamma or ABI, MU 15' pup and rack MWD tools in derrick, B/O the
bit, C/O the geo pilot, MU bit and MWD tools. Plug in and download tools, With the 15' pup, jt MU TD and shallow test tools at 117' pumping 460 gpm, 870 psi,
good test, LD pup jt, MU the remaining BHA to 295' RIH with 5'' stands drill pipe from the derrick to 1820', fill pipe, shallow test tools, 450 gpm, 1000 psi, 40-70 rpm,
3 k torque, break in geo pilot seals, good, RIH to 2290', off NPT @ 11:30 Continue to RIH on elevators from 2290' to 6865' filling the pipe every 2000', single in with
3 joints drill pip to 6948' fill pipe, single in with 2 more jts to 6987', MU single and TD. PU 260K, SO 80K PJSM. Drain stack, pull MPD riser and install MPD RCD,
leak test same, good PJSM for displacing, wash and ream 3 singles to TD @ 7104' pumping 450 gpm, 1320 psi, 40 rpm, 19k torque Pump 30 bbl hi vis spacer,
Displace w/ 520 bbls 8.8 ppg flow pro mud @7 BPM, 650 psi. With mud out bit, P/U into 9 5/8'' casing rack back std, Cont displacing @ 7 BPM. Dump spud mud
returns to rock washer. Rot 30 rpm, Start 18k Tq, 11k Tq final. Shut down, close MPD and monitor psi, No increase. Hang blocks, slip and cut 73' drilling line, re-
calibrate block height. Service top drive. Install buoy in flowline and skirt up bell nipple to drip pan. Simops: clean pit 4 and under shakers. Continue monitor MPD
pressure – No build. Obtain SPRs. Wash/ream to bottom. 450 GPM, 30 RPM. 180k PUW, 95k SOW, 120k ROT Drill 8-1/2" lateral from 7104' to 7624' (3961'
TVD), 520' drilled, 80'/hr AROP. 550 GPM, 1620 PSI, 150 RPM, 13k Tq, 5-13k WOB. 8.85 MW 40 vis, 10.20 ECD, 1136u max gas. 155k PUW / 82k SOW / 114k
ROT. Backream 30' on connections. MPD full open while drilling and trap 100 PSI on connections. Drilled through Fault #1 @ 7204’ - 4’ throw DTW Last survey at
7551.59’ MD / 3961.78' TVD, 89.61° inc, 333.28° azm, 23.70' from plan, 12.60' High and 20.09’ left. We have drilled 6 concretions for a total thickness of 32’ (7.5%
of the lateral). Daily disposal to G&I = 821 bbls Total disposal to G&I = 9798 bbls. Daily water hauled from A-Pad Res = 485 bbls Total water hauled from A-Pad
Res = 7575 bbls. Daily fluid loss interval = 6 bbls Total fluid loss interval = 6 bbls. Daily metal recovered = 10 lbs Total metal recovered = 21 lbs.
7/19/2022 Drill 8-1/2" lateral from 7624' to 8277' (3980' TVD), 653' drilled, 108.8'/hr AROP. 450 GPM, 1250 PSI, 120 RPM, 14k Tq, 12-15k WOB. MW 8.8 ppg, vis 38, ECD
10.3 ppg, max gas 1009u. 149k PUW / 90k SOW / 115k ROT. Shakers blinding off at 8000', increase screen kleen to 1%. At 8100', control drill as needed. MPD
start holding 100 psi while drilling and trap 275 PSI on connections, Pump 30 bbl hi vis sweep @ 8100', back on time, 50% increase. Drill in the OA-1, at 8000'
undulate down, target 87 deg Drill 8-1/2" lateral from 8277' to 8861' (3995' TVD), 584' drilled, 97.3'/hr AROP. 550 GPM, 1760 PSI, 135 RPM, 14k Tq, 12-15k
WOB. MW 8.8 ppg, vis 38, ECD 10.3 ppg, max gas 1593u. 150k PUW / 88k SOW / 122k ROT. MPD holding 140 psi while drilling and trap 310 PSI on
connections Drill OA-2 from 8127' to 8256', drill in the OA-3 targeting 87 to 90 deg. Drill 8-1/2" lateral from 8861' to 9151' (3997' TVD), 290' drilled, 48’/hr AROP.
550 GPM, 1760 PSI, 135 RPM, 14k Tq, 12-15k WOB. MW 8.8 ppg, vis 38, ECD 10.46 ppg, max gas 1060u. 155k PUW / 83k SOW / 116k ROT. MPD holding 140
psi while drilling and trap 310 PSI on connections to target a 10.5 ppg ECD. Maintain the OA-3. Hi-Vis Sweep at 9055’, back on time w/ 10% increase. DD having
difficulty getting trajectory to turn left being hindered with and pushed right from concretions. Drill 8-1/2" lateral from 9151' to 9173' (3997' TVD), 22' drilled, 44’/hr
AROP. 550 GPM, 1690 PSI, 135 RPM, 14k Tq, 12k WOB. MW 8.8 ppg, vis 36, ECD 10.46 ppg, max gas 126u. 155k PUW / 78k SOW / 114k ROT. Experience
deflection off a concretion at 9142’ pushing assembly up and to the right. Micro dogleg >10° (14°) from 9142’ to 9162’. Attempt to ream out DL, 500 GPM - 1580
psi, 100 RPM -10k Tq. Work pipe f/ 9140' to 9162', achieve a 0.5° drop. Drill 8-1/2" lateral from 9151' to 9432' (4000' TVD), 281' drilled, 47’/hr AROP. 500 GPM,
1600 PSI, 80 RPM, 9k Tq, 6-8k WOB. MW 8.8 ppg, vis 38, ECD 10.50 ppg, max gas 377u. 150k PUW / 81k SOW / 115k ROT. MPD holding 140 psi while drilling
and trap 310 PSI on connections to target a 10.5 ppg ECD. Maintain the OA-3 Last survey at 9360.35’ MD / 3996.10' TVD, 88.29° inc, 335.75° azm, 68.28’ from
plan, 6.67 High and 67.95’ right. We have drilled 23 concretions for a total thickness of 224’ (10.1% of the lateral). Daily disposal to G&I = 904 bbls Total disposal
to G&I = 10702 bbls. Daily water hauled from A-Pad Res = 745 bbls Total water hauled from A-Pad Res = 8320 bbls. Daily fluid loss interval = 0 bbls Total fluid
loss interval = 6 bbls. Daily metal recovered = 18.5 lbs Total metal recovered = 39.5 lbs.
7/20/2022 Drill 8-1/2" lateral from 9,432' to 9,905' (3,982' TVD), 473' drilled, 78.83’/hr AROP. 548 GPM, 1,840 PSI, 130 RPM, 10k Tq, 9-10k WOB. MW 8.8 ppg, vis 36, ECD
10.6 ppg, max gas 427u. 155k PUW / 81k SOW / 115k ROT. MPD holding 140 psi while drilling and trap 310 PSI on connections. Maintain the OA-3, at 9715',
undulate up targeting 92.5 deg. Drill 8-1/2" lateral from 9,905' to 10,461' (3,982' TVD), 556' drilled, 92.67’/hr AROP. 550 GPM = 1,840 psi, 135 RPM = 8-10K ft-lbs
torque, WOB = 8-10K, PU = 158K, SO = 73K, ROT = 116K. MW = 8.8 ppg, Vis = 38, ECD = 10.4 ppg, max gas units = 806. Pump 30 bbl hi vis sweep @ 10095',
back on time, 50% increase. Target 92.5 deg, drill OA-2 from 9825' to 9983', drill in the OA-1, target 90 deg. Drill 8-1/2" lateral from 10,461' to 11,030' (3,982'
TVD), 569' drilled, 94.83’/hr AROP. 550 GPM = 2,000 psi, 150 RPM = 9-10K ft-lbs torque, WOB = 7-10K, PU = 160K, SO = 70K, ROT = 110K. MW = 8.9 ppg, Vis
= 40, ECD = 10.76 ppg, max gas units = 1,035 MPD holding 130-160 psi while drilling and 320 psi on connections to maintain 10.5 ppg ECD. Drill 8-1/2" lateral
from 11,030' to 11,621' (4,005' TVD), 591' drilled, 98.5’/hr AROP. 550 GPM = 2,020 psi, 135 RPM = 10-11K ft-lbs torque, WOB = 14-15K, PU = 165K, SO = 72K,
ROT = 114K. MW = 8.9 ppg, Vis = 37, ECD = 10.71 ppg, max gas units = 1,288 MPD holding 130-160 psi while drilling and 320 psi on connections to maintain
10.5 ppg ECD. Pumped hi-vis sweep at 11,148', back on time with 50% increase. Perform planned undulation from the OA-1 to the OA-3 at 11,142'. Exited the OA-
1 at 11,210’ and entered the OA-3 at 11,377’. Drilled 46 concretions for a total thickness of 365' (8.2% of the lateral). Last survey at 11,359.29’ MD / 4,849.68' TVD,
86.79° INC, 330.11° AZM, Distance from WP07a = 10.56’, 7.93’ high, 6.97’ left Daily disposal to G&I = 726 bbls Total disposal to G&I = 11,428 bbls. Daily water
hauled from A-Pad Res = 465 bbls Total water hauled from A-Pad Res = 8,785 bbls. Daily fluid loss = 0 bbls Total fluid loss = 6 bbls. Daily metal recovered = 11
lbs Total metal recovered = 50.5 lbs.
7/21/2022 Drill 8-1/2" lateral from 11,621' to 12,126' (4,032' TVD). Drilled 505' = 91.82'/hr AROP. 553 GPM = 2,070 psi, 135 RPM = 12-13K ft-lbs torque, WOB = 3-9K, PU =
175K, SO = 50K, ROT = 115K. MW = 8.8 ppg, Vis = 39, ECD = 10.7 ppg, max gas units = 704. MPD fully open while drilling and holding 320 psi on connections to
maintain 10.6-10.7 ppg ECD. Pump 30 bbl hi vis sweep @ 12,100', back on time with 10% increase. Drill in the OA-3, deflected off concretion causing 13.97 deg
micro dog leg from 12,100' to 12,118', Ream dog leg from 12,095' to 12,125' for total of 4 times reducing the DL to 9.96 deg, at 553 gpm, 2,070 psi, 100 rpm, 11-
12k torque. Drill 8-1/2" lateral from 12,126' to 12,559' (4,011' TVD). Drilled 433' = 86.6'/hr AROP. 550 GPM = 2,060 psi, 135 RPM = 12K ft-lbs torque, WOB = 15K,
PU = 170K, SO = 65K, ROT = 115K. MW = 8.9 ppg, Vis = 38, ECD = 10.73 ppg, max gas units = 882 Drill in the OA-3 targeting 91° until 12,205’ when we entered
the OA-4. Began undulation up targeting 93.5° and exited the OA-4 at 12,390’. Continue undulating up through the OA-3. Drill 8-1/2" lateral from 12,559' to
12,944' (4,000' TVD). Drilled 385' = 64.17'/hr AROP. 550 GPM = 2,140 psi, 135 RPM = 13K ft-lbs torque, WOB = 10K, PU = 175K, SO = 40K, ROT = 116K. MW =
8.9 ppg, Vis = 37, ECD = 10.7 ppg, max gas units = 958 MPD fully open while drilling and holding 320 psi on connections to maintain 10.6-10.7 ppg ECD. Exited
the OA-3 at 12,700' and entered the OA-1 at 12,814'. Drill 8-1/2" lateral from 12,944' to 13,595' (3,970' TVD). Drilled 651' = 108.5'/hr AROP. 550 GPM = 2,270 psi,
135 RPM = 16K ft-lbs torque, WOB = 14K, PU = 175K, SO = 40K, ROT = 110K. MW = 9.0 ppg, Vis = 36, ECD = 11.2 ppg, max gas units = 984 MPD fully open
while drilling and holding 320 psi on connections to maintain 10.6-10.7 ppg ECD. Pumped hi-vis sweep at 13,140', back on time with 50% increase. Drill in the OA-
1 targeting 91° until 13,139'. Began building inclination, targeting 96° in anticipation of fault #2. Exited the top of the OA-1 at 13,410' entering the NF clays.
Continue drilling up at 96°. Drilled 68 concretions for a total thickness of 504’ (7.9% of the lateral). Last survey at 13,450.05’ MD / 3,987.14' TVD, 95.95° INC,
337.69° AZM, Distance from WP07a = 31.24’, 31.22’ low & 1.19’ right. Daily disposal to G&I = 679 bbls Total disposal to G&I = 12,107 bbls. Daily water hauled
from A-Pad Res = 455 bbls Total water hauled from A-Pad Res = 9,240 bbls. Daily fluid loss = 0 bbls Total fluid loss = 6 bbls. Daily metal recovered = 8.3 lbs
Total metal recovered = 58.8 lbs.
7/22/2022 Drill 8-1/2" lateral from 13,595' to 13,600', slow drilling, seeing erratic torque and wanting to stall. 550 GPM = 2,270 psi, 135 RPM = 16K ft-lbs torque, WOB = 14K,
PU = 175K, SO = 40K, ROT = 110K. MW = 9.0 ppg, Vis = 36, ECD = 11.2 ppg Logged fault # 2 at 13,587' MD (3,979' TVD) with 52' throw DTE from the NF clays
to the upper OA-4. MPD choke fully open drilling and holding 330 psi on connections. Back ream up to wipe the hole seeing 400 psi pressure increase and 24k
torque from 13,528' to 13,518', ream 2 times at 550 gpm, 2270-2570 psi, 135 rpm, 16-24k torque cleaning up same. Drill 8-1/2" lateral from 13,600' to 13,936'
(3,947' TVD). Drilled 363' = 80.66'/hr AROP. 553 GPM = 2,270 psi, 120 RPM = 16K ft-lbs torque, WOB = 11-16K, PU = 173K, SO = 40K, ROT = 108K. MW = 9
ppg, Vis = 39, ECD = 11.2 ppg, max gas units = 984 MPD choke fully open drilling and holding 330 psi on connections. Exited the OA-4 top and entered the OA-3
at 13,630'. Drill up through the OA-3 to the bottom of the OA-2 at 13,802'. Drill 8-1/2" lateral from 13,936' to 14,570' (3,942' TVD). Drilled 634' = 105.67'/hr AROP.
550 GPM = 2,300 psi, 120 RPM = 15K ft-lbs torque, WOB = 10K, PU = 185K, SO = 40K, ROT = 112K. MW = 9 ppg, Vis = 38, ECD = 11.3 ppg, max gas units =
1,238 MPD choke fully open drilling and holding 330 psi on connections. Pump 30 bbl hi-vis sweep at 14,096', back 200 strokes late with 20% increase. Exited the
OA-2 and entered the OA-1 at 13,949', target 91° in anticipation of fault at 14,250' but did not see the fault. At 14,532’ began undulation down in the OA-1 targeting
88° in anticipation of predicated fault at 15,300'. Drill 8-1/2" lateral from 14,570' to 15,140' (3,960' TVD). Drilled 570' = 95'/hr AROP. 550 GPM = 2,350 psi, 135
RPM = 15K ft-lbs torque, WOB = 7K, PU = 180K, SO = 40K, ROT = 115K. MW = 8.9 ppg, Vis = 38, ECD = 11.1 ppg, max gas units = 1,339 MPD choke fully open
drilling and holding 330 psi on connections. Performed dump and dilute with 490 bbls of new mud. Exited the OA-1 at 14,918' and entered the OA-3 at 14,978' Drill
8-1/2" lateral from 15,140' to 15,522' (3,972' TVD). Drilled 382' = 63.67'/hr AROP. 500 GPM = 1,980 psi, 135 RPM = 15K ft-lbs torque, WOB = 5-10K, PU = 178K,
SO = 40K, ROT = 111K. MW = 8.9 ppg, Vis = 39, ECD = 11.0 ppg, max gas units = 1,035 MPD choke fully open drilling and holding 330 psi on connections.
Pump a hi-vis sweep at 15,140' back 200 strokes late with 10% increase. Did not see predicted fault at 15,300'. Drilled 89 concretions for a total thickness of 601’
(7.1% of the lateral). Last survey at 14,450.48’ MD / 3,972.07' TVD, 89.26° INC, 333.81° AZM, Distance from WP07a = 43.78’, 27.46’ low & 34.10’ right. Daily
disposal to G&I = 1,444 bbls Total disposal to G&I = 13,551 bbls. Daily water hauled from A-Pad Res = 435 bbls Total water hauled from A-Pad Res = 9,675 bbls.
Daily fluid loss = 0 bbls Total fluid loss = 6 bbls. Daily metal recovered = 8 lbs Total metal recovered = 66.8 lbs.
7/23/2022 Drill 8-1/2" lateral from 15,522' to 16,250' (4007' TVD). Drilled 728' = 121.33'/hr AROP. 527 GPM = 2,360 psi, 135 RPM = 18K ft-lbs torque, WOB = 14-15K, PU =
181K, SO = 40K, ROT = 108K. MW = 8.9 ppg, Vis = 39, ECD = 11.7 ppg, max gas units = 1,441 Logged fault #3 at 15,540' with 27' DTW throw moving from lower
OA-3 to upper OA-1. Logged fault #4 at 15,938' with 32' DTW throw moving from the low OA-1 to NF clay. Entered the OA-1 at 16,204'. MPD choke fully open
drilling and holding 330 psi on connections. Drill 8-1/2" lateral from 16,250' to TD at 16,530' (4,043' TVD). Drilled 280' = 56'/hr AROP. 527 GPM = 2,430 psi, 120
RPM = 20K ft-lbs torque, WOB = 10K, PU = 215K, SO = 40K, ROT = 112K. MW = 8.9 ppg, Vis = 42, ECD = 11.56 ppg, max gas units = 781 Exited the OA-1 at
16,303’ and entered the OA-3 at 16,345’. Exited the OA sand at 16,458’ and geologist called TD at 16,530’. MPD choke fully open drilling and holding 330 psi on
connections. Obtain final survey at 16,530’ MD / 4,043.55' TVD, 81.86° INC, 330.99° AZM, Distance from WP07a = 124’, 123’ low & 21’ right (the well was drilled
beyond the plan so distance to plan is not representative). Drilled 95 concretions for a total thickness of 662’ (7.0% of the lateral). Pump hi-vis sweep back 200
strokes late with 0% increase. Circulate a total of 4.5 BU at 530 GPM = 2,410 psi, 120 RPM = 16K ft-lbs TQ. Racking back one stand each BU to 16,200'. SimOps:
Clean pit and prep for displacement to viscosified brine. Wash and ream from 16,200' to 16,530'. at 430 GPM = 2,050 psi, 80 RPM = 15K ft-lbs TQ. PJSM.
Displace the wellbore to 8.45 ppg viscosified brine: 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-TQ) at 260 - 310 GPM = 960-1030 psi,
80 RPM = 18K ft-lbs TQ, rotating and reciprocating 95'. Shut down when clean 8.45 ppg brine to surface. Monitor pressure with MPD choke closed. 5 min built to
85 psi, bleed off, 5 min built to 71 psi, bleed off, 5 min built to 64 psi, bleed off and final 5 min built to 61 psi = 8.8 ppg EMW. With 75 psi trip margin KWF = 9.2
ppg. SimOps: Finish cleaning pit #3 and line up to circulate. Load brine into pits 3 & 4. Obtain new SPR's. Place GWD tool in record mode. Obtain survey to
confirm command. BROOH from 16,530' to 15,895,' at 5-10 min/stand slowing as needed. 500 GPM = 1,480 psi, 120 RPM = 16K ft-lbs TQ, max gas units = 50. PU
= 215K, SO = 40K & ROT = 124K. MPD chokes open while BROOH & holding 160 psi on connections. LD DP in the mouse hole. Loss rate = 30 BPH (dynamic)
Daily disposal to G&I = 1,269 bbls Total disposal to G&I = 14,820 bbls. Daily water hauled from A-Pad Res = 575 bbls Total water hauled from A-Pad Res =
10,250 bbls. Daily fluid loss = 0 bbls Total fluid loss = 6 bbls. Daily metal recovered = 8.2 lbs Total metal recovered = 75 lbs.
7/24/2022 BROOH from 15,895' to 13,045,' at 5-10 min/stand slowing as needed. 500 GPM = 1,480 psi, 120 RPM = 16K ft-lbs TQ, max gas units = 176. PU = 200K, SO =
80K & ROT = 124K. MPD chokes open while BROOH & holding 160 psi on connections. LD DP in the mouse hole. Loss rate = 15-20 BPH (dynamic). BROOH
from 13,045' to 10,700' at 5-10 min/stand slowing as needed. 500 GPM = 1,420 psi, 120 RPM = 13K ft-lbs TQ, max gas units = 881. PU = 178K, SO = 92K & ROT
= 120K. MPD chokes open while BROOH & holding 160 psi on connections. LD DP in the mouse hole. Loss rate = 15-20 BPH (dynamic) BROOH from 10,700' to
7,907' at 5-10 min/stand slowing as needed. 500 GPM = 1,360 psi, 120 RPM = 8K ft-lbs TQ, max gas units = 151. PU = 160K, SO = 95K & ROT = 120K. MPD
chokes open while BROOH & holding 160 psi on connections. LD DP in the mouse hole. Loss rate = 10-20 BPH (dynamic) BROOH from 7,907' to 7,367' at 5-10
min/stand slowing as needed. 500 GPM = 1,280 psi, 120 RPM = 7K ft-lbs TQ, max gas units = 352. PU = 151K, SO = 95K & ROT = 125K. MPD chokes open while
BROOH & holding 160 psi on connections. LD DP in the mouse hole. Loss rate = 9 BPH (dynamic) TOOH with no rotary from 7,367' to 7,052' at 500 GPM = 1,280
psi. Observed no overpull with 10K drag pulling BHA into the shoe Pump hi-vis sweep and circulate the well clean at 500 GPM = 1,280 psi, 80 RPM = 4-7K ft-lbs
TQ reciprocating 90'. Back on time with no increase. Continue to circulate 2 BU. Loss rate = 6 BPH. SimOps: Mobilize MPD riser to the rig floor. Monitor pressure
with MPD choke closed with 8.8 ppg MW. 5 min built to 41 psi, bleed off, 5 min built to 37 psi, bleed off, 5 min built to 33 psi, bleed off and final 5 min built to 30 psi
= 9.0 ppg EMW. KWF = 9.2 ppg. Weight up the active pits to 9.0 ppg. Circulate 9.0 ppg while weighting up the returns on the fly to 9.0 ppg at 300 GPM = 580 psi,
80 RPM = 4-7K ft-lb TQ reciprocating 90'. Good 9.0 ppg in/out. Continue to circulate weighting up to 9.2 ppg. Daily disposal to G&I = 1,592 bbls Total disposal to
G&I = 16,412 bbls. Daily water hauled from A-Pad Res = 185 bbls Total water hauled from A-Pad Res = 10,435 bbls. Daily fluid loss = 215 bbls Total fluid loss =
221 bbls. Daily metal recovered = 8.5 lbs Total metal recovered = 83.5 lbs.
7/25/2022 Continue to circulate weighting up to 9.2 ppg at 300 GPM = 580 psi, 80 rpm = 5-7K ft-lbs TQ, reciprocating 90'. Good 9.2 ppg in/out. Pumps off. Monitor MPD for
pressure build, 5 min ea, shut in, build to 25 psi, bleed off, build to 23 psi, bleed off, shut in again, 18 psi line pressure only, no pressure build, open bleeder at
RCD head, monitor well, very slight stream going static in 10 min, well is dead PJSM. Remove MPD RCD and install trip nipple. Changeout and 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. Pump Dry job. Drop 2.45" drift
on wire. Blow down the top drive. TOOH from 7,052' to 4,557' racking back stands of 5'' DP. Continue TOOH racking back stands of 5'' DP from 4,557' to 295' at the
HWDP. Observe the well for flow well on slight losses. Hold PJSM, Recover drift on wire, LD jar stand, float subs & NMFCs. Download MWD data. LD remaining
BHA. 8 1/2" bit grade= 3-3-BT-A-X-I-WT-TD. ILS on ADR- 1/3 of the tiles worn off of the middle of blades, IBS stab- worn on leading edge of all 4 blades. 43 bbl
losses TOOH from the shoe, Clear and clean the rig floor. Blow down the choke manifold. Static loss rate = 3 BPH. Pull split bushings and install master bushing.
Mobilize handling equipment and power tongs to the rig floor. RU to run 4-1/2" liner. MU crossover on the bottom of the FOSV. Mobilize 236 centralizers to the rig
floor. PJSM. Static loss rate = 3 BPH PU, MU & RIH round nose float shoe/WIV with crossover joint on 4-1/2", 13.5#, L-80, H625 pre-drilled liner per tally installing a
centralizer on every joint to 3,092'. Optimum TQ = 9,600 ft-lbs. PU = 66K & SO = 63K. Loss rate = 3 BPH Continue to RIH with 4-1/2", 13.5#, L-80, H625 pre-
drilled liner per tally installing a centralizer on every joint from 3,092' to 9,623'. Optimum TQ = 9,600 ft-lbs. PU = 115K & SO = 75K. At the shoe PU = 100K & SO =
78K. Loss rate = 3 BPH. Daily disposal to G&I = 52 bbls Total disposal to G&I = 15,200 bbls. Daily water hauled from A-Pad Res = 50 bbls Total water hauled from
A-Pad Res = 10,485 bbls. Daily fluid loss = 48 bbls Total fluid loss = 269 bbls. Daily metal recovered = 4 lbs Total metal recovered = 87.5 lbs.
7/26/2022 At 9,623', verify liner count. Change elevators to 5" DP. PU Baker 7" x 9-5/8" SLZXP liner top packer and MU ITTS to the bottom of the running tool. MU SLZXP to
the liner. Verify 9 pins on pusher tool for 3,254 psi, 4 pin on set tool for 2,097 psi, 6 pins on packer for 44,100K. RIH to 9,662' RIH 1 stand of 5" DP to 9,752'.
Pump 10 bbls at 2 BPM = 110 psi to ensure clear flow path. Set TD torque @ 8K, Obtain parameters : PU = 115K, SO = 75K & ROT = 85K at 10/20 RPM= 7K ft-
lbs TQ. 26 BBL losses Running liner. RIH with 4-1/2" liner conveyed on 47 stands drifted 5" drill pipe from 9,752' to 14,136' at 30 FPM. Single in the hole with 5''
HWDP from 14,136' to 14,515'. Loss rate continues at 3 BPH. Submit 24 hr notification to AOGCC for pre injection MIT. Continue to single in the hole with 5''
HWDP from 14,515' to 16,481' for a total of 76 joints. MU 2 joints of 5" DP, tag TD 2 times with 10K at 16,530'. Set down 20K at 15,895' just before fault #4, work
pipe 3-4 times 20' working thru same. PU = 235K, SO = 120K. Losses RIH with DP = 20.4 bbls. PU to 16,509', LD 1 joint DP and MU 20' pup joint. Set liner on
depth. RU to circulate with cement line. RU the test pump. PT lines to 3,500 psi (good test). Break circulation with 10 bbls at 3 BPM = 380 psi. Drop 1” phenolic
ball. Set string on depth, in tension with 220K PU. Pump ball down with 30 bbl hi-vis sweep. Ball on seat at 905 stks. Pressure up to 2,700 psi, observed shear at
2,120 psi. Hold pressure for 3 min. Slack off to 60K. Pressure up with rig pump, shear ball seat at 3,540 psi. PU to confirm release with 182K PUW. Top of SLZXP
at 6,876'. RU testing equipment. Purge air from lines. Close UPR. PT the IA/LTP to 1,500 psi for 10 minutes charted (good test). Open UPR & RD test
equipment. Pull the running tool out of the SLZXP while circulating at 3 BPM = 380 psi. Continue to circulate a total of 1.5 BU at 400 GPM = 1,200 psi with
reciprocating 30' (no rotation). RD circulating equipment. LD 1 joint of DP & 1 joint HWDP to 6,831'. Blow down the top drive, choke/kill line & cement line. PJSM.
Slip and cut 86' (13 wraps) of drilling line. Service the top drive & draw works. Calibrate the blocks. Inspect saver sub. Static loss rate = 2 BPH Pump 25 bbl dry
job. Blow down the top drive. POOH laying down 5" HWDP from 6,831' to 4,517'. Loss rate = 4 BPH TIH with 5" DP in the derrick from 4,517' to 6,770'. POOH
laying down 5" DP from 6,770' to 3,627'. Loss rate = 4 BPH Daily disposal to G&I = 285 bbls Total disposal to G&I = 16,754 bbls. Daily water hauled from A-Pad
Res = 125 bbls Total water hauled from A-Pad Res = 10,610 bbls. Daily fluid loss = 62 bbls Total fluid loss = 331 bbls. Daily metal recovered = 2.5 lbs Total metal
recovered = 90 lbs.
Activity Date Ops Summary
7/27/2022 POOH laying down 5" drill pipe from 3,627' to 46'. LD Baker liner running tool. 2 BPH loss rate.,RD 5" handling equipment and clear the rig floor. Mobilize upper
completion tools and equipment to the rig floor. Pull the wear ring. MU hanger on 5" drill pipe landing joint and perform dummy run - good. RU Centrilift spooler &
sheave. RU Doyon casing tongs, elevators and slips. 2.5 BPH loss rate. PJSM. PU Baker 7" bullet seal assembly to 18'. Run 3-1/2", 9.3#, L-80, EUE 8rd tubing
from 18' to 866'. Torque all connections to 2,800 ft/lbs with Doyon double stack tongs. 3 BPH loss rate.,PU XN nipple (2.75" no-go), tubing joint, Centrilift Zenith
gauge assy, tubing joint and Halliburton sliding sleeve assy to 992'. Continue to run tubing and installing Cannon clamps as per tally from 992' to 1,422'. PU = 55K
& SO = 55K. Torque all connections to 2,800 ft/lbs with Doyon double stack tongs. 3 BPH loss rate.,Centrilift hydraulic Cannon clamp crimper failed. Source
replacement from A-pad shop.,Continue to RIH with completion on 3-1/2" tubing, installing Cannon clamps and spooling Tec wire as per tally from 1,422' to 6,806'.
PU = 85K & SO = 65K. Torque all connections to 2,800 ft/lbs with Doyon double stack tongs. Testing Tec wire every 1,000',RIH no-go on LTP at 6,874'. Set 10K
down to confirm and pressure up on the IA to 500 psi to confirm seal engagement (good test). Bleed pressure to 0 psi. Lay down joint #218, 217 & 216. MU space
out pup (6.08') and joint #216. Lost a total of 17 bbls while running 3-1/2" completion,MU the landing joint to the tubing hanger then MU the tubing hanger to the 3-
1/2" tubing. Terminate the Tec wire, feed it through the tubing hanger and secure it.,Drain the BOP stack. Land the tubing hanger. Verify tubing hanger landed.
RU to reverse circulate.,Purge air, close the annular and pressure up on the IA to 500 psi. PU 7' & observe pressure drop. Reverse circulate 435 bbls of corrosion
inhibited source water down the IA taking returns up the tubing at 7 BPM = 700 psi.,Reverse circulate 435 bbls of corrosion inhibited source water down the IA
taking returns up the tubing at 7 BPM = 580 psi (ICP) & 700 psi (FCP),Land the tubing hanger and RILDS.
7/28/2022 PT the 3-1/2" x 9-5/8" IA to 3,700 psi. Pumped 69 strokes and trap 3875 PSI which held good for 30 minutes and charted. Bleed off and RD test equipment.,Tubing
slightly underbalance. Bullhead 20 bbls of 9.25 ppg viscosified brine at 1 BPM, 230 psi ICP, 650 psi FCP. Shut down and pressure stabilized at 530 PSI. Bleed off
pressure. Observe initial 1.63 BPH flow to static after 15 minutes. Sim-ops: clear rig floor of casing and Centrilift equipment. Remove drip pan from BOP stack.,RD
circulating equipment and LD landing joint. Blow down choke and kill lines. Utilize rig vac to vacuum out fluid form the stack. Dry rod in BPV. Pull riser, Remove
choke and kill lines from mud cross. ND BOP stack. Remove spacer spool from BOP stack and set back on pedestal.,Remove MPD orbit valve from MPD in
preparation for BOP stack removal during upcoming rig move. Prep tubing spool for well head install. Remove spacer spool and orbit valve from the cellar. Mobilize
adapter flange and tree into the cellar. Off high line power at 15:00, Code 99 Black on Moose pad access road. Stop operations while emergency personnel respond
and shut down traffic to and from the rig. Send vac truck to assist in containment / cleanup. Rig loader transported the rigs spill connex to provide material for
containment.,NU the tubing head adapter and tree. Obtain final gauge reading: tubing pressure = 1655 psi, IA pressure = 1681 psi, tubing & IA temperature = 72°
and voltage = 20.7.
7/29/2022 RU testing equipment. PT the tubing hanger void to 500/5,000 psi for 10 minutes each (good test). PT the tree with diesel to 250/5,000 psi (good test). Pull the
CTS plug and BPV with the dry rod. Install gauges. Shut in and secure the well.,Rig welder cut off the mouse hole and seal weld the bottom of the cellar box.
SimOps: Work on rig move checklist.,PJSM. Skid the rig floor into move position. Rig released from well M-29 at 06:00 hours.
7/8/2022Spud Date:
Well Name:
Field:
County/State:
MP M-29
Milne Point
Hilcorp Energy Company Composite Report
, Alaska
50-029-23719-00-00API #:
Well Name Rig API Number Well Permit Number Start Date End Date
MP M-29 Eline / Fullbore 50-029-23719-00-00 222-072 7/29/2022 9/1/2022
Hilcorp Alaska, LLC
Weekly Operations Summary
7/29/2022
wellhead: M/U hanger to string, terminate 1/4" tech wire. land hanger and RILDS. Clean void and install CTS plug, CAHN seal
and RX-54. Land adaptor and tree running tech wire through adaptor. Torque, fill void with test fluid. Test void 500/5 5K/10
good test. Rig test tree Good. Pull CTS plug, well on slight vac. Pull 3" BPV secure well. Install tree cap and gauges.
*** WELL SHUT-IN ON ARRIVAL, 250L / 2500H.***
SHIFT XD-SS AT 5,900' MD (Appears open). W/ 3-1/2" 42BO.
SET 3" JETPUMP (serial# - HC-00031, ratio: 13B) IN XD-SS AT 5,900' MD.
*** WELL SHUT-IN ON DEPARTURE, PAD OP NOTIFIED.***
8/30/2022
MPU Well Support S/I well,due to end of 30-day sundry,R/D hardline to Production/Test/PowerFluid and tied well in as
Injector. PT'd surface lines and set wellhouse.
No issues
8/29/2022
9/1/2022
(Pre Injection MIT-IA Passed) (Pressure Test equipment to 250/2500 psi) Pressured up IA to 2200 psi with 6.25 bbls diesel. 15
min IA lost 73 psi. 30 min IA lost 29 psi. Bled IA to 100 psi and recovered 4 bbls.
PT PCE 300L / 3500H. USE POWER FLUID TO DISPLACE TUBING. PULL 3"" JETPUMP (serial# - HC-00031, ratio: 13B) FROM XD-
SS AT 5,900' MD. LRS PUMPED 157bbls CORROSION INHIBITOR, 243bbls DIESEL DOWN IA. SHIFT XD-SS W/ 3-1/2"" 42BO AT
5,900' MD (appears closed). LRS PERFORMED PASSING MIT-IA. (Swap to Injector)(Pressure Test equipment to 250/2500 psi)
Pumped 157 bbls of inhibited 1% KCL down IA followed by 220 bbls diesel to freeze protect. MIT-IA to 1500 psi.(PASSED)
Pressured up IA to 1646 psi with 22.75 bbls diesel. 15 min IA lost 53 psi. 30 min IA lost 16 psi. Bled IA to 60 psi and recovered
4 bbls.
Pressured up IA to 2200 psi with 6.25 bbls diesel. 15
min IA lost 73 psi. 30 min IA lost 29 psi. Bled IA to 100 psi and recovered 4 bbls
TD Shoe Depth: PBTD:
No. Jts. Returned
RKB RKB to BHF RKB to THF
Jts.
1
2
1
1
1
108
1
1
1
58
2
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? Yes X No Spacer returns?Yes X No Vol to Surf:
Cement In Place At: Date: Estimated TOC:
Method Used To Determine TOC:
Preflush (Spacer)
Type: Density (ppg) Volume pumped (BBLs)
Lead Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Tail Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Post Flush (Spacer)
Type: Density (ppg) Rate (bpm): Volume:
Displacement:
Type: Density (ppg) Rate (bpm): Volume (actual / calculated):
FCP (psi): Pump used for disp:X Yes No
Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job
Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf:
Cement In Place At: Date: Estimated TOC:
Method Used To Determine TOC:
Post Job Calculations:
Calculated Cmt Vol @ 0% excess: Total Volume cmt Pumped:
Cmt returned to surface: Calculated cement left in wellbore:
OH volume Calculated: OH volume actual: Actual % Washout:
Cut Joint of Casing
Casing (Or Liner) Detail
Shoe
Pup Joint
Casing
10 3/4
561 44.5388.3
SE
C
O
N
D
S
T
A
G
E
Rig
12:25
Cement to surface
Rotate Csg Recip Csg Ft. Min. PPG9.4
Shoe @ 7075 FC @ Top of Liner6,990.00
Floats Held
419.1 791
190 591.8
Spud Mud
CASING RECORD
County State Alaska Supv.D. Yessak / J. Vanderpool
Hilcorp Energy Company
CASING & CEMENTING REPORT
Lease & Well No.MP M-29 Date Run 14-Jul-22
Setting Depths
Component Size Wt. Grade THD Make Length Bottom Top
TXP BTC-SR Innovex 1.66 7,075.00 7,073.34
52.47 32.37
34.95 128.78 93.83
93.839 5/8 47.0 L-80 TXP BTC-SR Tenaris 41.36
TXP BTC-SR
9 5/8 47.0 L-80 TXP BTC-SR Tenaris
52.47
9 5/8 47.0 L-80 Tenaris 20.10
Csg Wt. On Hook:325,000 Type Float Collar:Innovex No. Hrs to Run:28
9.4 6
1800
10
10.7 436 6.5
94
600
Bump Plug?
FI
R
S
T
S
T
A
G
E
10Tuned Spacer 53
15.8
450
4
9.4 6 184.02/186.2
519.5/520.7
1150
0
Rig
15.8 82
Bump press
Calculated from volumes
Bump Plug?
1:57 7/15/2022 3,189
2539
7,075.007,084.00
CEMENTING REPORT
Csg Wt. On Slips:100,000
Spud Mud
Tuned Spacer
856 2.88
Stage Collar @
60
Bump press
100
190
ES Cementer Closure OK
56
12 217
RKB to CHF
Type of Shoe:Innovex Casing Crew:Doyon
No. Jts. Delivered No. Jts. Run 171
Length Measurements W/O
Threads
Ftg. Delivered Ftg. Run 7,042.63 Ftg. Returned
Ftg. Cut Jt.20.10 Ftg. Balance
www.wellez.net WellEz Information Management LLC ver_04818br
4
ArcticCem Cement
Type
Casing 9 5/8 40.0 L-80 TXP BTC-SR Tenaris 81.18 7,073.34 6,992.16
Float Collar 10 3/4 TXP BTC-SR Innovex 1.31 6,992.16 6,990.85
Casing 9 5/8 40.0 L-80 TXP BTC-SR Tenaris 39.37 6,990.85 6,951.48
Baffle Adapter 10 3/4 TXP BTC-SR HES 1.40 6,951.48 6,950.08
Casing 9 5/8 40.0 L-80 TXP BTC-SR Tenaris 4,389.70 6,950.08 2,560.38
Pup Joint 9 5/8 40.0 L-80 TXP BTC-SR Tenaris 18.09 2,560.38 2,542.29
ES Cementer 10 3/4 TXP BTC-SR HES 2.81 2,542.29 2,539.48
Pup Joint 9 5/8 40.0 L-80 TXP BTC-SR Tenaris 17.61 2,539.48 2,521.87
Casing 9 5/8 47.0 L-80 TXP BTC-SR Tenaris 2,393.09 2,521.87 128.78
Type I/II Cement 516 2.35
Premium G 400 1.16
4
Premium G 270 1.17
7/15/2022 Surface
Spud Mud
Surface
3,189
X
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Benjamin Hand Digitally signed by Benjamin Hand
Date: 2022.07.29 14:29:19 -08'00'Chelsea Wright Digitally signed by Chelsea Wright
Date: 2022.08.01 08:01:12 -08'00'
RBDMS JSB 120222
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: 08/18/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL :
WELL: MPU M-29
PTD: 222-072
API: 50-029-23719-00-00
FINAL LWD FORMATION EVALUATION LOGS (07/08/2022 to 07/23/2022)
x AGR, ABG, DGR, EWR-M5, ADR, Horizontal Presentation (2” & 5” MD/TVD Color Logs)
x Final Definitive Directional Survey
x Final Geosteering and EOW Report/Plots
SFTP Transfer – Main Folders:
FINAL LWD Subfolders:
FINAL Geosteering Subfolders:
Please include current contact information if different from above.
PTD:222-072
T36894
Kayla
Junke
Digitally signed by
Kayla Junke
Date: 2022.08.19
08:50:26 -08'00'
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Monday, December 19, 2022
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Bob Noble
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
Hilcorp Alaska, LLC
M-29
MILNE PT UNIT M-29
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 12/19/2022
M-29
50-029-23719-00-00
222-072-0
W
SPT
3941
2220720 2000
103 103 103 103
INITAL P
Bob Noble
10/12/2022
Pre-produced injector. Tested to 2000 psi per sundry 322-410.
30 MinPretest Initial 15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:
MILNE PT UNIT M-29
Inspection Date:
Tubing
OA
Packer Depth
151 2236 2153 2126IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitRCN221013161434
BBL Pumped:4.1 BBL Returned:4.1
Monday, December 19, 2022 Page 1 of 1
Pre-produced injector. Tested to 2000 psi per sundry 322-410.
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CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas
Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential
and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you
are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the
mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov.
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0380
37'
Date: 7/8/2022 Development: X Exploratory:
Drlg Contractor: Rig No. 14 AOGCC Rep:
Operator:Oper. Rep:
Field/Unit/Well No.:Rig Rep:
PTD No.: 2220720 Rig Phone:
Rig Email:
MMISCELLANEOUS:DIVERTERR 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
AACCUMULATORR SYSTEM:Diverter Size: 21 1/4 in.
Systems Pressure: 3000 psig P Hole Size: 12 1/4 in.
Pressure After Closure: 1825 psig P Vent Line(s) Size: 16 in. P
200 psi Recharge Time: 42 Seconds P Vent Line(s) Length: 171 ft. P
Full Recharge Time:167 Seconds P Closest Ignition Source: 81 ft. P
Nitrogen Bottles (Number of): 6 Outlet from Rig Substructure: 161 ft. P
Avg. Pressure: 2025 psig P
Accumulator Misc: NA
Vent Line(s) Anchored: P
MMUDD 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: 25 sec P
Mud System Misc: 0 NA Knife Valve Open Time: 12 sec P
Diverter Misc: NA
GGASS 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:
SSTATEE OFF AL ASK A
AAL ASK AA OILL ANDD GASS CONSERVATIONN COMMISSION
DDi v er t err Sys t em ss In s p ec t i o nn Rep o r t
GGENERALL INFORMATION
WaivedDoyon
**Al ll Di ver t err r epor t ss ar ee duee t oo t h ee ag enc yy w i t h i nn 55 dayss off t est i n g *
alaskans-doyon14-dsms@hilcorp.com
TTESTT DATA
T.Shones / J.Charlie
phoebe.brooks@alaska.gov
Hilcorp
AOGCC Adam Earl waived witness for Diverter test @ 17:36 hrs on 7-7-2022, Notification made @ 20:33 on 7-6-2022. Test performed with 5"
DP, Gas alarms tested good, PVT system calibrated functioned and tested good, Vent line checked out Good
0
C.Demoski / J.Vanderpool
0
907-670-3090
TTESTT DETAILS
jim.regg@alaska.gov
AOGCC.Inspectors@alaska.gov
MPU M-29
Form 10-425 (Revised 04/2018)2022-0708_Diverter_Doyon14_MPU_M-29
+LOFRUS$ODVND//&
9
9
9
9
9
9
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AOGCC Adam Earl waived witness
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-29
Hilcorp Alaska, LLC
Permit to Drill Number: 222-072
Surface Location: 4914' FSL, 80' FEL, Sec. 14, T13N, R09E, UM, AK
Bottomhole Location: 1538' FNL, 1255' 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 June, 2022.
Jeremy
Price
Digitally signed by
Jeremy Price
Date: 2022.06.14
12:04:51 -08'00'
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Milne Point Unit
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4000450050005500600065007000750080008500900095001000010500110001150012000125001300013500140001450015000155001600016407MPU M-29 wp07Start Dir 3º/100' : 350' MD, 350'TVDStart Dir 4º/100' : 500' MD, 499.85'TVDEnd Dir : 2009.09' MD, 1691.45' TVDStart Dir 4º/100' : 3518.54' MD, 2348.5'TVDEnd Dir : 6765.07' MD, 3948.27' TVDStart Dir 3º/100' : 6965.07' MD, 3965.7'TVDEnd Dir : 7126.77' MD, 3972.96' TVDStart Dir 2º/100' : 8061.34' MD, 3975.4'TVDEnd Dir : 8251.44' MD, 3982.19' TVDStart Dir 2º/100' : 8392.99' MD, 3991.93'TVDEnd Dir : 8576.9' MD, 3998.69' TVDStart Dir 2.5º/100' : 9576.9' MD, 4003.4'TVDEnd Dir : 9825.99' MD, 3991.05' TVDStart Dir 2.5º/100' : 9876.79' MD, 3985.78'TVDEnd Dir : 10115.08' MD, 3973.4' TVDStart Dir 2.5º/100' : 11045.08' MD, 3973.4'TVDEnd Dir : 11239.49' MD, 3981.64' TVDStart Dir 2.5º/100' : 11430.05' MD, 3997.79'TVDEnd Dir : 11630.46' MD, 4006.02' TVDStart Dir 3º/100' : 12630.46' MD, 4003.4'TVDEnd Dir : 12799.47' MD, 3995.49' TVDStart Dir 3º/100' : 12985.39' MD, 3978.58'TVDEnd Dir : 13137.06' MD, 3970.77' TVDStart Dir 2.5º/100' : 13337.06' MD, 3968.4'TVDEnd Dir : 13552.65' MD, 3955.99' TVDStart Dir 2.5º/100' : 13665.44' MD, 3944.35'TVDEnd Dir : 13888.37' MD, 3932.07' TVDStart Dir 2.5º/100' : 14413.37' MD, 3928.4'TVDEnd Dir : 14540.28' MD, 3931.03' TVDStart Dir 2.5º/100' : 14744.53' MD, 3940.91'TVDEnd Dir : 14853.03' MD, 3943.59' TVDStart Dir 2º/100' : 15628.03' MD, 3944.4'TVDEnd Dir : 15662.45' MD, 3944.39' TVDTotal Depth : 16405.96' MD, 3943.4' TVDSV5Base PermafrostUG Coal 1LA3UG_MBSB NASB OAHilcorp Alaska, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: Plan: MPU M-29Ground Level: 24.70+N/-S +E/-WNorthingEastingLatitudeLongitude0.000.006027767.05534084.62 70° 29' 12.785 N 149° 43' 17.095 WSURVEY PROGRAMDate: 2016-08-02T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool33.70 6965.00 MPU M-29 wp07 (MPU M-29) GYD_Quest GWD6965.00 16405.96 MPU M-29 wp07 (MPU M-29) GYD_Quest GWDFORMATION TOP DETAILSTVDPath TVDssPath MDPath Formation1345.40 1287.00 1433.68 SV51894.40 1836.00 2475.33 Base Permafrost2848.40 2790.00 4423.17 UG Coal 13218.40 3160.00 5000.03 LA33500.40 3442.00 5470.03 UG_MB3788.40 3730.00 6081.16 SB NA3958.40 3900.00 6881.32 SB OAREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU M-29, True NorthVertical (TVD) Reference:MPU M-29 as built RKB @ 58.40usftMeasured Depth Reference:MPU M-29 as built RKB @ 58.40usftCalculation Method:Minimum CurvatureProject:Milne PointSite:M Pt Moose PadWell:Plan: MPU M-29Wellbore:MPU M-29Design:MPU M-29 wp07CASING DETAILSTVD TVDSS MD SizeName3965.69 3907.29 6965.00 9-5/8 9 5/8" x 12 1/4"3943.40 3885.00 16405.96 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 0.002 350.00 0.00 0.00 350.00 0.00 0.00 0.00 0.00 0.00 Start Dir 3º/100' : 350' MD, 350'TVD3 500.00 4.50 135.00 499.85 -4.16 4.16 3.00 135.00 -5.60 Start Dir 4º/100' : 500' MD, 499.85'TVD4 750.00 14.45 128.06 746.13 -30.40 35.74 4.00 -10.00 -43.315 2009.09 64.20 112.44 1691.45 -365.51 728.48 4.00 -18.34 -656.40 End Dir : 2009.09' MD, 1691.45' TVD6 3518.54 64.20 112.44 2348.50 -884.34 1984.49 0.00 0.00 -1688.90 Start Dir 4º/100' : 3518.54' MD, 2348.5'TVD7 6765.07 85.00 333.25 3948.27 787.12 3159.44 4.00 -121.99 -733.02 End Dir : 6765.07' MD, 3948.27' TVD8 6965.07 85.00 333.25 3965.70 965.04 3069.76 0.00 0.00 -533.78 Start Dir 3º/100' : 6965.07' MD, 3965.7'TVD9 7126.77 89.85 333.20 3972.96 1109.21 2997.01 3.00 -0.64 -372.30 End Dir : 7126.77' MD, 3972.96' TVD10 8061.34 89.85 333.20 3975.40 1943.36 2575.57 0.00 0.00 562.26 M-29 wp06 tgt2 Start Dir 2º/100' : 8061.34' MD, 3975.4'TVD11 8251.44 86.06 333.42 3982.19 2113.06 2490.25 2.00 176.55 752.20 End Dir : 8251.44' MD, 3982.19' TVD12 8392.99 86.06 333.42 3991.93 2239.36 2427.07 0.00 0.00 893.42 Start Dir 2º/100' : 8392.99' MD, 3991.93'TVD13 8576.90 89.73 333.26 3998.69 2403.58 2344.63 2.00 -2.56 1077.16 End Dir : 8576.9' MD, 3998.69' TVD14 9576.90 89.73 333.26 4003.40 3296.63 1894.69 0.00 0.00 2077.14 M-29 wp06 tgt4 Start Dir 2.5º/100' : 9576.9' MD, 4003.4'TVD15 9825.99 95.96 333.23 3991.05 3518.67 1782.75 2.50 -0.29 2325.80 End Dir : 9825.99' MD, 3991.05' TVD16 9876.79 95.96 333.23 3985.78 3563.77 1759.99 0.00 0.00 2376.32 Start Dir 2.5º/100' : 9876.79' MD, 3985.78'TVD17 10115.08 90.00 333.27 3973.40 3776.18 1652.93 2.50 179.60 2614.19 End Dir : 10115.08' MD, 3973.4' TVD18 11045.08 90.00 333.27 3973.40 4606.80 1234.63 0.00 0.00 3544.18 M-29 wp06 tgt6 Start Dir 2.5º/100' : 11045.08' MD, 3973.4'TVD19 11239.49 85.14 333.29 3981.64 4780.23 1147.32 2.50 179.78 3738.35 End Dir : 11239.49' MD, 3981.64' TVD20 11430.05 85.14 333.29 3997.79 4949.85 1061.97 0.00 0.00 3928.22 Start Dir 2.5º/100' : 11430.05' MD, 3997.79'TVD21 11630.46 90.15 333.32 4006.02 5128.69 972.04 2.50 0.36 4128.40 End Dir : 11630.46' MD, 4006.02' TVD22 12630.46 90.15 333.32 4003.40 6022.21 523.03 0.00 0.00 5128.38 M-29 wp06 tgt8 Start Dir 3º/100' : 12630.46' MD, 4003.4'TVD23 12799.47 95.22 333.44 3995.49 6173.09 447.42 3.00 1.39 5297.14 End Dir : 12799.47' MD, 3995.49' TVD24 12985.39 95.22 333.44 3978.58 6338.71 364.64 0.00 0.00 5482.29 Start Dir 3º/100' : 12985.39' MD, 3978.58'TVD25 13137.06 90.68 333.76 3970.77 6474.34 297.31 3.00 176.00 5633.70 End Dir : 13137.06' MD, 3970.77' TVD26 13337.06 90.68 333.76 3968.40 6653.72 208.89 0.00 0.00 5833.67 M-29 wp06 tgt10 Start Dir 2.5º/100' : 13337.06' MD, 3968.4'TVD27 13552.65 95.92 332.50 3955.99 6845.65 111.66 2.50 -13.43 6048.82 End Dir : 13552.65' MD, 3955.99' TVD28 13665.44 95.92 332.50 3944.35 6945.17 59.87 0.00 0.00 6161.01 Start Dir 2.5º/100' : 13665.44' MD, 3944.35'TVD29 13888.37 90.40 333.26 3932.07 7143.21 -41.55 2.50 172.19 6383.51 End Dir : 13888.37' MD, 3932.07' TVD30 14413.37 90.40 333.26 3928.40 7612.05 -277.77 0.00 0.00 6908.49 M-29 wp06 tgt12 Start Dir 2.5º/100' : 14413.37' MD, 3928.4'TVD31 14540.28 87.23 333.29 3931.03 7725.37 -334.82 2.50 179.41 7035.36 End Dir : 14540.28' MD, 3931.03' TVD32 14744.53 87.23 333.29 3940.91 7907.61 -426.51 0.00 0.00 7239.37 Start Dir 2.5º/100' : 14744.53' MD, 3940.91'TVD33 14853.03 89.94 333.27 3943.59 8004.49 -475.27 2.50 -0.48 7347.83 End Dir : 14853.03' MD, 3943.59' TVD34 15628.03 89.94 333.27 3944.40 8696.67 -823.86 0.00 0.00 8122.82 M-29 wp06 tgt14 Start Dir 2º/100' : 15628.03' MD, 3944.4'TVD35 15662.45 90.08 332.60 3944.39 8727.32 -839.52 2.00 -78.55 8157.23 End Dir : 15662.45' MD, 3944.39' TVD36 16405.96 90.08 332.60 3943.40 9387.39 -1181.73 0.00 0.00 8900.72 M-29 wp06 tgt15 Total Depth : 16405.96' MD, 3943.4' TVD
-1500
-750
0
750
1500
2250
3000
3750
4500
5250
6000
6750
7500
8250
9000
9750
10500
South(-)/North(+) (1500 usft/in)-4500 -3750 -3000 -2250 -1500 -750 0 750 1500 2250 3000 3750 4500 5250
West(-)/East(+) (1500 usft/in)
M-29 wp06 tgt15
M-29 wp06 tgt14
M-29 wp06 tgt13
M-29 wp06 tgt12
M-29 wp06 tgt11
M-29 wp06 tgt10
M-29 wp06 tgt9
M-29 wp06 tgt8
M-29 wp06 tgt7
M-29 wp06 tgt6
M-29 wp06 tgt5
M-29 wp06 tgt4
M-29 wp06 tgt3
M-29 wp06 tgt2
M-29 wp06 tgt1
9 5/8" x 12 1/4"
4 1/2" x 8 1/2"500100015001750200022502500275030003
2
5
0
3500
375 0
4 0 0 0
3 9 4 3
M P U M -2 9 w p 0 7
Start Dir 3º/100' : 350' MD, 350'TVD
Start Dir 4º/100' : 500' MD, 499.85'TVD
End Dir : 2009.09' MD, 1691.45' TVD
Start Dir 4º/100' : 3518.54' MD, 2348.5'TVD
End Dir : 6765.07' MD, 3948.27' TVD
Start Dir 3º/100' : 6965.07' MD, 3965.7'TVD
End Dir : 7126.77' MD, 3972.96' TVD
Start Dir 2º/100' : 8061.34' MD, 3975.4'TVD
End Dir : 8251.44' MD, 3982.19' TVD
Start Dir 2º/100' : 8392.99' MD, 3991.93'TVD
End Dir : 8576.9' MD, 3998.69' TVD
Start Dir 2.5º/100' : 9576.9' MD, 4003.4'TVD
End Dir : 9825.99' MD, 3991.05' TVD
Start Dir 2.5º/100' : 9876.79' MD, 3985.78'TVD
End Dir : 10115.08' MD, 3973.4' TVD
Start Dir 2.5º/100' : 11045.08' MD, 3973.4'TVD
End Dir : 11239.49' MD, 3981.64' TVD
Start Dir 2.5º/100' : 11430.05' MD, 3997.79'TVD
End Dir : 11630.46' MD, 4006.02' TVD
Start Dir 3º/100' : 12630.46' MD, 4003.4'TVD
End Dir : 12799.47' MD, 3995.49' TVD
Start Dir 3º/100' : 12985.39' MD, 3978.58'TVD
End Dir : 13137.06' MD, 3970.77' TVD
Start Dir 2.5º/100' : 13337.06' MD, 3968.4'TVD
End Dir : 13552.65' MD, 3955.99' TVD
Start Dir 2.5º/100' : 13665.44' MD, 3944.35'TVD
End Dir : 13888.37' MD, 3932.07' TVD
Start Dir 2.5º/100' : 14413.37' MD, 3928.4'TVD
End Dir : 14540.28' MD, 3931.03' TVD
Start Dir 2.5º/100' : 14744.53' MD, 3940.91'TVD
End Dir : 14853.03' MD, 3943.59' TVD
Start Dir 2º/100' : 15628.03' MD, 3944.4'TVD
End Dir : 15662.45' MD, 3944.39' TVD
Total Depth : 16405.96' MD, 3943.4' TVD
CASING DETAILS
TVD TVDSS MD Size Name
3965.69 3907.29 6965.00 9-5/8 9 5/8" x 12 1/4"
3943.40 3885.00 16405.96 4-1/2 4 1/2" x 8 1/2"
Project: Milne Point
Site: M Pt Moose Pad
Well: Plan: MPU M-29
Wellbore: MPU M-29
Plan: MPU M-29 wp07
WELL DETAILS: Plan: MPU M-29
Ground Level: 24.70
+N/-S +E/-W Northing Easting Latitude Longitude
0.00 0.00
6027767.05 534084.62 70° 29' 12.785 N 149° 43' 17.095 W
REFERENCE INFORMATION
Co-ordinate (N/E) Reference:Well Plan: MPU M-29, True North
Vertical (TVD) Reference:MPU M-29 as built RKB @ 58.40usft
Measured Depth Reference:MPU M-29 as built RKB @ 58.40usft
Calculation Method:Minimum Curvature
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0.001.002.003.004.00Separation Factor0 375 750 1125 1500 1875 2250 2625 3000 3375 3750 4125 4500 4875 5250 5625 6000 6375 6750 7125Measured Depth (750 usft/in)MPU M-10MPU M-11MPU M-43M-09DSW wp02- AP HillNo-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.NOERRORSWELL DETAILS:Plan: MPU M-29 NAD 1927 (NADCON CONUS)Alaska Zone 04Ground Level: 24.70+N/-S +E/-W Northing EastingLatitudeLongitude0.000.006027767.05534084.6270° 29' 12.785 N 149° 43' 17.095 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU M-29, True NorthVertical (TVD) Reference: MPU M-29 as built RKB @ 58.40usftMeasured Depth Reference:MPU M-29 as built RKB @ 58.40usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2016-08-02T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool33.70 6965.00 MPU M-29 wp07 (MPU M-29) GYD_Quest GWD6965.00 16405.96 MPU M-29 wp07 (MPU M-29) GYD_Quest GWD0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)0 375 750 1125 1500 1875 2250 2625 3000 3375 3750 4125 4500 4875 5250 5625 6000 6375 6750 7125Measured Depth (750 usft/in)MPU M-10MPU M-11MPU M-13MPU M-43MPU M-44iMPU M-45MPU M-28 wp07M-30i wp02MPU M-27MPU M-27 wp07GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference33.70 To 16406.60Project: Milne PointSite: M Pt Moose PadWell: Plan: MPU M-29Wellbore: MPU M-29Plan: MPU M-29 wp07Ladder / S.F. Plots1 of 2CASING DETAILSTVD TVDSS MD Size Name3965.69 3907.29 6965.00 9-5/8 9 5/8" x 12 1/4"3943.40 3885.00 16405.96 4-1/2 4 1/2" x 8 1/2"
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0.001.002.003.004.00Separation Factor6750 7500 8250 9000 9750 10500 11250 12000 12750 13500 14250 15000 15750 16500 17250 18000 18750 19500 20250 21000Measured Depth (1500 usft/in)MPU M-28 wp07M-30i wp02MPU M-27 wp07No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:Plan: MPU M-29 NAD 1927 (NADCON CONUS)Alaska Zone 04Ground Level: 24.70+N/-S +E/-W Northing EastingLatitudeLongitude0.000.006027767.05534084.6270° 29' 12.785 N149° 43' 17.095 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU M-29, True NorthVertical (TVD) Reference: MPU M-29 as built RKB @ 58.40usftMeasured Depth Reference:MPU M-29 as built RKB @ 58.40usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2016-08-02T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool33.70 6965.00 MPU M-29 wp07 (MPU M-29) GYD_Quest GWD6965.00 16405.96 MPU M-29 wp07 (MPU M-29) GYD_Quest GWD0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)6750 7500 8250 9000 9750 10500 11250 12000 12750 13500 14250 15000 15750 16500 17250 18000 18750 19500 20250 21000Measured Depth (1500 usft/in)GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference33.70 To 16406.60Project: Milne PointSite: M Pt Moose PadWell: Plan: MPU M-29Wellbore: MPU M-29Plan: MPU M-29 wp07Ladder / S.F. Plots2 of 2CASING DETAILSTVD TVDSS MD Size Name3965.69 3907.29 6965.00 9-5/8 9 5/8" x 12 1/4"3943.40 3885.00 16405.96 4-1/2 4 1/2" x 8 1/2"
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