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:Thursday, December 22, 2022
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Bob Noble
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
Hilcorp Alaska, LLC
B-31
MILNE PT UNIT B-31
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 12/22/2022
B-31
50-029-23723-00-00
222-084-0
N
SPT
4445
2220840 3500
154 147 141 166
INITAL P
Bob Noble
11/5/2022
MIT-IA to 3500 as PTD
30 MinPretest Initial 15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:
MILNE PT UNIT B-31
Inspection Date:
Tubing
OA
Packer Depth
304 3700 3583 3536IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitRCN221110153756
BBL Pumped:6.8 BBL Returned:6.5
Thursday, December 22, 2022 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: 22.9' BF:
Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation:
4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number:
Surface: x- y- Zone- 4
TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD:
Total Depth: x- y- Zone- 4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 (ft MSL)
22.Logs Obtained:
23.
BOTTOM
20" X-52 149'
L-80 1901'
L-80 4459'
4-1/2" L-80 4558'
24. Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr):
Press. 24-Hour Rate
9-5/8"12-1/4"
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
CASING, LINER AND CEMENTING RECORD
List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion,
Uncemented Drilled Liner8-1/2"
TUBING RECORD
Liner Top Packer
6309'3-1/2" 9.3# L-80
SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date Perfd):
Stg 2 L - 680 sx / 270 sx
Driven
Surface 2075' Stg 1 L - 595 sx / T - 379 sx
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
8/21/2022
5264' FSL, 4298' FEL, Sec. 19, T13N, R11E, UM, AK
1106' FSL, 2054' FWL, Sec. 11, T13N, R10E, UM, AK
222-084
Milne Point Field / Schrader Bluff Oil Pool
56.82'
13828' / 4558'
8/16/2022
8/2/2022
HOLE SIZE AMOUNT
PULLED
50-029-23723-00-00
MPU B-31
571994 6023107
1773' FSL, 2549' FWL, Sec. 13, T13N, R10E, UM, AK
CEMENTING RECORD
6024862
SETTING DEPTH TVD
6029423
BOTTOM TOP
Surface
Surface
ROP, AGR, DGR, ABG, EWR, ADR MD & TVD
CASING WT. PER
FT.GRADE
13.5#
568332
562514
TOP
SETTING DEPTH MD
Surface
6297'
Per 20 AAC 25.283 (i)(2) attach electronic information
40#
13830'
1901'
4445'
DEPTH SET (MD)
6297' / 4445'
PACKER SET (MD/TVD)
129.5#
47#
149'
2075' 6493'
Gas-Oil Ratio:Choke Size:Water-Bbl:
PRODUCTION TEST
*Pre-Produced, converted to Injector 9/25/2022*
Date of Test:
Flow Tubing
Oil-Bbl:
suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray,
caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation
record. Acronyms may be used. Attach a separate page if necessary
Water Injection
4-1/2" Drilled Liner 8/18/2022
6489' - 13463' 4459' - 4525'
Sr Res EngSr Pet GeoSr Pet Eng
Oil-Bbl: Water-Bbl:
ADL 047438, 047437 & 047433
81-054
1938' / 1786'
N/AN/A
None
13830' / 4558'
Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment
By James Brooks at 8:00 am, Sep 28, 2022
Completed
8/21/2022
JSB
RBDMS JSB 10132022
GMGR12NOV2022DSR-10/14/22
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
27' 27'
1965' 1813'
Top of Productive Interval 6393' 4452'
2371' 2120'
5110' 3874'
5874' 4327'
6393' 4452'
SB OA 6393' 4452'
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: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
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:
Schrader Bluff NA
LOT / FIT Data Sheet, Drilling and Completion Reports, Post-Rig Summary, Casing and Cement Report, Definitive Directional
Survey, Wellbore Schematic
Signature w/Date:
Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
INSTRUCTIONS
Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
TPI (Top of Producing Interval).
Yes No
Well tested? Yes No
28. CORE DATA
If yes, list intervals and formations tested, briefly summarizing test results.
Attach separate pages to this form, if needed, and submit detailed test
information, including reports, per 20 AAC 25.071.
NAME
Schrader Bluff OA
SV3
Ugnu LA3
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram
with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical
reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted.
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis,
paleontological report, production or well test results, per 20 AAC 25.070.
If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form,
if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071.
Authorized Name: Monty Myers
Authorized Title: Drilling Manager
Permafrost - Base
29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS
Permafrost - Top
Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment
9.27.2022Digitally 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: 2022.09.27 14:16:51 -08'00'
Monty M
Myers
CASING AND LEAK-OFF FRACTURE TESTS
Well Name:MPU B-31 Date:8/11/2022
Csg Size/Wt/Grade:9.625"40# x 47#, L-80 Supervisor:Yessak/Vanderpool
Csg Setting Depth:6493 TMD 4459 TVD
Mud Weight:9.4 ppg LOT / FIT Press =602 psi
.
LOT / FIT =12.00 Hole Depth =6521 md
Fluid Pumped=1.2 Bbls Volume Back =1.0 bbls
Estimated Pump Output:0.101 Barrels/Stroke
LOT / FIT DATA CASING TEST DATA
Enter Strokes Enter Pressure Enter Strokes Enter Pressure
Here Here Here Here
->00 ->00
->160 ->4150
->2 121 ->8390
->3 180 ->12 570
->4 206 ->16 750
->5 271 ->20 942
->6 319 ->24 1162
->7 380 ->28 1375
->8 423 ->32 1595
->9 457 ->36 1828
->10 498 ->40 2084
->11 540 ->44 2336
->12 602 ->49 2600
->13 ->
Enter Holding Enter Holding Enter Holding Enter Holding
Time Here Pressure Here Time Here Pressure Here
->0 600 ->0 2600
->1 582 ->5 2590
->2 579 ->10 2580
->3 573 ->15 2575
->4 570 ->20 2572
->5 568 ->25 2570
->6 565 ->26 2570
->7 543 ->27 2570
->8 541 ->28 2570
->9 540 ->29 2570
->10 538 ->30 2570
->11 537 ->
->12 535 ->
->13 534 ->
->14 533
->15
->
0
1
2
3 4
5
6
7
8 9 10
11
12
0
4
8
12
16
20
24
28
32
36
40
44
49
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
)
600582579573570568565543541540538537535534533
2600 2590 2580 2575 2572 257025702570257025702570
0
100
200
300
400
500
600
700
800
900
1000
1100
1200
1300
1400
1500
1600
1700
1800
1900
2000
2100
2200
2300
2400
2500
2600
2700
2800
2900
3000
0 5 10 15 20 25 30 35
Pr
e
s
s
u
r
e
(p
s
i
)
Time (Minutes)
LOT / FIT DATA CASING TEST DATA
_____________________________________________________________________________________
Revised By: JNL 8/25/2022
SCHEMATIC
Milne Point Unit
Well: MPU B-31
Last Completed: 8/21/2022
PTD: 222-084
4-1/2” Drilled Liner
Top (MD) Top (TVD) Btm (MD) Btm (TVD)
6489’ 4459’ 13463’ 4525’
CASING DETAIL
Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF
20" Conductor 129.5 / X-52 / Weld N/A Surface 149’ N/A
9-5/8" Surface 47 / L-80 / TXP 8.525” Surface 2,075’ 0.0732
9-5/8" Surface 40 / L-80 / TXP 8.679” 2,075’ 6,493’ 0.0758
4-1/2” Solid / Slotted Liner 13.5 / L-80 / Hyd 625 3.920” 6,297’ 13,830’ 0.0149
TUBING DETAIL
3-1/2" Tubing 9.3 / L-80 / EUE 8RD 2.9924459” Surface 6,309’ 0.0087
OPEN HOLE / CEMENT DETAIL
Driven 20” Conductor
12-1/4"Stg 1 –Lead 595 sx / Tail 379 sx
Stg 2 –Lead 680 sx / Tail 270 sx
8-1/2” Uncemented Drilled 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#: 50-029-23723-00-00
Completion Date: TBD
WELL INCLINATION DETAIL
KOP @ 301’
90° Angle @ 6,589’ MD
TD =13,830’(MD) / TD =4,558’(TVD)
20”
Orig. KB Elev.:56.82’ / GL Elev.:22.9’
3-1/2”
7
2
9-5/8”
1
4/5
See
Slotted
Liner
Detail
PBTD =13,828’(MD) / PBTD =4,558’(TVD)
9-5/8” ‘ES’
Cementer @
2,092’
4-1/2”
6
3
JEWELRY DETAIL
No Top MD Item
ID
Upper Completion
1 5,890’ Sliding Sleeve 2.813” X profile, covered ports (opens down) 2.813”
2 5,945’ Zenith Gauge Carrier 2.992”
3 5,997’ 2.813” XN Nipple, 2.75” No-Go 2.750”
4 6,298’ Locator Sub, 8.25” No-Go (spaced out 2.07’) 6.170”
5 6,298’ Bullet Seals – TXP Top Box x Mule Shoe 6.170”
Lower Completion
6 6,297’ 9-5/8” SLZXP Liner Top Packer 6.190”
7 13,828’ Shoe
Activity Date Ops Summary
7/30/2022 Continue rig move from 1.7 mile of move to Milne Spine road, 5.5 mile of 9.7 total rig move. Continue rig move from 5.5 mile of move to Central Creek Bridge, 7.3
mile of 9.7 total rig move. Allowed traffic to pass at A-pad. Provided 24 hour diverter test notification to the AOGCC at 15:31. Light pole on bridge crossing interferes
with drag chain chute. Slide drag chain into the rig. Continue rig move from Central Creek Bridge to the entrance of MPU base camp, 8.2 mile of 9.7 total rig move.
Pipe for guardrail was too high to clear with a single mat. Remove mats from B-pad road and double mat entrance. Move rig into Milne parking lot then remove mats
and re-install on B-pad road. Move the rig from 8.2 miles (MP base camp) down B/D access road, arrive on B-pad and stage on the pad. Total rig move 9.7 miles.
PJSM. Remove front and rear booster tires. Lay timbers around the well. Set the cradle with BOP stack in the cellar. Remove the BOP stack from the cradle and
set on the pedestal. Remove booster tire framework from the front of the rig. Install stairs on the front of the rig. Install the diverter annular onto the diverter tee.
Spot wellhead equipment, tree, spacer spool, MPD orbit valve and knife valve behind the well.
7/31/2022 Attempt to back rig onto well, but unable to turn rear of rig tight enough. Pull forward and remove draglink off rear moving system. Back rig onto well, had to jockey
the rig forward and back multiple times due only about 8’ of movement available. Re-install drag link once rig was nearly aligned to the well. Remove rear driving
house for clearance to adjacent well. Spot and center rig over B-31. Shim rig level. The front of rig near the edge of the pad required more shimming than normally
required. AOGCC inspector Adam Earl waived witness of the upcoming diverter test at 15:56. PJSM. Skid rig floor into the drilling position. On highline power at
17:30. Secure stairs and landings. Skid the drag chain into drilling position. Spot auxiliary building and plug into electrical. Orientate the diverter. NU the diverter
tee, annular and knife valve. Install diverter pipe. Work on rig acceptance checklist. Spot the slop tank and rock washer. Continue NU the diverter line. NU diverter
riser to the annular and install the riser. SimOps: Start loading the the off drillers side pipe shed with 5" DP.
8/1/2022 Install mousehole. Load 222 joints of 5" drill pipe in the off driller's side of the pipe shed before the diverter line blocks access. Continue to work on the rig
acceptance checklist. Welders work on rock washer extension for super sucker lines. Continue install of diverter line. Milne electricians got highline power working
at the Doyon camp at 10:00. Continue to work on the rig acceptance checklist. Install sprocket on drag chain. Perform maintenance on shakers. Install 45° targeted
elbow and 40' section of diverter line. Continue rock washer extension for super sucker lines. MWD and GyroData test tools. Perform top drive inspection. Perform
diverter function test, witness waived by Adam Earl on 7/31. Surface annular closed on 5" DP. Knife valve open in 16 sec. & annular closed in 23 sec. 3000 psi
system pressure & 1,800 psi after closure. 37 sec. for 200 psi recovery & 161 sec. for full recovery. 6 bottles 2,025 psi avg. Test rig H2S and LEL gas alarms - good
tests. Mobilize new saver sub to the rig floor. Changeout saver sub and grabber dies. SimOps: Continue to weld on rock washer suction line modification. LD
double that was in the hole for changing out the saver sub. Install 30' mouse hole in the rotary table. MU 5 stand of 5" HWDP and 1 stand of 5" HWDP with jars.
SimOps: Continue to weld on rock washer suction line modification. Install secondary suction line modification. SimOps: Work on the shaker and rig acceptance
checklist. NU the diverter line. Continue to work on rig acceptance checklist. Load the pits with spud mud. Continue to NU the diverter line. Verify 75' from nearest
ignition source. SimOps: Perform derrick inspection. Test Totco PVT sensor and alarms (good test). Pre-spud meeting with all parties involved. Discussed well
objectives and surface hole hazards. PU and MU 12-1/4" Kymera bit, 8" mud motor with 1.5° bend and crossover sub to 36'. MU first stand of 5" HWDP and tag fill
at 82'. Fill lines and conductor with fresh water. Check for leaks (no leaks). PT lines to 3,500 psi (good test). Cleanout the conduction from 82' to 127' at 375 GPM
= 380 psi, 35 RPM = 1K ft-lbs TQ, WOB = 1K. Drag chain stopped operating. PU to 97'. Got the drag chain operating. Jet the flow line due to fill and drag chain
stopped operating again. Daily disposal to G&I = 0 bbls Total disposal to G&I = 0 bbls. Daily water hauled from A-Pad Res = 170 bbls Total water hauled from A-
Pad Res = 170 bbls. Daily fluid loss = 0 bbls Total fluid loss = 0 bbls. Daily metal recovered = 0 lbs Total metal recovered = 0 lbs.
8/2/2022 Clear drag chain and flow line. Attempt make a connection but encountered fill. Circulate a bottoms up. On rig repair time since 06:00. One hour of repair time was
carried on previous report. Attempt to set slips, but top drive carriage bound in the torque rails before getting down to connection height. Adjust A-legs to move
derrick out, but not enough movement at the bottom to correct problem. L/D single of HWDP. POOH. Drop plumb bob and verified rig was centered over hole. Hany
plumb bob on top drive torque rail, observe bottom of rail too far in. About 3" off at connection height. Mobilize top drive rail shim kit from Deadhorse. Loosen bolts
on lower top drive rail braces and pull top drive in alignment. Shim kit that arrived from Deadhorse was incorrect. Welder measure and fabricate shims in 1/8" and
1/4" thickness for top drive rails. Install shims on lower section of top drive rails and braces. 1/8" shimmed on upper braces and 1/4" and 3/8" shimmed on lower
braces. Cleanout the conductor from 127' to 149' at 350 GPM = 380 psi, 35 RPM = 1K ft-lbs TQ, WOB = 1K. Drill 12-1/4" surface hole from 149' to 218' (221'
TVD). Drilled 72' = 69'/hr AROP. 350 GPM = 430 psi, 40 RPM = 1K ft-lbs torque, WOB = 0-4K, PU = 50K, SO = 50K, ROT = 50K. MW = 8.7 ppg, Vis = 240
BROOH 1 stand at 350 GPM = 320 psi, 40 RPM = 0K ft-lbs TQ. POOH on elevator on the second stand to 34'. Blow down the top drive. Inspect bit (good). PJSM.
MU GWD, DM, EWR-M5 and TM collars to 98'. Test and initialize MWD tools. MU two NM flex collar and crossover to 160'. MU first stand of 5"HWDP. Wash
down at 3 BPM = 200 psi to tag at 216' with 10K down. Perform MWD shallow pulse test (good). Drill 12-1/4" surface hole from 218' to 353' (352' TVD). Drilled
135' = 67.5'/hr AROP. 400 GPM = 830 psi, 40 RPM = 1K ft-lbs torque, WOB = 5K, PU = 73K, SO = 68K, ROT = 67K. MW = 8.95 ppg, Vis = 203. Started 2°/100'
build at 300' Drag chain #2 to the rock stopped operating and packed off. Got drag chain #2 operational again Drill 12-1/4" surface hole from 353' to 620' (618'
TVD). Drilled 267' = 88'/hr AROP. 450 GPM = 1250psi, 40 RPM = 1K ft-lbs torque, WOB = 5K, PU = 82K, SO = 75K, ROT = 78K. MW = 8.95 ppg, Vis = 203. Last
survey at 474.02’ MD / 471.87' TVD, 7.27° INC, 275.39° AZM, Distance from WP11 = 4.63’, 4.61’ high & 0.4’ right. Daily disposal to G&I = 57 bbls Total disposal
to G&I = 57 bbls. Daily water hauled from A-Pad Res = 35 bbls Total water hauled from A-Pad Res = 205 bbls. Daily fluid loss = 0 bbls Total fluid loss = 0 bbls.
Daily metal recovered = 0 lbs Total metal recovered = 0 lbs.
8/3/2022 Drill 12-1/4" surface hole from 620' to 1,220', 600' drilled, 100'/hr AROP. 450 GPM, 1375 PSI, 40 RPM, 4K TQ, 10K WOB. 9.1 ppg MW, 263 vis, 9.8 ECD, 27u
max gas. 95K PU / 87K SO / 90K ROT. Last gyro survey at 1149'. 1st clean MWD survey at 1231' is 78' from B-30. Drill 12-1/4" surface hole from 1220' to 1780',
560' drilled, 93'/hr AROP. 500 GPM, 1700 PSI, 80 RPM, 4K TQ, 5-10K WOB. 9.2 ppg MW, 195 vis, 10.6 ECD, 51u max gas. 100K PU / 90K SO / 92K ROT Drill
12-1/4" surface hole from 1780' to 2332', 552' drilled, 92'/hr AROP. 500 GPM, 1760 PSI, 60 RPM, 5k Tq, 5-8K WOB. 9.2 ppg MW, 232 vis, 10.25 ECD, 76u max
gas. 113K PU / 92K SO / 100K ROT BOPF logged at 1,944’ MD / 1,796’ TVD. Hi vis sweep @ 2308’ back on time with a 15% increase Drill 12-1/4" surface hole
from 2332' to 3160', 828' drilled, 138'/hr AROP. 500 GPM, 1720 PSI, 80 RPM, 6-8k Tq, 3-6K WOB. 9.4 ppg MW, 94 vis, 10.19 ECD, 327u max gas. 125K PU /
92K SO / 106K ROT. EOB @ 2477'. Start maintaining ~50° tangent Fault A crossed at 2506’ MD / 2210’ TVD with an estimated 50' DTE throw. Last survey at
3041.39’ MD / 2554.50' TVD, 49.71° inc, 299.16° azm, 10.05’ from plan, 4.71’ High and 8.87’ Right. Daily disposal to G&I = 1326 bbls Total disposal to G&I =
1383 bbls. Daily water hauled from B-Creek = 1150 bbls Total water hauled from B-Creek = 1600 bbls. Daily fluid loss = 0 bbls Total fluid loss = 0 bbls. Daily
metal recovered = 0 lbs Total metal recovered = 0 lbs.
50-029-23723-00-00API #:
Well Name:
Field:
County/State:
MP B-31
Milne Point
Hilcorp Energy Company Composite Report
, Alaska
8/2/2022Spud Date:
8/4/2022 Drill 12-1/4" surface hole from 3,160' to 3,795', 635' drilled, 105.83'/hr AROP. 545 GPM, 2400 PSI, 80 RPM, 10K TQ, 17K WOB. 9.4 ppg MW, 155 vis, 10.97 ECD,
155u max gas. 135K PUW / 95K SO / 115K ROT. Top Ugnu 3,460' MD / 2,822' TVD. High vis sweep at 3,287' was not seen. Drill 12-1/4" surface hole from 3795'
to 4447', 652' drilled, 108.67'/hr AROP. 550 GPM, 2240 PSI, 80 RPM, 8-13K TQ, 3-13K WOB. 9.4 ppg MW, 129 vis, 10.5 ECD, 151u max gas. 152K PUW / 102K
SO / 122K ROT. Hi vis sweep at 4427’ back on time with a 10% increase. Drill 12-1/4" surface hole from 4447' to 4890', 443' drilled, 73.83'/hr AROP. 550 GPM,
2240 PSI, 80 RPM, 10-13k Tq, 3-14K WOB. 9.2 ppg MW, 188 vis, 10.38 ECD, 202u max gas. 162k PUW / 105k SO / 127k ROT. Maintain 50° tangent Drill 12-
1/4" surface hole from 4890' to 5474', 584' drilled, 97.3'/hr AROP. 550 GPM, 2460 PSI, 80 RPM, 10-15k Tq, 8-16K WOB. 9.5 ppg MW, 300 vis, 10.58 ECD, 277u
max gas. 185k PUW / 105k SO / 138k ROT. Hi vis sweep at 5381’ back on time with a 10% increase Ugnu LA3 logged at 5110’ MD / 3874’ TVD. Last survey at
5325.96’ MD / 4012.79' TVD, 50.20° inc, 300.25° azm, 9.75’ from plan, 6.42’ High and 7.33’ Right. Daily disposal to G&I = 1264 bbls Total disposal to G&I = 2647
bbls. Daily water hauled from B-Creek = 1575 bbls Total water hauled from B-Creek = 3175 bbls. Daily fluid loss = 0 bbls Total fluid loss = 0 bbls. Daily metal
recovered = 0 lbs Total metal recovered = 0 lbs.
8/5/2022 Drill 12-1/4" surface hole from 5,474' to 5,717', (4,251' TVD), 243' drilled, 69.43'/hr AROP. 550 GPM, 2410 PSI, 80 RPM, 14-16K TQ, 4-13K WOB. 9.4 ppg MW,
124 vis, 10.47 ECD, 427u max gas. 200K PU / 105K SO / 142K ROT. Began 4°/100' build and turn at 5,569'. Ugnu MB at 5,484' MD / 4,114' TVD. #1 conveyor
drag chain locked up and alarm did not sound. The motor pulley kept turning and caused the belt to overheat and part. Install replacement belt and electrician
repaired alarm sensor. Shut down pump so cuttings didn't fill conveyor. Reciprocate 30'. Drill 12-1/4" surface hole from 5,717' to 5,760' (4,274' TVD), 43' drilled,
43'/hr AROP. 550 GPM, 2420 PSI, 80 RPM, 10-15K TQ, 8-17K WOB. 9.4 ppg MW, 67 vis, 10.3 ECD, 126u max gas. 195K PU / 105K SO / 143K ROT. Drill 12-
1/4" surface hole from 5760' to 5998', (4378' TVD), 238' drilled, 39.67'/hr AROP. 550 GPM, 2300 PSI, 80 RPM, 13-18k Tq, 10-12k WOB. 9.5 ppg MW, 59 vis,
10.13 ECD, 1009u max gas. 193k PUW / 108k SO / 140k ROT. Slow ROP from 5,859' to 5,864', increased to 60'/hr then slowed to 15'/hr. At 5,897', pumped 18 bbl
sweep w/ 10#/bbl nut plug medium & 5% Screen Kleen. ROP increased from 5,900' to 5,942' then slowed again. Appears to be formation related, not bit balling.
Drill 12-1/4" surface hole from 5998' to 6333', (4442' TVD), 335' drilled, 55.83'/hr AROP. 550 GPM, 2330 PSI, 80 RPM, 14-17k Tq, 10-12k WOB. 9.5 ppg MW, 74
vis, 10.38 ECD, 579u max gas. 190k PUW / 105k SO / 137k ROT. Drill 12-1/4" surface hole from 6333' to TD @ 6501', (4460' TVD), 168' drilled, 84'/hr AROP. 550
GPM, 2320 PSI, 80 RPM, 14-17k Tq, 15k WOB. 9.5 ppg MW, 62 vis, 10.40 ECD, 1466u max gas. 200k PUW / 102k SO / 139k ROT. Obtain final survey and
backream out 2 stands to 6333’, pulling BHA out of the SB_OA1. 80 RPM,13-16k Tq. 450 GPM, 1525 psi Pump 30 bbl hi vis sweep around, 500 gpm, 2050 psi, 80
rpm, 15-18k torque, back on time with 10% increase. Rot & Recip string 94’, varying stop points. MW 9.50 ppg in, 9.5 ppg out, vis 57 with YP @ 22. Max gas -
478u. Wash to back to bottom, no fill. BROOH from 6501' to 6227' with 500 GPM, 1675 PSI, 80 RPM, 16K TQ. 200K PU / 107K SO / 140K ROT. Max gas 151u.
Utilize 5-10 min per stand pulling speed. Rig on Gen power at 05:45 SB_OA1 logged at 6393’ MD / 4452’ TVD. Last survey at 6446.97’ MD / 4456.13' TVD, 85.71°
inc, 301.26° azm, 11.54’ from plan, 11.28’ High and 2.44’ Left. Daily disposal to G&I = 1316 bbls Total disposal to G&I = 3963 bbls. Daily water hauled from B-
Creek = 905 bbls Total water hauled from B-Creek = 4080 bbls. Daily fluid loss = 0 bbls Total fluid loss = 0 bbls. Daily metal recovered = 0 lbs Total metal
recovered = 0 lbs.
8/6/2022 BROOH from 6,227' to 4,334', 500 GPM, 1750 PSI, 80 RPM, 8-16K TQ. 5-10'/min, slow as needed for pressure and torque in slide areas. 9.6 ppg MW, 57 vis,
10.31 ECD, 252u max gas. 175K PU / 105K SO / 127K ROT. BROOH from 4,334' to 2,427', 500 GPM, 1350 PSI, 80 RPM, 5-10K TQ, 5-10'/min, slow as needed
for pressure and torque in slide areas. 9.5 ppg MW, 47 vis, 9.99 ECD, 101u max gas. Pulled slow from 2,523' to 2,427' for a bottoms up before the build and base
of permafrost. BROOH from 2427' to 757' pulling 5-10 min/std. Slow pulling speed from 1950’-1850’ and 1060-757’ as hole unload sand. 450-500 GPM - 1370 PSI,
80 RPM, 1-7K ft/lbs torque. 9.55 ppg MW, 59 vis, 10.46 ECD. Max gas units = 55u. PU = 85K, SO =85K, ROT = 85K. Rig on Hi-Line @ 18:30. Hole unloading
sand at 1st BU on last stand of DP. when #1 conveyor chain came off the drive sprocket. Shut pumps down, S/O to 745' positioning tool joint at rotary table. Monitor
Well while troubleshoot conveyor. Rig up hose from supersucker to conveyor while reinstall conveyor chain on sprocket. Clear cuttings from trough in front of
shakers and attempt to test run conveyor. Obtain 10’ of travel before cuttings pile up and stopped conveyor. Move string several feet every half hour. No resistance
observed. Inspect idler sprocket while clearing remaining cuttings from trough. Chain was starting to walk off Idle sprocket also. Reposition chain onto sprocket and
ensure free movement of conveyor with comealong. Restart conveyor – good. Adjust rear sprocket tension and install cover. Losses at 1.5 BPH Slack off 30’, with no
pumps to 775’. No resistance observed. Continue BROOH f/ 775’ to 716’. Hole unloading sand for BU stks before cleaning up. 80 RPM, 1-2k Tq. 400 GPM, 780
psi. Rack back HWDP and jars from 716 'to 160'. L/D NMDC from 160' to 98'. Read MWD tools and continue laying down BHA to the ILS @ 88' Daily disposal to
G&I = 803 bbls Total disposal to G&I = 4766 bbls. Daily water hauled from B-Creek = 870 bbls Total water hauled from B-Creek = 4950 bbls. Daily fluid loss = 17
bbls Total fluid loss = 17 bbls. Daily metal recovered = 0 lbs Total metal recovered = 0 lbs.
8/7/2022 L/D BHA from 88'. Inline stabilizer in good condition but motor stabilizer worn on uphole side from backreaming. Break bit off and L/D mud motor. Bit graded: PDC 1-
2-BT-G-X-1-NO-TD / Roller cones 1-1-NO-A-F-1-WT-TD. 52.4 bbls total lost on trip. Clear rig floor of BHA components. Flush gravel from flow line. 1.75 BPH static
losses. M/U 9-5/8" Volant tool. R/U casing spiders, elevators and backup strap tong. Count casing on location and verify tally. PJSM with all parties involved. 1.0
BPH static losses. M/U 9-5/8" shoe joint with round nose float shoe, spacer joint, float collar joint with Halliburton baffle installed and baffle adapter joint to 165'.
Thread lock each connection with ForumLok. Torque to 21K with the Volant tool. Check floats - good. Run 9-5/8" 40# L-80 TXP-BTC casing from 165' to 1,619'.
Torque to 21K with the Volant tool. Install 9-5/8"x12-1/2" centralizers as per tally. Fill every joint and top off every 10. Bad connection between joint #40 and #41.
Torqued up 2 turns from full make-up. Observed 20K TQ while backing out, ending up backing out collar from joint #40. L/D joint #41 and C/O casing collar on joint
#40. Replacement joint length 40.58'. Continue to RIH with 9-5/8”, 40# casing from 1,619’ to 2,508’ at 30'/min running speed. Torque to 21,000 ft/lbs with the Volant
tool. Fill casing on the fly and top off every 10 joints. Centralizers installed as per tally. Losses @ 4-8 BPH. 130K PUW, 90K SOW. Circulate 1.5x BU in tangent
section, below the permafrost staging up to 5 BPM = 170 psi. Mw in 9.6, Vis 65. Mw out 9.65, Vis 130. Gas peak @ 1719u & Mud Wt gas cut to 8.5 ppg with a fair
amount of crude oil in returns. Circulate until good 9.6 ppg returns coming back. Lost 15 bbls while circulating Continue to RIH with 9-5/8”, 40# casing from 2508’ to
4144’ at 30'/min running speed. Torque to 21,000 ft/lbs with the Volant tool. Fill casing on the fly and top off every 10 joints. Cent installed as per tally. Set down w/
30k @ 2578’, work past with 5 RPM, 10k Tq. 2 BPM, 125 psi. Losses @ 4-8 BPH Bad connection between joint #102 and #103. Torqued halfway before stalling
out, dress threads and attempt to M/U again with same results. L/D joint #103 and C/O casing collar on joint #102. RIH 1 joint to 4180’ and experience the same
stalling at half M/U on next connection. Observe galling thread damage when backed out. Lay down hanging jt #105 and make up Volant to stump. Circulate 1.3x
bottoms up, staging pumps up to 6 BPM, 300 psi. Max Gas 1465u w/ 134 bbls pumped. MW - 9.5 ppg 61 Vis. Cuttings returns cleaning up with BU. Heavy crude
observed in returns. 12 bbls loss. 225k PU / 108k SO. SimOps: Mobilize casing tongs to rig floor and rig up. C/O collar on jt# 104 Continue RIH with 9-5/8”, 40#
casing from 4180’ to 4381' @ jt #108. Start and make up connection to 3000 ft/lbs with casing tongs then engage Volant tool and torque to 21,000 ft/lbs. Fill casing
on the fly. Cent installed as per tally. Losses @ 4-6 BPH. 230K PUW, 110K SO MU the ES cementer w/ pup jts Top & Btm t/ 4418'. Verify 3 pins set at 3300psi.
ForumLok top/bottom connections. RIH with 9-5/8", 47# casing f/ 4418' to 4828' . Start and make up connection to 3000 ft/lbs with casing tongs then engage Volant
tool and torque to 24,000 ft/lbs with the Volant tool. Fill casing on the fly, top off every 10 jts. Cents installed as per tally. Losses @ 6 BPH. 113 bbls total Daily
disposal to G&I = 554 bbls Total disposal to G&I = 5320 bbls. Daily water hauled from B-Creek = 440 bbls Total water hauled from B-Creek = 5390 bbls. Daily fluid
loss = 127 bbls Total fluid loss = 134 bbls. Daily metal recovered = 0 lbs Total metal recovered = 0 lbs.
8/8/2022 Threads galled about halfway through M/U with rig tongs of 47# joint #10. L/D joint #10 and change out collar on #9. Utilize a new bucket of pipe dope to rule out
contamination causing galled threads. Verified pipe is plumb, hole direction was not causing pipe to lean. Run 9-5/8" 47# L-80 TXP-BTC casing from 4,828' to
6,493'. Start M/U to 3,000 ft/lbs with casing tongs then engage Volant CRT and torque to final 24,000 ft/lbs. Fill casing on the fly and top off every 10 jts. Install
centralizers as per tally. 365K PU / 125K SO. Washed down from 6,437' to 6,493' with 3 BPM, 340 PSI as a precautionary measure, no fill observed. 6.7 BPH
losses, 128.0 bbls total lost while running casing. Provided 24 hour notification to AOGCC of upcoming BOP test at 08:03. Stage up pumps to 6 BPM, 400 PSI
while reciprocating 30'. Rotate with torque limit set at 20K with 2 RPM. Condition mud for cement job. Good returns, stage up to 7 BPM, 210 PSI. 9.55 ppg MW, 47
vis in / 9.65 MW, 105 vis out. Adding 40 BPH water. No losses. Blow down top drive. Service Volant CRT dies and dope cup. Rig up cement lines. Close upper and
lower IBOP. Blow air through lines to Halliburton. Offload mud from pit #3. Circulate 6 BPM, 260 PSI, 2 RPM, 20K TQ while reciprocating 30'. PJSM with all parties
involved. Continue to circulate while Halliburton batches up. Pre-treat last 50 bbls pumped from rig ahead of cement with CF Desco/SAPP/Bicarb. Pump 5 bbls
water, 3 BPM, 60 PSI. Pressure test lines 1000 PSI low / 3950 PSI high. Mix & pump 60 bbls of 10.0 ppg Tuned Spacer with 4# red dye & 5# Pol-E-Flake in 1st 10
bbls, 3.3 BPM, 140 PSI. Drop by-pass plug. Mix & pump 249 bbls of 12.0 ppg Type I/II lead cement (595 sxs, 2.347 ft^3/sk), 4.75 BPM, 300 PSI. ICP = 114 psi @
4.6 BPM. FCP = 335 psi @ 3 BPM Rotate 2-3 RPM, 20K TQ & reciprocate 20'. Mix & pump 78 bbls 15.8 ppg tail (Type I/II tail cement 1.156 ft^3/sk yield, 379 sks
total) @ 3.5 BPM, 475 PSI. Drop shutoff plug. Lost Drawworks dynamatic brake w/ 60 bbls tail pumped, Stop Rot & Recip. Set casing shoe on depth at 6493' for
remainder of job. HES pump 20 bbls water @ 7.5 BPM, 500 psi. Displace with 294 bbls (2912 strokes) 9.5 ppg spud mud from rig at 7.5 BPM, 400 PSI. Displace
with 80 bbls 9.4 ppg Tuned Spacer form HES at 5 BPM, 400 PSI, Continue to displace with 84.2 bbls, 9.5 ppg mud, from the rig at 5 BPM, 730 PSI ICP, slowing to
3 BPM for last 11 bbls, FCP 800 PSI. Bump plug at 3746 stks - 7 stks(0.71 bbl) late. CIP at 20:43. 46 bbls total losses Pressure to 1,400 psi, pressure not building
past 1400 psi, shut down pump and pressure bleed to 140psi. Bleed off and check floats, good. Decision made to drop the free falling closing plug. Drop plug and
let fall for 20 min. Pressure up and observe ESC open at 590 psi. Pump through ES cementer at 2092 at 4 BPM -190 PSI. Pol-E-Flake was observed at 350 stks.
Dump 80 bbls red dye spacer and interface, 75 bbls good cement and 126 bbls tuned spacer & clabbored up mud to Rockwasher before taking good mud returns
to pits & continue to circ total 5 BU. Disconnect knife valve from accumulator. Drain stack and flush with black water three times. Re-connect knife valve to the
accumulator. Continue to circulate through the ES cementer at 2092' staging up to 8 BPM , 370 psi while WOC & prepping for the 2nd stage. Hold PJSM with all
parties involved for 2nd stage, break out volante tool, clean dies and re-dope cup, blow air thru cement line to ensure clear. Pump 5 bbls water. Mix & pump 60 bbls
of 10.0 ppg Tuned Spacer w/ 4# red dye & 5# Pol-E-Flake in 1st 10 bbls at 3.3 BPM= 210 psi. Mix & pump 10.7 ppg Arctic Cem lead cement at 5 BPM = 385 psi
ICP. 240 bbls lead cement pumped as end of report. See red dye spacer with 270 total bbls pumped. No losses. Daily disposal to G&I = 780 bbls Total disposal to
G&I = 6100 bbls. Daily water hauled from B-Creek = 310 bbls Total water hauled from B-Creek = 5700 bbls. Daily fluid loss = 164 bbls Total fluid loss = 298 bbls.
Daily metal recovered = 0 lbs Total metal recovered = 0 lbs.
8/9/2022 Continue 2nd stage cement job. Finished pumping 349 bbls (1960 ft^3, 680 sxs, 2.883 ft^3/sk) 10.7 ppg Arctic Cem lead cement, 3.3 BPM, 300 PSI ICP, 400 PSI
FCP. Began seeing cement interface at 257 bbls pumped, 10.5 ppg at 330 bbls pumped and swap to tail. Pump 56 bbls (314 ft^3, 270 sks, 1.17 ft^3/sk) 15.8 ppg
Type I/II tail cement, 5.6 BPM, 690 PSI ICP, 350 PSI FCP. Drop closing plug. Pump 20 bbls water from Halliburton, 4.9 BPM, 250 PSI. Displace from rig with 9.5
ppg mud, 6 BPM, 170 GPM ICP, 550 GPM FCP. Had problems with suction line from pit #5, swap to pit #4. Slow to 4 BPM, 490 PSI ICP, 590 PSI bump pressure.
Bumped plug at 1452 stks, 130 stks / 13.0 bbl late due to pump problems. Pressure up and observe ES cementer close at 1610 PSI. Continue to 2000 PSI, holding
good. Bled off and observe no flow which confirmed ES cementer closed. CIP at 07:23. 218.5 bbls cement to surface. No losses during 2nd stage. Disconnect
accumulator lines to the knife valve. Drain cement from the stack. Flush stack with black water while operating the diverter annular 5x. Disconnect diverter line from
knife valve. Hoist stack and starting head. Sim-ops: R/D Volant CRT Center 9-5/8" casing in conductor. Install casing slips as per wellhead rep with 100K on slips.
Cut 9-5/8" casing and prep for wellhead installation. L/D 17.66' cut joint. 41.38' - 17.66' = 23.72' remaining in hole. Begin unbolting diverter to speed head. Clear
casing equipment from the rig floor. Flush the flow line. N/D diverter annular and riser. N/D diverter line. Secure surface annular preventer in cellar corner and
remove riser, diverter Tee & knife valve from cellar. No loader access to back of the rig. Send tugger line over the windwall. Utilize the tugger and bridge cranes to
drag equipment into place. Install T-103 Slip Lock Well Head. PT the voids to 3,800 & 5000 psi (good test). Set BOP stack on Wellhead unbolt adapter flange from
bottom of stack, and set stack back on moving pedestal. Install 2' spacer spool onto adapter flange and install bolts. Finish installing adapter flange bolts. Set BOP
stack on WH and start nipple up. Lost Hi-Line power at 02:10, mobilize Rig electrician and on rig generator power at 02:37. Sea-Gull in tract transformer. Continue
Nipple up BOP stack. Hydraulic Sweeney wrench broke, torque up bolts with hammer wrench. Install 90' mousehole. Install test plug. Daily disposal to G&I = 1561
bbls Total disposal to G&I = 7661 bbls. Daily water hauled from B-Creek = 350 bbls Total water hauled from B-Creek = 6050 bbls. Daily fluid loss = 0 bbls Total
fluid loss = 298 bbls. Daily metal recovered = 0 lbs Total metal recovered = 0 lbs.
8/10/2022 Install test plug and MPD test cap, NU orbit valve, pressure test orbit valve to 1400 psi for 5 min, good. Remove test cap. RU 3 1/2'' test joint and test equipment,
flood stack, lines and choke manifold with fresh water Trip nipple leaking water at clamp, tighten up trip nipple clamp, air up the air boots, no leaks, perform shell
test to 3000 psi, good Conduct initial BOPE test to 250/3,000 psi: LPR (2-7/8” x 5” VBR’s) and UPR (2-7/8” x 5” VBR’s) with 3-1/2” & 5” test joints, Annular with 3-
1/2” test joint. All tests performed w/ fresh water against test plug. Test witness was waived by AOGCC inspector Lou Laubenstein on 8/9/22 at 19:55 hrs. Test: 1.
Annular with 3-1/2” test joint, 5” TIW, choke valves 1, 12, 13, 14, kill valve 20 (passed). 2. UPR with 3 1/2” test joint, choke valves 9, 11, HCR kill, 5" dart valve
(passed). 3. Manual kill, choke valves 5, 8 & 10, upper IBOP (passed). 4. Lower IBOP, choke valves 4, 6 & 7 (passed) 5. Choke valve 2 (passed). 6. HCR choke
(passed). 7. Manual choke (passed). 8. LPR with 3-1/2” test joint (passed). 9. UPR with 5” test joint (passed) 10. LPR with 5'' test joint (passed). 11. Blind rams,
choke valve 3 (passed). 12. Manual adjustable choke (passed). 13. Hydraulic super choke (passed) Accumulator drawdown test: System pressure = 3050 psi.
Pressure after closure = 1675 psi. 200 psi attained in 23 seconds. Full pressure attained in 195 seconds. 6 N2 Bottle average at 2050 psi. Test rig gas alarms &
PVT R/D BOP testing equipment. Blow down the choke manifold, kill lines and top drive. Pull the test plug. M/U the wear ring running tool. Install the wear ring (ID =
10.063"). Lay down the wear ring running tool. M/U 8-1/2" mill tooth bit, 6.75" mud motor with 1.5° AKO Adjust trip nipple for clearer path to flowline. TIH w/ 17
joints HWDP and hydraulic jars to 588'. TIH with stands of DP from 588' to 2010'. Wash down from 2015' with 300 GPM – 450 PSI, 30 RPM - 3K Tq, see cement
stringers @ 2089 & tag ES cementer on depth at 2092' with 5K WOB. Drill ES cementer, dress 3x and pass through clean with pumps off. 102K PU / 85K SO / 94K
ROT. Continue to TIH w/ 5” DP out of the Derrick from 2111' to 6202'. Fill pipe every 20 stds. Wash & Ream down with 300 GPM, 800 psi 30 RPM, 15k Tq and tag
cement stringers at 6270'. 200k PU, 97k SO, 137k ROT Daily disposal to G&I = 57 bbls Total disposal to G&I = 7718 bbls. Daily water hauled from B-Creek = 140
bbls Total water hauled from B-Creek = 6190 bbls. Daily fluid loss = 0 bbls Total fluid loss = 298 bbls. Daily metal recovered = 0 lbs Total metal recovered = 0 lbs.
8/11/2022 Cleanup cement stringers from 6270', 300 GPM, 800 psi 30 RPM, 15k Tq and drill firm cement with 7k wob from 6280' to 6340' to 28' above the BA. 200k PU, 97k
SO, 137k ROT CBU pumping 460 gpm, 30 rpm, 15k torque working pipe 30' Parked @ 6295', RU to test the 9 5/8'' casing, purge lines, shut in the UPR, pressure
to 2600 psi for 30 charted minutes, good test, bleed off pressure, open UPR. RD test equipment. 4.8 bbls pumped, 4.8 bbls bled back Wash & ream from 6,295' to
6,340' at 450 GPM = 1200 psi, 30 RPM = 16K ft-lbs TQ, WOB = 5-8K. Drill cement and 9-5/8" shoe track from 6,340' to 6,493'. All equipment on depth. Cleanout
the rat hole from 6493' to 6,501'. Ream through the baffle adapter and float collar 3 times each. Drill 20' of new formation from 6,501' to 6,521' at 460 GPM = 1180
psi, 30 RPM = 17K ft-lbs TQ, WOB = 5-7K Ream through the shoe 3 times with/without pump/rotary. Rack back a stand to 6,486'. Circulate and condition the mud
for the FIT at 460 GPM = 1150 psi, 30 RPM = 17K ft-lbs TQ , reciprocating 90'. Max Gas = 126u. After 1.6 BU had good 9.4 ppg in/out and the well cleaned up.
Record SPRs. Simops: test MPD lines to 300/1400 psi 5 min ea. Parked @ 6,487' RU testing equipment. Fill lines and purge air. Close UPR, apply 602 psi,
Perform FIT to 12 ppg EMW with existing 9.4 ppg MW, good test, bleed off pressure, open UPR. Pumped 1.2 bbls, bled back 1 bbls, RD testing equipment. Blow
down lines. Flow check the well, static. Pump dry job, blow down the top drive. TOOH with cleanout assembly from 6487' to 588'. Hole take proper fill. Observe the
well for flow (static). Lay down 15 jts, 5" HWDP and rack back jar stand from. Lay down motor and tri-cone bit. Bit grade: 1-1-WT-A-E-I-NO-BHA Clear and clean
the rig floor. Remove the master bushing and install the split bushings. MU 8-1/2" NOV SK616M bit, NRP-A2 bit sleeve, 7600 Geo-Pilot, LWD (ADR & DGR),
MWD (PWD & GWD) directional tools, stabilizer and float sub to 94'. Plug in and initialize MWD tools. Finish making up BHA #3. P/U 3x Non-Mag drill collars,
HWDP and jars to 282'. TIH with 5" DP out of Derrick to 2187'. Proper displacement recorded. Shallow pulse test MWD and break-in Geo-Pilot seals, 450 GPM,
900 PSI, 5-30 RPM, 3.5k Tq. 95k PU, 92k SO, 94k ROT Continue to TIH f/ 2187’ t/ 3044' Daily disposal to G&I = 154 bbls Total disposal to G&I = 7872 bbls. Daily
water hauled from B-Creek = 160 bbls Total water hauled from B-Creek = 6350 bbls. Daily fluid loss = 0 bbls Total fluid loss = 298 bbls. Daily metal recovered = 0
lbs Total metal recovered = 0 lbs.
8/12/2022 Continue to TIH with BHA #3 f/ 3044’ t/ 6280', drift and single in with 5'' DP to 6470' just above the shoe, MU stand in mouse hole and rack in derrick. Fill pipe @
4095' and 6010' PJSM. Flow check the well, static. Drain stack, pull MPD riser and install MPD RCD, leak test same, good. Install buoy in flowline and skirt up bell
nipple to drip pan PJSM for displacing, load 35 bbl hi vis spacer in pipe, followed with new 8.8 ppg flo pro mud, wash and ream to TD @ 6521' pumping 365 gpm,
1160 psi, 40 rpm, 16k torque. PU 205K, SO 90K, ROT 135K Displace w/ 505 bbls 8.8 ppg flow pro mud @ 6 BPM, 750 psi. With mud out bit, P/U into 9 5/8''
casing, Continue displacing @ 6 BPM. FCP 480 psi, Dump spud mud returns and interface to rock washer. Rot 40 rpm, Start 16k Tq,12k Tq final. PU 186K, SO
110K, ROT 142K Rack stand back, Hang blocks, slip and cut 61' drilling line, change out drilling line anchor bolts, re-calibrate block height. Service top drive,
inspect saver sub and grabber dies, adjust brake band rollers. Simops: clean pit 4 and under shakers. Monitor MPD for pressure – No build. MU stand drill pipe,
Record SPRs, wash and ream to bottom at 6521' pumping 450 gpm, 1060 psi, 60 rpm, 10k torque. Simops: take on 290 bbls Flo Pro mud. Drill 8-1/2" lateral from
6,521' to 6852' (4456' TVD). Drilled 331' = 47'/hr AROP. 500 GPM = 1280 psi, 120 RPM = 14k Tq, WOB = 12k. MW = 8.8 ppg, Vis = 37, ECD = 9.62 ppg, max
gas units = 1085. PU = 153k, SO = 105k, ROT = 124k. MPD full open while drilling, trap 150 psi on connections. Drill 8-1/2" lateral from 6852' to 7518' (4451'
TVD). Drilled 666' = 111'/hr AROP. 550 GPM = 1570 psi, 120 RPM = 13k Tq, WOB = 12-15k. MW = 8.85 ppg, Vis = 38, ECD = 10.09 ppg, max gas units = 1085.
PU = 153k, SO = 101k, ROT = 127k Backream 30' on connections. MPD full open while drilling and trap 100 PSI on connections. Maintain the OA sands Last
survey at 7445.01’ MD / 4450.46' TVD, 89.61° inc, 310.29° azm, 21.27' from plan, 21.20' High and 2.68’ left. We have drilled 12 concretions for a total thickness of
103’ (10.8% of the lateral). Daily disposal to G&I = 541 bbls Total disposal to G&I = 8413 bbls. Daily water hauled from B-Creek = 270 bbls Total water hauled
from B-Creek = 6620 bbls. Daily fluid loss = 0 bbls Total fluid loss = 298 bbls. Daily metal recovered = 0 lbs Total metal recovered = 0 lbs.
8/13/2022 Drill 8-1/2" lateral from 7518' to 8181' (4445' TVD). Drilled 663' = 110.5'/hr AROP. 532 GPM = 1620 psi, 120 RPM = 13k Tq, WOB = 11-14k. MW = 8.9 ppg, Vis =
40, ECD = 10.4 ppg, max gas units = 1009. PU = 151k, SO = 95k, ROT = 119k. Back ream 30' on connections. 7790' MPD start holding 100 psi drilling and trap
250 PSI on connections. Pump 30 bbl hi vis sweep @ 7518', back on time with 70% increase. Maintain the OA sands. Drill 8-1/2" lateral from 8181' to 8725' (4437'
TVD). Drilled 544' = 90.66'/hr AROP. 550 GPM = 1720 psi, 120 RPM = 13k Tq, WOB = 5-13k. MW = 9.0 ppg, Vis = 42, ECD = 10.33 ppg, max gas units = 807.
PU = 153k, SO = 95k, ROT = 124k Back ream 30' on connections. MPD holding 100 psi drilling and trap 250 PSI on connections. Pump 30 bbl hi vis sweep @
8469', back on time with 50% increase. Maintain the OA sands. Drill 8-1/2" lateral from 8725' to 9226' (4442' TVD). Drilled 501' = 83.5'/hr AROP. 550 GPM =
1740 psi, 120 RPM = 11k Tq, WOB = 10-13k. MW = 8.9 ppg, Vis = 40, ECD = 10.37 ppg, max gas units = 755. PU = 155k, SO = 93k, ROT = 125k Back ream 30'
on connections. MPD holding 100 psi drilling and trap 250 PSI on connections. Maintain the OA sands. Drill 8-1/2" lateral from 9226' to 9810' (4426' TVD). Drilled
584' = 97.33'/hr AROP. 550 GPM = 1860 psi, 120 RPM = 13k Tq, WOB = 10-15k. MW = 9.05 ppg, Vis = 40, ECD = 10.71 ppg, max gas units = 1111. PU = 156k,
SO = 85k, ROT = 120k Back ream 30' on connections. MPD holding 100 psi drilling and trap 250 PSI on connections. Pump 30 bbl hi vis sweep @ 9513', back on
time with 30% increase. Crossed fault #1 @ approx 9748’, moving the bit from top of OA sand into shale below OA. Last survey at 9631.84’ MD / 4428.94' TVD,
90.91° inc, 300.94° azm, 7.45' from plan, 5.96' low and 4.47’ left. We have drilled 40 concretions for a total thickness of 320’ (10% of the lateral). Daily disposal to
G&I = 632 bbls Total disposal to G&I = 9045 bbls. Daily water hauled from B-Creek = 740 bbls Total water hauled from B-Creek = 7360 bbls. Daily fluid loss = 0
bbls Total fluid loss = 298 bbls. Daily metal recovered = 13 lbs Total metal recovered = 13 lbs.
8/14/2022 Drill 8-1/2" lateral from 9810' to 10300' (4404' TVD). Drilled 490' = 81.6/hr AROP. 536 GPM = 1900 psi, 120 RPM = 120k Tq, WOB = 12-14k. MW = 9 ppg, Vis =
40, ECD = 10.78 ppg, max gas units = 832. PU = 160k, SO = 75k, ROT = 117k. Back ream 30' on connections. MPD holding 100 psi drilling and trap 250 PSI on
connections. Target 95 deg, Geo reports back in the OA sand @ 9921', level off in anticipation of fault #2. Drill 8-1/2" lateral from 10,300' to 10,778' (4416' TVD).
Drilled 478' = 79.67'/hr AROP. 550 GPM = 1910 psi, 120 RPM = 16k Tq, WOB = 10-13k. MW = 9.0 ppg, Vis = 41, ECD = 10.62 ppg, max gas units = 429. PU =
167k, SO = 85k, ROT = 124k Back ream 30' on connections. MPD holding 100 psi drilling and trap 250 PSI on connections. Pump 30 bbl hi vis sweep @ 10466',
back 100 stks late, 30% increase. Maintain OA sand, at 10500' target 87 deg. Drill 8-1/2" lateral from 10778' to 11166' (4432' TVD). Drilled 388' = 64.67'/hr AROP.
550 GPM = 1970 psi, 120 RPM = 13k Tq, WOB = 10-13k. MW = 9.0 ppg, Vis = 39, ECD = 10.78 ppg, max gas units = 454. PU = 165k, SO = 80k, ROT = 118k.
MPD holding 90 psi drilling and trap 250 PSI on connections. Drill 8-1/2" lateral from 11166' to 11702' (4448' TVD). Drilled 536' = 89.33'/hr AROP. 550 GPM =
1970 psi, 120 RPM = 13-18k Tq, WOB = 10-13k. MW = 9.0 ppg, Vis = 39, ECD = 10.71 ppg, max gas units = 503. PU = 173k, SO = 67k, ROT = 122k Back ream
30' on connections. MPD holding 90 psi drilling and trap 250 PSI on connections. Pump 30 bbl hi vis sweep @ 11511', back 150 stks late with 10% increase.
Maintain the OA sands, target 89°. Last survey at 11630.90’ MD / 4447.00' TVD, 88.62° inc, 309.54° azm, 12.46' from plan, 9.12' low and 8.50’ left. We have drilled
64 concretions for a total thickness of 641’ (12.6% of the lateral). Daily disposal to G&I = 979 bbls Total disposal to G&I = 10024 bbls. Daily water hauled from B-
Creek/A-pad = 1090/290 bbls Total water hauled from B-Creek/A-pad = 8450/220 bbls. Daily fluid loss = 0 bbls Total fluid loss = 298 bbls. Daily metal recovered
= 12 lbs Total metal recovered = 25 lbs.
8/15/2022 Drill 8-1/2" lateral from 11702' to 12,180' (4474' TVD). Drilled 487' = 81.16'/hr AROP. 550 GPM = 2170 psi, 120 RPM = 14k Tq, WOB = 12-18k. MW = 9.1 ppg,
Vis = 40 ECD = 10.99 ppg, max gas units = 781. PU = 177k, SO = 63k, ROT = 121k. Back ream 30' on connections. MPD holding 90 psi drilling and trap 250 PSI
on connections. Maintain the OA sands, target 86-87.5°. Drill 8-1/2" lateral from 12,180' to 12640' (4495' TVD). Drilled 460' = 76.66'/hr AROP. 550 GPM = 2170
psi, 120 RPM = 13-14k Tq, WOB = 10-16k. MW = 9.1 ppg, Vis = 42 ECD = 11.19 ppg, max gas units = 378. PU = 175k, SO = 0k, ROT = 123k. Lost SOW @
12561'. Back ream 30' on connections. MPD holding 70 psi drilling and trap 250 PSI on connections. Pump 30 bbl hi vis sweep @ 12465', back on time with 15%
increase. Maintain the OA sands, target 87.5 deg Drill 8-1/2" lateral from 12640' to 13129' (4515' TVD). Drilled 489' = 81.5'/hr AROP. 550 GPM = 2030 psi, 120
RPM = 11-13k Tq, WOB = 12-14k. MW = 9.0 ppg, Vis = 39, ECD = 10.55 ppg, max gas units = 453. PU = 180k, SO = 70k, ROT = 125k. Maintain the OA sands
Performed a 290 bbl dump and dilute at 12777' MD. MBT decreased from 6.0 to 3.5. Regained SOW @ 13034’. Back ream 30' on connections. MPD full open
choke while drilling and trap 250 PSI on connections. Crossed Fault #2 at 12,995’, 18’ DTNW throw from lower OA-3 to upper OA-1. Drill 8-1/2" lateral from 13129'
to 13700' (4535' TVD). Drilled 571' = 95.17'/hr AROP. 550 GPM = 2160 psi, 120 RPM = 15k Tq, WOB = 15-21k. MW = 9.1 ppg, Vis = 38, ECD = 10.92 ppg, Max
Gas = 503u. PU = 172k, SO = 65k, ROT = 121k Back ream 30' on connections. MPD full open choke while drilling and trap 250 PSI on connections. Pump 30 bbl
hi vis sweep @ 13512', back on time with 10% increase. Exited top OA for 70’, from 13,147’ to 13,217’ MD Last survey at 11630.90’ MD / 4531.43' TVD, 86.58° inc,
318.12° azm, 9.51' from plan, 9.27' low and 2.13’ left. We have drilled 92 concretions for a total thickness of 941’ (13.2% of the lateral). Daily disposal to G&I = 1031
bbls Total disposal to G&I = 11055 bbls. Daily water hauled from B-Creek/A-pad = 1210/0 bbls Total water hauled from B-Creek/A-pad = 9660/220 bbls. Daily fluid
loss = 0 bbls Total fluid loss = 298 bbls. Daily metal recovered = 9 lbs Total metal recovered = 34 lbs.
8/16/2022 Drill 8-1/2" lateral from 13700' to TD @ 13830' at the base of the OA(4558' TVD). Drilled 130' = 86.67'/hr AROP. 550 GPM = 2190 psi, 120 RPM = 14-15k Tq,
WOB = 16-19k. MW = 9.1 ppg, Vis = 38, ECD = 11.15 ppg, Max Gas = 253u. PU = 176k, SO = 58k, ROT = 121k Take Final survey: 13757.53' MD, 80.94° INC ,
318.10° AZ 4546.81' TVD, 21.31' from plan. 21.31' low, 0.18' left. Drilled 99 concretions for a total thickness of 1,002' (13.7% of the lateral). Pump 30 bbl sweep
around cleaning up the well, back on time, no increase, Circulate at 544 gpm, 2160 psi, 120 rpm, 14k torque, racking a stand back each BU to 13798'. Simops:
clean pits and prep for brine displacement. Circulate at 544 gpm, 2160 psi, 120 rpm, 14k torque, back reaming slow and racking a stand back each BU to 13313'.
for a total of 9 BU. Simops: finish cleaning pits, load pits with 8.5 lubed, viscosified brine, build SAPP pills, replace bearing on #1 drag chain. Rig mechanic continue
to change out bearing on drag #1 while back reaming slow and racking a stand back each BU from 13313' to 13256' Wash to bottom at 13830’. 300 GPM,900 psi
PJSM. Displace the wellbore to 8.55 ppg viscosified brine: Pump 30 bbl high vis spacer, 25 bbls vis brine, 30 bbls SAPP, 25 bbls vis brine, 30 bbls SAPP, 25 bbls
vis brine, 30 bbls SAPP, 30 bbls high vis spacer. Pump 8.55 ppg 2% KCl 3% lube (1.5% 776 and 1.5% Lo-TQ) at 6 BPM, 770 psi, 60 RPM = 15kTq, rotating and
reciprocating 95'. Take returns to pits when clean 8.55 ppg brine to surface. 1250 total bbls dumped to RW. No losses recorded. Obtain new SPR's. Monitor
pressure with MPD choke closed. 5 min built to 92 psi, bleed off, 5 min built to 83 psi, bleed off, 5 min built to 76 psi. BROOH from 13830' to 11280,' at 5-10
min/stand slowing as needed. 450-500 GPM = 1200-1610 psi, 120 RPM =12k ft-lbs Tq, Max gas units = 100. MPD chokes open while BROOH & Trapping 175 psi
on connections. L/D DP in the mouse hole. Loss rate 4-17 BPH dynamic. Daily disposal to G&I = 1745 bbls Total disposal to G&I = 12800 bbls. Daily water hauled
from B-Creek/A-pad = 0/405 bbls Total water hauled from B-Creek/A-pad = 8230/1835 bbls. Daily fluid loss = 0 bbls Total fluid loss = 298 bbls. Daily metal
recovered = 4 lbs Total metal recovered = 38 lbs.
8/17/2022 BROOH from 11,280' to 8,215,' at 5-10 min/stand slowing as needed, LD DP in the mouse hole. 475 GPM = 1,060 psi, 120 RPM =10k ft-lbs Tq, Max gas units =
75. MPD chokes open while BROOH & Trapping 175 psi on connections. PU 155K, SO 105K, ROT 126K. Loss rate= 10 BPH BROOH from 8,215' to 6,467,'
pulling in 9 5/8" shoe, pulling 5-10 min/stand slowing as needed, L/D DP in the mouse hole. slow to 20 rpm, 5k tq pulling the BHA into the shoe. 450 GPM = 920
psi, 120 RPM =9k ft-lbs Tq, Max gas units = 0. Losses BR to shoe= 151 bbls Pump 30 bbl hi vis sweep and circulate the casing clean at 500 GPM = 2,120 psi, 100
RPM = 8K ft-lbs TQ. Sweep back on time with 20% increase. Monitor pressure with MPD choke closed with 8.9 ppg MW. 5 min built to 64 psi, bleed off, 5 min built
to 54 psi, bleed off, 5 min built to 48 psi, bleed off, 5 min built to 42 psi,bleed off and final 5 min built to 36 psi = 9.06 ppg EMW. KWF = 9.2 ppg. Weight up the
active pits to 9.1 ppg. Circulate 9.1 ppg while weighting up the returns on the fly to 9.1 ppg at 300 GPM = 580 psi, 80 RPM = 4-7K ft-lb TQ reciprocating 90'. Good
9.1 ppg in/out. Continue to circulate weighting up to 9.2 ppg at 300 GPM = 580 psi, 80 rpm = 5-7K ft-lbs TQ, reciprocating 90'. Good 9.2 ppg in/out. Pumps off.
Monitor pressure with MPD. In 5 min built to 35 psi, bleed off, 5 min built to 23 psi, bleed off and in 5 min built to line pressure of 16 psi with no pressure built.
Open the RCD head bleeder, drain the line and well is static. Observe the well for flow for 15 minutes and well is still static. Remove the RCD bearing and install
the MPD trip nipple. Inflate the air boots, fill the stack and check for leaks (good). Pump a dry job. Drop 2.45" OD drift on wire. Blow down the top drive and geo
span. TOOH standing back 5" DP from 6,467' to 282'. Observe the well for flow, well is on slight losses. Recover drift on wire. LD jar stand, float sub and 3 NM flex
collars. Download MWD data. Static loss rate = 4 BPH. Daily disposal to G&I = 534 bbls Total disposal to G&I = 13,334 bbls. Daily water hauled from B-Creek/A-
pad = 0/210 bbls Total water hauled from B-Creek/A-pad = 8,230/2,045 bbls. Daily fluid loss = 184 bbls Total fluid loss = 482 bbls. Daily metal recovered = 7 lbs
Total metal recovered = 45 lbs.
8/18/2022 Finish downloading MWD data, LD remaining BHA 3, bit grade= 2-1-CT-A-X-I-BT-TD. Integral blade stab showed wear on both leading and trailing blade edges.
ADR tool had wear on stab. 8.5 bbl losses TOOH from shoe. Monitor well on the trip tank, Clear and clean the rig floor. Static loss rate 2.5 BPH Pull split bushings
and install master bushing. Mobilize handling equipment and power tongs to the rig floor. RU to run 4-1/2" liner. MU crossover on the FOSV. Mobilize centralizers
to the rig floor. PJSM. MU & RIH round nose float shoe/WIV with crossover joint , RIH WITH 4-1/2", 13.5#, L-80, H625 pre-drilled injection liner as per tally installing
a centralizer on every joint to 2503'. MU to optimum TQ @ 9,600 ft-lbs. PU = 73K, SO = 70K. Loss rate RIH= 2 BPH Continue RIH with 4-1/2" pre-drilled injection
liner as per tally installing a centralizer on every joint from 2503' to 7501', PU 102K, SO 84K at the shoe before entering open hole, RIH 30 fpm. Verify pipe count.
MU to optimum TQ @ 9,600 ft-lbs. PU = 104K, SO = 81K. Loss rate RIH= 1.5-2 BPH Change out elevators to 5'' DP. PU 9-5/8'' X 7'' SLZXP LTP assembly. TIH 1
stand to 7,642'. Obtain parameters: 3 BPM = 200 psi, 10 RPM = 5K ft-lbs TQ, PU = 107K, SO = 85K & ROT = 95K. Blow down the top drive. Lost 14 bbls while
running 4-1/2" liner TIH with 4-1/2" injection liner on 5" DP from 7,642' to 13,830'. Tag TD twice with 10K down. Break circulation with 10 bbls at 3 BPM = 350 psi.
PU =180K & SO = 100K. Drop 1" phenolic ball. Blow down the top drive. MU TIW & side entry sub below 20' DP pup joint. RU cement line and test pump. Pump
the ball down with 25 bbl hi-vis sweep. Ball on seat at 770 strokes. Pressure up to 2,500 psi and observed shear at 1,900 psi. Hold for 3 minutes and SO 60K.
Continue to pressure up with the rig pumps, neutralizer sheared at 2,800 psi, HRD sheared at 2,900 psi and the ball seat sheared at 4,003 psi. PU to confirm
release with PU = 145K. Top of the SLZXP LTP at 6,297' RU testing equipment and purge air from lines. Close the annular. PT the IA/LTP to 1,500 psi for 10
minutes charted (good test). Bleed off pressure and open the annular. RD the circulating equipment. Blow down the cement line. Pull the running tool out of the
SLZXP while circulating at 3 BPM = 300 psi. Continue to circulate a total of 1.5 BU at 450 GPM = 1,200 psi with reciprocating 30' (no rotation). LD 1 stand of 5" DP
in the mouse hole. Observe the well for flow - static. Blow down the top drive and choke/kill line. PJSM. Slip and cut 62' (9 wraps) of drilling line. Service the draw
works and top drive. Static loss rate = 1 BPH. Daily disposal to G&I = 0 bbls Total disposal to G&I = 13,334 bbls. Daily water hauled from B-Creek/A-pad = 0/215
bbls Total water hauled from B-Creek/A-pad = 8,230/2,260 bbls. Daily fluid loss = 42 bbls Total fluid loss = 524 bbls. Daily metal recovered = 0 lbs Total metal
recovered = 45 lbs.
8/19/2022 With the well static, pump a dry job and blow down the top drive. TOOH from 6,227' to 1,182' LD 5'' DP Troubleshoot pipe skate, counter weight pull back cable
failed, spool 3/8 line on same, good. SimOps: load out 4-1/2'' handling equipment. Mobilize the tubing hanger to the rig floor. Monitor well, 1 BPH loss rate. Swap to
completions AFE at 12:00 hours. Daily disposal to G&I = 154 bbls Total disposal to G&I = 13,488 bbls. Daily water hauled from B-Creek/A-pad = 0/125 bbls Total
water hauled from B-Creek/A-pad = 8,230/2,385 bbls. Daily fluid loss = 24.5 bbls Total fluid loss = 548.5 bbls. Daily metal recovered = 0 lbs Total metal recovered
= 45 lbs.
Activity Date Ops Summary
8/19/2022 Continue POOH LD 5'' DP from 1179' to 40'. LD liner running tool, inspect same, good. 16 bbl losses LD DP,RU pulling tool and pull the wear bushing. Drain the
stack, make hanger dummy run as per WHR. Clean and clean rig floor. Mobilize Centrilift tools, 120 cannon clamps, Tec wire spool and 3-1/2” handling equipment
to rig floor. RU to run upper completion. MU crossover to FOSV. Static loss = 1.5 BPH.,PU bullet seal assembly and RIH on 3-1/2”, 9.3#, L-80, EUE 8rd tubing per
tally to no-go at 6,310' with 5K down. PU = 81K and SO = 73K. Torque to 2,800 ft-lbs with Doyon double stack tongs. Installing cannon clamps, spooling Tec wire
and testing Tec wire every 1000'. Loss rate = 1-1.5 BPH,Lay down joints #200 and #199. MU 2.17' then 5.09' pup joints. MU joint #198. Lost 15 bbls while running
3-1/2" completion.,Change elevators to 5" DP. PU 5" DP landing joint. MU crossover to the landing joint and MU the tubing hanger. MU the tubing hanger to the
completion,Terminate the Tec wire, feed through the tubing hanger and secure. Drain the BOP stack. Land the tubing hanger. RU to reverse circulate. Purge air,
close the annular and pressure up to 200 psi on the IA. PU to expose the ports in the tie back seals. PJSM.
8/20/2022 RU 2'' hose from annulus to the slop tank, Pump 16 bbls 9.2 ppg CIB down the IA 3 bpm, 310 PSI, with returns out tubing to rock washer, find that the vac truck with
diesel has an issue with fault code for the DEF system, shut down pumping.,Replacement vac truck and ASRC mechanic in-route from Deadhorse. Vac truck on
location at 08:30. Transfer diesel and RU alternate vac truck. SimOps: Clear Centrilift tools and equipment from rig floor,Continue reverse circulate total 215 bbls
9.2 ppg CI brine down the IA taking returns out tubing to the rock washer at 6 BPM = 550 psi followed with 186 bbls diesel at 5 BPM = 550 psi, freeze protecting the
IA to 3,000'.,Slack off closing the ports. Drain the stack. Open the annular, flush out the stack with water and blow down lines. Land the tubing hanger with 33K on
hanger, 2.07' off no-go & end of the tubing at 6,308.09'. RILDS,Line up to pump down the IA, Pressure up to 3,700 psi and perform MIT on the 9 -/8'' x 3-1/2''
annulus for 30 charted minutes, good test, bleed off pressure, blow down lines, RD test equipment. 6.5 bbls pumped, 6.5 bbls bled back,RD landing joint and lines.
Install BPV. Rig off highline power and on generators at 15:00 hours.,LD mousehole, pull MPD riser and remove the kill line. ND the BOP stack, remove the spacer
spool and set on pedestal. SimOps: Clean in the pits.,Install the CTS plug into the BPV. Pull the tree into the cellar and install onto the tubing head.,NU the tubing
head adapter and tree. Obtain final gauge reading: tubing pressure = 2,020 psi, IA pressure = 1,786 psi, tubing & IA temperature = 83° and voltage = 20.6,PT the
tubing hanger void to 500/5,000 psi for 10 minutes each (good test). Fill the tree with diesel. PT the tree to 250/5,000 psi (good test).,Pull the CTS plug and
BPV.,RU to bullhead down the tubing.,Bullhead 26 bbls of diesel down the tubing. ICP at 2 BPM = 210 psi, FCP at 1.6 BPM = 920 psi. Flush the line with 2 bbls of
water at 1 BPM = 680 psi. Blow down and RD circulating lines. Bleed the tubing down to 500 psi (would not bleed down to 0 psi). Shut in and secure the well.
SimOps: Empty the slop tank,Clean the cellar box. Daily disposal to G&I = 854 bbls Total disposal to G&I = 14,342 bbls. Daily water hauled from B-Creek/A-pad =
0/75 bbls Total water hauled from B-Creek/A-pad = 8,230/2,460 bbls. Daily fluid loss = 0 bbls Total fluid loss = 548.5 bbls. Daily metal recovered = 0 lbs Total
metal recovered = 45 lbs.
8/21/2022 Rig welder cut off the mouse hole and seal weld the bottom of the cellar box. SimOps: Prep for rig move,PJSM. Skid the rig floor into move position. Remove the
stairs handrails and prepare to move the rig off of well B-31. Rig released from well B-31 at 06:00 hours.
50-029-23723-00-00API #:
Well Name:
Field:
County/State:
MP B-31
Milne Point
Hilcorp Energy Company Composite Report
, Alaska
8/2/2022Spud Date:
MIT on the 9 -/8'' x 3-1/2''
annulus for 30 charted minutes, good test,
Well Name Rig API Number PTD# Start Date End Date
MPU B-31 Eline/Fullbore 50-029-23723-00-00 222-084 8/21/2022 9/25/2022
9/2/2022
PULL 3" JETPUMP (serial# - HC-00041, ratio: 12A) FROM XD-SS AT 5,890' MD. USE POWER FLUID TO DIPLACE TUBING. ATTEMPT TO
SET 3"" JETPUMP IN XD-SS AT 5,890' MD (Unsuccessful).
8/21/2022
Hilcorp Alaska, LLC
Weekly Operations Summary
Wellhead: Land 11 x 3 1/2 CIW hanger, Set 3" CST BPV in well, Nipple down BOPs, terminate Tech Line, Nipple up adapter and tree,
Test both to 500 / 5000 for 5/10 mins, All thest good. Pull Test dart and BPV with dry rod.
8/23/2022
WELL S/I ON ARRIVAL. OPEN SLEEVE @ 5877' SLM / 5889' MD. SET W/3" JET PUMP (serial# HC-00041, ratio: 12A, screen, sec. loc.,
OAL=69"). S/I ON DEPARTURE
CONTINUE WSR FROM 9-2-22, PT PCE 300L / 3500H. USE POWER FLUID TO ASSIDT W/ BRUSH, 2.60"" G-RING FROM SURFAVE TO
5,900' SLM (No issues). SET 3" JETPUMP (serial# - HC-00030, ratio: 13A) IN XD-SS AT 5,890' MD. WELL SHUT-IN ON DEPARTURE,
NOTIFIED PAD OP.
9/3/2022
9/25/2022
(Post Well Flow) (Pressure Test equipment to 250/2500 psi) Pumped 25 bbls produced water down Hardline to prod. Freeze
protected 2 hardline from tree to prod and test header with a total of 10 bbls 60/40. Pumped 74 bbls criesel down IA and 26 bbls
criesel down TBG. Tags hung.
TD Shoe Depth: PBTD:
No. Jts. Returned
Jts.
1
1
1
1
1
104
1
1
1
49
1
X Yes No X Yes No 30
Fluid Description:
Liner hanger Info (Make/Model): Liner top Packer?: Yes No
Liner hanger test pressure:X Yes No
Centralizer Placement:
Preflush (Spacer)
Type: Density (ppg) Volume pumped (BBLs)
Lead Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Tail Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Post Flush (Spacer)
Type: Density (ppg) Rate (bpm): Volume:
Displacement:
Type: Density (ppg) Rate (bpm): Volume (actual / calculated):
FCP (psi): Pump used for disp:X Yes No
Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job
Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf:
Cement In Place At: Date: Estimated TOC:
Method Used To Determine TOC:
Preflush (Spacer)
Type: Density (ppg) Volume pumped (BBLs)
Lead Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Tail Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Post Flush (Spacer)
Type: Density (ppg) Rate (bpm): Volume:
Displacement:
Type: Density (ppg) Rate (bpm): Volume (actual / calculated):
FCP (psi): Pump used for disp:X Yes No
Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job
Cement returns to surface?X Yes No Spacer returns?Yes X No Vol to Surf:
Cement In Place At: Date: Estimated TOC:
Method Used To Determine TOC:
Post Job Calculations:
Calculated Cmt Vol @ 0% excess: Total Volume cmt Pumped:
Cmt returned to surface: Calculated cement left in wellbore:
OH volume Calculated: OH volume actual: Actual % Washout:
Casing (Or Liner) Detail
Shoe
Cut joint
10 3/4
463.79 31354
SE
C
O
N
D
S
T
A
G
E
Rig #2
7:23
Cement to surface
Rotate Csg Recip Csg Ft. Min. PPG9.55
Shoe @ 6493 FC @ Top of Liner6,408.81
Floats Held
403.71 732
218.5 513.5
Spud Mud
CASING RECORD
County State Alaska Supv.C. Demoski / J. Vanderpool
Hilcorp Energy Company
CASING & CEMENTING REPORT
Lease & Well No.MP B-31 Date Run 8-Aug-22
Setting Depths
Component Size Wt. Grade THD Make Length Bottom Top
TXP-BTC Innovex 1.75 6,493.00 6,491.25
23.72 55.92 32.209 5/8 47.0 L-80 TXP-BTC Tenaris
Csg Wt. On Hook:345,000 Type Float Collar:Innovex No. Hrs to Run:26
9.5 7.5
590
10
10.7 349 5
5.3
800
Bump Plug?
FI
R
S
T
S
T
A
G
E
10Tuned Spacer 60
15.8
550
5.6
9.5 6 146.65/133.5
478.2/477.49
890
75
Rig #2
15.8 78
Bump press
Cement Circ to surface
Bump Plug?
Y
20:43 8/8/2022 2,092
2092.1
6,493.006,501.00
CEMENTING REPORT
Csg Wt. On Slips:100,000
Spud Mud
Tuned Spacer
680 2.88
Stage Collar @
60
Bump press
100
218.8
ES Cementer Closure OK
56
12 249
Type of Shoe:Innovex Casing Crew:Doyon
No. Jts. Delivered No. Jts. Run
www.wellez.net WellEz Information Management LLC ver_04818br
3.5
Arctic Cem
Type
82 total 9-5/8" x 12-1/4" centralizers installed.
2 each with 4 stop rings installed on joint #1
1 each free floating on joint #2
1 each with 2 stop rings each installed on joints #3 & #4
1 each free floating on joints #5 to 24.
1 each every 2nd joint #26 to 54, then every 3rd joint #57 to 102.
1 each with 1 stop ring on pup joint above and below ES cementer.
Every joint #105 to 113, then every 3rd joint #116 to 155.
Casing 9 5/8 40.0 L-80 TXP-BTC Tenaris 81.13 6,491.25 6,410.12
Float Collar 10 3/4 TXP-BTC Innovex 1.31 6,410.12 6,408.81
Casing 9 5/8 40.0 L-80 TXP-BTC Tenaris 39.10 6,408.81 6,369.71
Baffle Adapter 10 3/4 TXP-BTC Halliburton 1.40 6,369.71 6,368.31
Casing 9 5/8 40.0 L-80 TXP-BTC Tenaris 4,256.87 6,368.31 2,111.44
Casing Pup Joint 9 5/8 40.0 L-80 TXP-BTC Tenaris 15.61 2,111.44 2,095.83
ES Cementer 10 3/4 TXP-BTC Halliburton 3.73 2,095.83 2,092.10
Casing Pup Joint 9 5/8 40.0 L-80 TXP-BTC Tenaris 17.49 2,092.10 2,074.61
Casing 9 5/8 47.0 L-80 TXP-BTC Tenaris 2,018.69 2,074.61 14.54
Type I/II lead 595 2.35
Type I/II Tail 379 1.16
4.75
Type I/II Tail 270 1.17
8/9/2022 Surface
Spud Mud
Surface
Cement Circ to surface
X
2,092
X
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Chelsea Wright Digitally signed by Chelsea
Wright
Date: 2022.08.16 15:21:02 -08'00'
Benjamin Hand Digitally signed by Benjamin Hand
Date: 2022.08.16 15:22:34 -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: 08/30/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL :
WELL: MPU B-31
PTD: 222-084
API: 50-029-23723-00-00
FINAL LWD FORMATION EVALUATION LOGS (08/03/2022 to 08/16/2022)
x ROP, AGR, DGR, ABG, EWR-M5, ADR, Horizontal Presentation (2” & 5” MD/TVD Color Logs)
x Final Definitive Directional Survey
x Final Geosteering and EOW Report/Plots
SFTP Transfer – Main Folders:
FINAL LWD Subfolders:
FINAL Geosteering Subfolders:
Please include current contact information if different from above.
PTD:222-084
T36953
Kayla
Junke
Digitally signed by
Kayla Junke
Date: 2022.08.31
08:51:07 -08'00'
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STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
SSu bm it t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner: Rig No.:14 DATE: 8/10/22
Rig Rep.: Rig Email:
Operator:
Operator Rep.: Op. Rep Email:
Well Name:PTD #2220840 Sundry #
Operation: Drilling: X Workover: Explor.:
Test: Initial: X Weekly: Bi-Weekly: Other:
Rams:250-3000 Annular:250-3000 Valves:250-3000 MASP:1519
MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 1P
Permit On Location P Hazard Sec.P Lower Kelly 1P
Standing Order Posted P Misc.NA Ball Type 1P
Test Fluid Water Inside BOP 1P
FSV Misc 0NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0NATrip Tank PP
Annular Preventer 1 13-5/8"P Pit Level Indicators PP
#1 Rams 1 2-7/8x5"P Flow Indicator PP
#2 Rams 1 Blind P Meth Gas Detector PP
#3 Rams 1 2-7/8x5"P H2S Gas Detector PP
#4 Rams 0NAMS Misc 0NA
#5 Rams 0NA
#6 Rams 0NAACCUMULATOR SYSTEM:
Choke Ln. Valves 1 3-1/8x5000 P Time/Pressure Test Result
HCR Valves 2 3-1/8x5000 P System Pressure (psi)3025 P
Kill Line Valves 2 3-1/8x5000 P Pressure After Closure (psi)1675 P
Check Valve 0NA200 psi Attained (sec)43 P
BOP Misc 0NAFull Pressure Attained (sec)195 P
Blind Switch Covers: All stations Yes
CHOKE MANIFOLD:Bottle Precharge:P
Quantity Test Result Nitgn. Bottles # & psi (Avg.): 2050 P
No. Valves 14 P ACC Misc 0NA
Manual Chokes 1P
Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result
CH Misc 0NA Annular Preventer 23 P
#1 Rams 6 P
Coiled Tubing Only:#2 Rams 7 P
Inside Reel valves 0NA #3 Rams 7 P
#4 Rams 0 NA
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:0 Test Time:7.5 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 8/8/2022 8:02
Waived By
Test Start Date/Time:8/10/2022 14:00
(date) (time)Witness
Test Finish Date/Time:8/10/2022 21:30
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Lou Laubenstein
Doyon
Performed BOP test with 3-1/2" & 5" test joints to 250 psi low and 3000 psi high 5 min. each, all test's preformed against test
plug. Test one 4.5" IF FOSV & one 4.5" IF Dart valve. Tested gas alarms both audio & visual. Tested PVT'S & flow paddle,
preform draw downs on super choke & manual choke @ 1500 psi
T.Shones/A.Carlo
Hilcorp
D.Yessak/J.Vanderpool
MPU B-31
Test Pressure (psi):
dyessak@hilcorp.com
Form 10-424 (Revised 08/2022) 2022-0810_BOP_Doyon14_MPU_B-31
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CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas
Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential
and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you
are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the
mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov.
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038%
37'
Date: 8/1/2022 Development: X Exploratory:
Drlg Contractor: Rig No. 14 AOGCC Rep:
Operator:Oper. Rep:
Field/Unit/Well No.:Rig Rep:
PTD No.: 2220840 Rig Phone:
Rig Email:
MMISCELLANEOUS:DIVERTER SYSTEM:
Location Gen.: P Well Sign: P Designed to Avoid Freeze-up? P
Housekeeping: P Drlg. Rig. P Remote Operated Diverter? P
Warning Sign P Misc: NA No Threaded Connections? P
24 hr Notice: P Vent line Below Diverter? P
AACCUMULATOR SYSTEM:Diverter Size: 21 1/4 in.
Systems Pressure: 3000 psig P Hole Size: 12 1/4 in.
Pressure After Closure: 1800 psig P Vent Line(s) Size: 16 in. P
200 psi Recharge Time: 37 Seconds P Vent Line(s) Length: 212 ft. P
Full Recharge Time:161 Seconds P Closest Ignition Source: 76 ft. P
Nitrogen Bottles (Number of): 6 Outlet from Rig Substructure: 205 ft. P
Avg. Pressure: 2025 psig P
Accumulator Misc: NA
Vent Line(s) Anchored: P
MMUD SYSTEM:Visual Alarm Turns Targeted / Long Radius: P
Trip Tank: P P Divert Valve(s) Full Opening: P
Mud Pits: P P Valve(s) Auto & Simultaneous:
Flow Monitor: P P Annular Closed Time: 23 sec P
Mud System Misc: 0 NA Knife Valve Open Time: 16 sec P
Diverter Misc: NA
GGAS DETECTORS:Visual Alarm
Methane: P P
Hydrogen Sulfide: P P
Gas Detectors Misc: 0 NA
Total Test Time: 0.5 hrs Non-Compliance Items: 0
Remarks:
Submit to:
AlaskaNS-Doyon14-DSMs@hilcorp.co
TTEST DATA
J Hansen / J.Charlie
phoebe.brooks@alaska.gov
Hilcorp
24 hr notice given at 15:31 on 7/30/22 and AOGCC rep Adam Earl waived witness at 15:56 hrs on 7/31/22. Test performed with 5" DP, Gas
alarms tested good, PVT system calibrated functioned and tested good, Vent line checked out Good
0
C.Demoski / I Toomey
0
907-670-3092
TTEST DETAILS
jim.regg@alaska.gov
AOGCC.Inspectors@alaska.gov
MPU B-31
SSTATE OF AL ASK A
AAL ASK A OIL AND GAS CONSERVATION COMMISSION
DDi v er t er Sys t em s In s p ec t i o n Rep o r t
GGENERAL INFORMATION
WaivedDoyon
**Al l Di ver t er r epor t s ar e due t o t h e ag enc y w i t h i n 5 days of t est i n g *
Form 10-425 (Revised 04/2018)2022-0801_Diverter_Doyon14_MPU_B-31
+LOFRUS$ODVND//&
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CAUTION: This email originated from outside the State of Alaska mail system. Do not click links
or open attachments unless you recognize the sender and know the content is safe.
From:Rixse, Melvin G (OGC)
To:Nathan Sperry (nathan.sperry@hilcorp.com)
Cc:AOGCC Records (CED sponsored)
Subject:20220719 1613 APPROVAL for MISSING VARIANCE APPROVALS on PTD 222-084 Hilcorp Well B-31
Date:Tuesday, July 19, 2022 4:17:08 PM
Attachments:image003.png
Nathan,
Your variance requests should have been approved on the PTD cover. Please utilize this email as Hilcorp’s
approval for the variances requested below:
1. Variance to 20 AAC 25.412 (b) - APPROVED. Packer placement for this WINJ is not required to be within 200’
MD of the top of perforations. The packer will be place below the top of the confining zones to the SB formation.
2. Hilcorp is APPROVED for a pre-production flow period of 30 days utilizing a reverse circulating jet pump. Hilcorp will
provide a 24/7 man watch while this well is on production.
Mel Rixse
Senior Petroleum Engineer (PE)
Alaska Oil and Gas Conservation Commission
907-793-1231 Office
907-297-8474 Cell
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),
State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or
disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding
it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov).
From: Nathan Sperry <Nathan.Sperry@hilcorp.com>
Sent: Tuesday, July 19, 2022 2:45 PM
To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Cc: Brian Glasheen <Brian.Glasheen@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com>
Subject: PTD 222-084 Hilcorp Well B-31 Question re: variances
Hello Mel,
In the MPU B-31 PTD application, Hilcorp requested 2 variances (page 9 of the procedure, screenshot included below).
In the approved PTD, I do not see where the AOGCC either granted or denied those variance requests. Are these
variances approved?
Thank you,
Nate Sperry
Drilling Engineer
Hilcorp Alaska, LLC
O: 907-777-8450
C: 907-301-8996
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity namedabove. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this
email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed
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While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission,opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard andthe recipient should carry out such virus and other checks as it considers appropriate.
CORRECTION 4298' FEL
CORRECTION 4298' FEL
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Wd W/ t >> ^ddh^dŽƉŽĨ^K;DͿdŽƉŽĨ^K;dsƐƐͿdŽƉŽĨĞŵĞŶƚ;DͿdŽƉŽĨĞŵĞŶƚ;dsͿ^ĐŚƌĂĚĞƌKƐƚĂƚƵƐ ŽŶĂů/ƐŽůĂƚŝŽŶϭϴϮͲϭϵϰ ϱϬͲϬϮϵͲϮϬϴϲϲͲϬϬͲϬϬ DWhͲϬϮ ĐƚŝǀĞŝŶũĞĐƚŽƌͲ<ƵƉĂƌƵŬ ϱϳϯϴ ϰϯϵϰ ΕϯϳϬϬ ΕϯϬϱϯ ůŽƐĞĚ >ϴͬϮϮͬϭϵϵϵΕdKϯϳϬϬDϮϭϳͲϬϵϮ ϱϬͲϬϮϵͲϮϯϱϳϵͲϬϬͲϬϬ DWhͲϰϱ ĐƚŝǀĞŝŶũĞĐƚŽƌͲ<ƵƉĂƌƵŬ ϲϰϰϲ ϰϰϭϭ ^ƵƌĨĂĐĞ ^ƵƌĨĂĐĞ ůŽƐĞĚdKĂƚƐƵƌĨĂĐĞ͘dŚĞϵͲϱͬϴΗƐƵƌĨĂĐĞĐĂƐŝŶŐǁĂƐƐĞƚĂƚϳ͕ϬϭϱΖĂŶĚĐĞŵĞŶƚĞĚƚŽƐƵƌĨĂĐĞŝŶϮϬϭϳǁŝƚŚϮϮϰďďůƐƚŽƐƵƌĨĂĐĞ͘ϮϭϲͲϭϱϭ ϱϬͲϬϮϵͲϮϯϱϳϬͲϬϬͲϬϬ DWhͲϯϮ ĐƚŝǀĞƉƌŽĚƵĐĞƌͲ^ĐŚƌĂĚĞƌE Eͬ Eͬ Eͬ Eͬ EͬtĞůůdĂďŽǀĞƚŚĞKnjŽŶĞ͘ϵͲϱͬϴΗĂƐŝŶŐĨŝƌƐƚƐƚĂŐĞĐĞŵĞŶƚũŽď͕ϮϲϯďďůƐŽĨϭϭ͘ϳηůĞĂĚĐĞŵĞŶƚĨŽůůŽǁĞĚďLJϰϯďďůƐŽĨϭϱ͘ϴηƚĂŝůĐĞŵĞŶƚ͘WůƵŐďƵŵƉĞĚ͘^ĞĐŽŶĚƐƚĂŐĞĐĞŵĞŶƚũŽď͕ϮϯϬďďůƐŽĨϭϬ͘ϳηůĞĂĚĐĞŵĞŶƚĨŽůůŽǁĞĚďLJϲϬďďůƐŽĨϭϱ͘ϴηƚĂŝůĐĞŵĞŶƚ͘ϭϰϬďďůƐŽĨĐĞŵĞŶƚƌĞƚƵƌŶĞĚĂƚƐƵƌĨĂĐĞ͘ϮϭϲͲϬϮϳ ϱϬͲϬϮϵͲϮϯϱϲϲͲϬϬͲϬϬ DWhͲϮϴ ĐƚŝǀĞƉƌŽĚƵĐĞƌͲ^ĐŚƌĂĚĞƌE Eͬ Eͬ Eͬ Eͬ EͬtĞůůdĂďŽǀĞƚŚĞKnjŽŶĞ͘ϵͲϱͬϴΗĐĂƐŝŶŐĨŝƌƐƚƐƚĂŐĞĐĞŵĞŶƚũŽďǁĂƐϮϯϲďďůƐŽĨϭϭ͘ϳηůĞĂĚĐĞŵĞŶƚĨŽůůŽǁĞĚďLJϰϰďďůƐŽĨϭϱ͘ϴηƚĂŝůĐĞŵĞŶƚ͘WůƵŐďƵŵƉĞĚ͘^ĞĐŽŶĚƐƚĂŐĞĐĞŵĞŶƚũŽďǁĂƐϮϱϭďďůƐŽĨϭϬ͘ϳηůĞĂĚĐĞŵĞŶƚĨŽůůŽǁĞĚďLJϱϱďďůƐŽĨϭϱ͘ϴηƚĂŝůĐĞŵĞŶƚ͘ϵϬďďůƐŽĨĐĞŵĞŶƚƌĞƚƵƌŶĞĚĂƚƐƵƌĨĂĐĞ͘ϭϴϱͲϮϮϵ ϱϬͲϬϮϵͲϮϭϰϱϬͲϬϬͲϬϬ DWhͲϭϴ ĐƚŝǀĞŝŶũĞĐƚŽƌͲ<ƵƉĂƌƵŬ ϲϭϮϴ ϰϰϬϲ ϮϰϱϬ ϮϯϬϱ ůŽƐĞĚϵͲϱͬϴΗƐĞƚĂƚϲ͕ϰϬϱΖĂŶĚĐĞŵĞŶƚĞĚǁŝƚŚϲϬϭďďůƐŽĨWĞƌŵĂĨƌŽƐƚ ĂŶĚϱϲďďůƐŽĨ'ŝŶϭϵϴϱ͘dŚĞŽƌŝŐŝŶĂůŽƉĞƌĂƚŽƌĞƐƚŝŵĂƚĞĚƚŚĞdKĂƚϮ͕ϰϬϱΖD͘ϮϭϲͲϬϭϱ ϱϬͲϬϮϵͲϮϯϱϲϰͲϬϬͲϬϬ DWhͲϮϵ ĐƚŝǀĞŝŶũĞĐƚŽƌͲ^ĐŚƌĂĚĞƌE Eͬ Eͬ Eͬ Eͬ EͬtĞůůdĂďŽǀĞƚŚĞKnjŽŶĞ͘ϵͲϱͬϴΗĐĂƐŝŶŐĨŝƌƐƚƐƚĂŐĞĐĞŵĞŶƚũŽďǁĂƐϭϴϳďďůƐŽĨϭϭ͘ϳηůĞĂĚĐĞŵĞŶƚĨŽůůŽǁĞĚďLJϰϬďďůƐŽĨϭϱ͘ϴηƚĂŝůĐĞŵĞŶƚ͘WůƵŐďƵŵƉĞĚ͘^ĞĐŽŶĚƐƚĂŐĞĐĞŵĞŶƚũŽďǁĂƐϮϮϲďďůƐŽĨϭϬ͘ϳηůĞĂĚĐĞŵĞŶƚĨŽůůŽǁĞĚďLJϱϱ͘ϴďďůƐŽĨϭϱ͘ϴηƚĂŝůĐĞŵĞŶƚ͘ϭϴϬďďůƐŽĨĐĞŵĞŶƚƌĞƚƵŶƌĞĚĂƚƐƵƌĨĂĐĞϮϭϲͲϭϲϰ ϱϬͲϬϵͲϮϯϱϳϯͲϬϬͲϬϬ DWhͲϯϯ ĐƚŝǀĞŝŶũĞĐƚŽƌͲ^ĐŚƌĂĚĞƌE EͬEͬ Eͬ Eͬ EͬtĞůůdĂďŽǀĞƚŚĞKnjŽŶĞ͘ϵͲϱͬϴΗĂƐŝŶŐĨŝƌƐƚƐƚĂŐĞĐĞŵĞŶƚũŽďǁĂƐϮϮϬďďůƐŽĨϭϭ͘ϳηůĞĂĚĐĞŵĞŶƚĨŽůůŽǁĞĚďLJϰϯďďůƐŽĨϭϱ͘ϴηƚĂŝůĐĞŵĞŶƚ͘WůƵŐďƵŵƉĞĚ͘^ĞĐŽŶĚƐƚĂŐĞĐĞŵĞŶƚũŽďǁĂƐϰϱϬƐdžƐŽĨϭϬ͘ϳηůĞĂĚĐĞŵĞŶƚĨŽůůŽǁĞĚďLJϱϲ͘ϲďďůƐŽĨϭϱ͘ϴηƚĂŝůĐĞŵĞŶƚ͘ϮϬϭďďůƐŽĨĐĞŵĞŶƚƌĞƚƵƌŶĞĚĂƚƐƵƌĨĂĐĞ͘ϭϴϱͲϬϭϳ ϱϬͲϬϮϵͲϮϭϮϴϬͲϬϬͲϬϬ DWhͲϭϬ ĐƚŝǀĞƉƌŽĚƵĐĞƌͲ<ƵƉĂƌƵŬ ϱϱϯϰ ϰϰϮϳ ^ƵƌĨĂĐĞ ^ƵƌĨĂĐĞ ůŽƐĞĚϵͲϱͬϴ͟ĐĂƐŝŶŐ;ďĂƐĞĂƚϱϳϴϵΖDͿǁĂƐĐĞŵĞŶƚĞĚďĂĐŬƚŽƐƵƌĨĂĐĞǁŝƚŚϴϲϴďďůƐĐĞŵĞŶƚ͘&ƵůůƌĞƚƵƌŶƐƚŚƌŽƵŐŚŽƵƚũŽď͕ϱϬďďůƐĐĞŵĞŶƚƌĞƚƵƌŶĞĚƚŽƐƵƌĨĂĐĞ͘ƌĞĂŽĨZĞǀŝĞǁDWhͲϯϭ^K
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1 0 0 00105001100011500120001250013000135001400014388MPU B-31i wp07Start Dir 2º/100' : 300' MD, 300'TVDStart Dir 3º/100' : 500' MD, 499.84'TVDEnd Dir : 1600' MD, 1517.62' TVDStart Dir 4º/100' : 2100' MD, 1918.93'TVDEnd Dir : 2497.2' MD, 2207.09' TVDStart Dir 4º/100' : 5515.11' MD, 4135.49'TVDEnd Dir : 6438.65' MD, 4466.27' TVDStart Dir 2º/100' : 6538.65' MD, 4471.5'TVDEnd Dir : 6831.78' MD, 4477.65' TVDStart Dir 2º/100' : 7906.25' MD, 4466.5'TVDEnd Dir : 8170.44' MD, 4459.89' TVDStart Dir 2º/100' : 8562.43' MD, 4444.34'TVDEnd Dir : 8652.39' MD, 4441.97' TVDStart Dir 2.5º/100' : 9452.39' MD, 4431.5'TVDEnd Dir : 9597.92' MD, 4425.38' TVDStart Dir 2.5º/100' : 9895.8' MD, 4404.24'TVDEnd Dir : 10113.87' MD, 4396.5' TVDStart Dir 2º/100' : 10188.87' MD, 4396.5'TVDEnd Dir : 10280.13' MD, 4397.95' TVDStart Dir 2º/100' : 11050.78' MD, 4422.5'TVDEnd Dir : 11086.26' MD, 4423.43' TVDStart Dir 2º/100' : 11295.38' MD, 4427.78'TVDEnd Dir : 11900.1' MD, 4447.32' TVDStart Dir 2º/100' : 12225.1' MD, 4461.5'TVDEnd Dir : 12234.28' MD, 4461.91' TVDStart Dir 2º/100' : 13328.99' MD, 4513.16'TVDEnd Dir : 13388.16' MD, 4515.32' TVDTotal Depth : 14388.16' MD, 4541.5' TVDBPRFSV3UG4UG3LA3LA2UG MBUG MCSB NASB NBSB NCSB NDSB NESB OA targetHilcorp Alaska, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: Plan: MPU B-31Ground Level: 22.80+N/-S +E/-WNorthingEastingLatitudeLongitude0.000.006023106.90571993.59 70° 28' 24.293 N 149° 24' 43.042 WSURVEY PROGRAMDate: 2016-11-04T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool33.70 1200.00 MPU B-31i wp07 (MPU B-31) GYD_Quest GWD1200.00 6539.00 MPU B-31i wp07 (MPU B-31) 3_MWD+IFR2+MS+Sag6539.00 14388.16 MPU B-31i wp07 (MPU B-31) 3_MWD+IFR2+MS+SagFORMATION TOP DETAILSTVDPath TVDssPath MDPath Formation1826.50 1770.00 1984.84 BPRF2132.50 2076.00 2385.07 SV32828.50 2772.00 3469.69 UG43234.50 3178.00 4105.07 UG33888.50 3832.00 5128.57 LA33906.50 3850.00 5156.74 LA24136.50 4080.00 5516.68 UG MB4184.50 4128.00 5594.47 UG MC4352.50 4296.00 5932.78 SB NA4372.50 4316.00 5986.02 SB NB4392.50 4336.00 6044.96 SB NC4404.50 4348.00 6084.02 SB ND4418.50 4362.00 6134.49 SB NE4468.50 4412.00 6481.33 SB OA targetREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU B-31, True NorthVertical (TVD) Reference:MPB-31 prelim RKB @ 56.50usftMeasured Depth Reference:MPB-31 prelim RKB @ 56.50usftCalculation Method:Minimum CurvatureProject:Milne PointSite:M Pt B PadWell:Plan: MPU B-31Wellbore:MPU B-31Design:MPU B-31i wp07CASING DETAILSTVD TVDSS MD SizeName4471.52 4415.02 6539.00 9-5/8 9 5/8" x 12 1/4"4541.50 4485.00 14388.16 4-1/2 4 1/2" x 8 1/2"SECTION DETAILSSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation1 33.70 0.00 0.00 33.70 0.00 0.00 0.00 0.00 0.002 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 Start Dir 2º/100' : 300' MD, 300'TVD3 500.00 4.00 275.00 499.84 0.61 -6.95 2.00 275.00 5.72 Start Dir 3º/100' : 500' MD, 499.84'TVD4 800.00 13.00 275.00 796.24 4.47 -51.08 3.00 0.00 42.005 1600.00 36.62 286.50 1517.62 81.20 -374.22 3.00 17.00 338.86 End Dir : 1600' MD, 1517.62' TVD6 2100.00 36.62 286.50 1918.93 165.90 -660.18 0.00 0.00 612.36 Start Dir 4º/100' : 2100' MD, 1918.93'TVD7 2497.20 50.28 298.42 2207.09 272.94 -909.71 4.00 35.47 872.32 End Dir : 2497.2' MD, 2207.09' TVD8 5515.11 50.28 298.42 4135.49 1377.72 -2951.40 0.00 0.00 3146.48 Start Dir 4º/100' : 5515.11' MD, 4135.49'TVD9 6438.65 87.00 302.91 4466.27 1812.47 -3676.23 4.00 7.48 3981.19 End Dir : 6438.65' MD, 4466.27' TVD10 6538.65 87.00 302.91 4471.50 1866.73 -3760.06 0.00 0.00 4080.29 MPU B-31i wp06 tgt1 Start Dir 2º/100' : 6538.65' MD, 4471.5'TVD11 6831.78 90.59 307.54 4477.65 2035.70 -3999.35 2.00 52.25 4372.20 End Dir : 6831.78' MD, 4477.65' TVD12 7906.25 90.59 307.54 4466.50 2690.40 -4851.25 0.00 0.00 5445.63 MPU B-31i wp05 tgt2 Start Dir 2º/100' : 7906.25' MD, 4466.5'TVD13 8170.44 92.27 302.53 4459.89 2841.98 -5067.42 2.00 -71.44 5708.66 End Dir : 8170.44' MD, 4459.89' TVD14 8562.43 92.27 302.53 4444.34 3052.60 -5397.64 0.00 0.00 6097.01 Start Dir 2º/100' : 8562.43' MD, 4444.34'TVD15 8652.39 90.75 303.49 4441.97 3101.59 -5473.06 2.00 147.77 6186.27 End Dir : 8652.39' MD, 4441.97' TVD16 9452.39 90.75 303.49 4431.50 3542.99 -6140.19 0.00 0.00 6981.04 MPU B-31i wp05 tgt3 Start Dir 2.5º/100' : 9452.39' MD, 4431.5'TVD17 9597.92 94.07 302.00 4425.38 3621.62 -6262.46 2.50 -24.14 7125.26 End Dir : 9597.92' MD, 4425.38' TVD18 9895.80 94.07 302.00 4404.24 3779.07 -6514.44 0.00 0.00 7419.49 Start Dir 2.5º/100' : 9895.8' MD, 4404.24'TVD19 10113.87 90.00 305.63 4396.50 3900.31 -6695.44 2.50 138.20 7636.07 End Dir : 10113.87' MD, 4396.5' TVD20 10188.87 90.00 305.63 4396.50 3944.00 -6756.39 0.00 0.00 7710.86 MPU B-31i wp05 tgt4 Start Dir 2º/100' : 10188.87' MD, 4396.5'TVD21 10280.13 88.17 305.63 4397.95 3997.16 -6830.56 2.00 -179.93 7801.84 End Dir : 10280.13' MD, 4397.95' TVD22 11050.78 88.17 305.63 4422.50 4445.85 -7456.64 0.00 0.00 8569.85 MPU B-31i wp05 tgt5 Start Dir 2º/100' : 11050.78' MD, 4422.5'TVD23 11086.26 88.81 305.31 4423.43 4466.43 -7485.53 2.00 -26.60 8605.22 End Dir : 11086.26' MD, 4423.43' TVD24 11295.38 88.81 305.31 4427.78 4587.27 -7656.14 0.00 0.00 8813.58 Start Dir 2º/100' : 11295.38' MD, 4427.78'TVD25 11900.10 87.50 317.34 4447.32 4985.62 -8109.21 2.00 96.39 9416.71 End Dir : 11900.1' MD, 4447.32' TVD26 12225.10 87.50 317.34 4461.50 5224.40 -8329.23 0.00 0.00 9738.74 MPU B-31i wp05 tgt6 Start Dir 2º/100' : 12225.1' MD, 4461.5'TVD27 12234.28 87.32 317.33 4461.91 5231.14 -8335.44 2.00 -177.23 9747.83 End Dir : 12234.28' MD, 4461.91' TVD28 13328.99 87.32 317.33 4513.16 6035.18 -9076.58 0.00 0.00 10832.40 Start Dir 2º/100' : 13328.99' MD, 4513.16'TVD29 13388.16 88.50 317.34 4515.32 6078.65 -9116.65 2.00 0.43 10891.04 End Dir : 13388.16' MD, 4515.32' TVD30 14388.16 88.50 317.34 4541.50 6813.79 -9794.07 0.00 0.00 11882.51 MPU B-31i wp05 tgt7 Total Depth : 14388.16' MD, 4541.5' TVD
-750
0
750
1500
2250
3000
3750
4500
5250
6000
6750
7500
8250
9000
9750
10500
11250
12000
12750
13500
South(-)/North(+) (1500 usft/in)-9750 -9000 -8250 -7500 -6750 -6000 -5250 -4500 -3750 -3000 -2250 -1500 -750 0
West(-)/East(+) (1500 usft/in)
MPU B-31i wp05 tgt7
MPU B-31i wp05 tgt6
MPU B-31i wp05 tgt5
MPU B-31i wp05 tgt4
MPU B-31i wp05 tgt3
MPU B-31i wp06 tgt1
MPU B-31i wp05 tgt2
9 5/8" x 12 1/4"
4 1/2" x 8 1/2"
2501250175022502500275030003250350037504000425045004542MPU B -31i w p07Start Dir 3º/100' : 500' MD, 499.84'TVD
End Dir : 1600' MD, 1517.62' TVD
Start Dir 4º/100' : 2100' MD, 1918.93'TVD
End Dir : 2497.2' MD, 2207.09' TVD
Start Dir 4º/100' : 5515.11' MD, 4135.49'TVD
End Dir : 6438.65' MD, 4466.27' TVD
Start Dir 2º/100' : 6538.65' MD, 4471.5'TVD
End Dir : 6831.78' MD, 4477.65' TVD
Start Dir 2º/100' : 7906.25' MD, 4466.5'TVD
End Dir : 8170.44' MD, 4459.89' TVD
Start Dir 2º/100' : 8562.43' MD, 4444.34'TVD
End Dir : 8652.39' MD, 4441.97' TVD
Start Dir 2.5º/100' : 9452.39' MD, 4431.5'TVD
End Dir : 9597.92' MD, 4425.38' TVD
Start Dir 2.5º/100' : 9895.8' MD, 4404.24'TVD
End Dir : 10113.87' MD, 4396.5' TVD
Start Dir 2º/100' : 10188.87' MD, 4396.5'TVD
End Dir : 10280.13' MD, 4397.95' TVD
Start Dir 2º/100' : 11050.78' MD, 4422.5'TVD
End Dir : 11086.26' MD, 4423.43' TVD
Start Dir 2º/100' : 11295.38' MD, 4427.78'TVD
End Dir : 11900.1' MD, 4447.32' TVD
Start Dir 2º/100' : 12225.1' MD, 4461.5'TVD
End Dir : 12234.28' MD, 4461.91' TVD
Start Dir 2º/100' : 13328.99' MD, 4513.16'TVD
End Dir : 13388.16' MD, 4515.32' TVD
Total Depth : 14388.16' MD, 4541.5' TVD
CASING DETAILS
TVD TVDSS MD Size Name
4471.52 4415.02 6539.00 9-5/8 9 5/8" x 12 1/4"
4541.50 4485.00 14388.16 4-1/2 4 1/2" x 8 1/2"
Project: Milne Point
Site: M Pt B Pad
Well:Plan: MPU B-31
Wellbore: MPU B-31
Plan: MPU B-31i wp07
WELL DETAILS: Plan: MPU B-31
Ground Level: 22.80
+N/-S +E/-W Northing Easting Latitude Longitude
0.00 0.00
6023106.90 571993.59 70° 28' 24.293 N 149° 24' 43.042 W
REFERENCE INFORMATION
Co-ordinate (N/E) Reference:Well Plan: MPU B-31, True North
Vertical (TVD) Reference: MPB-31 prelim RKB @ 56.50usft
Measured Depth Reference:MPB-31 prelim RKB @ 56.50usft
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)MPB-02MPB-18MPB-27MPB-28MPU B-35 wp09No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:Plan: MPU B-31 NAD 1927 (NADCON CONUS)Alaska Zone 04Ground Level: 22.80+N/-S +E/-W Northing EastingLatitudeLongitude0.000.006023106.90571993.5970° 28' 24.293 N 149° 24' 43.042 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU B-31, True NorthVertical (TVD) Reference: MPB-31 prelim RKB @ 56.50usftMeasured Depth Reference:MPB-31 prelim RKB @ 56.50usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2016-11-04T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool33.70 1200.00 MPU B-31i wp07 (MPU B-31) GYD_Quest GWD1200.00 6539.00 MPU B-31i wp07 (MPU B-31) 3_MWD+IFR2+MS+Sag6539.00 14388.16 MPU B-31i wp07 (MPU B-31) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre 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)MPB-02MPB-06MPB-17MPB-18MPB-25MPB-27MPB-28MPB-29MPU B-30MPU B-32MPU B-33MPU B-35 wp09NO GLOBAL FILTER: Using user defined selection & filtering criteria33.70 To 14388.16Project: Milne PointSite: M Pt B PadWell: Plan: MPU B-31Wellbore: MPU B-31Plan: MPU B-31i wp07Ladder / S.F. Plots1 of 2CASING DETAILSTVD TVDSS MD Size Name4471.52 4415.02 6539.00 9-5/8 9 5/8" x 12 1/4"4541.50 4485.00 14388.16 4-1/2 4 1/2" x 8 1/2"
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0.001.002.003.004.00Separation Factor6800 7225 7650 8075 8500 8925 9350 9775 10200 10625 11050 11475 11900 12325 12750 13175 13600 14025 14450Measured Depth (850 usft/in)MPB-18MPB-28MPB-29MPU B-32MPU B-35 wp09MPC-02MPU C-45No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:Plan: MPU B-31 NAD 1927 (NADCON CONUS)Alaska Zone 04Ground Level: 22.80+N/-S +E/-W Northing EastingLatitudeLongitude0.000.006023106.90 571993.59 70° 28' 24.293 N149° 24' 43.042 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU B-31, True NorthVertical (TVD) Reference: MPB-31 prelim RKB @ 56.50usftMeasured Depth Reference:MPB-31 prelim RKB @ 56.50usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2016-11-04T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool33.70 1200.00 MPU B-31i wp07 (MPU B-31) GYD_Quest GWD1200.00 6539.00 MPU B-31i wp07 (MPU B-31) 3_MWD+IFR2+MS+Sag6539.00 14388.16 MPU B-31i wp07 (MPU B-31) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)6800 7225 7650 8075 8500 8925 9350 9775 10200 10625 11050 11475 11900 12325 12750 13175 13600 14025 14450Measured Depth (850 usft/in)NO GLOBAL FILTER: Using user defined selection & filtering criteria33.70 To 14388.16Project: Milne PointSite: M Pt B PadWell: Plan: MPU B-31Wellbore: MPU B-31Plan: MPU B-31i wp07Ladder / S.F. Plots2 of 2CASING DETAILSTVD TVDSS MD Size Name4471.52 4415.02 6539.00 9-5/8 9 5/8" x 12 1/4"4541.50 4485.00 14388.16 4-1/2 4 1/2" x 8 1/2"
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