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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-56 114'
L-80 1972'
L-80 3953'
7" L-80 3936'
4-1/2" L-80 3966'
24. Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr):
Press. 24-Hour Rate
9-5/8"12-1/4"
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
CASING, LINER AND CEMENTING RECORD
List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion,
Uncemented TiebackTieback
TUBING RECORD
Uncemented Screen Liner
Liner Top Packer
6438'4-1/2" 12.6# L-80
SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date Perfd):
6430' 15481'
Stg 2 L - 671 sx / T - 270 sx
3935'
42"
13.5#
Surface 2456' Stg 1 L - 555 sx / T - 400 sx
8-1/2"
~270 ft3
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Hilcorp Alaska, LLC
WAG
Gas
3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503
7/6/2022
4914' FSL, 110' FEL, Sec. 14, T13N, R09E, UM, AK
2263' FNL, 1356' FEL, Sec. 02, T13N, R09E, UM, AK
222-053
Milne Point Field / Schrader Bluff Oil Pool
58.85'
15481' / 3966'
HOLE SIZE AMOUNT
PULLED
50-029-23717-00-00
MPU M-28
534055 6027767
333' FSL, 2619' FEL, Sec. 12, T13N ,R09E, UM, AK
CEMENTING RECORD
6028479
SETTING DEPTH TVD
6036423
BOTTOM TOP
Surface
Surface
CASING WT. PER
FT.GRADE
26#
536822
532763
TOP
SETTING DEPTH MD
Surface
Surface
Per 20 AAC 25.283 (i)(2) attach electronic information
40#
6441'
1972'
Surface
DEPTH SET (MD)
6430' / 3935'
PACKER SET (MD/TVD)
129.5#
47#
114'
2456' 6598'
Gas-Oil Ratio:Choke Size:Water-Bbl:
PRODUCTION TEST
Not on Production
Date of Test:
Flow Tubing
Oil-Bbl:
suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray,
caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation
record. Acronyms may be used. Attach a separate page if necessary
N/A
4-1/2" Screen Liner 7/3/2022
6580' - 15437' 3951' - 3966'
ROP, AGR, DGR, ABG, EWR, ADR MD & TVD
Sr Res EngSr Pet GeoSr Pet Eng
Oil-Bbl: Water-Bbl:
6/30/2022
6/16/2022
ADL 025514 & 388235
16-004
2195' / 1848'
N/AN/A
None
15481' / 3966'
Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment
By James Brooks at 9:58 am, Jul 27, 2022
Completed
7/6/2022
JSB
RBDMS JSB 072722
GDSR-8/1/22MGR30AUG2022
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
28' 28'
2223' 1876'
Top of Productive Interval 6547' 3947'
1407' 1339'
2316' 1913'
4828' 3228'
5755' 3758'
6547' 3947'
SB OA 6547' 3947'
31. List of Attachments:
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Joe Lastufka
Contact Email:joseph.lastufka@hilcorp.com
Authorized Contact Phone: 907-777-8400
General:
Item 1a:
Item 1b:
Item 4b:
Item 9:
Item 15:
Item 19:
Item 20:
Item 22:
Item 23:
Item 24:
Item 27:
Item 28:
Item 30:
Item 31:
If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form,
if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071.
Authorized Name: Monty Myers
Authorized Title: Drilling Manager
Schrader Bluff OA
Permafrost - Base
29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS
Permafrost - Top
Schrader Bluff NA
SV5
SV1
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram
with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical
reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted.
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis,
paleontological report, production or well test results, per 20 AAC 25.070.
Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
TPI (Top of Producing Interval).
Yes No
Well tested? Yes No
28. CORE DATA
If yes, list intervals and formations tested, briefly summarizing test results.
Attach separate pages to this form, if needed, and submit detailed test
information, including reports, per 20 AAC 25.071.
NAME
Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment, whichever occurs first.
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Formation at total depth:
Ugnu LA3
LOT / FIT Data Sheet, Drilling and Completion Reports, Casing and Cement Report, Definitive Directional Survey, Wellbore
Schematic
Signature w/Date:
Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
INSTRUCTIONS
The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment
7.27.2022Digitally signed by Monty M Myers
DN: cn=Monty M Myers, c=US,
o=Hilcorp Alaska, LLC, ou=Technical
Services - AK Drilling,
email=mmyers@hilcorp.com
Reason: I am approving this document
Date: 2022.07.26 12:14:53 -08'00'
Monty M
Myers
_____________________________________________________________________________________
Edited By: JNL 7/7/2022
SCHEMATIC
Milne Point Unit
Well: MPU M-28
Last Completed: 7/6/2022
PTD: 222-053
TD =15,481’ (MD) / TD =3,966’ (TVD)
4
20”
Orig. KB Elev.: 58.85’ / GL Elev.: 24.8’
7”
6
9-5/8”
1
2
3
See
Screen/
Solid
Liner
Detail
PBTD = 15,481’ (MD) / PBTD = 3,966’ (TVD)
9-5/8” ‘ES’
Cementer @
2,473’
5
4-1/2”
Shoe @
15,481’
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 1144’ N/A
9-5/8" Surface 47 / L-80 / TXP 8.681 Surface 2,456’ 0.0732
9-5/8” Surface 40 / L-80 / TXP 8.835 2,456’ 6,598’ 0.0758
7” Tieback 26 / L-80 / TXP 6.276 Surface 6,441’ 0.0383
4-1/2” Liner 100ђ Screens 13.5 / L-80 / Hyd 625 3.920 6,430’ 15,481’ 0.0149
TUBING DETAIL
4-1/2" Tubing 12.6# / L-80 / TXP 3.958 Surface 6,438’ 0.0152
OPEN HOLE / CEMENT DETAIL
42” ±270 ft3
12-1/4"Stg 1 Lead – 555 sx / Tail – 400 sx
Stg 2 Lead – 671 sx / Tail 270 sx
8-1/2” Cementless Screened Liner
WELL INCLINATION DETAIL
KOP @ 398’
90° Hole Angle = @ 7,167’
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: 50-029-23717-00-00
Completion Date: 7/6/2022
JEWELRY DETAIL
No. MD Item ID
1 Surface 4-1/2” TCII Tubing Hanger 4.500”
2 5,604’ Haliburton X-Line Sliding Sleeve (opens down) 3.813”
3 5,675’ Baker Gauge Carrier 3.865”
4 5,744’ Baker Retrievable Packer 3.880”
5 5,800’ XN Nipple, 3.813”, 3.725” No Go 3.725”
6 6,401’ WLEG/Mule Shoe 3.958”
7 6,430’ SLZXP Liner Top Packer 6.180”
8 6,452’ 7” H563 x 4.5” TSH 625 XO 4.810”
9 15,479’ Shoe 3.970”
4-1/2”SCREENS LINER DETAIL
Jts Top
(MD)
Top
(TVD)
Btm
(MD)
Btm
(TVD)
216 6580’ 3951’ 15437’ 3966’
CASING AND LEAK-OFF FRACTURE TESTS
Well Name:MPU M-28 Date:6/25/2022
Csg Size/Wt/Grade:9.625", 40# & 47#, L-80 Supervisor:Yessak/Toomey
Csg Setting Depth:6598 TMD 3952 TVD
Mud Weight:9.4 ppg LOT / FIT Press =535 psi
.
LOT / FIT =12.00 Hole Depth =6625 md
Fluid Pumped=0.91 Bbls Volume Back =0.9 bbls
Estimated Pump Output:0.101 Barrels/Stroke
LOT / FIT DATA CASING TEST DATA
Enter Strokes Enter Pressure Enter Strokes Enter Pressure
Here Here Here Here
->00 ->00
->197 ->2117
->2 139 ->6354
->3 188 ->10 611
->4 236 ->14 835
->5 305 ->18 1025
->6 360 ->20 1123
->7 406 ->24 1332
->8 478 ->28 1546
->9 535 ->32 1765
->10 ->36 2003
->11 ->40 2241
->12 ->44 2480
->13 ->48 2621
Enter Holding Enter Holding Enter Holding Enter Holding
Time Here Pressure Here Time Here Pressure Here
->0 535 ->0 2621
->1 522 ->5 2604
->2 513 ->10 2597
->3 504 ->15 2590
->4 496 ->20 2584
->5 489 ->25 2579
->6 483 ->26 2577
->7 477 ->27 2576
->8 472 ->28 2576
->9 467 ->29 2575
->10 463 ->30 2574
->11 459 ->
->12 455 ->
->13 452 ->
->14 449
->15 446
->
FIT Press
12.00
535
0
1
2
3
4
5
6
7
8
9
0
2
6
10
14
18
20
24
28
32
36
40
44
48
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
)
535522513504496489483477472467463459455452449446
2621 2604 2597 2590 2584 257925772576257625752574
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
6/14/2022 Move and spot rig over M-28. Shim rig level. Secure landings and walkways. Skid rig floor into drilling position. Rig up mud lines and utilities on rig floor. Prepare
mud pits to take on spud mud. Install screens on shakers. Spot rockwasher and fuel trailer. Install 4" valves on conductor. Start rig up diverter system. Load HWDP
into pipe shed. Spot supports services units. On highline power at 14:40. Rig accepted at 18:00. Continue to RU on M-28, installing diverter line and N/U surface
annular preventer. Load remaining BHA into the pipe shed. Spot H2O pump house, uprights and cement silos. SimOps: Welder prep Derrick board for inspection,
Tuboscope inspect Derrick board and wind wall supports. No other issues found. Finish N/U Diverter line. Install surface riser and 90’ mousehole. Obtain RKBs.
Inspect the saver sub and grabber dies. Grabber dies are good. Changeout the saver sub. SimOps: Load 135 bbls H2O to upright. Start bring on 580 bbls spud
mud to pits.
6/15/2022 P/U 2 joints of drill pipe. Energize accumulator. Perform initial function of diverter (26 sec)and knife valve (16 sec). Continue to load 580 bbls of spud mud. AOGCC
inspector Adam Earl on location to witness testing. Inspected diverter line, signs and location - good. Perform testing of rig H2S & LEL gas alarms - good. Perform
diverter function test. Close annular on 5" drill pipe. Knife valve open 17 sec and annular close in 25 sec - passing. Accumulator drawdown testing. 2950 PSI
system pressure, 1800 PSI after closure, 37 sec 200 PSI recharge and 163 sec full recharge - passing. 6 nitrogen bottle average - 1950 PSI. Diverter length 206',
length from rig 203', closest ignition source 87' (wellhouse light) C/O top drive saver sub. Service and inspect top drive and draworks LD 2 joints 5'' DP, ready
upright water tank, dress shakers with 100# screens, start offloading 8.8 spud mud into the pits. Simops: welders continue to prep derrick board in shop Welders
continue to make derrick board repairs and prep for installation. Weld channel iron onto beam and Tuboscope inspected. - Good. Simops: C/O conveyor paddles,
install discharge screen on MP 2. Welders continue to make derrick board repairs and prep for installation. Install 4"x1/4" fishplate on face of beam. Simops:
Processing 9-5/8" casing.
6/16/2022 Welders continue to make derrick board repairs and prep for installation. Finish welding out 4"x1/4" fishplate on face of beam in derrick. MPI welds, load repaired
board to rig floor. Simops: Continue processing 9-5/8" casing. PJSM, following DDI procedure, mobilize repaired derrick board in place utilizing rig floor hoist and
man basket, weld board into place, MPI same. Lower Derrick fingers back into place, string tugger lines into place & re-attach tugger rollers. Clear floor of tools and
equip. Simops: Continue processing 9-5/8" casing, cleanup around the rig. Haliburton loading out surface cement. PU and MU 3 stands of 5" HWDP, 1 stand of 5"
HWDP with jar and 2 stands of 5" HWDP for the BHA. Pre-spud meeting with all parties involved. Discussed well objectives and surface hole hazards. Table top
diverter drill. M/U 12-1/4" Kymera bit, 8" mud motor with 1.5° AKO and XO sub to 35'. M/U stand of 5" HWDP to top drive. RIH with stand and tag up @ 113' MD.
Pressure test high pressure mud line & MWD Geo-Span, with H2O, to 3000 PSI. good test. Flood system with water and ensure no leaks. Engage pumps and rotary
clean, out conductor to 114' pumping 300 gpm, 180 psi, 40 rpm, 1k tq, 1-2k WOB. Drill 12-1/4" surface hole from 114' to 218'. Swap to Spud Mud @ 124’. 370
GPM, 500 PSI, 40 RPM, 1-2K ft/lbs TQ, 8K WOB. 49K PU / 49K SO / 49K ROT. 8.8 ppg MW, 300 vis. Initial cutting returns of pea gravel and sand, turning to
gravel and clay by 175'. Pump out of hole f/ 218' t/ 124' then pull out on elevators to surface. Inspect bit - No damage, cones rotate freely. Did find a grinder, wire
wheel wedged in cones. RIH with bit and motor. M/U remaining BHA with GWD, directional, gamma and resistivity. Initialize MWD tools.
6/17/2022 Finish initializing tools, MU remaining BHA #1, 2 flex collars, XO to 161', MU stand HW and TD, shallow test tools, gyro survey, wash to bttm, no fill. Drill 12-1/4"
surface hole from 218' to 506' (505' TVD). Drilled 288' = 72'/hr AROP. 400 GPM, 860 psi, 40 RPM, 1-2K ft/lbs torque, WOB 10-15K, PU 71K, SO 70K, ROT 70K.
MW = 9 ppg, Vis 183, ECD 9.64 ppg, max gas units = 0. Start 3 deg/100' build at 380' Drill 12-1/4" surface hole from 506' to 998' (984' TVD). Drilled 478' =
79.66'/hr AROP. 500 GPM, 1300 psi, 40 RPM, 2-4K ft/lbs torque, WOB 7K, PU 81K, SO 83K, ROT 83K. MW 9.0 ppg, Vis = 191, ECD 9.58 ppg, max gas units
= 9. Increase to 4 deg/100' at 700' Drill 12-1/4" surface hole from 998' to 1571' (1464' TVD). Drilled 573' = 95.5'/hr AROP. 500 GPM, 1430 psi, 40 RPM, 2-6k Tq,
WOB 9k, PU 90K, SO 85K, ROT 85K. MW 9.2 ppg, Vis = 173, ECD 10.02 ppg, max gas units = 142. Continue build @ 4°/100' Drill 12-1/4" surface hole from
1571' to 2238' (1875' TVD). Drilled 667' = 111.17’/hr AROP. 435 GPM, 1200 psi, 60 RPM, 6-7k Tq, WOB 5-6k, PU 106k, SO 82k, ROT 95k. MW 9.3 ppg, Vis
= 122, ECD 10.22 ppg, max gas units = 432. Continue build @ 4°/100' SV5 Logged @ 1407’ MD / 1339’ TVD. Last survey at 2090.16’ MD / 1803.59' TVD, 56.64°
inc, 114.15° azm, 21.47’ from plan, 16.68’ Low and 13.5’ Right. Daily disposal to G&I = 808 bbls Total disposal to G&I = 860 bbls. Daily water hauled from B Creek
= 860 bbls Total water hauled from B Creek = 860 bbls. Daily fluid loss = 0 bbls Total fluid loss = 0 bbls. Daily metal recovered = 0 lbs Total metal recovered = 0
lbs.
6/18/2022 Drill 12-1/4" surface hole from 2238' to 2934' (2162' TVD). Drilled 696' = 116’/hr AROP. 498 GPM, 1580 psi, 80 RPM, 4-6k Tq, WOB 4-5k, PU 105k, SO 80k,
ROT 91k. MW 9.3 ppg, Vis = 220, ECD 10.55 ppg, Max Gas = 283u. Continue build @ 4°/100' to 2342' then hold 65° tangent BOPF logged in at 2233' md, 1876'
TVD. Pump 1st 30 bbl hi vis sweep @ 2342', back on time with 100% increase. Pump another 30 bbl hi vis sweep @ 2933', Sweep back on time with 30%
increase. Drill 12-1/4" surface hole from 2934' to 3500' (2416' TVD). Drilled 566' = 94.33’/hr AROP. 490 GPM, 1550 psi, 80 RPM, 5-7k Tq, WOB 4k, PU 110k, SO
86k, ROT 95k. MW 9.3 ppg, Vis = 121, ECD 10.30 ppg, Max Gas = 283u. Hold 65° tangent to 3334' then drop and turn 45° Top of the Ugnu logged at 2943' md,
2165' TVD. Drill 12-1/4" surface hole from 3500' to 4046' (2705' TVD). Drilled 546' = 91’/hr AROP. 500 GPM, 1740 psi, 80 RPM, 8-9k Tq, WOB 10k, PU 125k, SO
90k, ROT 104k. MW 9.2 ppg, Vis = 97, ECD 10.01 ppg, Max Gas = 212u. Cont. w/ drop & turn, target 4.5° DL. 30 bbl Hi-Vis Sweep @ 3855’, 350 stks late, 20%
Drill 12-1/4" surface hole from 4046' to 4616' (3087' TVD). Drilled 570' = 95’/hr AROP. 500 GPM, 1800 psi, 80 RPM, 9-12k Tq, WOB 10-15k, PU 145k, SO 90k,
ROT 109k. MW 9.3 ppg, Vis = 134, ECD 10.37 ppg, Max Gas = 213u. Continue with drop and turn, target 4.5° DL Last survey at 4468.55’ MD / 2991.20' TVD,
47.94° inc, 63.15° azm, 7.08’ from plan, 4.75’ High and 5.25’ Left. Daily disposal to G&I = 1497 bbls Total disposal to G&I = 2357 bbls. Daily water hauled from B
Creek = 1645 bbls Total water hauled from B Creek = 2305 bbls. Daily fluid loss = 0 bbls Total fluid loss = 0 bbls. Daily metal recovered = 0 lbs Total metal
recovered = 0 lbs.
Spud Date: 6/16/2022
Well Name:
Field:
County/State:
MP M-28
Milne Point
Hilcorp Energy Company Composite Report
, Alaska
6/19/2022 Drill 12-1/4" surface hole from 4616' to 5125' (3423' TVD). Drilled 509' = 78.3’/hr AROP. 498 GPM, 1920 psi, 80 RPM, 11-12k Tq, WOB 4-6k, PU 155k, SO 97k,
ROT 120k. MW 9.3 ppg, Vis = 140, ECD 10.28 ppg, Max Gas = 734u. Continue to build and turn targeting 85 deg Pump 30 bbl hi vis sweep @ 4995', no indication
of sweep at returns. Gas watch system at shaker not operating, when flushing system- quit working, ran out of gas scrubber fluid, rack back stand, pump 500 gpm,
15 rpm, 13k torque working pipe 90' from 5090' Troubleshoot GW, electrician found broken wire on barrier card, repair same, 2 bottles of gas scrubber fluid arrived
from Deadhorse, fill canister with same , MU stand DP, wash to bottom. Drill 12-1/4" surface hole from 5125' to 5186' (3461' TVD). Drilled 61', gas watch not
reading correct, fluctuating from 2-27 units. Continue to build and turn Pump 490 gpm, 1550 psi, 15 rpm,13k torque working pipe 90' from 5180', electrician
troubleshoot GW system. W/O infrared sensor and bump test gas to arrive from Deadhorse, C/O sensor and bump test GW system. good bump test. Drill 12-1/4"
surface hole from 5186' to 5475' (3629' TVD). Drilled 289' = 57.8’/hr AROP. 500 GPM, 1920 psi, 80 RPM, 12-14k Tq, WOB 15k, PU 165k, SO 97k, ROT 122k.
MW 9.4 ppg, Vis = 77, ECD 10.15 ppg, Max Gas = 247u. Continue to build and turn targeting 85°. Drill 12-1/4" surface hole from 5475' to 5947' (3834' TVD).
Drilled 472' = 78.67’/hr AROP. 550 GPM, 2190 psi, 80 RPM, 14-16k Tq, WOB 4-6k, PU 175k, SO 90k, ROT 124k. MW 9.5 ppg, Vis = 111, ECD 10.62 ppg, Max
Gas = 397u. Continue with drop and turn, target 4.5° DL Last survey at 5798.46’ MD / 3775.83' TVD, 66.81° inc, 351.88° azm, 20.90’ from plan, 13.7’ High and
15.77’ Left. Ugnu LA3 logged at 4828’ MD / 3228’ TVD. SB_NA logged at 5755’ MD / 3759’ TVD Daily disposal to G&I = 979 bbls Total disposal to G&I = 3336
bbls. Daily water hauled from B Creek = 1055 bbls Total water hauled from B Creek = 3360 bbls. Daily fluid loss = 0 bbls Total fluid loss = 0 bbls. Daily metal
recovered = 0 lbs Total metal recovered = 0 lbs.
6/20/2022 Drill 12-1/4" surface hole from 5947' to 6423' (3934' TVD). Drilled 476' = 79.3’/hr AROP. 540 GPM, 2410 psi, 80 RPM, 13-15k Tq, WOB 18-20k, PU 170k, SO
88k, ROT 120k. MW 9.5 ppg, Vis = 60, ECD 10.47 ppg, Max Gas = 498u. Continue with drop and turn to 6396' then hold 85° tangent Pump 30 bbl hi vis sweep at
6007', back on time with no no increase. Drill 12-1/4" surface hole from 6423' to TD @ 6605' (3953' TVD) in the top OA sand. 550 GPM, 2170 psi, 80 RPM, 13k Tq,
WOB 8k, PU 170k, SO 90k, ROT 122k. MW 9.5 ppg, Vis = 55, ECD 10.36 ppg, Max Gas = 423u. Hold 85° tangent to TD. Final survey = 2.66' low, 11.16' right.
Pump 30 bbl hi vis sweep cleaning up the wellbore, 548 gpm, 2100 psi, 40 rpm, 14k torque, back on time with no increase. Condition mud, mw 9.5 ppg in, 9.6 ppg
out, vis 58 with YP @ 23 working pipe slow to 6518'. Wash to bottom, no fill. BROOH from 6605' to 6413'. Flow check the well (static). Continue BROOH from
6413' to 4700' pulling 5-10 minutes/stand slowing as needed to clean up slides/tight spots. 550 GPM -1780 PSI, 80 RPM - 12-15K ft/lbs torque, max gas units =
122. PU = 165K, SO = 90K, ROT = 130K. BROOH from 4700' to 1955' pulling 5-10 minutes/stand slowing as needed to clean up slides intervals & tight spots. 550
GPM - 1780 PSI, 80 RPM - 7-10K ft/lbs torque, max gas units =147. PU = 125K, SO =75K, ROT = 90K Daily disposal to G&I = 901 bbls Total disposal to G&I =
4237 bbls. Daily water hauled from B Creek = 1400 bbls Total water hauled from B Creek = 4760 bbls. Daily fluid loss = 0 bbls Total fluid loss = 0 bbls. Daily metal
recovered = 0 lbs Total metal recovered = 0 lbs.
6/21/2022 Continue to BROOH from 1955' to HW @ 716' pulling 5-10 minutes/stand slowing as needed to clean up slides intervals & tight spots. 500 GPM - 1200 PSI, 80
RPM - 2-3K ft/lbs torque, max gas units =273 Flow check well - static. TOOH on elevators, stand back 5" HWDP from 716' to 159'. BD the top drive. LD BHA #1,
LD 2 NMFCs to 97', read MWD, LD remaining BHA. Correct displacement TOOH.12 1/4'' bit grade: PDC cutters = 1-1-CT-A-X-I-WT-TD and cones = 1-1-SD-A-F-I-
WT-TD. M5 stabilizer and wear bands were in good shape. Motor stab showed damage on the upper portion of all 4 blades from BROOH. Clear and clean the rig
floor, load tools to the rig floor, RU volant tool and 9 5/8" handling equipment, hold PJSM with all parties involved. Monitor well, 4 BPH loss rate. NOV rep calibrate
and test gas watch, perform vac leak test, good. P/U and M/U 9-5/8" shoe track using ForumLok on each connection. Round nose float shoe joint, spacer joint, float
collar joint. Fill shoe track and install the top hat. M/U baffle adapter joint to 166'. Pump through shoe track at 3 BPM to ensure float equipment operating correctly -
good. RIH with 9-5/8", 40# casing from 166' to 2519' at 30'/min running speed. Torque to 21,000 ft/lbs with the Volant tool. Fill casing on the fly and top off every 10
joints. Centralizers installed as per tally. Losses @ 4-6 BPH Circulate bottoms up below the permafrost stage up to 6 BPM = 150 psi. Lost 18 bbls while circulating.
RIH with 9-5/8", 40# casing from 2,519' to 4104' at 30'/min running speed. Torque to 21,000 ft/lbs with the Volant tool. Fill casing on the fly and top off every 10
joints. Centralizers installed as per tally. Losses @ 4-6 BPH MU the ES cementer w/ pup jts Top & Btm t/ 4183'. ForumLok top/bottom connections. RIH with 9-5/8",
47# casing f/ 4183' to 4595'. 30'/min running speed. Torque to 24,000 ft/lbs with the Volant tool. Fill casing on the fly and top off every 10 joints. Centralizers
installed as per tally. Losses @ 4-6 BPH, Total Losses = 58. PU = 230K and SO = 95K. Daily disposal to G&I = 456 bbls Total disposal to G&I = 4828 bbls. Daily
water hauled from B Creek = 470 bbls Total water hauled from B Creek = 5230 bbls. Daily fluid loss = 30 bbls Total fluid loss = 30 bbls. Daily metal recovered = 0
lbs Total metal recovered = 0 lbs.
6/22/2022 RIH 30 fpm with 9-5/8", 47# casing f/ 4595 to 6524'. @ jt 58. Torque to 24,000 ft/lbs with the Volant tool. Fill casing on the fly and top off every 10 joints.
Centralizers installed as per tally. Losses @ 4-6 BPH, Wash down joint #59 and short joint on depth at 6598' pumping 3 bpm, 450 psi, confirm 47# casing count.
Remove elevators and bale extensions. Total losses RIH and circulating= 87 bbls. PU 283k, SO 105K. Spot and RU cementers. Stage pumps to 6 bpm, 430 psi,
while working the string from 6598' to 6575', set TD torque @ 20k, establish rotation @ 1-2 rpm and 20k TQ while working pipe. Condition the mud for cementing,
Final 6 BPM = 240 psi with MW 9.5, YP = 14. 14 bbl losses circulating Shut down pump, BD TD, 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 while holding PJSM HES filled lines with 5 bbls fresh water. PT surface lines to
1,000/4,200 psi. good. Pump 1st stage cement job: Mix & pump 60 bbls of 10 ppg tuned spacer with 4# red dye & 5# Pol-E-Flake in 1st 10 bbls, 3 BPM = 170 PSI.
Drop bypass plug. Mix and pump 232 bbls of 12.0 ppg lead cement (Type I/II cement, 2.347ft^3/sk yield, 555 sks total) ) at 4.5 BPM = 400 psi. Mix & pump 82
bbls 15.8 ppg Premium G tail cement (1.156 ft^3/sk yield, 400 sks total) @ 4.25 BPM, 650 PSI. Rotate 2-3 RPM, 20K TQ & reciprocate 30'. Drop shutoff plug. HES
pump 20 bbls water @ 7 BPM, 640 psi. Displace with 273 bbls (2703 strokes) 9.5 ppg spud mud from rig at 7 BPM, 240 PSI Displace with 82.5 bbls 9.4 ppg Tuned
Spacer from HES at 4.8 BPM, 400 PSI, continue to displace with 109 bbls 9.5 ppg mud from the rig at 6 BPM, 446 PSI ICP, slow to 4 BPM for last 10 bbls, FCP
700 PSI. Bump plug 3741 strokes, 4 bbls early. CIP at 18:18 hours Pressure up to 1,300 psi and hold for 3 minutes. Bleed off and check floats (good). Pressure up
to 3,000 psi shifting the ES cementer open. Rotated and reciprocated throughout the entire job. Pump through the ES cementer at 2,476' at 255 GPM = 690 psi.
Dumped 70 bbls of spacer and interface. 10 bbls of cement was observed at surface. Take returns back to the pits and continue to circulate 5 BU. Disconnect the
knife valve from the accumulator. Drain and flush the stack with black water 3 times. Reconnect the knife valve to the accumulator. Continue to circulate through
the ES cementer at 2,476' at 3-6 BPM = 130 - 380 psi. Break out, inspect and MU the Volant tool. Clean the suction screens. Continue to circulate through the ES
cementer at 3 BPM = 120 psi. HES warming up cementing equipment. PJSM. Pump 2nd stage cement job: Pump 5 bbls of fresh water. PT lines to 1,000/3,500
psi (good). Mix and pump 60 bbls of 10.0 Tuned Spacer with 4# red dye and 5# Pol-E-Flake in the 1st 10 bbls at 3.8 BPM = 200 psi. Mix and pump 205 bbls of
10.7 ppg ArcticCem lead cement at 4.6 BPM = 320 psi ICP. Daily disposal to G&I = 1,156 bbls Total disposal to G&I = 5,984 bbls. Daily water hauled from B-Creek
= 420 bbls Total water hauled from B-Creek = 5,650 bbls. Daily fluid loss = 92 bbls Total fluid loss = 122 bbls. Daily metal recovered = 0 lbs Total metal recovered
= 0 lbs.
6598' pumping 3 bpm,
Mix & pump 60 bbls of 10 ppg tuned spacer with 4# red dye & 5# Pol-E-Flake in 1st 10 bbls, 3 BPM = 170 PSI.
Drop bypass plug. Mix and pump 232 bbls of 12.0 ppg lead cement (Type I/II cement, 2.347ft^3/sk yield, 555 sks total) ) at 4.5 BPM = 400 psi. Mix & pump 82
bbls 15.8 ppg Premium G tail cement (1.156 ft^3/sk yield, 400 sks total) @ 4.25 BPM, 650 PSI. Rotate 2-3 RPM, 20K TQ & reciprocate 30'. Drop shutoff plug. HES
pump 20 bbls water @ 7 BPM, 640 psi. Displace with 273 bbls (2703 strokes) 9.5 ppg spud mud from rig at 7 BPM, 240 PSI Displace with 82.5 bbls 9.4 ppg Tuned
Spacer from HES at 4.8 BPM, 400 PSI, continue to displace with 109 bbls 9.5 ppg mud from the rig at 6 BPM, 446 PSI ICP, slow to 4 BPM for last 10 bbls, FCP
700 PSI. Bump plug 3741 strokes, 4 bbls early. CIP at 18:18 hours Pressure up to 1,300 psi and hold for 3 minutes. Bleed off and check floats (good). Pressure up
to 3,000 psi shifting the ES cementer open. Rotated and reciprocated throughout the entire job. Pump through the ES cementer at 2,476' at 255 GPM = 690 psi.
Dumped 70 bbls of spacer and interface. 10 bbls of cement was observed at surface. Take returns back to the pits and continue to circulate 5 BU. Disconnect the
knife valve from the accumulator. Drain and flush the stack with black water 3 times. Reconnect the knife valve to the accumulator. Continue to circulate through
the ES cementer at 2,476' at 3-6 BPM = 130 - 380 psi. Break out, inspect and MU the Volant tool. Clean the suction screens. Continue to circulate through the ES
cementer at 3 BPM = 120 psi. HES warming up cementing equipment. PJSM. Pump 2nd stage cement job: Pump 5 bbls of fresh water. PT lines to 1,000/3,500
psi (good). Mix and pump 60 bbls of 10.0 Tuned Spacer with 4# red dye and 5# Pol-E-Flake in the 1st 10 bbls at 3.8 BPM = 200 psi. Mix and pump 205 bbls of
10.7 ppg ArcticCem lead cement at 4.6 BPM = 320 psi ICP. Daily disposal to G&I = 1,156 bbls Total disposal to G&I = 5,984 bbls. Daily water
tangent to TD.
BROOH from 6605
6/23/2022 Continue pumping 2nd stage cement job: Mix and pump an addition 130 bbls for a total of 345 bbls of 10.7 ppg ArcticCem lead cement (671 sxs at 2.883 ft^3/sk
yield) at 5.1 BPM = 550 psi FCP. Mix and pump 56 bbls of 15.8 ppg Premium G tail cement (270 sxs at 1.17 ft^3/sk yield) at 3.9 BPM = 330 psi Drop the closing
plug. Pump 20 bbls of 8.34 ppg fresh water at 5.5 BPM = 300 psi. Displace with 9.5 ppg spud mud at 6 BPM = 400 psi ICP, last 10 bbls slow to 4 BPM= 600 psi
FCP. Bumped the plug @ 1588 strokes, 12 strokes early, CIP @ 07:24 60 BBLS spacer, 38 BBLS of interface and 193 BBLS good 10.7 ppg cement returned,
100% returns during job. Pressure to 2200 psi shifting ESC closed, hold for 5 minutes, bleed off pressure, open block valve to casing, no flow. Disconnect the ac-
cumulator lines from the knife valve. Drain the cement from the stack into the cellar box. Flush the stack with black water three times. Jet the flow line with black
water. Power down the accumulator and disconnect 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.
Center up the 9 5/8'' casing, WHR install casing slips with 100k set on the slips. Welder make casing cut, LD cut joint, length on cut joint= 16.63', pull the riser,
reposition the annular, welder dress 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. NU tubing spool on top the casing head.
Remove the spacer spool and set the stack on the tubing head. NU the BOP stack. Install the kill line, turn buckles and MPD riser. Change the upper pipe rams
to 4-1/2" x 7" VBR's. RU BOPE testing equipment. MU the TIW and dart valve. Install the test plug. Flood the choke manifold and stack. Shell test the BOP
stack (passed). Conduct initial BOPE test to 250/3,000 psi: LPR (2-7/8” x 5” VBR’s) with 4-1/2” & 5” test joints, UPR (4-1/2” x 5” VBR’s) with 4-1/2” & 7” test
joints, 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 wit-
nessed by AOGCC inspector Lou Laubenstein. Tests: 1. Annular with 4-1/2” test joint, 3” Demco kill, 5” TIW, choke valves 1, 12, 13 & 14 (passed) Daily disposal
to G&I = 1,183 bbls Total disposal to G&I = 7,167 bbls. Daily water hauled from B-Creek = 290 bbls Total water hauled from B-Creek = 5,940 bbls. Daily fluid
loss = 0 bbls Total fluid loss = 122 bbls. Daily metal recovered = 0 lbs Total metal recovered = 0 lbs.
6/24/2022 Continue testing BOPE to 250/3,000 psi with 4-1/2'', 5'' & 7'' test joints. Tests: 2. UPR with 4-1/2” test joint, Choke valves 9, 11, HCR kill, 5'' dart valve (passed). 3.
LPR with 4 1/2'' test joint (passed). 4. UPR with 5'' test joint, Choke valves 5, 8, 10, Manual kill and upper IBOP (passed) 5. Lower IBOP, choke valves 4, 6 & 7
(passed). 6. Choke valve 2 (pass). 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. Manual adjustable choke (passed). 13. hydraulic Super choke (passed) System pressure = 3000 psi. Pressure after
closure = 1650 psi. 200 psi attained in 45 seconds. Full pressure attained in 190 seconds. Nitrogen Bottles - 6 at 2025 psi The test was witnessed by AOGCC
inspector Lou Laubenstein. Rig electrician calibrate and test the rig gas alarms. No failures. RD BOP testing equipment. BD the choke manifold, kill lines and TD.
Pull the test plug, Install the wear ring (ID = 9.25"). Simops: loosen flange bolts on MPD head, turn same so orbit valve clears landing in cellar. Re-torque flange
bolts. Cleanup around riser in flow box, pull MPD riser, install MPD test cap, test same to 1500 psi against blind ram, good, bleed off pressure, open BR. Remove
test cap, C/O air boot and re-install MPD riser. RU 5'' handling equipment. Install 30' mouse hole. PJSM, load tools to rig floor, MU 8-1/2'' tri cone bit, mud motor, 5
stands HWDP with jar stand to 588'. Simops: Load 580 BBLS 8.8 PPG Flo Pro mud into pits. TIH on 5'' DP from 588' to 2,396' Fill pipe. PU = 103K, SO = 75K &
ROT = 85K. Wash down at 5 BPM = 240 psi from 2,396' to hard tag with 10K down at 2,463' Wash & ream down at 450 GPM = 800 psi, 40 RPM = 5K ft-bls TQ
from 2,463' to 2,476'. Drill ES cementer from 2,476' to 2,478' at 450 GPM = 850 psi, 40 RPM = 5K ft-bls TQ, WOB = 5-10K. Ream through 3 times and trip through
with no pump/rotary without issue. Continue to wash & ream from 2,478' to 2,587' at 450 GPM = 800 psi, 40 RPM = 5K ft-bls TQ. TIH from 2,587' to 6,392' filling
the DP every 2,000'. Wash down at 5 BPM = psi from 6,392' to hard tag with 10K down at 6,442'. CBU at 450 GPM = 950 psi, 40 RPM = 19K ft-lbs TQ with
reciprocating 50'. Mud returns are thick. Continue to circulate an addition 2 BU for a total of 3 BU to condition the mud for the casing test. Rack back 1 stand to
6,388'. RU testing equipment. Fill lines and purge air. Close upper 4-1/2" x 7" VBR's on the 5" DP. PT 9-5/8" casing to 2,621 psi for 30 minutes charted (good
test). RD test equipment. MU stand that was racked back Wash & ream from 6,388' to 6,442' at 450 GPM = 1320 psi, 40 RPM = 16K ft-lbs TQ, WOB = 6-8K. Drill
cement and 9-5/8" shoe track from 6,442' to 6,598'. All equipment on depth. Cleanout the rat hole from 6598' to 6,605'. Ream through the baffle adapter and float
collar 3 times each. Drill 20' of new formation from 6,605' to 6,625' at 450 GPM = 1320 psi, 40 RPM = 16K ft-lbs TQ, WOB = 10-15K Ream through the shoe 3
times with/without pump/rotary. Stand back the stand to 6,580' Circulate and condition the mud for the FIT at 450 GPM = 1170 psi, 40 RPM = 17K ft-lbs TQ ,
reciprocating 95'. After 1.8 BU had good 9.4 ppg in/out and the well cleaned up. RU testing equipment. Fill lines and purge air. Close upper 4-1/2" x 7" VBR's on
the 5" DP. Daily disposal to G&I = 139 bbls Total disposal to G&I = 7,306 bbls. Daily water hauled from B-Creek = 250 bbls Total water hauled from B-Creek =
6,190 bbls. Daily fluid loss = 0 bbls Total fluid loss = 122 bbls. Daily metal recovered = 0 lbs Total metal recovered = 0 lbs.
6/25/2022 Perform FIT to 12.0 ppg at 6,598' MD / 3,952' TVD with 9.4 ppg MW and 535 psi applied at surface. Pumped 0.91 bbls and bled back 0.9 bbls. RD testing
equipment. Blow down lines. Flow check the well, static, pump dry job, blow down the top drive. POOH racking back stands of 5'' DP from 6598' to the HWDP at
588', L/D excess HW, rack jar stand in derrick, L/D bit and motor. Bit grade: 1-1-WT-A-E-I-NO-BHA. 9.4 BBL losses TOOH. Simops: test MPD lines to 250/1250
psi, good. Flush and jet flowline, clear and clean the rig floor, load tools to the rig floor, remove the master bushing and install split bushing. PJSM, MU BHA #3- 8-
1/2" NOV SK616M bit, NRP-A2 bit sleeve, 7600 Geo-Pilot, LWD (ADR & DGR), MWD (PWD & GWD), directional tools, stabilizer and float sub to 105'. Plug in
and initialize MWD tools. Finish making up BHA #3. P/U NMFCs , stand of HWDP with jars to 294'. MU stand of DP and TD. Shallow test tools 450 GPM = 990
psi. TIH on 5" DP from 294' to 2,198'. Fill the DP and break in the GeoPilot. Continue to TIH on 5" DP from 2,198' to 6,383' then single in the hole from 6,383' to
6,574' filling DP every 2000'. PU = 240K & SO = 77K PJSM. Drain stack, pull MPD riser and install MPD RCD. MU a stand of 5" DP. Wash & ream from 6,574' to
6,625' at 5 BPM = 420 psi, 40 RPM = 18K ft-lbs TQ, PU = 235K, SO = 67K & ROT =125K PJSM. Displace the well from spud mud to 8.8 ppg FloPro. Pump 30
bbl sweep with bit on bottom at 7 BPM = 800 psi. Once the sweep was out of the DP rack 1 stand back to 6,574'. Continue with the displacement at 7 BPM = 800
psi, 40 RPM = 18K ft-lbs TQ, reciprocating DP 95'. PJSM. Slip and cut 60' of drilling line. Calibrate the block height. Inspect and adjust the brakes. Service the top
drive. Monitor for pressure build against closed MPD choke (no pressure observed). SimOps: Clean pit #4 and surface equipment. Inspect and changeout the
saver sub due to wear. Inspect the grabber dies. Obtain SPR's. Wash down from 6,574' to 6,625'. Drill 8-1/2"" lateral from 6,625' to 6,669' (3,964' TVD). Drilled 44'
= 58.67'/hr AROP. 450 GPM = 1120 psi, 80 RPM = 14K ft-lbs torque, WOB = 6-8K, PU = 199K, SO = 84K, ROT = 115K. MW = 8.8 ppg, Vis = 41, ECD = 9.86
ppg, max gas units = 101 Daily disposal to G&I = 407 bbls Total disposal to G&I = 7,713 bbls. Daily water hauled from B-Creek = 320 bbls Total water hauled from
B-Creek = 6,510 bbls. Daily fluid loss = 0 bbls Total fluid loss = 122 bbls. Daily metal recovered = 0 lbs Total metal recovered = 0 lbs.
Perform FIT to 12.0 ppg at 6,598' MD / 3,952' TVD with 9.4 ppg MW and 535 psi applied at surface
Continue pumping 2nd stage cement job: Mix and pump an addition 130 bbls for a total of 345 bbls of 10.7 ppg ArcticCem lead cement (671 sxs at 2.883 ft^3/sk
yield) at 5.1 BPM = 550 psi FCP. Mix and pump 56 bbls of 15.8 ppg Premium G tail cement (270 sxs at 1.17 ft^3/sk yield) at 3.9 BPM = 330 psi Drop the closing
plug. Pump 20 bbls of 8.34 ppg fresh water at 5.5 BPM = 300 psi. Displace with 9.5 ppg spud mud at 6 BPM = 400 psi ICP, last 10 bbls slow to 4 BPM= 600 psi
FCP. Bumped the plug @ 1588 strokes, 12 strokes early, CIP @ 07:24 60 BBLS spacer, 38 BBLS of interface and 193 BBLS good 10.7 ppg cement returned,
100% returns during job. Pressure to 2200 psi shifting ESC closed, hold for 5 minutes, bleed off pressure, open block valve to casing, no flow
T 9-5/8" casing to 2,621 psi for 30 minutes charted (good
test).
6/26/2022 Drill 8-1/2" lateral from 6,669' to 7,046' (3,988' TVD). Drilled 377' = 62.83'/hr AROP. 494 GPM = 1490 psi, 120 RPM = 14-15K ft-lbs torque, WOB = 14-15K, PU =
183K, SO = 84K, ROT = 117K. MW = 8.8 ppg, Vis = 38, ECD = 10.2 ppg, max gas units = 1517. Undulate down targeting 86 deg to the OA-3 at 6772'. Target 89.5
deg. MPD choke wide open drilling, at 6747' start holding 100 psi drilling and 200 psi during connections to maintain 10+ ppg ECD. Shakers blinding off at 6968',
screen down front of shakers from 120s to 100s, add 4 drums screen kleen to sys to 3/4% Drill 8-1/2" lateral from 7,046' to 7,523' (3,988' TVD). Drilled 477' =
79.5'/hr AROP. 500 GPM = 1540 psi, 80 RPM = 13K ft-lbs torque, WOB = 12K, PU = 150K, SO = 90K, ROT = 115K. MW = 8.7 ppg, Vis = 40, ECD = 10.1 ppg,
max gas units = 2,607. Target 89.5 deg in the OA-3, MPD holding 100 psi while drilling and on connections. Pump hi-vis sweep at 7,523', back on time with 10%
increase. Drill 8-1/2" lateral from 7,523' to 8,095' (3,964' TVD). Drilled 572' = 95.3'/hr AROP. 500 GPM = 1540 psi, 120 RPM = 12K ft-lbs torque, WOB = 12K, PU =
145K, SO = 80K, ROT = 110K. MW = 8.7 ppg, Vis = 43, ECD = 10.5 ppg, max gas units = 882 MPD chokes open while drilling, holding 165 psi on connections.
Perform planned undulation from the OA-3 to the OA-1 at 7,358' & entered the OA-1 at 7,903' Drill 8-1/2" lateral from 8,095' to 8,264' (3,960' TVD). Drilled 169' =
169'/hr AROP. 500 GPM = 1540 psi, 120 RPM = 12K ft-lbs torque, WOB = 12K, PU = 145K, SO = 80K, ROT = 110K. MW = 8.8 ppg, Vis = 44, ECD = 10.2 ppg,
max gas units = 1720 Crossed Fault #1 at 8,134' (3,962' TVD), 9' DTE throw. Moved the wellbore from the OA-1 to the OA-2. Reentered the OA-1 at 8,197'. Data
exchange issue between the rig and Geologist/Geosteering with data transfer. Slowly BROOH from 8,264' to 8,211' while getting data exchange back up. Wash
and ream back to 8,263'. Drill 8-1/2" lateral from 8,263' to 8,284'. Geologist requested to relog the interval. BROOH from 8,284' to 8,188'. Wash & ream back
down to 8,284'. Drill 8-1/2" lateral from 8,264' to 8,665' (3,971'TVD). Drilled 401' = 133.67'/hr AROP. 500 GPM = 1720 psi, 120 RPM = 13K ft-lbs torque, WOB =
12-14K, PU = 145K, SO = 81K, ROT = 106K. MW = 8.9 ppg, Vis = 42, ECD = 10.57 ppg, max gas units = 427 MPD chokes open while drilling, holding 165 psi on
connections. Targeted 91.0° at 8300’ MD to build up to OA-1. At 8344’ MD, started dropping inclination to 87.5° to level off and move down in OA-1. At 8550’ MD,
targeted 89.0° to level off at dips. Drilled 17 concretions for a total thickness of 11' (1.3% of the lateral). Last survey at 8500.33' MD / 3,959.71' TVD, 88.02° INC,
335.25° AZM, Distance from WP09 = 19.35', 4.68’ high, 18.78’ left. Daily disposal to G&I = 1,599 bbls Total disposal to G&I = 9,312 bbls. Daily water hauled from
B-Creek = 960 bbls Total water hauled from B-Creek = 7,470 bbls. Daily fluid loss = 0 bbls Total fluid loss = 122 bbls. Daily metal recovered = 2 lbs Total metal
recovered = 2 lbs.
6/27/2022 Drill 8-1/2" lateral from 8,665' to 9,426' (3,983'TVD). Drilled 761' = 126.83'/hr AROP. 498 GPM = 1700 psi, 120 RPM = 10K ft-lbs torque, WOB = 9-11K, PU =
148K, SO = 83K, ROT = 112K. MW = 9 ppg, Vis = 40, ECD = 10.65 ppg, max gas units = 2584 MPD chokes open while drilling, holding 165 psi on connections.
Pump hi-vis sweep at 8,567', back on time with 50% increase. Target 89 deg in the OA-1 to 9,300', undulate down targeting 86 deg Drill 8-1/2" lateral from 9,426' to
9,770' (3,993'TVD). Drilled 344' = 57.33'/hr AROP. 500 GPM = 1,740 psi, 120 RPM = 11K ft-lbs torque, WOB =15K, PU = 155K, SO = 80K, ROT = 112K. MW =
8.9 ppg, Vis = 40, ECD = 10.4 ppg, max gas units = 1,770 MPD chokes open while drilling, holding 165 psi on connections. Continue to undulate down and entered
the OA-3 at 9,505'. Pumped 30 bbl hi vis sweep @ 9,617', back on time with no increase. Drill 8-1/2" lateral from 9,770' to 10,117' (4,003'TVD). Drilled 344' =
57.33'/hr AROP. 500 GPM = 1,740 psi, 120 RPM = 9K ft-lbs torque, WOB =15K, PU = 150K, SO = 80K, ROT = 110K. MW = 8.8 ppg, Vis = 38, ECD = 10.4 ppg,
max gas units = 2,024 MPD chokes open while drilling, holding 165 psi on connections. Drill 8-1/2" lateral from 10,117' to 10,473' (4,004'TVD). Drilled 356' =
59.33'/hr AROP. 500 GPM = 1,700 psi, 120 RPM = 9K ft-lbs torque, WOB =15K, PU = 159K, SO = 75K, ROT = 115K. MW = 8.8+ ppg, Vis = 37, ECD = 10.26
ppg, max gas units = 3,112 MPD chokes open while drilling, holding 165 psi on connections. Drilled 40 concretions for a total thickness of 271' (2.6% of the lateral).
Last survey at 10,308.23' MD / 4,001.28' TVD, 89.61° INC, 334.90° AZM, Distance from WP09 = 6.56', 6.56’ low, 0.15’ left. Daily disposal to G&I = 974 bbls Total
disposal to G&I = 10,262 bbls. Daily water hauled from B-Creek = 950 bbls Total water hauled from B-Creek = 8,420 bbls. Daily fluid loss = 0 bbls Total fluid loss
= 122 bbls. Daily metal recovered = 10 lbs Total metal recovered = 12 lbs.
6/28/2022 Drill 8-1/2" lateral from 10,473' to 10,780' (4,007' TVD). Drilled 307' = 51.16'/hr AROP. 557 GPM = 2,025 psi, 120 RPM = 11K ft-lbs torque, WOB =9-18K, PU =
160K, SO = 72K, ROT = 110K. MW = 8.9 ppg, Vis = 40, ECD = 10.49 ppg, max gas units = 2506 MPD choke fully open drilling and holding 165 psi during
connections. Pump 30 BBL hi vis sweep @ 10,665', on time with no increase. Perform planned undulation from the OA-3 to the OA-1 at 10,760'. Drill 8-1/2" lateral
from 10,780' to 11,519' (3,999' TVD). Drilled 739' = 123.17'/hr AROP. 550 GPM = 2,130 psi, 120 RPM = 10K ft-lbs torque, WOB =9K, PU = 266K, SO = 75K, ROT
= 110K. MW = 8.8 ppg, Vis = 40, ECD = 10.7 ppg, max gas units = 1,796 MPD choke fully open drilling and holding 165 psi during connections. Exited the OA-3 at
10,950' and entered the OA-1 at 11,060'. Drill 8-1/2" lateral from 11,519' to 11,996' (4,009' TVD). Drilled 477' = 79.5'/hr AROP. 550 GPM = 2,020 psi, 120 RPM =
11K ft-lbs torque, WOB =14K, PU = 163K, SO = 65K, ROT = 110K. MW = 8.9 ppg, Vis = 39, ECD = 10.8 ppg, max gas units = 1,846 MPD choke fully open drilling
and holding 165 psi during connections. Pumped hi-vis sweep at 11,614', back on time with 50% increase. Drill 8-1/2" lateral from 11,996' to 12,735' (3.989' TVD).
Drilled 739' = 123.17'/hr AROP. 550 GPM = 1920 psi, 120 RPM = 12K ft-lbs torque, WOB =14K, PU = 166K, SO = 57K, ROT = 107K. MW = 9.0 ppg, Vis = 39,
ECD = 10.9 ppg, max gas units = 1,237 MPD choke fully open drilling and holding 165 psi during connections. Pumped hi-vis sweep at 12,567', back on time with
10% increase. At 12,400' begin building, targeting 95° in anticipation of fault #2. Exited the OA-1 at 12,612' entering the NF clays. Drilled 70 concretions for a total
thickness of 422' (7.0% of the lateral). Last survey at 12,497.52' MD / 4,007.26' TVD, 90.31° INC, 332.61° AZM, Distance from WP09 = 38.77', 38.74’ low, 1.39’
right Daily disposal to G&I = 460 bbls Total disposal to G&I = 10,747 bbls. Daily water hauled from B-Creek = 710 bbls Total water hauled from B-Creek = 9,130
bbls. Daily fluid loss = 0 bbls Total fluid loss = 122 bbls. Daily metal recovered = 11 lbs Total metal recovered = 23 lbs.
6/29/2022 Drill 8-1/2" lateral from 12,735' to 13,233' (3968' TVD). Drilled 498' = 83'/hr AROP. 550 GPM = 2120 psi, 120 RPM = 12K ft-lbs TQ, WOB = 9-15K, PU = 160K,
SO = 53K, ROT = 108K. MW = 9.0ppg, Vis = 39, ECD = 11.2 ppg, max gas units = 1237 MPD choke fully open drilling and holding 165 psi during connections.
Fault #2 at 12,860' with 72' DTE throw. Build up to 95° entered OA-3 at 13,040'. Fault #3 at 13,327' with 18' DTE throw. Build up to 94° entered OA-3 at 13,532'.
Drill 8-1/2" lateral from 13,233' to 13,630' (3,954' TVD). Drilled 397' = 66.17'/hr AROP. 550 GPM = 2,170 psi, 120 RPM = 13K ft-lbs TQ, WOB = 14K, PU = 170k,
SO = 40K, ROT = 110K. MW = 8.9 ppg, Vis = 42, ECD = 11.1 ppg, max gas units = 808 MPD choke fully open drilling and holding 165 psi during connections.
Pumped hi-vis sweep at 13,613', back on time with 50% increase. Drill 8-1/2" lateral from 13,630' to 13,783' when the GeoPilot stopped responding to commands.
Troubleshoot the communication issue and got the GeoPilot responding to commands. Drill 8-1/2" lateral from 13,783' to 13,872' when the ADR stopped sending
data. Troubleshoot the communication issue and got the ADR data stream restored. Drill 8-1/2" lateral from 13,872' to 13,899' (3,958' TVD). Drilled 27' = 27'/hr
AROP. 550 GPM = 2,170 psi, 120 RPM = 13K ft-lbs TQ, WOB = 15K, PU = 170K, SO = 40K, ROT = 110K. MW = 8.9 ppg, Vis = 38, ECD = 10.9 ppg, max gas
units = 984. Drill 8-1/2" lateral from 13,899' to 14,374' (3,959' TVD). Drilled 475' = 79.17'/hr AROP. 550 GPM = 2,160 psi, 120 RPM = 13K ft-lbs TQ, WOB = 11K,
PU = 165K, SO = 40K, ROT = 112K. MW = 8.9 ppg, Vis = 38, ECD = 10.8 ppg, max gas units = 3,365 MPD choke fully open drilling and holding 165 psi during
connections. Drilled 82 concretions for a total thickness of 422' (6.8% of the lateral). Last survey at 14,209.73' MD / 3,956.45' TVD, 89.26° INC, 333.31° AZM,
Distance from WP09 = 37.07', 37.00’ low, 2.21' right. Daily disposal to G&I = 1,321 bbls Total disposal to G&I = 12,068 bbls. Daily water hauled from B-Creek =
1,115 bbls Total water hauled from B-Creek = 10,245 bbls. Daily fluid loss = 0 bbls Total fluid loss = 122 bbls. Daily metal recovered = 11 lbs Total metal
recovered = 34 lbs.
6/30/2022 Drill 8-1/2" lateral from 14,374' to 14,877' (3,955' TVD). Drilled 503' = 83.83'/hr AROP. 550 GPM = 2210 PSI, 120 RPM - 14K TQ, WOB = 13K, PU = 180K, SO =
no, ROT = 113K. MW = 8.9 ppg, Vis = 40, ECD = 11.1 ppg, max gas units = 4,031 MPD chokes open while drilling, holding 165 PSI on connections. Pumped high
vis sweep at 14,465', back on time w/ 25% increase. Performed 290 bbl new mud dilution after sweep. Encountered fault #4 at 14,740' with ~15' DTW throw.
Reentered the OA-1 at 14,863'. Drill 8-1/2" lateral from 14,877' to TD at 15,481' (3,966' TVD). Drilled 604' = 100.67'/hr AROP. 550 GPM = 23300 PSI, 120 RPM -
17K TQ, WOB = 10K, PU = 180K, SO = no, ROT = 110K. MW = 8.9 ppg, Vis = 39, ECD = 11.1 ppg, max gas units = 781 MPD chokes open while drilling, holding
165 PSI on connections. Drilled 70 concretions for a total thickness of 422' (7.0% of the lateral). Last survey at 15,481.00’ MD / 3,966.06' TVD, 90.25° INC, 333.14°
AZM, Distance from WP09 = 58.00’, 57.21’ low, 9.55’ right LD a joint of DP. Pump hi-vis sweep, back on time with 10% increase. Circulate 5 BU at 550 GPM =
2,360 psi, 120 RPM = 15K ft-lbs TQ reciprocating 95'. SimOps: Clean pits and prep for displacement to viscosified brine. Continue to circulate while cleaning pits
at 550 GPM = 2,360 psi, 120 RPM = 15K ft-lbs TQ reciprocating 95'. Circulated at total of 9 BU. PJSM. Displace the wellbore to 8.45 ppg viscosified brine: Pump
30 bbl high vis spacer, 25 bbls vis brine, 30 bbls SAPP pill #1, 25 bbls vis brine, 30 bbls SAPP pill #2, 25 bbls vis brine, 30 bbls SAPP pill #3, 30 bbls high vis
spacer. Pump 8.45 ppg 2% KCl 3% lube (1.5% 776 and 1.5% Lo-Torq) at 260 - 310 GPM = 960-1030 psi, 80 RPM = 18K ft-lbs TQ. Daily disposal to G&I = 1,474
bbls Total disposal to G&I = 13,542 bbls. Daily water hauled from B-Creek = 1,185 bbls Total water hauled from B-Creek = 11,430 bbls. Daily fluid loss = 0 bbls
Total fluid loss = 122 bbls. Daily metal recovered = 5 lbs Total metal recovered = 39 lbs.
7/1/2022 Continue displacement to 8.45 ppg lubricated brine. 310 GPM, 850 PSI, 80 RPM, 13-15K TQ. reciprocate 95' alternating stopping points. Shut down when clean
8.45 ppg brine to surface. PST passing results with 2.5, 2.5 and 2.6 sec/330 mL. Monitor pressure with MPD choke closed. 5 min built to 72 PSI, bleed off, 5 min
built to 65 PSI, bleed off and final 5 min built to 60 PSI = 8.8 ppg EMW. Finish cleaning pit #3 and line up to circulate. Load brine into pits 3 & 4. Obtain new SPRs.
200K PU / no SO pumps off. 170K PU / 50K SO pumps on BROOH from 15,481' to 14,565'. Began with 550 GPM = 1,700 psi, 120 RPM = 16K ft-lbs TQ with 25
BPH losses. Slow to 500 GPM = 1,500 psi with losses still at 25 BPH. Slow to 450 GPM = 1,380 psi with 21 BPH losses. 8.45 ppg MW, 10.13 ECD. 5 min/stand
and laying down drill pipe in the mousehole. MPD chokes open while reaming and trapping 165 PSI on connections. BROOH from 14,565' to 12,467' at 5-10
min/stand slowing as needed. 450 GPM = 1,470 psi, 120 RPM = 15K ft-lbs TQ, max gas units = 76. PU = 175K, SO = 75K & ROT = 115K. MPD chokes open while
BROOH & holding 165 psi on connections. BROOH from 12,467' to 10,208' at 5-10 min/stand slowing as needed. 450 GPM = 1,200 psi, 120 RPM = 9K ft-lbs TQ,
max gas units = 51. PU = 165K, SO = 85K & ROT = 115K. MPD chokes open while BROOH & holding 165 psi on connections. Loss rate = 20 BPH (dynamic).
BROOH from 10,208' to 7,999' at 5-10 min/stand slowing as needed. 450 GPM = 1,100 psi, 120 RPM = 7K ft-lbs TQ, max gas units = 101. PU = 145K, SO = 90K
& ROT = 120K. MPD chokes open while BROOH & holding 165 psi on connections. Loss rate = 10-15 BPH (dynamic). Daily disposal to G&I = 1,651 bbls Total
disposal to G&I = 15,192 bbls. Daily water hauled from B-Creek = 355 bbls Total water hauled from B-Creek = 11,785 bbls. Daily fluid loss = 216 bbls Total fluid
loss = 338 bbls. Daily metal recovered = 0 lbs Total metal recovered = 39 lbs.
7/2/2022 BROOH from 7,999' to 6,571', 450 GPM, 1090 PSI, 120 RPM, 3-5K TQ. max gas 126u. 135K PU / 107K SO / 117K ROT. 8.9 ppg MW, 9.7 ECD,
Pull 5-10 min/stands, slowing as needed to clean up slides/tight hole. 5-7K drag observed pulling BHA through shoe
281.7 bbls total lost while BROOH.;Pump 30 bbl high vis sweep. at 450 GPM, 1100 PSI, 80 RPM, 3K TQ, reciprocating 90'. Back on time with no increase.
Observe minor amounts of sand across shakers, continue circulate 2nd BU with 500 GPM, 1200 PSI,, 80 RPM, 3K TQ.
Mobilize trip nipple to the rig floor.;Monitor for pressure build with MPD chokes closed 8.9 ppg MW. 1st 5 min built to 37 PSI, bleed off. 2nd 5 min built to 28 PSI,
bleed off. 3rd 5 min built to 28 PSI.
Weight up pits to 9.1 ppg. Pressure only built to 30 PSI over 45 min.
Sim-ops: service top drive;Circulate the well to 9.1 ppg brine at 450 GPM, 1000 PSI, 80 RPM, 3K TQ, reciprocate 90'.
Perform PST - passing with 3.2, 3.4 & 3.4 sec for each 330 mL.;Monitor for pressure build with MPD chokes closed with 9.1 ppg MW. 1st 5 min built to 30 PSI,
bleed off. 2nd 5 min built to 19 PSI, bleed off.
Perform flow check, 0.5 BPH initial, 0.22 BPH after 5 min then static.;PJSM. Remove MPD RCD and install trip nipple. Fill stack, check for leaks - none.
Pump 30 bbl 10.0 ppg dry job.;TOOH from 6,571' to 294';Observe the well for flow, slight losses. LD the jar stand, float sub and NM flex collars from 294' to
97'.;Download MWD data.;LD remaining BHA from 97' to surface.
Bit grade: 1-1-WT-A-X-I-CT-TD. No abnormal wear or damaged observed on the BHA.;Clear rig floor of BHA components. MU crossover to the bottom of the
FOSV. Pull the split bushings & install the master bushing. Mobilize 4-1/2" handling equipment on power tongs to the rig floor. RU 4-1/2" handling equipment &
power tongs. PJSM.
Monitor the well via TT, static losses = 3 BPH.;PU and MU round nose float shoe with crossover joint. RIH with 4-1/2", 13.5#, L-80, H625, Superior 100 screens
per tally, torque to 9,600 ft-lbs (optimum) to 2,909'. PU = 70K & SO = 68K.;Daily disposal to G&I = 114 bbls; Total disposal to G&I = 15,307 bbls
Daily water hauled from B-Creek = 265 bbls; Total water hauled from B-Creek = 12,050 bbls
Daily fluid loss = 155 bbls; Total fluid loss = 493 bbls
Daily metal recovered = 4 lbs; Total metal recovered = 43 lbs
7/3/2022 Run 4-1/2", 13.5#, L-80, H625, Superior 100 screens per tally from 2,909' to 8,901' - 132K PU / 83K SO. Torque to 9,600 ft-lbs (optimum). Obtained weights at 9-
5/8" shoe 6,562' - 111K PU / 89K SO. M/U Baker 7" x 9-5/8" SLZXP liner top packer to 9062' then RIH one stand of 5" drill pipe to 9,157'. Pump 10 bbls to ensure
clear flow path, 3 BPM, 230 PSI. Obtain parameters: 132K PU / 83K SO / 105K ROT, 10 RPM = 6k TQ, 20 RPM = 5.5k TQ. RIH with 4-1/2" screened liner on 5"
drill pipe from 9,157' to 13,534' out of the derrick. Slack-off weight decreased to 70K at 12,350' and continued down to 65K at 13,439'. From 13,439' to 13,534'
SOW began to decrease as low as 45K, swap to HWDP. Fault #2 @ 12,860' & fault #3 @ 13,327'. RIH with 4-1/2" screened liner on 5" HWDP singles the pipe
shed from 13,534' to 15,476'. PU = 245K & SO = 105K. RIH to tag at 15,487' with 10K down. PU to set depth of 15,481'. Break circulation at 3 BPM = 380 psi.
Drop 1" setting ball. LD joint of DP. MU 10' DP pup with FOSV, side pump in sub and 5' DP pup. MU cement line and test pump. Pump hi-vis sweep and circulate
the ball to seat at 2 BPM = 400 psi. Ball on seat at 760 strokes. Pressure up to 2,700 psi to set the SLZXP. Set 50K, pressure up to 3,500 psi and pusher tool
neutralized. Continue to pressure up with the test pump to 5,400 psi to shear the ITTS ball seat. Verify the SLZXP is set with PU = 180K & SO = 145K. Top of liner
set at 6,430'. RU the test equipment. Purge air from the lines. Close the UPR. PT the LTP to 1,500 psi for 10 minutes charted (good test). RD testing equipment
and blow down lines. Pull the running tool out of the SLZXP while circulating at 6 BPM = 650 psi. Continue to circulate 1.5 BU at 500 GPM = 1,500 psi with
reciprocating 60' (no rotation). Blow down the top drive. Remove the power tongs from the rig floor. POOH laying down 5" HWDP from 6,425' to 4,415'. Loss rate =
4 BPH TIH with 5" DP in the derrick from 4,415' to 6,322'. PJSM. Slip and cut 88' (13 wraps) of drilling line. Daily disposal to G&I = 144 bbls Total disposal to G&I
= 15,451 bbls. Daily water hauled from B-Creek = 265 bbls Total water hauled from B-Creek = 12,315 bbls. Daily fluid loss = 48 bbls Total fluid loss = 541 bbls.
Daily metal recovered = 0 lbs Total metal recovered = 43 lbs.
7/4/2022 Finish slip and cut drilling line. Service the top drive and drawworks. 1.3 BPH static losses while on trip tank. Pump 25 bbl 10 ppg dry job. POOH LD 5" drill pipe
from 6,322' to 45'. LD Baker liner running tool. 19.4 bbls lost. Clear rig floor. Remove wear bushing. RU 7" casing equipment- tongs, slips and elevators. Perform
dummy run with 7" hanger - good. MU crossover sub to FOSV and pump in sub on landing joint. 2 BPH static losses. PJSM. PU Baker seal assembly to 14'. Run
7", 26#, L-80, TXP casing from 14' to 178'. Torque to 14,750 ft-lbs with Doyon double stack tongs. 1 bbl losses. Swap to completions AFE at 18:00.
Verify the SLZXP is set with PU = 180K & SO = 145K. Top of liner
set at 6,430'.
RIH to tag at 15,487' with 10K down. PU to set depth of 15,481'.
TD at 15,481'
Activity Date Ops Summary
7/4/2022 RIH with tie back seal assembly on 7", 26#, L-80, TXP casing from 178' to 4,304'. PU = 112K & SO = 95K. Torque to 14,750 ft-lbs.,RIH with tie back seal assembly
on 7", 26#, L-80, TXP casing from 4,304' to 6,416'. PU = 153K & SO = 110K. Torque to 14,750 ft-lbs. Lost 12 bbls while running casing, Continue to RIH,
observed the seals engage with 5K drag and no-go at 6,442.57' with 5K down. Close the annular and pressure up to 250 psi. PU 8' and observed the pressure
drop. Lay down joint #159, 158 & 157. MU 4.64', 5.67', 5.87' & 14.82' pup joints. MU joint #157 and mandrel casing hanger with landing joint. Land the casing
hanger. RU to reverse circulate.
7/5/2022 Finished rigging up lines to reverse circulate. Close annular on 7" landing joint, pressure up to 300 PSI, strip up 9' and observe pressure dump exposing circulate
ports on seal assembly. PJSM for displacement. Pressure test lines to 1500 PSI.,Reverse circulate 115 bbls of 9.1 ppg corrosion inhibited brine at 5 BPM, 850 PSI.
Reverse circulate 78.25 bbls of 7.0 ppg diesel freeze protection at 3 BPM, 380 PSI ICP / 580 PSI FCP. Clear lines with 5 bbls brine. Land tie-back liner on hanger -
70K on hanger.,Utilize vac truck to suck out lines and BOP stack. L/D 7" landing joint. P/U 2 joints of 5" HWDP and M/U running tool. Set 7" pack-off as per
wellhead rep. RILD. Pressure test pack-off void to 500 PSI for 5 min / 5000 PSI for 10 min. Sim-ops: install diverter tee & diverter on M-29,R/U to pressure test 7" x
9-1/2" OA. Utilize rig pump and pressure up to 1500 PSI, hold test for 30 min on chart - good test. 2.2 bbls pumps. Bleed off and R/D circulating and test
equipment,R/U 4-1/2 casing equipment and Centrilift TEC wire spooler, sheave, equipment and 90 Cannon clamps. Load jewelry in the pipe shed. Test landing
joint TCII threads in hanger - good. PJSM w/ all parties involved. 1.5 BPH losses.,Run 4-1/2” 12.6# L-80 TXP-BTC jet pump completion as per tally. Torque to
6,170 ft/lbs with Doyon double stack tongs. Run 15 joints tubing - first joint has cut mule shoe. M/U XN nipple with RHC-M plug installed at 622’. M/U 7” x 4-1/2”
Baker Premier packer at 693’. M/U Centrilift gauge carrier to 776'. Connect TEC wire to Zenith gauge. MU sliding sleeve to 845'. 1.0 BPH losses.,RIH 4-1/2” 12.6#
L-80 TXP-BTC jet pump completion as per tally spooling Tec wire & installing cannon clamps from 845' to 6,404'. Optimum torque = 6,170 ft-lbs Testing Tec wire
every 1,000'. Lost 17.5 bbls while running completion,PU the tubing hanger and install the BPV. MU the landing joint & MU the tubing hanger to the tubing.
Terminate the Tec wire, feed it through the hanger and secure. Drain the BOP stack. Land the tubing hanger (PU = 90K, SO = 73K & 33K on the hanger) and
RILDS. Mule shoe depth = 6,438'. LD the landing joint.,RD 4-1/2" handling equipment, Tec wire sheave & power tongs. Off load the Tec wire spooling unit and
power tongs. Pull the 30' & 90' mouse holes. Remove the the kill line. Pull the MPD riser. ND the BOP stack, set on pedestal and secure for transport. SimOps:
Cleaning mud pits.,Install the CTS plug into the BPV. Mobilize the tree into the cellar. MU the Tec wire to the tubing head adapter. NU the tree.,Daily disposal to
G&I = 706 bbls; Total disposal to G&I = 16,157 bbls. Daily water hauled from B-Creek = 140 bbls; Total water hauled from B-Creek = 12,685 bbls. Daily fluid loss =
18 bbls; Total fluid loss = 587 bbls. Daily metal recovered = 0 lbs; Total metal recovered = 46 lbs.
7/6/2022 Finish N/U FMC adapter flange and 4-1/16" Cameron 5M tree. Obtain final Centrilift readings: Pt 1714 PSI, Pa 1714 PSI, Tt 74.9°, Ta 74.9°, Bt 20.6 v. Pressure
test tree to 250 PSI low / 5000 PSI high. Remove BPV & CTS plug.,R/U circulating lines and pressure test to 3800 PSI. Reverse circulate 120 bbls 9.1 ppg
corrosion inhibited brine down the 4-1/2" x 7" IA - 100% returns. 3 BPM, 580 PSI.,Drop 1.75" ball on roller rod with 2" rollers. Allow ball to fall for 30 minutes.
Replace 2" Chiksan swing and re-test lines to 3800 PSI.,Pressure up to 3500 PSI and set Baker 4-1/2" x 7" premier packer. 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.,Blow down circulating lines and manifold.
R/D all lines and manifold. Secure well. 0 PSI on tubing, 0 PSI on IA, 0 PSI on OA. Rig on generator power at 15:30,Clear and clean cellar. Rig welder cut
mousehole from cellar box and seal weld. Sim-ops: Blow down mud pumps and clean mud pits. Release rig @ 18:00.
Well Name:
Field:
County/State:
MP M-28
Milne Point
Hilcorp Energy Company Composite Report
, Alaska
6/17/2022Spud Date:
Pressure test 4-1/2" x 7" IA to 3500 PSI for 30 min on chart - good.,
Utilize rig pump and pressure up to 1500 PSI, hold test for 30 min on chart - good test.
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
1
1
1
1
103
1
1
1
58
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:
1.17
6/23/2022 Surface
Spud Mud
Type I/II cement 555 2.35
Premium G cement 400 1.16
4.5
2,455.57
Casing 9 5/8 47.0 L-80 TXP-BTC Tenaris 2,382.23 2,455.57 73.34
2,475.89 2,473.05
Casing Pup Joint 9 5/8 40.0 L-80 TXP-BTC 17.48 2,473.05
17.55 2,493.44 2,475.89
ES Cementer 10 3/4 TXP-BTC Halliburton 2.84
Casing Pup Joint 9 5/8 40.0 L-80 TXP-BTC
6,471.44
Casing 9 5/8 40.0 L-80 TXP-BTC Tenaris 3,978.00 6,471.44 2,493.44
6,512.92 6,472.85
Baffle Adapter 10 3/4 TXP-BTC Halliburton 1.41 6,472.85
1.31 6,514.23 6,512.92
Casing 9 5/8 40.0 L-80 TXP-BTC Tenaris 40.07
Float Collar 10 3/4 TXP-BTC Innovex
83 total 9-5/8" x 12"1/4" bowspring centralizers ran. Two in shoe joint w/ stop rings 10' from each end. One floating on joint
#2. One each with stop rings mid-joint on joint #3 & 4.
One each on joints 5 to 25, every other joint to #49 then every third joint to #97. One each on joints #99 to #108. One each
with stop rings on pup joints above and below ES cementer.
One each on every third joint #11 to #159.
Casing 9 5/8 40.0 L-80 TXP-BTC Tenaris 82.17 6,596.40 6,514.23
www.wellez.net WellEz Information Management LLC ver_04818br
4.25
Ftg. Returned
Ftg. Cut Jt.16.63 Ftg. Balance
No. Jts. Delivered No. Jts. Run
Length Measurements W/O Threads
Ftg. Delivered Ftg. Run
RKB to CHF
Type of Shoe:Innovex Casing Crew:Doyon
12 232
ES Cementer Closure OK
56
ArcticCem cement
Type
Premium G cement 270
Tuned Spacer
671 2.88
Stage Collar @
60
Bump press
100
193
6,598.006,605.00 6,473.00
CEMENTING REPORT
Csg Wt. On Slips:100,000
Spud Mud
18:18 6/22/2022 2,473
2473
15.8 82
Bump press
Cement to surface
Bump Plug?
3.9
9.5 6 180.3/181.5
480.5/484.5
1300
10
Rig
FI
R
S
T
S
T
A
G
E
10Tuned Spacer 60
15.8
600
9.5 6
2200
10
10.7 345 4.6
100
700
Bump Plug?
Csg Wt. On Hook:283 Type Float Collar:Innovex No. Hrs to Run:19
TXP-BTC Innovex 1.60 6,598.00 6,596.40
Setting Depths
Component Size Wt. Grade THD Make Length Bottom Top
Hilcorp Energy Company
CASING & CEMENTING REPORT
Lease & Well No.MP M-28 Date Run 21-Jun-22
CASING RECORD
County State Alaska Supv.D. Yessak / J. Vanderpool
6,513.00
Floats Held
401.96 715
203 512
Spud Mud
Rotate Csg Recip Csg Ft. Min. PPG9.5
Shoe @ 6598 FC @ Top of Liner
SE
C
O
N
D
S
T
A
G
E
Rig
7:24
Cement to surface
361.69 5828 30.42
Casing (Or Liner) Detail
Shoe 10 3/4
X
Surface
X
Cement to surface
Cement to surface
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Chelsea Wright Digitally signed by Chelsea
Wright
Date: 2022.07.06 11:18:18 -08'00'
Benjamin Hand Digitally signed by Benjamin Hand
Date: 2022.07.06 16:14:20 -08'00'
David Douglas Hilcorp Alaska, LLC
Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 777-8337
E-mail: david.douglas@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Date: 07/20/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL :
WELL: MPU M-28
PTD: 222-053
API: 50-029-23717-00-00
FINAL LWD FORMATION EVALUATION LOGS (06/14/2022 to 07/05/2022)
x ROP, AGR, ABG, DGR, EWR-M5, ADR, Horizontal Presentation (2” & 5” MD/TVD Color Logs)
x Final Definitive Directional Survey
x Final Geosteering and EOW Report/Plots
SFTP Transfer – Main Folders:
FINAL LWD Subfolders:
FINAL Geosteering Subfolders:
Please include current contact information if different from above.
PTD:222-053
T36819
Kayla Junke
Digitally signed by Kayla
Junke
Date: 2022.07.22 09:04:40
-08'00'
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________MILNE PT UNIT M-28
JBR 07/21/2022
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:0
Test was completed with a 4-1/2", 5" and 7" test jionts. Closure times; Annular 14 sec, upper VBR 8 sec, Blinds 8 sec, lower
VBR 8 sec, HCR Kill 3 sec, HCR Choke 4 sec.
Test Results
TEST DATA
Rig Rep:Hansen/CarloOperator:Hilcorp Alaska, LLC Operator Rep:Yessak/Toomey
Contractor/Rig No.:Doyon 14 PTD#:2220530 DATE:6/24/2022
Type Operation:DRILL Annular:
250/2500Type Test:INIT
Valves:
250/3000
Rams:
250/3000
Test Pressures:Inspection No:bopLOL220627075005
Inspector Lou Laubenstein
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 6
MASP:
1358
Sundry No:
Location Gen.:P
Housekeeping:P
PTD On Location P
Standing Order Posted P
Well Sign P
Drl. Rig P
Hazard Sec.P
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 PHydraulic Chokes
0 NACH Misc
Stripper 0 NA
Annular Preventer 1 13-5/8"P
#1 Rams 1 4-1/2" x 7" vb P
#2 Rams 1 Blinds P
#3 Rams 1 2-7/8"x5" VB 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 P3000
Pressure After Closure P1650
200 PSI Attained P45
Full Pressure Attained P190
Blind Switch Covers:Pyes
Nitgn. Bottles (avg):P6 @ 2025
ACC Misc NA0
P PTrip Tank
P PPit Level Indicators
P PFlow Indicator
P PMeth Gas Detector
P PH2S Gas Detector
NA NAMS Misc
Inside Reel Valves 0 NA
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
DIVERTER Test Report for:
Reviewed By:
P.I. Suprv
Comm ________MILNE PT UNIT M-28
JBR 07/20/2022
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:Tested w 5" DP , good test.
TEST DATA
Rig Rep:T. Shones / A. CarloOperator:Hilcorp Alaska, LLC Operator Rep:C.A. Demoski
Contractor/Rig No.:Doyon 14 PTD#:2220530 DATE:6/15/2022
Well Class:DEV Inspection No:divAGE220621160148
Inspector Adam Earl
Inspector
Insp Source
Related Insp No:
Test Time:1
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:0 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:206 P
Closest Ignition Source:87 P
Outlet from Rig Substructure:203 P
Vent Line(s) Anchored:P
Turns Targeted / Long Radius:P
Divert Valve(s) Full Opening:P
Valve(s) Auto & Simultaneous:
Annular Closed Time:25 P
Knife Valve Open Time:17 P
Diverter Misc:0 NA
Systems Pressure:P2950
Pressure After Closure:P1800
200 psi Recharge Time:P37
Full Recharge Time:P163
Nitrogen Bottles (Number of):P6
Avg. Pressure:P1950
Accumulator Misc:NA0
P PTrip Tank:
P PMud Pits:
P PFlow Monitor:
0 NAMud System Misc:
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Monty M. Myers
Drilling Manager
Hilcorp Alaska, LLC
3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Re: Milne Point Field, Schrader Bluff Oil Pool, MPU M-28
Hilcorp Alaska, LLC
Permit to Drill Number: 222-053
Surface Location: 4913' FSL, 111' FEL, Sec. 14, T13N, R09E, UM, AK
Bottomhole Location: 2171' FNL, 1413' FEL, Sec. 02, T13N, R09E, UM, AK
Dear Mr. Myers:
Enclosed is the approved application for the permit to drill the above referenced well.
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,composite curves for well logs
run must be submitted to the AOGCCwithin 90 days after completion, suspension or abandonment
of this well.
This permit to drill does not exempt you from obtaining additional permits or an approval required
by law from other governmental agencies and does not authorize conducting drilling operations
until all other required permits and approvals have been issued. In addition, the AOGCC reserves
the right to withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska
Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply
with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code,
or an AOGCC order, or the terms and conditions of this permit may result in the revocation or
suspension of the permit.
Sincerely,
Jeremy M. Price
Chair
DATED this ___ day of May, 2022.
Jeremy
Price
Digitally signed by
Jeremy Price
Date: 2022.05.20
13:24:58 -08'00'
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0600120018002400300036004200True Vertical Depth (1200 usft/in)-2400 -1800 -1200 -600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000Vertical Section at 333.00° (1200 usft/in)M-28 wp06 tgt1M-28 wp06 tgt2M-28 wp06 tgt3M-28 wp06 tgt4M-28 wp06 tgt5M-28 wp06 tgt6M-28 wp06 tgt7M-28 wp06 tgt8M-28 wp06 tgt9M-28 wp06 tgt10M-28 wp06 tgt11M-28 wp06 tgt129 5/8" x 12 1/4"4 1/2" x 8 1/2"500100015002 0 0 0
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400045005000550060006500700075008000850090009500100001050011000115001200012500130001350014000145001500015385MPU M-28 wp06Start Dir 3º/100' : 400' MD, 400'TVDStart Dir 4º/100' : 700' MD, 698.77'TVDEnd Dir : 2019.82' MD, 1740.06' TVDStart Dir 4.5º/100' : 3434.47' MD, 2414.81'TVDEnd Dir : 6308.66' MD, 3932.25' TVDStart Dir 2º/100' : 6608.66' MD, 3958.4'TVDEnd Dir : 6816.81' MD, 3969' TVDStart Dir 2º/100' : 7802.86' MD, 3983.4'TVDEnd Dir : 8046.02' MD, 3976.64' TVDStart Dir 2º/100' : 8103.44' MD, 3972.6'TVDEnd Dir : 8312.97' MD, 3965.54' TVDStart Dir 2.25º/100' : 9337.97' MD, 3968.4'TVDEnd Dir : 9568.33' MD, 3979.45' TVDStart Dir 2.25º/100' : 9601.95' MD, 3982.58'TVDEnd Dir : 9833.66' MD, 3993.64' TVDStart Dir 2.5º/100' : 10608.66' MD, 3995.4'TVDEnd Dir : 10819.82' MD, 3986.16' TVDStart Dir 2.5º/100' : 10914.67' MD, 3977.65'TVDEnd Dir : 11120.7' MD, 3968.4' TVDStart Dir 2º/100' : 12250.7' MD, 3968.4'TVDEnd Dir : 12469.33' MD, 3960.06' TVDStart Dir 2º/100' : 12715.44' MD, 3941.3'TVDEnd Dir : 12893.58' MD, 3933.24' TVDStart Dir 2º/100' : 13943.58' MD, 3918.4'TVDEnd Dir : 14010.51' MD, 3916.67' TVDEnd Dir : 14284.88' MD, 3908.4' TVDTotal Depth : 15384.88' MD, 3908.4' TVDSV5Base PermafrostUG Coal 1LA3UG_MBSB NASB OAHilcorp Alaska, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: Plan: MPU M-28iGround Level: 24.70+N/-S +E/-WNorthingEastingLatitudeLongitude0.000.006027766.01534054.01 70° 29' 12.776 N 149° 43' 17.995 WSURVEY PROGRAMDate: 2016-07-15T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool33.70 6609.00 MPU M-28 wp06 (MPU M-28i) GYD_Quest GWD6609.00 15384.88 MPU M-28 wp06 (MPU M-28i) GYD_Quest GWDFORMATION TOP DETAILSTVDPath TVDssPath MDPath Formation1343.40 1285.00 1407.21 SV51888.40 1830.00 2330.83 Base Permafrost2836.40 2778.00 4149.04 UG Coal 13225.40 3167.00 4714.71 LA33492.40 3434.00 5127.00 UG_MB3768.40 3710.00 5663.74 SB NA3939.38 3880.98 6390.43 SB OAREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU M-28i, True NorthVertical (TVD) Reference:M-28 as staked RKB @ 58.40usftMeasured Depth Reference:M-28 as staked RKB @ 58.40usftCalculation Method:Minimum CurvatureProject:Milne PointSite:M Pt Moose PadWell:Plan: MPU M-28iWellbore:MPU M-28iDesign:MPU M-28 wp06CASING DETAILSTVD TVDSS MD SizeName3958.43 3900.03 6609.00 9-5/8 9 5/8" x 12 1/4"3908.40 3850.00 15384.88 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 0.002 400.00 0.00 0.00 400.00 0.00 0.00 0.00 0.00 0.00 Start Dir 3º/100' : 400' MD, 400'TVD3 700.00 9.00 100.00 698.77 -4.08 23.16 3.00 100.00 -14.15 Start Dir 4º/100' : 700' MD, 698.77'TVD4 2019.82 61.51 113.69 1740.06 -274.42 704.90 4.00 15.14 -564.52 End Dir : 2019.82' MD, 1740.06' TVD5 3434.47 61.51 113.69 2414.81 -773.91 1843.50 0.00 0.00 -1526.49 Start Dir 4.5º/100' : 3434.47' MD, 2414.81'TVD6 6308.66 85.00 333.20 3932.25 668.13 2800.31 4.50 -124.96 -676.00 End Dir : 6308.66' MD, 3932.25' TVD7 6608.66 85.00 333.20 3958.40 934.89 2665.56 0.00 0.00 -377.15 M-28 wp06 tgt1 Start Dir 2º/100' : 6608.66' MD, 3958.4'TVD8 6816.81 89.16 333.20 3969.00 1120.40 2571.86 2.00 0.05 -169.32 End Dir : 6816.81' MD, 3969' TVD9 7802.86 89.16 333.20 3983.40 2000.47 2127.38 0.00 0.00 816.62 M-28 wp06 tgt2 Start Dir 2º/100' : 7802.86' MD, 3983.4'TVD10 8046.02 94.03 333.22 3976.64 2217.39 2017.87 2.00 0.23 1059.61 End Dir : 8046.02' MD, 3976.64' TVD11 8103.44 94.03 333.22 3972.60 2268.52 1992.07 0.00 0.00 1116.89 Start Dir 2º/100' : 8103.44' MD, 3972.6'TVD12 8312.97 89.84 333.03 3965.54 2455.28 1897.43 2.00 -177.35 1326.25 End Dir : 8312.97' MD, 3965.54' TVD13 9337.97 89.84 333.03 3968.40 3368.80 1432.57 0.00 0.00 2351.25 M-28 wp06 tgt4 Start Dir 2.25º/100' : 9337.97' MD, 3968.4'TVD14 9568.33 84.66 333.10 3979.45 3573.86 1328.39 2.25 179.18 2581.26 End Dir : 9568.33' MD, 3979.45' TVD15 9601.95 84.66 333.10 3982.58 3603.72 1313.24 0.00 0.00 2614.74 Start Dir 2.25º/100' : 9601.95' MD, 3982.58'TVD16 9833.66 89.87 333.01 3993.64 3809.97 1208.41 2.25 -1.03 2846.10 End Dir : 9833.66' MD, 3993.64' TVD17 10608.66 89.87333.01 3995.40 4500.56 856.69 0.00 0.00 3621.10 M-28 wp06 tgt6 Start Dir 2.5º/100' : 10608.66' MD, 3995.4'TVD18 10819.82 95.15 332.89 3986.16 4688.38 760.79 2.50 -1.28 3831.99 End Dir : 10819.82' MD, 3986.16' TVD19 10914.67 95.15 332.89 3977.65 4772.47 717.74 0.00 0.00 3926.46 Start Dir 2.5º/100' : 10914.67' MD, 3977.65'TVD20 11120.70 90.00 333.06 3968.40 4955.75 624.26 2.50 178.13 4132.20 End Dir : 11120.7' MD, 3968.4' TVD21 12250.70 90.00 333.06 3968.40 5963.13 112.30 0.00 0.00 5262.20 M-28 wp06 tgt8 Start Dir 2º/100' : 12250.7' MD, 3968.4'TVD22 12469.33 94.37 333.05 3960.06 6157.84 13.33 2.00 -0.12 5480.63 End Dir : 12469.33' MD, 3960.06' TVD23 12715.44 94.37 333.05 3941.30 6376.58 -97.88 0.00 0.00 5726.01 Start Dir 2º/100' : 12715.44' MD, 3941.3'TVD24 12893.58 90.81 333.02 3933.24 6535.17 -178.56 2.00 -179.50 5903.95 End Dir : 12893.58' MD, 3933.24' TVD25 13943.58 90.81 333.02 3918.40 7470.80 -654.88 0.00 0.00 6953.84 M-28 wp06 tgt10 Start Dir 2º/100' : 13943.58' MD, 3918.4'TVD26 14010.51 92.15 333.03 3916.67 7530.43 -685.22 2.00 0.64 7020.75 End Dir : 14010.51' MD, 3916.67' TVD27 14177.45 92.15 333.03 3910.41 7679.12 -760.87 0.00 0.00 7187.5728 14284.88 90.00 333.02 3908.40 7774.84 -809.58 2.00-179.607294.97 End Dir : 14284.88' MD, 3908.4' TVD29 15384.88 90.00 333.02 3908.40 8755.12 -1308.63 0.00 0.00 8394.97 M-28 wp06 tgt12 Total Depth : 15384.88' MD, 3908.4' TVD
-1200
-600
0
600
1200
1800
2400
3000
3600
4200
4800
5400
6000
6600
7200
7800
8400
9000
9600
10200
South(-)/North(+) (1200 usft/in)-4800 -4200 -3600 -3000 -2400 -1800 -1200 -600 0 600 1200 1800 2400 3000 3600
West(-)/East(+) (1200 usft/in)
M-28 wp06 tgt12
M-28 wp06 tgt11
M-28 wp06 tgt10
M-28 wp06 tgt9
M-28 wp06 tgt8
M-28 wp06 tgt7
M-28 wp06 tgt6
M-28 wp06 tgt5
M-28 wp06 tgt4
M-28 wp06 tgt3
M-28 wp06 tgt2
M-28 wp06 tgt1
9 5/8" x 12 1/4"
4 1/2" x 8 1/2"100015001750200022502500275030003
2
5
0
3500
375 0
3 9 0 8
M P U M -2 8 w p 0 6
Start Dir 3º/100' : 400' MD, 400'TVD
Start Dir 4º/100' : 700' MD, 698.77'TVD
End Dir : 2019.82' MD, 1740.06' TVD
Start Dir 4.5º/100' : 3434.47' MD, 2414.81'TVD
End Dir : 6308.66' MD, 3932.25' TVD
Start Dir 2º/100' : 6608.66' MD, 3958.4'TVD
End Dir : 6816.81' MD, 3969' TVD
Start Dir 2º/100' : 7802.86' MD, 3983.4'TVD
End Dir : 8046.02' MD, 3976.64' TVD
Start Dir 2º/100' : 8103.44' MD, 3972.6'TVD
End Dir : 8312.97' MD, 3965.54' TVD
Start Dir 2.25º/100' : 9337.97' MD, 3968.4'TVD
End Dir : 9568.33' MD, 3979.45' TVD
Start Dir 2.25º/100' : 9601.95' MD, 3982.58'TVD
End Dir : 9833.66' MD, 3993.64' TVD
Start Dir 2.5º/100' : 10608.66' MD, 3995.4'TVD
End Dir : 10819.82' MD, 3986.16' TVD
Start Dir 2.5º/100' : 10914.67' MD, 3977.65'TVD
End Dir : 11120.7' MD, 3968.4' TVD
Start Dir 2º/100' : 12250.7' MD, 3968.4'TVD
End Dir : 12469.33' MD, 3960.06' TVD
Start Dir 2º/100' : 12715.44' MD, 3941.3'TVD
End Dir : 12893.58' MD, 3933.24' TVD
Start Dir 2º/100' : 13943.58' MD, 3918.4'TVD
End Dir : 14010.51' MD, 3916.67' TVD
End Dir : 14284.88' MD, 3908.4' TVD
Total Depth : 15384.88' MD, 3908.4' TVD
CASING DETAILS
TVD TVDSS MD Size Name
3958.43 3900.03 6609.00 9-5/8 9 5/8" x 12 1/4"
3908.40 3850.00 15384.88 4-1/2 4 1/2" x 8 1/2"
Project: Milne Point
Site: M Pt Moose Pad
Well: Plan: MPU M-28i
Wellbore: MPU M-28i
Plan: MPU M-28 wp06
WELL DETAILS: Plan: MPU M-28i
Ground Level: 24.70
+N/-S +E/-W Northing Easting Latitude Longitude
0.00 0.00
6027766.01 534054.01 70° 29' 12.776 N 149° 43' 17.995 W
REFERENCE INFORMATION
Co-ordinate (N/E) Reference:Well Plan: MPU M-28i, True North
Vertical (TVD) Reference: M-28 as staked RKB @ 58.40usft
Measured Depth Reference:M-28 as staked RKB @ 58.40usft
Calculation Method:Minimum Curvature
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0.001.002.003.004.00Separation Factor0 350 700 1050 1400 1750 2100 2450 2800 3150 3500 3850 4200 4550 4900 5250 5600 5950 6300 6650Measured Depth (700 usft/in)MPU M-11M-09DSW wp02- AP HillNo-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:Plan: MPU M-28i NAD 1927 (NADCON CONUS)Alaska Zone 04Ground Level: 24.70+N/-S +E/-W Northing EastingLatitudeLongitude0.000.006027766.01534054.0170° 29' 12.776 N149° 43' 17.995 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU M-28i, True NorthVertical (TVD) Reference:M-28 as staked RKB @ 58.40usftMeasured Depth Reference:M-28 as staked RKB @ 58.40usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2016-07-15T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool33.70 6609.00 MPU M-28 wp06 (MPU M-28i) GYD_Quest GWD6609.00 15384.88 MPU M-28 wp06 (MPU M-28i) GYD_Quest GWD0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)0 350 700 1050 1400 1750 2100 2450 2800 3150 3500 3850 4200 4550 4900 5250 5600 5950 6300 6650Measured Depth (700 usft/in)MPU M-13M-30i wp02MPU M-44iMPU M-14MPU M-43MPU M-10MPU M-12MPU M-29 wp06MPU M-11M-09DSW wp02- AP HillMPU M-27 wp06MPU M-45GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference33.70 To 15384.88Project: Milne PointSite: M Pt Moose PadWell: Plan: MPU M-28iWellbore: MPU M-28iPlan: MPU M-28 wp06Ladder / S.F. Plots1 of 2CASING DETAILSTVD TVDSS MD Size Name3958.43 3900.03 6609.00 9-5/8 9 5/8" x 12 1/4"3908.40 3850.00 15384.88 4-1/2 4 1/2" x 8 1/2"
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0.001.002.003.004.00Separation Factor6650 7125 7600 8075 8550 9025 9500 9975 10450 10925 11400 11875 12350 12825 13300 13775 14250 14725 15200 15675Measured Depth (950 usft/in)M-30i wp02MPU M-29 wp06MPU M-27 wp06No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:Plan: MPU M-28i NAD 1927 (NADCON CONUS)Alaska Zone 04Ground Level: 24.70+N/-S +E/-W Northing EastingLatitudeLongitude0.000.006027766.01534054.0170° 29' 12.776 N149° 43' 17.995 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU M-28i, True NorthVertical (TVD) Reference:M-28 as staked RKB @ 58.40usftMeasured Depth Reference:M-28 as staked RKB @ 58.40usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2016-07-15T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool33.70 6609.00 MPU M-28 wp06 (MPU M-28i) GYD_Quest GWD6609.00 15384.88 MPU M-28 wp06 (MPU M-28i) GYD_Quest GWD0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)6650 7125 7600 8075 8550 9025 9500 9975 10450 10925 11400 11875 12350 12825 13300 13775 14250 14725 15200 15675Measured Depth (950 usft/in)GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference33.70 To 15384.88Project: Milne PointSite: M Pt Moose PadWell: Plan: MPU M-28iWellbore: MPU M-28iPlan: MPU M-28 wp06Ladder / S.F. Plots2 of 2CASING DETAILSTVD TVDSS MD Size Name3958.43 3900.03 6609.00 9-5/8 9 5/8" x 12 1/4"3908.40 3850.00 15384.88 4-1/2 4 1/2" x 8 1/2"
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