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: 24.8' 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 1994'
L-80 4001'
7" L-80 3988'
5-1/2"x L-80 4092'
4-1/2"
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
Sr Res EngSr Pet GeoSr Pet Eng
Oil-Bbl: Water-Bbl:
Water-Bbl:
PRODUCTION TEST
Not on Production
Date of Test: Oil-Bbl:
Flow Tubing
N/A
5-1/2" x 4-1/2" Screen Liner 12/17/2022
8417' - 10424' 3999' - 4018'
10467' - 18960' 4017' - 4092'
Gas-Oil Ratio:Choke Size:
Per 20 AAC 25.283 (i)(2) attach electronic information
40#
8287'
4001'
Surface
129.5#
47#
114'
2777' 8445'
SIZE DEPTH SET (MD)
8276' / 3987'
PACKER SET (MD/TVD)
8276'
42"
20#/13.5#
6029119
SETTING DEPTH TVD
6038607
TOP HOLE SIZE AMOUNT
PULLED
538337
533532
TOP
SETTING DEPTH MD
suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud
log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing
collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary.
None
N/A N/A
2492' / 1857'
4912' FSL, 35' FEL, Sec. 14, T13N, R09E, UM, AK
82' FNL, 576' FEL, Sec. 02, T13N, R09E, UM, AK
58.3'
3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503
534130 6027766
966' FSL, 1101' FEL, Sec. 12, T13N, R09E, UM, AK
ADL 025514 & 388235
16-004
50-029-23734-00-00
MPU M-32
Milne Point Field / Schrader Bluff Oil Pool
18998' / 4092'
19000' / 4092'
11/24/2022
12/15/2022
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Hilcorp Alaska, LLC
WAG
Gas
12/22/2022 222-128
ROP, AGR, DGR, ABG, EWR, ADR MD & TVD
BOTTOM
~270 ft3
Surface Stg 1 L - 880 sx / T - 400 sx
26#
Surface
Surface
2777'
CASING WT. PER
FT.GRADE CEMENTING RECORD
Surface
Surface
9-5/8"12-1/4"
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date perf'd or liner run):
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
CASING, LINER AND CEMENTING RECORD
List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion,
Uncemented TiebackTieback
TUBING RECORD
Uncemented Screen Liner19000'
Stg 2 L - 870 sx / T - 270 sx
3987' 8-1/2"
Liner Top Packer
8274'4-1/2" 12.6# L-80
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
By James Brooks at 9:22 am, Jan 09, 2023
Completed
12/22/2022
JSB
RBDMS JSB 011123
G
DSR-1/23/23SFD 2/23/2023MGR28JULY2023
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
30' 30'
2522' 1887'
Top of Productive Interval 8352' 3993'
1458' 1338'
2608' 1923'
5538' 3226'
7247' 3818'
8352' 3993'
8352' 3993'
31. List of Attachments:
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Joe Lastufka
Digital Signature with Date: Monty Myers Contact Email:joseph.lastufka@hilcorp.com
Contact Phone:907-777-8400
Drilling Manager
General:
Item 1a:
Item 1b:
Item 4b:
Item 9:
Item 15:
Item 19:
Item 20:
Item 22:
Item 23:
Item 24:
Item 27:
Item 28:
Item 30:
Item 31:
INSTRUCTIONS
Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment; or 90 days after log acquisition, whichever occurs first.
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Ugnu LA3
Schrader Bluff NA
Authorized Title:
Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic
diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from
a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071.
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core
analysis, paleontological report, production or well test results, per 20 AAC 25.070.
Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
TPI (Top of Producing Interval).
Authorized Name and
If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if
needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired.
Schrader Bluff OA
Yes No
Well tested? Yes No
28. CORE DATA
If Yes, list intervals and formations tested, briefly summarizing test results for
each. Attach separate pages if needed and submit detailed test info including
reports and Excel or ASCII tables per 20 AAC 25.071.
NAME
Permafrost - Top
Permafrost - Base
29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS
Schrader Bluff OA
LOT / FIT Data Sheet, Drilling and Completion Reports, Cement Report, Definitive Directional Survey, Wellbore Schematic
SV5
SV1
Formation Name at TD:
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
1.9.2023
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: 2023.01.09 07:27:50 -09'00'
Monty M
Myers
_____________________________________________________________________________________
Edited By: JNL 12/27/2022
SCHEMATIC
Milne Point Unit
Well: MPU M-32
Last Completed: 12/22/2022
PTD: 222-128
TD =19,000’(MD) / TD =4,092’(TVD)
4
20”
Orig. KB Elev.: 58.3’ / GL Elev.: 24.8’
7”
6
9-5/8”
1
2
3
See
Screen/
Solid
Liner
Detail
PBTD =18,998’(MD) / PBTD = 4,092’(TVD)
9-5/8” ‘ES’
Cementer @
2,798’
5
7
9
12
8
4-1/2”
CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm BPF
20" Conductor 129.5 / X56 / Weld N/A Surface 114’ N/A
9-5/8" Surface 47 / L-80 / TXP 8.681 Surface 2,777’ 0.0732
9-5/8” Surface 40 / L-80 / TXP 8.835 2,777’ 8,445’ 0.0758
7” Tieback 26 / L-80 / TXP 6.276 Surface 8,287’ 0.0383
5-1/2” Liner 100ђ Screens 20 / L-80 / JFE Bear 4.780 8,276’ 10,424’ 0.0222
4-1/2” Liner 100ђ Screens 13.5 / L-80 / Hyd 625 3.920 10,424’ 19,000’ 0.0149
TUBING DETAIL
4-1/2" Tubing 12.6# / L-80 / TXP 3.958 Surface 8,274’ 0.0152
OPEN HOLE / CEMENT DETAIL
42” ±270 ft3
12-1/4"Stg 1 Lead – 880 sx / Tail – 400 sx
Stg 2 Lead – 870 sx / Tail 270 sx
8-1/2” Cementless Screened Liner
WELL INCLINATION DETAIL
KOP @ 151’
90° Hole Angle = @ 8,881’
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: 50-029-23734-00-00
Completion Date: 12/22/2022
JEWELRY DETAIL
No. MD Item ID
1 Surface 4-1/2” TCII Tubing Hanger 4.500”
2 5,810’ Haliburton X-Line Sliding Sleeve (opens down) 3.813”
3 5,877’ Baker Gauge Carrier 3.865”
4 5,945’ Baker Retrievable Packer 3.960”
5 6,016’ XN Nipple, 3.813”, 3.725” No Go 3.725”
6 8,234’ WLEG/Mule Shoe 3.958”
7 8,276’ SLZXP Liner Top Packer 6.180”
8 8,299’ 7” H563 x 4.5” TSH 625 XO 4.810”
9 18,998’ Shoe 3.970”
5-1/2” x 4-1/2”SCREENS LINER DETAIL
Size Top
(MD)
Top
(TVD)
Btm
(MD)
Btm
(TVD)
5-1/2” 8417’ 3999’ 10424’ 4018’
4-1/2” 10467’ 4017’ 18960’ 4092’
CASING AND LEAK-OFF FRACTURE TESTS
Well Name:MPU M-32 Date:12/7/2022
Csg Size/Wt/Grade:9.625", 40# & 47#, L-80 Supervisor:Yessak/Vanderpool
Csg Setting Depth:8445 TMD 4001 TVD
Mud Weight:9.25 ppg LOT / FIT Press =573 psi
.
LOT / FIT =12.00 Hole Depth =8470 md
Fluid Pumped=1.30 Bbls Volume Back =1.30 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
->166 ->487
->3 172 ->8 245
->5 251 ->12 410
->7 337 ->16 560
->9 433 ->20 691
->11 498 ->24 841
->12 540 ->28 1005
->13 573 ->32 1161
-> ->36 1327
-> ->40 1511
-> ->44 1678
-> ->48 1871
-> ->52 2039
Enter Holding Enter Holding ->56 2245
Time Here Pressure Here ->60 2418
->0 573 ->64 2593
->1 568 ->65 2636
->2 555 Enter Holding Enter Holding
->3 543 Time Here Pressure Here
->4 532 ->0 2636
->5 523 ->5 2622
->6 516 ->10 2615
->7 509 ->15 2610
->8 502 ->20 2606
->9 496 ->25 2603
->10 488 ->26 2603
->11 482 ->27 2602
->12 477 ->28 2602
->13 476 ->29 2600
->14 473 ->30 2600
->15 470 ->
-> ->
0
1
3
5
7
9
11
1213
0
4
8
12
16
20
24
28
32
36
40
44
48
52
56
60
64
65
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 10203040506070
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
)
573568555543532523516509502496488482477476473470
2636 2622 2615 2610 2606 260326032602260226002600
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
Activity Date Ops Summary
11/23/2022 Provided 24 hour diverter test notification at 06:38. Jack up rig and remove shims. Move rig forward off M-31 to provide room for crane and slickline work. SimOps:
Pull Roof Hatch & C/O Centrifuge #1 bowl. Install Diverter Tee and Surface Bag on M-32. Move Rig, Spot, level and shim on Well M-32. Spot Rockwasher, Skid Rig
floor into drilling position. Start acceptance checklist. Continue acceptance checklist. R/U utilities to the rig floor. Hook up high pressure lines. Secure landings and
walkways. Spot support buildings and fuel trailer. Load BHA into Shed.
11/24/2022 Continue rigging up and finish rig acceptance checklist. Rig accepted at 09:00. Perform derrick inspection, electrician plug in top drive and function test good. N/U
surface stack and riser. Load 264 joints of 5" drill pipe in the pipe shed. MWD and Gyro While Drilling test tools. On high line power at 08:40. Install new saver sub
on top drive and inspect grabber dies. Service top drive. Spot upright water tanks and cement silos. Sort HWDP and load 17 joints in the pipe shed. Test H2S &
LEL gas alarms. Finish rig up Diverter vent line. Take on 430 bbls spud mud to pits. Perform the diverter function test with 5" HWDP. The states right to witness
was waived by AOGCC inspector Kam StJohn on 11/24/22 at 05:47 hours. Knife valve opened in 17 seconds and the annular closed in 21 seconds. Accumulator
Test: System psi = 3,000 psi. PSI after closure = 1,800 psi. 200 psi attained in 37 seconds. Full pressure attained in 149 seconds. N2 Bottles - 6 at 2,012 psi
(average). Diverter length = 163'. Nearest ignition source is an air heater, staged at end of the opposite Well row, at 94'. MU and rack back 6 stands 5" HWDP
including jar stand. P/U and M/U 12-1/4" bit, 8" mud motor with 1.5 bend and crossover to 35'. M/U stand HWDP and top drive, RIH and tag up at 108'. Fill stack
with water, check for leaks - Air up leaking air boot on riser. Pressure test mud lines to 3500 psi - good. Cleanout 20" conductor from 108' to 114' with 400 GPM,
230 PSI, 30 RPM, 1K Tq. Drill 12-1/4" hole from 114' to 131', 17' drilled, 34'/hr AROP. 400 GPM, 370 PSI, 30 RPM, 2K TQ, 3-5K WOB. 55K PU / 53K SO / 54K
ROT. MW 8.8 in / 8.8 out, Vis 300+ in / 300+ out. #1 conveyor stop working. Troubleshoot and find conveyor rolling off rear sprocket and binding up. Adjust
sprocket / conveyor tension. SimOps. Work pipe and circ 5 bbls every 5 min while troubleshoot. Rack stand back and blow down TD, pull into conductor while
adjusting sprocket. Drill 12-1/4" hole from 131' to 218', 87' drilled, 58'/hr AROP. 400 GPM, 360 PSI, 40 RPM, 2K TQ, 5K WOB. 50K PU / 55K SO / 51K ROT. MW
8.8 in / 8.8 out, Vis 300+ in / 300+ out. Daily disposal to G&I = 0 bbls. Total disposal to G&I = 0 bbls. Daily water hauled from 6 mile = 245 bbls. Total water hauled
from 6 mile = 245 bbls. Daily fluid loss = 0 bbls. Total fluid loss = 0 bbls. Daily metal recovered = 0 lbs. Total metal recovered = 0 lbs.
11/25/2022 BROOH from 218' to 125' then pull one stand to 35'. Blow down top drive. P/U and inspect bit - good. PJSM. M/U MWD tools with directional, gamma, resistivity,
PWD and GWD from 35' to 97'. Plug in and attempt to communicate with MWD tools. Suspect communication problems due to cold MWD tools.
M/U XO and stand of HWDP. Pump mud through MWD tool string for 30 minutes to warm up collars at 300 GPM = 430 PSI. Rack back stand of HWDP and blow
down top drive. Plug in and initialize MWD tools. M/U three non-mag flex drill collars to 188'. Observe oil seepage from the top drive. Grease RLA (Rotary Link
Adapter). Function top drive and still observe leakage. Mechanic inspected top drive and the tool pusher made decision made to repair before continue drilling. L/D
BHA from 188' to allow for top drive repair. Read MWD tools to power down tools and stop battery consumption. Doyon mobilizing parts and tools for repair or
replacement depending upon observations during disassembly. Clear and clean rig floor. Remove Bails. Slip on 10 wraps drlg line. Disassemble top drive for repair,
removing pipe handler, IBOP, TopDrive rail stops, shot pin assembly and RLA. SimOps: Change out #1 conveyor idler sprocket and add two paddles. Install new
RLA on TopDrive. SimOps: Continue #1 conveyor maintenance, adding two paddles, changing out worn link pins and removing two links from chain. Daily disposal
to G&I = 171 bbls. Total disposal to G&I = 171 bbls. Daily water hauled from 6 mile = 335 bbls. Total water hauled from 6 mile = 580 bbls. Daily fluid loss = 0 bbls.
Total fluid loss = 0 bbls. Daily metal recovered = 0 lbs. Total metal recovered = 0 lbs.
11/26/2022 Finished installing replacement Rotating Link Adapter. Function test RLA - good. Install IBOP and saver sub. Cut off excess drilling line slipped on to lower the top
drive to the rig floor. Install bails & elevators and top drive rail stops. Sim-ops: Continue maintenance on #1 & #2 conveyors. Perform final inspection of top drive to
ensure no tools left on top drive and all fasteners are safety wired. Perform final function test - good. PJSM. M/U 12-1/4" Kymera bit, mud motor with 1.5 AKO, MWD
tools with directional, gamma, resistivity, PWD and GWD from to 97'. Plug in and initialize MWD tools. P/U 1 NM flex drill collar, run in hole and tag up at 118'.
Rotate assembly 180 deg and tag up same spot. L/D collar and P/U stand HWDP. Wash/Ream f/ 97' t/ 194'. 350 GPM, 700 psi, 20 RPM, 2k Tq. Did not see ledge
or any fill. Pump stand HWDP out of hole and rack back & B/D TD. Make up 3 NM flex collars t/ 188'. Off rig repair time at 20:30 - 31 total hours. Make up XO & Std
HWDP. Obtain first Gyro Svy @ 151'. Establish drilling parameters, orient motor TF and wash down to bottom @ 218', 400 GPM, 775 psi. No fill encountered. Drill
12-1/4" hole from 218' to 355' (354' TVD). Drilled 137' = 45.67'/hr AROP. 400 GPM = 840 PSI, 40 RPM = 2-3K TQ, WOB = 5-10K. MW 9.0, Vis 249, ECD 9.12. PU
= 65k, SO = 60k, ROT = 63k. Target 3 deg BUR. Drill 12-1/4" hole from 355' to 414' (413' TVD). Drilled 59' = 59/hr AROP. 400 GPM = 950 PSI, WOB = 10K. MW
9.1, Vis 300, ECD 9.45. PU = 67, SO = 62k. Target 3 deg/100'. A 5" x 10' section of AR wear plate in #1 conveyor became detached and got lodged in conveyer
paddles, stalling the conveyor. Call out Rig Welder. Pull up to 97', racking HWDP in Derrick and put stand of NMFC in 90' mousehole. B/D TD. M/U XO and 5' pup
to top of MWD. Rig up SuperSucker & hoses, clean trough. Rotate chain in reverse to dislodge AR plate. Welder cut plate free and remove. Tack down the cut end
in trough & operate conveyor to clear cuttings and clean trough while welder fabricates a new sections of AR plate to put in place. Monitor hole via TT. Rig Welder
install new sections of AR wear plate in #1 conveyor trough. Last Gyro survey at 332.40 MD / 332.31 TVD, 3.16 inc, 114.26 azm, 3.72 from plan, 3.28 High and
1.76 Right. Daily disposal to G&I = 82 bbls. Total disposal to G&I = 253 bbls. Daily water hauled from 6 mile = 120 bbls. Total water hauled from 6 mile = 700 bbls.
Daily fluid loss = 0 bbls. Total fluid loss = 0 bbls. Daily metal recovered = 0 lbs. Total metal recovered = 0 lbs.
11/27/2022 Finish welding in 10' piece of AR wear plate in the #1 conveyor. Re-install guards and test run good. RIH with one stand of drill collars and HWDP from the derrick
to 375', then wash down from 375' to 414' with 400 = 830 PSI, 40 RPM = 1.5k TQ. 6.5 hours total repair time. Drill 12-1/4" surface hole from 414' to 744', 330'
drilled = 73.33'/hr AROP. 400 GPM = 1,250 PSI, 60 RPM = 2K TQ, WOB = 10-15K. MW = 9.1 ppg, vis = 189, ECD = 9.6. PU = 81K, SO = 80K & ROT = 82K. Drill
12-1/4" surface hole from 744' to 1217' (1156' TVD). Drilled 473' = 78.83/hr AROP. 450 GPM = 1230 PSI, 80 RPM = 1-5K TQ, WOB = 10-15K. MW = 9.1, Vis =
184, ECD = 9.89. PU = 87, SO = 87k, ROT = 88k. Drill 12-1/4" surface hole from 1217' to 1601' (1432' TVD). Drilled 384' = 64/hr AROP. 450 GPM, 1250 psi, 80
RPM, 3-6k Tq, WOB 5-10k. MW = 9.2 ppg, Vis = 169, ECD = 9.9 ppg, Max Gas = 8u. PU 90k, SO 87k, ROT 87k. Drill 12-1/4" surface hole from 1601' to 2115'
(1705' TVD). Drilled 514' = 85.67/hr AROP. 500 GPM, 1720 psi, 80 RPM, 4-6k Tq, WOB 15k. MW = 9.45 ppg, Vis = 128, ECD = 10.3 ppg, Max Gas = 49u. PU
92k, SO 83k, ROT 89k. Last Gyro survey at 1178.05 MD / 1124.51' TVD then swap to MWD. Last survey at 2020.68 MD / 1653.43 TVD, 59.41 inc, 109.30 azm,
10.11 from plan, 1.79 Low and 9.95 Right. Daily disposal to G&I = 869 bbls. Total disposal to G&I = 1122 bbls. Daily water hauled from 6 mile = 825 bbls. Total
water hauled from 6 mile = 1525 bbls. Daily fluid loss = 0 bbls. Total fluid loss = 0 bbls. Daily metal recovered = 0 lbs. Total metal recovered = 0 lbs.
50-029-23734-00-00API #:
Well Name:
Field:
County/State:
MP M-32
Milne Point
Hilcorp Energy Company Composite Report
, Alaska
11/24/2022Spud Date:
11/28/2022 Drill 12-1/4" surface hole 2,115' to 2,644', 529' drilled = 88.17'/hr AROP. 450 GPM = 1630 PSI, 70 RPM = 5-6K TQ, WOB = 7K. MW = 9.5, Vis = 300+, ECD =
10.3, max gas = 58 units. PU = 100K, SO = 80K & ROT = 90K. Base of permafrost at 2,522' MD / 1,887' TVD. Drill 12-1/4" surface hole f/ 2644' t/ 3310' (2232'
TVD). Drilled 666' = 111/hr AROP. 475 GPM, 1860 psi, 70 RPM, 8-10k Tq, WOB 10-12k. MW = 9.3 ppg, Vis = 178, ECD = 10.41 ppg, Max Gas = 52u. PU 105k,
SO 83k, ROT 91k. Pumped high vis sweep at 2740', back on time w/ no increase. Ugnu logged at 3198' MD / 2183' TVD. Drill 12-1/4" surface hole from 3310' to
3789' (2444' TVD). Drilled 479' = 79.83/hr AROP. 500 GPM, 2140 psi, 70 RPM, 6-10k Tq, WOB 1-6k. MW = 9.3 ppg, Vis = 194, ECD = 10.54 ppg, Max Gas =
35u. PU 115k, SO 83k, ROT 97k. Pumped high vis sweep at 3691', back on time w/ no increase. Drill 12-1/4" surface hole from 3789' to 4483' (2751' TVD). Drilled
694' = 115.67/hr AROP. 500 GPM, 2150 psi, 80 RPM, 10k Tq, WOB 7-15k. MW = 9.3 ppg, Vis = 136, ECD = 10.40 ppg, Max Gas = 63u. PU 135k, SO 85k, ROT
105k. Last survey at 4400.28 MD / 2714.35 TVD, 63.69 inc, 109.16 azm, 19.06 from plan, 19.06 High and 0.43 Left. Daily disposal to G&I = 1383 bbls. Total
disposal to G&I = 2506 bbls. Daily water hauled from 6 mile = 1465 bbls. Total water hauled from 6 mile = 2990 bbls. Daily fluid loss = 0 bbls. Total fluid loss = 0
bbls. Daily metal recovered = 0 lbs. Total metal recovered = 0 lbs.
11/29/2022 Drill 12-1/4" surface hole from 4,483' to 4,888', 405' drilled = 67.5'/hr AROP. 500 GPM = 1920 PSI, 80 RPM = 8-12K TQ, 7-15K WOB. MW = 9.4, Vis = 300+, ECD
= 10.4, max gas = 84 units. PU = 140K, SO = 85K & ROT = 103K. Pumped high vis sweep at 4,786', 150 strokes late w/ no increase. Began planned 4/100 turn /
turn & build at 4,600. Drill 12-1/4" surface hole from 4888' to 5298' (3114' TVD). Drilled 410' = 68.33/hr AROP. 500 GPM, 1970 psi, 80 RPM, 12-16k Tq, WOB 8-
15k. MW = 9.3 ppg, Vis = 196, ECD = 10.28 ppg, Max Gas = 32u. PU 163k, SO 81k, ROT 115k. Drill 12-1/4" surface hole from 5298' to 5610' (3256' TVD). Drilled
312' = 52/hr AROP. 500 GPM, 1840 psi, 70 RPM, 13-15k Tq, WOB 1-10k. MW = 9.3 ppg, Vis = 162, ECD = 10.13 ppg, Max Gas = 32u. PU 173k, SO 80k, ROT
118k. Add 4 drums, (0.25%), Lo-Torq at 5600' to help reduce high Stickslip. Drill 12-1/4" surface hole from 5610' to 5784' (3326' TVD). Drilled 174' = 69.6/hr
AROP. 500 GPM, 1940 psi, 70 RPM, 15-17k Tq, WOB 4-10k. MW = 9.3 ppg, Vis = 147, ECD = 10.13 ppg, Max Gas = 32u. PU 175k, SO 80k, ROT 118k. Pumped
high vis sweep at 5760', was strung out and not recognized at surface. Shakers blinding off bad with fine sand, silt and clay. Screen shakers down from 120s to
100s & 80s to handle 450 gpm. Start adding screenkleen to system target 1.25%. Continue drilling, increase flow back to 500 GPM as shakers allow. Drill 12-1/4"
surface hole from 5784' to 5975' (3399' TVD). Drilled 191' = 63.67/hr AROP. 500 GPM, 2010 psi, 70 RPM, 15-20k Tq, WOB 4-12k. MW = 9.35 ppg, Vis = 213,
ECD = 10.13 ppg, Max Gas = 133u. PU 174k, SO 80k, ROT 120k. Screen back to 120's as returns allow. LA3 logged at 5538 MD / 3225 TVD. Last survey at
5732.04 MD / 3305.90 TVD, 67.56 inc, 59.84 azm, 10.41 from plan, 8.70 Low and 5.72 Left. Daily disposal to G&I = 1093 bbls. Total disposal to G&I = 3599 bbls.
Daily water hauled from 6 mile = 1430 bbls. Total water hauled from 6 mile = 4420 bbls. Daily fluid loss = 0 bbls. Total fluid loss = 0 bbls. Daily metal recovered = 0
lbs. Total metal recovered = 0 lbs.
11/30/2022 Drill 12-1/4" surface hole from 5,975' to 6,310' (3,520' TVD), 335' drilled = 55.83'/hr AROP. 500 GPM = 2150 PSI, 80 RPM = 15-20K TQ, WOB = 7-15K. MW = 9.4
ppg, Vis = 280, ECD = 10.6, max gas = 83 units. PU = 183K, SO = 75K & ROT = 119K. Drill 12-1/4" surface hole from 6310' to 6641' (3626' TVD). Drilled 331' =
55.17/hr AROP. 500 GPM, 2160 psi, 80 RPM, 17-21k Tq, WOB 5-10k. MW = 9.4 ppg, Vis = 198, ECD = 10.58 ppg, Max Gas = 134u. PU 187k, SO 73k, ROT
119k. Continue 4 deg build and turn for landing. Drill 12-1/4" surface hole from 6641' to 6866' (3702' TVD). Drilled 225' = 37.50/hr AROP. 500 GPM, 1880 psi, 80
RPM, 19-23k Tq, WOB 5k. MW = 9.3 ppg, Vis = 109, ECD = 9.99 ppg, Max Gas = 82u. PU 200k, SO 75k, ROT 123k. Pumped high vis sweep at 6736', back 100
stks late w/ 10% increase. Drill 12-1/4" surface hole from 6866' to 7116' (3783' TVD). Drilled 250' = 41.67/hr AROP. 520 GPM, 2090 psi, 80 RPM, 20-24k Tq, WOB
1-7k. MW = 9.3 ppg, Vis = 120, ECD = 10.2 ppg, Max Gas = 55u. PU 200k, SO 80k, ROT 126k. UG_MB logged at 6,393 MD / 3,550' TVD. Last survey at 7064.04
MD / 3763.75 TVD, 72.66 inc, 2.43 azm, 21.84 from plan, 12.83 Low and 17.67 Right. Daily disposal to G&I = 1036 bbls. Total disposal to G&I = 4635 bbls. Daily
water hauled from 6 mile = 1130 bbls. Total water hauled from 6 mile = 5550 bbls. Daily fluid loss = 0 bbls. Total fluid loss = 0 bbls. Daily metal recovered = 0 lbs.
Total metal recovered = 0 lbs.
12/1/2022 Drill 12-1/4" surface hole from 7116' to 7425' (3870' TVD). Drilled 309' = 51.5/hr AROP. 500 GPM, 2100 psi, 80 RPM, 18-20k Tq, WOB 3-9k. MW = 9.3 ppg, Vis =
168, ECD = 10.63 ppg, Max Gas = 258u. PU 188k, SO 75k, ROT 123k. Build and turn 4 deg/100'. The SB_NA logged at 7247' MD / 3818' TVD, the NB logged at
7370' MD / 3855' TVD. Drill 12-1/4" surface hole from 7425' to 7784' (3938' TVD). Drilled 359' = 59.83/hr AROP. 500 GPM, 2040 psi, 80 RPM, 20-21k Tq, WOB 8-
10k. MW = 9.3 ppg, Vis = 124, ECD = 10.32 ppg, Max Gas = 283u. PU 190k, SO 77k, ROT 123k. Build and turn 4 deg/100'. Pump 30 bbl hi vis sweep at 7689',
returned on time w/ no increase in cuttings observed. Drill 12-1/4" surface hole from 7784' to 8088' (3971' TVD). Drilled 250' = 41.67/hr AROP. 500 GPM, 2050 psi,
80 RPM, 18-20k Tq, WOB 10k. MW = 9.4 ppg, Vis = 88, ECD = 10.58 ppg, Max Gas = 133u. PU 185k, SO 75k, ROT 119k. Drill 12-1/4" surface hole from 8088' to
8450' at TD in the SB_OA (4001' TVD). 362' drilled. 500 GPM, 2110 PSI, 80 RPM, 21k Tq, 7K WOB. 9.5 ppg MW, 69 vis, 10.7 ECD, 108u max gas. 195K PU /
73K SO / 120K ROT. Top of the OA sand logged at 8352' (3393' TVD) landed out 8' TVD below the OA top @ 85.28 deg. Final survey at 8398.14 MD / 3996.90
TVD, 85.28 INC, 330.75 AZM. Distance from Wp08= 6.51'/ 5.84' Low & 2.86' left. Rack stand back to 8354', pump 30 bbl hi vis sweep. Circulate sweep around
cleaning up the wellbore at 510 GPM, 2060 psi, 60 rpm, 21k Tq. Condition mud, lowering YP. Daily disposal to G&I = 1388 bbls. Total disposal to G&I = 6023 bbls.
Daily water hauled from 6 mile = 1345 bbls. Total water hauled from 6 mile = 6895 bbls. Daily fluid loss = 0 bbls. Total fluid loss = 0 bbls. Daily metal recovered = 0
lbs. Total metal recovered = 0 lbs.
12/2/2022 Rack stand back to 8256' circulating sweep around cleaning up the wellbore at 510 GPM, 2060 psi, 60 rpm, 21k Tq. sweep on time, no increase, condition the mud,
9.35 ppg MW, 51 vis, YP at 20. Wash from 8163' back to bttm, no fill. Flow check the well, static. Set MWD mode switch to Gyro. Max gas 508u. BROOH from
8450' to 6640' pulling 5-10 minutes/stand slowing as needed to clean slides/tight spots. 550 GPM = 1990 psi, 60 RPM = 20K ft-bs TQ, max gas = 10 units. PU =
176K, SO = 85K, ROT = 120K. BROOH from 6640' to 3775' pulling 5-10 minutes/stand slowing as needed to clean slides/tight spots. 550 GPM = 1700 psi, 60
RPM = 10-12K Tq, Max gas = 9 units. PU = 140K, SO = 75K, ROT = 105K. BROOH from 3775' to 1981' @ 5-10 min/std slowing as needed for slides/tight spots.
High Tq (18-23k) and shakers blinding from clay & fine sand, f/ 2250'-t/ 2120'. 450-550 GPM = 1020 psi, 60 RPM = 8-23K Tq, Max gas = 309u. PU = 140k, SO =
70k, ROT = 90k. Reduce pulling speed to CBU from 2550' to 2400'. BROOH from 1981' to 744' pulling 5-10 minutes/stand slowing as needed to clean slides/tight
spots. 500 GPM = 1160 psi, 60 RPM = 8K Tq, Max gas = 110 units. Circulate 2x BU while pulling last stand of DP. No losses recorded while BROOH. Flow check
the well at the HWDP and the well is static. POOH on elevators from 744' to 190' racking back HWDP and jar stand. L/D crossover and flex collars to 98'. Download
MWD and L/D remaining BHA to the GWD Collar. Daily disposal to G&I = 979 bbls. Total disposal to G&I = 7002 bbls. Daily water hauled from 6 mile = 1150 bbls.
Total water hauled from 6 mile = 8045 bbls. Daily fluid loss = 0 bbls. Total fluid loss = 0 bbls. Daily metal recovered = 0 lbs. Total metal recovered = 0 lbs.
12/3/2022 L/D remaining BHA from GWD Collar. 12 1/4'' bit grade= PDC= 1-3-BT-G-X-1-WT-TD, Tri-cone = 2-2-WT-A-E-1-NO-TD. Normal wear on the BHA from BROOH,
note: 1- flex collar had severe wear on 1 side of the hardband. No losses BROOH. Clear and clean the rig floor, flush and clean the flowline. RU the volante tool, bail
extensions, 9-5/8'' handling equipment and DDI casing tongs. Ready FOSV and crossover. Loss rate 2-3.5 bph. PJSM. MU 9-5/8", 40#, L-80, TXP-BTC shoe track.
Bakerlok 1-4 connections with 21K ft-lbs TQ. HES rep installed "top hat" above float collar. Pump thru shoe track and check floats (good). RIH with 9-5/8", 40#
casing from 140' to 2587', TQ = 21K ft-lbs with Volant tool. Fill on the fly and top off every 10 joints. Installing centralizer per tally. PU = 125K, SO = 87K. Loss rate =
6.5 BPH slowing to 3.6 BPH. RIH with 9-5/8", 40# casing from 2588' to 4434'. TQ = 21K ft-lbs with Volant tool. Fill on the fly and top off every 10 joints. Installing
centralizer per tally. PU = 200K, SO = 90K. Loss rate = 4.5 BPH. Circulate one casing volume, stage up to 6 BPM = 280 psi reciprocating 25'. PU = 175K, SO =
100K. 11 bbls loss while circulating. RIH with 9-5/8", 40# casing from 4434' to 4475'. TQ = 21K ft-lbs with Volant tool. Troubleshoot scraping noise from string.
Observe lifting ear on riser bent over and scraping on casing while slacking off. Bend lifting ear back straight and run one joint in hole t/ 4517'. Lifting ear still in
close proximity to casing string. Reposition the riser, rotating 90 deg to remove possibility of contacting casing collars. Work string intermittently to ensure free. RIH
with 9-5/8", 40# casing from 4517' to 5631'. MU the ES cementer (6x brass screws set for 3300 psi shear) and BakerLok the connections to 5668'. TQ = 21K ft-lbs
with Volant tool. Fill on the fly and top off every 10 joints. Installing centralizer per tally.
Loss rate = 4 BPH. RIH with 9-5/8", 47# casing from 5631' to 6246'. TQ = 24K ft-lbs with Volant tool. Fill on the fly and top off every 10 joints. Installing centralizer
per tally. Loss rate = 6 BPH. Daily disposal to G&I = 711 bbls. Total disposal to G&I = 7713 bbls. Daily water hauled from 6 mile = 265 bbls. Total water hauled from
6 mile = 8310 bbls. Daily fluid loss = 53 bbls. Total fluid loss = 53 bbls. Daily metal recovered = 0 lbs. Total metal recovered = 0 lbs.
12/4/2022 RIH with 9-5/8", 47# casing from 6246' to 8389'. TQ = 24K ft-lbs with Volant tool. Fill on the fly and top off every 10 joints. Installing centralizer per tally. Wash last 5
joints down 2 bpm, 100 psi, on depth at 8445', verify pipe count. PU 315K, SO 60k. Losses RIH and circulating= 89 bbls. Stage pumps slowly from 2 BPM to 6
BPM = 630 psi, while working the string from 8445' to 8415'. Set TD torque at 18K, establish rotation at 1-2 RPM while working pipe. Spot and RU cementers.
Condition the mud for cementing, Final 6 BPM = 320 psi with MW 9.3+ ppg, YP = 17. Shut down pump, BD TD and breakout volant. RU plug valves and cement
hose. Re-dope and MU volant. Close upper and lower IBOP. Continue to circulate 6 BPM = 420 psi. Blow air to cement unit. Finish getting the pits ready. No losses
circulating. Continue to circulate 6 BPM, 300 psi, Hold PJSM with all parties involved. Pump 50 bbls mud treated with desco, HES filled lines with 5 bbls fresh
water. PT surface lines to 1,000/4,000 psi, good. Unable to rotate and work string due to PU wt exceeding 400K, park on depth at 8445'. Pump 1st stage cement
job: Mix & pump 60 bbls of 10 ppg tuned spacer with 4# red dye & 5# Pol-E-Flake in 1st 10 bbls at 4 BPM = 200 psi.
Drop bypass plug. Mix and pump 367 bbls of 12.0 ppg lead cement (Type I-II cement, 2.347ft^3/sk yield, 880 sks total) at 5.5 BPM = 410 psi. Mix & pump 82 bbls
15.8 ppg Premium G tail cement (1.156 ft^3/sk yield, 400 sks total) at 3.5 BPM = 360 psi. Drop shutoff plug. HES pump 20 bbls water at 4 BPM = 180 psi. Displace
with 388.8 bbls (3848 strokes) 9.3+ ppg spud mud from rig at 6.5 BPM =590 psi. Displace with 80 bbls 10.0 ppg Tuned Spacer from HES at 5 BPM = 590 psi.
Continue to displace with 9.35 ppg mud from the rig at 6 BPM = 650 psi ICP, slow to 3 bpm for last 10 bbls, FCP 660 psi. Bumped plugs at 5202 strokes (1.6 bbls
late). Pressure up to 1,200 psi, hold for 3 minutes, bleed off. Bumped plugs at 5202 strokes (1.6 bbls late). Pressured up to 1,200 psi, hold for 3 minutes, bleed off
pressure, check floats and floats held. Pressure up to shift the ES cementer open, stage tool opened at 2400 psi and gained returns. No clear indication of
substantial pressure drop. Pressure up to 3600 psi at 9 bpm attempting to shift ES cementer further - no success. Continued to circulate at 6 bpm, 1090 psi. CIP at
21:35. 17 bbl losses cementing. Pump through ES cementer at 2797' at 6 BPM = 1090 psi. Slow to 4 BPM - 450 psi when diverting to RW. Dumped 70 bbls of
tuned spacer, 30 bbls of cmt and 115 bbls of clabbered mud/interface to the RW before take returns to the pits. Dump 360 bbls thick mud returns after 5th BU.
Circulated total of 7 BU. Disconnect knife valve from accumulator. Drain stack and flush with black water two times. Re-connect knife valve to the accumulator.
Clean rig floor cement valves. Circulate through the ES cementer at 2797' staging the pumps up to 4-6 BPM = 267-517 psi. Daily disposal to G&I = 866 bbls. Total
disposal to G&I = 8579 bbls. Daily water hauled from 6 mile = 600 bbls. Total water hauled from 6 mile = 8910 bbls. Daily fluid loss = 53 bbls. Total fluid loss = 106
bbls.
12/5/2022 Break out the Volant, clean, dope the cup and MU same. PJSM with all parties involved for 2nd stage cement job. Blow air through the cement line to the cementers.
Fuel cementers, continue to circulate 4 bpm, 250 psi while W/O last load of water to arrive. Lineup to cementers. Pump 2nd stage cement job: Pump 5 bbls of water
and PT lines to 1,000/4,000 psi (good test). Mix & pump 60 bbls of 10.0 ppg Tuned Spacer w/ 4# red dye & 5# Pol-E-Flake in 1st 10 bbls at 4 BPM = 420 psi. Mix &
pump total 448 bbls 10.7 ppg Arctic Cem lead cement (870 sx at 2.883 ft^3/sk yield) at 5.5 BPM, ICP= 620, FCP= 700 psi
At 360 bbls pumped start seeing spacer returns, dump returns to rock washer. At 425 bbls pumped start seeing cement returns. Mix & pump 56 bbls of 15.8 ppg
Premium G tail cement (270 sx at 1.17 ft^3/sk yield) at 5.5 BPM= 840 psi. Drop the closing plug. Pump 20 bbls of 8.34 ppg fresh water at 7 BPM = 520 psi.
Displace with 187.9 bbls 9.3 ppg spud mud at 6 BPM = 350 psi ICP, last 10 bbls slow to 4 BPM = 490 psi FCP. Bumped the plug at 1860 strokes, 2.9 bbls over
calculated, CIP at 11:10. 60 BBLS spacer, 95 bbls of interface and 252 bbls good 10.7 ppg cement returned, 100% returns during job. Pressure to 1900 psi shifting
ESC closed, hold for 3 minutes, bleed off pressure, open block valve to casing, no flow. Disconnect the accumulator lines from the knife valve. Drain the cement
from the stack into the cellar box. Flush the stack with black water 3 times. Jet the flow line with black water. Power down the accumulator and disconnect lines from
diverter annular. RD the Volant tool. Vacuum out the casing to below ground level. Remove the turnbuckles. Clear the rig floor of casing running equipment. Back
out the grub screws from the starting head. Hoist the diverter stack. Prep to set casing slips. SimOps: clean the mud pits. Center up the 9-5/8'' casing, WHR install
casing slips with 100K set on the slips. Welder made casing cut. LD cut joint. Length on cut joint= 17.94'. Pull the riser and reposition the annular. Welder dressed
the casing stump. ND diverter stack/tee and remove from cellar. SimOps: clean the mud pits. Install the slip lock casing head and tubing spool. PT the void to 500
psi for 5 minutes and 3,800 psi for 10 minutes (good test). Torque casing slips. SimOps: clean the mud pits. N/U the BOP stack. Install turn buckles and MPD riser.
N/U the kill line. Install annular hydraulic hoses. Obtain RKB's. M/U top drive test sub. R/U BOPE testing equipment. Changeout the seal ring and install the test
plug. Grease IBOP. M/U 3-1/2" & 5" FOSVs. Flood the stack, lines and choke manifold with fresh water. Check for leaks. Purge air from the system. Daily disposal
to G&I = 1802 bbls. Total disposal to G&I = 10381 bbls. Daily water hauled from 6 mile = 505 bbls. Total water hauled from 6 mile = 9415 bbls. Daily fluid loss = 0
bbls. Total fluid loss = 106 bbls.
12/6/2022 Perform BOP shell test to 250/3000 psi (passed). Conduct initial BOPE test to 250/3,000 psi: UPR (4-1/2 x 7 VBR) with 4-1/2, 5'' & 7" test jts. LPR (2-7/8 x 5 VBRs)
with 4-1/2" & 5" test jts, annular with 4-1/2 test jt, accumulator drawdown test & test gas alarms. All tests performed with fresh water against test plug. Witness
waived by AOGCC inspector B. Bixby via email on 12/4/22 at 19:47 hours. Tests: 1. Annular with 4-1/2 test joint, 3" kill, 5" TIW, choke valves 1, 12, 13 & 14
(passed). 2. UPR with 4-1/2 test joint, HCR kill, 5" Dart valve, choke valves 9, 11 (passed). 3. UPR with 4-1/2 test joint (passed). 4. UPR with 5" test joint, upper
IBOP, manual kill, choke valves 5, 8 & 10, 3 1/2'' FOSV (passed). 5. Lower IBOP, choke valves 4, 6 & 7, 3 1/2'' dart valve (passed). 6. Choke valve 2 (passed). 7.
HCR choke (passed). 8. Manual choke (passed). 9. LPR with 5"" test joint (passed). 10. UPR with 7'' test joint (passed). 11. Blind rams, choke valve 3 (passed). 12.
Hydraulic super choke (passed). 13. Manual adjustable choke (passed). Accumulator Test: System pressure = 2950 psi. Pressure after closure = 1700 psi. 200 psi
attained in 49 seconds. Full pressure attained in 189 seconds. Nitrogen Bottles - 6 at 1958 psi. Rig electrician calibrate and test rig gas alarms. RD BOP testing
equipment. BD the choke manifold and kill line.Install the 9-1/8" ID wear bushing. Service the top drive, inspect saver sub and grabber dies, good. PJSM, MU
cleanout BHA, 8-1/2'' Tricone bit, 1.5 deg motor, 5 stands 5" HWDP with jar stand to 586'. TIH with cleanout BHA from 586' to 2679', MU TD, fill pipe. PU = 105K &
SO = 70K. Wash and ream from 2679' to 2795' pumping 300 gpm, 450 psi, 30 rpm, 5-7k torque. Drill plugs and ES cementer from 2795' to 2798' at 350 GPM =
620 psi, 30 RPM = 6-8K Tq, WOB = 3-6K. Wash and ream through the ES cementer 3 times and drift through clean without pump/rotary. Blow down the top drive.
TIH with cleanout BHA from 2798' to 8196' filling DP every 2,000'. PU = 250K & SO = 50K. Ream down from 8196, observed soft cement and a few stringers
starting at 8220 cement firming up at 8300. 450 GPM, 1100 psi. 30 RPM, 20-24k Tq. CBU at 450 GPM = 1100 psi, 30 RPM = 20K ft-lbs Tq, reciprocate string 90'.
Blow down the top drive. R/U test equipment and purge air from the system. Close upper pipe rams. PT the 9-5/8" ,40#/47# casing to 2,500 psi for 30 minutes
charted (good test). Blow down and R/D test equipment. Pumped 6.5 bbls & bled back 6.5 bbls. Continue to drill cement, plugs, BA, 9-5/8" shoe track and float
equipment from 8300' to 8445' at 445 GPM = 1130 psi, 30 RPM = 21K ft-lbs Tq, WOB = 6-10K. PU = 250K, SO = 50K & ROT = 120K. All equipment on depth.
Drill out rat hole from 8445' to 8450'. Drill 20' of new formation from 8450' to 8470' at 445 GPM = 1130 psi, 30 RPM = 21k ft-lbs Tq, WOB = 10k. Daily disposal to
G&I = 0 bbls. Total disposal to G&I = 10381 bbls. Daily water hauled from 6 mile = 110 bbls. Total water hauled from 6 mile = 9525 bbls. Daily fluid loss = 0 bbls.
Total fluid loss = 106 bbls.
12/7/2022 PU into the 9-5/8" casing shoe at 8,445'. Circulate and condition the mud at 448 GPM = 1,220 psi, 30 RPM = 20K ft-lbs TQ, reciprocating 60' until good 9.25 ppg
MW in/out. Max gas = 57 units. PU = 245K, SO = 65K, ROT = 120K. Parked at 8,386'. BD TD. RU test equipment. Fill lines, purge air and close the UPR. Perform
FIT to 12 ppg EMW with existing 9.25 ppg MW, apply 573 psi at surface, good test, bleed off pressure, open UPR. Pumped 1.3 bbls, bled back 1.3 bbl. Blow down
and RD testing equipment, flow check the well, static. Pump 30 bbl dry job, blow down the top drive. TOOH from 8,386' to HWDP at 586'. Note: severe drag for the
first 2,000' TOOH. Flow check the well, static. LD excess HWDP, rack back jar stand, LD cleanout BHA. 8-1/2'' tri cone bit grade= 1-1-WT-A-E-I-NO-BHA. 8 bbl
losses TOOH. Clear and clean the rig floor. Mobilize BHA components to the rig floor. Remove the master bushing and install the split bushings. Monitor well with
trip tank, static. PJSM, MU 8-1/2" NOV PDC bit, NRP-A2 bit sleeve, 7600 Geo-Pilot, LWD (ADR & DGR), MWD (PWD & GWD) directional tools and stabilizer to
102'. initialize MWD. Finish making up BHA with 3 NM flex collars, NM float sub, 5" HWDP and jar to 292'. SimOps: PT MPD lines to 350/1,500 psi - good test. TIH
with lateral BHA from 292' to 766'. Fill pipe. Shallow pulse test MWD at 450 GPM = 900 psi. Break in the Geo Pilot seals. Blow down the top drive. TIH with lateral
BHA from 766' to 8,188'. RIH with 5" DP from the pipe shed from 8,188' to 8,378'. No losses while TIH. PJSM. Drain the stack, pull the MPD riser and install the
MPD RCD. Install the RCD head skirt for the drip pan. PJSM. Displace the well from 9.25 ppg spud mud to 8.8 ppg FloPro at 6 BPM = 480 psi (ICP), 30 RPM =
21K ft-lbs TQ. PU = 255K, SO = 45K & ROT = 117K. After displacement 7 BPM = 630 psi (FCP), 30 RPM = 10K ft-lbs TQ. PU =170K, SO = 93K & ROT = 120K.
Daily disposal to G&I = 194 bbls. Total disposal to G&I = 10,575 bbls. Daily water hauled from 6 mile = 115 bbls. Total water hauled from 6 mile = 9,640 bbls. Daily
fluid loss = 8 bbls. Total fluid loss = 114 bbls. Daily metal recovered = 9 lbs. Total metal recovered = 9 lbs.
12/8/2022 TOOH racking 1 stand back from 8,438' to 8,378', blow down the top drive. Monitor the well with MPD. PJSM. Slip and cut 72' of drilling line. Inspect break linkage.
Service the top drive and draw works. Inspect saver sub and grabber dies- torque die bolts, calibrate block height. Obtain new SPR's. Monitor the well with MPD, no
pressure build. SimOps: Clean pit 4 and under shaker. Wash and ream to bottom at 8,470' (no fill). Drill 8-1/2" lateral from 8,470' to 8,733' (4021' TVD). Drilled 263'
= 87.6'/hr AROP. 448 GPM = 1280 psi, 120 RPM = 9K ft-lbs TQ, WOB = 9-11K. PU = 155K, SO = 90K & ROT = 120K. MW = 8.95 ppg, Vis = 45, ECD = 10.1 ppg,
max gas = 328 units. MPD choke full open while drilling and trapping 0 psi on connections. Drill down targeting 87 deg exiting the OA-1 at 8,546', entering OA-3 at
8,627' and level out in the OA-3 targeting 88.5 deg. Drill 8-1/2" lateral from 8,733' to 9,145' (4,029' TVD). Drilled 412' = 68.7'/hr AROP. 450 GPM = 1,290 psi, 120
RPM = 10K ft-lbs TQ, WOB = 10-15K. PU = 155K, SO = 85K & ROT = 120K. MW = 8.9 ppg, Vis = 39, ECD = 10.0 ppg, max gas = 572 units. MPD choke full open
while drilling and trapping 0 psi on connections. Target 89 deg in the OA-3. Drill 8-1/2" lateral from 9,145' to 9,575' (4,034' TVD). Drilled 430' = 71.7'/hr AROP. 450
GPM = 1,270 psi, 120 RPM = 12K ft-lbs TQ, WOB = 10-15K. PU = 155K, SO = 85K & ROT = 120K. MW = 8.8 ppg, Vis = 38, ECD = 9.95 ppg, max gas = 484
units. MPD choke full open while drilling and trapping 70 psi on connections. Pumped 30 bbl hi-vis sweep at 9,520'. Back on time with 20% increase. Drill 8-1/2"
lateral from 9,575' to 10,282' (4,025' TVD). Drilled 707' = 117.8'/hr AROP
450 GPM = 1,410 psi, 120 RPM = 10K ft-lbs TQ, WOB = 10-15K. PU = 152K, SO = 85K & ROT = 117K. MW = 8.8 ppg, Vis = 44, ECD = 10.35 ppg, max gas =
484 units. MPD choke full open while drilling and trapping 70 psi on connections. Begin planned undulation up at 9,825' targeting 92 deg. Exited the OA-3 at
10,210'. Drilled 24 concretions for a total thickness of 202' (11.7% of the lateral). Last survey at 9,927.15 MD / 4,037.76 TVD, 90.86 INC, 337.16 AZM. Distance
from WP08 = 12.17, 9.36 high & 7.77 left. Daily disposal to G&I = 1,112 bbls. Total disposal to G&I = 11,687 bbls. Daily water hauled from 6 mile = 415 bbls. Total
water hauled from 6 mile = 10,055 bbls. Daily fluid loss = 0 bbls. Total fluid loss = 114 bbls. Daily metal recovered = 14.5 lbs. Total metal recovered = 23.5 lbs.
12/9/2022 Drill 8-1/2" lateral from 10,282' to 10,948' (4014' TVD). Drilled 666' = 111'/hr AROP. 450 GPM = 1480 psi, 120 RPM = 18K ft-lbs TQ, WOB = 15-17K. PU = 159K,
SO = 75K & ROT = 114K. MW = 8.9 ppg, Vis = 45, ECD = 10.6 ppg, max gas = 409 units. MPD choke full open while drilling and trapping 85 psi on connections.
Undulate up targeting 92 deg. Entered the OA-1 at 10,443' and leveled out at 90 deg. Pumped 30 bbl hi vis sweep at 10,472, back on time with 100% increase. Drill
8-1/2" lateral from 10,948' to 11,709' (4,044' TVD). Drilled 761' = 126.8'/hr AROP. 450 GPM = 1,620 psi, 120 RPM = 15K ft-lbs TQ, WOB = 10-15K. PU = 165K,
SO = 73K & ROT = 117K. MW = 8.9 ppg, Vis = 42, ECD = 10.65 ppg, max gas = 559 units. MPD choke full open while drilling and trapping 85 psi on connections.
Begin planned undulation down at 11,250' targeting 87 deg. Exited the OA-1 at 11,398', entered the OA-3 at 11,505' and leveled out at 90 deg. Pump 30 bbl hi vis
sweep at 11,520', back on time with 100% increase. Drill 8-1/2" lateral from 11,709' to 12,281' (4,044' TVD). Drilled 572' = 95.3'/hr AROP. 450 GPM = 1,650 psi,
120 RPM = 12K ft-lbs TQ, WOB = 10-15K. PU = 160K, SO = 75K & ROT = 112K. MW = 9.0 ppg, Vis = 41, ECD = 10.69 ppg, max gas = 434 units. MPD choke full
open while drilling and trapping 65-85 psi on connections. Drill 8-1/2" lateral from 12,281' to 12,949' (4,053 TVD). Drilled 668' = 111.3'/hr AROP. 450 GPM = 1,620
psi, 120 RPM = 14K ft-lbs TQ, WOB = 11K. PU = 165K, SO = 70K & ROT = 115K. MW = 8.9+ ppg, Vis = 39, ECD = 10.76 ppg, max gas = 478 units. MPD choke
full open while drilling and trapping 65-85 psi on connections. Pump 30 bbl hi vis sweep at 12,565', back on time with 100% increase. Did not see predicted fault at
12,600'. Drilled 54 concretions for a total thickness of 432 (9.8% of the lateral). Last survey at 12,877.43 MD / 4,052.62 TVD, 87.70 INC, 331.00 AZM. Distance
from WP08 = 16.23, 16.19 high & 1.13 left. Daily disposal to G&I = 1,078 bbls. Total disposal to G&I = 12,765 bbls. Daily water hauled from 6 mile =880 bbls. Total
water hauled from 6 mile = 10,935 bbls. Daily fluid loss = 0 bbls. Total fluid loss = 114 bbls. Daily metal recovered = 7.5 lbs. Total metal recovered = 30.5 lbs.
12/10/2022 Drill 8-1/2" lateral from 12,949' to 13,711 (4,046 TVD). Drilled 762' = 127'/hr AROP. 450 GPM = 1,790 psi, 120 RPM = 14K ft-lbs TQ, WOB = 9K. PU = 168K, SO =
60K & ROT = 113K. MW = 8.9 ppg, Vis = 41, ECD = 10.7 ppg, max gas = 478 units. MPD choke full open while drilling and trapping 65-85 psi on connections.
Pump 30 bbl hi vis sweep at 13,518', back on time with 50% increase. Geo reports crossed fault 1 at 12,371' with 7' DTW throw from lower to mid OA-3. Begin
undulation up at 13,100' targeting 93 deg. Exited the OA-3 at 13,140', entering the OA-1 at 13,229' and leveled out at 90 deg. Drill 8-1/2" lateral from 13,711' to
14,380' (4,056' TVD). Drilled 669' = 111.5'/hr AROP. 450 GPM = 1,740 psi, 120 RPM = 18K ft-lbs TQ, WOB = 10-15K. PU = 170K, SO = 55K & ROT = 111K. MW
= 9.0 ppg, Vis = 41, ECD = 11.02 ppg, max gas = 384 units. MPD choke full open while drilling and trapping 65-85 psi on connections. Begin planned undulation
down at 14,035' to the OA-3 targeting 87 deg. Exited the OA-1 at 14,064', entering the OA-3 at 14,144' and leveled off at 90 deg. Drill 8-1/2" lateral from 14,380' to
14,897' (4,055' TVD). Drilled 517' = 86.2'/hr AROP. 450 GPM = 1,730 psi, 120 RPM = 14K ft-lbs TQ, WOB = 10-15K. PU = 190K, SO = 40K & ROT = 112K. MW
= 9.0 ppg, Vis = 39, ECD = 10.75 ppg, max gas = 433 units. MPD choke full open while drilling and trapping 65-85 psi on connections. Pump 30 bbl hi vis sweep at
14,565', back on time with 30% increase. Drill 8-1/2" lateral from 14,897' to 15,517' (4,061' TVD). Drilled 620' = 103.3'/hr AROP. 450 GPM = 1,750 psi, 120 RPM =
15K ft-lbs TQ, WOB = 9K. PU = 175K, SO = 40K & ROT = 115K. MW = 8.9+ ppg, Vis = 40, ECD = 10.84 ppg, max gas = 481 units. MPD choke full open while
drilling and trapping 65-85 psi on connections. Drilled 72 concretions for a total thickness of 603 (8.6% of the lateral). Last survey at 15,352.18 MD / 4,065.27 TVD,
90.51 INC, 332.58 AZM. Distance from WP08 = 12.08, 6.91 high & 9.91 left. Daily disposal to G&I = 746 bbls. Total disposal to G&I = 13,511 bbls. Daily water
hauled from 6 mile =840 bbls. Total water hauled from 6 mile = 11,775 bbls. Daily fluid loss = 0 bbls. Total fluid loss = 114 bbls. Daily metal recovered = 6.5 lbs.
Total metal recovered = 37 lbs.
12/11/2022 Drill 8-1/2" lateral from 15,517' to 15,910' (4,060' TVD). Drilled 393' = 65.5'/hr AROP. 450 GPM = 1,860 psi, 120 RPM = 15K ft-lbs TQ, WOB = 12K. PU = 148K,
SO = 40K & ROT = 112K. MW = 8.9 ppg, Vis = 44, ECD = 10.9 ppg, max gas = 534 units. MPD choke full open while drilling and trapping 65-85 psi on
connections. Pump 30 bbl hi vis sweep at 15,517', back on time with no increase. At 15,575' perform 290 bbl dump and dilute with new 8.8 ppg flo pro mud. Target
88.5 deg in the OA-3 to 15,628' and begin undulation up targeting 94 deg. Exited the OA-3 at 15,899'. Drill 8-1/2" lateral from 15,910' to 16,625' (4,011' TVD).
Drilled 715' = 119.2'/hr AROP. 450 GPM = 1,910 psi, 120 RPM = 14K ft-lbs TQ, WOB = 10-15K. PU = 165K, SO = 40K & ROT = 110K. MW = 8.9 ppg, Vis = 41,
ECD = 11.14 ppg, max gas = 467 units. MPD choke full open while drilling and trapping 65-85 psi on connections. Pump 30 bbl hi vis sweep at 16,562', back on
time with 30% increase. Continue undulation up and entered the OA-1 at 15,977'. Encountered fault #2 at 16,091' with 40' DTE throw moving the wellbore from the
OA-1 to below the SB OA base. Reacquired the OA-4 at 16,206' and entered OA-3 at 16,284'. Encountered fault #3 at 16,450' with 6' DTE throw moving the
wellbore from the upper OA-3 to the middle OA-3. Drill 8-1/2" lateral from 16,625' to 16,990' (4,021' TVD). Drilled 365' = 60.8'/hr AROP. 450 GPM = 1,800 psi, 120
RPM = 15K ft-lbs TQ, WOB = 10-15K. PU = 170K, SO = 40K & ROT = 110K. MW = 8.9 ppg, Vis = 39, ECD = 10.84 ppg, max gas = 408 units. MPD choke full
open while drilling and trapping 65-85 psi on connections. Level out in the OA-3 targeting 90 deg. Drill 8-1/2" lateral from 16,990' to 17,259' (4,024' TVD). Drilled
269' = 44.8'/hr AROP. 450 GPM = 1,810 psi, 120 RPM = 16K ft-lbs TQ, WOB = 10K. PU = 180K, SO = 40K & ROT = 115K. MW = 8.8+ ppg, Vis = 40, ECD = 10.8
ppg, max gas = 608 units. MPD choke full open while drilling and trapping 65-85 psi on connections. Drilled 96 concretions for a total thickness of 844 (9.6% of the
lateral). Last survey at 17,158.64 MD / 4,022.84 TVD, 89.54 INC, 333.11 AZM. Distance from WP08 = 17.44, 15.69 high & 7.62 left. Daily disposal to G&I = 1,261
bbls. Total disposal to G&I = 14,772 bbls. Daily water hauled from 6 mile = 1,185 bbls. Total water hauled from 6 mile = 12,960 bbls. Daily fluid loss = 0 bbls. Total
fluid loss = 114 bbls. Daily metal recovered = 5 lbs. Total metal recovered = 42 lbs.
12/12/2022 Drill 8 1/2'' lateral, Continue to drill on very hard concretion from 17,259', BR 114' and alternate pump rates from 400-500 gpm, 30-150 rpm, 14-16K torque 4-25k
WOB, unable to make any progress. Discuss with town team, decision made to BROOH to inspect the BHA. PU = 180K, SO = 40K & ROT = 115K. BROOH to
17,227', obtain SPRs, monitor MPD for pressure build 3 times, no build- remains at 23 psi, service the TD while monitoring MPD. Last survey at 17,184.59 MD /
4,023.05 TVD, 89.54 INC, 333.64 AZM. Distance from WP08 = 17.36, 15.61 high & 7.59 left. BROOH from 17,227' to 14,472' pulling 5-10 minutes/stand slowing
as needed to clean up slides/tight spots and racking back stands in derrick. 500 GPM = 1,950 psi, 120 RPM = 13K ft-bs TQ, max gas = 87 units. PU = 165K, SO =
65K, ROT = 115K. MPD choke open while reaming and holding pressure on connections (if needed) to maintain a 9.0 ppg EMW. Loss rate = 6-7 BPH. BROOH
from 14,472' to 11,521 pulling 5-10 minutes/stand slowing as needed to clean up slides/tight spots and racking back stands in derrick. 500 GPM = 1,750 psi, 120
RPM = 10K ft-bs TQ, max gas= 8 units. PU = 155K, SO = 83K, ROT = 117K. MPD choke open while reaming and holding pressure on connections (if needed) to
maintain a 9.0 ppg EMW. Loss rate = 6-7 BPH. BROOH from 11,521' to 8,667' pulling 5-10 minutes/stand slowing as needed to clean up slides/tight spots and
racking back stands in derrick. 500 GPM = 1,450 psi, 120 RPM = 7K ft-bs TQ, max gas= 179 units. PU = 155K, SO = 100K, ROT = 117K. MPD choke open while
reaming and holding pressure on connections (if needed) to maintain a 9.0 ppg EMW. Loss rate = 6-7 BPH. Total losses while BROOH = 115 bbls. Pump out of
hole at 500 GPM = 1,410 psi without rotary while pulling the BHA into the shoe from 8,667' to 8,378' - no issues pulling into the shoe. Pump 30 bbl hi vis sweep
circulating a total of 2 BU at 500 GPM = 1,630 psi, 40 RPM = 5-7K ft-lbs TQ reciprocating DP 90'. Daily disposal to G&I = 404 bbls. Total disposal to G&I = 15,176
bbls. Daily water hauled from 6 mile = 455 bbls. Total water hauled from 6 mile = 13,415 bbls. Daily fluid loss = 65 bbls. Total fluid loss = 179 bbls. Daily metal
recovered = 5 lbs. Total metal recovered = 47 lbs.
12/13/2022 Pump sweep around, back on time, 25% increase, circulate a total of 2 BU until clean, 500 GPM = 1,630 psi, 40 RPM = 5-7K ft-lbs TQ reciprocating DP 90'.
MW 9 ppg in/out. Blow down the top drive, Monitor MPD for pressure build 4 times, with the first building to 13 psi, bleed off same, then no pressure build, close
orbit valve, perform flow check, open 2'' valve on RCD, on slight vac initially then static, monitor for total of 15 min. PJSM. Remove MPD RCD and install trip nipple,
no leaks, 8.4 bbls to fill, monitor the well, slight losses, pump dry job, blow down top drive. TOOH from 8,378' to 3,429' racking stands 5'' drill pipe in the derrick. 8
BBL losses TOOH from the shoe. POOH laying down 5'' DP from 3,429' to 292' at the jar stand, flow check the well, slight losses. Losses TOOH from shoe = 21.8
BBLS. PJSM. Rack the jar stand and NMFCs, LD the ILS, POOH with BHA pulling the bit to the rig floor. LD bit and NRP. 8-1/2'' PDC bit grade= 2-2-BT-S-X-1-CT-
PR. Run BHA in the hole, download MWD and LD the remaining BHA. Mobilize new BHA. MU 8-1/2"" NOV PDC bit, NRP-A2 bit sleeve, 7600 Geo-Pilot, LWD
(ADR & DGR), MWD (PWD & GWD) directional tools and stabilizer to 103'. Initialize MWD. Finish making up BHA with 3 NM flex collars, NM float sub, 5" HWDP
and jar to 293'. RIH with 8-1/2" lateral BHA with 5" DP from the pipe shed from 297' to 2,200'. PU = 75 & SO = 70K. Fill pipe. Shallow pulse test MWD at 500 GPM
= 900 psi. Break in the Geo Pilot seals. Blow down the top drive. RIH with 8-1/2" lateral BHA with 5" DP from the pipe shed from 2,200' to 3,437'. TIH on 5" DP from
3,437' to 8,383'. No losses while TIH. PJSM. Drain the stack, pull the MPD riser and install the MPD RCD. Install the RCD head skirt for the drip pan. Slip and cut
79' (12 wraps) of drilling line. Daily disposal to G&I = 389 bbls. Total disposal to G&I = 15,565 bbls. Daily water hauled from 6 mile = 100 bbls. Total water hauled
from 6 mile = 13,515 bbls. Daily fluid loss = 77 bbls. Total fluid loss = 256 bbls. Daily metal recovered = 2.5 lbs. Total metal recovered = 49.5 lbs.
12/14/2022 Continue to slip and cut 79' (12 wraps) drilling line. Inspect the saver sub and grabber dies - good. Service the top drive. Calibrate the block height. TIH on elevators
from 8,386' to 16,230' where slack off weight was lost. Filling the pipe every 2,000'. 6 BPH loss rate TIH. Wash and ream down from 16,230' to 17,259' with 350
GPM = 1,300 psi, 80 RPM = 15K ft-lbs TQ. PUW = 160K, SO = no & ROT = 115K. Establish drilling parameters with 450 GPM and 80 RPM. Drill from 17,259' to
17,263' and observed 13.88 dogleg over 10' from concretion dropping inclination from 89.61 to 88.29. Stop drilling due to 10 deg/100' tool limitation. Consult with
drilling engineer and Halliburton manager about Geo-Pilot and MWD tool limits with high dogleg. Ream dogleg area while discussing options. Decision was made to
drill with reduced parameters of 80 RPM and 10K WOB until MWD tools past the dogleg. Drill 8-1/2" lateral from 17,263' to 17,709' (4,032' TVD). Drilled 446' =
63.7'/hr AROP. 530 GPM = 2,160 psi, 120 RPM = 17K ft-lbs TQ, WOB = 10K. PU = 175K, SO = 40K & ROT = 110K. MW = 9.0 ppg, Vis = 38, ECD = 11.11 ppg,
max gas = 390 units. MPD choke full open while drilling and trapping 0-30 psi on connections. Encountered fault #4 at 17,432' with 6' DTW throw moving the
wellbore from the middle OA-3 to the lower OA-2. Reentered the OA-3 at 17,483' targeting 86 deg in preparation for fault #5. Drill 8-1/2" lateral from 17,709' to
18,376' (4,087' TVD). Drilled 667' = 111.2'/hr AROP. 530 GPM = 2,190 psi, 120 RPM = 19K ft-lbs TQ, WOB = 10-15K. PU = 185K, SO = 40K & ROT = 115K. MW
= 8.9+ ppg, Vis = 41, ECD = 11.2 ppg, max gas = 457 units. MPD choke full open while drilling and trapping 30 psi on connections. Perform 150 bbl dump and
dilute at 17,900'. Pump 30 bbl hi-vis sweep at 18,088', back on time with 0% increase. Entered the OA-4 at 17,934'. Encountered fault #5 at 17,990' with 45' DTW
throw moving the wellbore from the OA-4 to the NF clays. Entered the OA-1 at 18,067' targeting 86 deg. Drilled 100 concretions for a total thickness of 905 (9.2% of
the lateral). Last survey at 18,208.34 MD / 4,075.21 TVD, 85.67 INC, 335.58 AZM. Distance from WP08 = 16.66, 13.37 low & 9.95 left. Daily disposal to G&I = 292
bbls. Total disposal to G&I = 15,857 bbls. Daily water hauled from 6 mile = 150 bbls. Total water hauled from 6 mile = 13,665 bbls. Daily fluid loss = 42.5 bbls. Total
fluid loss = 298.5 bbls. Daily metal recovered = 4 lbs. Total metal recovered = 53.5 lbs.
12/15/2022 Drill 8-1/2" lateral from 18,376, to 18,872' (4,092' TVD). Drilled 496' = 82.7'/hr AROP. 500 GPM = 2,160 PSI, 120 RPM = 20K ft-lbs TQ, WOB = 10K. PU = 190K,
SO = no & ROT = 107K. MW = 9.0 ppg, Vis = 39, ECD = 11.28, max gas = 506 units. Drill 8-1/2" lateral from 18,872' to 19,000' (4,092' TVD). Drilled 128' = 64'/hr
AROP. 500 GPM = 2,200 PSI, 120 RPM = 19K ft-lbs TQ, WOB = 10K. PU = 200K, SO = no & ROT = 107K. MW = 9.0 ppg, Vis = 40, ECD = 11.25, max gas = 459
units. Obtain final survey & SPR's. Downlink Geo-Pilot to home position. Drilled 112 concretions for a total thickness of 1,026 (9.7% of the lateral). Last survey at
19,000 MD / 4,092.11 TVD, 89.98 INC, 328.18 AZM. Distance from WP08 = 16.89, 16.12 high & 5.03 left. Pump 30 bbl hi-vis sweep, back on time with 10%
increase in cuttings. Circulated a total of 4x bottoms up at 500 GPM = 2,160 psi, 120 RPM = 20K ft-lbs TQ. ECD = 11.2 ppg with 9.0 ppg MW. Reciprocate DP
alternating end points. Pump 30 bbls high vis spacer, 25 bbls 8.45 ppg vis brine, 30 bbls SAPP pill #1, 25 bbls brine, 30 bbls SAPP pill #2, 25 bbls brine, 30 bbls
SAPP pill #3 then 30 bbls high vis spacer. Displace with 1,213 bbls of 8.45 ppg viscosified brine with 3% lubes (1.5% 776 and 1.5% LoTorq). 6 BPM = 990 psi
(ICP), 30 RPM = 18K ft-lbs TQ & 7 BPM = 730 psi (FCP), 30 RPM = 18K ft-lbs TQ, reciprocating 95' alternating stopping points. Shut down the pumps with clean
8.45 ppg viscosified brine to surface. No losses. Obtain passing PST: 3.1, 3.3 & 3.1 seconds per 350 ml sample. Monitor the wellbore pressure with MPD choke 3
times 5 minutes each = 33, 24 & 20 psi. EMW = 8.57 ppg. Obtain new SPR's. SimOps: Clean pit #3 and load 8.45 ppg 3% lube brine in pits #3 & 4. BROOH from
19,000' to 16,851' pulling 5-10 minutes/stand slowing as needed to clean up slides/tight spots. Laying down DP in the mouse hole. 450 GPM = 1,300 psi, 120 RPM
= 19 ft-lbs TQ, max gas = 31 units. PU = 175K, SO = none & ROT = 125K. Loss rate = 30-23 BPH. Lowered the flow rate from 530 GPM to 450 GPM to manage
losses. Daily disposal to G&I = 2065 bbls. Total disposal to G&I = 17,922 bbls. Daily water hauled from 6 mile = 200 bbls. Total water hauled from 6 mile = 13,865
bbls. Daily fluid loss = 0 bbls. Total fluid loss = 298.5 bbls. Daily metal recovered = 7 lbs. Total metal recovered = 60.5 lbs.
12/16/2022 BROOH from 16,851' to 14,026' pulling 5-10 minutes/stand slowing as needed to clean up slides/tight spots. Laying down DP in the mouse hole. 450 GPM = 1,330
psi, 120 RPM = 16 ft-lbs TQ, max gas = 414 units. PU = 175K, SO = 65 & ROT = 123K. Loss rate = 13-17 BPH. BROOH from 14,026' to 11,050' pulling 5-10
minutes/stand slowing as needed to clean up slides/tight spots. Laying down DP in the mouse hole. 450 GPM = 1,150 psi, 120 RPM = 10 ft-lbs TQ, max gas = 81
units. PU = 155K, SO = 90 & ROT = 120K. Loss rate = 10-20 BPH. BROOH from 11,050' to 8,576' pulling 5-10 minutes/stand slowing as needed to clean up
slides/tight spots. Laying down DP in the mouse hole. 450 GPM = 1,150 psi, 120 RPM = 10 ft-lbs TQ, max gas = 81 units. PU = 155K, SO = 90 & ROT = 120K.
Loss rate = 6-19 BPH. Pump into the shoe without rotary from 8,576 to 8,386' at 450 GPM = 1,100 psi observing 15K drag. Lost 365 bbls while BROOH. Pump 30
bbl hi-vis sweep at 450 GPM = 1,050 psi, 60 RPM = 5K ft-lbs TQ reciprocating 90' and circulate late the casing clean with 2 BU. Sweep back on time with 0%
increase. Obtain passing PST. MW in/out = 8.7 ppg. Monitor the wellbore pressure with MPD choke 4 times 5 minutes each = 35, 24,18, & 9 psi. EMW = 8.74 ppg.
Weight up the surface system to 8.9 ppg. Circulate 8.9 ppg while weighting up the returns on the fly to 8.9 ppg at 5 BPM = 350 psi, 56 RPM = 5K ft-lbs TQ
reciprocating 90'. Good 8.9 ppg in/out. Shut down and monitor with MPD, 6 psi in 5 minutes and starting to drop. Blow down the top drive. Open the 2" valve on the
MPD head and observe the well for flow. Slight flow then no flow after 7 minutes. PJSM. Remove the RCD and install the MPD riser. Well on a slight vac. Obtain
SPR's. Pump dry job. Daily disposal to G&I = 384 bbls. Total disposal to G&I = 18,306 bbls. Daily water hauled from 6 mile = 230 bbls. Total water hauled from 6
mile = 14,095 bbls. Daily fluid loss = 346 bbls. Total fluid loss = 644.5 bbls. Daily metal recovered = 5.5 lbs. Total metal recovered = 66 lbs.
12/17/2022 Drop 2.45" OD drift on 100' of wire. Trip out of the hole from 8,383' to 297' racking back 85 stands in the derrick. LD HWDP, jars, Non-Mag Flex collars and float
subs to 103'. Plug in and read MWD tools - 100% data recovery. LD stabilizer, MWD tools, Geo-Pilot and bit. Observed wear on leading edges of Integral Blade
Stabilizer 25% of blades and 40% of upper portion of In-Line Stabilizer. Bit graded 1-2-BT-T-X-I-CT-TD. 27.5 bbls lost on trip from shoe. Mobilize casing equipment
and crossovers to the rig floor. Remove split bushings and install master bushings. RU 4-1/2" double stack tongs, elevators and slips. MU crossover sub on FOSV.
Static loss rate = 5.5 BPH. PJSM with all parties involved. PU round nose float shoe, WIV, 4-1/2", 12.6# blank liner joint, crossover and 4-1/2", 13.5#, L-80, H625
pup joint to 40'. RIH with Superior 4-1/2", 13.5#, L-80, Hydril 625, 100-micron screens from 40' to 8,574'. PU = 115K & SO = 90K. Torque to 9,600 ft-lbs with Doyon
double stack tongs and verify MU mark. Loss rate = 7 BPH. MU safety joint for 5-1/2" screens. MU 4-1/2" H625 x 5-1/2" EZGO crossover. MU 1st 5-1/2" screen.
Install the air slips. MU 2nd screen. While RIH the screen jacket snagged the air slips and close on the screen jacket. POOH, remove the air slips, break out the
damaged screen and lay down. MU new screen and RIH to 8,662'. Utilize hands slips. RIH with Delta, 5-1/2", 20#, L-80, EZGO HT, 100-micron screens per tally
from 8,662' to10,699'. PU = 145K & SO = 85K. Torque to EZGO HT to 8,850 ft-lbs & JFE Bear to 7,400 ft-lbs with Doyon double stack tongs. Loss rate = 5 BPH.
Lost 79 bbls while running liner. Daily disposal to G&I = 57 bbls. Total disposal to G&I = 18,363 bbls. Daily water hauled from 6 mile = 200 bbls. Total water hauled
from 6 mile = 14,295 bbls. Daily fluid loss = 71.5 bbls. Total fluid loss = 716 bbls. Daily metal recovered = 0 lbs. Total metal recovered = 66 lbs.
Activity Date Ops Summary
12/19/2022 POOH laying down 5" drill pipe from 6,595' to 32'. LD Baker liner running tool from 32'. Nothing abnormal observed externally on liner running tool. 41.3 bbls total
lost on trip out of the hole, 3.6 BPH average.MU stack washing tool and flush BOP stack. Remove wear bushing & perform 7" mandrel casing hanger dummy
run.Mobilize casing equipment to the rig floor. RU 7" slip, elevators and Doyon double stack tongs. MU crossover to FOSV. PJSM.MU and RIH with 7" tie back seal
assembly on 7", 26#, L-80, TXP-BTC casing from 20' to 4,395'. PU = 115K & SO = 92K. Torque to 14,750 ft-lbs with Doyon double stack tongs.Slip and cut the
pipe skate counterweight cable.RIH with 7", 26#, L-80, TXP-BTC casing from 4,395' to 8,035'. PU = 165K & SO = 110K. Torque to 14,750 ft-lbs with Doyon double
stack tongs. Loss rate = 2 BPH.Daily disposal to G&I = 57 bbls. Total disposal to G&I = 18,517 bbls. Daily water hauled from 6 mile = 210 bbls. Total water hauled
from 6 mile = 14,505 bbls. Daily fluid loss = 73 bbls. Total fluid loss = 872 bbls. Daily metal recovered = 0 lbs. Total metal recovered = 66 lbs. Rig Fuel = 6,173
gallons, Used = 952 gallons.
12/20/2022 RIH with 7", 26#, L-80, TXP-BTC from 8,035' and no-go on depth at 8,289.73' with 10K. Torque to 14,750 ft-lbs with Doyon double stack tongs. PU = 168K & SO =
110K. 24.3 bbls lost on casing run, 2 BPH average.LD three joints to 8,202'. MU 9.52' pup joint, joint #201, casing hanger and landing joint and land on hanger at
8,287.17' (2.56' off no-go),RU circulating equipment to reverse circulate. Close annular on 7" landing joint. Pump through injection line to OA and pressure up to
350 PSI to confirm seals engaged. PU to expose circulating ports. Pump to confirm returns up the casing. PJSM for displacement. Pressure test lines to 2,000 psi -
good.Reverse circulate 155.2 bbls of 8.45 ppg corrosion inhibited brine at 5 BPM = 880 psi. Reverse circulate 71 bbls of diesel freeze protection at 3 BPM = 380 psi
ICP, 880 psi FCP. Strip down through annular, closing circulating ports and land casing on hanger.Bleed off pressure and drain BOP stack. RD circulating
equipment. LD 7" landing joint.MU 2 joints of 5" HWDP and pack-off running tool. Install 7" pack-off as per wellhead rep. Run in lock down screws. Pressure test
pack-off void to 500 psi for 5 minutes and 5,000 psi for 10 minutes - good. LD HWDP and pack-off running tool.Rig up injection line and test equipment to the OA.
Pressure test 7" X 9-5/8" OA. Utilize rig pump and pressure up to 1,500 psi, hold test for 30 minutes on chart. 2.9 bbls pumped. Bleed off and RD circulating and
test equipment.Install upper test plug and 4-1/2" test joint. Rig up test equipment and line up choke. Fill stack, choke and lines with fresh water.Conduct bi-weekly
BOPE test to 250/3,000 psi: UPR (4-1/2" x 7" VBR) with 4-1/2" test joint. LPR (2-7/8" x 5" VBRs) with 4-1/2" test joint, annular with 4-1/2" test joint, accumulator
drawdown test and test gas alarms. All tests performed with fresh water against test plug. The test was witnessed by AOGCC inspector Brian Bixby. Tests: 1.
Annular with 4-1/2" test joint, 3 Demco kill, 3-1/2" TIW, choke valves 1, 12, 13 & 14 (passed). 2. UPR with 4-1/2" test joint, HCR kill, 3-1/2" dart valve, choke valves
9 & 11 (passed). 3.Upper IBOP, manual kill, choke valves 5, 8 & 10 (passed). 4. Lower IBOP, choke valves 4, 6 & 7 (passed). 5. Choke valve 2 (passed). 6. HCR
choke (passed). 7. Manual choke (passed). 8. LPR with 4-1/2" test joint (passed). 9. Blind rams, choke valve 3 (passed). 10. Manual adjustable choke (passed). 11.
Hydraulic super choke (Fail, cycled, passed). Accumulator Test: System pressure = 3,025 psi. Pressure after closure = 1,700 psi. 200 psi attained in 43 seconds.
Full pressure attained in 183 seconds. Nitrogen Bottles - 6 at 2,025 psi,Blow down and RD BOPE testing equipment,Mobilize 4-1/2" handling equipment, double
stack, spooling unit with Tec wire, job box, cannon clamps, crossovers, pup joint and tubing hanger. MU crossover to 3-1/2" TIW. Static loss rate = 3.5 BPM.PJSM.
PU mule shoe joint and RIH on 4-1/2", 12.6#, L-80, TXP-BTC tubing to 2,246'. Torque to 6,170 ft-lbs with Doyon double stack tongs.MU XN nipple, 1 joint, Baker
Premier Packer, 1 joint and Gauge carrier. MU Zenith gauge and Tec wire. MU 1 joint and sliding sleeve with covered ports for Tec wire bypass to 2,472'.RIH on 4-
1/2", 12.6#, L-80, TXP-BTC tubing from 2,472' to 3,295' installing cannon clamps per tally and checking electrical continuity of the Tec wire every 1,000'. Torque to
6,170 ft-lbs with Doyon double stack tongs.Daily disposal to G&I = 468 bbls. Total disposal to G&I = 18,965 bbls. Daily water hauled from 6 mile = 230 bbls. Total
water hauled from 6 mile = 14,740 bbls. Daily fluid loss = 32 bbls. Total fluid loss = 904 bbls. Daily metal recovered = 0 lbs. Total metal recovered = 66 lbs. Rig Fuel
= 5,151 gallons, Used = 1,022 gallons.
12/21/2022 Continue to run 4-1/2", 12.6#, L-80, TXP-BTC tubing from 3,295' to 8,240' installing Cannon clamps per tally and checking electrical continuity of TEC wire every
1000'. Torque to 6,170 ft-lbs with Doyon double stack tongs. PU = 100K & SO = 75K. 26.3 bbls lost on tubing run, 2 BPH average.M/U tubing hanger with BPV
installed, XO and 5" drill pipe landing joint. Perform hanger penetration with TEC wire. Sim-ops: Drain stack and blow down lines. Land tubing on hanger with mule
shoe at 8,273.17' with 35K on hanger. Run in lock down screws. On rig generator power at 16:00 for rig move.Pull the MPD riser. Remove Drip Pan. N/D the BOP
stack & set on pedestal and secure for transport. SimOps: Clear floor of tubing handling equipment. Start cleaning mud pits.Install CTS plug in BPV. Perform TEC
wire penetration of adapter flange. N/U adapter flange and tree. Test hanger void 500 psi for 5 min, 5000 psi for 10 min. Good test. Obtain final Centrilift readings: Pt
1478.2 PSI, Tt 68.3 deg, Vt 20.2v.Rig up to test, fill Tree with diesel. Pressure test tree to 250 PSI low / 5000 PSI high - Good test. Drain diesel from the tree through
the wing valve. Pull the CTS plug and BPV with the dry rod. R/U circulating lines to pump down IA and take returns from tubing. PJSM, Pressure test lines to 3700
PSI. Daily disposal to G&I = 57 bbls. Total disposal to G&I = 19,022 bbls. Daily water hauled from 6 mile = 0 bbls. Total water hauled from 6 mile = 14,740 bbls.
Daily fluid loss = 29 bbls. Total fluid loss = 933 bbls. Daily metal recovered = 0 lbs. Total metal recovered = 66 lbs. Rig Fuel = 7,626 gallons, Used = 1,022 gallons,
Rec = 3,997.
12/22/2022 Reverse circulate 89 bbls 8.9 ppg corrosion inhibited brine down the 4-1/2" x 7" IA, 3.5 BPM, 720 psi. Reverse circulate 125 bbls diesel freeze protect, down the 4-
1/2" x 7" IA, 3 BPM 660 psi. Take returns from tubing, up cement line to trough and out to rockwasher.Line up and U-Tube freeze protect from IA to tubing. 120 psi
on IA, 120 psi on tbg.Shut master valve, bleed pressure and drain tree to wing valve. Set 1-7/8'' ball and roller rod in tree and install lubricator extension.Drop ball
and roller rod to set premier packer. Allow to gravitate for 30 minutes.Pressure up to 3500 PSI and set Baker 4-1/2" x 7" premier packer, observe initial set shear at
1960 PSI and final set at 2150 PSI. 2.2 bbls pumped. Pressure test 4-1/2" tubing to 3500 PSI for 30 min on chart - good. Bleed down to 2000 PSI. Pressure test 4-
1/2" x 7" IA to 3500 PSI for 30 min on chart - good. Rig released at 06:00.
50-029-23734-00-00API #:
Well Name:
Field:
County/State:
MP M-32
Milne Point
Hilcorp Energy Company Composite Report
, Alaska
Pressure test 7" X 9-5/8" OA. Utilize rig pump and pressure up to 1,500 psi, hold test for 30 minutes on chart. 2.9 bbls pumped.
.Pressure up to 3500 PSI and set Baker 4-1/2" x 7" premier packer, observe initial set shear at
1960 PSI and final set at 2150 PSI. 2.2 bbls pumped. Pressure test 4-1/2" tubing to 3500 PSI for 30 min on chart - good.
TD Shoe Depth: PBTD:
No. Jts. Returned
RKB RKB to BHF RKB to THF
Jts.
1
2
1
1
1
1
134
1
1
1
66
1
Yes X No Yes X 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? Yes X No Reciprocated? Yes X No % Returns during job
Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf:
Cement In Place At: Date: Estimated TOC:
Method Used To Determine TOC:
Preflush (Spacer)
Type: Density (ppg) Volume pumped (BBLs)
Lead Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Tail Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Post Flush (Spacer)
Type: Density (ppg) Rate (bpm): Volume:
Displacement:
Type: Density (ppg) Rate (bpm): Volume (actual / calculated):
FCP (psi): Pump used for disp:X Yes No
Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job
Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf:
Cement In Place At: Date: Estimated TOC:
Method Used To Determine TOC:
Post Job Calculations:
Calculated Cmt Vol @ 0% excess: Total Volume cmt Pumped:
Cmt returned to surface: Calculated cement left in wellbore:
OH volume Calculated: OH volume actual: Actual % Washout:
Casing (Or Liner) Detail
Shoe
Casing
Cut Joint of Casing
10 3/4
631 35.78464.72
SE
C
O
N
D
S
T
A
G
E
Rig
11:10
Cement to surface
Rotate Csg Recip Csg Ft. Min. PPG9.35
Shoe @ 8445 FC @ Top of Liner8,361.30
Floats Held
505.06 953
282 671
Spud Mud
CASING RECORD
County State Alaska Supv.D. Yessak / J. Vanderpool
Hilcorp Energy Company
CASING & CEMENTING REPORT
Lease & Well No.MP M-32 Date Run 3-Dec-22
Setting Depths
Component Size Wt. Grade THD Make Length Bottom Top
TXP BTC-SR Innovex 1.60 8,445.00 8,443.40
2,721.93 2,777.21 55.28
55.289 5/8 47.0 L-80 TXP BTC-SR Tenaris 23.48
9 5/8 47.0 L-80 TXP BTC-SR Tenaris
31.80
Csg Wt. On Hook:425,000 Type Float Collar:Innovex No. Hrs to Run:27
9.35 6.5
1900
10
10.7 448 5.5
99
660
Bump Plug?
FI
R
S
T
S
T
A
G
E
10Tuned Spacer 60
15.8
490
5.5
9.3 6 207.9/205.2
605.4/603.6
1200
30
Rig
15.8 82
Bump press
Cement to suface
Bump Plug?
21:35 12/4/2022 2,797
2794.76
8,445.008,450.00
CEMENTING REPORT
Csg Wt. On Slips:100,000
Spud Mud
Tuned Spacer
870 2.88
Stage Collar @
60
Bump press
100
252
ES Cementer Closure OK
56
12 367
24.80 RKB to CHF 29.35
Type of Shoe:Innovex Casing Crew:Doyon Casing
No. Jts. Delivered No. Jts. Run
Length Measurements W/O Threads
Ftg. Delivered Ftg. Run Ftg. Returned
Ftg. Cut Jt.23.48 Ftg. Balance
www.wellez.net WellEz Information Management LLC ver_04818br
3.5
ArcticCem Cement
Type
98 total 95/8" x 12-1/4" bowspring centralizers ran. Two in shoe joint w/ stop rings 10' from each end. One floating on
joint B. One each with stop rings, mid-joint, on joints C & pup joint-D. Once each joints 1 to 21, every other joint to #43
then every third joint to #127. One each on joints #129 to #140. One each with stop rings on pup joints above and below
ES cementer. One each on every third joint #143 to #197
Casing 9 5/8 40.0 L-80 TXP BTC-SR Tenaris 82.07 8,443.40 8,361.33
Float Collar 10 3/4 TXP BTC-SR Innovex 1.30 8,361.33 8,360.03
Casing 9 5/8 40.0 L-80 TXP BTC-SR Tenaris 41.23 8,360.03 8,318.80
Baffle Adapter 10 3/4 TXP BTC-SR HES 1.39 8,318.80 8,317.41
Pup Joint 9 5/8 40.0 L-80 TXP BTC-SR Tenaris 12.69 8,317.41 8,304.72
Casing 9 5/8 40.0 L-80 TXP BTC-SR Tenaris 5,489.53 8,304.72 2,815.19
Pup Joint 9 5/8 40.0 L-80 TXP BTC-SR Tenaris 17.60 2,815.19 2,797.59
ES Cementer 10 3/4 TXP BTC-SR HES 2.83 2,797.59 2,794.76
Pup Joint 9 5/8 40.0 L-80 TXP BTC-SR Tenaris 17.55 2,794.76 2,777.21
Type I/II Cement 880 2.35
Premium G Cement 400 1.16
5.5
Premium G Cement 270 1.17
12/5/2022 37
Spud Mud
37
X
Cement to surface
2,797
252
99
100
Cement to suface
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Chelsea Wright Digitally signed by Chelsea
Wright
Date: 2022.12.19 15:33:10 -09'00'
Benjamin Hand Digitally signed by Benjamin Hand
Date: 2022.12.20 10:09:51 -09'00'
David Douglas Hilcorp Alaska, LLC
Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 777-8337
E-mail: david.douglas@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Date: 01/05/2023
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL :
WELL: MPU M-32
PTD: 222-128
API: 50-029-23734-00-00
FINAL LWD FORMATION EVALUATION LOGS (11/24/2022 to 12/15/2022)
x ROP, AGR, DGR, ABG, EWR-M5, ADR, Horizontal Presentation (2” & 5” MD/TVD Color Logs)
x Final Definitive Directional Survey
x Final Geosteering and EOW Report/Plots
SFTP Transfer – Main Folders:
FINAL LWD Subfolders:
FINAL Geosteering Subfolders:
Please include current contact information if different from above.
By Meredith Guhl at 1:59 pm, Jan 05, 2023
222-128
T37422
Meredith Guhl Digitally signed by Meredith Guhl
Date: 2023.01.05 14:00:59 -09'00'
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________MILNE PT UNIT M-32
JBR 01/26/2023
MISC. INSPECTIONS:
FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK:
ACCUMULATOR SYSTEM:MUD SYSTEM:
P/F P/F
P/FP/FP/F
Visual Alarm
QuantityQuantity
Time/Pressure
SizeQuantity
Number of Failures:1
Tested all Gas Alarms and PVT's, Tested with 4.5" Test Joint, Super Choke was flushed and passed retest. Pre-Charge Bottles
= 1@900psi, 1@925psi, 8@950psi, 2@975psi and 6@1000psi.
Test Results
TEST DATA
Rig Rep:Hansen / CharlieOperator:Hilcorp Alaska, LLC Operator Rep:Demoski / Toomey
Rig Owner/Rig No.:Doyon 14 PTD#:2221280 DATE:12/20/2022
Type Operation:DRILL Annular:
250/3000Type Test:BIWKLY
Valves:
250/3000
Rams:
250/3000
Test Pressures:Inspection No:bopBDB221225072218
Inspector Brian Bixby
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 4.5
MASP:
1397
Sundry No:
Control System Response Time (sec)
Time P/F
Housekeeping:P
PTD On Location P
Standing Order Posted P
Well Sign P
Hazard Sec.P
Test Fluid W
Misc NA
Upper Kelly 1 P
Lower Kelly 1 P
Ball Type 1 P
Inside BOP 1 P
FSV Misc 0 NA
14 PNo. Valves
1 PManual Chokes
1 FPHydraulic Chokes
0 NACH Misc
Stripper 0 NA
Annular Preventer 1 13 5/8"P
#1 Rams 1 4 1/2"x7"P
#2 Rams 1 Blinds P
#3 Rams 1 2 7/8"x5"P
#4 Rams 0 NA
#5 Rams 0 NA
#6 Rams 0 NA
Choke Ln. Valves 1 3 1/8"P
HCR Valves 2 3 1/8"P
Kill Line Valves 2 3 1/8"P
Check Valve 0 NA
BOP Misc 0 NA
System Pressure P3025
Pressure After Closure P1700
200 PSI Attained P43
Full Pressure Attained P183
Blind Switch Covers:PYES
Bottle precharge P
Nitgn Btls# &psi (avg)P6@2025
ACC Misc NA0
P PTrip Tank
P PPit Level Indicators
P PFlow Indicator
P PMeth Gas Detector
P PH2S Gas Detector
0 NAMS Misc
Inside Reel Valves 0 NA
Annular Preventer P19
#1 Rams P8
#2 Rams P8
#3 Rams P7
#4 Rams NA0
#5 Rams NA0
#6 Rams NA0
HCR Choke P2
HCR Kill P2
FP
Tested all Gas Alarms and PVT's, Tested with 4.5" Test Joint, Super Choke was flushed and passed retest. Pre-Charge Bottles
1
Regg, James B (OGC)
From:Alaska NS - Doyon 14 - DSMs <AlaskaNS-Doyon14-DSMs@hilcorp.com>
Sent:Friday, November 25, 2022 9:10 AM
To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC)
Cc:Nathan Sperry; Doug Yessak - (C)
Subject:MPU M-32 Diverter Function Test Report
Attachments:MPU M-32 Diverter 11-24-2022.xlsx
Goodmorning,
AttachedisthediverterfunctiontestreportfromHilcorpAlaskaMPUMͲ32onDoyon14.
Regards,
C.A.Demoski
Doyon14DSM
907Ͳ670Ͳ3090Office
907Ͳ670Ͳ3092RigFloor
907Ͳ378Ͳ7530Cell
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named
above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this
email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed
above, then promptly and permanently delete this message.
While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission,
opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and
the recipient should carry out such virus and other checks as it considers appropriate.
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open
attachments unless you recognize the sender and know the content is safe.
0LOQH3RLQW8QLW0
37'
Date: 11/24/2022 Development: X Exploratory:
Drlg Contractor: Rig No. 14 AOGCC Rep:
Operator:Oper. Rep:
Field/Unit/Well No.:Rig Rep:
PTD No.: 2221280 Rig Phone:
Rig Email:
MMISCEL L ANEOUS:DIVERTER SYSTEM:
Location Gen.: P Well Sign: P Designed to Avoid Freeze-up? P
Housekeeping: P Drlg. Rig. P Remote Operated Diverter? P
Warning Sign P Misc: NA No Threaded Connections? P
24 hr Notice: P Vent line Below Diverter? P
AACCUMUL ATOR SYSTEM:Diverter Size: 21-1/4 in.
Systems Pressure: 3000 psig P Hole Size: 12 1/4 in.
Pressure After Closure: 1800 psig P Vent Line(s) Size: 16 in. P
200 psi Recharge Time: 37 Seconds P Vent Line(s) Length: 163 ft. P
Full Recharge Time:149 Seconds P Closest Ignition Source: 94 ft. P
Nitrogen Bottles (Number of): 6 Outlet from Rig Substructure: 125 ft. P
Avg. Pressure: 2012 psig P
Accumulator Misc: NA
Vent Line(s) Anchored: P
MMUD SYSTEM:Visual Alarm Turns Targeted / Long Radius: P
Trip Tank: P P Divert Valve(s) Full Opening: P
Mud Pits: P P Valve(s) Auto & Simultaneous:
Flow Monitor: P P Annular Closed Time: 21 sec P
Mud System Misc: 0 NA Knife Valve Open Time: 17 sec P
Diverter Misc: NA
GGAS DETECTORS:Visual Alarm
Methane: P P
Hydrogen Sulfide: P P
Gas Detectors Misc: 0 NA
Total Test Time: 1 hrs Non-Compliance Items: 0
Remarks:
Submit to:
SSTATE OF AL ASK A
AAL ASK A OIL AND GAS CONSERVATION COMMISSION
DDi v er t er Sys t em s In s p ec t i o n Rep o r t
GGENERAL INFORMATION
WaivedDoyon
**Al l Di verter rep o r t s ar e d u e t o t h e ag en c y w i t h i n 5 d ays o f t est i n g *
AlaskaNS-Doyon14-DSMs@hilcorp.co
TTEST DATA
T.Shones / J.Charlie
phoebe.brooks@alaska.gov
Hilcorp
Test performed with 5" HWDP, test H2S and LEL gas alarms, AOGCC Kam St.John waived witness at 0547 hours on 11/24/2022
0
C.Demoski / J.Vanderpool
0
907-670-3092
TTEST DETAIL S
jim.regg@alaska.gov
AOGCC.Inspectors@alaska.gov
Milne Point Unit M-32
Form 10-425 (Revised 05/2021)2022-1124_Diverter_Doyon14_MPU_M-32
$ODVND//&9
9
9
9
9
-5HJJ
From:Brooks, James S (OGC) on behalf of AOGCC Reporting (CED sponsored)
To:AOGCC Records (CED sponsored)
Subject:FW: Diverter - Doyon 14
Date:Wednesday, December 28, 2022 9:29:41 AM
Attachments:2022-1124_Diverter_Doyon14_MPU_M-32.pdf
-$0(6%522.6
5(6($5&+$1$/<67,,E$/$6.$2,/$1'*$6&216(59$7,21&200,66,21
'(3$570(172)&200(5&(&20081,7<$1'(&2120,&'(9(/230(17
E-$0(6%522.6#$/$6.$*29
From: Regg, James B (OGC) <jim.regg@alaska.gov>
Sent: Tuesday, December 27, 2022 4:32 PM
To: AOGCC Reporting (CED sponsored) <aogcc.reporting@alaska.gov>
Subject: Diverter - Doyon 14
Milne Point Unit M-32 (PTD 2221280)
Jim Regg
Supervisor, Inspections
AOGCC
333 W. 7th Ave, Suite 100
Anchorage, AK 99501
907-793-1236
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
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11.24.2022
By Anne Prysunka at 8:01 am, Nov 25, 2022
MGR25NOV22
1. BOPE test to 3000 psi. Annular to 2500 psi.
2. Casing test of 9-5/8" surface casing and FIT digital data to
AOGCC immediately upon performing the FIT.
Milne Point Unit
M-32 SB Producer
PTD Application
Milne Point Unit
M-32 SB Producer
PTD Application
Milne Point Unit
M-32 SB Producer
PTD Application
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PTD Application
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PTD Application
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M-32 SB Producer
PTD Application
Confirm that these test pressures match those specified on the APD.
If the BOP is used to shut in on the well in a well control situation or control fluid flow from the
well bore, AOGCC is to be notified and we must test all BOP components utilized for well control
prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP
test.
o
“A casing pressure test
must be performed if BOPE is to be installed on a casing. The casing must be tested to hold a
minimum surface pressure equal to 50 percent of the casing internal yield pressure. The test
pressure must show stabilizing pressure and may not decline more than 10 percent within 30
minutes. The results of this test and any subsequent tests of the casing must be recorded as required
by 20 AAC 25.070(1)”.
Milne Point Unit
M-32 SB Producer
PTD Application
o
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o
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Ensure to report the following on wellez:
Send final “As-Run” casing tally & casing and cement report to nathan.sperry@hilcorp.com and
joseph.lastufka@hilcorp.com This will be included with the EOW documentation that goes to the
AOGCC.
Milne Point Unit
M-32 SB Producer
PTD Application
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Email casing test and FIT digital data to AOGCC upon completion of FIT. email: melvin.rixse@alaska.gov
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Revised 2/2015
TRANSMITTAL LETTER CHECKLIST
WELL NAME: ______________________________________
PTD: _____________________________________________
___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional
FIELD: ____________________________ POOL: ______________________________________
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK OPTIONS TEXT FOR APPROVAL LETTER
MULTI
LATERAL
(If last two digits
in API number are
between 60-69)
The permit is for a new wellbore segment of existing well Permit
No. _____________, API No. 50-_______________________.
Production should continue to be reported as a function of the original
API number stated above.
Pilot Hole
In accordance with 20 AAC 25.005(f), all records, data and logs
acquired for the pilot hole must be clearly differentiated in both
well name (_______________________PH) and API number
(50-_____________________) from records, data and logs acquired for
well (name on permit).
Spacing
Exception
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce/inject is contingent upon issuance of
a conservation order approving a spacing exception.
(_____________________________) as Operator assumes the liability
of any protest to the spacing exception that may occur.
Dry Ditch Sample
All dry ditch sample sets submitted to the AOGCC must be in no greater
than 30' sample intervals from below the permafrost or from where
samples are first caught and 10' sample intervals through target zones.
Non-
Conventional
Well
Please note the following special condition of this permit:
Production or production testing of coal bed methane is not allowed for
well ( ) until after ( )
has designed and implemented a water well testing program to provide
baseline data on water quality and quantity.
(________________________) must contact the AOGCC to obtain
advance approval of such water well testing program.
Well Logging
Requirements
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types
of well logs to be run. In addition to the well logging program proposed
by (_______________________________) in the attached application,
the following well logs are also required for this 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 AOGCC
within 90 days after completion, suspension or abandonment of this
well.
MPU M-32
222-128
X
Milne Point Unit
Schrader Bluff Oil
X
X
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
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07501500225030003750True Vertical Depth (1500 usft/in)-1500 -7500750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 12000 12750Vertical Section at 357.07° (1500 usft/in)M-32 wp02 tgt1M-32 wp02 tgt2M-32 wp02 tgt4M-32 wp02 tgt6M-32 wp02 tgt8M-32 wp02 tgt10M-32 wp02 tgt12M-32 wp02 tgt15M-32 wp02 tgt16M-32 wp02 tgt18M-32 wp02 tgt19M-32 wp02 tgt20M-32 wp02 tgt21M-32 wp02 tgt239 5/8" x 12 1/4"4 1/2" x 8 1/2"500100015002000250030003500400045005000550060006500700075008000850090009500100001050011000115001200012500130001350014000
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175 001800018500190001950019850MPU M-32 wp03Start Dir 3º/100' : 191.5' MD, 191.5'TVDStart Dir 4º/100' : 441.5' MD, 440.79'TVDEnd Dir : 2020.41' MD, 1624.49' TVDStart Dir 4.25º/100' : 5025.95' MD, 2707.78'TVDEnd Dir : 8065.79' MD, 3978.35' TVDStart Dir 2.5º/100' : 8365.79' MD, 4004.5'TVDEnd Dir : 8557.31' MD, 4013.21' TVDStart Dir 2º/100' : 9176.96' MD, 4015.5'TVDEnd Dir : 9420.55' MD, 4026.69' TVDStart Dir 2º/100' : 9434.3' MD, 4027.91'TVDEnd Dir : 9657.08' MD, 4038.92' TVDStart Dir 2.5º/100' : 10557.08' MD, 4048.5'TVDEnd Dir : 10723.19' MD, 4044.51' TVDStart Dir 2.5º/100' : 10829.19' MD, 4038.3'TVDEnd Dir : 10982.18' MD, 4034.27' TVDStart Dir 2.5º/100' : 12032.18' MD, 4040.5'TVDEnd Dir : 12171.95' MD, 4045.2' TVDStart Dir 2.5º/100' : 12322.73' MD, 4054.45'TVDEnd Dir : 12458.38' MD, 4058.88' TVDStart Dir 2.5º/100' : 13608.38' MD, 4063.5'TVDEnd Dir : 13764.71' MD, 4058.83' TVDStart Dir 2.5º/100' : 13875.36' MD, 4051.77'TVDEnd Dir : 14012.6' MD, 4047.11' TVDStart Dir 2.5º/100' : 14912.6' MD, 4043.5'TVDEnd Dir : 15103.29' MD, 4050.66' TVDStart Dir 2.5º/100' : 15142.29' MD, 4053.74'TVDEnd Dir : 15317.4' MD, 4060.92' TVDStart Dir 2.5º/100' : 16242.4' MD, 4063.5'TVDEnd Dir : 16496.08' MD, 4050.18' TVDStart Dir 2.5º/100' : 16597.27' MD, 4039.29'TVDEnd Dir : 16721.85' MD, 4029.24' TVDStart Dir 2º/100' : 17071.85' MD, 4010.5'TVDEnd Dir : 17171.8' MD, 4006.89' TVDStart Dir 2.5º/100' : 17619.01' MD, 3998.5'TVDEnd Dir : 17762.28' MD, 3991.36' TVDStart Dir 2.5º/100' : 17796.58' MD, 3988.59'TVDEnd Dir : 17992.73' MD, 3981.08' TVDStart Dir 2º/100' : 18317.73' MD, 3982.5'TVDEnd Dir : 18508.4' MD, 3989.65' TVDStart Dir 2º/100' : 18605.28' MD, 3996.5'TVDEnd Dir : 18785.87' MD, 4003.59' TVDStart Dir 2.5º/100' : 19027.69' MD, 4005.5'TVDEnd Dir : 19087.79' MD, 4005.19' TVDStart Dir 2.5º/100' : 19166.55' MD, 4003.74'TVDEnd Dir : 19386.68' MD, 4010.26' TVDStart Dir 2.5º/100' : 19433.97' MD, 4013.93'TVDEnd Dir : 19670.36' MD, 4020.09' TVDTotal Depth : 19850.36' MD, 4015.5' TVDSV6BPFRSV1UG4UG MBNbOaHilcorp Alaska, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: Plan: MPU M-3224.80+N/-S +E/-WNorthingEastingLatitudeLongitude0.000.0027765.630534129.770 70° 29' 12.7693 N 149° 43' 15.7663 WSURVEY PROGRAMDate: 2022-08-18T00:00:00 Validated: Yes Version: Depth From Depth ToSurvey/PlanTool33.70 1500.00MPU M-32 wp03 (MPU M-32)GYD_Quest GWD1500.00 8558.00MPU M-32 wp03 (MPU M-32)3_MWD+IFR2+MS+Sag8558.00 19850.36MPU M-32 wp03 (MPU M-32)GYD_Quest GWDFORMATION TOP DETAILSTVDPath TVDssPath MDPath Formation846.14 787.64 864.57 SV61896.57 1838.07 2775.30 BPFR1933.16 1874.66 2876.81 SV12177.98 2119.48 3556.06 UG43580.26 3521.76 6784.71 UG MB3864.50 3806.00 7489.16 Nb4004.75 3946.25 8368.68 OaREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU M-32, True NorthVertical (TVD) Reference:MPU M-32 as built RKB @ 58.50usftMeasured Depth Reference:MPU M-32 as built RKB @ 58.50usftCalculation Method:Minimum CurvatureProject:Milne PointSite:M Pt Moose PadWell:Plan: MPU M-32Wellbore:MPU M-32Design:MPU M-32 wp03CASING DETAILSTVD TVDSS MD SizeName4013.21 3954.71 8558.00 9-5/8 9 5/8" x 12 1/4"4015.50 3957.00 19850.36 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 0.002 191.50 0.00 0.00 191.50 0.00 0.00 0.00 0.00 0.00 Start Dir 3º/100' : 191.5' MD, 191.5'TVD3 441.50 7.50 130.00 440.79 -10.50 12.52 3.00 130.00 -11.13 Start Dir 4º/100' : 441.5' MD, 440.79'TVD4 791.50 21.50 130.00 778.80 -66.69 79.48 4.00 0.00 -70.675 2020.41 68.87 108.76 1624.49 -417.57 842.06 4.00 -26.53 -460.08 End Dir : 2020.41' MD, 1624.49' TVD6 5025.95 68.87 108.76 2707.78 -1319.22 3496.64 0.00 0.00 -1496.29 Start Dir 4.25º/100' : 5025.95' MD, 2707.78'TVD7 8065.79 85.00 333.21 3978.35 353.57 4729.28 4.25 -115.83 111.28 End Dir : 8065.79' MD, 3978.35' TVD8 8365.79 85.00 333.21 4004.50 620.35 4594.58 0.00 0.00 384.60 M-32 wp02 tgt1 Start Dir 2.5º/100' : 8365.79' MD, 4004.5'TVD9 8557.31 89.79 333.19 4013.21 791.07 4508.34 2.50 -0.24 559.51 End Dir : 8557.31' MD, 4013.21' TVD10 9176.96 89.79 333.19 4015.50 1344.11 4228.86 0.00 0.00 1126.11 M-32 wp02 tgt2 Start Dir 2º/100' : 9176.96' MD, 4015.5'TVD11 9420.55 84.94 333.70 4026.69 1561.71 4120.10 2.00174.05 1348.98 End Dir : 9420.55' MD, 4026.69' TVD12 9434.30 84.94 333.70 4027.91 1573.98 4114.03 0.00 0.00 1361.56 Start Dir 2º/100' : 9434.3' MD, 4027.91'TVD13 9657.08 89.39 333.43 4038.92 1773.17 4014.99 2.00 -3.43 1565.55 End Dir : 9657.08' MD, 4038.92' TVD14 10557.08 89.39 333.43 4048.50 2578.08 3612.45 0.00 0.00 2389.98 M-32 wp02 tgt4 Start Dir 2.5º/100' : 10557.08' MD, 4048.5'TVD15 10723.19 93.36 332.21 4044.51 2725.77 3536.62 2.50 -17.03 2541.36 End Dir : 10723.19' MD, 4044.51' TVD16 10829.19 93.36 332.21 4038.30 2819.39 3487.29 0.00 0.00 2637.38 Start Dir 2.5º/100' : 10829.19' MD, 4038.3'TVD17 10982.18 89.66 333.18 4034.27 2955.26 3417.15 2.50 165.34 2776.66 End Dir : 10982.18' MD, 4034.27' TVD18 12032.18 89.66 333.18 4040.50 3892.29 2943.41 0.00 0.00 3736.69 M-32 wp02 tgt6 Start Dir 2.5º/100' : 12032.18' MD, 4040.5'TVD19 12171.95 86.48 334.64 4045.20 4017.73 2881.98 2.50 155.38 3865.10 End Dir : 12171.95' MD, 4045.2' TVD2012322.73 86.48 334.64 4054.45 4153.72 2817.52 0.00 0.00 4004.22 Start Dir 2.5º/100' : 12322.73' MD, 4054.45'TVD21 12458.38 89.77 333.80 4058.88 4275.78 2758.56 2.50 -14.31 4129.13 End Dir : 12458.38' MD, 4058.88' TVD22 13608.38 89.77 333.80 4063.50 5307.62 2250.83 0.00 0.00 5185.58 M-32 wp02 tgt8 Start Dir 2.5º/100' : 13608.38' MD, 4063.5'TVD23 13764.71 93.66 333.40 4058.83 5447.55 2181.37 2.50 -5.89 5328.88 End Dir : 13764.71' MD, 4058.83' TVD24 13875.36 93.66 333.40 4051.77 5546.29 2131.92 0.00 0.00 5430.02 Start Dir 2.5º/100' : 13875.36' MD, 4051.77'TVD25 14012.60 90.23 333.24 4047.11 5668.83 2070.34 2.50 -177.35 5555.55 End Dir : 14012.6' MD, 4047.11' TVD26 14912.60 90.23 333.24 4043.50 6472.44 1665.11 0.00 0.00 6378.83 M-32 wp02 tgt10 Start Dir 2.5º/100' : 14912.6' MD, 4043.5'TVD27 15103.29 85.46 333.12 4050.66 6642.44 1579.16 2.50 -178.56 6553.00 End Dir : 15103.29' MD, 4050.66' TVD28 15142.29 85.46 333.12 4053.74 6677.11 1561.59 0.00 0.00 6588.53 Start Dir 2.5º/100' : 15142.29' MD, 4053.74'TVD29 15317.40 89.84 333.26 4060.92 6833.24 1482.69 2.50 1.84 6748.48 End Dir : 15317.4' MD, 4060.92' TVD30 16242.40 89.84 333.26 4063.50 7659.31 1066.49 0.00 0.00 7594.76 M-32 wp02 tgt12 Start Dir 2.5º/100' : 16242.4' MD, 4063.5'TVD31 16496.08 96.18 333.14 4050.18 7885.31 952.33 2.50 -1.07 7826.30 End Dir : 16496.08' MD, 4050.18' TVD32 16597.27 96.18 333.14 4039.29 7975.07 906.88 0.00 0.00 7918.26 Start Dir 2.5º/100' : 16597.27' MD, 4039.29'TVD33 16721.85 93.07 333.29 4029.24 8085.90 850.93 2.50 177.26 8031.81 End Dir : 16721.85' MD, 4029.24' TVD34 17071.85 93.07 333.29 4010.50 8398.10 693.84 0.00 0.00 8351.64 M-32 wp02 tgt15 Start Dir 2º/100' : 17071.85' MD, 4010.5'TVD35 17171.80 91.07 333.17 4006.89 8487.28 648.86 2.00 -176.61 8443.00 End Dir : 17171.8' MD, 4006.89' TVD36 17619.01 91.07 333.17 3998.50 8886.29 447.05 0.00 0.00 8851.80 M-32 wp02 tgt16 Start Dir 2.5º/100' : 17619.01' MD, 3998.5'TVD37 17762.28 94.64 333.53 3991.36 9014.15 382.89 2.50 5.76 8982.78 End Dir : 17762.28' MD, 3991.36' TVD38 17796.58 94.64 333.53 3988.59 9044.76 367.65 0.00 0.00 9014.13 Start Dir 2.5º/100' : 17796.58' MD, 3988.59'TVD39 17992.73 89.75 333.14 3981.08 9219.86 279.72 2.50 -175.41 9193.50 End Dir : 17992.73' MD, 3981.08' TVD40 18317.73 89.75 333.14 3982.50 9509.80 132.88 0.00 0.00 9490.56 M-32 wp02 tgt18 Start Dir 2º/100' : 18317.73' MD, 3982.5'TVD41 18508.40 85.95 333.44 3989.65 9679.98 47.25 2.00 175.48 9664.90 End Dir : 18508.4' MD, 3989.65' TVD42 18605.28 85.95 333.44 3996.50 9766.42 4.05 0.00 0.00 9753.43 M-32 wp02 tgt19 Start Dir 2º/100' : 18605.28' MD, 3996.5'TVD43 18785.87 89.55 333.15 4003.59 9927.59 -77.03 2.00 -4.62 9918.54 End Dir : 18785.87' MD, 4003.59' TVD44 19027.69 89.55 333.15 4005.50 10143.33 -186.25 0.00 0.00 10139.59 M-32 wp02 tgt20 Start Dir 2.5º/100' : 19027.69' MD, 4005.5'TVD45 19087.79 91.05 333.13 4005.19 10196.95 -213.40 2.50 -0.70 10194.53 End Dir : 19087.79' MD, 4005.19' TVD46 19166.55 91.05 333.13 4003.74 10267.19 -248.99 0.00 0.00 10266.49 Start Dir 2.5º/100' : 19166.55' MD, 4003.74'TVD47 19328.78 87.00 333.33 4006.50 10411.98 -322.03 2.50 177.20 10414.83 M-32 wp02 tgt2148 19386.68 85.55 333.30 4010.26 10463.61 -347.97 2.50 -179.00 10467.71 End Dir : 19386.68' MD, 4010.26' TVD49 19433.97 85.55 333.30 4013.93 10505.73 -369.15 0.00 0.00 10510.86 Start Dir 2.5º/100' : 19433.97' MD, 4013.93'TVD50 19670.36 91.46 333.13 4020.09 10716.60 -475.59 2.50 -1.70 10726.90 End Dir : 19670.36' MD, 4020.09' TVD51 19850.36 91.46 333.13 4015.50 10877.11 -556.92 0.00 0.00 10891.36 M-32 wp02 tgt23 Total Depth : 19850.36' MD, 4015.5' TVD
-1500
-750
0
750
1500
2250
3000
3750
4500
5250
6000
6750
7500
8250
9000
9750
10500
11250
South(-)/North(+) (1500 usft/in)-2250 -1500 -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250
West(-)/East(+) (1500 usft/in)
M-32 wp02 tgt23
M-32 wp02 tgt21
M-32 wp02 tgt20
M-32 wp02 tgt19
M-32 wp02 tgt18
M-32 wp02 tgt16
M-32 wp02 tgt15
M-32 wp02 tgt12
M-32 wp02 tgt10
M-32 wp02 tgt8
M-32 wp02 tgt6
M-32 wp02 tgt4
M-32 wp02 tgt2
M-32 wp02 tgt1
9 5/8" x 12 1/4"
4 1/2" x 8 1/2"500125015001750200022502500275030003
2
50
3500
3750
4 0 0 0
4 0 1 6
MPU M-32 wp03
Start Dir 3º/100' : 191.5' MD, 191.5'TVD
Start Dir 4º/100' : 441.5' MD, 440.79'TVD
End Dir : 2020.41' MD, 1624.49' TVD
Start Dir 4.25º/100' : 5025.95' MD, 2707.78'TVD
End Dir : 8065.79' MD, 3978.35' TVD
End Dir : 8557.31' MD, 4013.21' TVD
Start Dir 2º/100' : 9176.96' MD, 4015.5'TVD
End Dir : 9420.55' MD, 4026.69' TVD
Start Dir 2º/100' : 9434.3' MD, 4027.91'TVD
End Dir : 9657.08' MD, 4038.92' TVD
Start Dir 2.5º/100' : 10557.08' MD, 4048.5'TVD
End Dir : 10723.19' MD, 4044.51' TVD
Start Dir 2.5º/100' : 10829.19' MD, 4038.3'TVD
End Dir : 10982.18' MD, 4034.27' TVD
Start Dir 2.5º/100' : 12032.18' MD, 4040.5'TVD
End Dir : 12171.95' MD, 4045.2' TVD
Start Dir 2.5º/100' : 12322.73' MD, 4054.45'TVD
End Dir : 12458.38' MD, 4058.88' TVD
Start Dir 2.5º/100' : 13608.38' MD, 4063.5'TVD
End Dir : 13764.71' MD, 4058.83' TVD
Start Dir 2.5º/100' : 13875.36' MD, 4051.77'TVD
End Dir : 14012.6' MD, 4047.11' TVD
Start Dir 2.5º/100' : 14912.6' MD, 4043.5'TVD
End Dir : 15103.29' MD, 4050.66' TVD
End Dir : 15317.4' MD, 4060.92' TVD
Start Dir 2.5º/100' : 16242.4' MD, 4063.5'TVD
End Dir : 16496.08' MD, 4050.18' TVD
Start Dir 2.5º/100' : 16597.27' MD, 4039.29'TVD
End Dir : 16721.85' MD, 4029.24' TVD
Start Dir 2º/100' : 17071.85' MD, 4010.5'TVD
End Dir : 17171.8' MD, 4006.89' TVD
Start Dir 2.5º/100' : 17619.01' MD, 3998.5'TVD
End Dir : 17762.28' MD, 3991.36' TVD
Start Dir 2.5º/100' : 17796.58' MD, 3988.59'TVD
End Dir : 17992.73' MD, 3981.08' TVD
Start Dir 2º/100' : 18317.73' MD, 3982.5'TVD
End Dir : 18508.4' MD, 3989.65' TVD
Start Dir 2º/100' : 18605.28' MD, 3996.5'TVD
End Dir : 18785.87' MD, 4003.59' TVD
Start Dir 2.5º/100' : 19027.69' MD, 4005.5'TVD
End Dir : 19087.79' MD, 4005.19' TVD
Start Dir 2.5º/100' : 19166.55' MD, 4003.74'TVD
End Dir : 19386.68' MD, 4010.26' TVD
Start Dir 2.5º/100' : 19433.97' MD, 4013.93'TVD
End Dir : 19670.36' MD, 4020.09' TVD
Total Depth : 19850.36' MD, 4015.5' TVD
CASING DETAILS
TVD TVDSS MD Size Name
4013.21 3954.71 8558.00 9-5/8 9 5/8" x 12 1/4"
4015.50 3957.00 19850.36 4-1/2 4 1/2" x 8 1/2"
Project: Milne Point
Site: M Pt Moose Pad
Well: Plan: MPU M-32
Wellbore: MPU M-32
Plan: MPU M-32 wp03
WELL DETAILS: Plan: MPU M-32
24.80
+N/-S +E/-W Northing Easting Latitude Longitude
0.00 0.00
6027765.630 534129.770 70° 29' 12.7693 N 149° 43' 15.7663 W
REFERENCE INFORMATION
Co-ordinate (N/E) Reference:Well Plan: MPU M-32, True North
Vertical (TVD) Reference:MPU M-32 as built RKB @ 58.50usft
Measured Depth Reference:MPU M-32 as built RKB @ 58.50usft
Calculation Method:Minimum Curvature
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0.001.002.003.004.00Separation Factor0 450 900 1350 1800 2250 2700 3150 3600 4050 4500 4950 5400 5850 6300 6750 7200 7650 8100 8550Measured Depth (900 usft/in)MPU M-62 wp01MPL-20MPL-32MPU M-10No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.NOERRORSWELL DETAILS:Plan: MPU M-32 NAD 1927 (NADCON CONUS)Alaska Zone 0424.80+N/-S +E/-W Northing EastingLatitudeLongitude0.000.006027765.630534129.77070° 29' 12.7693 N149° 43' 15.7663 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU M-32, True NorthVertical (TVD) Reference: MPU M-32 as built RKB @ 58.50usftMeasured Depth Reference:MPU M-32 as built RKB @ 58.50usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2022-08-18T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool33.70 1500.00 MPU M-32 wp03 (MPU M-32) GYD_Quest GWD1500.00 8558.00 MPU M-32 wp03 (MPU M-32) 3_MWD+IFR2+MS+Sag8558.00 19850.36 MPU M-32 wp03 (MPU M-32) GYD_Quest GWD0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)0 450 900 1350 1800 2250 2700 3150 3600 4050 4500 4950 5400 5850 6300 6750 7200 7650 8100 8550Measured Depth (900 usft/in)MPU M-28MPU M-33 wp03MPU M-30 wp10MPU M-27MPU M-29MPU M-31 wp06NO GLOBAL FILTER: Using user defined selection & filtering criteria33.70 To 19850.36Project: Milne PointSite: M Pt Moose PadWell: Plan: MPU M-32Wellbore: MPU M-32Plan: MPU M-32 wp03Ladder / S.F. Plots1 of 2CASING DETAILSTVD TVDSS MD Size Name4013.21 3954.71 8558.00 9-5/8 9 5/8" x 12 1/4"4015.50 3957.00 19850.36 4-1/2 4 1/2" x 8 1/2"
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0.001.002.003.004.00Separation Factor9000 9750 10500 11250 12000 12750 13500 14250 15000 15750 16500 17250 18000 18750 19500 20250 21000 21750 22500Measured Depth (1500 usft/in)MPF-81MPU M-33 wp03MPU M-62 wp01MPU M-30 wp10MPU M-29MPU M-31 wp06MPF-96MPL-32MPU M-63 wp01No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:Plan: MPU M-32 NAD 1927 (NADCON CONUS)Alaska Zone 0424.80+N/-S +E/-W Northing EastingLatitudeLongitude0.000.006027765.630534129.77070° 29' 12.7693 N149° 43' 15.7663 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU M-32, True NorthVertical (TVD) Reference: MPU M-32 as built RKB @ 58.50usftMeasured Depth Reference:MPU M-32 as built RKB @ 58.50usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2022-08-18T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool33.70 1500.00 MPU M-32 wp03 (MPU M-32) GYD_Quest GWD1500.00 8558.00 MPU M-32 wp03 (MPU M-32) 3_MWD+IFR2+MS+Sag8558.00 19850.36 MPU M-32 wp03 (MPU M-32) GYD_Quest GWD0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)9000 9750 10500 11250 12000 12750 13500 14250 15000 15750 16500 17250 18000 18750 19500 20250 21000 21750 22500Measured Depth (1500 usft/in)NO GLOBAL FILTER: Using user defined selection & filtering criteria33.70 To 19850.36Project: Milne PointSite: M Pt Moose PadWell: Plan: MPU M-32Wellbore: MPU M-32Plan: MPU M-32 wp03Ladder / S.F. Plots2 of 2CASING DETAILSTVD TVDSS MD Size Name4013.21 3954.71 8558.00 9-5/8 9 5/8" x 12 1/4"4015.50 3957.00 19850.36 4-1/2 4 1/2" x 8 1/2"
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