Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Tuesday, February 21, 2023
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Brian Bixby
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
Hilcorp Alaska, LLC
M-31
MILNE PT UNIT M-31
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 02/21/2023
M-31
50-029-23731-00-00
222-119-0
W
SPT
3979
2221190 1500
642 637 640 641
INITAL P
Brian Bixby
1/8/2023
Monobore Completion - No OA
30 MinPretestInitial15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:MILNE PT UNIT M-31
Inspection Date:
Tubing
OA
Packer Depth
120 1701 1639 1615IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitBDB230108151449
BBL Pumped:3.9 BBL Returned:3.6
Tuesday, February 21, 2023 Page 1 of 1
1a. Well Status:Oil SPLUG Other Abandoned Suspended
1b. Well Class:
20AAC 25.105 20AAC 25.110 Development Exploratory
GINJ WINJ WDSPL No. of Completions: _1 Service Stratigraphic Test
2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry:
Aband.:
3. Address: 7. Date Spudded: 15. API Number:
4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number:
Surface:
Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s):
GL: 24.7' BF:
Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation:
4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number:
Surface: x- y- Zone- 4
TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD:
Total Depth: x- y- Zone- 4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 N/A (ft MSL)
22.Logs Obtained:
23.
BOTTOM
20" X-52 114'
L-80 1968'
L-80 4000'
5-1/2"x L-80 4093'
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
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 Slotted Liner8-1/2"
TUBING RECORD
Stg 2 L - 870 sx / T - 270 sx
Liner Top Packer
7491'3-1/2" 9.3# L-80
ROP, AGR, DGR, ABG, EWR, ADR MD & TVD
BOTTOM
21 yds Concrete
Surface Stg 1 L - 696 sx / T - 400 sx
17#/13.5#
Surface
7473'
2601'
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Hilcorp Alaska, LLC
WAG
Gas
11/23/2022 222-119
4912' FSL, 50' FEL, Sec. 14, T13N, R09E, UM, AK
378' FNL, 902' FEL, Sec. 02, T13N, R09E, UM, AK
58.62'
3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503
534115 6028766
396' FSL, 1232' FEL, Sec. 12, T13N, R09E, UM, AK
50-029-23731-00-00
MPU M-31
Milne Point Field / Schrader Bluff Oil Pool
ADL 025514 & 388235
16-004
11/2/2022
11/17/2022
18559' / 4093'
18561' / 4093'
CASING WT. PER
FT.GRADE CEMENTING RECORD
6028549
SETTING DEPTH TVD
6038310
TOP HOLE SIZE AMOUNT
PULLED
538209
533207
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.
2369' / 1847'
N/A
None
Surface
Surface
Per 20 AAC 25.283 (i)(2) attach electronic information
40#
18561'
1968'
3979'
129.5#
47#
114'
2601' 7629'
SIZE DEPTH SET (MD)
7473' / 3979'
PACKER SET (MD/TVD)
42"
Flow Tubing
Water Injection
4-1/2" Slotted Liner 11/20/2022
7650' - 18519' 4002' - 4093'
Gas-Oil Ratio:Choke Size:
Sr Res EngSr Pet GeoSr Pet Eng
Oil-Bbl: Water-Bbl:
Water-Bbl:
PRODUCTION TEST
*Pre-Produced, converted to Injector 12/22/22*
Date of Test: Oil-Bbl:
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
By James Brooks at 8:23 am, Jan 03, 2023
Completed
11/23/2022
JSB
RBDMS JSB 010523
GDSR-1/9/23MGR28JULY2023
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
29' 29'
2398' 1876'
Top of Productive Interval 7563' 3992'
1441' 1337'
2490' 1917'
5320' 3233'
6877' 3810'
7563' 3992'
7563' 3992'
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:
SV5
SV1
Formation Name at TD:
If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if
needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired.
LOT / FIT Data Sheet, Drilling and Completion Reports, Post-Rig Summary, Cement Report, Definitive Directional Survey,
Wellbore Schematic
Schrader Bluff OA
Schrader Bluff OA
Yes No
Well tested? Yes No
28. CORE DATA
If Yes, list intervals and formations tested, briefly summarizing test results for
each. Attach separate pages if needed and submit detailed test info including
reports and Excel or ASCII tables per 20 AAC 25.071.
NAME
Permafrost - Top
Permafrost - Base
29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment; or 90 days after log acquisition, whichever occurs first.
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Ugnu LA3
Schrader Bluff NA
Authorized Title:
Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic
diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from
a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071.
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core
analysis, paleontological report, production or well test results, per 20 AAC 25.070.
Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
TPI (Top of Producing Interval).
Authorized Name and
INSTRUCTIONS
Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
12.31.2022
Digitally signed by Monty M Myers
DN: cn=Monty M Myers, c=US,
o=Hilcorp Alaska, LLC, ou=Technical
Services - AK Drilling,
email=mmyers@hilcorp.com
Reason: I am approving this document
Date: 2022.12.31 12:09:34 -09'00'
Monty M
Myers
_____________________________________________________________________________________
Revised By: JNL 11/28/2022
SCHEMATIC
Milne Point Unit
Well: MPU M-31
Last Completed: 11/23/2022
PTD: 222-119
4-1/2” Slotted Liner Detail
Top
(MD)
Top
(TVD)
Btm
(MD)
Btm
(TVD)
7650’ 4002’ 18519’ 4093’
CASING DETAIL
Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF
20" Conductor 129.5 / X-52 / Weld N/A Surface 114’ N/A
9-5/8" Surface 47 / L-80 / TXP 8.525” Surface 2,601’ 0.0732
9-5/8" Surface 40 / L-80 / TXP 8.679” 2,601’ 7,629’ 0.0758
5-1/2” Solid/Slotted Liner 17 / L-80 / JFE Bear 4.767” 7,473’ 9,554’ 0.0232
4-1/2” Solid/Slotted Liner 13.5 / L-80 / Hyd 625 3.920” 9,554’ 18,561’ 0.0149
TUBING DETAIL
3-1/2" Tubing 9.3 / L-80 / EUE 8RD 2.867” Surface 7,491’ 0.0087
OPEN HOLE / CEMENT DETAIL
42” 21 yds Concrete
12-1/4"Stg 1 –Lead 696 sx / Tail 400 sx
Stg 2 –Lead 870 sx / Tail 270 sx
8-1/2” Cementless Slotted Liner
TREE & WELLHEAD
Tree Cameron 3 1/8" 5M w/ 3-1/8” 5M Cameron Wing
Wellhead FMC 11” 5K x sliplock bottom w/ (2) 2-1/16” 5K outs
GENERAL WELL INFO
API#: 50-029-23731-00-00
Completion Date: 11/23/2022
WELL INCLINATION DETAIL
KOP @ 334’
90° Hole Angle = @ 8,214’ MD
TD =18,561’(MD) / TD =4,093’(TVD)
20”
Orig. KB Elev.: 58.62’ / GL Elev.: 24.7’
3-1/2”
6
2
9-5/8”
1
3
See
Slotted
Liner
Detail
7
PBTD = 18,559’(MD) / PBTD = 4,093’(TVD)
9-5/8” ‘ES’
Cementer @
2,619’
5-1/2” xo
4-1/2”
@ 9,554’
4/5
JEWELRY DETAIL
No Top MD Item
ID
Upper Completion
1 6,220’ Sliding Sleeve 2.813” X profile, covered ports (opens down) 2.813”
2 6,277’ Baker Zenith Gauge Carrier 2.992”
3 6,329’ XN Nipple, 2.813”, 2.75” No-Go 2.750”
4 7,480’ No Go Locater Sub (1.7’ off No-go) 6.140”
5 7,481’ Bullet Seals – TXP Top Box x Mule Shoe 6.140”
Lower Completion
6 7,473’ 9-5/8” SLZXP Liner Top Packer 6.180”
7 18,559’ Shoe
CASING AND LEAK-OFF FRACTURE TESTS
Well Name:MPU M-31 Date:
Csg Size/Wt/Grade:9.625", 40# & 47#, L-80 Supervisor:Yessak/Toomey
Csg Setting Depth:7629 TMD 3999 TVD
Mud Weight:9.3 ppg LOT / FIT Press =561 psi
.
LOT / FIT =12.00 Hole Depth =7654 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
->151 ->498
->372 ->8 245
->5 112 ->12 425
->6 144 ->16 606
->7 198 ->20 819
->8 232 ->24 1038
->9 266 ->28 1263
->10 317 ->32 1459
->11 352 ->36 1691
->12 396 ->40 1910
->13 463 ->44 2109
->14 504 ->48 2347
->15 561 ->53 2616
Enter Holding Enter Holding Enter Holding Enter Holding
Time Here Pressure Here Time Here Pressure Here
->0 561 ->0 2616
->1 541 ->5 2600
->2 537 ->10 2594
->3 531 ->15 2588
->4 528 ->20 2583
->5 526 ->25 2579
->6 524 ->26 2578
->7 522 ->27 2578
->8 520 ->28 2577
->9 518 ->29 2577
->10 515 ->30 2577
->11 515 ->
->12 514 ->
->13 514 ->
->14 514
->15 513
->
0
1 3 5 6
7 8 9
1011
12
13
14
15
0
4
8
12
16
20
24
28
32
36
40
44
48
53
0
100
200
300
400
500
600
700
800
900
1000
1100
1200
1300
1400
1500
1600
1700
1800
1900
2000
2100
2200
2300
2400
2500
2600
2700
2800
2900
3000
0 102030405060
Pr
e
s
s
u
r
e
(
p
s
i
)
Strokes (# of)
LOT / FIT DATA CASING TEST DATA
Pr
e
s
s
u
r
e
(
p
s
i
)
561541537531528526524522520518515515514514514513
2616 2600 2594 2588 2583 257925782578257725772577
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
11/1/2022 Provided 24 hour notice to the AOGCC at 07:55 of upcoming diverter test. Move rig on to M-31, center and level over conductor. Skid rig floor into moving position.
Secure landings and walkways. Spot support buildings and fuel trailer. R/U utilities to the rig floor. Working on rig acceptance check list. Install diverter knife valve
and begin installing diverter line. Finish installing 8' of new AR plate in the #2 conveyor. On highline power at 16:00. Continue acceptance checklist: Rig up beaver
slide, install surface riser and bell nipple. Install drag chain into #2 conveyor trough. Start load, strap & tally 5" DP into ODS pipeshed. Change out saver sub and
inspect grabber dies. Spot Water uprights and cement silos. Install 90' mousehole, hook up lines to pump house, put heater on H2O uprights & load 300 bbls H2O.
Finish load and tally 5" DP. Cont work on nipple up diverter line. Load 290 bbls spud mud to pits.
11/2/2022 P/U and rack back 6 stands 5" HWDP and jars. Finish acceptance checklist & accept Rig @ 06:00M/U 12-1/4" Kymera K5M633 bit, 8" mud motor and XO to 36'.
M/U stand of 5" HWDP and RIH to 66'. Finished last 20' section of diverter line. Finish tallying 225 joints of 5" drill pipe. Completed hooking up water pump to
external upright tank. Clean and clear rig floor. Service draw works and top drive. Perform diverter test - AOGCC inspector Kam St.John on location to witness. 2875
PSI system pressure. 1800 PSI after closure. 35 seconds 200 PSI recovery. 149 seconds full recovery. 1975 PSI 6 nitrogen bottle avg. 14 sec knife valve open / 18
sec annular closure on 5" HWDP Test PVT and flow sensors - good tests. H2S and LEL gas alarms - good tests. Pre-spud meeting with all parties involved. Discuss
safe briefing areas, diverter drill, broaching and subsidence, traffic patterns and parking areas. Discuss flooding lines and pressure testing. Everyone has the stop
work authority. Flood conductor and surface stack with water - no leaks. Fill standpipe and rotary hose with water and pressure test to 3500 PSI - good. Pressure test
Sperry Geo-Span to 2000 PSI. Tag fill in the conductor at 98'. Clean out conductor from 98' to 114' with fresh water. Swap to mud on the fly. Drill 12-1/4" surface hole
from 114' to 219'. 450 GPM = 600 PSI, 40 RPM = 1K, WOB = 2K. MW = 8.85, Vis = 311. BROOH f/ 219' t/ 125' while circulating a bottom up then pull out on
elevators to surface and inspect bit Good. Blow down TopDrive M/U MWD tools with Gyro While Drilling, directional, gamma, resistivity and PWD to 98'. Initialize and
confidence test MWD tools. M/U three NMDC & XO to 189'. Shallow pulse test MWD - Good. Ream to bottom, 30 RPM, 400 GPM - No fill encountered. Drill 12-1/4"
hole from 219' to 466' (465' TVD). Drilled 247' = 44.9'/hr AROP. 400 GPM = 940 PSI, 40 RPM = 1-2K TQ, WOB = 5-10K. MW 9.1 in / 9.1 out, Vis 300 in / 300 out.
PU = 72k, SO = 75k, ROT = 70k. Target 3 deg BUR Drill 12-1/4" hole from 466' to 1029' (1004' TVD). Drilled 563' = 93.83/hr AROP. 450 GPM = 1020 PSI, 40 RPM
= 2-5K TQ, WOB = 5-18K. MW 9.15 in / 9.15 out, Vis 260 in / 300 out. PU = 89k, SO = 92k, ROT = 92k. Target 4 deg BUR Last survey (Gyro) at 894.68 MD /
882.41' TVD, 21.89 inc, 110.94 azm, 11.43 from plan, 0.64 Low and 11.42 Left Daily disposal to G&I = 228 bbls Total disposal to G&I = 228 bbls. Daily water hauled
from 6 Mile = 715 bbls Total water hauled from 6 Mile = 715 bbls. Daily fluid loss = 0 bbls Total fluid loss = 0 bbls.
11/3/2022 Drill 12-1/4" hole from 1029' to 1505' (1378' TVD). Drilled 476' = 79.3/hr AROP. 500 GPM = 1330 PSI, 40 RPM = 3-5K TQ, WOB = 5-10K. MW 9.2, Vis 278, ECD
10.12, max gas= 7u. PU = 92, SO = 88k, ROT = 92k. Target 4 deg/100' Drill 12-1/4" hole from 1505' to 1981' (1662' TVD). Drilled 476' = 79.3/hr AROP. 500 GPM =
1350 PSI, 60 RPM = 3-6K TQ, WOB = 7-10K. MW 9.2, Vis 300, ECD 10.43, max gas= 6u. PU = 95k, SO = 85k, ROT = 92k. Target 4 deg/100'. Drill 12-1/4" surface
hole from 1981' to 2430' (1891' TVD), 449' drilled, 74.83'/hr AROP. 500 GPM, 1490 PSI, 40 RPM, 4-7k Tq, 5-10K WOB. 9.4 ppg MW, 211 vis, 10.27 ECD, 145u
max gas. 100K PU / 83K SO / 92K ROT. EOB at 2156'. Hi vis sweep @ 2552 back on time with a 25% increase Trouble getting build f/ 1886' t/ 2026'. Two
consecutive surveys, 1st with a 50 slide interval & next with a full std slide, showed an inc drop of 1.29 deg & 0.61 deg respectively before assembly start a build
trend. Closest AC was 24.3 @ 2200 MD with 2.4 CF. BOPF logged at 2,398 MD, 1,876' TVD Drill 12-1/4" surface hole from 2430' to 3175', (2226' TVD). 745' drilled,
124.17/hr AROP. 500 GPM, 1680 PSI, 80 RPM, 6-8k Tq, 5-8K WOB. 9.45 ppg MW, 180 vis, 10.15 ECD, 43u max gas. 110K PU / 85K SO / 94K ROT. Maintain 62
deg tangent. Last Gyro survey at 1657.18 MD / 1481.99' TVD then swap to MWD. Last Survey at 3070.03 MD / 2176.97 TVD, 9.47 inc, 105.33 azm, 9.47 from plan,
3.21 High and 8.91 Left Daily disposal to G&I = 1207 bbls Total disposal to G&I = 1435 bbls. Daily water hauled from 6 Mile = 1095 bbls Total water hauled from 6
Mile = 1810 bbls. Daily fluid loss = 0 bbls Total fluid loss = 0 bbls.
11/4/2022 Drill 12-1/4" surface hole from 3175' to 3217', (2247' TVD). 42' drilled, 84'/hr AROP. 500 GPM, 1680 PSI, 80 RPM, 6-8k Tq, 5-8K WOB. 9.45 ppg MW, 180 vis,
10.15 ECD, 4u max gas. 110K PU / 85K SO / 94K ROT. Maintain 61.5 deg tangent Coupler came off #1 drag chain drive motor, pump 400 GPM, 1080 PSI, 60 RPM,
working pipe 90' while installing new coupler on drag chain. Drill 12-1/4" surface hole from 3217' to 3312', (2292' TVD). 95' drilled, 63.3'/hr AROP. 500 GPM, 1590
PSI, 80 RPM, 5-9k Tq, 11-13K WOB. 9.45 ppg MW, 167 vis, 10.58 ECD, 6u max gas. 113K PU / 85K SO / 98K ROT. Maintain 61.5 deg tangent New coupler failed
on #1 drag chain drive motor, pump 400 GPM, 1060 PSI, 40 RPM, working pipe 90' while installing new coupler and adjusting drag chain tension. Drill 12-1/4"
surface hole from 3312' to 3979', (2610' TVD). 667' drilled, 102.61'/hr AROP. 500 GPM, 1570 PSI, 80 RPM, 6-10k Tq, 2-12K WOB. 9.4 ppg MW,169 vis, 10.27
ECD,35u max gas. 130K PU / 85K SO / 105K ROT Maintain 61.5 deg tangent. Geo reports upper Ugnu came in at 3073' MD, 2221' TVD. Pump 30 bbl hi vis sweep
@ 3504', back on time w/ 30% increase Drill 12-1/4" surface hole from 3979' to 4385', (2798' TVD). 406' drilled, 67.66'/hr AROP. 525 GPM, 1910 PSI, 80 RPM, 7-
13k Tq, 1-13K WOB. 9.4 ppg MW, 162 vis, 10.47 ECD, 145u max gas. 135K PU / 87K SO / 107K ROT. Maintain 61.5 deg tangent Drill 12-1/4" surface hole from
4385' to 4931', (3065' TVD). 546' drilled, 91/hr AROP. 525 GPM, 2020 PSI, 80 RPM, 11-16k Tq, 9-11K WOB. 9.4 ppg MW, 135 vis, 10.30 ECD, 48u max gas. 150K
PU / 85K SO / 115K ROT. Start 5 deg/100 build & turn @ 4800' Hi vis sweep @ 4550' back on time with a 25% increase. Last Survey, 4783.88' MD / 2994.41' TVD,
61.24 inc, 104.02 azm, 4.75' from plan, 3.32' High and 3.39' Right Daily disposal to G&I = 1150 bbls Total disposal to G&I = 2585 bbls. Daily water hauled from 6
Mile = 1110 bbls Total water hauled from 6 Mile = 2920 bbls. Daily fluid loss = 0 bbls Total fluid loss = 0 bbls.
11/5/2022 Drill 12-1/4" surface hole from 4931' to 5407', (3271' TVD). 476' drilled, 79.3/hr AROP. 525 GPM, 1930 PSI, 80 RPM, 13-16k Tq, 7k WOB. 9.3 ppg MW, 135 vis,
10.2 ECD, 31u max gas. 165k PU / 82k SO / 114k ROT. Build and turn 5 deg/100' LA3 sand logged at 5320' md, 3233' tvd. Drill 12-1/4" surface hole from 5407' to
5572', (3333' TVD). 165' drilled, 55/hr AROP. 490 GPM, 1750 PSI, 80 RPM, 15-17k Tq, 6k WOB. 9.3 ppg MW, 124 vis, 10.13 ECD, 132u max gas. 167k PU / 80k
SO / 115k ROT. Build and turn 5 deg/100' Pump 30 bbl hi vis sweep @ 5503', Due to the shakers blinding off sweep was not seen at surface. Shakers blinding off
bad with fine sand and oil, stop drilling and slow pump rate to 350 gpm, 1020 psi working pipe 70', screen shakers down from 120s to 100s then to 80s to handle the
350 gpm while adding screenkleen to system. Increase pump rate to 510 gpm, 1700 psi. Drill 12-1/4" surface hole from 5572' to 5680', (3377' TVD). 108' drilled,
70'/hr AROP. 500 GPM, 1800 PSI, 80 RPM, 13-17k Tq, 8k WOB. 9.3 ppg MW, 197 vis, 10.0 ECD, 25u max gas. 160k PU / 87k SO / 117k ROT. Build and turn 5
deg/100'. Drill 12-1/4" surface hole from 5680' to 6072', (3546' TVD). 392' drilled, 65.33/hr AROP. 500 GPM, 1940 PSI, 80 RPM, 14-17k Tq, 5-8K WOB. 9.3 ppg
MW, 93 vis, 10.2 ECD, 71u max gas. 173K PU / 85K SO / 125K ROT. Build and turn 5 deg/100'. Drill 12-1/4" surface hole from 6072' to 6375', (3660' TVD). 303'
drilled, 50.5'/hr AROP. 515 GPM, 2160 PSI, 80 RPM, 17-19k Tq, 10-13K WOB. 9.3 ppg MW, 220 vis, 10.20 ECD, 107u max gas. 185K PU / 75K SO / 125K ROT.
Build and turn 5 deg/100'. Last Svy, 6305.23' MD / 3634.81' TVD, 67.59 inc, 22.78 azm, 11.77' from plan. 0.71' Low and 11.71 Right Daily disposal to G&I = 1233
bbls Total disposal to G&I = 3818 bbls. Daily water hauled from 6 Mile = 1410 bbls Total water hauled from 6 Mile = 4330 bbls. Daily fluid loss = 0 bbls Total fluid
loss = 0 bbls.
50-029-23731-00-00API #:
Well Name:
Field:
County/State:
MP M-31
Milne Point
Hilcorp Energy Company Composite Report
, Alaska
11/2/2022
Job Name:221-00104.04 MPU M-31 Drilling
Spud Date:
11/6/2022 00:00-06:00 time includes 1 extra hour for daylight savings adjustment. Difficult sliding from 6262 to 6297. Experiencing motor stalls due to wt slipping off after
stacking up. Drill 12-1/4" surface hole from 6375' to 6568'', (3721' TVD). 193' drilled, 32.16'/hr AROP. 525 GPM, 2250 PSI, 80 RPM, 15k Tq, 9-15K WOB. 9.3 ppg
MW, 147 vis, 10.1 ECD, 31u max gas. 177K PU / 85K SO / 125K ROT. Build and turn 5 deg/100'. At 6390' add 2 drums 776 lube in the system to assist with sliding.
Pump 30 bbl hi vis sweep @ 6548', back on time, 20% increase. Drill 12-1/4" surface hole from 6568' to 6796', (3781' TVD). 228' drilled, 38'/hr AROP. 500 GPM,
2010 PSI, 80 RPM, 15-17k Tq, 9-11K WOB. 9.2 ppg MW, 92 vis, 9.95 ECD, 9u max gas. 173K PU / 85K SO / 123K ROT. Build and turn 5 deg/100' Drill 12-1/4"
surface hole from 6796' to 6976', (3842' TVD). 180' drilled, 30'/hr AROP. 500 GPM, 1950 PSI, 80 RPM, 18-20k Tq, 20-23K WOB. 9.3 ppg MW, 119 vis, 10.14 ECD,
57u max gas. 177K PU / 83K SO / 125K ROT. Build and turn 5 deg/100'. Top of SB_NA logged at 6877 MD, 3810 TVD. Drill 12-1/4" surface hole from 6976' to
7340', (3948' TVD). 364' drilled, 60'/hr AROP. 515 GPM, 1980 PSI, 80 RPM, 17k Tq, 18K WOB. 9.35 ppg MW, 77 vis. 10.28ECD, 409u max gas. 182K PU / 83K
SO / 127K ROT. Build and turn 5 deg/100'. Last Survey, 7258.12 MD / 3929.43 TVD, 75.42 inc, 331.80 azm, 7.16 from plan, 7.01 High and 1.49 Left Daily disposal
to G&I = 1269 bbls Total disposal to G&I = 5087 bbls. Daily water hauled from 6 Mile = 1170 bbls Total water hauled from 6 Mile = 5500 bbls. Daily fluid loss = 0 bbls
Total fluid loss = 0 bbls.
11/7/2022 Drill 12-1/4" surface hole from 7340' to 7598', (3994' TVD). 258' drilled, 43'/hr AROP. 557 GPM, 2160 PSI, 60 RPM, 17k Tq, 15K WOB. 9.4 ppg MW, 64 vis, 10.1
ECD, 84u max gas. 186K PU / 83K SO / 127K ROT. Build and turn 5 deg/100'. Difficult sliding, add 2 drums 776 lube to help with weight to bit transfer and with stick
slip rotating Drill 12-1/4" surface hole from 7598' to 7634' at TD in the OA (4000' TVD). 36' drilled. 557 GPM, 2160 PSI, 60 RPM, 17k Tq, 15K WOB. 9.4 ppg MW,
58 vis, 10.1 ECD, 257u max gas. 186K PU / 83K SO / 127K ROT Top of the OA sand logged at 7563' (3992' TVD) landed out 8' TVD below the OA top @ 85.5 deg.
Final survey at 7581.22 MD / 3994.13 TVD, 82.33 INC, 327.53 AZM. Distance from WP 09= 7.10'/ 0.68' high & 7.07' left. Rack stand back to 7589', pump 30 bbl hi
vis sweep cleaning up the wellbore at 550 gpm, 1910 psi, 60 rpm, 16-17k TQ, sweep back on time with 10% increase, condition the mud, 9.35 ppg MW, 51 vis, YP
at 19. wash from 7505' back to bottom, no fill. Set MWD mode switch to Gyro. BROOH from 7634' to 3886' pulling 5-10 minutes/stand slowing as needed to clean
slides/tight spots. 550 GPM = 1550 psi, 60 RPM = 15-18K ft-bs TQ, max gas = 269 units. PU = 135K, SO = 84K, ROT = 105K BROOH from 3886' to 746' pulling 5-
10 minutes/stand slowing as needed to clean slides/tight spots. 500 GPM = 1075 psi, 80 RPM = 5K ft-bs TQ, max gas = 233 units. PU = 90K, SO = 82K, ROT =
85K. Reduce pulling speed to CBU from 2550' to 2400' and 2x BU while pulling last stand of DP. Flow check the well at the HWDP and the well is static, POOH on
elevators from 746' to 650' racking back HWDP. 28 bbls loss recorded while BROOH. Daily disposal to G&I = 1041 bbls Total disposal to G&I = 6128 bbls. Daily
water hauled from 6 Mile = 1310 bbls Total water hauled from 6 Mile = 6810 bbls. Daily fluid loss = 0 bbls Total fluid loss = 0 bbls.
11/8/2022 Continue to POOH on elevators from 650' to 191' racking back HWDP and jar stand. LD crossover and flex collars to 98'. Download MWD and LD remaining BHA.
28 bbls losses BROOH. 12-1/4'' bit grade = PDC: 1-3-BT-T-X-2-CT-TD & Tri-cone grade: 2-2-WT-A-E-2-NO-TD. Observed excessive wear on top edge of motor
stabilizer and normal wear on ILS. Load out BHA tools, clear and clean the rig floor, Flush/clean the flowline RU the volante tool, bail extensions, 9-5/8'' handling
equipment and DDI casing tongs. Ready FOSV and crossover. Loss rate 3 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 166' to 2867'. PU =
180K & SO = 90K. TQ = 21K ft-lbs with Volant tool. Fill on the fly and top off every 10 joints. Installing centralizer per tally. Loss rate = 6-7 BPH. Circulate bottoms up,
staging pump up from 3 BPM to 5 BPM = 200 psi, reciprocating string 40'. RIH with 9-5/8", 40# casing from 2867' to 4906'. PU = 215K & SO = 100K. TQ = 21K ft-
lbs with Volant tool. Fill on the fly and top off every 10 joints. Installing centralizer per tally. Loss rate = 3-7 BPH Circulate one casing volume, stage up to 6 BPM =
250 psi reciprocating 40'. RIH with 9-5/8", 40# casing from 4,906' to 5007'. MU the ES cementer and BakerLok the connections to 5027'. TQ = 21K ft-lbs with Volant
tool. Fill on the fly and top off every 10 joints. Installing centralizer per tally. RIH with 9-5/8", 40# casing from 4,906' to 5007'. MU the ES cementer (6x brass screws
set for 3300 psi shear) and BakerLok the connections to 5027'. TQ = 21K ft-lbs with Volant tool. Fill on the fly and top off every 10 joints. Installing centralizer per tally.
RIH with 9-5/8", 47# casing from 5027' to 5313'. TQ = 24K ft-lbs with Volant tool. Fill on the fly and top off every 10 joints. Installing centralizer per tally. Loss rate = 3
BPH. Daily disposal to G&I = 461 bbls Total disposal to G&I = 6589 bbls. Daily water hauled from 6 Mile = 450 bbls Total water hauled from 6 Mile = 7260 bbls. Daily
fluid loss = 97 bbls Total fluid loss = 97 bbls.
11/9/2022 RIH with 9-5/8", 47# casing from 5,313' to 7,570' at joint #62, TQ = 24K ft-lbs with Volant tool. Fill on the fly and top off every 10 joints. Installing centralizer per tally.
Wash last 2 joints down to 7,629' at 2 BPM, 380 psi. Verify pipe count. PU= 325K, SO= 105K. Lost 123.5 bbls RIH. Stage pumps slowly to 6 BPM = 300 psi, while
working the string from 7,629' to 7605'. Set TD torque at 18K, establish rotation at 1-2 RPM = 18K TQ while working pipe. Spot and RU cementers. Condition the
mud for cementing, Final 6 BPM = 140 psi with MW 9.3+ ppg, YP = 18. 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 = 300 psi. Blow air to cement unit. Finish getting the pits ready. No losses circulating.
Continue to circulate, 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, plug valve on volante to cement hose not holding. Bleed off and C/O same, flood line, re-tested good. Pump 1st stage cement job: Mix & pump 60
bbls of 10 ppg tuned spacer with 4# red dye & 5# Pol-E-Flake in 1st 10 bbls at 4 BPM = 250 psi. Drop bypass plug. Mix and pump 291 bbls of 12.0 ppg lead cement
(Type I-II cement, 2.347ft^3/sk yield, 696 sks total) at 4 BPM = 314 psi. Mix & pump 82 bbls 15.8 ppg Premium G tail cement (1.156 ft^3/sk yield, 400 sks total) at 3
BPM = 420 psi. Rotate 1-2 RPM = 18K TQ & reciprocate 25'. Drop shutoff plug. HES pump 20 bbls water at 2 BPM = 334 psi. Displace with 341.5 bbls (3381
strokes) 9.35 ppg spud mud from rig at 6 BPM =180 psi Displace with 80 bbls 9.4 ppg Tuned Spacer from HES at 6 BPM = 634 psi. Continue to displace with 9.35
ppg mud from the rig at 6 BPM = 600 psi ICP, slow to 3 bpm for last 10 bbls, FCP 600 psi. Rotated and reciprocated until the last 10 bbls. Bumped plugs at 4,583
strokes (0.8 bbls early). Pressured up to 1,100 psi, hold for 5 minutes, bleed off pressure, check floats and floats held. Pressure up to 3,100 psi to shift the ES
cementer open. CIP at 20:30. Pump through ES cementer at 2,619' at 6 BPM = 250 psi. Dumped 60 bbls of tunned spacer, 103.5 bbls of cement and 172 bbls of
clabbered mud to the rock washer before taking returns to the pits. Circulated total of 5 BU. Disconnect knife valve from accumulator. Drain stack and flush with black
water two times. Re-connect knife valve to the accumulator. Circulate through the ES cementer at 2,619' stagging the pumps up to 6 BPM = 480 psi Daily disposal to
G&I = 1,122 bbls Total disposal to G&I = 7,711 bbls. Daily water hauled from 6 mile = 340 bbls Total water hauled from 6 mile = 7,600 bbls. Daily fluid loss = 205.5
bbls Total fluid loss = 302.5 bbls.
Mix & pump 82 bbls 15.8 ppg Premium G tail cement (
103.5 bbls of cement
Total fluid loss = 302.5 bbls
Mix and pump 291 bbls of 12.0 ppg lead cement
(Type I-II cement, 2.347ft^3/sk yield, 696 sks total
Bumped plugs
11/10/2022 Continue to circulate through the ES cementer at 2,619' pumping 3 BPM = 110 psi the alternating to 6 BPM = 380 psi every 10 min, while prepping for 2nd stage.
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, W/O last load of water to arrive. 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 4.2 BPM = 315 psi. Mix & pump total 446 bbls 10.7 ppg Arctic Cem lead cement (870 sx
at 2.883 ft^3/sk yield) at 5 BPM, ICP= 450, FCP= 650 psi. At 276 bbls pumped start seeing spacer, dump returns to rock washer. Mix & pump 56 bbls of 15.8 ppg
Premium G tail cement (270 sx at 1.17 ft^3/sk yield) at 3.7 BPM= 580 psi. Drop the closing plug. Pump 20 bbls of 8.34 ppg fresh water at 8.5 BPM = 1,100 psi.
Displace with 173.4 bbls 9.4 ppg spud mud at 6 BPM = 430 psi ICP, last 10 bbls slow to 5 BPM = 750 psi FCP. Bumped the plug at 1,717 strokes, 1.3 bbls over
calculated, CIP at 11:43. 60 BBLS spacer, 141 bbls of interface and 279 bbls good 10.7 ppg cement returned, 100% returns during job. Pressure to 2,330 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= 17.89'. Pull the riser and reposition the annular. Welder
dressed the casing stump. ND diverter stack/tee and remove from cellar. ND the diverter line. SimOps: clean the mud pits. NU the slip lock casing head. 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. Install adapter and spacer spool. NU the BOP
stack. Install turn buckles and MPD riser. NU the kill line. Install annular hydraulic hoses. Obtain RKB's. MU top drive test sub. Service the top drive. RU BOPE
testing equipment. Changeout the seal ring and install the test plug. Flood the stack, lines and choke manifold with fresh water. Purge air from the system. Shell test
the BOP stack to 250/3,000 psi (passed). Conduct initial BOPE test to 250/3,000 psi: UPR (4-1/2 x 7 VBR) with 4-1/2 & 5-1/2 test joint. LPR (2-7/8 x 5 VBRs) with 3-
1/2 & 5 test joints, annular with 3-1/2 test joint, accumulator drawdown test and test gas alarms. All tests performed with fresh water against test plug. The states right
to witness was waived by AOGCC inspector Guy Cook via email on 11/10/22 at 17:41 hours. Tests: 1. Annular with 3-1/2 test joint, 3 Demco kill, 5 TIW, choke valves
1, 12, 13 & 14 (passed). 2. LPR with 3-1/2 test joint, HCR kill, 5 Dart valve (passed). 3. UPR with 4-1/2 test joint, HCR kill, choke valves 9 & 11 (passed). Daily
disposal to G&I = 1,739 bbls Total disposal to G&I = 9,450 bbls. Daily water hauled from 6 mile = 415 bbls Total water hauled from 6 mile = 8,015 bbls. Daily fluid
loss = 8 bbls Total fluid loss = 310.5 bbls.
11/11/2022 Continue to conduct initial BOPE test to 250/3,000 psi: 4. UPR with 5-1/2 test joint, upper IBOP, manual kill, choke valves 5, 8 & 10 (passed). 5. Lower IBOP, choke
valves 4, 6 & 7 (passed). 6. Choke valve 2 (passed). 7. HCR choke (passed). 8. Manual choke (passed). 9. LPR with 5" test joint (passed). 10. Blind rams, choke
valve 3 (passed). 11. Manual adjustable choke (passed). 12. Hydraulic super choke (passed). Accumulator Test: System pressure = 3,000 psi. Pressure after closure
= 1,700 psi. 200 psi attained in 40 seconds. Full pressure attained in 176 seconds. Nitrogen Bottles - 6 at 1,967 psi. Rig electrician calibrate and test rig gas alarms.
No failures. RD BOP testing equipment. BD the choke manifold, kill lines. Install the 9-3/16" ID wear bushing. Change elevators to 5''. Mobilize tools to the rig floor.
PJSM for BHA. MU cleanout BHA, 8-1/2'' Tricone bit, 1.5 deg motor, 5 stands 5" HWDP with jar stand to 587'. TIH with cleanout BHA from 587' to 2,491'. PU = 107K
& SO = 76K. Fill pipe. Wash down at 3 BPM = 350 psi from 2,491' to tag at 2,611', Drill cement from 2,611' to 2,616', Drill plugs and ES cementer from 2,616' to
2,621' at 400 GPM = 700 psi, 30 RPM = 5-7K ft-lbs TQ, WOB = 3-6K. Wash and ream through the ES cementer 3 times and drift through clean without pump/rotary.
Continue to wash and ream down cleaning up cement stringers from 2,621' to 2,870' at 400 GPM = 680 psi, 30 RPM = 5-6K ft-lbs TQ, WOB = 3-5K Blow down the
top drive. TIH with cleanout BHA from 2,870' to 7,439' filling DP every 2,000'. PU = 250K & SO = 67K. Wash down from 7,439' to 7,490' at 300 GPM = 780 psi.
Observed soft cement and a few stringers but no hard cement. Stand back 1 stand of DP to 7,439'. CBU at 450 GPM = 1,150 psi, 30 RPM = 20K ft-lbs TQ with
reciprocating 90'. Blow down the top drive. RU testing 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 RD testing equipment. Pumped 5.3 bbls & bled back 5.0 bbls Wash and ream down from 7,490' to tag on the
baffle adapter plugs at 7,502'. Drill out plugs and baffle adapter from 7,502' to 7,504' tagging hard cement. Continue to drill cement and 9-5/8" shoe track from 7,504'
to 7,629' at 440 GPM = 1,250 psi, 30 RPM = 18K ft-lbs TQ, WOB = 7-9K. PU = 225K, SO = 75K & ROT = 125K. All equipment on depth. Drill rat hole from 7,629' to
7,634'. Drill 20' of new formation from 7,634' to 7,654' at 440 GPM = 1,250 psi, 30 RPM = 18K ft-lbs TQ, WOB = 5-7K PU into the 9-5/8" casing shoe at 7,629'.
Circulate and condition the mud at 440 GPM = 1,050 psi, 30 RPM = 18K ft-lbs TQ, reciprocating 65' until good 9.3 ppg MW in/out. Max gas = 376 units. Parked at
7,625'. RU test equipment. Fill lines, purge air and close the UPR. Perform FIT to 12 ppg EMW with casing shoe at 7,629' (3,999' TVD) with 9.3 ppg MW and 561
psi applied at surface (good test). Bleed off pressure and open UPR. Pumped 1.3 bbls and bled back 1.3 bbls. Blow down and RD testing equipment. Observe the
well for flow - static. Pump 30 bbl dry job and blow down the top drive. TOOH with cleanout BHA from 7,625' to 5,533'. Daily disposal to G&I = 171 bbls Total
disposal to G&I = 9,622 bbls. Daily water hauled from 6 mile = 355 bbls Total water hauled from 6 mile = 8,370 bbls. Daily fluid loss = 0 bbls Total fluid loss = 310.5
bbls. Daily metal recovered = 13 lbs Total metal recovered = 13 lbs.
11/12/2022 Continue to TOOH with cleanout BHA from 5,533' to 5200'. TOOH from 5,200' to 587' utilizing the mud bucket due to pulling very wet. LD excess HWDP and rack
the jar stand in the derrick. LD the cleanout BHA. 8-1/2'' tri-cone bit grade: 1-1-WT-A-E-1-NO-BHA. 18 bbl losses recorded on TOOH. Clear and clean the rig floor.
Mobilize BHA components to the rig floor. Remove the master bushing and install the split bushings. Monitor the well, 0.5 BPH loss rate PJSM, MU 8-1/2" NOV PDC
bit, NRP-A2 bit sleeve, 7600 Geo-Pilot, LWD (ADR & DGR), MWD (PWD & GWD) directional tools, stabilizer and NM float sub to 97'. initialize MWD, good. Finish
making up BHA #3: 3 NM flex collars, NM float sub, 5" HWDP and jar to 294' TIH with stands 5'' DP from 294' to 2,198'. PU = 100K & SO = 75K Fill pipe. Shallow
pulse test MWD at 414 GPM = 840 psi. Break in the Geo Pilot seals. Blow down the top drive. TIH with lateral BHA from 2,198' to 7,335'. PU = 260K & SO = 60K. No
losses while TIH. RIH with 5" DP from the pipe shed from 7,335' to 7,620'. 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 9.3 ppg spud mud to 8.8 ppg FloPro at 6 BPM = 680 psi (ICP), 30 RPM = 18K ft-lbs TQ. PU = 260K, SO = 60K &
ROT = 120K. After displacement 6 BPM = 480 psi (FCP), 30 RPM = 11K ft-lbs TQ. PU =195K, SO = 95K & ROT = 125K. Stand back 1 stand and blow down the top
drive. PJSM. Slip and cut 73' of drilling line. Inspect break linkage. Service the top drive and draw works. Inspect saver sub and calibrate block height. Obtain SPR's.
SimOps: Clean pit 4 and under shaker. Monitor the well with MPD - no pressure build. Wash and ream to bottom at 7,654' (no fill). Drill 8-1/2" lateral from 7,654' to
7,811' (4,014' TVD). Drilled 157' = 78.5'/hr AROP. 500 GPM = 1,270 psi, 120 RPM = 11K ft-lbs TQ, WOB = 10-12K. PU = 150K, SO = 98K & ROT = 120K. MW =
8.8 ppg, Vis = 38, ECD = 9.87 ppg, max gas = 347 units. MPD choke full open while drilling and trapping 0 psi on connections. Drilling down targeting 86 deg
through the OA-1 to the OA-3 Daily disposal to G&I = 342 bbls Total disposal to G&I = 9,964 bbls. Daily water hauled from 6 mile = 300 bbls Total water hauled from
6 mile = 8,670 bbls. Daily fluid loss = 0 bbls Total fluid loss = 310.5 bbls. Daily metal recovered = 12 lbs Total metal recovered = 25 lbs.
Mix & pump total 446 bbls 10.7 ppg Arctic Cem lead cement
Bumped the plug
279 bbls good 10.7 ppg cement returned
Mix & pump 56 bbls of 15.8 ppg
Premium G tail cement
100% returns during job
11/13/2022 Drill 8-1/2" lateral from 7,811' to 8,314' (4,022' TVD). Drilled 503' = 83.8'/hr AROP. 502 GPM = 1,420 psi, 120 RPM = 14K ft-lbs TQ, WOB = 8K. PU = 151K, SO =
86K & ROT = 117K. MW = 8.9 ppg, Vis = 38, ECD = 9.9 ppg, max gas = 778 units Drill down targeting 86 deg entering the OA-3 at 7,765' and leveled out targeting
89 deg. Drill in the OA-3 until planned undulation up at 8,105'. At 8,300' maintain 50 psi choke pressure while drilling and trap 80 psi during connections. Drill 8-1/2"
lateral from 8,314' to 8,744' (4,007' TVD). Drilled 430' = 71.7'/hr AROP. 500 GPM = 1,490 psi, 120 RPM = 12K ft-lbs TQ, WOB = 10-15K. PU = 145K, SO = 88K &
ROT = 117K. MW = 8.9 ppg, Vis = 36, ECD = 10.12 ppg, max gas = 750 units MPD holding 115 psi with the choke while drilling and trapping 85 psi during
connections. Exited the OA-3 at 8,410', entered the OA-1 at 8,479' and leveled off at 90 deg. Pump 30 bbl hi-vis sweep at 8,665', back on time with 100% increase.
Drill 8-1/2" lateral from 8,744' to 9,221' (4,015' TVD). Drilled 477' = 79.5'/hr AROP. 530 GPM = 1,700 psi, 120 RPM = 8K ft-lbs TQ, WOB = 10-15K. PU = 145K, SO
= 90K & ROT = 115K. MW = 9.0 ppg, Vis = 35, ECD = 10.14 ppg, max gas = 559 units MPD choke full open while drilling and trapping 90 psi on connections. Drill 8-
1/2" lateral from 9,221' to 10,000' (4,030' TVD). Drilled 779' = 129.8'/hr AROP. 544 GPM = 1,860 psi, 130 RPM = 11K ft-lbs TQ, WOB = 11-13K. PU = 149K, SO =
84K & ROT = 118K. MW = 9.0+ ppg, Vis = 38, ECD = 10.4 ppg, max gas = 633 units MPD choke full open while drilling and trapping 90 psi on connections. Begin
planned undulation down at 9,400' targeting 87 deg. Exited the OA-1 at 9,450', entered the OA-3 at 9,670' and leveled off at 90 deg. Pump 30 bbl hi-vis sweep at
9,619', back on time with 100% increase. Drilled 21 concretions for a total thickness of 233 (10.5% of the lateral). Last survey at 9,833.37 MD / 4,030.16 TVD, 88.80
INC, 334.20 AZM. Distance from WP09 = 11.14, 7.57 high & 8.17 right. Daily disposal to G&I = 777 bbls Total disposal to G&I = 10,399 bbls. Daily water hauled
from 6 mile = 335 bbls Total water hauled from 6 mile = 9,005 bbls. Daily fluid loss = 0 bbls Total fluid loss = 310.5 bbls. Daily metal recovered = 14 lbs Total metal
recovered = 39 lbs.
11/14/2022 Drill 8-1/2" lateral from 10,000' to 10,666' (4,043' TVD). Drilled 666' = 111'/hr AROP. 553 GPM = 1,960 psi, 130 RPM = 11K ft-lbs TQ, WOB = 13K
PU = 157K, SO = 70K & ROT = 117K. MW = 8.9 ppg, Vis = 41, ECD = 10.6 ppg, max gas = 591 units MPD choke full open while drilling and trapping 90 psi on
connections. Drill in the OA-3 targeting 90 deg. Pump 30 bbl hi-vis sweep at 10,664', back on time with 10% increase. Drill 8-1/2" lateral from 10,666' to 11,331'
(4,030' TVD). Drilled 665' = 110.8'/hr AROP. 550 GPM = 2,040 psi, 130 RPM = 11K ft-lbs TQ, WOB =10-15K. PU = 155K, SO = 75K & ROT = 111K
MW = 9 ppg, Vis = 40, ECD = 10.7 ppg, max gas = 478 units MPD choke full open while drilling and trapping 90 psi on connections. Drill in the OA-3 to planned
undulation up at 10,900'. Exited the OA-3 at 10,964' and entered the OA-1 at 11,150' leveling off at 90 deg. Drill 8-1/2" lateral from 11,331' to 11,934' (4,029' TVD).
Drilled 665' = 110.8'/hr AROP. 550 GPM = 2,150 psi, 120 RPM = 10K ft-lbs TQ, WOB =10K. PU = 155K, SO = 73K & ROT = 110K. MW = 9 ppg, Vis = 42, ECD =
10.8 ppg, max gas = 495 units MPD choke full open while drilling and trapping 90 psi on connections. Pump 30 bbl hi-vis sweep at 11,618', back on time with 50%
increase. Drill 8-1/2" lateral from 11,934' to 12,664' (4,052' TVD). Drilled 730' = 121.7'/hr AROP. 550 GPM = 2,060 psi, 130 RPM = 13K ft-lbs TQ, WOB =10-15K.
PU = 17K, SO = 55K & ROT = 112K. MW = 9 ppg, Vis = 39, ECD = 10.8 ppg, max gas = 534 units MPD choke full open while drilling and trapping 90 psi on
connections. Drill in the OA-1 to planned undulation down at 11,910'. Exited the OA-1 at 12,137' and entered the OA-3 at 12,253' leveling off at 90 deg. Drilled 42
concretions for a total thickness of 413 (8.5% of the lateral). Last survey at 12,495.70 MD / 4,054.92 TVD, 89.50 INC, 331.38 AZM. Distance from WP09 = 30.76,
15.49 low & 26.58 right. Daily disposal to G&I = 742 bbls Total disposal to G&I = 11,481 bbls. Daily water hauled from 6 mile = 370 bbls Total water hauled from 6
mile = 9,375 bbls. Daily fluid loss = 0 bbls Total fluid loss = 310.5 bbls. Daily metal recovered = 9.5 lbs Total metal recovered = 48.5 lbs.
11/15/2022 Drill 8-1/2" lateral from 12,664' to 13,233' (4,072' TVD). Drilled 569' = 94.8'/hr AROP. 540 GPM = 2,140 psi, 130 RPM = 12K ft-lbs TQ, WOB = 5-12K. PU = 161K,
SO = 0K & ROT = 111K. MW = 8.9 ppg, Vis = 45, ECD = 10.9 ppg, max gas = 484 units MPD choke full open while drilling and trapping 90 psi on connections.
Crossed fault #1 at 12,625' with 9' DTW faulting from lower OA-3 into the base of the OA-2. Re-entered the OA-3 at 12,750'. Pump 30 bbl hi-vis sweep at 12,664',
back on time with 25% increase. Drill 8-1/2" lateral from 13,233' to 13,828' (4,044' TVD). Drilled 595' = 99.2'/hr AROP. 550 GPM = 2,170 psi, 130 RPM = 12K ft-lbs
TQ, WOB = 5-15K. PU = 160K, SO = 50K & ROT = 110K. MW = 8.9 ppg, Vis = 43, ECD = 10.76 ppg, max gas = 509 units MPD choke full open while drilling and
trapping 90 psi on connections. Drill in the OA-3 to planned undulation up at 13,233'. Exited the OA-3 at 13,526' and entered the OA-1 at 13,608' leveling off at 90
deg. Pumped 30 bbl hi vis sweep at 13,614', back on time with 75% increase. Drill 8-1/2" lateral from 13,828' to 14,469' (4,035' TVD). Drilled 641' = 106.8'/hr AROP.
550 GPM = 2,240 psi, 130 RPM = 13K ft-lbs TQ, WOB = 5-15K. PU = 165K, SO = 45K & ROT = 115K. MW = 9.0 ppg, Vis = 40, ECD = 11.0 ppg, max gas = 551
units MPD choke full open while drilling and trapping 90 psi on connections. Drill 8-1/2" lateral from 14,469' to 15,138' (4,055' TVD). Drilled 669' = 111.5'/hr AROP.
550 GPM = 2,060 psi, 120 RPM = 14K ft-lbs TQ, WOB = 6K. PU = 173K, SO = 45K & ROT = 108K. MW = 8.9 ppg, Vis = 40, ECD = 11.1 ppg, max gas = 518 units
MPD choke full open while drilling and trapping 90 psi on connections. Pumped 30 bbl hi vis sweep at 14,660', back on time with 10% increase. Perform 390 bbl
dump and dilute at 15,050'. Drilled 65 concretions for a total thickness of 617 (8.3% of the lateral). Last survey at 14,970.99 MD / 4,049.16 TVD, 88.27 INC, 329.97
AZM. Distance from WP09 = 15.43, 5.01 low & 14.60 right. Daily disposal to G&I = 742 bbls Total disposal to G&I = 11,481 bbls. Daily water hauled from 6 mile =
805 bbls Total water hauled from 6 mile = 10,180 bbls. Daily fluid loss = 50 bbls Total fluid loss = 360.5 bbls. Daily metal recovered = 7 lbs Total metal recovered =
55.5 lbs.
11/16/2022 Drill 8-1/2" lateral from 15,138' to 15,707' (4,022' TVD). Drilled 569' = 94.8'/hr AROP. 532 GPM = 2,220 psi, 120 RPM = 14K ft-lbs TQ, WOB = 8-17K. PU = 164K,
SO = 40K & ROT = 104K. MW = 8.9 ppg, Vis = 39, ECD = 11.4 ppg, max gas = 409 units MPD choke full open while drilling and trapping 90 psi on connections.
Pump 30 bbl hi vis sweep at 15,613', back on time with 10% increase. Crossed fault #2 at 15,133', 4' DTW throw moving the wellbore from the middle OA-1 into the
upper OA-1. Undulate up prepping for large fault exiting the OA-1 at 15,176' & entering the NF-clays. Crossed fault #3 at 15,379' with 41' DTE throw moving the
wellbore from the NF-clays into the OA-3. Continue undulating up exiting the OA-3 at 15,492' & entering the OA-1 at 15,568' leveling off at 90 deg. Drill 8-1/2" lateral
from 15,707' to 16,303' (4,034' TVD). Drilled 596' = 99.3'/hr AROP. 550 GPM = 2,270 psi, 130 RPM = 17K ft-lbs TQ, WOB = 15K. PU = 170K, SO =40K & ROT =
112K. MW = 9.0 ppg, Vis = 41, ECD = 11.34 ppg, max gas = 411 units MPD choke full open while drilling and trapping 90 psi on connections. Drill in the OA-1 to
planned undulation down at 15,958'. Exited the OA-1 at 16,045' and entered the OA-3 at 16,167' leveling out at 90 deg. Drill 8-1/2" lateral from 16,303' to 16,725'
(4,038' TVD). Drilled 422' = 70.3'/hr AROP. 550 GPM = 2,360 psi, 120 RPM = 15K ft-lbs TQ, WOB = 5K. PU = 170K, SO =40K & ROT = 114K. MW = 9.0 ppg, Vis =
40, ECD = 11.4 ppg, max gas = 483 units MPD choke full open while drilling and trapping 90 psi on connections. Pump 30 bbl hi vis sweep at 16,562', back on time
with 20% increase. Drill 8-1/2" lateral from 16,725' to 17,231' (4,038' TVD). Drilled 506' = 84.3'/hr AROP. 550 GPM = 2,250 psi, 120 RPM = 18K ft-lbs TQ, WOB =
19K. PU = 180K, SO =40K & ROT = 111K. MW = 8.9 ppg, Vis = 38, ECD = 11.0 ppg, max gas = 529 units MPD choke full open while drilling and trapping 90 psi on
connections. Perform 290 bbl dump and dilute at 17,015'. Crossed fault #4 at 17,097' with 56' DTW throw moving the wellbore from the OA-3 to the NF-clays.
Targeting 84 deg to reacquire the OA sand. Drilled 87 concretions for a total thickness of 834 (8.8% of the lateral). Last survey at 17,063.64' MD / 4,035.91' TVD,
89.33 INC, 332.97 AZM. Distance from WP09 = 7.15', 7.11' low & 0.74' left. Daily disposal to G&I = 1,095 bbls Total disposal to G&I = 13,533 bbls. Daily water
hauled from 6 mile = 935 bbls Total water hauled from 6 mile = 11,115 bbls. Daily fluid loss = 0 bbls Total fluid loss = 360.5 bbls. Daily metal recovered = 6.5 lbs
Total metal recovered = 62 lbs.
11/17/2022 Drill 8-1/2" lateral from 17,231' to 17,690' (4,101' TVD). Drilled 459' = 76.5'/hr AROP. 550 GPM = 2,320 PSI, 120 RPM = 22K ft-lbs TQ, WOB = 10-15K. PU =
178K, SO = no & ROT = 110K. MW = 9.0 ppg, Vis = 40, ECD = 11.4 ppg, max gas = 384 units.;MPD choke full open while drilling and trapping 90 psi on connec-
tions. Pump 30 bbl hi vis sweep at 17,609', back on time with 0% increase. Reacquired the OA-1 sand at 17,434' continued down exiting the OA-1 at 17,543' and
entered the OA-3 at 17,596'. Began final undulation up at 17,609'. Drill 8-1/2" lateral from 17,690' to 17,990' (4,091' TVD). Drilled 300' = 50'/hr AROP. 550 GPM =
2,350 PSI, 130 RPM = 19K ft-lbs TQ, WOB = 10-18K. PU = 185K, SO = 40 & ROT = 115K. MW = 9.0 ppg, Vis = 40, ECD = 10.9 ppg, max gas = 395 units.;MPD
choke full open while drilling and trapping 90 psi on connections. Continue undulation up toward the OA-1. Observed high micro dogleg off concretion at 17,722'
showing initial 12.64 deg with ABI readings. Reamed 3 times and reduced to 10.89 deg over 12' and survey showed 4.55 deg/100'. Drill 8-1/2" lateral from
17,990' to TD at 18,561' (4,092' TVD). Drilled 571' = 103.8'/hr AROP. 550 GPM = 2,550 PSI, 130 RPM = 20K ft-lbs TQ, WOB = 10K. PU = 185K, SO = 40 & ROT
= 112K. MW = 9.0 ppg, Vis = 39, ECD = 11.35 ppg, max gas = 417 units.;MPD choke full open while drilling and trapping 90 psi on connections. Exited the OA-3
at 18,011' and entered the OA-1 at 18,055' leveling out at 90 deg. Drilled 96 concretions for a total thickness of 924' (8.5% of the lateral). Last survey at 18,561
MD / 4,092.94 TVD, 89.41 INC, 331.91 AZM. Distance from WP09 = 40.72, 39.31 low & 10.62 left. Obtain final survey & SPR's. Downlink Geo-Pilot to home posi-
tion. Pump 30 bbl hi-vis sweep, back on time with 0% increase in cuttings. Circulated a total of 4x bottoms up at 550 GPM = 2,550 psi, 130 RPM = 18-20K ft-lbs
TQ. ECD = 11.3 ppg with 9.15 ppg MW. Reciprocate DP alternating end points. Daily disposal to G&I = 1,035 bbls; Total disposal to G&I = 14,588 bbls. Daily wa-
ter hauled from 6 mile = 1,055 bbls; Total water hauled from 6 mile = 12,170 bbls. Daily fluid loss = 0 bbls; Total fluid loss = 360.5 bbls. Daily metal recovered =
7.5 lbs. Total metal recovered = 69.5 lbs.
11/18/2022 Wash to bottom from 18,180' to 18,561', 450 GPM = 2,000 psi, 100 RPM = 20K ft/lbs TQ. PJSM with all parties involved for displacement. 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 = 1,075 psi (ICP), 130 RPM = 21K ft-lbs TQ & 5.5 BPM =
600 psi (FCP), 120 RPM = 20K ft-lbs TQ, reciprocating 95' alternating stopping points. Shut down the pumps with clean 8.45 ppg viscosified brine to surface. No
losses. Monitor pressure with MPH choke 3 times 5 minutes each = 43, 37 & 35 psi. EMW = 8.7 ppg. Clean pit #3 and load 8.45 ppg 3% lube brine in pits #3 & 4.
Obtain new SPRs. BROOH from 18,561' to 16,089' pulling 5-10 minutes/stand slowing as needed to clean up slides/tight spots. 475 GPM = 1,500 psi, 120 RPM =
20 ft-lbs TQ, max gas = 449 units. PU = 180K, SO = 50K & ROT = 115K Initially attempted 550 GPM, but observed 20 BPH losses, slow to 475 GPM and loss rate
reduced to 12 BPH. MPD choke open while reaming and holding 120 psi on connections for 8.9 ppg EMW. Regained slack off weight at 16,089'. Loss rate = 12 BPH
BROOH from 16,089' to 13,139' pulling 5-10 minutes/stand slowing as needed to clean up slides/tight spots. 475 GPM = 1,410 psi, 120 RPM = 15K ft-bs TQ, max
gas units = 84. PU = 170K, SO = 70K, ROT = 115K MPD choke open while reaming and holding 120 psi on connections for 8.9 ppg EMW. Loss rate = 7 BPH
BROOH from 13,139' to 10,473' pulling 5-10 minutes/stand slowing as needed to clean up slides/tight spots. 490 GPM = 1,270 psi, 120 RPM = 10K ft-bs TQ, max
gas units = 82. PU = 158K, SO = 85K, ROT = 112K MPD choke open while reaming and holding pressure on connections (if needed) to maintain an 8.9 ppg EMW.
Loss rate = 6 BPH. Daily disposal to G&I = 1,886 bbls Total disposal to G&I = 16,474 bbls. Daily water hauled from 6 mile = 290 bbls Total water hauled from 6 mile
= 12,460 bbls. Daily fluid loss = 103 bbls Total fluid loss = 463.5 bbls. Daily metal recovered = 4.5 lbs Total metal recovered = 74 lbs.
11/19/2022 BROOH from 10,473' to 7,621' pulling 5-10 minutes/stand slowing as needed to clean up slides/tight spots. 490 GPM = 1,240 PSI, 120 RPM = 5K ft-lbs TQ, max
gas 154 units. Pu = 148K, SO = 98K, ROT = 115K MPD choke open while reaming and holding pressure on connections (if needed) to maintain an 8.9 ppg EMW.
Loss rate = 3.3 BPH. 143.3 bbls total lost while BROOH. Pump 30 bbl high vis sweep, back on time with 50% increase. Continue to circulate 2x bottoms up at 490
GPM = 1,160 PSI, 60 RPM = 6K ft-lbs TQ. Reciprocate pipe 90' to overlap tool joints. 8.75 ppg MW in / out. Monitor pressure with MPD choke closed 3 times 5 min
each = 31, 22 &15 psi. EMW = 8.85 ppg. Weight up pit #4 to 9.0 ppg. Weight up wellbore from 7,621' to 9.0 ppg at 260 GPM = 450 PSI, 40 RPM = 5K ft-lbs TQ. 9.0
ppg MW in / out. Wait until return flow stops, then shut MPD - no pressure build in 5 minutes. Blow down top drive and perform flow check through 2" bleeder below
RCD. Initial 0.5 BPH flow to static in 15 minutes. PJSM. Remove MPD RCD and install trip nipple. Pump dry job and blow down the top drive. Drop 2.45" OD drift
with 100' wire tail. TOOH standing back 5" DP from 7,621' to 293'. Observe the well for flow - static
Lost 20.4 bbls while TOOH LD HWDP, jars, three NMDC, float and stabilizer to 96'. Download MWD data. LD remainder of BHA. Bit graded 2-2-CT-A-X-I-BT-TD.
Observed integral blade stabilizer blades worn smooth Clear the rig floor of BHA components. Remove the split bushings and install the master bushings. Static loss
rate = 4 BPH. Mobilize and RU 4-1/2" handling equipment and power tongs. MU crossover to FOSV. PJSM. Static loss rate = 4 BPH. PU, MU & RIH round nose float
shoe/WIV with crossover joint on 4-1/2"", 13.5#, L-80, H625 pre-drilled liner per tally installing a centralizer on every joint to 1,890'. Optimum TQ = 9,600 ft-lbs. PU =
60K & SO = 57K. Loss rate = 3 BPH. Daily disposal to G&I = 114 bbls Total disposal to G&I = 16,588 bbls. Daily water hauled from 6 mile = 225 bbls Total water
hauled from 6 mile = 12,685 bbls. Daily fluid loss = 77 bbls Total fluid loss = 540.5 bbls. Daily metal recovered = 6.5 lbs Total metal recovered = 80.5 lbs.
11/20/2022 RIH with 4-1/2", 13.5#, L-80, H-625 slotted liner as per tally installing a centralizer on every joint from 1,890' to 9,006'. Optimum TQ = 9,600 ft-lbs. PU = 102K & SO
= 70K. 3 BPH losses. At 9-5/8" shoe PU = 98K & SO = 76K. 35.2 bbls lost running 4-1/2" liner. Change tong heads, slips and elevators to 5-1/2". M/U 5-1/2" JFE
Bear crossover to FOSV RIH with 5-1/2", 17#, L-80, JFE Bear slotted liner as per tally installing a centralizer on every joint from 9,006' to 11,061'. Optimum TQ =
7,400 ft-lbs. PU = 112K & SO = 75K. 9.6 bbls lost running 5-1/2" liner. Swap elevators. M/U 7" x 9-5/8" Baker SLZXP liner top packer to 11,100'. RIH one stand of 5"
drill pipe to 11,193'. Pump 5 bbls through LTP to ensure clear flow path. Blow down top drive. Remove XO from FOSV. TIH with 4-1/2" x 5-1/2" injection liner on 5"
DP from 11,193' to 18,522'. PU = 180K & SO = 75K Single in the hole with 5" DP from the pipe shed from 18,522' to tag at TD of 18,561'. Space out with 2 pup
joints. Break circulation at 3 BPM = 360 psi. Blow down the top drive. Drop 1.125" phenolic setting ball. MU FOSV, side pump in sub and 10' pup joint. RU circulating
lines. PU to set depth of 18,561' placing the liner in tension. PT lines to 4,000 psi - good test. Pump 30 bbl hi-vis sweep. Circulate setting ball to seat at 3 BPM = 450
psi. Ball on seat at 1,049 strokes (216 strokes early). Pressure up to 2,000 psi observing shear at 1,870 psi and hold for 5 minutes. Set down 25K verifying hanger
set. Continue pressuring up observing neutralization at 2,954 psi and ball seat shear at 4,400 psi. PU 3' to confirm released (PU = 140K). Top of LTP at 7,473.18'.
Purge air from choke and kill lines. Close the annular. PT the SLZXP line hanger/packer to 1,500 psi for 10 minutes charted - good test. Bleed to 0 psi and open the
annular. RD and blow down circulating lines. RD 10' pup joint, side pump in sub and FOSV. Bring the pump on at 1 BPM pulling the pack-off out then increase to 3
BPM while pulling the liner running tool out of the SLZXP to 18,553'. Lay down 1 joint 5" DP and 2 DP pups. Circulate the 9-5/8" casing clean at 435 GPM = 1,270
psi reciprocating 93'. Sweep back on time with no increase in solid. Circulated a total of 1.5 BU. Blow down the top drive. PJSM. Slip and cut 108' (16 wraps) of
drilling line. Service the top drive and draw works. Inspect break linkage. Calibrate the block height. Perform derrick inspection. Static loss rate = 5 BPH. Daily
disposal to G&I = 90 bbls Total disposal to G&I = 16,678 bbls. Daily water hauled from 6 mile = 0 bbls Total water hauled from 6 mile = 12,685 bbls. Daily fluid loss =
61.5 bbls Total fluid loss = 602 bbls. Daily metal recovered = 0 lbs Total metal recovered = 80.5 lbs.
Activity Date Ops Summary
11/21/2022 Pump dry job and blow down top drive. POOH from 7,421' to 31' while laying down 5" drill pipe. L/D Baker liner running tool. 34.6 bbls lost on trip out. Provided MIT-
IA test notification, inspector Adam Earl waived witness at 07:28.,MU stack jet nozzle, jet the BOP stack and blow down the top drive. Lay down the stack jet
nozzle.,Pull the wear ring. Clean and clear the floor.,Mobilize 3-1/2" handling equipment, power tongs, spooling unit, spool of tec wire and tubing hanger to the rig
floor. Static loss rate = 2.5 BPH,RU 3-1/2" handling equipment, power tongs and tec wire spooling unit. Static loss rate = 2.5 BPH,PJSM. PU tie back seal assembly
and RIH on 3-1/2", 9.3#, L-80, EUE 8rd tubing from 22' to 1,149'. Torque = 2,800 ft-lbs,MU nipple assembly, 1 joint and gauge carrier assembly to 1,224'. Install
gauge and MU tec wire to gauge. MU 1 joint and sliding sleeve to 1,282'.,RIH with injection completion on 3-1/2" tubing spooling tec wire, installing cannon clamps
per tally and testing the Tec wire every 1,000' from 1,282' to 4,955'. PU = 65K & SO = 60K. Loss rate = 2 BHP.
11/22/2022 Run 3-1/2" 9.3# EUE L-80 tubing from 4,955' to 7,492.5' bottom of mule shoe, no-go with 10K on liner top @ 7,482.92'. Torque to 2,800 ft-lbs with Doyon casing
double stack tongs. Install cross coupler Cannon clamps on TEC wire as per tally. 110 clamps installed. PU = 80K & SO = 66K. 31 bbls total lost while running
tubing.,LD joint #234 - 236. MU 8.23', 4.08' & 10.32' pup joints and joint #234.,Change elevators to 5", PU 5" landing joint, 4-1/2" IF x 3-1/2" IF XO, 3-1/2" IF x 3-
1/2" TC-II XO and tubing hanger. Perform hanger penetration with TEC wire. Centrilift readings: Tubing = 1,700.2 psi & 74.4, Annulus = 1,700.64 psi & 74.3, 20.7
volts. Land tubing on hanger at 7,490.80' with locator sub 1.7' of no-go. Rig up circulating lines to reverse circulate down the IA with returns out the tubing. Apply
400 psi on IA then PU to expose circulating ports on seal assembly observing pressure drop. Swap to generator power for rig move at 14:00.,PSJM with all parties
involved. Reverse circulate 313.25 bbls of 8.6 ppg corrosion inhibited brine at 5 BPM = 900 psi ICP / 1,020 psi FCP followed by 159.4 bbls diesel freeze protection
at 5 BPM = 870 psi ICP / 1,010 psi FCP.,Strip through annular to close circulating ports - 2' off seat with hanger. Drain stack, blow down lines and rinse stack. Land
tubing on hanger at 7,490.80'. Run in lock down screws. Rig down circulating lines from landing joint.,RU testing equipment. PT the IA to 3,500 psi for 30 minutes
charted - good test.,Lay down the landing joint and install the BPV with dry rod.,PJSM. Pull the MPD riser and 90' mousehole. Remove the drip pan, turn buckles
and kill line. ND the BOP stack. ND the spacer spool. Set BOP on pedestal and secure for transport. SimOps: Clean and clear the rig floor on completion running
equipment. Clean the mud pits. Mobilize the tree into the cellar. Install CTS plug into the BPV. NU the tubing head adapter and NU the tree. SimOps: Obtain final
gauge reading: tubing pressure = 1,619.53 psi, IA pressure = 1,440.35 psi tubing & IA temperature = 70.7 deg and voltage = 19.9 V.,PT the tubing hanger void to
500 psi for 5 minutes and 5,000 psi for 10 minutes. RU testing equipment. PT the tree with diesel to 250/5,000 psi (good test).,Pull CTS plug and BPV with dry rod.
RU to pump down the tubing. Bullhead 23 bbls of diesel down the tubing at 1 BPM = 150 psi ICP/ 500 psi FCP. Blow down and RD circulating lines. Daily disposal
to G&I = 558 bbls Total disposal to G&I = 17,236 bbls. Daily water hauled from 6 mile = 75 bbls Total water hauled from 6 mile = 12,795 bbls. Daily fluid loss = 31
bbls Total fluid loss = 700.5 bbls. Daily metal recovered = 0 lbs Total metal recovered = 80.5 lbs. Rig Fuel = 4,414 gallons, Used = 1,096 gallons.
11/23/2022 Shut in and secure the well. Final well pressures: tubing = 200 psi & IA = 0 psi.,Rig welder cut off the mouse hole and seal weld the bottom of the cellar box.
SimOps: Work on rig move checklist. Prep to skid the rig floor. Rig released at 06:00 hours.
50-029-23731-00-00API #:
Well Name:
Field:
County/State:
MP M-31
Milne Point
Hilcorp Energy Company Composite Report
, Alaska
Well Name Rig API Number Well Permit Number Start Date End Date
MPU M-31 Doyon 14 50-029-23731-00-00 222-119 11/23/2022 12/28/2022
MPU Well Support tied well into Production, PT'd surface lines and assisted with temporary heated hootch. No issues.
Turned well over to I&E group for FCO. MPU Well Support tied well into process and PT'd surface line. no issues. Turned well
over to I&E Group.
12/24/2022
12/28/2022
T/I/O=1073/vac (Pre Injection MIT-IA) Pressured up IA to 1750 psi with 8 bbls diesel. 1st 15 min IA lost 60 psi. 2nd 15 min IA
lost 25 psi for a total loss of 85 psi in 30 min. PASS. Bled IA to 100 psi and recovered 5 bbls Final Whps1066/100
12/23/2022
LRS PUMPED 242bbls INHIBITED WATER & 226bbls DIESEL DOWN IA. SHIFT XD-SS AT 6,220' MD W/ 3-1/2" 42BO (appears
closed).
Assist SL. Pumped 201 bbls DSL into IA for FP. Pumped 13 bbls DSL into IA after Sleeve shifted to pressure test to 1500 psi.
1st MIT-IA Inconclusive. (Thermal) Pumped .4 bbls to achieve max applied pressure of 1723 psi. 1st 15 min, IA lost 40 psi.
2nd 15 min, IA lost 33 psi, 3rd 15 min, IA lost 29 psi, 4th 15 min, IA lost 27 psi. Bled IA to 145 psi, bled back 3.39 bbls. 2nd
MIT-IA Inconclusive. (Thermal) Pumped 3.85 bbls DSL to achieve max applied pressure of 1695 psi 1st 15 min, IA lost 39 psi.
2nd 15 min, IA lost 24 psi. 3rd 15 min, IA lost 23 psi, 4th 15 min, IA lost 22 psi. Possible thermal Bled back3.48 bbls. FWHP's =
527/200.
11/23/2022
Hilcorp Alaska, LLC
Weekly Operations Summary
SHIFT XD-SS AT 6,220' MD W/ 3-1/2" 42BO (Appears open). SET 3" JETPUMP (serial# - HC-00019, ratio: 13B) IN XD-SS AT
6,220' MD.
Terminate one 1/4" Tech wire, Land tubing hanger to RKB-31'.80K up and 66 dwn weights, RILDS Clean hanger void and
install SBMS seal CTS plug and RX-54 ring gasket. Land adaptor and tree running Tech wire through adapter. Torque and test
void to 500/5 5K/10 good test. Rig test tree, Good Test. Pull CTS plug, well on slight vac. Pull 3" BPV with dry rod without
issue. Rig to pump freeze protect and secure well.
12/22/2022
PULL 3-1/2" JETPUMP (serial# - HC-00029, ratio: 13B). FROM XD-SS AT 6,220' MD.
T/I/O = 500/0. Temp - NA. Load diesel transport and heat 250 bbls to 90*. Pumped 2 bbls of 90* diesel down Test &
Production leg to assist Op's. Rig up to well side flowline. Pumped 3 bbls of 70* diesel down FL to assist Op's. Pumped 3 bbls
60/40 into TBG. Pumped 3 bbls 60/40 into IA. Assist SL. Pumped 3 bbls 60/40 and 242 bbls Brine. Pumped 25 bbls DSL for FP.
TD Shoe Depth: PBTD:
No. Jts. Returned
RKB RKB to BHF RKB to THF
Jts.
1
1
1
1
1
122
1
1
1
62
1
X Yes No X Yes No
Fluid Description:
Liner hanger Info (Make/Model): Liner top Packer?: Yes No
Liner hanger test pressure:X Yes No
Centralizer Placement:
Preflush (Spacer)
Type: Density (ppg) Volume pumped (BBLs)
Lead Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Tail Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Post Flush (Spacer)
Type: Density (ppg) Rate (bpm): Volume:
Displacement:
Type: Density (ppg) Rate (bpm): Volume (actual / calculated):
FCP (psi): Pump used for disp:X Yes No
Casing Rotated?X Yes No Reciprocated?X Yes No % Returns during job
Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf:
Cement In Place At: Date: Estimated TOC:
Method Used To Determine TOC:
Preflush (Spacer)
Type: Density (ppg) Volume pumped (BBLs)
Lead Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Tail Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Post Flush (Spacer)
Type: Density (ppg) Rate (bpm): Volume:
Displacement:
Type: Density (ppg) Rate (bpm): Volume (actual / calculated):
FCP (psi): Pump used for disp:X Yes No
Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job
Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf:
Cement In Place At: Date: Estimated TOC:
Method Used To Determine TOC:
Post Job Calculations:
Calculated Cmt Vol @ 0% excess: Total Volume cmt Pumped:
Cmt returned to surface: Calculated cement left in wellbore:
OH volume Calculated: OH volume actual: Actual % Washout:
Casing (Or Liner) Detail
Shoe
Cut Joint
D14 RKB
10 3/4
452.14 7.86419.2
SE
C
O
N
D
S
T
A
G
E
Rig
11:43
cement to surface
Rotate Csg Recip Csg Ft. Min. PPG9.35
Shoe @ 7629 FC @ Top of Liner7,543.93
Floats Held
459.56 875
382.5 492.5
Spud mud
CASING RECORD
County State Alaska Supv.D. Yessak / J. Vanderpool
Hilcorp Energy Company
CASING & CEMENTING REPORT
Lease & Well No.MP M-31 Date Run 8-Nov-22
Setting Depths
Component Size Wt. Grade THD Make Length Bottom Top
TXP-BTC Innovex 1.59 7,629.00 7,627.41
23.50 55.28 31.78
31.7831.78
9 5/8 47.0 L-80 TXP-BTC
Csg Wt. On Hook:325,000 Type Float Collar:Innovex No. Hrs to Run:22
9.35 6
2330
10
10.7 446 5
1000
600
Bump Plug?
FI
R
S
T
S
T
A
G
E
10Tuned Spacer 60
15.8
750
3.7
9.4 6 173.3/172
563.2/564
1100
103.5
Rig
15.8 82
Bump press
cement to surface
Bump Plug?
Yes
20:30 11/9/2022 2,619
2618.67
7,629.007,634.00
CEMENTING REPORT
Csg Wt. On Slips:100,000
Spud
Tuned Spacer
870 2.88
Stage Collar @
60
Bump press
100
279
ES Cementer Closure OK
56
12 291
RKB to CHF
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. Ftg. Balance
www.wellez.net WellEz Information Management LLC ver_04818br
3
ArcticCem cement
Type
90 total 9-5/8" x 12"1/4" bowspring centralizers ran. Two in shoe joint w/ stop rings 10' from each end. One floating on
joint #2. One each with stop rings mid-joint on joint #3 & 4. One each on joints 5 to 25, every other joint to #47 then every
third joint to #116. One each on joints #118 to #127. One each with stop rings on pup joints above and below ES
cementer. One each on every third joint #130 to #181.
Casing 9 5/8 40.0 L-80 TXP-BTC Tenaris 82.18 7,627.41 7,545.23
Float Collar 10 3/4 TXP-BTC Innovex 1.30 7,545.23 7,543.93
Casing 9 5/8 40.0 L-80 TXP-BTC Tenaris 39.90 7,543.93 7,504.03
Baffle Adapter 10 3/4 TXP-BTC Halliburton 1.40 7,504.03 7,502.63
Casing 9 5/8 40.0 L-80 TXP-BTC Tenaris 4,862.72 7,502.63 2,639.91
Casing Pup Joint 9 5/8 40.0 L-80 TXP-BTC 18.42 2,639.91 2,621.49
ES Cementer 10 3/4 TXP-BTC Halliburton 2.82 2,621.49 2,618.67
Casing Pup Joint 9 5/8 40.0 L-80 TXP-BTC 17.55 2,618.67 2,601.12
Casing 9 5/8 47.0 L-80 TXP-BTC Tenaris 2,545.84 2,601.12 55.28
TyperI/II cement 696 2.35
Premium G cement 400 1.16
4
Premium G cement 270 1.17
11/10/2022 37
Spud Mud
No. Jts. Delivered No. Jts. Run
Ftg. Delivered Ftg. Run Ftg. ReturnedLength Measurements W/O
Threads Ftg. Cut Jt.Ftg. Balance
RKB to CHF
Casing 9 5/8 40.0 L-80 TXP-BTC Tenaris 82.18 7,627.41 7,545.23
Float Collar 10 3/4 TXP-BTC Innovex 1.30 7,545.23 7,543.93
Casing 9 5/8 40.0 L-80 TXP-BTC Tenaris 39.90 7,543.93 7,504.03
Baffle Adapter 10 3/4 TXP-BTC Halliburton 1.40 7,504.03 7,502.63
Casing 9 5/8 40.0 L-80 TXP-BTC Tenaris 4,862.72 7,502.63 2,639.91
Casing Pup Joint 9 5/8 40.0 L-80 TXP-BTC 18.42 2,639.91 2,621.49
ES Cementer 10 3/4 TXP-BTC Halliburton 2.82 2,621.49 2,618.67
Casing Pup Joint 9 5/8 40.0 L-80 TXP-BTC 17.55 2,618.67 2,601.12
Casing 9 5/8 47.0 L-80 TXP-BTC Tenaris 2,545.84 2,601.12 55.28
Type of Shoe:Innovex Casing Crew:Doyon Casing
90 total 9-5/8" x 12"1/4" bowspring centralizers ran. Two in shoe joint w/ stop rings 10' from each end. One floating ongjg g
joint #2. One each with stop rings mid-joint on joint #3 & 4. One each on joints 5 to 25, every other joint to #47 then every
third joint to #116. One each on joints #118 to #127. One each with stop rings on pup joints above and below ES
cementer. One each on every third joint #130 to #181.
TyperI/II cement 2.35
4
Premium G cement 1.16
3
Type ES Cementer Closure OK
ArcticCem cement
Premium G cement 0 1.17
279
//37
www.wellez.net WellEz Information Management LLC ver_04818br
X
2,619
cement to surface
X
cement to surface
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Benjamin Hand Digitally signed by Benjamin Hand
Date: 2022.11.23 15:20:12 -09'00'Chelsea Wright Digitally signed by Chelsea Wright
Date: 2022.11.28 08:28:01 -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: 12/19/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL :
WELL: MPU M-31
PTD: 222-119
API: 50-029-23731-00-00
FINAL LWD FORMATION EVALUATION LOGS (11/02/2022 to 11/17/2022)
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:g
Please include current contact information if different from above.
By Meredith Guhl at 3:50 pm, Dec 19, 2022
222-119
T37391
Meredith Guhl Digitally signed by Meredith Guhl
Date: 2022.12.19 15:55:16 -09'00'
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner:Rig No.:14 DATE:11/11/22
Rig Rep.:Rig Email:
Operator:
Operator Rep.:Op. Rep Email:
Well Name:PTD #2221190 Sundry #
Operation:Drilling:X Workover:Explor.:
Test:Initial:X Weekly:Bi-Weekly:Other:
Rams:250 / 3000 Annular:250 / 3000 Valves:250 / 3000 MASP:1377
MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 1 P
Permit On Location P Hazard Sec.P Lower Kelly 1 P
Standing Order Posted P Misc.NA Ball Type 1 P
Test Fluid Water Inside BOP 1 P
FSV Misc 0 NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0 N/A NA Trip Tank P P
Annular Preventer 1 13-5/8"P Pit Level Indicators P P
#1 Rams 1 4-1/2"x7"P Flow Indicator P P
#2 Rams 1 Blind P Meth Gas Detector P P
#3 Rams 1 2-7/8"x5"P H2S Gas Detector P P
#4 Rams 0 NA MS Misc 0 NA
#5 Rams 0 NA
#6 Rams 0 NA ACCUMULATOR SYSTEM:
Choke Ln. Valves 1 3-1/8x5000 P Time/Pressure Test Result
HCR Valves 2 3-1/8x5000 P System Pressure (psi)3000 P
Kill Line Valves 2 3-1/8x5000 P Pressure After Closure (psi)1700 P
Check Valve 0 NA 200 psi Attained (sec)40 P
BOP Misc 0 NA Full Pressure Attained (sec)176 P
Blind Switch Covers:All stations Yes
CHOKE MANIFOLD:Bottle Precharge:P
Quantity Test Result Nitgn. Bottles # & psi (Avg.):6 @1967 P
No. Valves 14 P ACC Misc 0 NA
Manual Chokes 1 P
Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result
CH Misc 0 NA Annular Preventer 13 P
#1 Rams 7 P
Coiled Tubing Only:#2 Rams 7 P
Inside Reel valves 0 NA #3 Rams 7 P
#4 Rams 0 NA
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:0 Test Time:5.0 HCR Choke 2 P
Repair or replacement of equipment will be made within days. HCR Kill 2 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 11/9/22, 17:56PM
Waived By
Test Start Date/Time:11/11/2022 4:00
(date)(time)Witness
Test Finish Date/Time:11/11/2022 9:00
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Guy Cook
Doyon
Performed BOP test with 3-1/2", 4-1/2", 5" & 5-1/2"' test joints to 250 low and 3000 high 5 Min. each, all test's performed against
test plug. Test 1 ea 4.5' IF FOSV & 1 ea 4.5" IF DART vavle. Tested gas alarms both audio & visual. Tested PVT'S & flow paddle,
perform draw downs on super choke & manual choke @ 1500 psi.
Hansen / Carlo
Hilcorp
Yessak / Toomey
MPU M-31
Test Pressure (psi):
rig14@doyondrilling.com
dyessak@hilcorp.com
Form 10-424 (Revised 08/2022)2022-1111_BOP_Doyon14_MPU_M-31
Alaska LLC
J. Regg; 12/5/2022
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
DIVERTER Test Report for:
Reviewed By:
P.I. Suprv
Comm ________MILNE PT UNIT M-31
JBR 12/21/2022
MISC. INSPECTIONS:
GAS DETECTORS:
DIVERTER SYSTEM:MUD SYSTEM:
P/F
P/F
P/F
Alarm
Visual Alarm
Visual Time/Pressure
Size
Number of Failures:0
Remarks:Good Test Vent line looked good and had 1 slight turn with a targeted elbow. Used a 5" Drill pipe for test. PVT and all gas alarms worked good.
TEST DATA
Rig Rep:T. Shones/J. CharlieOperator:Hilcorp Alaska, LLC Operator Rep:C. Demboski/J. Vanderpool
Contractor/Rig No.:Doyon 14 PTD#:2221190 DATE:11/2/2022
Well Class:DEV Inspection No:divKPS221103032936
Inspector Kam StJohn
Inspector
Insp Source
Related Insp No:
Test Time:1.5
ACCUMULATOR SYSTEM:
Location Gen.:P
Housekeeping:P
Warning Sign P
24 hr Notice:P
Well Sign:P
Drlg. Rig.P
Misc:NA
Methane:P P
Hydrogen Sulfide:P P
Gas Detectors Misc:NA NA
Designed to Avoid Freeze-up?P
Remote Operated Diverter?P
No Threaded Connections?P
Vent line Below Diverter?P
Diverter Size:21.25 P
Hole Size:12.25 P
Vent Line(s) Size:16 P
Vent Line(s) Length:167 P
Closest Ignition Source:103 P
Outlet from Rig Substructure:159 P
Vent Line(s) Anchored:P
Turns Targeted / Long Radius:P
Divert Valve(s) Full Opening:P
Valve(s) Auto & Simultaneous:
Annular Closed Time:18 P
Knife Valve Open Time:14 P
Diverter Misc:0 NA
Systems Pressure:P2875
Pressure After Closure:P1800
200 psi Recharge Time:P35
Full Recharge Time:P149
Nitrogen Bottles (Number of):P6
Avg. Pressure:P1975
Accumulator Misc:NA0
P PTrip Tank:
P PMud Pits:
P PFlow Monitor:
NA NAMud System Misc:
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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Chmielowski
Digitally signed by Jessie L.
Chmielowski
Date: 2022.10.04 15:45:56
-08'00'
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minutes. The results of this test and any subsequent tests of the casing must be recorded as required
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Drilling Procedure
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Milne Point Unit
M-31 SB Injector
Drilling Procedure
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3DJH
Milne Point Unit
M-31 SB Injector
Drilling Procedure
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3DJH
Milne Point Unit
M-31 SB Injector
Drilling Procedure
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Milne Point Unit
M-31 SB Injector
Drilling Procedure
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Send final “As-Run” casing tally & casing and cement report to nathan.sperry@hilcorp.com and
joseph.lastufka@hilcorp.com This will be included with the EOW documentation that goes to the
AOGCC.
3DJH
Milne Point Unit
M-31 SB Injector
Drilling Procedure
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Milne Point Unit
M-31 SB Injector
Drilling Procedure
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Milne Point Unit
M-31 SB Injector
Drilling Procedure
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Milne Point Unit
M-31 SB Injector
Drilling Procedure
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Milne Point Unit
M-31 SB Injector
Drilling Procedure
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Drilling Procedure
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