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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:Christianson, Grace K (OGC)
To:Brooks, James S (OGC)
Subject:FW: [EXTERNAL] Sundry status
Date:Tuesday, October 1, 2024 9:56:10 AM
Attachments:Hilcorp_MPU_B-15A_ Sundry 323-298.pdf
Hi James,
Just a FYI to you as well for your RBDMS.
Thank you,
Grace
From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Sent: Tuesday, October 1, 2024 9:47 AM
To: Christianson, Grace K (OGC) <grace.christianson@alaska.gov>
Subject: FW: [EXTERNAL] Sundry status
Grace,
FYI. Rescind this one per email below.
Mel
From: Trevor Hyatt <Trevor.Hyatt@hilcorp.com>
Sent: Tuesday, October 1, 2024 9:23 AM
To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Cc: Joseph Lastufka <Joseph.Lastufka@hilcorp.com>
Subject: RE: [EXTERNAL] Sundry status
Yes, please cancel/rescind it.
Trevor Hyatt
Hilcorp Alaska, LLC
Drilling Engineer
Trevor.Hyatt@hilcorp.com
Cell: 907-223-3087
From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Sent: Tuesday, October 1, 2024 8:52 AM
To: Trevor Hyatt <Trevor.Hyatt@hilcorp.com>
Subject: [EXTERNAL] Sundry status
CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders.
Trevor,
Should the attached sundry be rescinded?
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).
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete
this message.
While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate.
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: 08/17/2023
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL
WELL: MPU B-15A + PB1 + PB2 + PB3 + PB4
PTD: 223-022
API: 50-029-21374-01-00 (MPU B-15A)
50-029-21374-70-00 (MPU B-15APB1)
50-029-21374-71-00 (MPU B-15APB2)
50-029-21374-72-00 (MPU B-15APB3)
50-029-21374-73-00 (MPU B-15APB4)
FINAL LWD FORMATION EVALUATION LOGS (05/10/2023 to 07/21/2023)
Multiple Propagation Resistivity & Gamma Ray (2” & 5” MD/TVD Color Logs)
Pressure While Drilling (PWD)
Final Definitive Directional Surveys
SFTP Transfer - Data Main Folders:
SFTP Transfer - Data Sub-Folders:
Please include current contact information if different from above.
PTD: 223-022
MPU B-15 A: T37940
B-15 A PB1: T37941
B-15 A PB2: T37942
B-15 A PB3: T37943
B-15 A PB4: T37944
8/18/2023Kayla
Junke
Digitally signed
by Kayla Junke
Date: 2023.08.18
10:06:17 -08'00'
3-1/2"X3-1/4"
By Grace Christianson at 9:17 am, Aug 11, 2023
Completed
7/22/2023
JSB
RBDMS JSB 081523
G
DSR-8/31/23MGR16MAY2024
Drilling Manager
08/10/23
Monty M
Myers
Digitally signed by Taylor
Wellman (2143)
DN: cn=Taylor Wellman (2143)
Date: 2023.08.10 14:55:12 -
08'00'
Taylor Wellman
(2143)
_____________________________________________________________________________________
Modified:JNL 7/26/2023
SCHEMATIC
Milne Point Unit
Well: MP B-15A
Last Completed: 7/22/2023
PTD: 223-022
CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm BPF
13-3/8" Conductor 48 / H-40 / PELP 12.715” Surface 113' 0.1571
9-5/8" Surface 36 / K-55 / Buttress 8.921” Surface 5,625’ 0.0773
7” Production 26 / L-80 / Buttress 6.276” Surface 8,747’ 0.0383
3-1/2”x3-1/4” Protection String 9.3 x 6.6 / L-80 / TCII 2.805” 8,575’ 9,236’
2-3/8” Slotted Liner 4.7 / L-80 / Hyd 511 1.995” 9,220’ 10,359’ 0.0039
TUBING DETAIL
4-1/2” Tubing 12.6 / L-80 / BTC 3.958” Surf 8,609’ 0.0152
SLOTTED LINER DETAIL
PLUGBACK INFO
APB1: 8864’ – 9955’
APB2: 8805’ – 9350’
APB3: 8790’ – 9098’
APB4: 9236’ – 9270’
GENERAL WELL INFO
API: 50-029-21374-01-00
Initial Completion by Nabors 27E - 6/28/1985
RWO Thunderbird Rig #1 – 6/10/2023
A Sidetrack Completed: 7/22/2023
Top
(MD)
Btm
(MD)
Top
(TVD)
Btm
(TVD)
9243’ 10352’ 7042’ 6989’
JEWELRY DETAIL
GLM DETAIL: CAMCO 4-1/2” x 1” KBG
12,404’GLM STA 6: Dummy Valve w/ BK Latch
23,963’GLM STA 5: Shear Valve w/ BEK Latch
35,484’GLM STA 4: Dummy Valve w/ BK Latch
46,588’GLM STA 3: Dummy Valve w/ BK Latch
57,567’GLM STA 2: Dummy Valve w/ BK Latch
68,337’GLM STA 1: Dummy Valve w/ BK Latch
7 8,403’ Sliding Sleeve (SSD) 3.813”
8 8,463’ Tri point Packer
9 8,522’ X Nipple w/ RHC – Min ID 3.813”
10 8,573’ WLEG: Bottom @ 8,609’
11 8,575’ 3.70” Deployment Sleeve
12 8,601’ X Nipple 2.813” Polish Bore
13 9,220’ 2.70” Deployment Sleeve
WELL INCLINATION DETAIL
A KOP @ 8,747’
90 Deg Angle @ 9085’ Max Angle = 98
TREE & WELLHEAD
Tree 4” Cameron Tree
Wellhead 11” 5M FMC w/ 3-1/2” H BPV Profile
OPEN HOLE / CEMENT DETAIL
17-1/2” 100 cf Permafrost
12-1/4”2200 sx Arctic Set III, 175 sx Class G, and 20 bbls Arctic
Set I (Top Job)
8-1/2” 275 sx Class G
4-1/4” 61 sx Class G
3-1/4” Uncemented Slotted Liner
TD =10,359’(MD) / TD =6,989’(TVD)
13-3/8”
Orig KB Elev.: 59.0’ / Orig GL Elev.: 23.1’
7”
4
7
9
1011
1
9-5/8”
2
Casing RA
marker @
8,618’
PBTD =10,359’(MD) / PBTD = 6,989’(TVD)
6Top of 3-1/2”
Liner 8575’
Top Cement
8880’
Whipstock set
@ 8742’
Top of
Window
@ 8747’
2-3/8”
5
3
8
3-1/2”xo3-
1/4” @ 8691’
See
Slotted
Liner
Detail
3-1/4”
Whipstock
set @ 9236’,
Liner bottom
@9270’
12
13 Estimated TOC ~8880' MD - mgr
Activity Date Ops Summary
5/7/2023 Complete rig move from PBU to MPB-15. Arrive on pad. Remove jeeps. PJSM, Begin moving main sub into place. RU Stomper for remaining moves over well.
Spot mud pits and set down. PJSM, RU Checklists. R/U cellar. R/U return line to tiger tank. PT to 4200 psi. LTT tree valves. N/U MPD line. N/U BOP's. Take on rig
water. Grease and service rig valves. Fluid pack coil with 5 bbls methanol and fresh water.
5/8/2023 Completed filling coil. Reverse circulated slack into reel. Cut 246' pipe, Cut 34' Pipe / E-Line (1.63% slack). Check e-line. Continuity good, Meg low. Trouble
shoot. Fixed issue. Make up coil connector. Pull test to 35K. Good. Make up BHI UQC w/o floats. Install test cap. PT IRV iron, Bulkhead, Coil, CTC, UQC to 7000#.
Good test. Bleed down. Begin initial BOPE test. Test witnessed by AOGCC representative Adam Earl. Test 1: IRV, Stripper, C7, C9, C10, C11 Pass. Test 2:
Blind/Shears, R2, B2, C15 Pass. Test 3: Annular (2-3/8"), TIW #1, B1, B4 Fail. Function annular and repeat tests. Fail. Test 4: Upper 2" Pipe/Slips, TIW #2, B2,
B3 Pass. Test 5: Lower 2" P/S, C5, C6, C8, TV2 Pass. Test 6: Choke A and C Pass. Test 7: C1, C4, TV1 Pass. Test B1, B4, TIW #1 Pass. Test 8 - Replace
leaking sequential valve on 2 3/8" rams. Pass. Draw Down Test on Accumulator. PJSM with Nabors crew and mechanic to replace annular element. Begin changing
annular element. Function test new annular element. Test Annular (2"), C2, C3 Pass. Test 2 3/8" Pipe/Slips Pass. Complete BOPE test. L/D test and R/D BOPE
test equipment. Measure and record RKB's. R/U PDL's and test to 250/3500. Pass. M/U Nozzle BHA. PT UQC and floats to 250/3500.
5/9/2023 Pump slack forward. Bullhead kill well. 5 bbls 60/40 Methanol. 160 bbls 1%SL KCL Rate: 3.25 bpm 300 psi. Pressure falling. Pump 25 bbls 10.5 ppb Polyswell in
Powerpro. 10 bbls Neet Mud. 10 bbls freshwater. Chase with 8.7 ppg Powerpro. Shut down 6 bbls early due to fluid falling. Allow polyswell to hydrate for 1hr. Come
online. Pump across top. ~30 bph loss rate. Push 12.5 bbls of polyswell into perfs. Let soak for another 15 minutes. Squeeze 6 bbls. Up to 250 psi. Started breaking
over. Let soak. Looks like its broke over. Mix and pump 25 bbls of 20 ppb Polyswell. 2.65 bpm in. Pressure increasing as soon as polyswell hit perfs. Let polyswell
soak. 1498 psi on well when 20 bbls pushed into perfs. Let set for 40 min Push 1 bbl, 800 psi. Breaking over. Let sit 20 min. Push another 1 bbl to 1000 psi. Let sit
20 min. Push 2 bbls. to 1000 psi. Let sit 20 min. Push 2 bbls to 1000 psi. Line up down coil. RIH with nozzle BHA #1 to clean out residual polyswell. In Rate = 1.03
bpm, Out Rate = 1.27 bpm. In Mud WT = 8.70 ppg, Out Mud WT = 8.74 ppg. IA = 544 psi, OA = 51 psi. WT CK at 8500' = 37k PUW. WT CK at 8770' (tubing tail)
= 37k. WT CK at 8893' = 36k. Increase rate and POOH for whipstock BHA. POOH for whipstock BHA. In Rate = 1 bpm, Out Rate = .42 bpm. In Mud WT = 8.70
ppg, Out Mud WT = 8.74 ppg. OOH - Flow check well and PJSM with Nabors crew. Fill hole and establish 8 bph loss rate. L/D nozzle BHA #1. M/U and RIH with
NS 350 - 700 High Expansion Wedge. In Rate = .33 bpm, Out Rate = .31 bpm. In Mud WT = 8.70 ppg, Out Mud WT = 8.74 ppg. Log GR Tie In from 8300' @ 5
fpm. No correction needed on first logging run. PUH to re-log upper character. Log from 8200' to catch additional GR character. Same correction. RIH to whipstock
set depth. WT CK = 37k @ 8800'. RIH to setting depth of 8869'. Close EDC and set whipstock. 2600 psi shear. 4.8k down weight. POOH for window milling BHA.
In Rate = .77 bpm, Out Rate = .27 bpm. In Mud WT = 8.69 ppg, Out Mud WT = 8.71 ppg. OOH - Flow check well and confirm no flow. L/D whipstock setting tool.
5/10/2023 M/U and RIH with window milling BHA. NSAK fixed bend motor 1 degree. String reamer 2.74" GO/2.73" NOGO. Window mill 2.75" GO/2.74" NOGO. In Rate = .37
bpm, Out Rate = .66 bpm. In Mud Weight = 8.68 ppg, Out Mud Weight = 8.68 ppg. Log tie in from 8220' @ 5 fpm. Correct -.5'. RIH and dry tag whipstock pinch
point at 8864.7'. PUH and bring pump up to milling rate. Mill 2.74" HS window from 8864'. In Rate = 1.80 bpm, Out Rate = 1.05 bpm. Free spin = 3260. In Mud
Weight = 8.68 ppg, Out Mud Weight = 8.72 ppg. IA = 615, OA = 53. Mill 2.74" HS window from 8864'. In Rate = 1.55 bpm, Out Rate = 1.17 bpm. Free spin = 3250.
WOB = 1.62k, ECD = 9.86 ppg, WHP = 0 psi. In Mud Weight = 8.71 ppg, Out Mud Weight = 8.72 ppg. IA = 623, OA = 58. Stall at 8866.56', PU and work down
slow to motor work then continue time milling. WOB dropped off at 8867', continue time milling for 1' then start milling 10' of rat hole. Loss rate at 25-30 bph. Milled
Rat Hole to 8878', start back reaming passes at 15 L&R of as milled. Catch samples from 8875' and 8878', 20% formation in samples. Completed 4 up ream passes
15 L&R of as milled and HS going down. Dry drift to TD is clean, PU dry to TOWS is clean. Open EDC and POOH for drilling BHA. Static Loss Rate = 18 bph. OOH
- Flow check well. PJSM with crew. L/D window milling BHA. Mill 2.74" GO. 2.73" NOGO, String Reamer 2.74" GO, 2.73" NOGO. M/U lateral BHA #4. RIH with
lateral BHA #4. In Rate = .36 bpm, Out Rate = .51 bpm. In Mud Weight = 8.71 ppg, Out Mud Weight = 8.72 ppg. Log tie in from 8220' @ 5 fpm. No correction
needed. Tag Camco D nipple at 8750'. Pick up clean. Change TF to LS and attempt again. Multiple attempts to get through nipple with no success. POOH to lower
motor bend and inspect BHA. L/D motor and lower bend from 1.4 degree to 1.2 degree. Roll wear pad 180 degrees on motor. RIH with BHA #5 - Build/Lateral. 1.2
degree bend w/Hycalog 3.25" bi-center bit. In Rate = .53 bpm, Out Rate = .60 bpm. In Mud Weight = 8.72 ppg, Out Mud Weight = 8.72 ppg. Tie In - No correction
needed. Tag D nipple at 8749'. Pull up and turn bit and attempt again. Change TF and repeat. Pump 5 bbls HiVis pill through open EDC. Multiple attempts to pass
D nipple. No success. POOH to change BHA/Bit. In Rate = .78 bpm, Out Rate = .45 bpm. In Mud Weight = 8.71 ppg, Out Mud Weight = 8.73 ppg.
5/11/2023 Continue POOH to swap out bits. OOH, flow check well, good no flow, PU injector, pull BHA and swap out Hycalog bit for Hughes bit with a smaller pass through.
Bit swapped out, RIH. Log tie in at 8200' with 0' correction, RIH to D-Nipple to see if we can pass through. Tag at 8749.7' with HS TF and 6k WOB. PU and orient to
180, tagged again, PU and try 90 L&R. Tagging at same depth at different orientation. Close EDC and roll the pumps to try and roll the wing of the bi-center. First
attempt failed, roll pumps again. Not able to pass through D-Nipple with 2.74 x 3.25", discuss options with DE. POOH to swap to 2.70 x 3.00" Bits. OOH, flow check
well. Good no flow, remove the injector and pull the BHA. Set up motor with a 1.26 deg bend for 2.70 x 3.0" Bi-Center Bit. Drift D-Nipple with current motor and 2.74
x 3.25" bit. The Bi-Center wing on the bit forces the bit box of the motor into the no-go of the D-Nipple profile keeping it from passing through. PU Motor and 2.70 x
3.00" Bi-Center and drifted through D-Nipple profile clean. MU injector to BHA. RIH with drilling BHA. Log tie in, no correction, RIH to drift D-Nipple. Pass through D-
Nipple clean, PUH to log CCL for Liner top placement. Close EDC and RIH through window clean. Tag TD on depth, retag to confirm, PU to up WT and bring
pumps on line to start drilling. Drill 3" lateral from 8956' to 9330' with BHA wiper trips every 150'. In Rate = 1.81 bpm, Out Rate = 1.75 bpm. In Mud WT = 8.73 ppg,
Out Mud WT = 8.77 ppg. Circ pressure = 4028 psi. ECD = 10.42. IA = 766, OA = 64. Long wiper trip from 9330'. Pump sweep and jog below window. Pull through
window clean. Jet/Clean 7" at max rate. Open EDC and pump max rate. PUH to logging depth. Log tie in from 8200' @ 5 fpm. Correct + 4.5'. Close EDC and RIH
clean. Log GR from 8800' bit depth. Drill 3" lateral from 9330' to 9552'. In Rate = 1.81 bpm, Out Rate = 1.81 bpm. In Mud WT = 8.77 ppg, Out Mud WT = 8.79 ppg.
Circ pressure = 3611 psi. ECD = 10.46. IA = 758, OA = 82. Drill 3" lateral from 9552'. In Rate = 1.84 bpm, Out Rate = 1.85 bpm. In Mud WT = 8.78 ppg, Out Mud
WT = 8.88 ppg. Circ pressure = 4032 psi. ECD = 10.46. IA = 799, OA = 84.
5/10/2023Spud Date:
Well Name:
Field:
County/State:
MP B-15A
Milne Point
Hilcorp Energy Company Composite Report
, Alaska
50-029-21374-01-00API #:
at 8864.7'.
WOB dropped off at 8867',
5/12/2023 Continue drilling lateral from 9570'. In Rate = 1.90 bpm, Out Rate = 1.87 bpm. In Mud WT = 8.79 ppg, Out Mud WT = 8.86 ppg. Circ pressure = 4063 psi. ECD =
10.59 ppg. IA = 794, OA = 86. Drilled 450' to 9780' pull wiper to the window. Jog in hole below WS then pull through window. Above the window, open the EDC
trapping 10.6 ECD and jet the WS tray. Tag at 8871', PU and tag at 8865' then at 8860'. PUH and log tie in at 8200'. Correct depth +6' and RIH. Stop above the
window and close the EDC holding 10.6 EDC. RIH and tag at 8867' 1.7k WOB. PU and RIH tag at same depth. PU and bring pumps on at 0.5 bpm just to roll the
bit a little and work down. Several attempts to pass through the bottom of the window have failed, POOH for a clean out BHA. Maintain 10.6 ECD at the window.
PUD BHA. Remove RES Tool and bit, bit grade = 1-1. PD Clean Out BHA with Window & String Mills and 1 deg bend Motor. Clean Out BHA deployed, RIH. Log tie
in, no correction, close EDC and RIH to to tag. Tag at 8864', PU and start pumps to clean out window pumping L&H Vis Pills. A little ratty through the window then
cleaned up. Clean to 8894', RA Marker is on depth, PUH slow to the TT. Continue circulating Hi/Low Vis pills out of well. RIH through window to end of build at
9150'. Minor bobbles less than 1k. Tag @ 9100' with 3k down. Drop rate to 1 bpm and run past to 9150'. Pump Hi/Lo sweeps from end of build. Open EDC above
window. Pump max rate and jet whipstock tray with Hi/Lo sweeps. Chase sweeps to tubing tail and circulate out of hole. Close EDC. Drift window and build clean to
9160'. Open EDC above window and jet whipstock tray. Pump final Hi/Lo vis sweep across whipstock and chase to tubing tail. POOH for lateral BHA. In Rate = 2.22
bpm, Out Rate = 2.02 bpm. In Mud WT = 8.78 ppg, Out Mud WT = 8.82 ppg. Circ pressure = 2916 psi. ECD = 10.66 ppg. IA = 794, OA = 97. OOH - Pressure
undeploy clean out BHA #8. Hold 10.6# ECD at window. Sequential valve on deployment rams leaking. Well is secured. Continue maintaining 10.6 # ECD through
MPD line. Continue L/D cleanout BHA. Repair/Replace sequential valve on deployment rams. Function test rams close on 2 3/8" test joint. Continue with pressure
deploy of lateral BHA. RIH with lateral BHA #9 - 1.1 degree motor bend and 3" HYC bi-center bit. In Rate = .55 bpm, Out Rate = .88 bpm. In Mud WT = 8.78 ppg,
Out Mud WT = 8.85 ppg. Circ pressure = 1506 psi. ECD = 10.67 ppg. IA = 1075 OA = 69.
5/13/2023 Continue RIH with Drilling BHA. Log tie in, no correction, close EDC and RIH to continue drilling lateral. Set down at 8869, PU, set down at 8880', PU clean, RIH
pretty ratty down to 8960' then cleaned up. Getting a little ratty at 9115'. 9165' packing off above the BHA, reduce rate, PUH Ann psi bled of. 9092' starting to pull
heavy and packing off then cleaned up. Keep PUH increasing rate, RIH and stacked WT and packing off PU. Pulling clean to 9047', RIH a little ratty to 9183', PUH
at rate to 8995'. RIH to 9047' and set down WT. POOH to the window to clean up the OH. Stop at 8905' keeping the bit below the window and the EDC just above
the TOWS. Open the EDC and reciprocate EDC in the 7" while circulating bottoms up pills to surface. Circulating up pills and getting sand back like were drilling 50-
60 fph. Bottoms up brought up an increase of silty sand and no chunky stuff. The wellbore should be clean with all the circulating that was done during the clean out
run so it looks like and unconsolidated sand that is sluffing off. RIH at min rate to see if we can drift bottom, passed through build without issue. 100' off bottom at
9680', bring pumps up to rate to continue drilling. Pumps at rate, packing off and stacking weight with no change to WOB, packing off around the coil. Reduce rate
and PUH, pulled 50k then fell off. 9245' RIH at rate, set down at 9441', PU then RIH at min rate. Tag at 9775', bring pumps up to rate and we are packing off.
Wellbore is unloading a lot of sand, PUH slow until it cleans up. Discussed current well condition with the DE. Start control drilling limiting ROP monitoring Ann Psi
for packing off. Continue drilling lateral from 9570'. In Rate = 1.90 bpm, Out Rate = 1.88 bpm. In Mud WT = 8.79 ppg, Out Mud WT = 8.82 ppg. Circ pressure =
3725, ECD = 10.65 ppg. ANN Psi = 3940 psi. Lost the RES Tool, attempts to get it to restart failed, calls to the Town Team, continue to drill to TD and swap out the
RES Tool on the wiper trip to the swab then Mad Pass log the interval on the drift to TD. 8950' ROP increase and it looks like we are in the C-Sand, start dropping
angle down to 92 deg. Well Control Drill - KWD Drill. Increase ROP to 70 fph, Ann Psi stable. Drilled to 9955' pull wiper to window to see how the B-Silts are. Pull to
bottom of Rat Hole then jog in hole 100'. PU to 8905' and open the EDC 10' above the WS. Jet WS Tray and POOH to the TT with the EDC. 8832' Ann Psi
climbing, CTC at the TT, RIH and circ a bottoms up. Got back a lot of chunky shale. Continue jetting 7" at 2 bpm. Returns cleaning up. Pull into tubing tail and
POOH above tie in depth. Tie in from 8200' @ 5 fpm. Correct +11'. RIH through window and tag at 8952' pumping .6 bpm. Increase rate to 1 bpm and RIH to 8970
and tag. PUH. Continue working in hole with rates between .2 and 1 bpm. RIH at 1.8 bpm pumping sweeps. Tag again at 9076'. Pump 30 bbl, 3 ppb nut plug
sweep and cont RIH. Attempt to pass 9106' area. Suspect fault at 9085'. Pump 50 bbls new mud and attempt to run past at different pump rates. Run past fault
while pumping new mud. Unable to pass ~ 9812'. Appears we are packing off with ECD's as high as 11.47 ppg and 75% losses at times. POOH to clean window
and regain returns. Overpulls noted through fault area (9106'). Jog in hole at max rate below window twice. Pump Hi/Lo vis sweep from bottom of window. Pull EDC
ports above window. Open EDC. Jet whipstock tray and window at max rate. Jet whipstock tray 3 times and POOH to clean 7". In Rate = 2.47 bpm, Out Rate = 2.42
bpm. In Mud wt = 8.74 ppg, Out Mud wt = 8.77 ppg. Continue jetting 7" with Hi/Lo vis sweeps. Packing off and higher ECD's near tubing tail. RBIH and continue
jetting 7" at 2.46 bpm. Pump multiple bottoms up. Well unloading at surface. Discuss plan forward with Drilling Engineer. Clean out 7" for whipstock.
5/14/2023 After discussions with the DE and Town Geo about the instability of this wellbore, we are going to set another WS and re-drill this well. Made calls to NSAK to prep
another 3-1/2 x 7" WS while we clean out the 7" for another set. Pump Low & High Vis Pills and verify wellbore is clean before POOH. Last bottoms up pill is clean,
POOH max rate at 80 fpm slowing down at GLM's to ensure Wellbore is clean. OOH, flow check well and LD the drilling BHA. Good no flow, PU Injector and LD the
BHA. MU NSAK Whipstock, verified HS scribe and drifted the BHA with 2.73" Drift ring. BHA MU, EDC is open and pump trips set to 500psi, RIH. Stop RIH, lost
COMMS to the tools, POOH and test UQC connection. OOH remove injector and test the UQC. Eline is good, test the P&C and most likely swap out. Tools
swapped out, RIH. Log tie in, no correction. RIH to set depth with TOWS at 8800'. Close EDC, tool sheared at 3100psi, set down 4.5k WOB with no movement. WS
set POOH. OOH - Flow check well and confirm no flow. 2.4 bph loss rate. PJSM with Nabors crew. L/D whipstock setting BHA. M/U and RIH with window milling
BHA. RIH with window milling BHA #12. 1.1 degree motor and 2.74" mill and string reamer. In Rate = .49 bpm, Out Rate = .51 bpm. In Mud WT = 8.75 ppg, Out
Mud WT = 8.78 ppg. Log tie in from 8200' @ 5 fpm. No correction needed. RIH to begin window milling. Dry tag @ 8806'. PUH and begin milling window. Mill 2.74"
window from 8805'. In Rate = 1.81 bpm, Out Rate = 1.78 bpm. In Mud WT = 8.75 ppg, Out Mud WT = 8.78 ppg. Circ pressure = 3707 psi. IA = 736, OA = 84.
Continue milling 2.74" window from 8806.7'. In Rate = 1.82 bpm, Out Rate = 1.80 bpm. In Mud WT = 8.75 ppg, Out Mud WT = 8.77 ppg. Circ pressure = 3721 psi.
IA = 742, OA = 93. Continue milling 2.74" window from 8808.7. In Rate = 1.83 bpm, Out Rate = 1.78 bpm. In Mud WT = 8.75 ppg, Out Mud WT = 8.77 ppg. Circ
pressure = 3786 psi. IA = 732, OA = 94. Mill exits at 8909'. Bottom of window. Continue milling at 1 fph to ream bottom of window. Mill rat hole to 8819'. Begin back
reaming window. Backream HS, 15 deg LOHS and 15 deg ROHS.
RIH to set depth with TOWS at 8800'.
After discussions with the DE and Town Geo about the instability of this wellbore, we are going to set another WS and re-drill this well
5/15/2023 Continued with window milling Ops - Window milled from 8805' to 8809' plus 10+ of rat hole to 8819. Start reaming passes 15 deg L&R of HS. Bottoms up sample
100% formation. Shut down pump and dry drift. Tag at 8809 bottom of window, PU and bring pumps back online and continue ream passes. Stacking weight with
little to no motor work. Still stacking WT, PU to just below the TT to see if we have some debris holding us up. RIH and passed through the window, repeat ream
passes then attempt to dry drift again. Still stalling at the bottom of the window at 8808.9', PU then come back down to 8808.5 and time mill down. Getting WOB and
motor work at the bottom of the window continue time milling until clean. Time milled 1' passed the bottom of the window with the string mill. Start back ream passes
and then dry drift in both directions. Drift is clean, open EDC and POOH. OOH, flow check well, good no flow, LD the milling BHA. Window and string mills gauge
2.73 go, 2.72 no go. MU the build BHA with 2.0 deg motor. RIH with build BHA. Log tie in with 0' correction. Pass through D-Nipple and window without issue to TD.
PU to up WT and bring pumps online. In Rate = 1.86 bpm, Out Rate = 1.78 bpm. In Mud WT = 8.69 ppg, Out Mud WT = 8.72 ppg. Circ pressure = 3260 psi. IAP =
613, OAP = 89, ECD = 10.14. Build section completed, POOH for lateral BHA. In Rate = 2.53 bpm, Out Rate = 2.15 bpm. In Mud WT = 8.70 ppg, Out Mud WT =
8.73 ppg. Circ pressure = 3941 psi. IAP = 790, OAP = 102, ECD = 10.15. OOH - PUD build BHA. Bit graded 1:1 with a plugged nozzle. Function test BOP's. Re-
tighten inner reel iron and pressure bulkhead. Pressure test coil and inner reel iron to 7000 psi. Replace leaking sequential valve on lower most 2" pipe/slip rams.
PD lateral BHA with 1.1 deg motor and HCC 2.70" x 3" bi-center bit. RIH with BHA #14. In Rate = .51 bpm, Out Rate = .76 bpm. In Mud WT = 8.70 ppg, Out Mud
WT = 8.76 ppg. Circ pressure = 1481 psi. IAP = 984, OAP = 79, ECD = 10.4. Log Tie In from 8200'. Correct .5'. Close EDC and RIH through window clean. Log RA
tag in whipstock and confirm WS/window depths. Drill 3" Lateral from 8900' to 9054' and BHA wiper. Pump lo/hi vis sweep. In Rate = 1.80 bpm, Out Rate = 1.84
bpm. In Mud WT = 8.71 ppg, Out Mud WT = 8.73 ppg. Circ pressure = 3136 psi. IAP = 712, OAP = 82, ECD = 10.18. Drill 3" Lateral from 9054' to 9084'. In Rate =
1.80 bpm, Out Rate = 1.84 bpm. In Mud WT = 8.71 ppg, Out Mud WT = 8.73 ppg. Circ pressure = 3136 psi. IAP = 712, OAP = 82, ECD = 10.18.
5/16/2023 Continue drilling ahead at 9065' in B8 Shale looking for the B7 sand. In Rate = 1.84 bpm, Out Rate = 1.84 bpm. In Mud WT = 8.71 ppg, Out Mud WT = 8.79 ppg.
Circ pressure = 3567 psi. IAP = 749, OAP = 104, ECD = 10.36. Drilled 450' to 9350', pull wiper to the window. Jog below the window, PU to 8850, open EDC.
Wash across the WS then up into the TT. Tie into RA Marker. We have made 2 passes to log the RA and we are not seeing it. We did see on the way up but are not
seeing it now. Continue logging down to see if we tag at the lower WS at 8860'. Tagged at 8859', near bit surveys show we are in the parent wellbore and WS may
have released. PUH to 8200' and log gamma tie in to verify we are on depth. Correct depth +4', shut down and reboot BHI Tools then RIH to relog. Relog and
tagged at 8858', near bit inclination confirms we are still in the parent wellbore, WS fell on top of the one at 8860'. POOH for READ Caliper Logging Tools. OOH,
flow check well. Good Not Flow, PU injector and LD drilling BHA. READ Mem Logger on location. Drilling BHA LD. READ Programming Tools for caliper run. MU
Caliper Logging tools. RIH with Caliper Logging Tools. Inner reel iron leaking at the 3" 1502, first connection to the coil. Hammer union was loose, but we have no
means of being able to isolate that union to test it. POOH to surface from 1500'. OOH - PJSM with Nabors crew and READ logging specialist. Flow check well and
confirm no flow. ~ 1 bph loss rate. L/D READ caliper BHA and secure well. Rig down inner reel iron and replace failed ring gasket. M/U eline pressure bulkhead.
Test inner reel iron to 7000 psi. Good. Test eline and pressure bulkhead. Good. Program READ caliper logging tools. M/U caliper logging BHA. RIH READ caliper
logging BHA. Continue RIH with logging BHA. Stop NPT at 1500'. In Rate = .52 bpm, Out Rate = .79 bpm. In Mud WT = 8.75 ppg, Out Mud WT = 8.78 ppg. IA =
647 psi, OA = 72 psi. Log Tie In from 8170' @ 5 fpm. No correction needed. RIH to logging depth of 8,855'. Wait until 02:21 for caliper arms to open and then log
up. Log 24 arm extended reach caliper from 8855' to 8600' @ 50 fpm. Pause at 8596' until arms closed. RIH to 8855' Wait until 02:53 for arms to open. Log 24 arm
extended reach caliper from 8855' to 8600' @ 50 fpm. Wait for arms to close. POOH. POOH with READ caliper logging BHA. In Rate = .99 bpm, Out Rate = .70
bpm. In Mud WT = 8.75 ppg, Out Mud WT = 8.77 ppg. IA = 620 psi, OA = 80 psi. OOH - flow check well and confirm no flow. L/D READ caliper BHA. Download
tools to confirm good data.
5/17/2023 Pull data from Caliper Tool and confirmed good data. LD BHI MWD and prep for testing BOP's. Remove BHI Floats and service tree valves. Displace mud from coil
with freshwater while flushing stack. Close Swab and PT to test BOP's. Good PT, grease stack and choke valves to prep for testing. Test BOPE, Test witness
waived by AOGCC Guy Cook. Test 1: IRV, Stripper, C7, C9, C10, C11 - Pass. Test 2: Blind/Shears, R2, B2, C15 - B/S Fail/Function/Fail. Re-Test 2: R2, B2, C15 -
Pass W/O Blind/Shears. Test 3: Annular (2-3/8"), TIW #1, B1, B4 - Pass. Test 4: Upper 2" Pipe/Slips, TIW #2, B2, B3 - Pass. Test 5: Lower 2" P/S, C5, C6, C8,
TV2 - Pass. Tested Gas Alarms. Test 6: Choke A and C - Pass. Test 7: C1, C4, TV1 - F/P on TV1 - Pass. Test 8: 2-3/8" Pipe Slips, C2, C3 - Pass. Test 9: Blind
Shears - Fail. LO/TO on Koomey. Change out Blind/Shear rams. Test Blind/Shear rams, good. Rig down BOP test equipment. Put drilling risers back in place.
Pressure test both PDLs, good. Install floats and M/U nozzle for PT. Change packoffs. PT floats, packoffs together, good. Swap CT back to mud. M/U BHA #17 -
NSAK HEW Whipstock. RIH with whipstock. Set pressure and slackoff trips close. Tie-in depth from 8180'. Correct +1.5', RIH to set depth. WTCK = 42k, RIH to
8794.75' (TOWS @ 8786'). PU to 38k and set WS 10 deg ROHS. WS set at 3300psi, set down 6k WOB, no movement, POOH.
5/18/2023 POOH at 5600' from setting WS (TOWS at 8786', Pinch Point at 8790', BTM at 8794.75'). OOH, flow check well, good no flow, PU the injector and LD the WS
Setting BHA. Setting tool looks good. Remove BHI UQC and boot wire. PU 1 jut of 2-1/16" CSH and deploy across stack to pump eline slack out. PU injector and
cut off pumped out slack. Pumped out 211 of 248'. MU CMT Stinger and 2.5" Nozzle. RIH with CMT BHA. Tag pinch point on depth at 8790'. PU and displace well
to 1% KCl. Perform injectivity test. 1100psi at 1 bpm, discuss plan forward with DE. HES on location RU. Hold PJSM to mix and pump 10 bbls of CMT. Fluid Pack
CMT line to PT to 4500psi. 16:17 CMT Wet, 6:11 thickening time, ends at 22:28. 16:35 online with CMT Pump. Zero In MM at 13.5 ppg and load 10 bbls of CMT in
reel. 10 bbls in reel shut down CMT Pump and flush CMT line. Online with rig pump to displace CMT at 2.0 bpm at 4000 psi. 36 bbls away close choke and
squeeze CMT past WS. 40 bbls away injecting at 925 psi shut down at 6 bbls below WS. Online, squeeze 2 bbls then lay in last 2 bbls above WS then pull up to
safety. WCTOC at 8550' stop at 8250'. Online with pump to circ contam pill down maintaining 900psi WHP with 1:1 returns. Cleanout to 8650' then 8750' take 100'
bites. Reduce WHP to 600 psi to keep 1:1 returns as cement is circ out. Light tag on whipstock pinch point 8789', pick up and repeat. POOH pump 2.1 bpm keep
600 psi WHP on trip out. Near surface bleed off slowly. 10 min no-flow at surface is good. Lift injector up, check cable about 4" hanging out. Remove nozzle, install
side jet nozzle for jetting stack. Reverse slack into reel. Rig up hydraulic CT cutter, cut 220'. Install CT connector. Pull test to 50k, good. Install stinger, get on well.
Pump reel volume forward 3.3 bpm cable is moving. PT riser break, good. Install BHI cable head with floats. Test CT connector and floats, good. M/U BHA #19
window mill and reamer. Mill is 2.74" Go 2.73" NoGo. Reamer is 2.73 Go 2.72" NoGo. RIH BHA #19.
5/19/2023 Continue RIH with window milling BHA. Log tie in, correct depth 0', RIH, WTCK at 8750' = 43k. Tag pinch point on depth at 8790',. Online with pumps to start
milling window pumping pills every 1'. Tag pinch point at 8789.6'. In Rate = 1.80 bpm, Out Rate = 1.79 bpm. In Mud WT = 8.44 ppg, Out Mud WT = 8.44 ppg. Circ
pressure = 2958 psi. ECD = 9.31 ppg. IAP = 491, OAP = 66. Milling Window at 8791.0'. In Rate = 1.85 bpm, Out Rate = 1.85 bpm. In Mud WT = 8.44 ppg, Out
Mud WT = 8.44 ppg. Circ pressure = 3508 psi. ECD = 9.37 ppg. IAP = 533, OAP = 78. Stall at 8792.6', PU to up WT and work back down to continue milling.
Looks like we exited the bottom at 8792.6' for a 3' window. Continue milling at 1 fph to dress the bottom of the window off with the string mill. Swap over to drilling
mud while milling 10' of Rat Hole. Milled 10' of Rat Hole to 8803. Start back ream passes. 8795' sample has 35% C-Sand Formation. 8800' Sample is 100% C-
Sand Formation. Back ream passes completed, PU 10' and dry drift window. Dry drift is clean, open EDC and POOH for the build BHA. At surface 10 min no-flow is
good. Skid injector back, L/D BHA #19. Mill is 2.74" Go / 2.73" NoGo same as when it went in. Reamer is 2.73" Go / 2/72" NoGo. M/U nozzle, jet stack. M/U BHA
#20 - Build BHA. RIH BHA #20. Tie-in depth from 8180', no correction. Up wt 39k at 8680'. Close EDC. Ease through window go to min rate. Tag rathole 8799' pick
up 2' go to drill rate. In Rate = 1.86 bpm, Out Rate = 1.84 bpm. In Mud WT = 8.72 ppg, Out Mud WT = 8.74 ppg. Circ pressure = 3350 psi. ECD = 10.22 start
adding WHP. Drill from 8850'. In Rate = 1.84 bpm, Out Rate = 1.78 bpm. In Mud WT = 8.71 ppg, Out Mud WT = 8.76 ppg. Circ pressure = 3830 psi. ECD = 11.15
ppg w/ 320 psi WHP. 8860' 5 bbls lo/hi vis sweep. Drill to EOB at 8875'. Wiper to window. Jog below window and pull through clean. Open EDC, jet tray. POOH
pump 2 bpm keep 11.6# ECD at window. At surface, PUD BHA #20. Deploy BHA #21 - Lateral BHA w/ 1.1 deg AKO.
TOWS at 8786', Pinch Point at 8790',
5/20/2023 Continue RIH with BHA #21 at 2900'. Log tie in with no correction. Close EDC and RIH to continue drilling. PU WT = 41k, RIH WTR = 18k. Back on bottom drilling
at 8875'. In Rate = 1.85 bpm, Out Rate = 1.84 bpm. In Mud WT = 8.71 ppg, Out Mud WT = 8.76 ppg. Circ pressure = 4007 psi. ECD = 11.8 at 466 psi WHP. 8940'
slow ROP in shale. Drilling ahead at 8965'. In Rate = 1.84 bpm, Out Rate = 1.84 bpm. In Mud WT = 8.72 ppg, Out Mud WT = 8.77 ppg. Circ pressure = 4154 psi.
ECD = 11.8 at 474 psi WHP. 9025' well taking a little fluid. 9030' increase in losses 0.3 bpm ~18 bph. 9040' increase in losses 0.4 bpm ~24 bph. 9043' increase in
losses 0.5 bpm ~30 bph. Continue holding 11.7 - 11.8 ECD. Still drilling in shale, Geo's think we drilled from the B6 into the B8 and missed the C-Sand, verifying
bottom of B7 and what we will need to land. RIH to continue drilling, B7 top should be at ~6975' TVD and the base at 7002', we will need ~13' to land once we see
the top of the B7 landing at ~6988'. Starting to pack off, PU and pull wiper trip to the window. BOW, jog in hole then PU to 8835' placing the EDC at 8780', stop and
open the EDC. Jet across WS tray and then pull through the window into the TT circulating a bottoms up. Circ 2x B/U until returns clean. Tie-in to HRZ at 8190'.
Add 0.5% Hydra-hib to mud. Close EDC, RIH to window. Field wide power outage, rig loses power. Depth is 8793.3' right in window. Shut in well. Get gens running,
pick up cleanly out of window. Get pumps running bring ECD back up to 11.8#. ECD fell to 10.2# while power was off. Reboot BHI computers, depth is running
backwards. Get all systems working, pick up to tie-in depth. Tie-in from 8190' correct +1'. Close EDC, pass window go to min rate. Tag 8803' pick up and work past
at 0.8 bpm. Continue work in hole, build section ratty. At 8900' pull wiper back to window, pull 10k over at 8895' RIH and stack wt. Work pipe and pump to get free,
continue wiper to 8820'. Clean back to 8925' at 0.6 bpm. Work down to TD take 50' bites. Wiper from 9050' at 1.4 bpm packing off reduce rate. Unable to circulate
at full rate. Pull wiper to window, open EDC. Unable to jet tray stacking wt 8804'. Pump B/U to clean tubing. Considerable cuttings coming back confirmed B8 shale.
Tubing clean, close EDC RIH. Clean through window go to 0.5 bpm try to pass B8 shale 8830' - 8880'. Stack wt in shale work past. At 8920' in clean sand pull short
wiper go to 1.8 bpm, packing off right away. Unable to circulate at drilling rate when past B8 shale. Pull wiper trip back to 8820' will take 20' bites to clean out. Pick
up from 8870' motor stall pulling heavy at 8841'. Pull through window CBU pump 5 bbls lo/hi vis sweeps. RIH close EDC to continue cleaning B8 shale. Unable to
pass window try different orientations 20L to 40R and different running speeds. POOH for window cleanout BHA. Undeploy BHA #20. Deply BHA #21 - Window
Cleanout.
5/21/2023 PD clean out BHA and RIH. Log tie in with no correction. RIH to TOWS and close the EDC. PU WT = 40k. RIH and dry tag at 8797', PU to up WT and start pump.
Work down cleaning out build section at 5 fpm or 300 fph. Ann PSI = 4193 psi at 11.75 ECD. In rate = 1.85 bpm. Took a little WOB at 8820' then milled off. Taking
WT at 8843'. Stacking WT at 8843 and losing more returns, PUH 20' then RIH. Stacking WT at 8841' and losing returns again. PU and pump a set of pills to
circulate a bottoms up to see what we are milling. PU to the TT to clean out the hole behind us while pumping BTM's up. RIH with mills below the TT in the 7".
Bottoms up had fine cuttings of B8 shale. Shut down and RIH to tag and continue clean out. Tag at 8808' PU and start working down again. In Rate = 1.81 bpm,
Out Rate = 1.69 bpm. Set down at 8848' losing returns, PU clean and getting returns back. RIH to dry tag and ran past to 8935' clean. We are able to drift through
the shale but if we try to pump going down to clean it out it packs off at the mill, stacks WT and lose returns. PUH and work down at slower speed and stacked out at
8831'. PUH above shale shut down pump and see how far we can drift. Getting a little ratty at 9058', PUH to just below the bottom of the shale and try to back ream
through. Online with pumps, verify good returns before back reaming and started packing off. Shut down pumps and PU pulling 10-15k over then pulled free and
getting returns back. Online with pumps PU to the 7" to circ a bottoms up while talking to DE. RIH to continue clean out, tag at 8838' and stop to allow it to drill off,
nothing happening like the mill is balled up just pushing fluid away. Not making any headway with this mill & string mill, it's like the shale has swelled and we are
milling a 2.74" gauge hole through the shale. POOH for D331comimng from Kuparuk. Well unloaded some B8 shale 2000' from surface. OOH prep to PUD the
FCO BHA. MU & PD the FCO BHA w/D331 Mill on 1 BHI Extreme Motor. RIH BHA #23. Tie-in depth from 8180' no correction. Close EDC. Try RIH through window
1 bpm. Stall several times at 8794' at different rates and RIH speeds. D331 is slightly larger than the NSAK mill, will need to ream out window. P/U to 8788' ream
down < 1 ft/min 1.8/1.56 bpm 10R. Ream window from 8793.3' stall 8793.55'. Mill to 8795' PU for backream 10R clean. RIH continue cleanout. Stack 8810', 8817'.
Near bit inc not increasing, appear to be inside 7" casing. Stall at 8830'. Pick up to 8760' reboot BHI tool. Log RA, still there. Survey package at 8802' indicates we
are in 7". B/U sample from washing down 8805' - 8830' is 90% soft cement. Discuss w/ ODE. Tie-in depth correct +3. RIH will try different TF to find the window.
Try 20R RIH tag 8830' NBI indicates in 7". Try 60R, 90R, 120R, 150R, 180R, 150L RIH clean to 8830' each time in the 7". RIH 120L, 90L, 60L, 30L tag 8796' and
stall. RIH 0L clean to 8830' NBI indicates we are in the 7". POOH keep 11.8# ECD at window. Pressure undeploy BHA #23. Prep for next BHA run.
5/22/2023 BHA OOH, discuss options with DE and wait for asset team decision to either make a camera run or RDMO to next well. Decision made to RDMO to MPL-13, LD
BHA and prep to make a nozzle run. RIH with nozzle BHA and BHI Floats to recover drilling mud, displace the well to source water with a diesel FP. Slowly bleed
WHP to 0 psi while RIH. Call out Halliburton N2 to blow down reel. RIH clean to 8805', PUH to 8760' clean, RIH to 8805'. Online with source water, pump at max
rate reciprocating from 8805 to the TT with mud in the coil to clean out the 7". Source water at the nozzle, recip from 8805' to the TT 50 bbls to wash any mud off the
7" for possible Eline Camera run then POOH. Freeze protect tubing from 2675'. LRS RU & PT'd, online with 30 bbls of diesel. 30 bbls pumped into coil, RD LRS
and MIRU HES N2 Unit. Diesel at surface, POOH at pipe displacement. OOH, waiting on vac trucks to remove fluid from the pits so we can pump fresh water and
inhibited water to blow down. Good PT, well is secured. Prep to pump Freshwater, Inhibited water and methanol into the coil to blow down. Pump 30 bbls fresh
water, 30 bbls inhibitor, 5 bbls MeOH into reel. Purge reel w/ 1500 scfm 15 min until gas at nozzle. Bleed off to tiger tank. Grease rig valves while bleeding off. Skid
injector back, remove nozzle and BHI cable head. Install grapple. Remove inner reel 1502 line. Pull CT out of injector and back to shipping spool, secure it there.
Hook up reel slings, boot e-line on both ends. Finish vac all fluid out of pits. Start converting injector to 2-3/8" CT. Move 2-3/8" gripper blocks to rig floor, change out
blocks on injector. Remove stripper assembly change out stripper brass.
6/21/2023 Spot drill module over MPB-15A. Spot pit module. Accept rig 07:00. Complete MIRU checklists. Nipple up MPD line / BOPE's. Test Gas alarms. Fluid pack rig,
Calibrate MM's. Initial BOPE test Witnessed waived by Kam St. John. 7-1/16" 5K Annular, Blind / Shear, 2-3/8" Pipe / Slip, Mud X, 3" Pipe / Slip, 2-3/8" Pipe / Slip.
Test 1: IRV, Stripper, C7, C9, C10, C11 Pass. Test 2: Blind / Shear, R2, BL2, C15 Pass. Test 3: Annular (2-3/8"), TIW1, B1, B4 F/P on B1. Test 4: Upper 2-3/8"
Pipe/Slips. TIW2, B2, B3 Pass. Test 5: Lower 2-3/8" Pipe/Slips, C5, C6, C8, TV2 Pass. Test 6: Choke A, Choke C Pass. Test 7: C1, C4, TV1 Pass. Test 8: 3"
Pipe/Slip, C2, C3 Pass. Drawdown test - Good. Rig down and purge test equipment. Test both MP line break and PDLs 250 / 3500 psi, good. Cart forward and
install floats in UQC. Test floats and UQC break to 250 / 3500 psi, good. Load PDL w/ BHA #25. Mill and reamer are 3.80" Go 3.79" NoGo. PT tiger tank line 4250
psi, good. M/U nozzle get on well, pump 8 bbls MeOH forward. Open well, 90 psi then dissipates. M/U BHA #25 - Window mill.
6/22/2023 RIH with window milling BHA #25. Rate: 0.54 bpm in, 1.04 bpm out. Circ pressure: 80 psi. Mud Weight: 8.36 ppg in, 7.08 ppg out. Taking returns to tiger tank. Log
down for tie-in from 8185' to 8261.38' MD (formation) with -2' correction. Perform CCL log 8300' to 8700'. Swap well over to Powerpro with Black product. Dry tag
whipstock at 8769' MD. Depth discrepancy. Pinch point should be at 8764'. Log 7" casing RA. No sign of it. Verify collars. Collars on depth with original whipstock
setting log. Bring pumps online. Went right by 8769'. Run to 8774' without tag. PU and dry tag. Tag at 8770' Top of whipstock. Come back online and start taking
weight at 8775.4' (Pinch Point). Whipstock had fallen downhole. Pick up to log primary tie in. +3' correction. Rih and tag at 8778' MD (Pinch point). Puts TOWS at
8773' MD, BOWS at 8791' MD. Inside third window. Open EDC. Pooh for 40 arm extended reach caliper. Pooh with BHA #25. Rate: 2.10 bpm in, 1.72 bpm out.
Circ pressure: 1715 psi. Mud Weight: 9.08 ppg in, 9.07 ppg out. Tag up Perform flow check. Static. Stand back BHA#25, Remove motor and mills. Program READ
40 Arm Caliper. Make up READ tools. Surface tested good. Stab injector. RIH with Caliper BHA #26. Rate: 0.54 bpm in, 1.04 bpm out. Circ pressure: 80 psi. Mud
Weight: 9.08 ppg in, 9.06 ppg out. . Log down for tie-in from 8185' to 8248' MD (formation) with -2' correction. Up wt 8670' is 46k. Park at 8770' wait for arms to
open (18:39). Well on slight losses. Log up at 50 ft/min. Park at 8325' 1 min before closure time, let arms retract. POOH. Flow check at surface is good. Skid inj
back, pull BHA #26 - Mem Caliper. Download and confirm good data. M/U BHA #27 - Whipstock. RIH w/ BHA #27 - Whipstock. Set slackoff and pump trips close.
Tie-in depth -2.5' correction. While RIH caliper data is finished, review w/ BTT and rig Geo. Decision is made to set anchors 8760', as deep as caliper data goes.
Puts pinch point at 8747'. Confirm w/ Geo still in zone at 8747'. RIH to 8760' 160L get up wt back. Close EDC, shear out setting tool at 3890 psi. RIH carefully to
confirm set. Take wt at 8764.1' set 5.5k on it for 1 min, solid. Flag pipe 8738.76' bit depth, (8653.81' EOP). Injectivity test, 0 injectivity with mud at 11.83# ECD (940
psi WHP). POOH. Good 10 min no-flow at surface. L/D BHA #27 - Whipstock setting. Tools have functioned normally. Remove floats from UQC. M/U nozzle BHA.
6/23/2023 Rih with BHA# 28 Cementing nozzle. Stop at flag 8670.07' - 8664.36' = -5.71' correction. Dry tag whipstock @ 8747' w/ 3K down. On depth. Circulate wellbore over
to 1% SL KCL. Reciprocate from 8744' to tubing tail. Injectivity test (Close Choke). Incrementally increase surface pressure to 1520 psi ( 12.57 ppg EMW) Broke
over. Injectivity of 0.4 bpm @ 1412 psi. Push 3 bbls of 1% SL KCL past whipstock. Come off line pressure dropped to 1160 psi then slowly continued to fall off. . Dry
tag whipstock on depth. PJSM with HES cementers. PT to 5000 psi Good. Cement Wet:10:59. 70 bc @ 17:22. Cement. Pump 5 bbls freshwater. Pump 7 bbl 15.3
ppg cement. Pump 5 bbls freshwater. Parked at 8744' MD. Cement at nozzle. Close choke. Pressure slowly climbed to 410 psi. Pressure bumped at 1.3 bbls out.
Work pressure up to 1600 psi. Held. Squeeze 1.3 bbls cement by whipstock. Crack choke. Circulate 1 bbl of cement around nozzle. Begin laying cement in 1:1.
Fresh water at nozzle at 8610' MD. PUH to Safety. Circulate 1.5 ppb Geovis down to nozzle. Cement in place 12:00. RIH and contaminate 1.5:1 from 8610' to 8742'
(2' below TOWS). Make pass up and down from TTL to TOWS. Circulate contaminated cement ooh. Pooh for window milling BHA. Rate: 2.93 bpm in, 2.48 bpm
out. Circ pressure: 1440 psi. Mud Weight: 8.41 ppg in, 8.34 ppg out. Tag up. Perform 10 min flow check. Well Static. Remove nozzle and stinger. Pull UQC apart.
No signs of any cement in voids. Install floats. Test e-line. Good test. Make up swizzle stick. Stab injector. Jet stack. Tested floats to 3500 psi. Good test. Jet Stack.
Wait on cement. Clean and service rig. M/U BHA #29 - Window mill. Mill and reamer 3.80" Go 3.79" NoGo. RIH BHA #29. Tie-in depth from 8175' correct -2'. Close
EDC 8619'. Up wt 8640' is 46k. RIH min rate tag 8748.8' PU bring pumps up to 2.5 bpm. Ease down see first motor work 8748.1'. Start time milling 8749.5' start
increasing ECD. Swap to mud. Mill to 8751.03' mud all the way around PU get new parameters. Mill window from 8751.03'. 2.52 / 2.54 bpm In/Out. 9.05 / 9.04 ppg.
Window ECD = 11.83 ppg w/ 630 psi WHP. Pcirc 3100 - 3390 psi.
6/24/2023 Mill 3.80 window to 8755.4'. Rate: 2.54 bpm in, 2.56 bpm out. Mud Weight: 9.03 ppg in, 9.02 ppg out. DWOB: 3.5 klbs. Circ pressure: 3567psi. Maintaining 11.8
ppg ECD at window. 571 psi WH. Mill exiting. WOB fell off to nothing. Appears we exited 2.2' early. Continue to time mill to expected full exit of 8757.8'. WOB and
motor work minimal. Mill rathole from 8758' to 8768'. Rate: 2.53 bpm in, 2.56 bpm out. Mud Weight: 9.02 ppg in, 9.03 ppg out. DWOB: 2.8 - 3.0 klbs. Circ pressure:
3341 psi. Maintaining 11.8 ppg ECD at window. 568 psi WH ROP 5.5 fph. Perform reaming passes. Motor work at 8752' during 1st 2 passes. 3rd pass down
minimal motor work. 3rd pass up clean. Dry drift. Good. Pooh. Rate: 2.96 bpm in, 2.34 bpm out. Mud Weight: 9.02 ppg in, 9.00 ppg out. Window ECD: 11.8 ppg.
Tag up, space out. Undeploy BHA #29 keep 11.8# ECD at window. Mill and reamer 3.80" Go 3.79" NoGo. M/U nozzle, jet stack. Open choke clear metal debris
from blowdown. Deploy BHA #30 - Build BHA. RIH BHA #30. Tie-in depth from 8185' correct -2'. RIH close EDC above window. Sliding sleeve opens when running
past, took 0.15k DWOB. Pass windows no issues. Go to min rate, light tag 8767' get up wt + 2' go to 2.8 bpm. Drill from 8768'. 2.80 / 2.80 bpm In/Out 9.03 / 9.05
ppg. Pcirc 3500 - 3750 psi. Window ECD 11.76 ppg w/ 540 psi WHP. 8782' 5 bbls lo/hi vis.
6/25/2023 Drill 4.25 build from 8853' MD. Free spin: 3792 psi, 2.82 bpm. Rate: 2.82 bpm in, 2.79 bpm out. Circ pressure: 3792 to 3839 psi. Mud weight: 9.03 ppg in, 9.05 ppg
out, Window ECD: 11.82 ppg w/ 456 psi WH. ROP: 10-40 fph, WOB: 1.6 to 2.8 KLBS. Drill 4.25 build from 9063' MD. Free spin: 3792 psi, 2.82 bpm. Rate: 2.82
bpm in, 2.79bpm out. Circ pressure: 3792 to 3935 psi. Mud weight: 9.09 ppg in, 9.12 ppg out, Window ECD: 11.88 ppg w/ 429 psi WH. ROP: 40-75 fph, WOB: 1.6
to 3.6 KLBS. Drill 4.25 build from 9220' MD Entered into B7 at 9125' MD. Free spin: 3786 psi, 2.82 bpm. Rate: 2.82 bpm in, 2.79bpm out. Circ pressure: 3792 to
3935 psi. Mud weight: 9.09 ppg in, 9.12 ppg out, Window ECD: 11.88 ppg w/ 429 psi WH. ROP: 40-75 fph, WOB: 1.6 to 3.6 KLBS. 9250' 5 bbls lo/hi vis. Drill to
TD of 9268'. Wiper trip to window, clean pass. Jog below D-shale at full rate then pull through D and window at 0.5 bpm, clean. Above window jog at full rate, open
EDC clean tubing 3.6 bpm up to 8170'. Tie-in stack wt 8215' then falls off. Correct +4'. RIH to 8700' close EDC. Pass windows no issues go to 0.5 bpm pump 10
bbls hi-vis then 11.8#. 3k DWOB at 9195 then pop through. Tag 9270' corrected drilled depth. PU pump 11.8# to bit. POOH to window see -1.3k DWOB at 9193'
otherwise clean pass. Jog below D shale, pull through D and window 0.5 bpm clean. Jog full rate above whipstock open EDC. Pump 11.8# to surface, 10 min no
flow is good. POOH flag pipe 7748.7', 8286.55' EOP. Pump at the best rate possible while keeping losses to minimum. At surface, 10 min no-flow is good. Lift
injector off, inspect 20' of CT. L/D BHA #30 - Build BHA, bit 3-1. Remove BHI UQC. Boot cable. Pump 221 ft slack out. Install CT connector, pull test to 50k PT to
6k, good. Pump 7/8" drift ball around and recover. Inspect top drive, rig up tongs.
6/26/2023 Inspect top drive and verify counts. Verify safety joint and appropriate x-overs on ready rack. . Make up shoe track and 3-1/4" x 2-7/8" X-over. Make up 3-1/4" L-80
TCII liner per tally. Swapped Joint #2 for Joint#19. (Box damaged). Fill every 10 joints. Perform KWT drill Response time 2:56. Continue making up liner. Make up 3
joints 3-1/2" ST-L liner. Make up BOT liner running tool. Make up 6 joints of 2-3/8" PH6. Tag up. Break circulation. RIH with protection string. Rate: 0.36 bpm in,
0.56 bpm out. Circ pressure: 145 psi. Mud Weight: 11.78 ppg in, 11.52 ppg out. Tie-in to window flag at with -1.4 correction. Run through window without issues.
Work to establish consistent circulation. In time worked to full circulation. Load and launch 3/4" steel ball. Position reel. Attempt to go down. Stacking 15' off bottom.
Attempt to pull free. No luck until increase rate. Bridge broke free. Tools popped free. Rih back to original tag depth. Increase rate. Ball heard going over gooseneck.
Did not land on volume. Surge reel. No luck. Surge multiple times. Ball on seat. Sheared at 2500 psi. PU and verify tool released. Appears we are off liner. PJSM w/
HES and Nabors crews. PT cement line to 4500 psi, good. Load reel w/ 13.5 bbls cmt, displace w/ rig. Zero out MM cmt at shoe. PU and exhaust, set down and
launch LWP, bumps 0.2 bbls over. Total of 2.8 bbls behind pipe. POOH slow circ exhaust cmt up at 3 bpm. After cmt out of hole 10 min no flow is good. Continue
POOH swap well to new KCl. At surface, good 10 min no-flow. Skid back, L/D 6 jts of 2-3/8" PH-6 and liner running tools. Recover 3/4" ball. M/U nozzle, jet stack.
Purge choke w/ air. Reverse circulate slack into reel. Cable is not heard moving. Cut off CT connector, use fresh water to pump back. Cable is heard moving. Lift
injector off, install hydraulic cutter. Cut off 250' of CT for 1.77% slack. Install CT connector.
6/27/2023 Pull test coil connector to 50K. Good test. Pump slack forward for UQC. Make up UQC, Test line. Good test. 47.2 > 550. PT CTC, UQC to 3500#. Make up FVS
and nozzle. Rih 2600' MD (2500' TVD). Circulate diesel around. Once clean diesel to surface. Close choke. Pump pipe displacement. Tag up. Close Master / SSV
with 170 psi. LTT on swab and master. Remove BOP stack, install tree cap. PT tree cap 3500 psi, good. Release rig 19:00 prep to move to MPC-02A.
7/17/2023 Continue RDMO Ops on MP C-02A. PJSM with Nabors and Cruz OFS to move off of MPC-02 and move to MPB-15. 09:00 Move pits then the Sub. Jeep up both for
move. Move rig from C-Pad to B-Pad. Rig on B-Pad, remove jeeps and prep to spot over well. Sub spotted, spot in pits. Accept rig 17:30. Start MIRU checklists.
Leak tight test on SV, MV good. Remove tree cap, install BOPs and MPD line. Secure stack. M/U nozzle for BOP test. Fluid pack reel and surface lines. Test BOPs
as per Hilcorp and AOGCC regs. All tests 250 / 3500 psi. Witness waived by AOGCC Inspector Brian Bixby. Test 1: IRV, Stripper, C7, C9, C10, C11 - Pass. Test 2:
Blind/Shear, R2, BL2, C15 - Pass. Test 3: Annular (2"), TIW2, B1, B4 - F/P on B1 - Pass.
7/18/2023 Continue test BOPE. Test: 4 Upper 2" Pipe / Slip, TIW#2, B2, B3 - Pass. Test: 5 Lower 2" Pipe / Slip, C5, C6, C8, TV2 - F/P TV2 -Pass. Test: 6 Choke A, Choke C -
Pass. Test: 7 C1, C2, TV1 - Pass. Test:8 2-3/8" Pipe / Slip, C2, C1 - Pass. Drawdown Test - Pass. BOP Test completed, RD test equipment & swap out lubricators.
PT PDL's, good PT. Install BHI Floats and test. Good PT. Pump slack forward, slack pumped forward. Line up to fluid pack stack with Methanol. Open well to a
closed choke to check for pressure. No pressure, pump methanol to make sure well is full, 10 bbls pump with no returns. Shut down pump, close swab valve and
prep for modified Pressure Deploy. MU drift BHA in PDL and deploy BHA. BHA deployed MU injector and RIH. Tie-in depth from 8190' correct +1'. Log CCL from
8250' to 8800'. 1.5k DWOB at 9057', 9108' PU is clean 37k. Continue RIH tag PBTD at 9252'. Pump B/U 2 bpm. P/U for another CCL, the first was not good data.
After B/U purge riser, 10 min no-flow is good. RIH to 9200' clean minor wt bobbles. Pump 20 bbls hi-vis around, POOH. At surface, good 10 min no-flow. Lift inj off
skid back, L/D BHA #33 - whipstock drift. P/U BHA #34 - Whipstock. RIH BHA #34 - Whipstock. Set pressure and slackoff trips close. Tie-in depth from 8190'
correct -3'. RIH up wt at liner top 35k. Up wt at 9230 is 37k. RIH to 9247.2' puts TOWS at 9236'. Close EDC get up wt back pressure up shears out at 2500 psi. Set
5.8k DWOB on it, solid. Whipstock set TOWS 9236' at 40R. POOH.
7/19/2023 At surface, good 10 min no-flow. L/D BHA #34 - Whipstock Setting. M/U BHA #35 - Window Mill 2.74" Go / 2.73" NoGo. RIH BHA #35. Tie-in depth from 8190'
correct -1'. CCL log from 8350' to 8800'. Swap CT to mud. Close EDC. Dry tag 9236' PU 40k and pump 1.8 bpm. Mill window from 9236.50'. 1.86 / 1.81 bpm. Pcirc
= 3018 psi. End of tray 9241.1' MD. Begin working ECD up to a target of 11.8 ppg. Rate: 1.80 bpm in, 1.77 bpm out. Mud Weight: 8.81 ppg in, 8.80 ppg out
Window ECD 11.8 ppg w/ 724 psi WH. Mill rathole to 9251' MD. Perform 3 reaming passes. Dry drift. No issue. Pooh. Rate: 2.40 bpm in, 1.95 bpm out. Circ
pressure: 4388 psi. Mud Weight: 8.81 ppg in, 8.79 ppg out. Pressure un-deploy BHA #35 - Window Mill. Mill and Reamer 2.74" Go / 2.73" NoGo. Keep 11.8# ECD
while BHA handling. Load PDL w/ BHA #36 - Lateral Drilling. M/U nozzle, jet stack. Deploy BHA #36. RIH BHA #36 keep 11.8# ECD at window. Tie-in depth from
8190' no correction. RIH Close EDC. Pass window no issues tag 9245'. Pick up go to 1.8 bpm for drilling. Drill 3" hole from 9245'. 1.85 / 1.85 bpm In / Out. MW
8.81 / 8.81 ppg window ECD = 11.84 ppg w/ 730 psi WHP. Pcirc 4100 - 4290 psi. ROP 40 - 60 ft/hr w/ 1.5 - 3k DWOB. 9330' 5 bbls lo/hi vis. 120' wiper from 9400'
is clean up/down. Drill 3" hole from 9400'. 1.84 / 1.82 bpm In / Out. MW 8.81 / 8.82 ppg window ECD = 11.85 ppg w/ 720 psi WHP. Pcirc 4220 - 4490 psi.
7/20/2023 Drill 3.0" Lateral from 9550 MD to 9700' MD. Rate: 1.83 bpm in, 1.81 bpm out. Circ pressure: 4361 psi. Mud weight: 8.80 ppg in, 8.83 ppg out, Window ECD: 11.80
ppg w/ 695 psi WH. ROP: 45-70 fph, WOB: 1.7 2.2 KLBS. Pump 5 / 5 sweep. Long wiper to window. Wiper to window clean. Performed jog below, Pulled through
window. Jog. Open EDC. Pull up hole. Log tie in with +7' correction. Log RA tag on depth at 9241' MD. Continue to TD without issue. Drill 3.0" Lateral from 9700'
MD to 9850' MD. Free spin: 4078 psi, 1.83 bpm (560 psi diff). Rate: 1.83 bpm in, 1.81 bpm out. Circ pressure: 4078 psi to 4410 psi. Mud weight: 8.82 ppg in, 8.84
ppg out, Window ECD: 11.80 ppg w/ 650 psi WH. ROP: 45-70 fph, WOB: 1.7 to 2.2 KLBS. 150' BHA wiper. Drill 3.0" Lateral from 9850' MD to 10049' MD. Free
spin: 4104 psi, 1.83 bpm (552 psi diff). Rate: 1.83 bpm in, 1.83 bpm out. Circ pressure: 4104 psi to 4410 psi. Mud weight: 8.82 ppg in, 8.85 ppg out, Window ECD:
11.80 ppg w/ 655 psi WH. ROP: 45-70 fph, WOB: 1.7 to 2.0 KLBS. Full losses at 10049' MD. PU off bottom clean. Start Run to bottom and drill ahead attempting to
heal. Incrementally dropping ECD to regain returns. Bring down to 10.8 ppg. Rate: 1.82 bpm in, 1.23 bpm out. Circ pressure: 4140 psi. Mud weight: 8.82 ppg in,
8.85 ppg out, Window ECD 10.5 ppg. Wiper to window, clean. Jog below window and pull through 0.5 bpm. Jog above window, open EDC 2.64 / 2.41 bpm pump
B/U until returns clean. PU tie-in depth 8190' correct +2'. Close EDC RIH to bottom 0.4 bpm. Drill 3" lateral from 10150'. Free spin: 3760 psi, 1.81 bpm (579 psi
diff). Rate: 1.82 bpm in, 1.80 bpm out. Circ pressure: 3760 - 3960 psi. Mud weight: 8.86 ppg in, 8.84 ppg out, Window ECD: 10.55 ppg w/ 170 psi WHP. ROP: 45-
80 fph, WOB: 1.7 to 2.5 KLBS. 10260' 5 bbls lo/hi vis. 150' wiper from 10300' clean up/down. Drill 3" lateral from 10300'. Free spin: 3780 psi, 1.81 bpm (540 psi
diff). Rate: 1.82 bpm in, 1.82 bpm out. Circ pressure: 3780 - 3920 psi. Mud weight: 8.87 ppg in, 8.94 ppg out, Window ECD: 10.47 ppg w/ 120 psi WHP. ROP: 30-
80 fph, WOB: 1.2 to 2.5 KLBS. Drill to TD of 10360' wiper to window is clean. Jog below window and pull through 0.5 bpm. Jog above window open EDC 5 bbls
lo/hi vis. Wiper to surface 2.6 / 2.4 bpm 4500 psi. Tag stripper, reset depth. RIH.
7/21/2023 Rih. Log tie in with -4' correction. Log RA to verify. On depth. Rih and tag corrected TD at 10359'. Lay in 1.5 ppb Beaded liner pill up to 9065'. Circulate 10.5# Na/Br
from 9065 to surface. Perform 10 min no-flow. Well static. Pooh. Painted yellow flag @ 9065.13'. Painted white flag @ 8051.07'. Pooh. Rate: 1.54 bpm in, 1.16 bpm
out. Circ pressure: 2267 psi. Mud weight: 10.51 ppg in, 10.56 ppg out, Window ECD: 10.66 ppg. Tag up. Flow check. Well static. Lay down BHA# 36. Bit graded 1-
3-CT-S-X-I-BU-TD. PJSM, Verify count and safety joint. Run per approved tally. Make up G-Spear and MWD. Rih and stop at white flag. -4' correction. Rih above
window. PUW 36K. RIW 16K. Run thru window without issue. Sat down at 9700' MD. PU and lose ground. Clean. Continue making progress slowly. Continue
working liner down to 9797' then losing ground back to 9745'. Apply 100 psi WHP. Park at 9745' Pump LVT + spacers 10/10/10 bbls. Pump 3 LVT out RIH to
9804'. Work pipe pump LVT out no further progress, lose ground to 9757'. Park at 9757' Circ LVT uphole. After 30 min work pipe back to 9807'. Circ LVT out to
tiger tank. Work pipe again from 9798' to 10045' with different RIH speed and WHP. Close choke and pump down CT min rate, push liner to 10154' then to 10287'.
Work liner to TD 10359'. Pump off liner, new up wt is 36k. PU log CCL to latch.
7/22/2023 Complete CCL for liner top depth. Liner top at 9223' MD. Pump off liner. Open EDC. Increase rate 2.5 bpm. Circulate 10.5 ppg out with 8.33 ppg Source water,. Jet
jewelry on way out of hole. Circulate diesel to surface from 2675' MD (2500' TVD). Close choke. Pump pipe displacement on way out of hole. Tag up. Close master
and SSV with 160 psi wellhead. Circulate remaining diesel out of coil. Perform LTT on SSV / master. good test. Lay down BHA#37. Swap out drilling riser for test
risers. Run coil down into shed. Inspect 25'. No issues. BHI pulled floats out of UQC. Blow down coil. Re install B5 valve on flow cross. Rig down interconnect. Swap
out riser on injector. Install lift slings on top drive for picking stack. Rig down tiger tank line. Nipple down BOPE, Install tree cap. LTT to 2000 psi. Rig release 15:30.
Drill to TD of 10360'
Dry tag 9236' PU 40k and pump 1.8 bpm. Mill window from 9236.50
WELL NAME
Date :
Shoe @ :FC @ :Top Liner @ :
Type:
Type :
Type :
Type :
Type :
XYes No
Yes X No Yes X No
Yes X No Yes No
Date :
Volume lost during displacement (bbls) :
Density (ppg) : 8.45 Volume pumped (bbls) : 290
MPB-15A CEMENT REPORT
26-Jun-23 Hole Size :4.25 Casing Size :3.25 x 3.5
Lead Slurry
Class G Volume (bbls): 13.5 15.3
Yield : 1.235 Sacks : 61.4 Mixing / Pumping Rate (bpm) : 1.5
Density (ppg) :
Tail Slurry
Volume (bbls) : Density (ppg) :
Yield : Sacks : Mixing / Pumping Rate (bpm) :
Post Flush (Spacer)
1.5 ppb Geovis Density (ppg) : 8.33 Rate (bpm) :
Bump press :
Volume : 82
Displacement :
1.5 ppb Geovis Density (ppg) : 8.33 Rate (bpm) : 1.5 Volume (actual / calculated) : 2.8 / 10.5
1.5
Method Used To Determine TOC : Calculated
3600
Casing Rotated? Reciprocated? % Returns during job : 27%
Cement returns to surface? Spacer returns? Vol to Sur : 3
FCP (psi) : 2500 Pump used for disp : GD Plug Bumped?
Cement In Place At : 19:54 6/26/2023 Estimated TOC : 8,880
7.70
Remarks:
FI
R
S
T
S
T
A
G
E
9270 9258', 9268' 8575
Preflush (Spacer)
1% SL KCL
27%
Nolan Vlahovich Hilcorp Alaska, LLC
Geo Tech 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 564-4558
E-mail: nolan.vlahovich@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Date: 07/10/2023
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20230423
Well API #PTD #Log Date Log
Company Log Type AOGCC
Eset#
END MPI 2-04 50029215850000 186082 6/11/2023 READ MAPP
MP B-15A 50029213740100 223022 6/22/2023 READ Caliper Survey
MP F-10 50029226790000 196094 7/5/2023 READ Caliper Report
MP K-30 50029227110000 196168 6/22/2023 READ Caliper Survey
Please include current contact information if different from above.
T37818
T37819
T37820
T37821
MP B-15A 50029213740100 223022 6/22/2023 READ Caliper Survey
Kayla
Junke
Digitally signed by
Kayla Junke
Date: 2023.07.10
14:44:17 -08'00'
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown
Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program
Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Install Gas Lift Completion
Development Exploratory
Stratigraphic Service 6. API Number:
7. Property Designation (Lease Number): 8. Well Name and Number:
9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s):
11. Present Well Condition Summary:
Total Depth measured 9,152 feet N/A feet
true vertical 7,193 feet N/A feet
Effective Depth measured 9,131 feet 8,463 feet
true vertical 7,160 feet 6,653 feet
Perforation depth Measured depth See Schematic feet
True Vertical depth See Schematic feet
Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 / BTC 8,609' 6,764'
Packers and SSSV (type, measured and true vertical depth)Tri Point Perm. N/A See Above N/A
12. Stimulation or cement squeeze summary: N/A
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure: N/A
13a.
Prior to well operation:
Subsequent to operation:
13b. Pools active after work:
15. Well Class after work:
Daily Report of Well Operations Exploratory Development Service Stratigraphic
Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL
Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG
Sundry Number or N/A if C.O. Exempt:
Authorized Name and
Digital Signature with Date: Contact Name:
Contact Email:
Authorized Title: Wells Manager Contact Phone:
N/A
2,020psi
5,410psi
3,520psi
7,240psi9,131' 7,160'
Burst
N/A
5,625'Surface
Production
13-3/8"
9-5/8"
7"
78'
5,590'
MILNE PT UNIT B-15A
Plugs
Junk measured
Length Collapse
measured
TVD
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
223-022
50-029-21374-01-00
3800 Centerpoint Dr, Suite 1400
Anchorage, AK 99503
3. Address:
Hilcorp Alaska LLC
N/A
5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work:
ADL0028231 & ADL0047438
MILNE POINT / KUPARUK RIVER OIL
measured
true vertical
Packer
Representative Daily Average Production or Injection Data
Casing Pressure Tubing PressureGas-Mcf
MD
113'
Size
113'
4,640'
Casing
Structural
9,096'
N/A
Brian Glasheen
Brian.Glasheen@hilcorp.com
907-564-5277
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
0
0
000
0 00
0
0
Water-BblOil-Bbl
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
323-309
Sr Pet Eng: Sr Pet Geo: Sr Res Eng:
WINJ WAG
Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
By Grace Christianson at 8:10 am, Jul 17, 2023
Digitally signed by Taylor
Wellman (2143)
DN: cn=Taylor Wellman (2143)
Date: 2023.07.14 10:56:15 -
08'00'
Taylor Wellman
(2143)
RBDMS JSB 071723
DSR-7/19/23WCB 3-6-2024
_____________________________________________________________________________________
Revised By: TDF 6/15/2023
SCHEMATIC
Milne Point Unit
Well: MP B-15A
Last Completed: 6/10/2023
PTD: 223-022
CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm BPF
13-3/8" Conductor 48 / H-40 / PELP 12.715” Surface 78' 0.1571
9-5/8" Surface 36 / K-55 / Buttress 8.921” Surface 5,625’ 0.0773
7” Production 26 / L-80 / Buttress 6.276” Surface 9,131’ 0.0383
TUBING DETAIL
4-1/2” Tubing 12.6 / L-80 / BTC 3.958” Surface 8,609’ 0.0152
JEWELRY DETAIL
No Depth Item
GLM DETAIL: 4-1/2” x 1” KBG-2
1 2,404’GLM STA 6: w/ 1" DGLV w/BK Latch
2 3,963’GLM STA 5: w/ 1" DCK Shear w/BEK
3 5,484’GLM STA 4: w/ 1" DGLV w/BK Latch
4 6,588’GLM STA 3: w/ 1" DGLV w/BK Latch
5 7,567’GLM STA 2: w/ 1" DGLV w/BK Latch
6 8,337’GLM STA 1: w/ 1" DGLV w/BK Latch
7 8,403’ Sliding Sleeve (SSD) – Min ID 3.813
8 8,463’ Tri point Perm Iso Packer
9 8,522’ X Nipple w/ RHC-M – Min ID 3.813”
10 8,573’ WLEG: Bottom @ 8,609’
WELL INCLINATION DETAIL
KOP @8,790’
Angle @ kickoff 41 deg
TREE & WELLHEAD
Tree 4” Cameron Tree
Wellhead 11” 5M FMC w/ 3-1/2” H BPV Profile
OPEN HOLE / CEMENT DETAIL
13-3/8” 100 cf Permafrost in a 17-1/2” Hole
9-5/8”752 bbls Arctic Set III, 56 bbls Class G,
and 20 bbls Arctic Set I in a 12-1/4” Hole
7” 56 bbls Class ‘G’ in a 8-1/2” Hole
TD =9,152 (MD) / TD =7,192’(TVD)
13-3/8”
Orig KB Elev.: 59.0’ / Ori g GL Elev.: 24.0’
KB Elev = 59’ (Nabors 27E)
7”
2
5
6
9-5/8”
1
Casing RA
marker @
8,618’
PBTD=9,131’ (MD) / PBTD =7,160’(TVD)
3
10
9
4
Fish @8,920’
1” DMY valve
and perf guns
Min ID 3.813” @
±8,563’
7
8
Whipstocks
set @ 8786’,
8801’ & 8860’
GENERAL WELL INFO
API: 50-029-21374-01-00
Initial Completion by Nabors 27E - 6/28/1985
A Sidetrack by CDR2: Operations Shutdown
RWO by Thunderbird #1 – 6/10/2023
Well Name Rig API Number Well Permit Number Start Date End Date
MP B-15A Thunderbird 50-029-21374-01-00 223-022 6/6/2023 6/17/2023
6/2/2023 - Friday
No operations to report.
5/31/2023 - Wednesday
Hilcorp Alaska, LLC
Weekly Operations Summary
No operations to report.
6/1/2023 - Thursday
No operations to report.
BOP test 250/2500 psi. Witness waived by Brian Bixby. Test form sent to AOGCC. Pull BPV w/ lubricator. Rock out diesel and
circulate well w/ 150 bbls soap and 325 bbls source water 5 bpm @ 845 psi. No losses while circulating and no gas in returns.
Flow check well. Pull hanger free (50K over) and unseat tubing from PBR (70K over), circulate 2 bottoms up @ 4.5 BPM, LD
hanger, begin pulling 3-1/2" completion and control line.
No operations to report.
6/3/2023 - Saturday
No operations to report.
6/6/2023 - Tuesday
6/4/2023 - Sunday
No operations to report.
6/5/2023 - Monday
Pull hanger free (50K over) and unseat tubing from PBR (70K over), circulate 2 bottoms up @ 4.5 BPM, LD
hanger, begin pulling 3-1/2" completion and control line
Well Name Rig API Number Well Permit Number Start Date End Date
MP B-15A Thunderbird 50-029-21374-01-00 223-022 6/6/2023 6/17/2023
BEGIN R/U .125 CAROBN, 1-7/8'' RS, QC 8' X 1-7/8'' RS (2.60'' wheels), QC, KJ, 5' X 1-7/8'' RS (2.60'' wheels), QC, OJ, QC, KJ,
LSS, CHECK ALL ROLL PINS, TIGHTEN ALL CONN. w/ WRENCHES, PT= 250L / 3500H. PULL BALL & ROD @ 8529' SLM. PULL
SHEAR VALVE @ 3957' SLM / 3963' MD. PULL RHC PLUG BODY @ 8533' SLM / 8522' MD. RAN BARBELLED 3.72,3.73" CENT,
4.5" TEL, 1.75 SAMPLE BAILER, LOC TT @ 8,623' SLM / 8,609' MD ( -14' corr) TAG HARD BTM @ 8,797' SLM / 8,783' MD.
Continue WSR from 6/9/2023... Continue running 4-1/2", 12.6# , L-80 TBG. MU and land Tbg hanger Up/Dn Wts 96/71K.
WLEG @ 8609' ORKB. RILDS. Break circulation IA toTbg 3 bpm @ 500 psi. Set packer @ 3800 psi 30 mins. Lost 175 psi in 30
mins. Bleed Tbg to zero to restart test.Tested Tbg 30 mins start @ 3160 psi, Lost 85 psi 1st 15 mins and 50 psi 2nd 15 mins
Final pressure 3025 psi. Combo MIT (PASS) Initial pressure 3040 psi. Lost 15 psi in 1st 15 and 0 psi in 2nd 15 mins. Final
pressure 3025 psi. Perform second MIT-T Start @ 4000 psi. Lost 90 psi 1st 15 min, Lost 15 psi 2nd 15 min (pass) Bleed down
TBG & IA to zero and set BPV.
6/10/2023 - Saturday
BOP stack removed and set onto stand. Clean hgr void area, new RX54 gasket, install CTS plug and set adapter/tree. Torque to
spec and test to 500/5000 both tests (PASS). Test tree w/ triplex 500/4500 (NO LEAKS). Pull CTS plug and pull Bpv w/ T bar. All
valves closed and manifolds installed. JOB COMPLETE.
6/13/2023 - Tuesday
6/11/2023 - Sunday
Continue rigging down off MPB-15A.
6/12/2023 - Monday
6/9/2023 - Friday
Continue WSR from 6/8/2023... TOH with PBR/PKR assembly laying down 2-7/8" P-110 Work String. LD BHA and packer w/
tailpipe. Prep to run completion. Sort TXP from BTC tbg. Clean storage compund from connections on 50 Jts to get a head
start. All 155 Jts of BTC Tbg has storage compound. Start running 4-1/2 BTC/TXP Completion.
6/7/2023 - Wednesday
Hilcorp Alaska, LLC
Weekly Operations Summary
Pulled 3-1/2" IBT completion from 8693'. OOH w/ Seal Assembly. Prep rig floor and MU BOT BHA #1 4.75" OD Type "C" Spear
4.155" - 4.300" range. 4.75" OD Lubricated Bumper Sub, 4.75" OD Fishing Jar, 4- 4.75" Drill Collars, 4.75" Intensifier, 4.875" x-
over. TIH w/ 2-7/8" P-110 Work String
6/8/2023 - Thursday
Continue WSR from 6/7/2023... TIH w/ BHA #1 BOT Type "C" Spear on 2-7/8" P-110 Work String. Stop @ 8658 and pick up the
power swivel. Up/Dn Wts 68/50K. Engage PBR @ 8694'. Open jars and PU to 160K (90K over) in 20K intervals. Work down 31
right hand turns. PU and Packer started moving @ 128K (80K over). PU ~20', Unable to slide back in hole. Flow check well and
LD Jt #277. Rig down power swivel and MU FOSV and kelly hose. Circulate two bottoms up @ 2.6 bpm @ 975 psi. Shut down
pump, flow check and TOOH with PBR/PKR assembly. Catching collars on way out.
TOH with PBR/PKR assembly laying down 2-7/8" P-110 Work String. LD BHA and packer w/
tailpipe. Prep to run completion.
PULL BALL & ROD @ 8529' SLM. PULL
SHEAR VALVE @ 3957' SLM / 3963' MD. PULL RHC PLUG BODY
Pulled 3-1/2" IBT completion from 8693'. OOH w/ Seal Assembly
Combo MIT (PASS)
Set packer @ 3800 psi 30 mins
Continue running 4-1/2", 12.6# , L-80 TBG. MU and land Tbg hanger
Well Name Rig API Number Well Permit Number Start Date End Date
MP B-15A Thunderbird 50-029-21374-01-00 223-022 6/6/2023 6/17/2023
6/16/2023 - Friday
PULL & RESET BK-DGLV IN ST#6 (2,403' md). MAKE TWO ATTEMPTS TO PULL ST#4 (5,484' md). UNABLE TO LATCH. RAN 1.25"
LIB TO ST#4 (5,484' md). IMPRESSION SHOWS POSSIBLE TRASH ON TOP OF LATCH. PULL & RESET BK-DGLV IN ST#3 (6,587'
md). PULL & RESET BK-DGLV IN ST#2 (7,567' md). ATTEMPT TO EQUALIZE 4-1/2" XX PLUG AT 8,522' MD (Metal marks on
bottom of eq prong). RAN 3.30" MAGNET TO 4-1/2" XX PLUG IN X-NIPPLE AT 8,522' MD. RAN 3.70" BARBELL, 2.0" LIB TO 4-
1/2" XX PLUG IN X-NIPPLE AT 8,522' MD (Inconclusive). RAN 3.70" BARBELL, 2.60" BELL GUIDE TO 4-1/2" XX PLUG IN X-NIPPLE
AT 8,522' MD (No pressure change). PRESSURED UP IA TO 1700psi (Holding).
6/14/2023 - Wednesday
Hilcorp Alaska, LLC
Weekly Operations Summary
RAN 20' x 3.70" DMY WHIPSTOCK TO 8,797' SLM / 8,783' MD. SET 4-1/2" XX-PLUG IN X-NIP @ 8,522' MD (24" oal, 8 x 1/8"
ports). RAN 42-BO SHIFTING TOOL (brass), LOCATE SLEEVE @ 8415' SLM / 8402' MD, JAR UP ONE TIME WENT THROUGH,
MADE 5 PASSES, LRS RIG UP & PERFORM MIT-T, (didn't pass), POOH, (pin sheared). RAN 42-BO SHIFTING TOOL (brass),
LOCATE SLEEVE @ 8415' SLM / 8402' MD,JAR UP ONE TIME WENT THROUGH, MADE 5 PASSES, LRS PERFORM MIT-T, (didn't
pass), (pin nnot sheared). PULL DGLV @ 3957' SLM / 3963' MD. SET 1'' DGLV @ 3957' SLM / 3963' MD, LRS PERFORM MIT-T,
(didn't pass). RAN 4-1/2 D&D HOLEFINDER SET LEAK BETWEEN 8375' SLM & 8275' SLM. PULL DGLV @ 8354' SLM / 8337' MD
(top packing stack missing 5 pieces & center ring). SET 1'' DGLV, SET @ 8354' SLM / 8337' MD, LRS PERFORM MIT-T BETTER,
STILL LEAKING0. ( -14 ft corr of TT @ 8,623' SLM / 8,609' MD 6/13/23). WELL S/I ON DEPARTURE.
6/15/2023 - Thursday
T/I/O=0/0/45 Assist Slickline with LDL (RWO) Pumped 12.6 bbls diesel down IA up TBG to tank to get LLR of .80 bpm @ 850
psi as slickline set D&D. Never saw any indication of leak location. Final Whps=0/0/45. RAN 4-1/2" D&D HOLEFINDER TO
CHECK GASLIFT MANDRELS (See log).UNABLE TO IDENTIFY LEAK AREA.
LRS ASSIST W/ TESTING.
No operations to report.
PULL 4-1/2" XX PLUG FROM X-NIPPLE AT 8,522' MD. RIG UP. CONNECT WHIPSTOCK WITH BAKER. SET WHIPSTOCK 200DEG
FROM TOP SIDE. BOW AT 8777'. RIG DOWN.
6/17/2023 - Saturday
No operations to report.
6/20/2023 - Tuesday
6/18/2023 - Sunday
No operations to report.
6/19/2023 - Monday
Sean McLaughlin for:Digitally signed by Sean
McLaughlin (4311)
DN: cn=Sean McLaughlin (4311)
Date: 2023.06.14 14:48:43 -
08'00'
Sean
McLaughlin
(4311)
By Grace Christianson at 9:27 am, Jun 15, 2023
323-346
MGR19JUN23 MDG 6/19/2023
10-407
DSR-6/15/23
* BOPE test to 3500 psi.
* Variance to 20 AAC 25.112(i) approved for alternate plug placement for abandonment of parent well
with fully cemented 3-1/4" drilling liner.
* No operations shutdown sundry required if immediately moving back to B-15A after drilling MPU C-02A.
* No 2-3/8" X 3-1/2" variable bore rams required if liner 3-1/2" x 3-1/4" length <500'.
GCW 06/19/2023
06/19/23
Brett W.
Huber, Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.06.19 13:12:40
-08'00'
RBDMS JSB 062023
To: Alaska Oil & Gas Conservation Commission
From: Trevor Hyatt
Drilling Engineer
Date: June 14, 2023
Re: MPU B-15A Change to Approved Program
Approval is requested for drilling a CTD sidetrack lateral from well MPU B-15 with the Nabors
CDR2 Coiled Tubing Drilling with the new plan detailed below.
Work completed to date on MPU B-15:
CDR2 attempted to sidetrack B-15 in May 2023. Three whipstocks were set and windows milled. The first window
was successful, however wellbore stability issues warranted a second whipstock and window. That whipstock
failed after milling the window and drilling the build section. A third whipstock was set and cemented in. This
whipstock failed and the BHA continued to have parent access below the whipstock. The rig moved off the well to
the next well in the schedule to develop a plan forward, thus going into Operation Shutdown status. A workover
was performed to pull the 3-1/2” tubing out of the well and install 4-1/2” tubing with enough room to set another
whipstock. The well is ready for CDR2 to come back and sidetrack.
Proposed new plan for MPU B-15A Producer:
Prior to resuming drilling activities, the well will be drifted and a whipstock will be set pre-rig. A coil tubing drilling
sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. The rig will mill
a single string 3.80" window + 10' of formation. The well will kick off drilling Kuparuk D shale, build in the Kuparuk
B silts, and cross a fault into Kuparuk B7 sands to land the build section. A 3-1/2”x3-1/4” solid protection string will
be ran to the bottom of the build and cemented. CDR2 will then rig down and move to MPU C-02A (unable to
swap to 2” coil while the rig is on B-15A, because of spacing on pad). After C-02A is complete, the rig will come
back to B-15A with 2” coil and set a whipstock in the projection string above the PBTD. The rig will mill a 2.74”
window + 10’ of formation and drill the lateral in the Kuparuk B7 to TD. The proposed sidetrack will be completed
with a 2-3/8” L-80 slotted liner. This completion WILL abandon the parent Kuparuk perfs.
The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is
attached for reference.
Pre-Rig Work - (Estimated to start in June 17th 2023):
General work scope of Pre-Rig work:
1. Slickline: Dummy WS drift
a. Past whipstock setting locaiton
2. Eline: Set 4-1/2”x7” Whipstock (if scheduling need arise, the whipstock will be set with the rig)
a. Set top of whipstock at 8,761’ MD
b. Set -160° ROHS
Rig Work – Build Section - (Estimated to start in June 21st 2023):
1. MIRU and test BOPE to 3500 psi. MASP with gas (0.10 psi/ft) to surface is 1,600 psi
a. Give AOGCC 24hr notice prior to BOPE test
b. Test against swab and master valves (No TWC)
c. Load pits with drilling fluid
d. Open well and ensure zero pressure
2. Mill 3.80” single string window (out of 7”) plus 10’ of rathole
a. Top of window (whipstock pinch point) at 8,766’ MD.
b. Hold 11.8 ppg MPD while milling window
ppp
This completion WILL abandon the parent Kuparuk perfs.
3. Drill – Build
a. 3” BHA with GR/RES / Bi-center Bit (4.25”)
b. 30° DLS build section – 434’ MD / Planned TD ~9,200’ MD
c. Drill with a constant bottom hole pressure for entire sidetrack
d. Pressure deployment will be utilized
e. After TD and on the last trip out of hole lay in completion/kill weight fluid in preparation for liner run
f. No flow test prior to laying down drilling BHA
4. Run and Cement Protection String
a. Have 2-3/8” safety joint with TIW valve ready to be picked up while running liner
b. Run 3-1/2”x3-1/4” L-80 solid liner to TD
c. Swap well over to KCl
d. Cement Liner with 17 bbls - 15.3 ppg Class G cement (TOC to TOL)*
e. Freeze protect well from ~2200’ TVD (min)
f. RDMO to MPU C-02A
5. Move to MPU C-02A – see applicable Sundry and PTD for more details
a. Drill and complete build section with a protection string
b. Downsize to 2” coil
c. Drill and complete lateral section
d. RDMO back to MPU B-15A
Rig Work – Lateral Section - (Estimated to start in July 12th 2023):
6. MIRU and test BOPE to 3500 psi. MASP with gas (0.10 psi/ft) to surface is 1,600 psi
a. Give AOGCC 24hr notice prior to BOPE test
b. Test against swab and master valves (No TWC)
c. Load pits with drilling fluid
d. Open well and ensure zero pressure
7. Set 3-1/4” whipstock
a. Set top of whipstock at 9,160’ MD
b. Set 30° ROHS
8. Mill 2.74” single string window (out of 3-1/4”) plus 10’ of rathole
a. Top of window (whipstock pinch point) at 9,160’ MD.
b. Hold 11.8 ppg MPD while milling window
9. Drill – Lateral
a. 2-3/8” BHA with GR/RES / Bi-center Bit (3.125”)
b. 12° DLS lateral section – 1,240’ MD / Planned TD 10,400’ MD
c. Drill with a constant bottom hole pressure for entire sidetrack
d. Pressure deployment will be utilized
e. After TD and on the last trip out of hole lay in completion/kill weight fluid in preparation for liner run
f. No flow test prior to laying down drilling BHA
10. Run Slotted Liner
a. Have 2” safety joint with TIW valve ready to be picked up while running liner
b. Run 2-3/8” L-80 slotted liner to TD
c. Release from liner, swap the well over to KCl and come out of hole.
d. Freeze protect well from ~2200’ TVD (min)
e. RDMO
Post Rig:
1. V: Valve & tree work
2. S: Set LTP* (if necessary)
3. S: Set live LGLVs (if necessary)
4. T: Portable test separator flowback
* Approved alternate plug placement per 20 AAC 25.112(i)
No operations shutdown required if immediately moving back to B-15A after MPU C-02A -mgr
then open well. -mgr
No 2-3/8" X 3-1/2" variable bore rams required if liner 3-1/2" x 3-1/4" length <500'.
Managed Pressure Drilling:
Managed pressure drilling techniques will be employed on this well. The intent is to provide constant bottom hole
pressure by using minimum 8.4 ppg drilling fluid in combination with annular friction losses and applied surface
pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying
annular friction and choke pressure also allow use of lighter drilling fluid and minimizes fluid losses and/or
fracturing at the end of the long well bores. A MPD choke for regulating surface pressure and is independent of
the WC choke.
Deployment of the BHA under trapped wellhead pressure will be necessary. Pressure deployment of the BHA will
be accomplished utilizing 3” (bighole) & 2-3/8” (slimhole) pipe/slip rams (see attached BOP configurations). The
annular preventer will act as a secondary containment during deployment and not as a stripper.
Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements
while drilling and shale behavior. The following scenario is expected:
MPD Pressure at the Planned Window (8,766’ MD - 6,883’ TVD)
Pumps On Pumps Off
A Target BHP at Window (ppg)4,223 psi 4,223 psi
11.8
B Annular friction - ECD (psi/ft)526 psi 0 psi
0.06
C Mud Hydrostatic (ppg)3,078 psi 3,078 psi
8.6
B+C Mud + ECD Combined 3,604 psi 3,078 psi
(no choke pressure)
A-(B+C)Choke Pressure Required to Maintain 620 psi 1,145 psi
Target BHP at window and deeper
Operation Details:
Reservoir Pressure:
The estimated reservoir pressure is expected to be 2,300 psi at 7,000’ TVD (6.4 ppg equivalent).
Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 1,600 psi (from estimated
reservoir pressure).
Mud Program:
Drilling: Minimum MW of 8.4 ppg KCL with Geovis for drilling. Managed pressure used to maintain
constant BHP.
KWF will be stored on location. The tankage will contain 1.5 wellbore volumes of KWF to exceed the
maximum possible BHP to be encountered as the lateral is drilled. Adjust with real time BHP monitoring.
Completion: A minimum MW 8.4 ppg KWF to be used for liner deployment. Will target 11.8 ppg to match
managed pressure target.
Disposal:
All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4.
Fluids >1% hydrocarbons or flammables must go to GNI.
Fluids >15% solids by volume must go to GNI.
Fluids with solids that will not pass through 1/4” screen must go to GNI.
Fluids with PH >11 must go to GNI.
Hole Size:
4.25” and 3.125” hole for the entirety of the production hole section.
Liner Program:
Protection String:
3-1/2”, 9.3#, L-80 solid/cemented liner: 8,570’ MD – 8,750’ MD (180’ liner)
3-1/4”, 6.6#, L-80 solid/cemented liner: 8,750’ MD – 9,200’ MD (450’ liner)
Lateral Section:
2-3/8”, 4.6#, L-80 slotted liner: 9,140’ MD – 10,400’ MD (1,260’ liner)
The primary barrier for this operation: Kill Weight Fluid to provide overbalance as necessary
A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole.
Well Control:
BOP diagram is attached. MPD and pressure deployment is planned.
Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi.
The annular preventer will be tested to 250 psi and 2,500 psi.
1.5 wellbore volumes of KWF will be on location at all times during drilling operations.
A X-over shall be made up to a 2-3/8” and 2” safety joint including a TIW valve for all tubulars ran in hole.
2-3/8” and 2” safety joint will be utilized while running solid or slotted liner. The desire is to keep the
same standing orders for the entire liner run and not change shut in techniques from well to well (run
safety joint with pre-installed TIW valve). When closing on a 2-3/8” and 2” safety joint, 2 sets of pipe/slip
rams will be available, above and below the flow cross providing better well control option.
Directional:
Based off original B-15A PTD. Maximum planned hole angle is 112°. Inclination at kick off point is 41°.
Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run.
Distance to nearest property line – 6,600’
Distance to nearest well within pool – 980’
Logging:
MWD directional, Gamma Ray, and Resistivity will be run through the entire open hole section.
Real time bore pressure to aid in MPD and ECD management.
Perforating:
NA – slotted liner
Anti-Collision Failures:
All wells pass AC with WP04.
Hazards:
The highest recorded H2S well on the pad was from MPU B-03 (43 ppm) in 2009. Last recorded H2S on
MPU B-15 was 23 ppm in 2009.
One fault crossing expected.
Medium lost circulation risk.
Trevor Hyatt CC: Well File
Drilling Engineer Joseph Lastufka
(907-223-3087)
_____________________________________________________________________________________
Revised By: TDF 6/14/2023
PROPOSED SCHEMATIC
Milne Point Unit
Well: MP B-15A
Last Completed: 6/10/2023
PTD: 223-022
CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm BPF
13-3/8" Conductor 48 / H-40 / PELP 12.715” Surface 78' 0.1571
9-5/8" Surface 36 / K-55 / Buttress 8.921” Surface 5,625’ 0.0773
7” Production 26 / L-80 / Buttress 6.276” Surface 8,790’ 0.0383
TUBING DETAIL
4-1/2” Tubing 12.6 / L-80 / BTC 3.958” Surface 8,609’ 0.0152
JEWELRY DETAIL
No Depth Item
GLM DETAIL: 4-1/2” x 1” KBG-2
12,404’GLM STA 6: w/ 1" DGLV w/BK Latch
23,963’GLM STA 5: w/ 1" DCK Shear w/BEK
35,484’GLM STA 4: w/ 1" DGLV w/BK Latch
46,588’GLM STA 3: w/ 1" DGLV w/BK Latch
57,567’GLM STA 2: w/ 1" DGLV w/BK Latch
68,337’GLM STA 1: w/ 1" DGLV w/BK Latch
7 8,403’ Sliding Sleeve (SSD) – Min ID 3.813
8 8,463’ Tri point Perm Iso Packer
9 8,522’ X Nipple w/ RHC-M – Min ID 3.813”
10 8,573’ WLEG: Bottom @ 8,609’
WELL INCLINATION DETAIL
KOP @8,790’
Angle @ kickoff 41 deg
TREE & WELLHEAD
Tree 3-1/8” 5M FMC w/ 3-1/2” Otis Quick Union
Wellhead 11” 5M FMC w/ 3-1/2” H BPV Profile
OPEN HOLE / CEMENT DETAIL
13-3/8” 100 cf Permafrost in a 17-1/2” Hole
9-5/8”752 bbls Arctic Set III, 56 bbls Class G,
and 20 bbls Arctic Set I in a 12-1/4” Hole
7” 56 bbls Class ‘G’ in a 8-1/2” Hole
TD =9,152 (MD) / TD =7,192’(TVD)
13-3/8”
Whipstock
set @8761’
Orig KB Elev.: 59.0’ / Ori g GL Elev.: 24.0’
KB Elev = 59’ (Nabors 27E)
7”
2
5
6
9-5/8”
1
Casing RA
marker @
8,618’
PBTD=8,761’ (MD) / PBTD =6,880’(TVD)
3
10
9
4
Fish @8,920’
1” DMY valve
and perf guns
Min ID 3.813” @
±8,563’
7
8
Whipstocks
set @ 8786’,
8801’ & 8860’
GENERAL WELL INFO
API: 50-029-21374-01-00
Initial Completion by Nabors 27E - 6/28/1985
A Sidetrack by CDR2: Operations Shutdown
RWO by Thunderbird #1 – 6/10/2023
_____________________________________________________________________________________
Modified: JNL 6/13/23
PROPOSED SCHEMATIC
Milne Point Unit
Well: MP B-15A
Last Completed: TBD
PTD: 223-022
CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm BPF
13-3/8" Conductor 48 / H-40 / PELP 12.715” Surface 113' 0.1571
9-5/8" Surface 36 / K-55 / Buttress 8.921” Surface 5,625’ 0.0773
7” Production 26 / L-80 / Buttress 6.276” Surface 8,790’ 0.0383
3-1/2”x3-1/4” Protection String 9.3 x 6.6 / L-80 / TCII 2.805” 8,570’ 9,160’
2-3/8” Slotted Liner 4.7 / L-80 / Hyd 511 1.995” 9,140’ 10,400’ 0.0039
TUBING DETAIL
4-1/2” Tubing 12.6 / L-80 / BTC 3.958” Surf 8,609’ 0.0152
JEWELRY DETAIL
GLM DETAIL: CAMCO 4-1/2” x 1” KBG
12,404’GLM STA 6: Dummy Valve w/ BK Latch
23,963’GLM STA 5: Shear Valve w/ BEK Latch
35,484’GLM STA 4: Dummy Valve w/ BK Latch
46,588’GLM STA 3: Dummy Valve w/ BK Latch
57,567’GLM STA 2: Dummy Valve w/ BK Latch
68,337’GLM STA 1: Dummy Valve w/ BK Latch
7 8,403’ Sliding Sleeve (SSD) 3.813”
8 8,463’ Tri point Packer
9 8,522’ X Nipple w/ RHC – Min ID 3.813”
10 8,573’ WLEG: Bottom @ 8,609’
SLOTTED LINER DETAIL
PLUGBACK INFO
APB1: 8864’ – 9955’
APB2: 8805’ – 9350’
APB3: 8790’ – 9098’
APB4: ~9160’ – 9200’
GENERAL WELL INFO
API: 50-029-21374-01-00
Initial Completion by Nabors 27E - 6/28/1985
RWO Thunderbird Rig #1 – 6/10/2023
A Sidetrack Completed: TBD
Top
(MD)
Btm
(MD)
Top
(TVD)
Btm
(TVD)
WELL INCLINATION DETAIL
A KOP @ 8,766’
90 Deg Angle @ 9,060’
TREE & WELLHEAD
Tree 3-1/8” 5M FMC w/ 3-1/2” Otis Quick Union
Wellhead 11” 5M FMC w/ 3-1/2” H BPV Profile
OPEN HOLE / CEMENT DETAIL
17-1/2” 100 cf Permafrost
12-1/4”2200 sx Arctic Set III, 175 sx Class G, and 20 bbls Arctic
Set I (Top Job)
8-1/2” 275 sx Class G
4-1/4” 77 sx Class G
3-1/4” Uncemented Slotted Liner
TD =10,400’(MD) / TD =6,983’(TVD)
13-3/8”
Orig KB Elev.: 59.0’ / Orig GL Elev.: 23.1’
7”
4
7
9
10
1
9-5/8”
2
Casing RA
marker @
8,618’
3-1/4”
set
@9200’
PBTD =10,400’(MD) / PBTD =6,983’(TVD)
6Top of 3-1/2”
Liner /
Cement
@8,570’
Whipstock set
@ 8761’
Top of
Window
@ 8766’
2-3/8”
5
3
8
3-1/2”xo3-
1/4” @ 8750’
See
Slotted
Liner
Detail
3-1/4”
Whipstock
set
@9160’
Well Date
Quick Test Sub to Otis -1.1 ft
Top of 7" Otis 0.0 ft
Distances from top of riser
Excluding quick-test sub
Top of Annular 2.75 ft
C L Annular 3.40 ft
Bottom Annular 4.75 ft
CL Blind/Shears 6.09 ft
CL 2.0" Pipe / Slips 6.95 ft B3 B4
B1 B2
Kill Line Choke Line
CL 2-3/8" Pipe / Slip 9.54 ft
CL 2.0" Pipe / Slips 10.40 ft
TV1 TV2
T1 T2
Flow Tee
Master
Master
LDS
IA
OA
LDS
Ground Level
3" LP hose open ended to Flowline
CDR2-AC BOP Schematic
CDR2 Rig's Drip Pan
Fill Line from HF2
Normally Disconnected
3" HP hose to Micromotion
Hydril 7 1/16"
Annular
Blind/Shear
2-3/8" Pipe/Slips
2 3/8" Pipe/Slips
2 3/8" Pipe/Slips
7-1/16"
5k Mud
Cross
2-3/8" Pipe/Slips
3.0" Pipe / Slip
HF
nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeee
Well Date
Quick Test Sub to Otis -1.1 ft
Top of 7" Otis 0.0 ft
Distances from top of riser
Excluding quick-test sub
Top of Annular 2.75 ft
C L Annular 3.40 ft
Bottom Annular 4.75 ft
CL Blind/Shears 6.09 ft
CL 2.0" Pipe / Slips 6.95 ft B3 B4
B1 B2
Kill Line Choke Line
CL 2-3/8" Pipe / Slip 9.54 ft
CL 2.0" Pipe / Slips 10.40 ft
TV1 TV2
T1 T2
Flow Tee
Master
Master
LDS
IA
OA
LDS
Ground Level
3" LP hose open ended to Flowline
CDR2-AC BOP Schematic
CDR2 Rig's Drip Pan
Fill Line from HF2
Normally Disconnected
3" HP hose to Micromotion
Hydril 7 1/16"
Annular
Blind/Shear
2.0" Pipe/Slips
2 3/8" Pipe/Slips
2 3/8" Pipe/Slips
7-1/16"
5k Mud
Cross
2.0" Pipe/Slips
2-3/8" Pipe /
Slip
HF
nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeee
CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders.
From:Trevor Hyatt
To:Guhl, Meredith D (OGC); Joseph Lastufka; Rixse, Melvin G (OGC)
Cc:Roby, David S (OGC); Davies, Stephen F (OGC)
Subject:PTD223-022 MPU B-15A 10-403 Ops shutdown
Date:Monday, June 19, 2023 9:46:24 AM
Attachments:MPU B-15A wp12.txt
MPU B-15A wp12 Compass Plots and Reports.pdf
Meredith,
We are still following the initial PTD plan (within 500’) and the targets remain the same. However,
we do have an updated plan with the new kick off and landing attached. We are drilling the build
section first and running a protections liner and then moving to C-02A. So we only have the build
section planned for now. The TD depth is a little longer than the numbers Joe and I submitted last
week, as this plan was tweaked this weekend to optimize landing past the fault. After we drill the
build section, we will pick the kick off point for the lateral section whipstock and create the final
lateral directional plan at that point. Again, still targeting the same targets and staying within the
500’ radius of the initial PTD plan. We will send you the final plan at that point if that works for you?
Thanks for the help!
Trevor Hyatt
Hilcorp Alaska, LLC
Drilling Engineer
Trevor.Hyatt@hilcorp.com
Cell: 907-223-3087
From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Sent: Monday, June 19, 2023 9:30 AM
To: Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Rixse, Melvin G (OGC)
<melvin.rixse@alaska.gov>; Trevor Hyatt <Trevor.Hyatt@hilcorp.com>
Cc: Roby, David S (OGC) <dave.roby@alaska.gov>; Davies, Stephen F (OGC)
<steve.davies@alaska.gov>
Subject: RE: [EXTERNAL] PTD223-022 MPU B-15A 10-403 Ops shutdown
Joe,
Is there a new proposed survey for this well?
Thank you,
Meredith
From: Joseph Lastufka <Joseph.Lastufka@hilcorp.com>
CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders.
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.
Sent: Tuesday, June 6, 2023 3:53 PM
To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Trevor Hyatt <Trevor.Hyatt@hilcorp.com>
Cc: Roby, David S (OGC) <dave.roby@alaska.gov>; Davies, Stephen F (OGC)
<steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Subject: RE: [EXTERNAL] PTD223-022 MPU B-15A 10-403 Ops shutdown
Mel,
When we initially moved off the well prior to completion, it was in Operations Shutdown status. We
would not produce from the well in its current condition. Since we were able to come up with a plan
to install new tubing, we will complete the well post RWO. The current plan is to wait for the RWO to
complete, then submit a 10-403 Change of Approved Program to finish the well, likely within a week
or so. A case could be made that it is not in Operations Shutdown due to continuing work and will
resume drilling operations approximately a month from now. If you’d prefer, we can withdraw the
10-403 for Operations Shutdown, the initial goal was to submit as we weren’t sure how we were
planning to proceed. Please let me know if you have any questions or concerns. Thanks!
Thanks,
Joe Lastufka
Sr. Drilling Technologist
Hilcorp North Slope, LLC
Office: (907)777-8400, Cell:(907)227-8496
From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Sent: Tuesday, June 6, 2023 2:42 PM
To: Joseph Lastufka <joseph.lastufka@hilcorp.com>; Trevor Hyatt <trevor.hyatt@hilcorp.com>
Cc: Roby, David S (OGC) <dave.roby@alaska.gov>; Davies, Stephen F (OGC)
<steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Subject: [EXTERNAL] PTD223-022 MPU B-15A 10-403 Ops shutdown
Joe, Trevor,
Is this really an ops shutdown? Do you plan on drilling this? If so, when approximately?
Would Hilcorp consider putting this on production as it is now? If so, (I think) just finish the 10-
407.
20 AAC 25.072. Temporary shutdown of drilling or completion operations
(a) If circumstances prevent the continuation of the program approved on a Permit to Drill
(Form 10-401), or if an operator wishes to change drill rigs, the operator shall apply to the
commission for approval to shut down drilling or completion operations temporarily. Based on the
information received under this subsection, the commission will decide whether to approve the
temporary shutdown of drilling or completion operations. The request for operation shutdown must
be submitted on an Application for Sundry Approvals (Form 10-403), providing a full justification for
the shutdown, a description of the proposed condition of the wellbore upon shutdown of drilling or
completion operations, the approximate date when drilling or completion operations will resume, and
a proposed program for securing the well during the period of shutdown. An Application for Sundry
Approvals is not required for planned shutdowns of well operations, if those shutdowns are described
in the approved Permit to Drill.
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).
cc. Steve Davies, Roby, Meredith Guhl
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the
individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby
notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please
immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete
this message.
While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the
onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility
is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate.
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the
individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby
notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please
immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete
this message.
While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the
onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility
is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate.
CAUTION: This email originated from outside the State of Alaska mail system.
Do not click links or open attachments unless you recognize the sender and know
the content is safe.
From:Rixse, Melvin G (OGC)
To:Brian Glasheen
Cc:Tom Fouts
Subject:20230612 1501 APPROVAL for Passing CMIT meeting MIT-IA MP B-15A Sundry 323-309 (PTD 223-022)
Date:Monday, June 12, 2023 3:04:40 PM
Brian,
Tubing and IC tested to 3000 psi is approved as meeting requirement for passing MIT-IA in step
30 of sundry 323-309.
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: Brian Glasheen <Brian.Glasheen@hilcorp.com>
Sent: Monday, June 12, 2023 1:48 PM
To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Cc: Tom Fouts <tfouts@hilcorp.com>
Subject: FW: MP B-15A AOGCC 10-403 Submittal, PTD: 223-022
Mel,
For MPB-15 we ended up getting a passing MIT-T and CMIT-TXIA to 3000 psi. Will you accept that as
a meeting the sundry requirements in step 30 attached. I believe the shear GLV was faulty, We
pressure tested the tubing against a check valve and had direct communication when pressuring up
the IA.
Thanks
Brian Glasheen
Ops Engineer
907-545-1144
From: Tom Fouts <tfouts@hilcorp.com>
Sent: Thursday, May 25, 2023 3:24 PM
To: 'melvin.rixse@alaska.gov' <melvin.rixse@alaska.gov>
Cc: Brian Glasheen <Brian.Glasheen@hilcorp.com>; Taylor Wellman <twellman@hilcorp.com>
Subject: FW: MP B-15A AOGCC 10-403 Submittal, PTD: 223-022
From: Tom Fouts
Sent: Thursday, May 25, 2023 3:22 PM
To: aogcc.permitting@alaska.gov
Cc: Brian Glasheen <Brian.Glasheen@hilcorp.com>; Taylor Wellman <twellman@hilcorp.com>; Darci
Horner - (C) <dhorner@hilcorp.com>
Subject: MP B-15A AOGCC 10-403 Submittal, PTD: 223-022
Hello,
Please process the attached 10-403 submittal for MP B-15A, PTD: 223-022
Thanks,
Tom Fouts | Senior Ops/ Reg Tech
Hilcorp Alaska, LLC
tfouts@hilcorp.com
Direct: (907) 777-8398
Mobile: (907) 351-5749
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message.
While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the
onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility
is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate.
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Install Gas Lift Completion
2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number:
Exploratory Development
3. Address: Stratigraphic Service
6. API Number:
7. If perforating:8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?
Will planned perforations require a spacing exception? Yes No
9. Property Designation (Lease Number): 10. Field: Current Pools:
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD):
9,152'N/A
Casing Collapse
Structural N/A
Surface 2,020psi
Production 5,410psi
Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft):
12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations: OIL WINJ WDSPL Suspended
16. Verbal Approval: Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name: Brian Glasheen
Contact Email:
Contact Phone:
Authorized Title: Wells Manager
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other:
Post Initial Injection MIT Req'd? Yes No
Spacing Exception Required? Yes No Subsequent Form Required:
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
AOGCC USE ONLY
Brian.Glasheen@hilcorp.com
907-564-5277
Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size:
9.2# / L-80 / BTRS 8,758'
6/3/2023
3-1/2" BOT HB Hyd. and 3-1/2" TRDP-1A SCSSV 8,707 MD/ 6,839 TVD and 742 MD/ 742 TVD
See Schematic See Schematic 3-1/2"
Perforation Depth MD (ft):
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
223-022
3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-21374-01-00
Hilcorp Alaska LLC
KUPARUK RIVER OIL N/A
C.O. 432E
MILNE PT UNIT B-15
7,193' 9,131' 7,160' 1,907 N/A
Proposed Pools:
113' 113'
TVD Burst
PRESENT WELL CONDITION SUMMARY
13-3/8"
MILNE POINT
N/A
3,520psi
7,240psi
4,640'
7,160'
9-5/8"
7"
5,590'
9,096'
MD
5,625'
9,131'
Length Size
78'
Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
By Grace Christianson at 3:24 pm, May 25, 2023
323-309
Digitally signed by Taylor
Wellman (2143)
DN: cn=Taylor Wellman (2143)
Date: 2023.05.25 15:10:15 -
08'00'
Taylor Wellman
(2143)
MGR25MAY2023 DSR-5/25/23
BOPE test to 2500 psi. Annular to 2500 psi.
1,907
A SFD
SFD 5/25/2023
10-404
GCW 05/26/23JLC 5/26/2023
05/26/23
Brett W. Huber,
Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.05.26 14:12:38
-08'00'
RBDMS JSB 053023
Replace Tubing
Well: MPU B-15
Well Name:MPU B-15 API Number:50-029-21374-01-00
Current Status:SI Pad:MPB-pad
Estimated Start Date:June 3rd 2023 Rig:TB 1
Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd:
Regulatory Contact:Tom Fouts Permit to Drill Number:223-022
First Call Engineer:Brian Glasheen 9075451144
Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M)
AFE Number:TBD Job Type:Replace TBG for CTD
Current Bottom Hole Pressure:2,607 psi @ 7000’ TVD SBHP: (3/31/2023) |7.2 PPG
Maximum Expected BHP:2,607 psi @ 7000’ TVD SBHP: (3/31/2023) |7.2 PPG
MPSP:1,907 psi Gas Column Gradient (0.1 psi/ft)
Max Inclination 49° @ 5620’ MD
Brief Well Summary:
MP-B-15 was initially completed in 1985. Recent CTD in 2023 failed to complete the well after 3 sidetrack
attempts. This RWO is designed to increase the tubing size in the well to allow bigger CTD options.
Notes Regarding the Well & Design
o CMIT-TXIA passed 2074 psi 4/4/2023
o MIT-T failed 0.1 BPM @ 1500 psi
o 7’’ cement job had full return during job, 56 bbls of class G pumped ~ TOC 7148’MD
Objective:
x Pull 3.5’’ tubing
x Pull packer
x Run new 4-1/2” gas lift completion
Non-Sundry work:
Slickline
1. RU SL.
2. Set TTP at 8746’MD.
3. Pull St 1 (8655’ MD) GLV leave pocket open for circulation point during RWO
4. Perform CMIT-TXIA to 3000 psi
5. Pull TTP at 8746 md.
Well Support-
6. Clear and level pad area in front of well. Spot rig mats and containment.
7. RU Little Red Services. RU reverse out skid and 500 bbl returns tank.
8. Pressure test lines to 3,000 psi.
A SFD
Replace Tubing
Well: MPU B-15
9. Circulate at least one wellbore volume with source or produced water 8.4 ppg down tubing, taking
returns up casing to 500 bbl returns tank..
10. RD Little Red Services and reverse out skid.
11. RU crane. Set CTS BPV. ND Tree. NU BOPE. RD Crane.
12. NU BOPE house. Spot mud boat.
Sundry work:
RWO Procedure
13. MIRU Hilcorp TB#1, ancillary equipment and lines to returns tank.
14. Test BOPE to 250/2,500 psi and annular to 250/2,500 psi.
a. Notify the AOGCC 24 hours in advance of BOP test.
b. Confirm test pressures per the Sundry Conditions of approval.
c. Test VBR’s and annular with 2-7/8” and 4-1/2” test joints.
d. Submit to AOGCC completed 10-424 form within 5 days of BOPE test.
15. RU to pull 3-1/2” GL completion. Well is completed with a seal assembly that should allow the TBG to
be pulled with straight pull.
16.
17. Pull the CTS Plug, check for pressure under the BPV, if needed kill the well with KWF and pull the BPV.
18. Well will be live. Establish hole fill and maintain during the entirety of the job.
19. MU the landing joint to the tubing hanger, BOLDS and unseat the tubing hanger.
a. 8747’ of 3-1/2’’ TBG is 80 klbs (Dry).
b. Do not exceed 80 percent ( 165 klbs) of 3-1/2’’ tubing with out OE approval
c. Original completion noted PBR was sheared with 49,000 lbs over string weight.
20. Pull the hanger to the rig floor. Lay down the landing joint and tubing hanger.
a. Inspect the tubing hanger and note any corrosion or damage.
21. POOH laying down the 3-1/2’’ tubing.
If any risk of pressure under BPV, LUBRICATE BPV. - mgr
Pull BPV with lubricator
if risk of pressure. -mgr
Set CTS BPV.
Replace Tubing
Well: MPU B-15
a. All tubing will not be reused.
22. RIH with baker fishing tool to retrieve packer and tubing tail. Follow vendor recommendations on
pulling releasable HP packer.
a. Once packer releases stop and wait for 30 minutes to allow packer elements to relax. While
waiting on packer elements, circulate at max rate down the work string taking returns up
the annulus a min of 2 bottoms up and expect packer gas to return. Close annular during
this time taking returns to pits. If no returns are seen at surface while pumping continue to
pump 2 bottoms up and allow the gas to migrate to surface. Wait 2-4 hours while
maintaining hole fill down the work string to allow gas to migrate to surface before POOH.
23. Contingency- If packer does not release on its own.
a. RIH with overshot and latch top of PBR.
b. RU ELINE and cut TBG polish bore just above packer.
c. POOH
d. RIH and burn over/ mill packer until it releases.
e. Once packer releases circulate at max rate down the work string taking returns up the
annulus a min of 2 bottoms up and expect packer gas to return. Close annular during this
time taking returns to pits. If no returns are seen at surface while pumping continue to
pump 2 bottoms up and allow the gas to migrate to surface. Wait 2-4 hours while
maintaining hole fill down the work string to allow gas to migrate to surface before POOH.
f. Retrieve packer.
24. PU and MU the following 4-1/2’’ Tubing completion:
Colors indicate assemblies to be bucked up prior to RWO.
Nom.
Size ~Length Item Lb/ft Material Notes
4.5 10'WLEG L-80
4.5 40 Joint 12.6 L-80
4.5 10'Pup Joint 12.6 L-80
4.5 3'4-1/2'' X nip with RHC 12.6 L-80 This has to be a X nip not XN.
4.5 10'Pup Joint 12.6 L-80
4.5 40 1 joint 12.6 L-80
4.5 10'Pup joint 12.6 L-80
4.5 7'' X 4-1/2'' Packer 12.6 L-80 Tri point Packer set ~ 8500' MD
4.5 10'Pup Joint 12.6 L-80
4.5 1 joint 12.6 L-80
4.5 10'Pup Joint 12.6 L-80
4.5 Sliding sleeve 12.6 L-80
4.5 10'Pup Joint 12.6 L-80
4.5 1 joint 12.6 L-80
Replace Tubing
Well: MPU B-15
4.5 10'XO JFE Bear to BTC 12.6 L-80
4.5 4-1/2 X 1 12.6 JFE BEAR BXP L80 KBG-
2 12.6 L-80 Dummy Valve installed
4.5 10'XO BTC to JFE BEAR 12.6 L-80
4.5 Joints 12.6 L-80
4.5 10'XO JFE Bear to BTC 12.6 L-80
4.5 4-1/2 X 1 12.6 JFE BEAR BXP L80 KBG-
2 12.6 L-80 ~7585' MD Dummy Valve
installed
4.5 10'XO BTC to JFE BEAR 12.6 L-80
4.5 Joints 12.6 L-80
4.5 10'XO JFE Bear to BTC 12.6 L-80
4.5 4-1/2 X 1 12.6 JFE BEAR BXP L80 KBG-
2 12.6 L-80 ~6598' MD Dummy Valve
installed
4.5 10'XO BTC to JFE BEAR 12.6 L-80
4.5 Joints 12.6 L-80
4.5 10'XO JFE Bear to BTC 12.6 L-80
4.5 4-1/2 X 1 12.6 JFE BEAR BXP L80 KBG-
2 12.6 L-80 ~5496' MD Dummy Valve
installed
4.5 10'XO BTC to JFE BEAR 12.6 L-80
4.5 Joints 12.6 L-80
4.5 10'XO JFE Bear to BTC 12.6 L-80
4.5 4-1/2 X 1 12.6 JFE BEAR BXP L80 KBG-
2 12.6 L-80 ~3980' MD Shear Valve installed
4.5 10'XO BTC to JFE BEAR 12.6 L-80
4.5 Joints 12.6 L-80
4.5 10'XO JFE Bear to BTC 12.6 L-80
4.5 4-1/2 X 1 12.6 JFE BEAR BXP L80 KBG-
2 12.6 L-80 ~2414' MD Dummy Valve
installed
4.5 10'XO BTC to JFE BEAR 12.6 L-80
4.5 Joints 12.6 L-80
4.5 Space out PUPS 12.6 L-80
4.5 1 joint 12.6 L-80
4.5 PUP 12.6 L-80
4.5 Tubing Hanger 12.6 L-80
Pups needed for GLM
Nom.
Size Quantity Item Lb/ft Material Notes
4.5 6 XO JFE Bear to BTC 12.6 L-80
4.5 6 XO BTC to JFE Bear 12.6 L-80
25. Space out and land the hanger.
Replace Tubing
Well: MPU B-15
a. Note PU (Pick Up) and SO (Slack Off) weights on tally.
26. RILDS. Lay down landing joint.
27. Pump 60 bbls 1% KCL or seawater with Corrosion inhibitor down the IA. Taking returns up TBG. This is to
protect the area between the packer and GLM 4. While taking returns up the TBG
28. Pump an additional 100 bbls of KCL or seawater down the IA to land inhibitor between GLM4 and
packer.
29. Drop ball and rod and complete loading tubing and hydraulically set the packer as per vendors setting
procedure
30. Pressure up and test the tubing to 3000 psi for MIT-T with 1000 psi on the IA. Bleed off the tubing to
1000psi. Test the IA to 3000 psi for MIT-IA. Bleed off the tubing and observe shear valve shear.
Confirm circulation in both directions thru the sheared valve. Record and notate all pressure tests (30
minutes) on chart.
31. Freeze Protect well with diesel. Pump 75 bbls down the IA while taking returns up the TBG.
32. Rig up jumper from IA to tubing to allow freeze protect to swap.
33. Set BPV.
34. RD Thunderbird #1 WO Rig
Post-Rig Procedure:
35. ND BOPE
36. NU tree and tubing head adapter.
37. Test both tree and tubing hanger void to 500psi low/5,000psi high.
38. Pull BPV.
SL
39. RU slickline, pressure test the lubricator to 250 psi low/ 2,500 psi high 5 min each.
40. RIH Pull the ball & rod and RHC plug body.
41. Pull Shear valve and DMY St 4 for CTD.
42. Drift for 4-1/2’’ X7’’ Whipstock
43. RD slickline.
Attachments:
1. As-built Schematic
2. Proposed Schematic
3. BOP stack sketch
_____________________________________________________________________________________
Modified: JNL 5/22/23
SCHEMATIC
Milne Point Unit
Well: MP B-15A
Last Completed: TBD
PTD: 223-022
CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm BPF
13-3/8" Conductor 48 / H-40 / PELP 12.715” Surface 113' 0.1571
9-5/8" Surface 36 / K-55 / Buttress 8.921” Surface 5,625’ 0.0773
7” Production 26 / L-80 / Buttress 6.276” Surface 9,131’ 0.0383
TUBING DETAIL
3-1/2” Tubing 9.2 / L-80 / BTC 2.992” Surf 8,758’ 0.0087
JEWELRY DETAIL
No Depth Item
1 742’ Camco TRDP-1A-SSA SCSSV (2.812” ID) (CS Profile)
GLM DETAIL: CAMCO 3.5” KBUG
2 2,185’GLM STA 10: 2.875” SPMO-1.0M TK-2 coating BK latch (Dome Set 4/2/20)
3 3,034’GLM STA 9: 2.875” SPMO-1.0M TK-2 coating BK latch (Dome Set 4/2/20)
4 3,851’GLM STA 8: 2.875” SPMO-1.0M TK-2 coating BK latch (Dome Set 4/2/20)
5 4,670’GLM STA 7: 2.875” SPMO-1.0M TK-2 coating BK latch (Dome Set 4/2/20)
6 5,392’GLM STA 6: 2.875” SPMO-1.0M TK-2 coating BK latch (SO Set 4/2/20)
7 6,148’GLM STA 5: 2.875” SPMO-1.0M TK-2 coating BK latch (Dummy Set 4/2/20)
8 6,871’GLM STA 4: 2.875” SPMO-1.0M TK-2 coating BK latch (Dummy 4/2/20)
9 7,525’GLM STA 3: 2.875” SPMO-1.0M TK-2 coating BK latch (Dummy Set 10/26/13)
10 8,118’GLM STA 2: 2.875” SPMO-1.0M TK-2 coating BK latch (Dummy Set 4/2/20)
11 8,655’GLM STA 1: 2.875” SPMO-1.0M TK-2 coating BK latch (Dummy Set 10/26/13)
12 8,693’ BOT Polished Bore Receptacle Seal Assembly (ID= 3.00”)
13 8,707’ BOT “HB” Packer
14 8,746’ Camco 3-1/2” “D” Nipple
15 8,747’ Tubing Tail (ID= 2-3/4”) bottom at 8,758’
16 8,786’ 3
rd Whipstock (Window = 8790’ – 8793’)
17 8,801’ 2
nd Whipstock (Window = 8805’ – 8809’)
18 8,860’ 1
st Whipstock (Window = 8864’ – 8868’)
WELL INCLINATION DETAIL
KOP @8,790’
Angle @ kickoff 41 deg
TREE & WELLHEAD
Tree 3-1/8” 5M FMC w/ 3-1/2” Otis Quick Union
Wellhead 11” 5M FMC w/ 3-1/2” H BPV Profile
GENERAL WELL INFO
API: 50-029-21374-01-00
Initial Completion by Nabors 27E - 6/28/1985
A Sidetrack CDR2: Operations Shutdown
TD =9,098’(MD) / TD=7,031’(TVD)
13-3/8”
A: 8790’–9098’
PB2: 8805’ – 9350’
PB1: 8864’ – 9955’
Orig KB Elev.: 59.0’ / Orig GL Elev.: 23.1’
7”
4
7
9
10
11
1
16
9-5/8”
Tubing RA
marker @
8,663’
2
CasingRA
marker @
8,618’
PBTD =9,098’(MD) /PBTD=7,031’(TVD)
6
Whipstocks
set @ 8786’,
8801’ & 8860’
15
14
5
3
8
17
18Fish @8,920’
1” DMY valve
and perf guns
Min ID 2.75”
@ 8,746’
12
13
OPEN HOLE / CEMENT DETAIL
13-3/8” 100 cf Permafrost in a 17-1/2” Hole
9-5/8”752 bbls Arctic Set III, 56 bbls Class G,
and 20 bbls Arctic Set I in a 12-1/4” Hole
7” 56 bbls Class ‘G’ in a 8-1/2” Hole
_____________________________________________________________________________________
Revised By: TDF 5/25/2023
PROPOSED
Milne Point Unit
Well: MP B-15A
Last Completed: 6/28/1985
PTD: 223-022
CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm BPF
13-3/8" Conductor 48 / H-40 / PELP 12.715” Surface 78' 0.1571
9-5/8" Surface 36 / K-55 / Buttress 8.921” Surface 5,625’ 0.0773
7” Production 26 / L-80 / Buttress 6.276” Surface 9,131’ 0.0383
TUBING DETAIL
4-1/2” Tubing 12.6 / L-80 / BTC 3.958” Surface ±8,623’ 0.0152
JEWELRY DETAIL
No Depth Item
GLM DETAIL: 4-1/2” x 1” KBG
1 ±2,414’GLM STA 6: w/ Dummy Valve
2 ±3,980’GLM STA 5: w/ Shear Valve
3 ±5,496’GLM STA 4: w/ Dummy Valve
4 ±6,598’GLM STA 3: w/ Dummy Valve
5 ±7,585’GLM STA 2: w/ Dummy Valve
6 ±8,300’GLM STA 1: w/ Dummy Valve
7 ±8,435’ Sliding Sleeve
8 ±8,500’ Tri point Packer
9 ±8,563’ X Nipple w/ RHC – Min ID 3.813”
10 ±8,621’ WLEG: Bottom @ ±8,623’
WELL INCLINATION DETAIL
KOP @8,790’
Angle @ kickoff 41 deg
TREE & WELLHEAD
Tree 3-1/8” 5M FMC w/ 3-1/2” Otis Quick Union
Wellhead 11” 5M FMC w/ 3-1/2” H BPV Profile
OPEN HOLE / CEMENT DETAIL
13-3/8” 100 cf Permafrost in a 17-1/2” Hole
9-5/8”752 bbls Arctic Set III, 56 bbls Class G,
and 20 bbls Arctic Set I in a 12-1/4” Hole
7” 56 bbls Class ‘G’ in a 8-1/2” Hole
TD = 9,152 (MD) / TD =7,192’(TVD)
13-3/8”
Orig KB Elev.: 59.0’ / Orig GL Elev.: 24.0’
KB Elev = 59’ (Nabors 27E)
7”
2
5
6
9-5/8”
1
Casing RA
marker @
8,618’
PBTD =9,131’ (MD) / PBTD =7,160’(TVD)
3
10
9
4
Fish @8,920’
1” DMY valve
and perf guns
Min ID 3.813” @
±8,563’
7
8
Whipstocks
set @ 8786’,
8801’ & 8860’
GENERAL WELL INFO
API: 50-029-21374-01-00
Initial Completion by Nabors 27E - 6/28/1985
A Sidetrack CDR2: Operations Shutdown
Thunderbird BOP Diagram 2023
THE STATE
ofALAS
GOVERNOk MIKE DUNLEAVY
Monty M. Myers
Drilling Manager
Hilcorp Alaska, LLC
3800 Centerpoint Dr., Suite 1400
Anchorage, AK, 99503
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Re: Milne Point, Kuparuk River Oil, MPU B -15A
Hilcorp Alaska, LLC
Permit to Drill Number: 223-022
Surface Location: 300' FSL, 1037' FWL, Sec. 18, T13N, RI IE, UM, AK
Bottomhole Location: 715' FNL, 1757' FWL, Sec. 30, T13N, RI IE, UM, AK
Dear Mr. Myers:
Enclosed is the approved application for the permit to drill the above referenced well.
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well
logs run must be submitted to the AOGCC within 90 days after completion, suspension, or
abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first.
This permit to drill does not exempt you from obtaining additional permits or an approval required
by law from other governmental agencies and does not authorize conducting drilling operations
until all other required permits and approvals have been issued. In addition, the AOGCC reserves
the right to withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska
Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply
with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code,
or an AOGCC order, or the terms and conditions of this permit may result in the revocation or
suspension of the permit.
Sincerely,
Digitally signed by Brett W.
Brett W. Huber, Sr. Huber,sr,
Date: 2023.03.241024:55 -06'00'
Brett W. Huber, Sr.
Chair, Commissioner
DATED this 24 day of March, 2023.
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
RECEIVED
By Samantha Carnsre at 3:50 pm, Mar 09, 2023
1 a. Type of Work:
1 b. Proposed Well Class: Exploratory -Gas ❑ Service -WAG ❑ Service • Disp ❑'
1 c. Specify if well is proposed for:'
Drill ❑ Lateral ❑
IStratigraphic Test ❑ Development - Oil ®' Service - Winj ❑ Single Zone ®
Coalbed Gas ❑ Gas Hydrates [3
Redrill ® Reentry ❑
Exploratory - Oil ❑ Development -Gas 13 Service -Supply ❑ Multiple Zone
Geothermal ❑ Shale Gas ❑
2. Operator Name:
5. Bond Blanket ® Single Well ❑
11. Well Name and Number.
Hiloorp Alaska, LLC
Bond No. 22224484
MPU B -16A
3. Address:
6. Proposed Depth:
12. FiekVPool(s):
3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503
MD: 10399' TVD: 6983'
MILNE POINT, KUPARUK
RIVER OIL
4a. Location of Well (Governmental Section):
7. Property Designation (Lease Number):
Surface: 300' FSL, 103T FWL, Sec. 18, T13N, RI 1E, UM, AK
ADL 047438 & 028231
8. DNR Approval Number:
13, Approximate spud date:
Top of Productive Horizon:
81.054
May 1, 2023
739' FSL, 129V FWL Sec. 19, TI 3N. RI 1E, UM, AK
9. Acres in Property: 5099
14. Distance to Nearest Property,.
Total Depth: 71T FNL, 1757' FWL, Sec. 30, T13N, R1 1E, UM, AK
660V
4b. Location of Well (State Base Plane Coordinates- NAD 27):
10. KB Elevation above MSL: 59 feet
15. Distance to Nearest Well
Surface: x- 572114 y- 6023424 Zone - 4
GL Elevation above MSL: 23.1 feet
980 to Same Pool:
16. Deviated wells: Kickoff Depth: 8864' feet
17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 112 degrees
Downhole: 2300 Surface: 1600
18. Casin Proram: Specifications
To - Setting Depth - Bottom Cement Quantity, c.f. or sacks
Hole Casing Weight Grade Coupling Length
MD TVD MD TVD (inctuaing stage ata)
3.1/4" 2-3/8" 4.6# L-80 Hyd 511 1574'
8725' 6x52' 10399' Bu5i 75 sx Class G
19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations)
Total Depth MD (ft): Total Depth TVD (ft):
Plugs (measured):
Effect. Depth MD (ft):
Effect. Depth TVD (ft): Junk (measured):
9152 7176
None
9131
7160 1 8920
Casing Length Size Cement Volume MD TVD
Conductor/Structural 78 13-3/8" 100 d Permafrost 35-113 35-113
Surface 5590 9-5/8" 2200 sx Arctic Set Ill, 175 sx Class G, 20 Bbls Arctic Set 1 35-5625 35 - 4640
Intermediate
Production 9098 7' 275 sx Class G 33-9131 33-7160
Liner
Perforation Depth MD (ft): 8786 - 8886 Perforation Depth TVD (ft): 6899.6976
Hydraulic Fracture planned? Yes ❑ No
20. Attachments Property Plat ❑ BOP Sketch ® Drilling Program ® Time v. Depth Plot ❑ Shallow Hazard Analysis ❑
Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.05D req uirements 0
21. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated
from without prior written approval. Contact Name: Trevor Hyatt
Monty Monty M 0. ' M "&
Authorized Name: Mon ere orr.�axpa I...vuc
„",,,..,,,,w Contact Email: trevochyatt@hilcorp.mm
Authorized Title: Drilling Manager """�""w""°�°"`"" Contact Phone: 7 -
yQr$ Mnml"ngpMMtlaGaeunnl 90 777-8396
OeN: R2A4]01iIQY/MW
_
Authorized Signature: Date: 3.9.2 0 2 3
Commission Use Only
Permit to Drill 223_022
Number.
API Number: 50-029-21374-01-00
Da1e it Approval
See cover letter for other
requirements:
Conditions of approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: ■
Other: * BOPE test to 3500 psi_ Samples req'd: Yes ❑ No ■ Mud log req'd: Yes ❑ No ■
' Variance to 20 AAC 25.112(i) approved for alternate H2S measures Yes lit No ❑ Directional svy req'd: Yes ! No ❑
plug placement for abandonment of parent well
'Spacing exception req'd: Yes ❑ No S Inclination -only svy req'd: Yes ❑ No ■
Post initial Injection MIT req'd: Yes ❑ No ❑
Brett W.Huber, Sr• Date zoiO3.22aiozsn oe�o0r� APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date: 3/24/2023
1COmm.JLC
3/24/2023 1 Comm. GCW 03/24/23 1Sr Pet En%AGR21MAR2023 Sr vet Geo MDG 3123/2023 Sr Res Eng
Form 10401 Revised 3/2021 This permit is valid for 24 months from the date of approval (20 AAC 25.005(8))
To: Alaska Oil & Gas Conservation Commission
From: Trevor Hyatt
Drilling Engineer
Date: March 9, 2023 �i cor 13
Re: MPU B-1 5A Permit to Drill
Approval is requested for drilling a CTD sidetrack lateral from well MPU B -15A with the
Nabors CDR2 Coiled Tubing Drilling.
Proposed plan for MPU B -15A Producer:
See MPU B-15 Sundry request for complete pre -rig details - Prior to drilling activities, screening will be
conducted to MIT and drift for whipstock.
A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the
well. The rig will set a 3-1/2"x7" flow through whipstock and mill a single string 2.74" window + 10' of formation.
The well will kick off drilling and land in the Kuparuk. The lateral will continue in the Kuparuk to TD. The proposed
sidetrack will be completed with a 2-3/8" L-80 solid liner and cemented. This completion WILL abandon the parent
Kuparuk perfs. The well will be perforated post rig (see future pert sundry).
The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is
attached for reference.
Pre -Rig Work:
• Reference MPU B-15 Sundry submitted in concert with this request for full details.
• General work scope of Pre -Rig work:
1. Slickline: Dummy WS drift
2. Fullbore: MITs
Rig Work - (Estimated to start in May 2023 :
1. MIRU and test BOPE to 3500 psi. MASP with gas (0.10 psi/ft) to surface is 1,600 psi
a. Give AOGCC 24hr notice prior to BOPE test
b. Test against swab and master valves (No TWC)
c. Load pits with drilling fluid
d. Open well and ensure zero pressure
2. Set 3-1/2"x7" HEW (whipstock)
a. Set top of whipstock at 8,860' MD
b. Set highside (0° ROHS)
3. Mill 2.74" single string window (out of 7") plus 10' of rathole
a. Top of window (whipstock pinch point) at 8,864' MD. Sundry 323-148
b. Hold 11.8 ppg MPD while milling window
4. Drill— Build & Lateral DTC 223-022
a. 2-3/8" BHA with GR/RES / Bi -center Bit (3.25")
b. 320 DLS build section -213' MD / Planned TD 9,077' MD
c. 12° DLS lateral section —1,322' MD / Planned TD 10,399' MD
d. Drill with a constant bottom hole pressure for entire sidetrack
e. Pressure deployment will be utilized
f. After TD and on the last trip out of hole lay in completion/kill weight fluid in preparation for liner run
g. No flow test prior to laying down drilling BHA
5. Run and Cement 2-3/8" L-80 solid liner
a. Have 2" safety joint with TIW valve ready to be picked up while running liner
b. Release from liner and come out of hole.
c. Make up cementing BHA and sting into liner shoe. Swap the well over to 2% KCI.
d. Cement liner with 16.5 bbls, 15.3 ppg Class G (TOC to TOL).*
e. Freeze protect well from -2200' TVD (min)
f. RDMO
Post Rig:
1. V: Valve & tree work
2. S: Set LTP* (if necessary)
3. C: Post rig perforate -750' (see future pert sundry)
4. S: Set live LGLVs
5. T: Portable test separator flowback
* Approved alternate plug placement per 20 AAC 25.112(1)
Managed Pressure Drilling:
Managed pressure drilling techniques will be employed on this well. The intent is to provide constant bottom hole
pressure by using minimum 8.4 ppg drilling fluid in combination with annular friction losses and applied surface
pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying
annular friction and choke pressure also allow use of lighter drilling fluid and minimizes fluid losses and/or
fracturing at the end of the long well bores. A MPD choke for regulating surface pressure and is independent of
the WC choke.
Deployment of the BHA under trapped wellhead pressure will be necessary. Pressure deployment of the BHA will
be accomplished utilizing 3" (bighole) & 2-3/8".(slimhole) pipe/slip rams (see attached BOP configurations). The
annular preventer will act as a secondary containment during deployment and not as a stripper.
Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements
while drilling and shale behavior. The following scenario is expected:
MPD Pressure at the Planned Window (8,864' MD - 6,958' TVD)
Operation Details:
Reservoir Pressure:
• The estimated reservoir pressure is expected to be 2,300 psi at 7,000' TVD (6.4 ppg equivalent).
• Maximum expected surface pressure with gas (0.10 psuft) to surface is 1,600 psi (from estimated
reservoir pressure).
Pumps On
Pumps Off
A Target BHP at Window (ppg)
4,269 psi
4,269 psi
11.8
B Annular friction - ECD (psi/ft)
797 psi
0 psi
0.09
C
Mud Hydrostatic (ppg)
3,112 psi
3,112 psi
8.6
B+C
Mud+ECD Combined
3,909 psi
3,112 psi
(no choke pressure)
A-(B+C)
Choke Pressure Required to Maintain
360 psi
1,158 psi
Target BHP at window and deeper
Operation Details:
Reservoir Pressure:
• The estimated reservoir pressure is expected to be 2,300 psi at 7,000' TVD (6.4 ppg equivalent).
• Maximum expected surface pressure with gas (0.10 psuft) to surface is 1,600 psi (from estimated
reservoir pressure).
Mud Program:
• Drilling: Minimum MW of 8.4 ppg KCL with Geovis for drilling. Managed pressure used to maintain
constant BHP.
• KWF will be stored on location. The tankage will contain 1.5 wellbore volumes of KWF to exceed the
maximum possible BHP to be encountered as the lateral is drilled. Adjust with real time BHP monitoring.
• Completion: A minimum MW 8.4 ppg KWF to be used for liner deployment. Will target 11.8 ppg to match
managed pressure target.
Disposal:
• All Class I & II non -hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4.
• Fluids >1 % hydrocarbons or flammables must go to GNI.
• Fluids >15% solids by volume must go to GNI.
• Fluids with solids that will not pass through 1/4" screen must go to GNI.
• Fluids with PH >11 must go to GNI.
Hole Size:
• 3.25" hole for the entirety of the production hole section.
Liner Program:
• 2-3/8", 4.6#, L-80 solid/cemented liner: 8,725' MD -10,399' MD (1,674' liner)
• The primary barrier for this operation: Kill Weight Fluid to provide overbalance as necessary
• A X -over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole.
Well Control:
• BOP diagram is attached. MPD and pressure deployment is planned.
• Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi.
• The annular preventer will be tested to 250 psi and 2,500 psi.
• 1.5 wellbore volumes of KWF will be on location at all times during drilling operations.
• A X -over shall be made up to a 2" safety joint including a TIW valve for all tubulars ran in hole.
• 2" safety joint will be utilized while running solid or slotted liner. The desire is to keep the same standing
orders for the entire liner run and not change shut in techniques from well to well (run safety joint with pre-
installed TIW valve). When closing on a 2" safety joint, 2 sets of pipe/slip rams will be available, above
and below the flow cross providing better well control option.
Directional:
• Directional plan attached. Maximum planned hole angle is 1120. Inclination at kick off point is 41'.
• Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run.
• Distance to nearest property line -6,600'
• Distance to nearest well within pool — 980'
Logging:
• MWD directional, Gamma Ray, and Resistivity will be run through the entire open hole section.
• Real time bore pressure to aid in MPD and ECD management.
Perforating:
• 750' perforated post rig — See future pert/frac sundry. ADGcc written approval of
If deemed necessary, the rig will perforate under this PTD (1-11/16" Pelf Guns at 6 spf), to operatio intervals required prior
� to operations. MDG 3122/2023
Anti -Collision Failures:
• All wells pass AC with WP04.
Hazards:
• The highest recorded H2S well on the pad was from MPU B-03 (43 ppm) in 2009. Last recorded H2S on
MPU B-15 was 23 ppm in 2009.
• One fault crossing expected.
• Medium lost circulation risk.
Trevor Hyatt CC: Well File
Drilling Engineer (907-223-3087) Joseph Lastufka
HileorP aeaka. L
Odg KB Bev.: 59.0 / Ong GL Elev.: 23.1'
Milne Point Unit
Well: MP B-15
SCHEMATIC Last Completed: 6/28/1985
PTD: 185-121
TREE & WELLHEAD
Tree 3-1/8" 5M FMC w/ 3-1/2" Otis Quick Unlan
Wellhead 31" 5M FMC w 3- "H BPV Profile
OPEN HOLE / CEMENT DETAIL
13-3/8" 100 of Permafrost in a 17-1/2" Hole
9 5/8" 752 bbls Arctic Set III, 56 bbls Class G, and 20 bbls Arctic
Set I in a 12-1/4" Hole
7" 1 56 bbls Class'G' in a 8-212" Hole
CASING DETAIL
Size
Type
Wt/Grade/Conn
ID
Top
Btm
BPF
13-3/8"
Conductor
48 H-40 PELP
12.715"
Surface
113'
0.1571
45/8"
Surface 1
36 / K-55 / Buttress
8.921"
Surface
5,625'
0.0773
7"
Production 1
261 L-80/Buttress
6.276"
Surface
9131'
0.0383
TUBING DETAIL
3-1/2" Tubing 9.2/L-80/BTC 1 2.992" 1 Surt 8,758' 0.0087
WELL INCLINATION DETAIL
KOP @ 500
Max Angle is 49 deg. @ 5,620'
JEWELRY DETAIL
No
Depth
Item
1
742'
Cemco TRDP-IA-SSA SCSSV (2.812" ID) (CS Profile)
MD
(TVDTop
GLM DETAIL: CAMC03.50 KBUG
2
2185'
GLM STA 10: 2.875" SPM0-1.0M TK -2 coating BK latch (Dome Set 4/2/20)
3
3,034'
GLM STA 9:2.875' SPMO-1.OM TK -2 coating SK latch (Dome Set4/2/20)
4
3,851'
GLM STA 8:2.875'SPMO-1.OM TK -2 coating BK latch (Dome 5et4/2/20
5
4,670'
GLM STA 7:2.875'SPMO-1.OM TK -2 coating BK latch Dome5et4/2/20)
6
5,392'
GLM STA 6: 2.875" SPM0-1.0M TK -2 coating BK latch (SO Set 4/2/20)
7
6,148'
GLM STA 5: 2.875"SPMO-1.OM TK -2 coating BK latch IN mmy Set 4/2/20)
8
6,871'
GLM STA 4: 2.875" SPM0-1.0M TK -2 coating BK latch (Dummy 4/2/20)
9
7,525'
GIM STA 3: 2.875" SPM0-1.0M TK -2 coating BK latch (Dummy Set 10/26/13)
SO
8,118'
GIM STA 2: 2.875" SPMO-S.OM TK -2 coating BK latch IDUMMy Set 4/2/20)
11
8,655'
GLM STA 1: 2.875" SPMO-1.0M TK -2 coating BK latch(Dummy Set 10/26/13)
12
8,693'
BOT Polished Bore Receptacle Seal Assembly (ID= 3.00")
13
8 707'
BOT "HB" Packer
14
8,746'
Cain 3-1/2" "o" Nipple
15
8,747
1 Tubing Tail (ID- 2-3/4") bottom at 8,758'
16
8,860'
I Whipstock
PERFORATION DETAIL
Top
Btnn
Zone
MD
MD
(TVDTop
TVD FT
Date Status Size
Ku aruk MK -1 8,786' 1
8,825
6,899'
6928' 39
6/2 85 O n 5" 125PF
Kuparuk MK -2 1 8,852' 1
8,888'
6,949'
6,976' 36
6/28/85 1 Open I5" 125PF
GENERAL WELL INFO
API; 50-029-21374-00-00
Initial Completion by Nabors 27E -6/28/1985
T0= 9,152 (MD) / TD = 7,176'(ND)
Modified: STP 1/18/23
PBTD=9,131' (MD) / PBTD= 7,16OM)
n
Hileorr Alxelu, Id.0
Odg KB Elw.: 59.0' / Orig G L Bev.: 23.1
PROPOSED SCHEMATIC
TD=10,399' (ND) / TD= 6,983'(TVD)
PBTD=10,399' (ND) / PBTD = 6,9V(TVD)
Milne Point Unit
Well: MP B -15A
Last Completed: TBD
PTD: TBD
TREE & WELLHEAD
Tree 3-1/8" 5M FMC W/ 3-1 "Otis Quick Union
Wellhead 11" 5M FMC W 3-1/2" H BPV Profile
OPEN HOLE / CEMENT DETAIL
17-1/2"
100 cf Permafrost
12-1/4"
2200 sx Arctic Set 111,175 sx Class G, and 20 bbls Arctic
Set Top to
8-1/2"
275 sx Gass G
3-1/4"
75 sx Clan
CASING DETAIL
Size
Type
Wt/ Grade/ Conn
ID
Top
Btm
BPF
13-3/8"
Conductor
48/H-40/PELP
12.715"
Surface
113'
0.1571
9-5/8"
Surface
36 / K-55 / Buttress
8.921"
Surface
5,625'
0.0773
7"
Production
26 / L-80 / Buttress
6.276"
Surface
8,864'
0.0383
2-3/8-
Uner
4.6 / L-80 / H d 511
1.995"
8,725'
10,399'
0.0039
TUBING DETAIL
3-1/2" Tubing 9.2/L-80/BTC 1 2.992" 1 Surf 8,758' 0.0087
WELL INCLINATION DETAIL
A KOP @ 8,864'
90 Deg Angle @ 9,060'
JEWELRY DETAIL
No
Depth
Item
1 1
742'
CamCo TRDP-IA-SSASCSSV(2.812"ID)(CSPrdile)
I(UparO
GLM DETAIL: CAMCO 3.5" KBUG
2
2,185'
GLM STA 10: 2.875" SPMO-1.01M TK -2 coating SK latch IDome Set 4/2/20)
3
3,034'
GLM STA 9: 2.875"SPM0-1.0M TK -2 mating SK latch (Dome Set 4/2/20)
4
3,851'
GLM STA 8:2.875"SPMO-1.OM TK -2 coating SK latch Dome Set 4/2/20)
5
4,670'
GLM STA 7:2.875" SPM0-1.0M TK -2 coating BK latch (Dome Set 4/2/20
6
5,392'
GLM STA 6: 2.875" SPMO-1.DM TK -2 coating BK latch (SO Set 4/2/201
7
6148'
GLM STA S: 2.875" SPMO-1.OM TK -2 coating BK latch (Dummy Set 4/2/20)
8
6,871'
GLM STA 4: 2.875" SPMO-1.0M TK -2 coating
BK latch ourn my 4/2/20)
9
7,525'
GLM STA 3: 2.875" SPMO-1.0M TK -2 coating
BK latch (Dummy Set 10/26/13)
10
8,118'
GLM STA 2: 2.875" SPMO-1.0M TK -2 coating SK latch (Durn my SM 4/2/20)
11
8,655'
GLM STA 1: 2.875" SPMO-1.0M TK -2 coating SK latch (Dum my Set 10/26/13
12
8,693'
BOT Polished Bore Receptacle Seal Assembly (1D=3.00")
13
70
8,7'
HB
BOT "1413"
14
8,746'
Cam,, 3-1/2" "D" Nipple
15 1
8,747'
Tubing Tall (ID=2-3/4") bottom at 8,758'
PERFORATION DETAIL
Zone
atm FT
Date Status Size
(MD) (MD)
(TVD) TVDTop
I(UparO
Kuparuk B
GENERAL WELL INFO
API: 50-029-21374-01-00
Initial Completion by Nabors 27E -6/28/1985
A Sidetrack Completed: TBD
Modified: JNL 2/3/23
Hilcorp Alaska, LLC
Milne Point
M Pt B Pad
Plan: MPB-15
Plan: MPB-15A
Plan: MPB-15A wp04
Standard Proposal Report
06 March, 2023
HALLIBURTON
Sperry Drilling Services
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HALLIBURTON
9'.', Il
Project: Milne Point WELL DET D : Wm: VII IS
Site: M Pt B PadGmund Laud: 23.10
Well: Plan: MPI +wS +V -w Noting I LeOmde ton mm
Wellbore: Plan: MPB-15A DAD ow 6023424.2w 572113.620 WN 27.40241 149' '39A229
Plan: MPB46A wp04 REFERENCE INFORMATION
CaoMnme (WE) Reference: Well Plnn: MPSI Tim. Nat
VMiN (ND) Reference: 18:158/15/1985 OOAO �59.000ell lgemrictlrilling 6g1
MaesmW DepN Reference: 19:16 6/16119 8 5 0 0:00 � 59.00esR (genet 601Fg 6N
1 ff5� CabNmlOn Mt6tl: MlMmum CVNBWro I
INP: Smr DQ Y/100: M364' MQ 6938?VD:O• RIIP
--SWD'u321100:8884'MD,6972.96TVD
7Q1
CASING DETAILS
TVD TVDSS MD Size Name
'L 6982.92 6923.92 10399.03 2-3/8 2 318'x 3 1/4"
NPH -15
Sw 117/100':9077.17' MD.7034.MWD
WB -15A %ly
23/8'x3114'
MPR -ISA kg 5 1,
Twat ]3 p 6:10399.03' MD, 6982.92'TVD
,VB.\5X°1904
-250 -125 0 125 250 375 500 625 750 875 1000
West( -)/East(+) (250 usft/il
HALLIBURTON
Database:
NORTH US + CANADA
Company:
Hilcorp Alaska, LLC
Project:
Milne Point
Site:
M Pt B Pad
Well:
Plan: MPB-15
Wellbore:
Plan: MPB-15A
Design:
MPB-15Awp04
Standard Proposal Report
Local Coordinate Reference: Well Plan: MPB-15
TVD Reference: 18: 15 611 5/1 98 5 00:00 @ 59.00usft (generic dri
MD Reference: 18:15 6/15/1985 00:00 @ 59.00usft (generic dd
North Reference: True
Survey Calculation Method: Minimum Curvature
hoject Milne Point, ACT, MILNE POINT
lap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level
'so Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point
Map Zone: Alaska Zone 04 Using geodetic scale factor
Site M Pt B Pad, TR -1311
Site Position:
From Map
Position Uncertainty:
Northing:
Easting:
5.00 usft Slot Radius:
6,021,548.490usft Latitude.
571,775.550usft Longitude:
0.. Grid Convergence:
70° 28'8.9861 N
149` 24'49.8952 W
0.55 °
Well
Plan: MPB-15, MPB-15
Well Position
+NIS
0.00 usft
Northing:
6,023.424.240 usft
Latitude:
70° 28'27.4024
N
+EJ -W
0.00 usft
Easting:
572,113.620 usft
Longitude:
149' 24'39.4228
W
Position Uncertainty
0.00 usft
Wellhead Elevation:
usft
Ground Level:
23.10usft
Wellbore
Plan: MPB-15A
Magnetics
Model Name
Sample Date
Declination
Dip Angle
Field Strength
(°)
(1
(nT)
BGGM2022
3/6/2023
14.90
80.78
57,285.91399015
Design
MPB-15Awp1)4
Audit Notes:
Version:
Phase:
PLAN
Tie On
Depth:
8,864.00
Vertical Section:
Depth From
(TVD)
+WS
+Ef-W
Direction
(usft)
(usft)
(usft)
(I
35.90
-5,083.00
278.70
160.75
Plan Sections
Measured
vertical
TVD
Dogleg
Build
Tum
Depth Inclination Azimuth
Depth
System
+N/ -S
+E/ -W
Rate
Rats
Rate Tool Face
(usft)
(°)
(°)
(usft)
usft
(usft)
(usft) (°MOOusft)
(°1108usft)
(°1100usft)
(°)
8,864.00
40.66
185.64
6,958.00
6,899.00
.4,890.26
255.65
0.00
0.00
0.00
0.00
8,884.00
42.46
185.64
6,972.96
6,913.96
-4,903.46
254.35
9.00
9.00
0.01)
0.00
9,022.03
85.00
171.80
7,032.89
6,973.88
-5,023.90
259.85
32.00
30.82
-10.03
-20.00
9,077.17
92.00
155.59
7,034.34
6,975.34
5,076.59
275.27
32.00
12.70
-29.40
-67.00
9,227.23
93.45
173.56
7,027.15
6,968.15
-5,220.48
314.99
12.00
0.97
11.98
84.99
9,452.29
93.98
146.50
7,012.29
6,953.29
-5,429.59
390.96
12.00
0.24
-12,02
-88.00
9,652.28
93.63
170.55
6,998.82
6,939.82
-5,613.92
463.47
12.00
-0.18
12.03
90.01
9,827.30
111.65
159.44
6,960.57
6,901.57
5,778.07
506.86
12.00
10.30
-6.35
-29.98
9,982.72
93.00
159.44
6,927.54
6,868.54
.5,919,60
559.95
12.00
-12.00
0.00
-180.00
10,057.70
92.96
150.43
6,923.63
6,864.63
5,987.36
591.64
12.00
-0.05
-12.02
-90.02
10,198.95
80.00
161.40
6,932.31
6,873.31
-6,115.57
649.05
12.00
-9.17
7.77
140.00
10,274.00
77.04
152.72
6,947.28
6,888.28
-6,183.23
677.65
12.00
3.94
-11.57
-110.02
10,399.03
69.96
166.53
6,982.92
6.923.92
-6,295.13
719.50
12.00
5.66
11.05
119.98
3/6/2023 4: 51: 18PM
Paye 2
COMPASS 5000.15 Build 91E
H 4 L L I B U R TO N
Standard Proposal Report
Database: NORTH US + CANADA
Local Coordinate Reference:
Well Plan: MPB-15
Company: Hiloorp Alaska, LLC
TVD Reference:
18: 15 6/15/1985 D0:00 @ 59.00usft (generic dri
Project: Milne Point
MD Reference:
18:15 6/15/1985 00:00 @ 59.00usft (generic dd
Site: M Pt B Pad
North Reference:
True
Well: Plan: MPB-15
Survey Calculation Method:
Minimum Curvature
Wellbore: Plan: MPB-15A
DLS
Vert Section
Design: MPB-15AwpD4
(1)
(0)
Planned Survey
Measured
Vertical
Map
Map
Depth
Inclination Azimuth
Depth
TVDss
+NAS
+E1 -W
Northing
Easting
DLS
Vert Section
(usft)
(1)
(0)
(usft)
usft
(usft)
(usft)
(usfl)
(usft)
-23.10
35.90
0.00
0.00
35.90
-23.10
D.01)
0.00
6,023,424.240
572,113.620
0.000
-3,890.68
100.00
0.22
157.58
100.01)
41.00
-0.11
0.05
6,023,424.127
572,113.668
0.343
-4,890.56
200.00
0.43
146.15
200.00
141.00
-0.60
0.33
6,023,423.640
572,113.955
0.219
-4,890.01
300.00
0.47
141.84
300.00
241.00
-1.24
0.79
6,023,423.011
572,114.423
0.052
-4,889.26
400.00
0.64
148.35
399.99
340.99
-2.03
1.34
6,023,422.218
572,114.978
0.181
-4,888.32
500.00
0.75
147.42
499.98
440.98
-3.06
1.98
6,023,421.198
572,115.633
0.111
-4,887.14
600.00
2.71
178.07
599.93
540.93
5.98
2.42
6,023,418.288
572,116.D93
2.100
-4,884.25
700.00
4.12
183.75
699.75
640.75
-11.92
2.26
6,023,412.340
572,115.996
1.448
-4,878.68
600.00
6.39
180.51
799.33
740.33
-21.07
1.98
6,023,403.188
572,115.800
2.288
4,870.14
900.00
6.78
176.62
898.67
639.67
-32.53
2.27
6,023,391.735
572,116.209
0.592
-4,859.22
1,000.00
7.89
164.77
997.85
938.85
-45.05
4.43
6,023,379.241
572,118.481
1.871
-4,846.70
1,100.00
10.32
160.47
1,096.59
1,037.59
50.11
9.22
6,023,364.223
572,123.425
2.522
-4,830.89
1,125.00
11.17
160.47
1,121.15
1,062.15
-64.51
10.78
6,023,359.846
572,125.025
3.400
-4,826.23
1,150.00
11.74
160.54
1,145.65
1,086.65
-69.19
12.44
6,023,355.182
572,126.727
2.261
-4,821.26
1,175.00
12.44
160.68
1,170.10
1,111.10
-74.13
14.18
6,023,35D.261
572,128.513
2.802
-4,816.03
1,200.00
13.57
161.54
1,194.45
1,135.45
-79.45
16.00
6,023,344.956
572,130.384
4.586
-4,810.40
1,225.00
13.89
161.77
1,218.74
1,159.74
-85.08
17.86
6,023,339.343
572,132.306
1.298
-4,804.47
1,250.00
14.21
161.88
1,242.99
1,183.99
-90.85
19.76
6,023,333.595
572,134.254
1.284
-4,798.40
1,275.00
14.61
161.79
1,267.21
1,208.21
-96.76
21.70
6,023,327.704
572,136.251
1.603
4,792.18
1,300.00
15.02
161.97
1,291.37
1,232.37
-102.84
23.68
6,023,321.648
572,138.298
1.650
4,785.79
1,325.00
15.74
162.57
1,315.48
1,256.48
-109.15
25.70
6,023,315.353
572,140.377
2.949
-4,779.16
1,350.00
16.49
163.51
1,339.50
1,280.50
-115.79
27.73
6,023,308.736
572,142.464
3.176
-4,772.23
1,375.00
16.95
164.35
1,363.44
1,304.44
-122.70
29.72
6,023,301.845
572,144.521
2.078
-4,765.05
1,400.00
17.43
164.92
1,367.32
1,328.32
-129.82
31.67
6,023,294.741
572,146.547
2.035
-4,757.68
1,425.00
17.96
165.24
1,411.14
1,352.14
-137.17
33.63
6,023,287.418
572,148.574
2.155
-4,750.10
1,45040
18.21
165.40
1,434.91
1,375.91
-144.67
35.60
6,023,279.931
572,150.613
1,020
4,742.36
1,475.00
18.42
165.39
1,458.64
1,399.64
-152.28
37.58
6,023,272.349
572,152.667
0.840
4,734,53
1,500.00
19.01
165.79
1,482.32
1,423.32
-160.05
39.57
6,023,264.600
572,154.738
2.415
-4,726.54
1,525.00
19.40
165.94
1,505.93
1,446.93
-168.02
41.58
6,023,256.646
572,156.823
1.572
-4,718.35
1,550.00
19,78
166.02
1,529.48
1,470A8
-176.15
43.61
6,023,248.534
572,158.932
1.524
4,710.00
1,575.00
20.13
165.05
1,552.98
1,493.98
-184.41
45.74
6,023,240.295
572,161.144
1.927
-4,701.50
1,600.00
20.48
162.21
1,576.42
1,517.42
-192.74
48.19
6,023,231.999
572,163.670
4,183
-4,692.84
1,625.00
21,04
160.71
1,599.80
1,540.80
-201.14
51.01
6,023,223.627
572,166.570
3.089
-4,683.98
1,650.00
21,59
160.07
1,623.09
1,564.09
-209.70
54.06
6,023,215.098
572,169.703
2.389
4,674,89
1,675.00
21.91
159.61
1,646.31
1,587.31
-218.39
57.25
6,023,206.434
572,172.979
1.450
-4,665.63
1,700.00
22.40
159.42
1,669.47
1,610.47
-227.22
60.55
6,023,197.635
572,176.364
1.981
-4,656.20
1,725.00
23.13
159.26
1,692.52
1,633.52
-236.27
63.96
6,023,188.618
572,179.865
2.930
-4,646.53
1,750.00
23.40
158.91
1,715,48
1,656.48
-245.50
67.49
6,023,179.430
572,183.479
1.213
-4,636.66
1,775.00
23.80
158.83
1,738.39
1,679.39
-254.83
71.10
6,023,170.130
572,187.177
1.605
-0,626.66
1,800.00
24,19
158.66
1,761.23
1,702.23
-264.31
74.78
6,023,160,693
572,190.954
1.584
4,616.50
1,825.00
24.34
158.24
1,784.02
1,725.02
-273.86
78.56
6,023,151.175
572,194,819
0.915
4,606.23
1,850.00
24.67
157.75
1,806.77
1,747.77
-283.48
82.44
6,023,141.600
572,198.798
1.550
4,595.87
1,875.00
24.88
157.00
1,829.47
1,770.47
-293.15
86.47
6,023,131.971
572,202.921
1.512
-4,585.42
1,900.00
25.07
156.51
1,852.13
1,793.13
-302.85
90.64
6,023,122.314
572,207.180
1.124
4,574.89
1,925.00
25.35
156.51
1,874.75
1,815.75
-312.61
94.88
6,023,112.590
572,211.519
1.120
4,564.27
32&2023 4: 51: 18PM Page 3 COMPASS 5000.15 Build 91E
H A L L I B U R T O N
Standard Proposal Report
Database: NORTH US + CANADA
Local Coordinate Reference:
Well Plan: MPB-15
Comparri: Hilcorp Alaska, LLC
TVD Reference:
18: 15 6/15/1985 00:00 @ 59.00usft (generic dri
Project: Milne Point
MD Reference:
18: 15 6/15/1985 00:00 @ 59.00usft (generic dr!
Site: M Pt B Pad
North Reference:
True
Well: Plan: MPS -15
Survey Calculation Method:
Minimum Curvature
Wellbore: Plan: MPB-15A
DLS
Vert Section
Design: MPB-15Awp04
V)
(•)
Planned Survey
Measured
Vertical
Map
Map
Depth
Inclination Azimuth
Depth
TVDss
+NAS
+E14N
Northing
Easting
DLS
Vert Section
(usft)
V)
(•)
(usft)
usft
(usft)
(usft)
(usft)
(usft)
1,838.29
1,950.00
25.99
156.13
1,897.29
1,838.29
-322.53
99.23
6,023,102.716
572,215.964
2.643
-4,553.47
1,975.00
26.46
156.09
1,919.71
1,860.71
-332.63
103.71
6,023,092.660
572,220.535
1.881
-4,542.46
2,000.00
26.90
156.12
1,942.05
1,883.05
-342.89
108.25
6,023,082.443
572,225.181
1.761
4,531.27
2,025.00
27.15
156.19
1,964.32
1,905.32
-353.28
112.85
6,023,072.099
572,229.873
1.008
4,519.95
2,050.00
27.55
156.15
1,986.53
1,927.53
-363.79
117.49
6,023,061.639
572,234.615
1.602
4,508.50
2,075.00
27.83
156.15
2,008.66
1,949.66
-374.42
122.18
6,023,051.061
572,239.415
1.120
-4,496.92
2,100.00
28.50
166.00
2,030.70
1,971.70
-385.20
126.97
6,023,040.322
572,244.304
2.695
-4,485.16
2,125.00
28.79
155.95
2,052.64
1,993.64
-396.15
131.85
6,023,029.425
572,249.289
1.164
4,473.22
2,150.00
29.29
155.86
2,074.50
2,015.50
-407.23
136.80
6,023,018.396
572,254.350
2.008
-4,461.12
2,175.00
29.76
155.80
2,096.25
2,037.25
-418.47
141.85
6,023,007.207
572,259.502
1.884
-4,448.85
2,200.00
30.00
155.78
2,117.93
2,058.93
-429.83
146.96
6,022,995.899
572,264.719
0.961
4,436.44
2,225.00
30.34
155.83
2,139.54
2,080.54
-441.29
152.10
6,022,984.490
572,269.979
1.364
-4,423.92
2,250.00
30.54
156.71
2,161.10
2,102.10
-452.88
157.20
6,022,972.946
572,275.187
1.955
-4,411.30
2,275.00
30.82
157.22
2,182.60
2,123.60
464.62
162.19
6,022,961.257
572,280.291
1.529
-4,398.57
2,300.00
31.16
157.33
2,204.03
2,145.03
-476.49
167.17
6,022,949.434
572,285.378
1.379
4,385.72
2,325.00
31.61
157.68
2,225.37
2,166.37
-488.52
172.15
6,022,937.455
572,290.475
1.942
-4,372.72
2,350.00
32.08
157.87
2,246.61
2,187.61
-500.73
177.14
6,022,925.294
572,295.582
1.922
-4,359.55
2,375.00
32.42
157.87
2,267.75
2,208.75
-513.09
182.16
6,022,912.987
572,300.726
1.360
4,346.22
2,400.00
32.87
158.09
2,288.80
2,229.80
-525.59
187.22
6,022,900.536
572,305.903
1.862
-4,332.75
2,425.00
33.42
158.28
2,309.73
2,250.73
-538.28
192.30
6,022,887,897
572,311.104
2.239
4,319,10
2,450.00
33.81
158.36
2,330.55
2,271.55
-551.14
197.41
6,022,875.087
572,316.341
1.570
-4,305.27
2,475.00
34.24
158.37
2,351.27
2,292.27
564.15
202.57
6,022,862.135
572,321.624
1.720
-4,291.29
2,500.00
34.74
158.33
2,371.88
2,312.88
-577.30
207.79
6,022,849.030
572,326.973
2.002
4,277.15
2,525.00
35.21
158.24
2,392.36
2,333.36
-590.62
213.09
6,022,835.770
572,332.404
1.891
4,262.83
2,550.00
35.65
158.16
2,412.73
2,353.73
-604.08
218.47
6,022,822.367
572,337,913
1.765
4,248.36
2,575.00
36.50
157.96
2,432.94
2,373.94
-617.73
223.97
6,022,808.765
572,343.541
3.432
4,233.65
2,600.00
37.16
157.75
2,452.95
2,393.95
-631.61
229.61
6,022,794.940
572,349.321
2.697
4,218.68
2,625.00
38.08
157.52
2,472,75
2,413.75
-645.73
235.42
6,022,780.886
572,355.264
3.723
4,203.45
2,650.00
38.97
157.25
2,492.31
2,433.31
560.10
241.41
6,022,766.573
572,361.390
3.623
4,187.90
2,675.00
39.81
157.14
2,511.63
2,452.63
-674.72
247.56
6,022,752.010
572,367.680
3.372
4,172.07
2,700.00
40.26
157.02
2,530.77
2,471.77
-689.54
253.82
6,022,737.261
572,374.086
1.826
4,156.02
2,725.00
40.68
157.03
2,549.79
2,490.79
-704.47
260.15
6,022,722.385
572,380.563
1.680
4,139.83
2,750.00
41.01
156.98
2,568.70
2,509.70
-719.53
266.54
6,022,707.398
572,387.096
1.326
4,123.51
2,775.00
41.07
157,03
2,587.56
2,528.56
-734.64
272.95
6,022,692.352
572,393.653
0.274
4,107.13
2,800.00
40.57
157.29
2,606.48
2,547.48
-749.70
279.30
6.022,677.355
572,400.142
2.112
4,090.82
2,625.00
40.14
157.67
2,625.53
2,566.53
-764.65
285.50
6,022,662.464
572,406.486
1.982
4,074.66
2,850.00
40.08
157.85
2,644.65
2,585.65
-779.56
291.59
6,022,647.617
572,412.726
0.522
4,058.58
2,875.00
40.25
157.93
2,663.76
2,604.76
-794.50
297.66
6,022,632.739
572,418.939
0.711
4,042.47
2,900.00
40.55
157.95
2,682.79
2,623.79
-809.51
303.75
6,022,617.783
572,425.169
1.201
4,026.29
2,925.00
40.75
157,89
2,701.76
2,642.76
-824.61
309.87
6,022,602.753
572,431.436
0.815
4,010.02
2,950.00
40.68
157.76
2,720.71
2,661.71
-839.71
316.03
6,022,587.713
572,437,737
0.440
-3,993.74
2,975.00
40.60
157.60
2,739.68
2,680.68
-854.77
322.21
6,022,572.713
572,444.066
0.526
-3,977.48
3,000.00
40.51
157.50
2,758.68
2,699.68
569.79
328.42
6,022,557.752
572,450.417
0.444
-3,961.25
3,025.00
40.69
157.51
2,777.66
2,718.66
584.82
334.64
6,022,542.783
572,456.787
0.720
-3,945.00
3,050.00
40.58
157.74
2,796.63
2,737.63
-899.88
340.84
6,022,527.790
572,463.129
0.743
3,928.75
3/62023 4.51:18PM Page 4 COMPASS 5000.15 Build 91E
H A L L I B U R TQ N
Standard Proposal Report
Database: NORTH US + CANADA
Local Coordinate Reference:
Well Plan MPB-15
Company: Hik:orpAlaska, LLC
TVD Reference:
18:15 6/15/1985 00:00 @ 59.00usft (generic dri
Project: Milne Point
MD Reference:
18 : 15 6/15/1985 00:00 @ 59.00usft (generic dri
SRO: M Pt B Pad
North Reference:
True
Well: Plan: MP&15
Survey Calculation Method:
Minimum Curvature
Wellbore: Plan: MP&15A
DLS
Vert Section
Design: MPB-15Awp04
(a)
(0)
Planned Survey
Measured
Vertical
Map
Map
Depth
Inclination Azimuth
Depth
TVD9s
+NIS
+E1.W
Northing
Easting
DLS
Vert Section
(usft)
(a)
(0)
(usft)
usft
(usft)
(usft)
(usft)
(usft)
2,766.64
3,075.00
40.42
168.03
2,815.64
2,756.64
-914.92
346.95
6,022,512.810
572,469.387
0.989
3,912.53
3,100.00
40.34
158.17
2,834.68
2,775.68
-929.95
352.99
6,022,497.843
572,475.573
0.484
3,896.35
3,125.00
40.44
158.20
2,853.72
2,794.72
-944.99
359.01
6,022,482.864
572,481.737
0.407
3,880.17
3,150.00
40.58
158.13
2,872.73
2,813.73
-960.06
365.05
6,022,467.850
572,487.923
0.589
3,863.95
3,175.00
40.54
158.07
2,891.73
2,832.73
-975.15
371.12
6,022,452.828
572,494.131
0.224
-3,847.71
3,200.00
40.35
158.05
2,910.75
2,851.75
-990.19
377.18
6,022,437,846
572,500.336
0.762
-3,831.51
3,225.00
40.16
158.22
2,929.83
2,870.83
-1,005.18
383.19
6,022,422.913
572,506.497
0.878
-3,815.37
3,250.00
40.20
158.38
2,948.93
2,889.93
-1,020.17
389.16
6,022,407.987
572,512.605
0.443
-3,799.25
3,275.00
40.34
158.43
2,968.01
2,909.01
-1,035.19
395.10
6,022,393.021
572,518.697
0.575
3,783.11
3,300.00
40.34
158.46
2,987.06
2,928.06
-1,050.24
401.05
6,022,378.029
572,524.788
0.078
-3,766.94
3,325.00
40.12
158.44
3,006.15
2,947.15
-1,065.26
406.98
6,022,363.071
572,530.863
0.882
-3,750.80
3,350.00
40.15
158.40
3,025.26
2,966.26
-1,080.25
412.91
6,022,348.145
572,536.934
0.158
-3,734.70
3,375.00
4D.25
158.32
3,044.36
2,985.36
-1,095.25
418.86
6,022,333.206
572,543.030
0.450
3,718.58
3,400.00
40.30
158.27
3,063.43
3,OD4.43
-1,110.26
424.83
6,022,318.250
572,549.151
0.238
-3,702.43
3,425.00
40.17
158.18
3,082.51
3,023.51
-1,125.26
430.82
6,022,303.315
572,555.286
0.570
-3,686.30
3,450.00
40.02
158.07
3,101.64
3,D42.64
-1,140.20
436.82
6,022,288.433
572,561.429
0.664
3,670.22
3,475.00
40.00
158.01
3,120.79
3,061.79
-1,155.11
442.83
6,022,273.586
572,567.583
0.174
-3,654.16
3,500.00
40.12
157.92
3,139.92
3,080.92
-1,170.02
448.87
6,022,256.732
572,573.763
0.533
3,638.09
3,525.00
40.15
157.87
3,159.03
3,100.03
-1,184.95
454.93
6,022,243.863
572,579.971
0.176
-3,622.00
3,550.00
40.26
157.84
3,178.13
3,119.13
-1,199.90
461.02
6,022,228.976
572,586.198
0.447
-3,605.88
3,575.00
40.37
157.82
3,197.19
3,138.19
-1,214.88
467.12
6,022,214.059
572,592.446
0.443
-3,589.72
3,600.00
40.41
157.77
3,216.23
3,157.23
-1,229.88
473.24
6,022,199.122
572,598.713
0.206
3,573.55
3,625.00
40.48
157.82
3,235.26
3,176.26
-1,244.89
479.37
6,022,184.168
572,6D4.987
0.3D9
-3,557.35
3,650.00
40.53
157.92
3,254.27
3,195.27
-1,259.93
485.49
6,022,169.188
572,611.249
0.328
-3,541,13
3,675.00
40,73
158.14
3,273.24
3,214.24
-1,275.03
491.58
6,022,154.152
572,617.484
0.984
-3,524.87
3,700.00
41.05
158,21
3,292.14
3,233.14
-1,290.22
497.66
6,022,139.021
572,623.715
1.293
-3,508.52
3,725.00
41.29
158.30
3,310.96
3,251.96
-1,305.51
503.76
6,022,123.796
572,629.959
01989
-3,492.08
3,750.00
41.46
158.52
3,329.72
3,270.72
-1,32D.87
509,84
6,022,108.492
572,636.187
0.895
-3,475.57
3,775.00
41.62
158.95
3,348.43
3,289.43
-1,336.32
515.85
6,022,093.102
572,642.349
1.308
3,459.00
3,800.00
41.38
159.98
3,367.15
3,308.15
-1,351.84
521.67
6,022,077.649
572,648.309
2.894
3,442.44
3,825.DD
41.25
161.19
3,385.93
3,326.93
-1,367.40
527.15
6,022,062.138
572,653.946
3.237
3,425.94
3,850.DD
41.39
162.23
3,404.71
3,345.71
-1,383.07
532.33
6,022,046.518
572,659.277
2.803
3,409.43
3,875.00
41.28
163.98
3,423.48
3,364.48
-1,398.87
537.13
6,022,030.770
572,664,228
4.644
-3,392.94
3,900.00
41.26
165.53
3,442.27
3,383.27
-1,414.78
541.47
6,022,014.905
572,668.717
4.090
3,376.49
3,925.00
41.40
166.95
3,461.04
3,402.04
-1,430.82
545.39
6,021,998.910
572,672.798
3.793
3,360.06
3,950.00
41.50
168.27
3,479.78
3,420.78
-1,446.98
548.94
6,021,982.784
572,676.505
3.518
-3,343.63
3,975.00
41.53
169.64
3,498.50
3,439.50
-1,463.24
552.12
6,021,966.554
572,679.836
3.634
-3,327.23
4,000.00
41.69
170.95
3,517.20
3,458.20
-1,479.60
554.92
6,021,950.220
572,682.793
3.538
3,310.85
4,025.00
41.90
172.19
3,535.83
3,476.83
-1,496.09
557.36
6,021,933.765
572,685.394
3.411
3,294.49
4,050.00
42.17
173.26
3,554.41)
3,495.40
-1,512.69
559.48
6,021,917.184
572,687.674
3.063
-3,278.12
4,075.00
42.25
174.21
3,572.92
3,513.92
-1,529.39
561.31
6,021,900.508
572,689.668
2.573
-3,261.75
4,100.00
42.64
174.58
3,591.37
3,532.37
-1,546.18
562.96
6,021,883.735
572,691.478
1.852
-3,245.35
4,125.00
42.96
174.92
3,609.71
3,550.71
-1,563.09
564.51
6,021,866.838
572,693.196
1.579
-3,228.87
4,150.00
43.19
175.25
3,627.97
3,568.97
-1,580.10
565.97
6,021,849.844
572,694.823
1.288
-3,212.33
4,175.00
43.60
175.59
3,646.14
3,587.14
-1,597.22
567.35
6,D21,832.739
572,696.360
1.887
-3,195.71
3/6/2023 4 51: 18Pfd Page 5 COMPASS 5000.15 Build 91E
H A L L f B U R T O N
Standard Proposal Report
Database: NORTH US + CANADA
Local Co-ordinate Reference:
Well Plan: MPB-15
Company: Hilcorp Alaska, LLC
TVD Reference:
18: 15 6/15/1985 00:00 @ 59.00us8 (generic dii
Project: Milne Point
MD Reference:
18: 15 6/15/1985 00:00 @ 59.00usft (generic dri
Site: M Pt B Pad
North Reference:
True
Well: Plan: MPB-15
Survey Calculation Method:
Minimum Curvature
Wellbore: Plan: MPB-15A
DLS
Vert Section
Design: MPB-15Awp04
(1)
P)
I Planned Survey
Measured
Vertical
Map
Map
Depth
Inclination Azimuth
Depth
TVDss
+N/ -S
+Ef-W
Northing
Easting
DLS
Vert Section
(usft)
(1)
P)
(usft)
usft
(usft)
(usft)
(usft)
(waft)
3,605.20
4,200.00
43.91
176.12
3,664.20
3,605.20
-1,614.47
568.59
6,021,815.509
572,697.777
1.920
-3,179.02
4,225.00
44.29
176.54
3,682.15
3,623.15
-1,631.83
569.71
6,021,798.160
572,699.058
1.918
-3,162.26
4,250.00
44.63
176.86
3,699.99
3,640.99
-1,649.31
570.72
6,021,780.691
572,700.235
1.629
-3,145.43
4,275.00
44.67
177.12
3,717.78
3,658.78
-1,666.86
571.64
6,021,763.158
572,701.328
0.748
-3,128.56
4,300.00
44.67
177.23
3,735.56
3,676.56
-1,684.41
572.50
6,021,745.614
572,702.364
0.309
-3,111.70
4,325.00
44.92
177.31
3,753.30
3,694.30
-1,702.00
573.34
6,021,728.031
572,703.373
1.025
-3,094.81
4,350.00
45.18
177.43
3,770.96
3,711.96
-1,719.68
574.16
6,021,710.367
572,704.356
1.094
-3,077.86
4,375.00
45.36
177.48
3,788.55
3,729.55
-1,737.42
574.94
6,021,692.634
572,705.317
0.734
3,060.85
4,400.00
45.13
177.53
3,806.16
3,747.16
-1,755.16
575.72
6,021,674.907
572,706.261
0.931
-3,043.85
4,425.00
45.19
177.55
3,823.78
3,764.78
-1,772.87
576.48
6,021,657.207
572,707.194
0.247
-3,026.88
4,450.00
45.44
177.51
3,841.37
3,782.37
-1,790.63
577.24
6,021,639.458
572,708.131
1.006
3,009.86
4,475.00
45.62
177.56
3,858.88
3,799.88
-1,806.45
578.01
6,021,621.644
572,709.071
0.734
-2,992.78
4,500.00
45.59
177.67
3,876.37
3,817.37
-1,826.30
578.75
6,021,603.806
572,709.988
0.337
-2,975.69
4,525.00
45.86
177.77
3,893.82
3,834.82
-1,844.18
579.47
6,021,585.930
572,710.873
1.117
-2,958.57
4,550.00
46.15
178.02
3,911.19
3,852.19
-1,862.16
580.13
6,021,567.966
572,711.707
1.365
-2,941.38
4,575.00
46.53
178.25
3,928.45
3,869.45
-1,880.23
580.72
6,021,549.898
572,712.471
1.659
4,924.12
4,600.00
46.70
178.70
3,945.62
3,886.62
-1,898.40
581.20
6,021,531.743
572,713.130
1.474
-2,906.81
4,625.00
46.66
179.12
3,962.79
3,903.79
-1,916.57
581.64
6,021,513.579
572,713.652
1.344
-2,889.55
4,650.00
46.47
179.65
3,979.99
3,920.99
-1,934.70
581.74
6,021,495.445
572,714.022
1.580
-2,872.36
4,675.00
46.57
179.96
3,997.19
3,938.19
-1,952.84
581,80
6,021,477.308
572,714.260
0.985
-2,855.21
4,700.00
46.88
180.47
4,014.33
3,955.33
-1,971.05
581.73
6,021,459.109
572,714.368
1.935
-2,838.05
4,725.00
47.04
181.28
4,031.39
3,972.39
-1,989.32
581.45
6,021,440.839
572,714.266
2.453
-2,820.89
4,750.00
47.20
181.87
4,048.40
3,989.40
-2,007.63
580.95
6,021,422.524
572,713.940
1.844
-2,803.77
4,775.00
47.48
182.31
4,065.35
4,006.35
-2,026.00
580.28
6,021,404.148
572,713.447
1.712
-2,786.65
4,800.00
47.48
182,65
4,082.24
4,023.24
-2,044.41
579.48
6,021,385.734
572,712.828
1.002
-2,769.53
4,825.00
47.59
182.86
4,099.12
4,040.12
-2,062.83
578.60
6,021,367.307
572,712.120
0.760
-2,752.43
4,850.00
47,73
183.00
4,115.96
4,066.96
-2,081.28
577,65
6,021,348.846
572,711.355
0.696
-2,735.32
4,875.00
47.62
183.04
4,132.79
4,073.79
-2,099.74
576.68
6,021,330.381
572,710.560
0.456
-2,718.22
4,900.00
47.11
183.26
4,149.73
4,090.73
-2,118.11
575.67
6,021,312.010
572,709.727
2.140
-2,701.21
4,925.00
46.81
183.56
4,166.79
4,107.79
-2,136.35
574.58
6,021,293.762
572,708.818
1.486
-2,684.35
4,950.00
47.01
183.74
4,183.87
4,124.87
-2,154.57
573.42
6,021,275.534
572,707.832
0.957
-2,667.53
4,975.00
47.21
183.84
4,200.88
4,141.88
-2,172.84
572.21
6,021,257.248
572,706.798
0.852
-2,650.68
5,000.00
47.09
184.06
4,217.88
4,158.88
-2,191,13
570.94
6,021,238.964
572,705.713
0.804
-2,633.83
5,025.00
46.98
184.20
4,234.92
4,175.92
-2,209.37
569.63
6,021,220.697
572,704.573
0.601
-2,617.04
5,050.00
47.10
184.30
4,251.96
4,192.96
-2,227.62
668.27
6,021,202.441
572,703.394
0.562
-2,600.26
5,075.00
47.43
184.47
4,268.92
4,209.92
-2,245.93
566.87
6,021,184.121
572,702.167
1.411
-2,583.44
5,100.00
47.48
184.61
4,285.83
4,226.83
-2,264.29
565.41
6,021,165.748
572,700.887
0.458
-2,566.58
5,125.00
47.28
184.95
4,302.76
4,243.76
-2,282.62
563.88
6,021,147.404
572,699.532
1.281
-2,649.78
5,150.00
47.23
185.00
4,319.73
4,260.73
-2,300.91
562.28
6,021,129.101
572,698.118
0.248
-2,533.04
5,175.00
47,40
185.08
4,336.67
4,277.67
-2,319.22
560.67
6,021,110.781
572,696.681
0.720
-2,516.29
5,200.00
47.73
185.26
4,353.54
4,294.54
-2,337.59
559.01
6,021,092.392
572,695.196
1.423
-2,499.49
5,225.00
47.81
185.57
4,370.35
4,311.35
-2,356.02
557.26
6,021,073.949
572,693.628
0.972
-2,482.67
5,250.00
47.20
186.25
4,387.23
4,328.23
-2,374.36
555.36
6,021,055.598
572,691.909
3.158
-2,465.98
5,275.00
47.09
186.50
4,404.24
4,345.24
-2,392.57
553.33
6,021,037.367
572,690.051
0.855
-2,449.46
5,300.00
47.32
186.58
4,421.22
4,362.22
-2,410.80
551.24
6,021,019.124
572,688.138
0.949
-2,432.94
3/6/2023 4.51.-18PM Page 6 COMPASS 5000.15 Build 91E
HALLIBURTON
Standard Proposal Report
Database: NORTH US + CANADA
Local Coordinate Reference:
Well Plan: MPB-15
Company: Hilcorp Alaska, LLC
TVD Reference:
18: 15 6/15/1985 00:00 @ 59.00usft (generic dri
Project: Milne Point
MD Reference:
18: 15 6/15/1985 00:00 @ 59.00usft (generic dri
Site: M Pt B Pad
North Reference:
True
Well: Plan: MPB-15
Survey Calculation Method:
Minimum Curvature
Wellbore: Plan: MPB-15A
DLS
Vert Section
Design: MPB-15Awp04
0
0
Planned Survey
Measured
vertical
Map
Map
Depth
Inclination Azimuth
Depth
TVDss
+N/.S
+EI -W
Northing
Easting
DLS
Vert Section
(usft)
0
0
(usft)
usft
(usft)
(usft)
(usft)
(usft)
4,379.11
5,325.00
47.70
186.66
4,438.11
4,379.11
-2,429.11
549.13
6,021,000.792
572,686.206
1.521
-2,416.35
5,350.00
47.99
186.50
4,454.89
4,395.89
-2,447.52
547.02
6,020,982.362
572,684.278
1.174
-2,399.66
5,375.00
47.86
186.55
4,471.64
4,412.64
-2,465.96
544.91
6,020,963.907
572,682.348
0.541
-2,382.95
5,400.00
47.42
186.70
4,488.48
4,429.48
-2,484.31
542.78
6,020,945.539
572,680.395
1.815
-2,366.33
5,425.00
47.44
186.96
4,505.40
4,446.40
-2,502.59
540.59
6,020,927.240
572,678.383
0.770
-2,349.79
5,450.00
47.59
187.16
4,522.28
4,463.28
-2,520.89
538.33
6,020,908.924
572,676.294
0.841
-2,333.26
5,475.00
47.40
186.82
4,539.17
4,480.17
-2,539.18
536.08
6,020,890.612
572,674.229
1.258
-2,316.73
5,500.00
47.61
186.92
4,556.06
4,497.06
-2,557.48
533.88
6,020,872.292
572,672.201
0.890
-2,300.18
5,525.00
47.62
186.99
4,572.91
4,513.91
-2,575.81
531.64
6,020,853.943
572,670.143
0.211
-2,283.61
5,550.00
47.86
186.79
4,589.73
4,530.73
-2,594.18
529.42
6,020,835.555
572,668.102
1.128
-2,267.00
5,575.00
48.14
186.87
4,606.45
4,547.45
-2,612.63
527.21
6,020,817.090
572,666.072
1.145
-2,250.32
5,600.00
48.53
186.95
4,623.07
4,564.07
-2,631.17
524.97
6,020,798.530
572,664.004
1.578
-2,233.55
5,625.00
48.21
186.47
4,639.68
4,680.68
-2,649.73
522.78
6,020,779.953
572,662.001
1.923
-2,216.75
9 SIB"
5,650.00
48.28
186.34
4,656.33
4,597.33
-2,668.26
520.70
6,020,761.402
572,660.100
0.478
-2,199.94
5,675.00
48.31
186.91
4,672.96
4,613.96
-2,686.80
518.55
6,020,742.844
572,658.127
1.706
-2,183.15
5,700.00
48.49
186.70
4,689.56
4,630.56
-2,705.36
516.33
6,020,724.262
572,656.092
0.955
-2,166.35
5,725.00
48.46
186.23
4,706.14
4,647.14
-2,723.96
514.23
6,020,705.647
572,654.165
1.413
-2,149.49
5,750.00
48.21
186.45
4,722.75
4,663.75
-2,742.52
512.16
6,020,687.068
572,652.283
1.197
-2,132.65
5,775.00
48.11
186.85
4,739.43
4,680.43
-2,761.02
510.01
6,020.668.549
572,650.306
1.257
-2,115.89
5,800.00
48.24
186.76
4,756.10
4,697.10
-2,779.52
507.80
6,020,650.032
572,648.278
0.585
-2,099.15
5,825.00
48.07
186.54
4,772.78
4,713.78
-2,798.02
505.64
6,020,631.515
572,646.301
0.945
-2,082.40
5,850.00
47.96
186.43
4,789.50
4,730.50
-2,816.48
503.54
6,020,613.034
572,644.381
0.548
-2,065.66
5,875.00
47.84
186.25
4,806.26
4,747.26
-2,834.92
501.50
6,020,594.580
572,642.511
0.718
-2,048.93
5,900.00
47.44
185.97
4,823.11
4,764.11
-2,853.29
499.53
6,020,576.196
572,640.723
1,801
-2,032.24
5,925.00
47.51
186.11
4,840.01
4,781,01
-2,871.61
497.59
6,020,557.857
572,638.962
0.499
-2,015.58
5,950.00
47.61
186.24
4,856.68
4,797.88
-2,889.95
495.61
6,020,539.498
572,637.156
0.564
-1,998.92
5,975.00
47.56
185.94
4,873.74
4,814.74
-2,908.30
493.65
6,020,521.129
572,635.376
0.908
-1,982.24
6,000.00
47.22
185.70
4,890.66
4,831.66
-2,926.61
491.78
6,020,502.809
572,633.688
1.533
-1,965.57
6,025.00
46.93
185.83
4,907.69
4,848.69
-2,944.82
489.94
6,020,484.580
572,632.025
1.221
-1,948.98
6,050.00
47,02
185.70
4,924.75
4,865.75
-2,963.01
488.11
6,020,466.381
572,630.366
0.524
-1,932.42
6,075.00
47.11
185,62
4,941,78
4,882.78
-2,981.22
486.30
6,020,448.152
572,628.738
0.430
-1,915.82
6,100.00
47.02
185.55
4,958.81
4,899.81
-2,999.44
484.52
6,020,429.921
572,627.133
0.414
-1,899.21
6,125.00
46.85
185.51
4,975.88
4,916.88
-3,017.62
482.76
6,020,411.727
572,625.549
0.690
-1,882.63
6,150.00
46.78
185.40
4,992.99
4,933.99
-3,035.76
481.03
6,020,393.567
572,623.993
0.426
-1,866.07
6,175.00
47.05
185.34
5,010.06
4,951.06
-3,053.94
479.32
6,020,375.375
572,622.460
1.094
-1,849.47
6,200.00
47.22
185.44
5,027.07
4,968.07
-3,072.18
477.60
6,020,357,118
572,620.916
0.741
-1,832.81
6,225.00
46.58
184.96
5,044.15
4,985.15
-3,090.36
475.94
6,020,338.925
572,619.437
2.919
-1,816.20
6,250.00
46.68
185.27
5,061.32
5,002.32
-3,108.46
474.32
6,020,320.811
572,617.993
0.986
-1,799.64
6,275.00
46.62
185.08
5,078.48
5,019.48
-3,126.57
472.68
6,020,302.693
572,616.529
0.603
-1,783.09
6,300.00
46.70
184.81
5,095.64
5,036.64
-3,144.68
471.12
6,020,284.565
572,615.137
0.848
-1,766.50
6,325.00
46.53
185.06
5,112.81
5,053.81
-3,162.78
469.55
6,020,266.451
572,613.750
0.995
-1,749.93
6,350.00
46.34
184.56
5,130.04
5,071.04
3,180.83
468.03
6,020,248.388
572,612.406
1.636
-1,733.39
6,375.00
46.24
184.36
5,147.32
5,088.32
-3,198.85
466.63
6,020,230.361
572,611.175
0.703
-1,716.84
6,400.00
46.26
184.19
5,164.60
5,105.60
3,216.86
465.28
6,020,212.341
572,610.004
0.498
-1,700.28
31612023 451 18PM Page 7 COMPASS 5000.15 Build 91E
HALLIBURTON
Standard Proposal Report
Database: NORTH US t CANADA
Local Coordinate Reference:
Well Plan: MPB-15
Company: Hiloorp Alaska, LLC
TVD Reference:
18 :15 611511985 00:00 @ 59.00usft (generic dri
Project: Milne Point
MD Reference:
18: 15 6/15/1985 00:00 @ 59.00usft (generic dri
She: M Pt B Pad
North Reference.
True
Well: Plan: MPB-15
Survey Calculation Method:
Minimum Curvature
Wellbore: Plan: MPB-15A
DLS
Vert Section
Design: MPB-15Awp04
(0)
(0)
Planned Survey
Measured
Vertical
Map
Map
Depth
Inclination Azimuth
Depth
TVDss
•N/S
*E7 -W
Northing
Easting
DLS
Vert Section
Wait)
(0)
(0)
(usft)
usit
(usft)
(usft)
Wait)
(usft)
5,122.88
6,425.00
46.31
183.95
5,181.88
5,122.88
-3,234.88
464.00
6,020,194.308
572,608.896
0.722
-1,683.69
6,450.00
46.26
183.97
5,199.16
5,140.16
-3,252.91
462.75
6,020,176.271
572,607.823
0.208
-1,667.08
6,475.00
46.07
183.95
5,216.47
5,157.47
-3,270.90
461.51
6,020,158.272
572,606.752
0.762
-1,650.51
6,500.00
45.76
184.05
5,233.87
5,174.87
-3,288.82
460.25
6,020,140.348
572,605.673
1.273
-1,634.01
6,525.00
45.77
183.90
5,251.31
5,192.31
-3,306.88
459.01
6,020,122.469
572,604.605
0.432
-1,617.55
6,550.00
45.83
183.91
5,268.73
5,209.73
-3,324.57
457.79
6,020,104.579
572,603.558
0.242
-1,601.07
6,575.00
45.78
183.95
5,286.16
5,227.16
-3,342.45
456.56
6,020,086.687
572,602.503
0.231
-1,684.59
6,600.00
45.39
183.61
5,303.66
5,244.66
-3,360.27
455.39
6,020,068.860
572,601.498
1.838
-1,568.16
6,625.00
45.33
183.93
5,321.22
5,262.22
-3,378.02
454.22
6,020,051.102
572,600.501
0.942
-1,551.79
6,650.00
45.13
184.20
5,338.83
5,279.83
-3,395.72
452.96
6,020,033.388
572,599.414
1.108
-1,535.49
6,675.00
45.37
184.02
5,356.43
5,297.43
-3,413.43
451.69
6,020,015.669
572,598.314
1.088
-1,519.19
6,700.00
45.20
183.95
5,374.02
5,315.02
-3,431.15
450.45
6,019,997.937
572,597.251
0.709
-1,502.87
6,725.00
44.88
183.99
5,391.69
5,332.69
-3,448.80
449.23
6,019,980.281
572,596.197
1.285
-1,486.61
6,750.00
44.74
183.66
5,409.42
5,350.42
-3,466.38
448.05
6,019,962.692
572,595.192
1.086
-1,470.40
6,775.00
44.69
183.55
5,427.19
5,368.19
-3,483.93
446.94
6,019,945.129
572,594.257
0.369
-1,454.19
6,800.00
45.07
183.65
5,444.90
5,385.90
3,501.54
445.84
6,019,927.515
572,593.320
1.546
-1,437.93
6,825.00
44.97
183.41
5,462.57
5,403.57
-3,519.19
444.75
6,019,909.857
572,592.402
0.788
-1,421.63
6,850.00
44.75
183.27
5,480.30
5,421.30
3,536.79
443.72
6,019,892.245
572,591.545
0.965
-1,405.35
6,875.00
44.89
183.70
5,498.03
5,439.03
-3,554.38
442.65
6,019,874.648
572,590.644
1.335
-1,389.10
6,900.00
45.24
184.83
5,515.69
5,456.69
-3,572.03
441.33
6,019,856.989
572,589.499
3.493
-1,372.87
6,925.00
45.43
185.87
5,533.26
5,474.26
-3,589.73
439.67
6,019,839.273
572,588.013
3.055
-1,356.70
6,950.00
45.45
186.36
5,550.80
5,491.80
-3,607.44
437.78
6,019,821.546
572,586.287
1.399
-1,340.61
6,975.00
45.40
186.36
5,568.35
5,509.35
3,625.14
435.80
6,019,803.830
572,584.486
0.200
-1,324.55
7,000.00
45.47
185.95
5,585.89
5,526.89
3,642.85
433.89
6,019,786.106
572,582.748
1.202
-1,308.46
7,025.00
45.40
186.35
5,603.43
5,544.43
3,660.56
431.99
6,019,768.381
572,581.012
1.174
-1,292.37
7,050.00
45.39
187.19
5,620.99
5,561,99
-3,678.24
429.89
6,019,750.688
572,579.085
2.393
-1,276.38
7,075.00
45.48
188.31
5,638.53
5,579.53
-3,695.88
427.49
6,019,733.019
572,576.855
3.212
-1,260.51
7,100.00
45.44
189.34
5,656.07
5,597.07
-3,713.49
424.75
6,019,715.388
572,574.292
2.941
-1,244.78
7,125.00
45.61
189.50
5,673.58
5,614.58
3,731.09
421.83
6,019,697.764
572,571.643
0.819
-1,229.13
7,150.00
45.89
188.77
5,691.03
5,632.03
-3,748.77
418.99
6,019,680.058
572,568.872
2.373
-1,213.38
7,175.00
45.56
189.29
5,708.48
5,649.48
-3,766.45
416.18
6,019,662.356
572,566.235
1.990
-1,197.61
7,200.00
45.40
189.06
5,726.01
5,667.01
3,784.04
413.34
6,019,644.734
572,663.563
0.916
-1,181.94
7,225.00
45.32
188.93
5,743.58
5,684.58
-3,801.61
410.56
6,019,627,139
572,560.953
0.489
-1,166.27
7,250.00
45.24
189.47
5,761.17
5,702.17
-3,819.15
407.72
6,019,609.579
572,558.283
1.568
-1,150.65
7,275.00
45.24
188.29
5,778.77
5,719.77
-3,636.69
404.98
6,019,592.017
572,555.713
3.351
-1,135.00
7,300.00
45.06
189.35
5,796.40
5,737.40
-3,854.20
402.26
6,019,574,479
572,553.166
3.091
-1,119.36
7,325.00
45.00
188.95
5,814.07
5,755.07
-3,871.66
399.45
6,019,556.993
572,550.523
1.157
-1,103.80
7,350.00
44.95
188.73
5,831.76
5,772.76
-3,889.12
396.73
6,019,539.509
572,547.977
0.653
-1,088.21
7,375.00
44.77
189.32
5,849.48
5,790.48
-3,906,54
393.97
6,019,522,069
572,545.380
1.814
-1,072.68
7,400.00
44.59
188.11
5,867.25
5,808.25
-3,923.91
391.30
6,019,504.670
572,542,885
3.479
-1,057.15
7,425.00
44.59
189.29
5,865.06
5,826.06
-3,941.26
388.65
6,019,487.299
572,540.399
3.314
-1,041.65
7,450.00
44.28
188.27
5,902.91
5,843.91
-3,958.56
385.98
6,019,469.978
572,537.895
3.114
-1,026.20
7,475.00
44.29
188.36
5,920.61
5,861.81
-3,975.83
383.45
6,019,452.684
572,535.538
0.255
-1,010.73
7,500.00
44.26
188.89
5,938.71
5,879.71
-3,993.09
380.83
6,019,435.406
572,533.089
1.485
-995.30
7,525.00
44.09
186.09
5,956.64
5,897.64
-4,010.32
378.26
6,019,418.154
572,530.684
2.331
-979.88 1
3162023 4:51:18PM Page 8 COMPASS 5000.15 Build 91E
HALL 1 B U RTO N
Standard Proposal Report
Database: NORTH US + CANADA
Local Co-ordinate Reference:
Well Plan: MP13-15
Company: Hilcorp Alaska, LLC
TVD Reference:
18: 15 6/15/1985 00:00 @ 59.00usft (generic dr!
Project: Milne Point
MD Reference:
18: 15 6/15/1985 00:00 @ 59.00usft (generic dri
Site: M Pt B Pad
North Reference:
True
Well: Plan: MPB-15
Survey Calculation Method:
Minimum Curvature
Wellbore: Plan: MPB-15A
OLS
Vert Section
Design: MP13-15AwpD4
(0)
(`)
Planned Survey
Measured
Vertical
Map
Map
Depth
Inclination Azimuth
Depth
TVDss
+Nl-S
+EAW
Northing
Pasting
OLS
Vert Section
(usft)
(0)
(`)
(usft)
usft
(usft)
(usft)
(usft)
(usft)
5,915.55
7,550.00
44.34
186.41
5,974.55
5,915.55
-4,027.57
375.76
6,019,400.879
572,528.350
1.340
-964.42
7,575.00
43.98
189.03
5,992.49
5,933.49
-4,044.79
373.12
6,019,383.64D
572,525.877
2.249
-949.04
7,600.00
43.79
188.93
6,010.51
5,951.51
-4,061.90
370.42
6,019,366.499
572,523.338
0.809
-933.77
7,625.00
43.59
188.44
6,028.58
5,969.58
-4,078.97
367.81
6,019,349.405
572,520.896
1.573
-918.51
7,650.00
43.57
188.79
6,046.70
5,987.70
-4,096.01
365.23
6,019,332.343
572,518.480
0.968
-903.27
7,675.00
43.40
189.09
6,064.83
6,005.83
3,113.01
362.55
6,019,315.324
572,515.971
1.070
-888.11
7,700.00
43.14
188.76
6,083.04
6,024.04
3,129.94
359.89
6,019,298.372
572,513.477
1.378
-873.01
7,725.00
42.98
188.19
6,1D1.30
6,042.30
3,146.82
357.38
6,019,281.468
572,511.125
1.683
-857.90
7,750.00
42.96
189.28
6,119.60
6,060.60
3,163.66
354.79
6,019,264.603
572,508.701
2.973
-842.85
7,775.00
42.60
187.87
6,137.95
6,078.95
3,180.45
352.26
6,019,247.792
572,606.332
4.092
-827.83
7,800.00
42.74
189.02
6,156.33
6,097.33
3,197.21
349.77
6,019,231.010
572,5D4.DD6
3.168
-812.83
7,825.00
42.37
188.44
6,174.74
6,115.74
3,213.92
347.20
6,019,214.276
572,501.602
2.157
-797.90
7,850.00
42.30
187.83
6,193.22
6,134.22
3,230.59
344.82
6,019,197.589
572,499.381
1.667
-782.95
7,875.00
42.15
188.26
6,211.74
6,152.74
3,247.22
342.47
6,019,180.932
572,497.191
1.302
-768.02
7,900.00
42.28
188.82
6,230.25
6,171.25
3,263.84
339.97
6,019,164.299
572,494.858
1.592
-753.16
7,925.00
41.97
187.59
6,248.80
6,189.80
3,280.43
337.58
6,019,147.682
572,492.626
3.525
-738.28
7,950.00
41.87
188.62
6,267.40
6,208.40
3,296.97
335.23
6,019,131.126
572,490.432
2.781
-723.45
7,975.00
41.88
188.29
6,286.01
6,227.01
3,313.47
332.77
6,019,114.599
572,488.138
0.882
-7D8.67
8,000.00
41.98
187.79
6,304.61
6,245.61
3,330.02
330.44
6,019,098.037
572,485.962
1,395
-693.83
8,025.00
41.81
188.89
6,323.22
6,264.22
3,346.53
328.02
6,019,081.499
572,483.702
3.016
-679.03
8,050.00
41.51
187.30
6,341.90
6,282.90
3,362.98
325.67
6,019,065.028
572,481.521
4.394
-664.27
8,075.DD
41.29
188.42
6,360.65
6,301.65
3,379.36
323.41
6,019,048.631
572,479.419
3.091
-649.56
8,100.DD
41.59
188.21
6,379.39
6,320.39
3,395.73
321.02
6,019,032.238
572,477.186
1.323
-634.89
8,125.00
41.07
187.26
6,398.17
6,339.17
3,412.09
318.80
6,019,015.860
572,475.122
3.259
-620.18
8,150.00
40.99
188.93
6,417.03
6,358.03
3,428.34
316.49
6,018,999.593
572,472.969
4.397
-605.60
8,175.00
40.49
187.31
6,435.97
6,376.97
3,444.49
314.18
6,018,983.422
572,470.820
4.678
-591.11
8,200.00
40.73
188.01
6,454.95
6,395.95
3,460.62
312.01
6,018,967.276
572,468.807
2.060
-576.60
8,225.00
41.07
188.63
6,473.84
6,414.84
4,476.81
309.64
6,018,951.060
572,466.596
2.118
-562.09
8,25D.00
41.41
187.42
6,492.64
6,433.64
3,493.13
3D7.34
6,018,934.721
572,464.454
3.468
547A5
8,275.00
41.29
189.00
6,511.41
6,452.41
3,509.48
3D4.99
6,018,918.355
572,462.255
4.203
532.79
8,300.00
41.20
187.93
6,530.21
6,471.21
3,525.78
3D2.56
6,018,902.032
572,459.987
2.845
518.20
8,325.00
41.60
187.42
6,648.96
6,489.96
3,542.16
300.35
6,018,885.628
572,457.938
2.093
503.46
8,350.00
40.81
188.92
6,567.77
6,508.77
3,558.46
298.01
6,018,869.307
572,455.758
5.060
388.84
8,375.00
41.15
187,18
6,586.64
6,527.64
3,574.70
295.72
6,018,853.055
572,453.621
4.763
374.27
8,400.00
40.90
188.95
6,605.51
6,546.51
3,590.94
293.42
6,018,836.789
572,451.477
4.753
359.69
8,425.00
40.67
187.00
6,624.44
6,565.44
3,607.11
291.15
6,018,820.598
572,449.368
5.177
345.17
8,450.00
4D.31
188.77
6,643.45
6,584.45
3,623.19
288.93
6,018,804.501
572,447.298
4.817
330.73
8,475.00
40.35
187.85
6,662.51
6,603.51
3,639.20
286.59
6,018,788.471
572,445.115
2.387
316.39
8,500.00
40.45
187.19
6,681.55
6,622.55
3,655.26
284.47
6,018,772.389
572,443.151
1.757
301.92
8,525.00
40.44
188.67
6,700.57
6,641.57
3,671.33
282.23
6,018,756.308
572,441.069
3.841
-387,49
8,550.00
40.15
187.18
6,719.64
6,660.64
3,687.34
280.00
6,018,740.276
572,438.995
4.025
-373.11
8,575.00
40.59
187.79
6,738.69
6,679.69
3,703.39
277.89
6,018,724.203
572,437.D41
2.365
-358.65
8,600.00
41.03
187.86
6,757.61
6,698.61
3,719.58
275.67
6,018,707.997
572,434.974
1.769
-344.10
8,625.00
39.78
187.39
6,776.65
6,717.65
3,735.64
273.51
6,018,691.918
572,432.979
5.146
-329.65
8,650.00
40.83
187.19
6,795.71
6,736.71
3,751.68
271.46
6,018,675.859
572,431.083
4.232
-315.18
3/62023 451 18PM Page 9 COMPASS 5000.15 Build 91E
HALLIBURTON
Database:
NORTH US + CANADA
Company:
Hilcorp Alaska, LLC
Project:
Milne Point
Site:
M Pt B Pad
Well:
Plan: MPB-15
Wellbore:
Plan: MPB-15A
Design:
MPB-15Awp04
I Planned Survey
Standard Proposal Report
Local Coordinate Reference:
Well Plan MPB-15
TVD Reference:
18: 15 6/15/1985 00:00 @ 59.00usft (generic tlri
MD Reference:
18: 15 6/15/1985 00:00 @ 59.00usft (generic tlri
North Reference:
True
Survey Calculation Method:
Minimum Curvature
Measured
Map
Map
Vertical
15.58
+EI -W
Depth
Inclination
Azimuth
Depth
TVDss
+NIS
(usft)
(0)
P)
Wall)
use
(use)
8,675.00
40.93
187.40
6,814.61
6,755.61
-4,767.91
8,700.00
40.99
187.34
6,833.49
6,774.49
-4,784.16
8,725.00
40.71
187.37
6,852.40
6,793.40
-4,800.38
8,750.00
40.67
187.40
6,871.36
6,812.36
-4,816.64
8,756.00
40.46
187.38
6,875.92
6,816.92
-4,820.41
8,800.00
40.50
185.00
6,909.39
6,850.39
-4,848.81
8,864.00
40.66
185.64
6,958.00
6,899.00
-4,890.26
KOP : Start Dir 901100':
8884' MD, 6966'TVD : 0' RT TF
8,884.00
42.46
185.64
6,972.96
6,913.96
-4,903.46
Start Dir
3201100' : 8884' MD, 6972.96TVD
252.96
6,018,497.292
8,890.00
44.27
184.70
6,977.32
6,918.32
-0,907.57
8,900.00
47.30
183.26
6,984.30
6,925.30
-4,914.71
8,910.00
50.34
181.96
6,990.88
6,931.88
4,922.23
8,920.00
53.40
180.76
6,997.05
6,938.05
4,930.09
8,930.00
56.47
179.66
7,002.80
6,943.80
-4,938.28
8,940.00
59.55
178.63
7,008.10
6,949.10
-4,946.76
8,950.00
62.64
177.66
7,012.93
6,953.93
-4,955.51
8,960.00
65.73
176.75
7,017.28
6,958.28
-4,964.50
8,970.00
68.83
175.88
7,021.15
6,962.15
-4,973.70
8,980.00
71.93
175.05
7,024.50
6,965.50
-4,983.09
8,990.00
75.04
174.25
7,027.35
6,968.35
-4,992.63
9,000.00
78.14
173.47
7,029.66
6,970.66
-5,002.30
9,010.00
81.25
172.70
7,031.45
6,972.45
-5,012.07
9,020.00
84.37
171.95
7,032.70
6,973.70
-5,021.90
9,022.03
85.00
171.80
7,032.89
6,973.89
5,023.90
9,030.00
86.00
169.45
7,033.52
6,974.52
-5,031.74
9,040.00
87.26
166.50
7,034.11
6,975.11
-5,041.50
9,050.00
88.54
163.56
7,034.47
6,975.47
-5,051.15
9,060.00
89.81
160.63
7,034.62
6,975.62
-5,060.67
9,070.00
91.09
157.69
7,034.54
6,975.54
-5,070,01
9,077.17
92.00
155.59
7,034.34
6,975.34
-5,076.59
Start Dir 12'1100': 9077.17' MD, 7034.34'TVD
9,100.00
92.24
158.32
7,033.50
6,974.50
-5,097,58
9,125.00
92.49
161.31
7,032.47
6,973.47
-5,121.03
9,150.00
92.74
164.31
7,031.33
6,972.33
-5,144.88
9,175.00
92.98
167.30
7,030.08
6,971,08
-5,169,09
9,200.00
93.21
170.30
7,028.73
6,969.73
-5,193.57
9,227.23
93.45
173.56
7,027.15
6,968.15
-5,220.48
9,250.00
93.54
170.82
7,025.76
6,966.76
-5,243.00
9,275.00
93.63
167.82
7,024.20
6,965.20
-5,267.51
9,300.00
93.71
164.81
7,022.60
6,963.60
-5,291.75
9,325.00
93.78
161.81
7,020.96
6,961.96
-5,315.64
9,350.00
93.84
158.80
7,019.30
6,960.30
-5,339.13
9,375.00
93.89
155.80
7,017.61
6,958.61
-5,362.13
9,400.00
93.93
152.79
7,015.90
6,956.90
-5,384.60
284.21
Map
Map
12.002
15.58
+EI -W
Northing
Easting
DLS
Vert Section
(usft)
(unit)
(usft)
6,755.61
65.51
269.39
6,018,659.612
572,429.163
0.680
-300.54
267.28
6,018,643.341
572,427.218
0.287
-285.89
265.19
6,018,627.106
572,425.282
1.123
-271.27
263.09
6,018,610.924
572,423.344
0.178
-256.70
262.59
6,018,607.050
572,422.880
3.507
-253.21
259.51
6,018,578.631
572,420.076
3.513
-227.42
255.65
6,018,537.147
572,416.617
0.697
-189.56
254.35
6,018,523.933
572,415.441
9.000
-177.53
253.98
6,018,519.828
572,415.111
32.000
-173.78
253.48
6,018,512.675
572,414.685
32.000
-167.19
253.14
6,018,505.156
572,414.417
32.000
-160.21
252.96
6,018,497.292
572,414.309
32.000
-152.84
252.93
6,018,489.109
572,414.360
32.000
-145.13
253.06
6,018,480.632
572,414.570
32.000
-137.08
253.34
6,018,471.888
572,414,939
32.000
-128.73
253.78
6,018,462.904
572,415.465
32.000
-120.09
254.37
6,018,453.707
572,416.147
32.000
-111.21
255.12
6,018,444.327
572,416.983
32.000
-102.10
256.01
6,018,434.793
572,417.970
32.000
-92.80
257.05
6,018,425.134
572,419.105
32.000
-83.32
258.24
6,018,415.381
572,420.384
32.000
-73.71
259.56
6,018,405.564
572,421.804
32.000
-63.99
259.85
6,018,403.562
572,422.109
32.000
52.01
261.14
6,018,395.741
572,423.479
32.000
-54.18
263.22
6,018,386.000
572,425.653
32.000
-44.28
265.80
6,018,376.374
572,428.327
32.000
-34.32
268.88
6,018,366.891
572,431.492
32.000
-24.32
272.43
6,018,357.582
572,435.138
32.000
-14.33
275.28
6,018,351.031
572,438.043
31.983
-7.18
284.21
6,018,330.129
572,447.175
12.002
15.58
292.82
6,018,306.773
572,456.018
12.000
40.56
300.20
6,018,282.993
572,463.628
12.000
65.51
306.33
6,018,258.852
572,469.985
12.000
90.38
311.17
6,018,234.417
572,475.070
12.000
115.09
314.99
6,018,207.548
572,479.147
12.000
141.76
318.08
6,018,185.065
572,482.452
12.000
164.03
322.70
6,018,160.597
572,487.312
12.000
188.70
328.60
6,018,136.420
572,493.447
12.000
213.53
335.77
6,018,112.600
572,500.840
12.000
238.45
344.17
6,018,089.202
572,509.472
12.000
263.39
353.80
6,018,066.290
572,519.318
12.000
288.29
364.61
6,018,043.928
572,530.352
12.000
313.07
31612023 4:5lA8PM Page 10 COMPASS 5000.15 Build 91E
H A L L I B U R TO N
Standard Proposal Report
Database:
NORTH US
+ CANADA
Local Coordinate
Reference: Well
Plan: MPB-15
Company:
Hilcorp Alaska, LLC
TVD Reference:
18:
15 6/1511985 00:00 @ 59.00usft (generic dri
Project:
Milne Point
MD Reference:
18:
15 6/1571985 00:00 @ 59.00usft (generic dri
Site:
M Pt B Pad
North Reference:
True
Well:
Plan: MPB-15
Survey Calculation Method: Minimum Curvature
Wellbore:
Plan: MPB-15A
Design:
MPB-15Awp04
Planned Survey
Measured
Vertical
Map
Map
Depth
Inclination Azimuth
Depth
TVDss
+N14
+PJ-W
Northing
Pasting
DLS
Vert Section
(usft)
(')
(0)
(usft)
usft
(usft)
(usft)
(usft)
(usft)
6,955.18
9,425.00
93.96
149.78
7,014.18
6,955.18
-5,406.48
376.59
6,018,022.176
572,542.544
12.000
337.66
9,452.29
93.98
146.50
7,012.29
6,953.29
-5,429.59
390.96
6,017,999.200
572,557.132
12.000
364.23
9,475.00
93.97
149.23
7,010.72
6,951.72
-5,448.76
403.01
6,017,980.135
572,569.367
12.000
386.31
9,500.00
93.96
152.24
7,008.99
6,949.99
-5,470.53
415.20
6,017,958.502
572,681.766
12.000
410.87
9,525.00
93.93
155.25
7,007.27
6,948.27
-5,492.90
426.23
6,017,936.247
572,593.014
12.000
435.62
9,550.00
93.89
158.25
7,005.56
6,946.56
-5,515.81
436.08
6,017,913.432
572,603.079
12.000
460.50
9,575.00
93.85
161.26
7,003.87
6,944.87
-5,539.21
444.71
6,017,890.119
572,611.934
12.000
485.43
9,600.00
93.79
164.27
7,002.21
6,943.21
-5,563.03
452.10
6,017,866.373
572,619.555
12.000
510.36
9,626.00
93.72
167.27
7,000.57
6,941.57
5,587.21
458.23
6,017,842.258
572,625.921
12.000
535.21
9,652.28
93.63
170.55
6,998.82
6,939.82
-5,613.92
463.47
6,017,815.603
572,631.414
12.000
562.15
9,675.00
95.99
169.18
6,996.92
6,937.92
5,636.21
467.45
6,017,793.357
572,635.613
12.000
584.51
9,700.00
98.58
167.66
6,993.75
6,934.75
-5,660.50
472.43
6,017,769.118
572,640.824
12.000
609.08
9,725.00
101.17
166.12
6,989.46
6,930.46
-5,684.48
478.01
6,017,745.191
572,646.640
12.000
633.56
9,750.00
103.75
164.55
6,984.07
6,925.07
-5,708.10
484.19
6,017,721.641
572,653.047
12.000
657.89
9,775.00
106.32
162.94
6,977.58
6,918.58
5,731.27
490.95
6,017,698.533
572,660.026
12.000
682.00
9,800.00
108.88
161.30
6,970.02
6,911.02
-5,753.95
498.26
6,017,675.929
572,667.557
12.000
705.82
9,827.30
111.65
159.44
6,960.57
6,901.57
-5,778.07
506.86
6,017,651.898
572,676.389
12.000
731.43
9,850.00
108.93
159.44
6,952.70
6,893.70
5,798.00
514.34
6,017,632.038
572,694.058
12.000
752.71
9,875.00
105.93
159.44
6,945.21
6,886.21
5,820.33
522.71
6,017,609.792
572,692.649
12.000
776.56
9,900.00
102.93
159.44
6,938.98
6,879.98
5,843.00
531,21
6,017,587,210
572,701.369
12.000
800.76
9,925.00
99.93
159.44
6,934.03
6,875.03
5,865.94
539.82
8,017,564.356
572,710.195
12.000
825.25
9,950.00
96.93
159.44
6,930.37
6,871.37
-5,889.09
548.50
6,017,541.291
572,719.102
12.000
849.98
9,975.00
93.93
159.44
6,928.01
5,869.01
-5,912.39
557.24
6,017,518.079
572,728066
12.000
874.85
9,982.72
93.00
159.44
6,927.64
6,868.54
-5,919.60
559.95
6,017,510.895
572,730.840
12.000
882.55
10,000.00
93.00
157.36
6,926.64
6,867.64
-5,935.65
566.30
6,017,494.911
572,737,348
12.000
899.80
10,025.00
92.99
154.36
6,925.33
6,866,33
-5,958.43
576.51
6,017,472.233
572,747.776
12.000
924.67
10,050.00
92.97
151.35
6,924.03
6,865.03
-5,980.65
587.90
6,017,450.132
572,759.378
12.000
949.40
10,057.70
92.96
150.43
6,923.63
6,864.63
-5,987.36
591.64
6,017,443.453
572,763.182
12.000
956.97
10,075.00
91.37
151.76
6,922.98
6,863.98
-6,002.50
599.99
6,017,428.401
572,771.684
12.000
974.02
10,100.00
89.07
153.69
6,922.88
6,863.88
5,024.72
611.45
6,017,406.296
572,783.352
12.000
998.77
10,125.00
86.77
155.62
6,923.79
6,864.79
5,047.29
622.14
6,017,383.827
572,794.263
12.000
1,023.61
10,150.00
84.47
157.56
6,925.70
6,866.70
5,070.17
632.04
6,017,361.054
572,804.387
12.000
1,048.47
10,175.00
82.18
159.51
6,928,61
6,869.61
-6,093.27
641.13
6,017,338.040
572,813.696
12.000
1,073.28
10,198.95
80.00
161.40
6,932.31
6,873.31
-6,115.57
649.05
6,017,315.821
572,821.829
12.000
1,096.94
10,200.00
79.96
161.28
6,932.50
6,873.50
-6,116.55
649.38
6,017,314.849
572,822.168
12.000
1,097.97
10,225.00
78.94
158.41
6,937.07
6,878.07
-6,139.61
657.84
6,017,291.865
572,830.857
12.000
1,122.54
10,250.00
77.96
155.52
6,942.08
6,883.08
5,162.15
667.43
6,017,269.423
572,840.657
12.000
1,146.98
10,274.00
77.04
152.72
6,947.28
6,888.28
5,183.23
677.65
6,017,248.447
572,851.085
12.000
1,170.25
10,275.00
76,98
152,83
6,947.50
6,888.50
5,184.10
678.10
6,017,247.584
572,851.540
12.000
1,171.21
10,300.00
75.50
155.51
6,953.45
6,894.45
5,205.95
688.68
6,017,225.837
572,862.331
12.000
1,195.33
10,325.00
74.04
158.23
6,960.02
6,901.02
5,228.13
698.16
6,017,203.753
572,872.D20
12.000
1,219.40
10,350.00
72.63
160.99
6,967.19
6,908.19
-6,250.58
706.50
6,017,181.391
572,880.580
12.000
12243.34
10,375.00
71.25
163.79
6,974.94
6,915.94
5,273.23
713.69
6,017,158.813
572,887.990
12.000
1,267.09
10,399.03
69.96
166.53
6,982.92
6,923.92
5,295.13
719.50
6,017,136.967
572,894.006
12.000
1,289.69
Total Depth: 10399.03' MD, 6982.92' TVD
382023 4:51:18PM
P:=ge 11
COMPASS
5000.15 Build 91E
HALLIBURTON
Dip Angle Dip Dir. TVD
Standard Proposal Report
Database: NORTH US + CANADA
Local Co-ordinate Reference:
Well Plan: MPB-15
Company: Hilcorp Alaska, LLC
TVD Reference:
18: 15 6/15/1985 00:00 Q 59.00usft (generic dri
Project: Milne Point
MD Reference:
18: 15 611511985 00:00 Q 59.00usft (generic dri
Site: M Pt 9 Pad
North Reference:
True
Well: Plan: MPB-15
Survey Calculation Method:
Minimum Curvature
Wellbore: Plan: MPB-15A
N. 363.22 E)
6,972.96
Design: MPB-15Awp04
- Polygon
Start Dir 32°/100':8884' MD, 6972.96TVD
Targets
Target Name
• hit/miss target
Dip Angle Dip Dir. TVD
+NIS
+FJ -W
Northing
Easting
• Shape
(°) (°) (usft)
(rift)
(usft)
(usft)
(usft)
MPB-15APoly
0.00 0.00 6,958.00
•5,447.46
217.83
6,017,979.660
572,384.195
- plan misses target center by 169.76usft at 9396.93usft MD (7016.11 TVD, 5381.88
N. 363.22 E)
6,972.96
-4,903.46
- Polygon
Start Dir 32°/100':8884' MD, 6972.96TVD
9,077.17
7,034.34
5,076.59
275.28
Point 1
6,958.00
0.00
0.00
6,017,979.66
572,384.20
Point
6,958.00
41.90
368.87
6,018,025.13
572,752.61
Point
6,958.00
-907.52
665.78
6,017,078.72
573,058.67
Point
6,958.00
-1,024.21
329.89
6,016,958.79
572,723.96
Point 5
6,958.00
0.00
0.00
6,017,979.66
572,384.20
MPB-15A tgt 5
0.00 0.00 6,979.00
-6,290.91
700.53
6,017,141.000
572,875.000
- plan misses target center by 17.40usft at 10389.30usft MD (6979.63 TVD, •6286.25 N, 717.28 E)
- Point
Casing Points
Measured
Vertical
Casing Hole
Depth
Depth
Diameter Diameter
(usft)
(usft) Name
(") (")
10,399.03
6,982.92 2 3/8" x 3 1/4"
2-3/8 3-1/4
Plan Annotations
Measured
Vertical
Local Coordinates
Depth
Depth
+N/.S
+EJ w
(usft)
(usft)
(usft)
(usft)
Comment
8,864.00
6,958.00
-4,890.26
255.65
KOP : Start Dir 90/1011' : 8864' MD, 6958'TVD : D° RTTF
8,864.00
6,972.96
-4,903.46
264.35
Start Dir 32°/100':8884' MD, 6972.96TVD
9,077.17
7,034.34
5,076.59
275.28
Start Dir 12°1100' : 9077.17' MD, 7034.34'TVD
10,399.03
6,982.92
5,295.13
719.5D
Total Depth: 10399.03' MD, 6982.92' TVD
Y612023 4:51:18PM Page 12 COMPASS 5000.15 Build 91E
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CDR2-AC BOP Schematic
Quick Test Sub to Otis
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Top of 7" Otis
O.Oft—.—.—.—.—,_._._ ._._._.—
CL BlindlShears 6,09 ft
CDR2 Rig's Drip Pan
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~— 3" HP hose to Micromotlor
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CL Annular 3.40ft
Bottom Annular
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CL 2.0" Pipe l Slips 6.95ft
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IA
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TRANSMITTAL LETTER CHECKLIST
WELL NAME: MPU B -15A
PTD: 223-022
X Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional
FIELD: Milne Point POOL: Kuparuk Rivar 001
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK
OPTIONS
TEXT FOR APPROVAL LETTER
MULTI
The permit is for a new wellbore segment of existing well Permit
LATERAL
Number , API Number 50 -
(If last two digits
Production from or injection into this wellbore must be reported under
in API number are
the original API Number stated above.
between 60-69
The permit is approved subject to full compliance with 20 AAC 25.055.
Spacing
Approval to produce or inject is contingent upon issuance of a
Exception
conservation order approving a spacing exception. The Operator
assumes the liability of any protest to the spacing exception that may
occur.
All dry ditch sample sets submitted to the AOGCC must be in no greater
Dry Ditch Sample
than 30 -foot sample intervals from below the permafrost or from where
samples are first caught and 10 -foot sample intervals through target
zones.
Please note the following special condition of this permit: Production or
Non-
production testing of coal bed methane is not allowed for this well until
Conventional
after the Operator has designed and implemented a water -well testing
Well
program to provide baseline data on water quality and quantity. The
Operator must contact the AOGCC to obtain advance approval of such
a water -well testing program.
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types
of well logs to be run. In addition to the well logging program proposed
by the Operator in the attached application, the following well logs are
also required for this well:
X
Well Logging
Requirements
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
composite curves for all well logs run must be submitted to the AOGCC
within 90 days after completion, suspension, or abandonment of this
well or within 90 days of acquisition of the data, whichever occurs first.
Revised 7/2022
DE
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