Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
Loading...
HomeMy WebLinkAbout225-022Nolan Vlahovich Hilcorp Alaska, LLC
Geotech 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: 6/18/2025
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20250618
Well API #PTD #Log Date Log
Company Log Type AOGCC
E-Set#
AN 07RD2 50733200120200 195113 6/1/2025 AK E-LINE LDL
AN 24RD 50733202850100 207170 6/1/2025 AK E-LINE LDL
BRU 221-24 50283202020000 225027 5/29/2025 AK E-LINE CBL
KALOTSA 10 50133207320000 224147 5/21/2025 AK E-LINE Perf
KALOTSA 2 50133206590000 216155 5/25/2025 AK E-LINE Perf
PAXTON 11 50133207040000 221114 5/27/2025 AK E-LINE Perf
PAXTON 11 50133207040000 221114 5/26/2025 AK E-LINE Perf
PBU 06-12C 50029204560300 225022 5/17/2025 HALLIBURTON RBT-COILFLAG
PBU 15-32C 50029224620300 217104 5/27/2025 HALLIBURTON RBT
PBU D-01B 50029200540200 224155 5/18/2025 BAKER MRPM
PBU D-01B 50029200540200 224155 5/18/2025 HALLIBURTON RBT-COILFLAG
PBU H-18A 50029208800100 224011 5/14/2025 BAKER MRPM
PBU H-18A 50029208800100 224011 5/14/2025 HALLIBURTON RBT-COILFLAG
PBU L-109 50029230460000 201201 5/24/2025 HALLIBURTON IPROF
PBU L-115 50029230350000 201140 5/19/2025 HALLIBURTON IPROF
PBU L-117 50029230390000 201167 5/30/2025 HALLIBURTON IPROF
PBU N-07B 50029201370200 223122 6/7/2025 HALLIBURTON RBT
PBU S-100A 50029229620100 224083 5/26/2025 HALLIBURTON PPROF-LDL
PBU Z-34 50029234690000 212061 5/17/2025 HALLIBURTON IPROF-LDL
Please include current contact information if different from above.
T40566
T40567
T40568
T40569
T40570
T40571
T40571
T40572
T40573
T40574
T40574
T40575
T40575
T40576
T40577
T40578
T40579
T40580
T40581
PBU 06-12C 50029204560300 225022 5/17/2025 HALLIBURTON RBT-COILFLAG
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2025.06.18 12:03:53 -08'00'
Nolan Vlahovich Hilcorp Alaska, LLC
Geotech 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: 6/13/2025
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20250613
Well API #PTD #Log Date Log
Company Log Type AOGCC
E-Set#
AN-17A 50733203110100 213049 4/14/2025 AK E-LINE GPT T40549
AN-17A 50733203110100 213049 4/16/2025 AK E-LINE Perf T40549
BRU 244-27 50283201850000 222038 5/15/2025 AK E-LINE Perf T40550
IRU 241-01 50283201840000 221076 5/16/2025 AK E-LINE Perf T40551
KU 13-06A 50133207160000 223112 3/18/2025 AK E-LINE CIBP T40552
KU 13-06A 50133207160000 223112 5/9/2025 AK E-LINE Perf T40552
KU 33-08 50133207180000 224008 5/30/2025 AK E-LINE Perf T40553
MPU K-33 50029227290000 196202 5/2/2025 AK E-LINE Caliper T40554
Aurora S-100A 50029229620100 224083 5/8/2025 BAKER MRPM Borax #2 T40555
PBU 06-12C 50029204560300 225022 5/15/2025 BAKER MRPM T40556
PBU B-30B 50029215420200 225009 4/9/2025 BAKER MRPM T40557
PBU D-03B 50029200570300 225008 5/2/2025 BAKER MRPM T40558
PBU H-29B 50029218130200 225005 5/7/2025 BAKER MRPM T40559
END 1-25A 50029217220100 197075 5/4/2025 HALLIBURTON MFC40 T40560
END 3-03 50029223060000 192121 5/18/2025 HALLIBURTON PPROF T40561
NS-33A 50029233250100 208189 5/13/2025 HALLIBURTON MFC24 T40562
PBU D-03B 50029200570300 225008 5/2/2025 HALLIBURTON RBT T40558
PBU H-29B 50029218130200 225005 5/7/2025 HALLIBURTON RBT T40559
PBU L-108 50029230900000 202109 5/16/2025 HALLIBURTON IPROF T40563
Please include current contact information if different from above.
PBU 06-12C 50029204560300 225022 5/15/2025 BAKER MRPM
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2025.06.17 11:38:14 -08'00'
David Douglas Hilcorp North Slope, 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:
Hilcorp North Slope, LLC
Date: 05/27/2025
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL:
Well: PBU 06-12C
PTD: 225-022
API: 50-029-20456-03-00
FINAL LWD FORMATION EVALUATION LOGS (04/16/2025 to 05/03/2025)
x ROP, BaseStar & iCruise Gamma Ray, StrataStar Resistivity, ALD, CTN
x Horizontal Presentation (2” & 5” MD/TVD Color Logs)
x Final Definitive Directional Survey
SFTP Transfer – Main Folders:
Please include current contact information if different from above.
225-022
T40447
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2025.05.27 14:10:44 -08'00'
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:Lau, Jack J (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: HAK PBU 06-12C (PTD: 225-022) 7" Casing Test & FIT
Date:Monday, April 28, 2025 1:40:33 PM
Attachments:HAK PBU 06-12C 7in Intermediate Casing Test & FIT.pdf
From: Joseph Engel <jengel@hilcorp.com>
Sent: Monday, April 28, 2025 1:11 PM
To: Lau, Jack J (OGC) <jack.lau@alaska.gov>
Cc: Joseph Lastufka <Joseph.Lastufka@hilcorp.com>
Subject: HAK PBU 06-12C (PTD: 225-022) 7" Casing Test & FIT
Jack –
Attached is the casing test and FIT of the 7” Intermediate casing on 06-12C.
7” cement job went well, we pumped 32bbls of 15.8ppg cement with full returns
throughout the job.
-Joe
Joe Engel | Drilling Engineer | Hilcorp Alaska, LLC
Office: 907.777.8395 | Cell: 805.235.6265
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 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.
CASING AND LEAK-OFF FRACTURE TESTS
Well Name:PBU 06-12C Date:4/28/2025
Csg Size/Wt/Grade:7", 29#, L-80 L-80 Supervisor:James Lott
Csg Setting Depth:8836 TMD 8592 TVD
Mud Weight:8.8 ppg LOT / FIT Press =760 psi
LOT / FIT =10.50 ppg Hole Depth =8859 md
Fluid Pumped=1.0 Bbls Volume Back =1.0 bbls
Estimated Pump Output:0.062 Barrels/Stroke
LOT / FIT DATA CASING TEST DATA
Enter Strokes Enter Pressure Enter Strokes Enter Pressure
Here Here Here Here
->0 0 ->0 28
->2 92 ->2 100
->4 192 ->4 208
->6 282 ->6 300
->8 375 ->8 414
->10 477 ->10 519
->12 572 ->12 623
->14 660 ->14 736
->16 760 ->16 857
->18 ->18 984
->20 ->20 1115
-> ->30 1787
-> ->40 2535
-> ->43 2700
Enter Holding Enter Holding Enter Holding Enter Holding
Time Here Pressure Here Time Here Pressure Here
->0 760 ->0 2688
->1 736 ->5 2629
->2 730 ->10 2620
->3 731 ->15 2609
->4 731 ->20 2597
->5 729 ->25 2590
->6729 ->30 2590
->7729 ->
->8729 ->
->9729 ->
->10 729 ->
-> ->
-> ->
-> ->
0
2
4
6
8
10
12
14
16
0
2
4
6
8
10
12
14
16
18
20
30
0
100
200
300
400
500
600
700
800
900
1000
1100
1200
1300
1400
1500
1600
1700
1800
1900
2000
0 1020304050Pressure (psi)Strokes (# of)
LOT / FIT DATA CASING TEST DATA
760736730731731729729729729729729
2688
2629 2620 2609 2597 2590 2590
0
100
200
300
400
500
600
700
800
900
1000
1100
1200
1300
1400
1500
1600
1700
1800
1900
2000
2100
2200
2300
2400
2500
2600
2700
2800
2900
3000
0 5 10 15 20 25 30Pressure (psi)Time (Minutes)
LOT / FIT DATA CASING TEST DATA
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:Lau, Jack J (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: 06-12C (PTD 225-022) Sundry Change Request
Date:Monday, April 14, 2025 10:52:08 AM
From: Lau, Jack J (OGC)
Sent: Friday, April 11, 2025 4:29 PM
To: Jacob Thompson <Jacob.Thompson@hilcorp.com>
Cc: Clint Montague - (C) <cmontague@hilcorp.com>; Joseph Engel <jengel@hilcorp.com>
Subject: RE: 06-12C Sundry Change Request
Approved.
From: Jacob Thompson <Jacob.Thompson@hilcorp.com>
Sent: Friday, April 11, 2025 2:53 PM
To: Lau, Jack J (OGC) <jack.lau@alaska.gov>
Cc: Clint Montague - (C) <cmontague@hilcorp.com>; Joseph Engel <jengel@hilcorp.com>
Subject: 06-12C Sundry Change Request
Jack,
As we discussed on the phone I would like to modify step 8.) of the approved PTD. We
are requesting to not set a storm packer, and to close the blind rams and test the
cement plug to 2,500 psi prior to nippleing down BOP's to add the 7" casing spool.
Our barriers for nippleing down the stack will then become a tested cement plug, and a
monitored column of kill weight fluid.
Thanks and have a great weekend,
Jacob
Jacob Thompson
Email: jacob.thompson@hilcorp.com
Cell: 907-854-4377
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 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 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 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.
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
Sean McLaughlin
Drilling Manager
Hilcorp Alaska, LLC
3800 Centerpoint Drive, Suite 1400
Anchorage, AK, 99503
Re: Prudhoe Bay Unit, Prudhoe Oil, PBU 06-12C
Hilcorp Alaska, LLC
Permit to Drill Number: 225-022
Surface Location: 3' FSL, 1679' FEL, Sec. 02, T10N, R14E, UM, AK
Bottomhole Location: 2168' FSL, 1784' FWL, Sec. 12, T10N, R14E, UM, AK
Dear Mr. McLaughlin:
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,
Jessie L. Chmielowski
Commissioner
DATED this 28th day of March 2025.
Jessie L.
Chmielowski
Digitally signed by Jessie
L. Chmielowski
Date: 2025.03.28 08:49:03
-08'00'
1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for:
Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates
Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas
2. Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number:
Bond No.
3. Address:6. Proposed Depth: 12. Field/Pool(s):
MD: 12421' TVD:8768'
4a. Location of Well (Governmental Section): 7. Property Designation:
Surface:
Top of Productive Horizon:8. DNR Approval Number: 13. Approximate Spud Date:
Total Depth: 9. Acres in Property: 14. Distance to Nearest Property:
4b. Location of Well (State Base Plane Coordinates - NAD 27): 10.KB Elevation above MSL (ft): 15.Distance to Nearest Well Open
Surface: x-685318 y- 5940584 Zone- 4 to Same Pool: 700'
16. Deviated wells: Kickoff depth: 3300 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 108 degrees Downhole: Surface:
Hole Casing Weight Grade Coupling Length MD TVD MD TVD
8-1/2"x9-7/8"7" 29# L-80 VamTop 8807' Surface Surface 8807' 8570'
6-1/8" 4-1/2" 12.6# 13Cr80 VamTop 3764' 8657' 8441' 12421' 8768'
19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations)
Junk (measured):
TVD
27 - 107
27 - 2709
26 - 7920
7724 - 8781
8582 - 8772
8774 - 8773
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 20 AAC 25.050 requirements
Contact Name:
Contact Email:jengel@hilcorp.com
Contact Phone:907-777-8395
Date:
Permit to Drill API Number: Permit Approval
Number:Date:
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:
Samples req'd: Yes No Mud log req'd: Yes No
H2S measures: Yes No Directional svy req'd: Yes No
Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No
Post initial injection MIT req'd: Yes No
APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
April 4, 2025
18095'
Sean McLaughlin
Drilling Manager
Joe Engel
Liner 929 3-1/4" 48 sx Class G 10604 - 11533
11587 - 12787
21. I hereby certify that the foregoing is true and the procedure approved herein will not be
deviated from without prior written approval.
Surface
Perforation Depth TVD (ft):
GL / BF Elevation above MSL (ft):
Perforation Depth MD (ft):
2682
281 sx Arctic Set II 27 - 107
27 - 270913-3/8" 2000 sx Fondu, 400 sx AS II
Effect. Depth MD (ft): Effect. Depth TVD (ft):
Authorized Title:
Authorized Signature:
2-3/8"
26 - 9696
2667 sx Class G
Uncemented Slotted Liner
Liner
Liner
9670
1428
1200
Intermediate
Authorized Name:
11608 - 12786
Conductor/Structural 20"80
LengthCasing Cement Volume MDSize
Plugs (measured):
(including stage data)
153 sx Class G
403 sx Class G
2560
18. Casing Program: Top - Setting Depth - BottomSpecifications
3286
Total Depth MD (ft): Total Depth TVD (ft):
107205344
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
2451
680' FNL, 560' FEL, Sec. 11, T10N, R14E, UM, AK
2168' FSL, 1784' FWL, Sec. 12, T10N, R14E, UM, AK
72-019
3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503
Hilcorp North Slope, LLC
3' FSL, 1679' FEL, Sec. 02, T10N, R14E, UM, AK ADL 028311
PBU 06-12C
PRUDHOE BAY, PRUDHOE OIL
Cement Quantity, c.f. or sacks
Commission Use Only
See cover letter for other
requirements.
8775 - 8773
500 sx Class G, 300 sx AS I
9440 - 108687"
9-5/8"
oooo
oo
ooo
ooo
oo
oo
oo
Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g)
By Gavin Gluyas at 8:01 am, Mar 05, 2025
Digitally signed by Sean
McLaughlin (4311)
DN: cn=Sean McLaughlin (4311)
Date: 2025.03.04 16:12:14 -
09'00'
Sean
McLaughlin
(4311)
64.8
50-029-20456-03-00
JJL 3/24/25
225-022
38.3
*Email digital data of casing test, cementing summary, and FIT to AOGCC
upon completion of FIT.
DSR-3/10/25A.Dewhurst 27MAR25
*AOGCC Witnessed BOP Test to 3500 psi, Annular to a minimum of 2500 psi.
*&:
Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski
Date: 2025.03.28 08:49:18 -08'00'
03/28/25
03/28/25
RBDMS JSB 040125
04 March 2025
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Re: Application for Permit to Drill
Hilcorp North Slope, LLC
06-12C
Dear Sir/Madam,
Hilcorp North Slope , LLC hereby applies for a Permit to Drill an onshore development well from the Drillsite
06 in Prudhoe Bay, Alaska. 06-12C is planned to be a horizontal producer targeting the Ivishak sands. The
parent bore, 06-12B will be reservoir abandoned on a prior sundry.
The approximate spud date is anticipated to be April 4th, 2025, pending rig schedule. The Innovation rig
will be used to drill this well.
The directional plan is two-hole section sidetrack. An 8-1/2” x 9-7/8” intermediate hole exiting the 9-5/8”
casing at ~3300’ MD drilled into the top of the Sag River, with 7” casing ran and cemented. A 6-1/8” lateral
will be drilled in the Ivishak. A 4-1/2” cemented liner will be run in the open hole section, followed by 4-1/2”
tubing.
Please find enclosed for your review Form 10-401 Permit to Drill with information as required by 20 AAC
25.005. If there are any questions, please contact me at (907)777-8395 or jengel@hilcorp.com.
Respectfully,
Joe Engel
Senior Drilling Engineer
Hilcorp North Slope, LLC
Enclosures:
Form 10-401 Permit to Drill
Application for Permit to Drill
Prudhoe Bay East
(PBU) 06-12C
Version 1
2/20/2025
Prudhoe Bay East
06-12C Producer
Table of Contents
1. Well Name ................................................................................................................................. 3
2. Location Summary ..................................................................................................................... 3
3. Blowout Prevention Equipment Information .............................................................................. 4
4. Drilling Hazards Information ...................................................................................................... 5
5. Procedure for Conducting Formation Integrity Tests .................................................................. 6
6. Casing and Cementing Program ................................................................................................. 6
7. Diverter System Information ...................................................................................................... 7
8. Drilling Fluid Program ................................................................................................................ 7
9. Abnormally Pressured Formation Information ........................................................................... 8
10. Seismic Analysis ....................................................................................................................... 8
11. Seabed Condition Analysis ....................................................................................................... 8
12. Evidence of Bonding ................................................................................................................ 8
13. Proposed Drilling Program ....................................................................................................... 9
14. Discussion of Mud and Cuttings Disposal and Annular Disposal .............................................. 12
15. Proposed Variance Request ................................................................................................... 12
Attachment 1: Location & GIS Maps ............................................................................................ 13
Attachment 2: BOPE Equipment .................................................................................................. 15
Attachment 3: Hole Section Hazards ............................................................................................ 17
Attachment 4: LOT / FIT Test Procedure ...................................................................................... 2 0
Attachment 5: Cement Summary ................................................................................................. 21
Attachment 6: Prognosed Formation Tops ................................................................................... 22
Attachment 7: Well Schematic..................................................................................................... 23
Attachment 8: Formation Evaluation Program ............................................................................. 25
Attachment 9: Wellhead Diagram ................................................................................................ 26
Attachment 10: Management of Change ..................................................................................... 27
Attachment 11: Drill Pipe Specs ................................................................................................... 28
Attachment 12: 06-12 Surface Casing FIT ..................................................................................... 3 0
Attachment 13: Directional Plan .................................................................................................. 31
Prudhoe Bay East
06-12C Producer
As per 20 AAC 25.005 (c), an application for a Permit to Drill must be accompanied by each of the
following items, except for an item already on file with the commission and identified in the application.
1. Well Name
20 AAC 25.005 (f)
Each well must be identified by a unique name designated by the operator and a unique API
number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well
branches, each branch must similarly be identified by a unique name and API number by adding a
suffix to the name designated for the well by the operator and to the number assigned to the well
by the commission.
The well for which this application for a Permit to Drill is submitted is designated as 06-12C.This
will be a development production well.
2. Location Summary
20 AAC 25.005 (c) (2)
A plat identifying the property and the property's owners and showing:
(A) the coordinates of the proposed location of the well at the surface, at the top of each objective
formation, and at total depth, referenced to governmental section lines;
(B) the coordinates of the proposed location of the well at the surface, referenced to the state plane
coordinate system for this state as maintained by the National Geodetic Survey in the National
Oceanic and Atmospheric Administration;
(C) the proposed depth of the well at the top of each objective formation and at total depth
Location at Surface
Reference to Government Section Lines 3' FSL, 1679' FEL, Sec 2, T10N, R14E, UM, AK
NAD 27 Coordinate System X: 685,318.2 Y: 5,940,584.4
Innovation Rig KB Elevation 26.5’ above GL
Ground Level 38.3’ above MSL
Location at Top of Productive Interval
Reference to Government Section Lines 680' FNL, 560' FEL, Sec 11, T10N, R14E, UM, AK
NAD 27 Coordinate System X: 686,454.2 Y: 5,939,929.9
Measured Depth, Rig KB (MD) 8,803.5’
Total Vertical Depth, Rig KB (TVD) 8,566.8’
Total vertical Depth, Subsea (TVDSS) 8,502’
Location at Bottom of Productive Interval
Reference to Government Section Lines 2168' FSL, 1784' FWL, Sec 12, T10N, R14E, UM, AK
NAD 27 Coordinate System X: 688,858.8 Y: 5,937,558
Measured Depth, Rig KB (MD) 12,421’
Total Vertical Depth, Rig KB (TVD) 8,768’
Total Vertical Depth, Subsea (TVDSS) 8,703.2’
Prudhoe Bay East
06-12C Producer
(D) other information required by 20 AAC 25.050(b);
20 AAC 25.050 (b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form
10-401) must:
(1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including
all adjacent wellbores within 200 feet of any portion of the proposed well; and
Please refer to Attachment 1: Location Maps, Attachment 6: Formation Tops and Attachment 13:
Directional Plan for further details.
(2) for all wells within 200 feet of the proposed wellbore:
(A) list the names of the operators of those wells, to the extent that those names are known or
discoverable in public records, and show that each named operator has been furnished a copy of
the application by certified mail; or
(B) state that the applicant is the only affected owner.
The applicant is the only affected owner.
3. Blowout Prevention Equipment Information
20 AAC 25.005 (c) (3)
A diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC
25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable;
BOP test frequency for 06-12C will be 7 days until window milling is initiated, afterwards 14-
days. Except in the event of a significant operational issue that may affect well integrity or pose
safety concerns, an extension to the 14-day BOP test period should not be requested.
Summary of Innovation BOP Equipment & Test Requirements
Hole Section Equipment Test Pressure (psi)
8-1/2” x 9-7/8”
& 6-1/8”
x 13-5/8” x 5M Control Technology Inc Annular BOP
x 13-5/8” x 5M Control Technology Inc Double Gate
o Blind ram in bottom cavity
x Mud cross w/ 3” x 5M side outlets
x 13-5/8” x 5M Control Technology Single ram
x 3-1/8” x 5M Choke Line
x 3-1/8” x 5M Kill line
x 3-1/8” x 5M Choke manifold
x Standpipe, floor valves, etc.
Initial Test: 250/3500
Subsequent Tests:
250/3500
Primary closing unit: Control Technology Inc. (CTI), 6 station, 3,000 psi, 220 gallon accumulator
unit.
Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is
an electric triplex pump on a different electrical circuit and emergency pressure is provided by
bottled nitrogen.
The remote closing operator panels are located in the doghouse and on accumulator unit.
Please refer to Attachment 2: BOPE Equipment for further details.
Prudhoe Bay East
06-12C Producer
4. Drilling Hazards Information
20 AAC 25.005 (c) (4)
Information on drilling hazards, including
(A) the maximum downhole pressure that may be encountered, criteria used to determine it, and
maximum potential surface pressure based on a pressure gradient to surface of 0.1 psi per foot of
true vertical depth, unless the commission approves a different pressure gradient that provides a
more accurate means of determining the maximum potential surface pressure;
8-1/2” x 9-7/8” Intermediate Hole Pressure Data
Maximum anticipated BHP 3,227 psi in the top Sag River at 8,569’ TVD
Maximum surface pressure 2,396 psi from the Sag River
(0.10 psi/ft gas gradient to surface)
Planned BOP test pressure Rams test to 3,500 psi / 250 psi
Annular test to 2,500 psi / 250 psi
Formation Integrity Test –
8-1/2” x 9-7/8”
12.5 ppg EMW FIT after drilling 20’ of new hole outside of 9-
5/8” window
If unable to achieve 12.5 ppg EMW, utilize surface casing FIT
t/ 12.5. See Attachment 12
12.5 provides greater than 25bbl KT based on 10.0 ppg MW
9-5/8” Casing Test 2,500 psi, chart for 30 min
(Test pressure driven by 50% of Casing Burst)
6-1/8” Production Hole Pressure Data
Maximum anticipated BHP 3,286 psi in the Ivishak at 8,965’ TVD
Maximum surface pressure 2,451 psi from the Sag River (Higher MASP than Ivishak)
(0.10 psi/ft gas gradient to surface)
Planned BOP test pressure Rams test to 3,500 psi / 250 psi
Annular test to 2,500 psi / 250 psi
Formation Integrity Test –
6-1/8” hole
10.5 ppg EMW FIT after drilling 20’ of new hole outside of 7”
10.5 provides greater than 25 bbl based on 8.8 ppg MW, 7.3
ppg pore pressure
7” Casing Test 2,500 psi , chart for 30 min
(B) data on potential gas zones; and
(C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost
circulation zones, and zones that have a propensity for differential sticking;
Please refer to Attachment 3: Hole Section Hazards
Prudhoe Bay East
06-12C Producer
5. Procedure for Conducting Formation Integrity Tests
20 AAC 25.005 (c) (5)
A description of the procedure for conducting formation integrity tests, as required under 20 AAC
25.030(f);
Please refer to Attachment 4: LOT / FIT Test Procedure
6. Casing and Cementing Program
20 AAC 25.005 (c) (6)
A complete proposed casing and cementing program as required by 20 AAC 25.030, and a
description of any slotted liner, pre-perforated liner, or screen to be installed;
Casing/Tubing Program
Hole Size Tubular
O.D.
Tubular
ID (in)Wt/Ft Grade Conn Length Top
MD
Bottom
MD / TVD
8-1/2” x 9-7/8”7” (Special
Drift)6.125” 29# L-80 VAMTOP 8,807’ Surface 8,807’ / 8,569’
6-1/8”4-1/2”
Solid 3.958” 12.6# 13Cr80 VAMTOP ~3,764 ~8,657’ 12,421’ / 8,768’
Tubing 4-1/2”
Solid 3.958” 12.6# 13Cr80 VAMTOP ~8,657 Surface ~8,657’ / 8,441’
Please refer to Attachment 5: Cement Summary for further details.
Prudhoe Bay East
06-12C Producer
7. Diverter System Information
20 AAC 25.005 (c) (7)
A diagram and description of the diverter system as required by 20 AAC 25.035, unless this
requirement is waived by the commission under 20 AAC 25.035(h)(2);
Diverter system is not applicable to a sidetrack well below the surface casing.
8. Drilling Fluid Program
20 AAC 25.005 (c) (8)
A drilling fluid program, including a diagram and description of the drilling fluid system, as required
by 20 AAC 25.033;
Drilling Fluid Program Summary
Intermediate Hole Production Hole
Mud Type 6% KCl LSND 3% KCl BaraDril-N
Mud Properties:
Mud Weight
PV
YP
HPHT Fluid Loss
pH
MBT
9.5-10.8 ppg
15-25
15-25
< 11.0
9-10
< 12
8.8 – 9.5 ppg
15-25
15-25
< 11
9-10
<7
A diagram of drilling fluid system on Innovation is on file with AOGCC.
Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033
Prudhoe Bay East
06-12C Producer
9. Abnormally Pressured Formation Information
20 AAC 25.005 (c) (9)
For an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted
abnormally geo-pressured strata as required by 20 AAC 25.033(f);
N/A – Application is not for an exploratory or stratigraphic test well.
10. Seismic Analysis
20 AAC 25.005 (c) (10)
For an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required
by 20 AAC 25.061(a);
N/A – Application is not for an exploratory or stratigraphic test well.
11. Seabed Condition Analysis
20 AAC 25.005 (c) (11)
For a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or
floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b);
The 06-12C is to be drilled from an onshore location.
12. Evidence of Bonding
20 AAC 25.005 (c) (12)
Evidence showing that the requirements of 20 AAC 25.025 have been met;
Evidence of bonding for Hilcorp North Slope, LLC is on file with the Commission.
Prudhoe Bay East
06-12C Producer
13. Proposed Drilling Program
20 AAC 25.005 (c) (13)
A copy of the proposed drilling program; the drilling program must indicate if a well is proposed for
hydraulic fracturing as defined in 20 AAC 25.283(m); to seek approval to perform hydraulic
fracturing, a person must make a separate request by submitting an Application for Sundry
Approvals (Form 10-403) with the information required under 20 AAC 25.280 and 20 AAC 25.283;
The proposed drilling program to 06-12C is listed below. Please refer to Attachments for a Well
Schematic, Formation Evaluation Program, and Wellhead & Tree Diagram.
Completed Pre Rig Work
1. Reservoir was abandoned as per prior approved separate sundry
2. 4-1/2” tubing cut at ~3,425’ MD
Proposed Drilling Program
06-12C
1. MIRU Innovation Rig
2. Verify well is dead. Circulate KWF if needed
3. Set BPV, ND Tree, NU BOPE, test as per PTD
4. Pull BPV, MU landing joint and BOLDS
5. Pull 4-1/2” tubing, pre rig cut ~ 3,425’ MD, confirm with OE
6. MU Mill BHA and perform scraper/cleanout run to top of 4-1/2” tubing stub.
7. Displace well to 9.5 ppg milling fluid
8. PU storm packer and hang off mill bha, test storm packer to 2500 psi
9. ND BOPE and tubing spool and install 7” casing spool. NU and shell test same.
a. Barriers:
i. Tested cement plug and IA, 2500 psi
ii. KWF
iii. PT Storm Packer
10. Release storm packer and POOH LD mill bha
11. MU Whipstock and Mill assembly and RIH to set depth ~3,300’ MD
12. Orient whipstock to ~ 100* azimuth with GWD, set anchor and shear off
13. Ensure wellbore 9.5ppg milling fluid in wellbore
14. Test 9-5/8” casing to 2500 psi f/ 30 min, chart test
15. Mill 9-5/8” window & 20’ of new hole
16. Pull milling assembly back into casing, RU and perform FIT to 12.5 ppg EMW
a. If unable to achieve 12.5 ppg EMW, utilize prior 13-3/8” FIT t/ 12.5 ppg EMW
b. See Attachment 12 for surface casing FIT value
17. POOH and LD milling assembly, gauge mills
a. If mills are under gauge, PU back up mills and dress of window
18. MU motor BHA, RIH, trip through window with pumps off and no rotary, drill to ~3700’MD
to bury 8-1/2” x 9-7/8” RSS BHA. POOH.
19. MU 8-1/2” x 9-7/8” RSS BHA, TIH, trip through window with no pumps or rotary, trip to
*Email digital data of casing test and FIT to AOGCC upon
completion of FIT.
* Verify cement plug test prior to ND BOPE.
*AOGCC Witnessed BOP Test to 3500 psi, Annular to
a minimum of 2500 psi.
Prudhoe Bay East
06-12C Producer
bottom. Displace well to drilling fluid, 9.7 ppg
20. Drill 8-1/2” x 9-7/8” hole to ~200’ MD above HRZ
21. CBU and perform short trip to window
22. TIH to bottom, add black product to mud for shale stability, and drill ahead to TD 8,807’
MD
a. Hold constant bottom hole pressure of ~10.5 – 11.0 ppg EMW for shale stability
23. At TD CBU, and increase MW t/ 10.5 for shale stability
24. POOH to window offsetting swab with MPD, pull BHA through window with no pumps or
rotary, POOH and LD BHA
25. Run 7” long string to TD
a. Circulate casing every ~ 2000’MD while RIH, max rate 4 bpm to not exceed drilling
ECDs
26. Cement 7” casing as per cement program,
27. Lay down landing joint and RILDS
28. Freeze protect 9-5/8” x 7” annulus and
29. Laydown 5” DP and PU 4” DP
30. MU 6-1/8” cleanout assembly, TIH top of 7” shoe track
31. PT 7” casing to 2500 psi, chart test
32. Drill out 7” shoe track & 20’ of new hole
33. Pull back into 7” shoe, perform FIT t/ 10.5 ppg EMW
34. POOH, LD Cleanout BHA
35. MU 6-1/8” RSS BHA, RIH to bottom
36. Drill 6-1/8” lateral as per directional plan to TD 12,421’ MD
37. CBU, and POOH to 7” shoe
38. POOH and LD BHA
39. RU and run 4-1/2” Liner on 4” DP to TD
40. Cement 4-1/2” Liner as per plan
41. Set Liner Hanger/liner top packer, release running tool
42. CBU to remove any cement above liner top packer
43. RU and PT liner to packer / 7” annulus t. 1500 psi f/ 10 min, charted
44. POOH LD running tool
45. Run 4-1/2” tubing as per tally
46. Land Hanger, RILDS
47. Install TWC, ND BOPE, NU Tree
48. PT tubing hanger void 500/5000 psi, PT tree to 250/5000psi
49. Spot CI Brine
50. Drop Ball & Rod, set tubing packer
51. PT Tubing 3500 psi, bleed tubing to 1000 psi & PT IA to 3500 psi
a. All tests 30 min, charted
52. Bleed Pressure on tubing to 0 psi, shear SOV, spot freeze protect
53. RU jumper to allowed freeze protect to swap
54. RDMO
*Email digital data of casing test, cementing summary,
and FIT to AOGCC upon completion of FIT.
Prudhoe Bay East
06-12C Producer
Post Rig Work
1. Wireline: Pull ball and rod, RHC Plug
2. Service Coil: Perforate Well (Separate Sundry)
3. Well Tie In
4. Put Well on Production
Note: This well will not be fracture stimulated
Prudhoe Bay East
06-12C Producer
14. Discussion of Mud and Cuttings Disposal and Annular Disposal
20 AAC 25.005 (c) (14)
A general description of how the operator plans to dispose of drilling mud and cuttings and a
statement of whether the operator intends to request authorization under 20 AAC 25.080 for an
annular disposal operation in the well.
All cuttings and mud generated during drilling operations will be hauled to Prudhoe G&I on Pad 4.
Drilling mud and cuttings will be hauled offsite as it is generated via truck.
There is no intention to request authorization under 20 AAC 25.080 for any annular disposal
operation in the well.
15. Proposed Variance Request
There are no variance requests for this well at this time.
Prudhoe Bay East
06-12C Producer
Attachment 1: Location & GIS Maps
Prudhoe Bay East
06-12C Producer
Prudhoe Bay East
06-12C Producer
Attachment 2: BOPE Equipment
Innovation Rig BOPE Schematic
Per 20 AAC 25.035(e)1.A
For an operation with a maximum potential surface pressure of 3,000 psi or less, BOPE must have at least
three preventers, including
(i) one equipped with pipe rams that fit the size of drill pipe, tubing, or casing being used, except
that pipe rams need not be sized to bottom-hole assemblies (BHAs) and drill collars;
(ii) (ii) one with blind rams, except that a subsea BOPE assembly must have blind/shear rams in
place of blind rams; and
(iii) (iii) one annular type
Prudhoe Bay East
06-12C Producer
BOPE Configuration:
x 13-5/8” Annular
x UPR: 2-7/8” x 5-1/2” VBR
x Blind Rams
x LPR: 4-1/2” x 7” VBR2
Innovation Rig Choke Manifold Schematic
Prudhoe Bay East
06-12C Producer
Attachment 3: Hole Section Hazards
8-1/2” x 9-7/8” Intermediate Hole Section
Hazard Mitigations
Overpressure SV1 & Ugnu Due to offset cretaceous injection, there may be higher than
normal pressure ein the SV1, Ugnu and Schrader Sands, ML PP
9.7ppg. MW will be increased accordingly. Utilize MPD to monitor
for pressure on connections.
Hole Cleaning Maintain rheology of mud system, 6 rpm value greater than hole
diameter. Maintain flow rates of 200 ft/min AV, 120 rpm. Do not
out drill our ability to clean the hole. Pump sweeps as needed.
Montior ECDs
Lost Circulation / Breathing Monitor ECD with MWD tools. Monitor active mud system. Pump
LCM as needed. Ensure adequate LCM is available, follow lost
circulation decision tree, Do not drill into sag any further than
necessary. Breathing has been seen, treat all flow at wellbore
influx until proven otherwise.
Casing run Underreamed hole section, sufficient wellbore clean up, pinned
float shoe, circulation schedule while RIH, monitor drag trends,
watch casing ciruclatoin rates and ECDs
Tight Hole/Stuck Pipe Conduct wiper trip if required, drilling jars included in BHA,
monitor torque and drag trends, use sufficient mud weight / back-
pressure to hold back formations – MPD to maintain CBHP
Shale Stability Hole section will cross multiple shale formations. Directional plan
and MW have been chosen based upon historical stability
window. Ensure black product has been added to the mud system,
MPD to maintain CBHP to minimize pressure cycling, swab
pressures. Ensure sufficient MW is left in the well at TD.
Pack Off During Cementing Clean up well bore at TD, and prior to running casing. Stage
circulation rates up following circulation schedule Circulate
bottoms up at multiple depths to condition mud the way in the
hole. Circulate at TD to planned cementing rates and ensure hole
is clean. Keep circulation rates below drilling ECDS, model
accordingly, low displacement rates
Gas Cut Mud Gas cut mud as been seen. Ensure sufficient MW is used during
hole section. Monitor wells and MPD while drilling and on
connections. Ensure gas detectors are tested and functioning.
Watch swab effect while TOOH
Intermediate Casing Pick Due to MW required for shale stability and low sag PP, we want to
call intermediate casing point with the least bout of sag open as
possible. Follow geologist for casing pick depth and procedure,
‘scrathc and sniff’.
Prudhoe Bay East
06-12C Producer
6-1/8” Production Hole Section
Hazard Mitigations
Offset Injection There are no offset injectors that need to be shut in
Lost Returns / Breathing Monitor ECD with MWD tools. Have adequate LCM available.
Breathing has been seen, treat all flow as influx until proven
otherwise. Have sufficient fluid available.
Faulting Be prepared for faulting, known and unknown. Losses can occur
after faults, if losses are extreme consider suspending well
operations.
Hole Swabbing Reduce tripping speed, lower mud rheology, offset swab with
MPD, pump out of the hole if required.
Abnormal Pressures Lower than normal pressures in the target reservoir. Ensure LCM
in the mud systems and monitor fluid systems.
Tight Hole/Stuck Pipe Conduct wiper trip if required, drilling jars included in BHA,
monitor torque and drag trends, use sufficient mud weight / back-
pressure to hold back formations.
Anti Collision See Close Approaches in Directional Plan attachment. Continually
monitor surveys for magnetic interference.
Shale / Wellbore Instability Maintain adequate mud weight / back-pressure for wellbore
stability. Monitor cuttings returns, LWD logs, and drilling.
Production hole could cross multiple shale formations. MPD to
minimize pressure cycles on formation.
Zone 3 Crossings Wellplan has 4 zone 3 crossings, which has high chert content,
slow rop, and historically rough on bits. A bit trip may be
necessary in the production hole section. Ensure correct bits are
available for backup. Also ensure proper WOB is being used prior
to tripping
Prudhoe Bay East
06-12C Producer
DS 06 has a history of H2S. Ensure detectors are tested and functioning.
x AOGCC to be notified withing 24 hours if H2S is encountered more than 20 ppm during drilling
operations
x Rig will have fully functional automatic H2S detection equipment meeting the requirements of 20
AAC 25.066
x In the event H2S is detected, well work will be suspended and personnel evacuated until a
detailed mitigation procured can be developed.
DS 06 H2S History:
Wells with over 100ppm H2S readings:
There are no wells with H2S 100ppm or greater
Prudhoe Bay East
06-12C Producer
Attachment 4: LOT / FIT Test Procedure
Prudhoe Bay East
06-12C Producer
Attachment 5: Cement Summary
7” Intermediate Casing Cement
OH x
CSG 8.5” x 9-7/8” OH x 7” Casing
Basis
Cement
Vol Open hole volume + excess + 120’ ft shoe track
TOC 500’ MD above Sag (Top Sag: 8803’ MD, TOC 8303’ MD)
Total
Cement
Volume
Spacer 60 bbls of 11.0 ppg Tuned Spacer
Cement 30% Open Hole Excess
15.8ppg:31.7 bbls, 177.3 ft3, 152.8 sks HalCem Class G – 1.16 cuft/sk
BHST 170 deg F
Displacement (8807’ – 120’) * .0371bpf =322.3 bbl
4-1/2” Liner Cement
OH x
CSG 6-1/8” OH x 4-1/2” Liner
Basis
Cement
Vol CH volume (150’ 7” Liner Lap) + (OH volume x 30%) + 120’ ft shoe track
TOC 7” x 5” Liner Top, ~ 8,657’ MD
Total
Cement
Volume
Spacer 30 bbls of 11.0 ppg Tuned Spacer
Cement 30% Open Hole Excess
15.8ppg: 83.3 bbls, 467.3 ft3, 402.9 sks HalCem Class G – 1.16 cuft/sk
BHST 170 -180 deg F
Displacement
(12421 – 8657 – 120) * .0152bpf (4-1/2” capacity) +
8657 * .0103 bpf (4” dp capacity)
55.4 + 89.2 =144.6 bbl
Section Calculation Vol (bbl) Vol (ft3) Vol (sks)
8.5" Pilot Hole x 7" (120') (8807 - 8687)' x 0.0226 bpf x 1.3 = 3.6 20.2
9.875" OH x 7" (8687 - 8303) x .0471bpf x 1.3 = 23.5 131.8
7" Shoetrack 120' x 0.0372 bpf = 4.5 25.2
Total Tail 31.6 177.3 152.8Tail
Section Calculation Vol (bbl) Vol (ft3) Vol (sks)
6-1/8" OH x 4-1/2" (12,421 - 8807)' x 0.0168 bpf x 1.3 = 78.9 442.6
7" CH x 4-1/2" (8807 - 8657) x .0175 bpf = 2.6 14.6
4-1/2" Shoetrack 120' x 0.0152 bpf = 1.8 10.1
Total Tail 83.3 467.3 402.9Tail
Prudhoe Bay East
06-12C Producer
Attachment 6: Prognosed Formation Tops
SV3 SV (Sand) Water ͓͒͒͐ ϱ͖͒͑͑ϟ͖͘
1430 8.4
SV2 SV (Sand) Water ͔͔͒͏ ϱ͓͒͗͐ϟ͏͔
1521 8.4
SV1 SV (Sand) Water ͔͒͒͘ ϱ͖͒͗͗ϟ͓͐
1956 9.7
UG4A Ugnu (Sand) Water ͓͔͏͓ ϱ͓͓͑͏ϟ͔͕
2230 9.7
UG3 Ugnu (Sand) Water ͓͖͑͘ ϱ͓͖͏͓ϟ͖
2373 9.7
UG1 Ugnu (Sand) Water ͔͔͒͒ ϱ͔͑͒͗ϟ͔͔
2642 9.7
WS2 Schrader (Sand) Water ͔͓͑͘ ϱ͔͖͗͐ϟ͖͗
2935 9.7
WS1 Schrader (Sand) Water ͕͕͐͏ ϱ͕͏͔͏ϟ͓͒
3052 9.7
CM3 Colville (Shale)͕͓͏͏ ϱ͕͕͑͗ϟ͑͗
CM2 Colville (Shale)͕͐͘͏ ϱ͕͖͗͗ϟ͓͐
CM1 Colville (Shale)͖͕͕͗ ϱ͖͔͐͑ϟ͓͓
THRZ HRZ (Shale)͗͏͕͗ ϱ͖͗͗͒ϟ͓͖
BHRZ HRZ (Shale)͗͑͗͒ ϱ͗͏͔͑ϟ͐͘
LCU Kingak (Shale)͔͗͒͗ ϱ͗͐͒͘ϟ͗͘
TSGR Sag River (Sand) Gas ͗͗͏͖ ϱ͔͗͏͐ϟ͔͘
3227 7.3
TSHU Shublik (Shale / Carbonate)͓͗͗͗ ϱ͔͕͗͒ϟ͖͘
3241 7.3
TSAD Ivishak (Sand) Gas ͓͕͗͘ ϱ͕͗͐͗ϟ͖͕
3227 7.2
42N Ivishak (Sand) Gas ͐͑͐͘ ϱ͖͓͔͗ϟ͓͘
3229 7.1
TCGL Ivishak (Conglomerate) Oil ͔͑͗͘ ϱ͗͗͑͐ϟ͔͑
3257 7.1
BCGL Ivishak (Conglomerate) Water ͔͐͘͏ ϱ͗͘͏͏ϟ͐͗
3286 7.1
BCGL Ivishak (Conglomerate) Water ͖͘͏͏ ϱ͗͘͏͓ϟ͓͘
TCGL Ivishak (Sand) Oil ͐͏͏͔͐ ϱ͓͗͗͐ϟ͕
42N Ivishak (Sand) Gas ͐͏͒͏͐ ϱ͖͖͗͗ϟ͒͒
42N Ivishak (Sand) Oil ͐͐͏͏͒ ϱ͖͖͗͘ϟ͑
TCGL Ivishak (Conglomerate) Water ͐͐͑͗͑ ϱ͔͗͗͏ϟ͗͗
TCGL Ivishak (Sand) Water ͐͐͐͑͘ ϱ͔͗͗͏ϟ͓
42N Ivishak (Sand) Oil ͔͐͑͐͘ ϱ͖͗͗͏ϟ͔͘
TD Ivishak (Sand) Gas ͓͐͑͑͐
TOP NAME LITHOLOGY EXPECTED
FLUID
MD
(FT)
ANTICIPATED FORMATION TOPS & GEOHAZARDS 06-12C wp2
TVD
(FT)
TVDSS
(FT)
Est. ML
PP ML PP Gradient
Prudhoe Bay East
06-12C Producer
Attachment 7: Well Schematic
Post Sundry Schematic, Well Status When Rig Arrives
Prudhoe Bay East
06-12C Producer
Prudhoe Bay East
06-12C Producer
Attachment 8: Formation Evaluation Program
8-1/2” x 9-7/8”” Intermediate Hole
LWD Gamma Ray (including at-bit Gamma)
Resistivity
6-1/8” Production Hole
LWD
Gamma Ray
Resistivity
Density Neutron
Mudlogging
No mudlogging is planned for 06-12C
Prudhoe Bay East
06-12C Producer
Attachment 9: Wellhead Diagram
Prudhoe Bay East
06-12C Producer
Attachment 10: Management of Change
Prudhoe Bay East
06-12C Producer
Attachment 11: Drill Pipe Specs
Prudhoe Bay East
06-12C Producer
Prudhoe Bay East
06-12C Producer
Attachment 12: 06-12 Surface Casing FIT
Prudhoe Bay East
06-12C Producer
Attachment 13: Directional Plan
Intermediate Section Offset Wells with CF < 1.0:
x 06-12/12A/12APB1/12APB2/12B/12BL1, Close approach at 3,301’ MD, is the parent well bore
for this sidetrack and 06-12C will deviate from it
Production Section Offset Wells with CF < 1.0:
x There are no wells with CF > 1.0 in the production hole section
! "
##
" $
3000375045005250600067507500825090009750True Vertical Depth (1500 usft/in)-3000 -2250 -1500 -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250Vertical Section at 131.93° (1500 usft/in)06-1206-12APB106-12APB206-12BL106-12A06-12B7" x 8-1/2"4-1/2" x 6-1/8"35004000450050005500600065007000750080008500900095001 0 0 0 0
1 0 50 011000115001200 0
1 2 4 2 106-12C wp02KOP: 12.01º/100' : 3300' MD, 3299.86'TVD : 54.99° LT TFEnd Dir : 3317' MD, 3316.85' TVDStart Dir 3º/100' : 3417' MD, 3416.78'TVDEnd Dir : 3689.23' MD, 3687.18' TVDStart Dir 2º/100' : 6828.93' MD, 6776.47'TVDEnd Dir : 8077.93' MD, 7944.81' TVDStart Dir 8º/100' : 8875.29' MD, 8628.29'TVDStart Dir 4º/100' : 9612.79' MD, 8975.62'TVDEnd Dir : 10012.79' MD, 8920.13' TVDStart Dir 4º/100' : 10152.79' MD, 8881.54'TVDStart Dir 4º/100' : 10665.84' MD, 8810.06'TVDStart Dir 4º/100' : 11133.84' MD, 8881.27'TVDStart Dir 4º/100' : 11598.94' MD, 8952.03'TVDEnd Dir : 12056.13' MD, 8880.78' TVDTotal Depth : 12421.03' MD, 8768.02' TVDSV3SV2SV1UG4AUG3UG1WS2WS1CM3CM2CM1THRZBHRZLCUTSGRTSHUTSADBCGLTCGL42NHilcorp North Slope, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: Plan: 06-12Ground Level: 38.31+N/-S +E/-WNorthingEastingLatittudeLongitude0.00 0.00 5940584.44 685318.20 70° 14' 33.6286 N 148° 30' 11.4496 WSURVEY PROGRAMDate: 2024-12-23T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool96.81 3300.00 06-12 Top GYD-CT-CMS Gyrodata (06-12) 3_Gyro-CT_Drill pipe3300.00 3700.00 06-12C wp02 (Plan: 06-12C) 3_MWD_Interp Azi+Sag3700.00 8807.00 06-12C wp02 (Plan: 06-12C) 3_MWD+IFR2+MS+Sag8807.00 12421.03 06-12C wp02 (Plan: 06-12C) 3_MWD+IFR2+MS+SagFORMATION TOP DETAILSTVDPath TVDssPath MDPath Formation3337.60 3272.79 3337.76 SV33545.86 3481.05 3546.44 SV23943.22 3878.41 3949.45 SV14485.37 4420.56 4500.45 UG4A4769.51 4704.70 4789.22 UG35303.36 5238.55 5331.78 UG15882.68 5817.87 5920.56 WS26115.15 6050.34 6156.82 WS16351.09 6286.28 6396.61 CM36853.22 6788.41 6907.03 CM27577.25 7512.44 7664.70 CM17948.28 7883.47 8081.97 THRZ8117.72 8052.91 8279.65 BHRZ8204.70 8139.89 8381.12 LCU8566.76 8501.95 8803.51 TSGR8601.78 8536.97 8844.37 TSHU8683.57 8618.76 8941.73 TSAD8810.30 8745.49 9116.29 42N8843.14 8778.33 9170.17 42N8844.01 8779.20 9171.68 42N8845.76 8780.95 9174.71 42N8886.33 8821.52 9251.35 TCGL8906.41 8841.60 9295.35 TCGL8915.21 8850.40 9316.53 TCGL8915.69 8850.88 9317.73 TCGL8964.99 8900.18 9489.27 BCGL8969.75 8904.94 9521.07 BCGLREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: 06-12, True NorthVertical (TVD) Reference:06-12C planned @ 64.81usftMeasured Depth Reference:06-12C planned @ 64.81usftCalculation Method: Minimum CurvatureProject:Prudhoe BaySite:06Well:Plan: 06-12Wellbore:Plan: 06-12CDesign:06-12C wp02CASING DETAILSTVD TVDSS MD SizeName8569.75 8504.94 8807.00 7 7" x 8-1/2"8768.02 8703.21 12421.03 4-1/2 4-1/2" x 6-1/8"SECTION DETAILSSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation1 3300.00 0.35 163.46 3299.86 -22.54 6.96 0.00 0.00 20.24 KOP: 12.01º/100' : 3300' MD, 3299.86'TVD : 54.99° LT TF2 3317.00 2.26 115.74 3316.85 -22.73 7.28 12.01 -54.99 20.60 End Dir : 3317' MD, 3316.85' TVD3 3417.00 2.26 115.74 3416.78 -24.45 10.83 0.00 0.00 24.39 Start Dir 3º/100' : 3417' MD, 3416.78'TVD4 3689.23 10.28 97.31 3687.18 -29.88 39.81 3.00 -23.40 49.58 End Dir : 3689.23' MD, 3687.18' TVD5 6828.93 10.28 97.31 6776.47 -101.18 595.56 0.00 0.00 510.68 Start Dir 2º/100' : 6828.93' MD, 6776.47'TVD6 8077.93 31.00 144.00 7944.81 -380.00 900.00 2.00 62.55 923.48 End Dir : 8077.93' MD, 7944.81' TVD7 8807.29 31.00 144.00 8570.00 -683.91 1120.80 0.00 0.00 1290.838 8875.29 31.00 144.00 8628.29 -712.24 1141.39 0.00 0.00 1325.08 Start Dir 8º/100' : 8875.29' MD, 8628.29'TVD9 9612.79 90.00 144.00 8975.62 -1208.90 1502.23 8.00 0.00 1925.41 Start Dir 4º/100' : 9612.79' MD, 8975.62'TVD10 10012.79 106.00 144.00 8920.13 -1528.32 1734.30 4.00 0.00 2311.51 End Dir : 10012.79' MD, 8920.13' TVD11 10152.79 106.00 144.00 8881.54 -1637.19 1813.40 0.00 0.00 2443.11 Start Dir 4º/100' : 10152.79' MD, 8881.54'TVD12 10665.84 90.00 130.98 8810.06 -2008.88 2155.68 4.00 -140.00 2946.12 Start Dir 4º/100' : 10665.84' MD, 8810.06'TVD13 11133.84 72.45 124.37 8881.27 -2290.78 2519.75 4.00 -160.00 3405.34 Start Dir 4º/100' : 11133.84' MD, 8881.27'TVD14 11598.94 90.00 130.63 8952.03 -2569.83 2882.45 4.00 20.00 3861.65 Start Dir 4º/100' : 11598.94' MD, 8952.03'TVD15 12056.13 108.00 133.91 8880.78 -2872.04 3215.38 4.00 10.00 4311.28 End Dir : 12056.13' MD, 8880.78' TVD16 12421.03 108.00 133.91 8768.02 -3112.74 3465.38 0.00 0.00 4658.11 Total Depth : 12421.03' MD, 8768.02' TVD
-4550
-4225
-3900
-3575
-3250
-2925
-2600
-2275
-1950
-1625
-1300
-975
-650
-325
0
325
650
975
1300
South(-)/North(+) (650 usft/in)0 325 650 975 1300 1625 1950 2275 2600 2925 3250 3575 3900 4225 4550
West(-)/East(+) (650 usft/in)
2 5 0 0
3750
06-12
TIP
TIP
7" x 8-1/2"
4-1/2" x 6-1/8"475055006250700075007750
8 0 0 0
8250
8500
8 7 5 0876806-12C wp02
KOP: 12.01º/100' : 3300' MD, 3299.86'TVD : 54.99° LT TF
End Dir : 3317' MD, 3316.85' TVD
Start Dir 3º/100' : 3417' MD, 3416.78'TVD
End Dir : 3689.23' MD, 3687.18' TVD
Start Dir 2º/100' : 6828.93' MD, 6776.47'TVD
End Dir : 8077.93' MD, 7944.81' TVD
Start Dir 8º/100' : 8875.29' MD, 8628.29'TVD
Start Dir 4º/100' : 9612.79' MD, 8975.62'TVD
End Dir : 10012.79' MD, 8920.13' TVD
Start Dir 4º/100' : 10152.79' MD, 8881.54'TVD
Start Dir 4º/100' : 10665.84' MD, 8810.06'TVD
Start Dir 4º/100' : 11133.84' MD, 8881.27'TVD
Start Dir 4º/100' : 11598.94' MD, 8952.03'TVD
End Dir : 12056.13' MD, 8880.78' TVD
Total Depth : 12421.03' MD, 8768.02' TVD
CASING DETAILS
TVD TVDSS MD Size Name
8569.75 8504.94 8807.00 7 7" x 8-1/2"
8768.02 8703.21 12421.03 4-1/2 4-1/2" x 6-1/8"
Project: Prudhoe Bay
Site: 06
Well: Plan: 06-12
Wellbore: Plan: 06-12C
Plan: 06-12C wp02
WELL DETAILS: Plan: 06-12
Ground Level: 38.31
+N/-S +E/-W Northing Easting Latittude Longitude
0.00 0.00 5940584.44 685318.20 70° 14' 33.6286 N 148° 30' 11.4496 W
REFERENCE INFORMATION
Co-ordinate (N/E) Reference:Well Plan: 06-12, True North
Vertical (TVD) Reference:06-12C planned @ 64.81usft
Measured Depth Reference:06-12C planned @ 64.81usft
Calculation Method:Minimum Curvature
%
&
#
'
()*
'
+
+
, -" !!"
#$%& '
* . (
* )*
-*
'
#$%& '
! "
'
+
,
-
&
/ *&
%
-
0
&*&-
. /012
3
)4 . /0 )45 5 - 3
- 6,14 ,),1
)*7
$
"
-8+
'
-88
'
&
#
# .
1
! " .
2 .
/ ,.
, $
'
'
'
9 %$
:
;.$ &&%;.
&$/$%&&
;%
/9 $<$%; &;
$&9=< .% $ +
+
+
# .
#
2 .
! " .
'
324+
3!4
1
'
'
'
/ #,
'
'
%
%
;.$;&$%$$
&;= &%
=&%= + "2 , =&%.& '
%;
/9 $<==% &
$&9=< %$$.+
+
*
567
."
5(7
&
* *
8.
567
- !&-.
>> $ $? =? ; $%= &% ;/;%...$;.;
" )
8 !
* . (
)
) *
" &5()*7
5 '7
3!4
5 '7
*
567
324+
5 '7
( 9*
"==%
= %.=%% %;
:
567
8; &"
567
324+
5 '7
(
567
3!4
5 '7
-
*
"
5 '7
)
*
"
5 '7
* . .
564 '7
$
564 '7
(
564 '7
()*
&
'
%%%%%. %;$= ..%& =%$%=;==%= =;%;
;$%.. &%/ % $ % /% & %/=== %&; ;%/$ % == /%= ; %$
%%%% %&= $%$;=$ %/& ;%/$ % =$ /%==; %./
=%$ %// %.;=%=.%& .%&&=&/% &./%= % &=&.% == %=/
%%%%;.;%; % &//%$/./%= % && &%.=/ %
%;;=%/$ % %.% =&%/.$$%& $$%= %&//%.=/&&%
%%%% %& &=%. &;/% $$%= %&&/% .&;;% .
%%%% $ %=. / % $& &% . $$%= %&&/;% .&;=%$&
%%&%&% ; % = &%.&./;% $$%.%. %/.&. %&
%%$%$% /=$%= ; &%= &. % = $$% % %/.&&;;%=
%%%% & =%$ =/% .&&& %;$ $$% % ; %/.&& %/=
$% %;$ =% $% ;;%& &%&&&& % =%.&.% ;%&$&/$;% ;
% %$ =%/;$% ; .%/; .%/&&&& % / $%=// %$; ==%&$&& %$
% %=;=%//$% && %$; ;.%&=&.; %= =%=.% ;.&%.$&&&/%
%%/ =%.$$%= ;%=& &/ %$&&&%/& ==%. &% ;% =&& ;%./
%%%%=$;%=& = %/$&/&% ==%. &% $ %=&/=%
%
&
#
'
()*
'
+
+
, -" !!"
#$%& '
* . (
* )*
-*
'
#$%& '
! "
'
+
,
-
*
"
5 '7
:
567
8; &"
567
324+
5 '7
-
! " .
5 '7
-
2 .
5 '7
3!4
5 '7
,
)
*
"
5 '7
()*
'
*#
<=><
)
%; % %; % %%&;= &% ;.$;&$%$$ =&%= % %
.%& %= .%& % . % /&%==&;= &% ;.$;&$% ;= %%$$ % =
.%& %= .%& % % . ;%/.&;= &%=;.$;&=%/& = %% ; %=
.%& %; .%& %=$ %=; /;%;&;= /%&&;.$;&=%. = %%$= %=
=.%& %=. =.%& % $ % & ;%&/&;= &%&;.$;& %=== %..% = %=
$.%& %$ $.%& %& % /%&;= &% .;.$;& %$$= %..%. %&.
;.%& % & ;.%& =%$ % /$%;/&;= &%=.;.$;& %;;= %..% = %=;
.%& % & .%& =%/ %= &%$&;= &%= ;.$;&%&= %..% %;$
/.%& %; /.%& =%.= %; ;% &;= &% $;.$;&%; /= %..% %;.
&.%& % &.%& $%; % $%/ &;= &%= ;.$;&%=.&= %..% %/
..%& % ; ..%& $% $ % ; $;%&;= &%$;;.$;&% .= %..%$ %.$
.%& %$ .%& $%; %$= $% &;= &%/$;.$;/.%& = %..% / =%$
.%& %; .%/. ;%= %&& $$%$.&;= .% ;.$;/.% = %.&%& $%
.%& %== .%/. ;%. % / ;=%= &;= .% ;.$;/&%;; = %.&% & $%.
=.%& %/$ =.%/. %& %= &&%= &;= .%/;.$;//% == %.&%; ;%;
$.%& %& $.%/& &% ; % = &% &;= .%;=;.$;/%= $= %./% % &
;.%& %& ;.%// .%;$ %./ &%;=&;= .%$;.$;/$%. ;= %.% /%
.%& %& .%/ %. %& &/%&;= .% /;.$;/=%; = %.;% /%.
/.%& %&$ /.%/; %=. %;. &.% &;= .% ;.$;/ %/ /= %.$%$ &%/
&.%& %&; &.%/= =%&$ %= .=%$&;= &%&;;.$;/% &= %. % .%$&
..%& %= ..%/= ;%/ % %&;= &%; ;.$;.%=& .= %. % ; %
.%& %= .%/ ;%& %$ %.=&;= &% .;.$;&%= = %. %=$ %
.%& % = .%/ % $ %; =% =&;= &%.;.$;&%= = %. % = %$
.%& % / .%/ %$= %== $ %.&;= &% /;.$;&% = %. % ; %/=
=.%& % $ =.%/ %& % ;&%;&&;= &%;;.$;/%= == %. %& % ;
$.%& %$ $.%/ /%=& % = ;;%&&;= &%/;.$;/%/ $= %. % %/
;.%& %/ ;.%/ &% = % $%$&;= .% ;.$;% = ;= %.% = %$
.%& %/. .%/ .% $ %$& /%& &;= % ;;.$;;%=$ = %.% =%&.
/$%& %/. /$%/ .% %;/ /% &;= % $;.$;;% & =.%.% $%
<<4=?
/.%& %/; /.%/ .%&. % .%.;&;= % &;.$;$% /= %&.% ;%
&.%& % &.%. %$; =%; ;% &;= %=;;.$;$%. &= %&&% $ %=&
..%& %;. ..%& %.= $%;. .%.$&;= =%=;.$;=%= .= %&/% /%$
=.%& %$ =.%& %$$ ;%;= %;&;= $% ;.$;=% $== %&/% &%$$
= .%& %;/ = .%/ %. %$; %;/&;= ;% .;.$; %;= = %&%. .%$/
= .%& %=; = .%/ %; %.; $%$/&;= ;%/ ;.$; % = = %&%=. %
==% %=; = ..%& %;$ %. =%$&;= ;%/ ;.$; %&= =;%;% . % $
@9>A4B<<B-*<>=B()*C>6#((
== /% % == %&; %/= /% & ;%/$&;= %=;.$; %&.= ; %$ % %
2* <<DB-*<<>=B()*
===/%/ % ===/% =%. &% ;%/$&;= %/&;.$; %;= / %/.% %=.
)<
=$% % ==..%/. $% ; % ;%/$&;= .% ;.$;%;;===$%.&% =%/;
=$ /% % =$ %/& $%$; %&= ;%/$&;= .%=;.$;% /==; %./% $%=.
* <A4B<CDB-*<C>D=B()*
%
&
#
'
()*
'
+
+
, -" !!"
#$%& '
* . (
* )*
-*
'
#$%& '
! "
'
+
,
-
*
"
5 '7
:
567
8; &"
567
324+
5 '7
-
! " .
5 '7
-
2 .
5 '7
3!4
5 '7
,
)
*
"
5 '7
()*
'
*#
<C<C>=
)
=;% $%; =$..% ;%.$ ;%;& =%$&;==$%$ ;.$;;&%&.=$=$%& =% &%.
=;$%$$ % =;$;%& %&$ .%& %&.&;==&%;;.$;;&% =$& %;=% = %/
)
=% /% =;..%$ /%.= %/..%&&;=$$%.$;.$;;/% =;=$% ==% =&%
=&.% = % & =&/% & .%&& =.%& ./%= &;=;&%/=;.$;;;%;;= %=/=% $.%;&
2* <=><B-*<=D>=B()*
=/% % & =./%// =% $ %/ ./%= &;=%$;.$;;;%=;== %.% ; %
=&% % & =/.% / = %=. ;.%$ ./%= &;=/&%=.;.$;;=%; =/= %=% ;%&;
=.% % & =&.$%; =$% //% ./%= &;=.% $;.$;; %.=& .%/;% &%;=
=.$.%$; % & =.$=% =;%/. &;%&/./%= &;$$%. ;.$;;%/&=&/&%$ % &/%/.
)
$% % & =.. %. =%.= .$%& ./%= &;$ =%&.;.$;$.%&;=. &% ;% .;%
$ % % & $. %=; =.% %; ./%= &;$= %$;.$;$&% $ %;$% .%.
$ % % & $ &.%/$ $ %$& =% ./%= &;$$.%=.;.$;$% &$ $%.=% $%;.
$=% % & $ &&% $ $=%/; $/%. ./%= &;$/% $;.$;$$%=;$ =%==% =.% &
$$% % & $=&%;= $% ;% ./%= &;$&$%&.;.$;$ %; $= %/ % ;=%.
$;% % & $$&$%.= $&% . &=%= ./%= &;; %$;.$;$%&$$ % % &%;
$;%$; % & $$&;%=/ $&%= &=%$./%= &;; %/ ;.$;$%/$$ %;% &%/
1/C8
$% % & $;&=%= ;%; % ./%= &;; %=.;.$;=&%&$$; &%; % &=%==
$/% % & $& %/ ; %&= &%/ ./%= &;;=&% $;.$;=/% $ %. % .&%
$/&.% % & $/.%; ;$%& =$%; ./%= &;;;=%.&;.$;=;%=/$/$%/% %
1/<
$&% % & $/&% ;;% =%$ ./%= &;;;;%&.;.$;=;% /$/ ;%=% %/
$.% % & $&/&%; ;/%=/ ;$% ./%= &;;/=%$;.$;==%=$$& =%/% /%=.
;% % & $./%. ;.%$ / %&=./%= &;;. %=.;.$;= %;$. %.% $ %&
; % % & ;/;%= %. &.%;=./%= &;.% $;.$; .%/; %$.% ;%/
; % % & ; /=%. $% & =/% =./%= &; %&.;.$; /%&=; &%&&% / %$;
;=% % & ; / %. %$ = $%.=./%= &;$$%$;.$; %; /% &% &% $
;== %/& % & ;==%= /% & ==%;;./%= &;;% .;.$; ;%$ ; =&%;;% .%&
1/
;$% % & ;=/%$& &%/= =$ %=./%= &; %=.;.$; $% ;=;%/% =%&
;;% % & ;$&%&& / % =%==./%= &;&% $;.$; %==;$$%/% = ;%;
;% % & ;;/% / /=% / =/&%=./%= &;./%.;.$; %$.;; %$% ==%
;/% % & ;;%/ /;%;$ =.;%/=./%= &;/ ;%;;.$; &%;%&% =$$%&&
;&% % & ;/$% //%& $ =%$=./%= &;/==%$;.$; %& ;..% ;% =;.%;/
;.% % & ;& %$; &%& $= % =./%= &;/; % ;;.$; $%..;/./%$% =/$% ;
;. %; % & ;&& %& &%;; $=$%//./%= &;/;$%&;.$; $% ;& /%&/% =//% /
+
% % & ;.%&; & %=; $$&%&$./%= &;/&%.;.$; =% ;;&.%$% =&&%.$
% % & ;.% $ &$% $%;$./%= &;/&%;;.$; %= ;..$%$=% $=%=
;%& % & ;% ; &;%. $/%;../%= &;/.%/=;.$; % /;%=$% $ %./
+
% % & ;/%$ &%&. $&$% $./%= &;&$%$;.$;.%$&. %&=% $ &%=
=% % & ;%= &.% ; %.$./%= &;& % ;;.$;/%; . % % $==%
%
&
#
'
()*
'
+
+
, -" !!"
#$%& '
* . (
* )*
-*
'
#$%& '
! "
'
+
,
-
*
"
5 '7
:
567
8; &"
567
324+
5 '7
-
! " .
5 '7
-
2 .
5 '7
3!4
5 '7
,
)
*
"
5 '7
()*
'
*#
=>=
)
=.% % & =; %. . %= ; .%$./%= &;&=.%=;.$;;%&& &% &% $$/% .
-<
$% % & =;$%$= . %$$ ; .%$./%= &;&=.%.;.$;;%& &.% % $$/%&
;% % & $; %& .=%/ ;=/%=$./%= &;&;/%;;.$;=%.&=&&% % $ %=/
% % & ;; % .;%.& ;;;%$./%= &;&/;%$;.$; % $$&%$ % $//%
/% % & $.% .&% ; ;/ %/$./%= &;&.=% ;;.$;%= ;&$%&% $. %/$
&% % & /$&% %; ;.%$$./%= &;. %.;.$$.&%$/&=% % ;%$=
& &%.= % & //%$/ % & ;.;%;./%= &;. %$;.$$./%.$/ %% ; %&
* A4B==><B-*DD>CDB()*
.% % &$%= =% &%$$ =%.=&;. &%./;.$$.;%& /& %; % ; %&.
./%= %. &;=% =%.; .%/; $%;$&;.=% &;.$$.;%; /&&%$ % ; =%&
-
/% % $ .$$% & .%&; /%;; %/&&;.$&% ;.$$.%&/.%$/ % ;$% /
/ % =%; /$ %/$ .%=$ $/%/. &% =&;.&%.;.$$& %/./%.= % ; %/
/ % ;% . / =&%;. = %. .% ; =% &;..%=;;.$$&%&;//=%/& % ;&%&
/=% %& / =$%/ $&%/ . %;. /%$$& =% &;.$$;=%$=/ .%. % =%$;
/$% &%;= /= .%.. /% / / ;% =%&.&=/% ;;.$$=$%& / ;% & % $=%//
/;% % & /$ $%= &.% /=.%= ==%/& % ;.$$ =%=/=;.%; % /%.&
/% %& /; /%;; ;% /;% =% .&&&%=/;.$=&&% /$; %/$ % / =%;
/$%/ =% /;//% ; ==%$ /& % =/%;/& ;%&;;.$=/%==/; %$$ % /=/%.
-
//% =%. /.% $=%. /. % =&% /& ;%;/;.$=%&/;$$%/. % /; %.$
/&% ;%/ //%=; /;%/ & .% $%/& $=%/&;.$= &%.&/=;%;$ % /.=%
/.% /%= //&.%. = %;; &$/%$$ $ %$& / %./;.$ .$%&=// $%&& % &=/%.&
&% .%; /&//%; =$&%$= &/% $=%=& =% ;.$ ;/%./& %. % &&;%
&//%.= = % /.$$%& =&% .% $$%& /% ;.$ %//&&% % . =%$&
2* =DD><B-*DCC>=B()*
&& %./ = % /.$&% & =& %. . % = $$%& &%$&;.$ ;%;/&&=%$/% . ;%;
(
0
& % = % /.=%/= =&.% .%& $$%& =$% ;.$ /%//&.&%. % .=$%
& % = % &$.%$; $=%&/ .=%. $$%& ;%$ ;.$ /%///.&$%$% .&$%.
& /.%; = % & /%/ $$%; . %/ $$%& .%==;.$ $$% &&; %. % ;%&
$
0
&=% = % & =;% $/ %;= ./% = $$%& .%.;.$ =;%&&/%=;% =;%==
&=& % = % & $%/ ;%== .. %/. $$%&= %/;.$ %/& =.%&.% /% .
# 1
&$% = % & %&& ; $% ../%; $$%&= /%.&;.$.$%.;& ;%/% &;%/
&;% = % &=% ;;;%&/ /%/& $$%&=;.% /;.$;$%$& $ %/.% =%
&% = % &=. %= ;./%;= ;&%; $$%&=.%;;;.$ =% =&= /%;% &%$=
&/% = % &$/&%= =.% &&%= $$%&$ %&$;.=../ % &$ =% % =%/.
&&=%; = % &;%/ & %== .% $$%&$;$% =;.=.. .%&&&; %.;% &&%.=
(/
&&/% = % &;.%/; &=%/. %/ $$%&$;;%= ;.=.. &%$;&;$%.$% .%&
D?E=4?
&&/% . = % &;/% &=%. %& $$%&$;;%$ ;.=.. &%==&;;% .% .%&=
%
&
#
'
()*
'
+
+
, -" !!"
#$%& '
* . (
* )*
-*
'
#$%& '
! "
'
+
,
-
*
"
5 '7
:
567
8; &"
567
324+
5 '7
-
! " .
5 '7
-
2 .
5 '7
3!4
5 '7
,
)
*
"
5 '7
()*
'
*#
=<>D
)
&&$$%=/ = % & %/& ..%= = %= $$%&$/% ;.=.. =% /&;=%./% =.%;
( 1
&&/;% . = % & &% & / % $ $ %=. $$%&$/%&;.=..%; &;=%$/% = ;%&
* =A4B==D>B-*==>B()*
&.% = %.& &$.% $ / %&= $.%& $$%&$&$%=;.=.&.% &;&$%$=&% ==/%&&
&.$ %/= =%= &&=%;/ /$ % =% $$%&$..%$;.=.&/ % && &%/&% = %&
(8*
&.;% =%.& &.% /$% ;%. $$%&; %$;.=.&/%=& ;%=.&% =;%.
.% $%.& &/ .% // %$; &$%$ $$%&; % $;.=.&$ %=&&$% ;&% =.%;
.;% $$%.& &/;%$ /..% $%$$ $$%&;$ %&$;.=.& ;%= &/%&=&% $ .%./
. % $&%.& &/..%/; & &%;. ;%. $$%&;$%$;.=./&% .&/=$%.$&% $;%/
. % . ;% & && %= &=&%= ==% $$%&;/ %;&;.=.//%$=&/$;%$.&% $//%&;
C!
. ;% ; %.& &&= % &% $&%/; $$%&;&/%=;.=./;;%$$&/%$ &% ;=%.
. /% / ;$%;. &&$=% $ &/=% / ;&%= $$%&;./%; ;.=./$ %; &//&%==&% ; .%
C!
. / %& ;$%/ &&$$% &/$% / ;.%= $$%&;.&% /;.=./$ %;$&//.% &% ; %&
C!
. /$%/ ;$%.; &&$;%/ &/% & %$. $$%&;..%//;.=./=.%;/&/&%.;&% ; =% =
C!
. % ;%.& &&;.%. &.=% = / %& $$%& %;;.=./ %.=&/.;% &% ;$=%/
. ;% %.& &&&;%& . /%/& ./%.. $$%&=&%;=;.=.&&%.&& %&/&% ;&;%
. ; %=; %& &&&%== . &%/$ .&%& $$%&=.% $;.=.&/%.&& %; &% ;&%//
( /#
. .;%=; $% &.%$ .%$ = %. $$%&=% ;.=.;%&/&&$ %&% ;%;
( /#
.=% $%.& &.&%=. .=%& = $% $$%&;%;&;.=.;=%;=&&$=%;&&% .%
.= %;= %= &. ;% ./% ===% $$%&/$%/=;.=.$ %;/&&;%$&% $=%&.
( /#
.= /%/= %$ &. ;%. ./%&& ===% $$%&/;%=.;.=.$%/&&;%&&&% $$%.
( /#
.=;% &%.& &. /%.$ %= =; % $$%&.=%;=;.=. %..&&=% =&% /$% ;
.$% / %.& &.$$% $ =.% / =/&%.. $$%&/ % =;.=.;/.%$;&&/.%$=&% / %=/
.$;% /%.& &.;/% . /&%== $/%= $$%&/; %;;.=.;$ % &&. %=&&% //%;&
.$&.% / &% &.$%.. .%$ $ .%.& $$%&//$%.$;.=.; %;$&.% &&% &;%
$ /#
.;% &%.& &.%/; &% $=% $$%&/& %=/;.=.; % =&. %.$&% & ;%;/
.; %/ & % &..%/; =$%&. $$&%$ $$%&/.$%$;.=.$&;%;/&.$%.$&% &=;%.
$ /#
.;;% &$%.& &./ %& ;&% $;%=/ $$%&& %; ;.=.$ %/ &.&%;&% &$%.
.% &&%.& &./;%; .&%;; $.$%/ $$%&&$ %&=;.=.$ =%/&. %.&% . %.
. %/. .% &./;% &%. ; % = $$%&&$.%;.=.$ %. &. %& &% . ;%$
* CA4B>DB-*=D>B()*
./% .=%$. &./ %. /.%$ ;;=%$ $$%&. %;;;.=.=$=%.&.&% ;$% %$
.&% ./%$. &.=%$ =;.%. %.; $$%&.=%;.=. $%$&&.&%;.$% /%.
..% %$. &.$%. $=.%/ .%. $$%&/ %.;.=. &%= &&& % $% $%=.
%
&
#
'
()*
'
+
+
, -" !!"
#$%& '
* . (
* )*
-*
'
#$%& '
! "
'
+
,
-
*
"
5 '7
:
567
8; &"
567
324+
5 '7
-
! " .
5 '7
-
2 .
5 '7
3!4
5 '7
,
)
*
"
5 '7
()*
'
*#
===>D
)
% ;%$. &. =% ; &%=; / /% $$%&/& %.;.=. .%.&&;&%/.$% ..%$/
%/. % &. % = ; &%= /=$%= $$%&/&.%$$;.=...%= &&;;%= $% = %;
2* >DB-*=><B()*
% % &&.%. ;.% = /&=%;/ $$%&/ $%=;.=.= %/=&&= % &% =.=%$&
; %/. % &&& %;$ =/% . & =%$ $$%&/ / % .;.=&.. %$=&& %/=% $$=%
* CA4B>DB-*===>CB()*
% $%;; &&.% /=%/= &$%;/ $ %/;&/ ..% ;;.=&.;%;&&$% .$% $&/%/$
=% %$ &&$% /$.%. . %= $% $&/ %&=;.=&&& %. &/& %/.$% ;&=%&
$% .&%=$ && .%$ & $%& .%. =/%;.&/= &%$ ;.=&&.%=&/$%$% & %;.
;% .;% && /% &.;%. =$%$ =;%.&/=.&%/ ;.=&/=.% ;&/; %/.$% /&%;&
% . %/ && % ; .;% % = % &/$/ %=$;.=&/ %. &/$%$$$% &&%=
;%&$ .% && % &%&& ;;%& =%.&&/; %$&;.=& .% &&/$;% ;$% .$%
* CA4B>=CB-*==>B()*
/% &&%/ && %$; = % & & %; =%; &/;$&%.;.=&/%=&/$;%$$% .&% /
&% &$%. && ;%. .;% ;&% .% $&/ /% ;.=&;$;% &/; % ;$% =&%=
.% & % && &% ;%& ==;%. /%/;&//%==;.=&$&;%&=&/=% $% = /.%
% //%$; &&$%;= % $ $%=& %==&//&% &;.=&$ &%;.&/& %/ $% = /%..
% /=%/ &&/ %$ / %=. $.=% $%&/&/&% ;.=&=/$% /&&% $% ==/=% =
==%&$ / %$; &&& % / .%/& ; .%/; $%=/&/&.=%=;;.=&=;%$$&& %$$% =$;%=;
* CA4B<<>=CB-*===>DB()*
% /$%.$ &&..%&; = /%; ;/ %& ;%=&/.$%==;.=&= %$&&=;%$$% =$&%=;
=% /&%/ &. %; =&$% ;% %&&& %$/;.=& % &&;/%&$$% =;;% &
$% & %$& &.=&%.. $$$% / .% &% && %= ;.=& &%= &&/$% &$% ==%;
;% &% &.$&%& ;% . &%. .%=$&& &;%$.;.=& $&%&&&=%..$% =/ %&=
;.&%.$ .% &.; %= ;.%& && %$; =%=&& %//;.=&&%$ &&&/% $% =& %$
* CA4B=>CB-*=><B()*
% .%$ &.; %= ;/%; &&=% ; =%$&& =%;.=&&;%/$&&&/% $% =& %/
/% .=%.& &.$&%; =%; .;&%& = %==&&=$% ;.=& %.&&&=%/ $% =. %
&% ./%. &.=&% / % & == %.$ = %$&&$ %$/;.=/.;/%& &&/=%=;$% $ %;
.% %& &. %.. /&%;& = ;%. = %/;&&$.%& ;.=/&.=% &&;% &$% $ %;$
% ;%/. &&./% &=$%.$ = /%;; ==%$.&&;=% .;.=/& &% &&= % .$% $ ;/%
;% = &% &&&%/& &/ %$ = ;%=& ==%. &&=% ;.=//. %$.&& ;%./$% $= % &
2* ><B-*===>D=B()*
% &% &&/% = .%.& = $;%$= ==%. &&==%//;.=//$%=&& %$ % $=; %.&
% &% &&=%= .%.$ == =%.; ==%. &&/=%&&;.=//%$&// %; % $$$&%=
=% &% &&;%$ == %. ==& %$ ==%. &&//=%..;.=/=;%/.&/$% % $;$=%/
$% &% &//$%; =.&%&/ =$;%./ ==%. &&&$$% ;.=/;/ %;=&/.%/ % $=&%
$ %= &% &/&% = %/$ =$;%=& ==%. &&&;&%&$;.=/;;&% &/=% % $;&%
( *
"C><B-*=D=>B()*
/:2& ? :&;.%/;&&/%/& ?
$ ? :2 ?&:&/&% $ %=$ ? ?&
%
&
#
'
()*
'
+
+
, -" !!"
#$%& '
* . (
* )*
-*
'
#$%& '
! "
'
+
,
-
*
"
5 '7
)
*
"
5 '7
*
*
567!& # " .
*
567
&
)
*
"
;. %; ;&& %& +
.= %;= &. ;% ,>
$/&.% $/.%; ->=
. % . && %= $
&&$$%=/ & %/& , -
/$%/ /;//% ;
& /.%; & /%/ 7
. / %& &&$$% $
. /% / &&$=% $ $
===/%/ ===/% @=
=;$%$$ =;$;%& @
.$&.% / &.$%.. >
./%= &;=%
. ; %=; &&&%== ,>
=.% =; %. =
. /$%/ &&$;%/ $
;%& ;% ; +
.= /%/= &. ;%. ,>
&& %./ /.$&% & ,7
$;%$; $$&;%=/ ->$)
;== %/& ;==%= ->
&&=%; &;%/ , >
=.$.%$; =.$=% @
&=& % & $%/ -
&.$ %/= &&=%;/ , )4
. .;%=; &.%$ ,>
.; %/ &..%/; >
-
*
"
5 '7
)
*
"
5 '7
324+
5 '7
3!4
5 '7
#
&&
8
==% = ..%& %;$ %. A5 % B? < ==< 4= ..%&<,@4 ;$%..9,,C
== /% == %&; %/= /% & 14 == /< 4== %&;<,@4
=$ /% =$ %/& $%$; %&=
4=B? < =$ /< 4=$ %/&<,@4
=&.% = =&/% & .%&& =.%& 14 =&.% =< 4=&/% &<,@4
& &%.= //%$/ % & ;.;%;
4 B? < & &%.=< 4//%$/<,@4
&//%.= /.$$%& =&% .% 14 &//%.=< 4/.$$%& <,@4
&&/;% . & &% & / % $ $ %=.
4&B? < &&/;% .< 4& &% .<,@4
. %/. &./;% &%. ; % =
4$B? < . %/.< 4&./;% <,@4
%/. &. % = ; &%= /=$%= 14 %/.< 4&. % =<,@4
; %/. &&& %;$ =/% . & =%$
4$B? < ; %/.< 4&&& %;$<,@4
;%&$ && % &%&& ;;%&
4$B? < ;%&$< 4&& %<,@4
==%&$ &&& % / .%/& ; .%/;
4$B? < ==%&$< 4&&& % /<,@4
;.&%.$ &.; %= ;.%& && %$;
4$B? < ;.&%.$< 4&.; %=<,@4
;% = &&&%/& &/ %$ = ;%=& 14 ;% =< 4&&&%/&<,@4
$ %= &/&% = %/$ =$;%=& ,
4
$ %=< 4&/&% <,@4
! " # $#% $#%&##%'()*$#% $#%% $#%%#%'
+) ,
- ). * !(/0!$&1&2&& #1+123.45&6++2#+7 &15+62&70/)
* $#%!8#&21
( *$++21142
(29
!) 2
:$24"
!$& !
; !2
((; !29,3 2
( <= <"
> ?3$;*
!(!@(* ? $ ? $
( $#%%#%' 0 %0 %)*89
!) .
(/9
).
(/3 .
(/89
!)
( !
; !2
((; !29,3 2
( *$++21142
(29
!) 2
+) ,
- ). * !(/()*$#% $#%% $#%%#%'9
!) .
(/
"!9
0*#
!
!
""
"" !
!
!
"" !
""
" "" " !
" "" "
#
!
" "
!
!
( $#%%#%' 0 %0 %)*89
!) .
(/9
).
(/3 .
(/89
!)
( !
; !2
((; !29,3 2
( *$++21142
(29
!) 2
+) ,
- ). * !(/()*$#% $#%% $#%%#%'9
!) .
(/
"!9
0*"" !
""
!
!
#
!
#
!
""
#
"" !
""
!
!
"" !
""
#
!
!
""
"" !
" "" "
" "" " !
( $#%%#%' 0 %0 %)*89
!) .
(/9
).
(/3 .
(/89
!)
( !
; !2
((; !29,3 2
( *$++21142
(29
!) 2
+) ,
- ). * !(/()*$#% $#%% $#%%#%'9
!) .
(/
"!9
0*" "" "
" "" " !
""
#
!
#
!
""
#
"" !
""
#
!
$2++214%21++2#2++214
> %
$2++214%21++2#2++214
> %
$ " "2++214%2++2#2&++214
> %
$ " "2++214%2++2#2&++214
> %
$""2++214%21++2#2++214
> %
$"%"%2++214%21++2#2++214
> %
( $#%%#%'
.
(/?.
(/
- A
- ? &'
(&#
) &*+#&,
-.
/ ) &*+#., 0.* .
/ ) &*+#., 0.* .
/!
1
2
3'
4
2
5)
2
2
6
7#
")
6 89#
")
6 !
:#
")
4
/4
5) ) 5
)
2
2 /4* 121 2
3
2
14
0.001.002.003.004.00Separation Factor3300 3600 3900 4200 4500 4800 5100 5400 5700 6000 6300 6600 6900 7200 7500 7800 8100 8400 8700 9000Measured Depth (600 usft/in)06-1106-04B06-0406-04A06-1206-12APB106-12APB206-12BL106-21A06-2106-12A06-12B06-1906-21B06-21C06-13A06-13APB106-13No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.NOERRORSWELL DETAILS:Plan: 06-12 NAD 1927 (NADCON CONUS)Alaska Zone 04Ground Level: 38.31+N/-S +E/-W Northing Easting Latittude Longitude0.000.00 5940584.44685318.2070° 14' 33.6286 N 148° 30' 11.4496 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: 06-12, True NorthVertical (TVD) Reference: 06-12C planned @ 64.81usftMeasured Depth Reference:06-12C planned @ 64.81usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2024-12-23T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool96.81 3300.00 06-12 Top GYD-CT-CMS Gyrodata (06-12)3_Gyro-CT_Drill pipe3300.00 3700.00 06-12C wp02 (Plan: 06-12C) 3_MWD_Interp Azi+Sag3700.00 8807.00 06-12C wp02 (Plan: 06-12C) 3_MWD+IFR2+MS+Sag8807.00 12421.03 06-12C wp02 (Plan: 06-12C) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)3300 3600 3900 4200 4500 4800 5100 5400 5700 6000 6300 6600 6900 7200 7500 7800 8100 8400 8700 9000Measured Depth (600 usft/in)06-1106-04B06-0406-04A06-13A06-13APB106-13NO GLOBAL FILTER: Using user defined selection & filtering criteria3300.00 To 8807.00Project: Prudhoe BaySite: 06Well: Plan: 06-12Wellbore: Plan: 06-12CPlan: 06-12C wp02Ladder / S.F. Plots1 of 2CASING DETAILSTVD TVDSS MD Size Name7272.92 7208.11 8807.00 7 7" x 8-1/2"8773.61 8708.80 12421.03 4-1/2 4-1/2" x 6-1/8"
! " # $#% $#%&##%'()*$#% $#%% $#%%#%'
+) ,
- ). * !(/0!$&1&2&& #1+123.45&6++2#+7 &15+62&70/)
* $#%!8#&21
( *$1142&2+
(29
!) 2
:$24"
!$& !
; !2
((; !29,3 2
( <= <"
> ?3$;*
!(!@(* ? $ ? $
( $#%%#%' 0 %0 %)*89
!) .
(/9
).
(/3 .
(/89
!)
( !
; !2
((; !29,3 2
( *$1142&2+
(29
!) 2
+) ,
- ). * !(/()*$#% $#%% $#%%#%'9
!) .
(/
"!9
0*#
!
!
""
"" !
!! !
!
!
#
!
!
!
#
!
!
#
!
!
#
!
" " !
#
" " !
!
!
" "
" " !
" " " " !
#
" " " "
( $#%%#%' 0 %0 %)*89
!) .
(/9
).
(/3 .
(/89
!)
( !
; !2
((; !29,3 2
( *$1142&2+
(29
!) 2
+) ,
- ). * !(/()*$#% $#%% $#%%#%'9
!) .
(/
"!9
0* " " " " !
" " " " !
"" !
#
""
"" !
+ !
#
!
.
(/?.
(/
- A
- ? $ %
!&$ #
!' $ ( ) #$ *
+,
- !' $ ( ) #, * ., ( ,
- !' $ ( ) #, * ., ( ,
-
/
0
1%
2
0
3' !
0
0
4
!
5#
"'
4 67#
"'
4
8#
"'
2
-2
3' ' 3
'
0
0 -2( / 0/ !0
1
0
/ 2
0.001.002.003.004.00Separation Factor9100 9425 9750 10075 10400 10725 11050 11375 11700 12025 12350 12675 13000 13325 13650 13975 14300 14625 14950Measured Depth (650 usft/in)06-20B06-18A06-1806-18B06-0906-13No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.NOERRORSWELL DETAILS:Plan: 06-12 NAD 1927 (NADCON CONUS)Alaska Zone 04Ground Level: 38.31+N/-S +E/-W Northing Easting Latittude Longitude0.000.005940584.44 685318.20 70° 14' 33.6286 N 148° 30' 11.4496 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: 06-12, True NorthVertical (TVD) Reference: 06-12C planned @ 64.81usftMeasured Depth Reference:06-12C planned @ 64.81usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2024-12-23T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool96.81 3300.00 06-12 Top GYD-CT-CMS Gyrodata (06-12) 3_Gyro-CT_Drill pipe3300.00 3700.00 06-12C wp02 (Plan: 06-12C) 3_MWD_Interp Azi+Sag3700.00 8807.00 06-12C wp02 (Plan: 06-12C) 3_MWD+IFR2+MS+Sag8807.00 12421.03 06-12C wp02 (Plan: 06-12C) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)9100 9425 9750 10075 10400 10725 11050 11375 11700 12025 12350 12675 13000 13325 13650 13975 14300 14625 14950Measured Depth (650 usft/in)NO GLOBAL FILTER: Using user defined selection & filtering criteria8807.00 To 12421.03Project: Prudhoe BaySite: 06Well: Plan: 06-12Wellbore: Plan: 06-12CPlan: 06-12C wp02CASING DETAILSTVD TVDSS MD Size Name7272.92 7208.11 8807.00 7 7" x 8-1/2"8773.61 8708.80 12421.03 4-1/2 4-1/2" x 6-1/8"
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:Lau, Jack J (OGC)
To:Boman, Wade C (OGC)
Subject:FW: [EXTERNAL] PBU 06-12C PTD Request
Date:Thursday, March 13, 2025 4:32:00 PM
Attachments:06-12C Intermediate Hole UKTC.pdf
06-12C Production Hole UKTC.pdf
From: Joseph Engel <jengel@hilcorp.com>
Sent: Thursday, March 13, 2025 3:09 PM
To: Lau, Jack J (OGC) <jack.lau@alaska.gov>
Subject: RE: [EXTERNAL] PBU 06-12C PTD Request
Jack –
Ram configuration is listed in Attachment 2 of the PTD Application (I’ll add page
numbers next submittal), I have copied them below. On future applications I will label
the configuration of each hole section.
06-12C BOPE Ram Configuration for all hole sections/operations:
Operations: Decomplete, Mill Window, Drill Intermediate, Run 7”, Drill Production,
Run 4-1/2” Liner and Tubing
MASP is under 3000 psi
13-5/8” Annular
UPR: 2-7/8” x 5-1/2” VBR
Blind Rams:
LPR: 4-1/2” x 7” VBR OR 7” Solid Body Rams
Attached are the outputs for kick tolerance calculations, from the 3rd party software we
use “The Ultimate Kick Tolerance Calculator”. DP size, BHA length and diameter are on
the form.
For the intermediate hole KT calculation, because the window will be milled in an
uncemented depth of the 9-5/8” I am using the 13-3/8” casing shoe at 2708’ MD/TVD as
the weak point and calculating KT with a 12.5ppg EMW at that depth.
For production hole KT calculation, a 9.4ppg EMW minimum is required to drill ahead, a
10.5 ppg is for ECDs.
CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders.
I will include these outputs and details in future submittals.
Let me know if you have any other questions.
Thanks for your time.
-Joe
From: Lau, Jack J (OGC) <jack.lau@alaska.gov>
Sent: Wednesday, March 12, 2025 4:54 PM
To: Joseph Engel <jengel@hilcorp.com>
Cc: Boman, Wade C (OGC) <wade.boman@alaska.gov>
Subject: [EXTERNAL] PBU 06-12C PTD Request
Joe –
I am reviewing your PTD application for PBU 06-12C and have the following requests.
Need detail for what rams will be used in each hole section/operation. Please
include this in future submissions.
Send your kick tolerance calculations. Please include this in future submissions.
Need DP, BHA size and length for each hole section (for KT calcs). Please include
this in future submissions.
Thanks!
Jack Lau
Senior Petroleum Engineer
Alaska Oil and Gas Conservation Commission
(907) 793-1244 Office
(907) 227-2760 Cell
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.
Revised 7/2022
TRANSMITTAL LETTER CHECKLIST
WELL NAME:______________________________________
PTD:_____________________________________________
___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional
FIELD:__________________________POOL:____________________________________
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK OPTIONS TEXT FOR APPROVAL LETTER
MULTI
LATERAL
(If last two digits
in API number are
between 60-69)
The permit is for a new wellbore segment of existing well Permit
Number _____________, API Number 50-______________________.
Production from or injection into this wellbore must be reported under
the original API Number stated above.
Spacing
Exception
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce or inject is contingent upon issuance of a
conservation order approving a spacing exception. The Operator
assumes the liability of any protest to the spacing exception that may
occur.
Dry Ditch Sample
All dry ditch sample sets submitted to the AOGCC must be in nogreater
than 30-foot sample intervals from below the permafrost or from where
samples are first caught and 10-foot sample intervals through target
zones.
Non-
Conventional
Well
Please note the following special condition of this permit: Production or
production testing of coal bed methane is not allowed for this well until
after the Operator has designed and implemented a water-well testing
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.
Well Logging
Requirements
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types
of well logs to be run. In addition to the well logging program proposed
by the Operator in the attached application, the following well logs are
also required for this well:
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
composite curves for 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.
PRUDHOE BAY PRUDHOE OIL
PBU 06-12C
225-022
WELL PERMIT CHECKLISTCompanyHilcorp North Slope, LLCWell Name:PRUDHOE BAY UNIT 06-12CInitial Class/TypeDEV / PENDGeoArea890Unit11650On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2250220PRUDHOE BAY, PRUDHOE OIL - 640150NA1 Permit fee attachedYes ADL0283112 Lease number appropriateYes3 Unique well name and numberYes PRUDHOE BAY, PRUDHOE OIL - 640150 - governed by CO 341J4 Well located in a defined poolYes5 Well located proper distance from drilling unit boundaryNA6 Well located proper distance from other wellsYes7 Sufficient acreage available in drilling unitYes8 If deviated, is wellbore plat includedYes9 Operator only affected partyYes10 Operator has appropriate bond in forceYes11 Permit can be issued without conservation orderYes12 Permit can be issued without administrative approvalYes13 Can permit be approved before 15-day waitNA14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For servNA15 All wells within 1/4 mile area of review identified (For service well only)NA16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)NA This well is a rotary sidetrack from an existing wellbore.18 Conductor string providedNA SC from the original wellbore will remain untouched.19 Surface casing protects all known USDWsNA SC from the original wellbore will remain untouched.20 CMT vol adequate to circulate on conductor & surf csgNA SC and PC from the parent wellbore will remain untouched.21 CMT vol adequate to tie-in long string to surf csgYes New 7" PC will be cemented 500+ feet MD above the Sag.22 CMT will cover all known productive horizonsYes23 Casing designs adequate for C, T, B & permafrostYes The Innovation rig has adequate tankage and good trucking support.24 Adequate tankage or reserve pitYes Yes. Sundry 325-111 has been approved.25 If a re-drill, has a 10-403 for abandonment been approvedYes26 Adequate wellbore separation proposedNA All drilling will be below the the SC shoe.27 If diverter required, does it meet regulationsYes Sag and Ivishak are 7.2 PPG. Mud used will be between 8.8 PPG and 10.8 PPG.28 Drilling fluid program schematic & equip list adequateYes 13-5/8" annular, 13-5/8" blind ram, flow cross,29 BOPEs, do they meet regulationYes 13-5/8" 5000 psi stack pressure tested to 3500 psi.30 BOPE press rating appropriate; test to (put psig in comments)Yes31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownYes Prudhoe's DS-06 max recent reading was 75 PPP in 06-12, in 202233 Is presence of H2S gas probableNA This is a development well.34 Mechanical condition of wells within AOR verified (For service well only)No DS 06 wells are H2S-bearing. H2S measures are required.35 Permit can be issued w/o hydrogen sulfide measuresYes Potential for overpressure in SV1, Ugnu, and Schrader sands. Target reservoir at 7.1 ppg EMW.36 Data presented on potential overpressure zonesNA37 Seismic analysis of shallow gas zonesNA38 Seabed condition survey (if off-shore)NA39 Contact name/phone for weekly progress reports [exploratory only]ApprADDDate3/27/2025ApprJJLDate3/27/2025ApprADDDate3/26/2025AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate*&:JLC 3/28/2025
