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Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout225-017MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Monday, August 4, 2025
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Sully Sullivan
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
Hilcorp Alaska, LLC
R-105
MILNE PT UNIT R-105
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 08/04/2025
R-105
50-029-23815-00-00
225-017-0
W
SPT
3985
2250170 1500
206 207 207 199
15 15 15 15
INITAL P
Sully Sullivan
7/4/2025
well online w/ 5 days of stable flow. Test to 2000 psi per
30 MinPretestInitial15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:MILNE PT UNIT R-105
Inspection Date:
Tubing
OA
Packer Depth
571 2160 2107 2090IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitSTS250705100849
BBL Pumped:6.3 BBL Returned:6
Monday, August 4, 2025 Page 1 of 1
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: 06/16/2025
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL: REVISED
WELL: MPU R-105 + PB1
PTD: 225-017
API: 50-029-23815-00-00 (MPU R-105)
API: 50-029-23815-70-00 (MPU R-105PB1)
FINAL LWD FORMATION EVALUATION + GEOSTEERING (03/31/2025 to 05/03/2025)
x AGR, ABG & BaseStar Gamma Ray, EWR-M5 and StrataStar Resistivity, ALD, CTN
x Horizontal Presentation (2” & 5” MD/TVD Color Logs)
x Final Definitive Directional Survey
x Final Geosteering and EOW Report/Plots
SFTP Transfer – Main Folders:
FINAL LWD Subfolders:
FINAL Geosteering Subfolders:g
Please include current contact information if different from above.
T40448
T40449
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2025.06.17 08:17:38 -08'00'
David Douglas Hilcorp Alaska, LLC
Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 777-8337
E-mail: david.douglas@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Date: 05/27/2025
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL:
WELL: MPU R-105 + PB1
PTD: 225-017
API: 50-029-23815-00-00 (MPU R-105)
API: 50-029-23815-70-00 (MPU R-105PB1)
FINAL LWD FORMATION EVALUATION + GEOSTEERING (03/31/2025 to 05/03/2025)
x AGR, ABG & BaseStar Gamma Ray, EWR-M5 and StrataStar Resistivity, ALD, CTN
x Horizontal Presentation (2” & 5” MD/TVD Color Logs)
x Final Definitive Directional Survey
x Final Geosteering and EOW Report/Plots
SFTP Transfer – Main Folders:
FINAL LWD Subfolders:
FINAL Geosteering Subfolders:
Please include current contact information if different from above.
T40448
T40449
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2025.05.28 08:23:04 -08'00'
2025-0517_Flowback_Unmanned_MPU_R-105_ksj
Page 1 of 4
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg DATE: 05/18/2025
P. I. Supervisor
FROM: Kam StJohn SUBJECT: Unmanned Flowback
Petroleum Inspector Milne Point Unit R-105
Hilcorp Alaska LLC
PTD 2250170; Sundry 325-284
5/17/25: MPU R-105 was recently drilled as a lateral injector in the Schrader OA zone.
and was. AOGCC recently approved an unmanned 30-day flowback before placing on
injection (Sundry 325-284). The purpose of my visit was to inspect the equipment rig-
up. I met with Hilcorp representative Derrick Weglin and we discussed the unmanned
flowback rig up. Hilcorp is using a reverse circulating jet pump for the flowback (power
fluid pumped down the tubing-casing annulus, return flow up the tubing).
The approved procedure calls for a short continuously manned flowback to tanks for
cleanup followed by up to 30 days unmanned flowback to the production and test
headers (unmanned). This flowback and power fluid lines are 3-inch hardline. A
manifold directs flow back fluids as follows:
- From the manifold to clean-up tanks; and
- To the production and test headers.
An actuated block valve on the power fluid line and the production line surface safety
valve have high- and low-pressure safety sensors set to trip the actuated valves closed.
The power fluid line block valve closes if pressure is below 1450 psi or above 2750 psi;
the surface safety valve closes if pressure falls below 250 psi.
Hilcorp operators will check the well and flowback equipment at least once every 12-
hour shift.
I found the rig up clean and well organized. The only flaw that I observed – and
addressed with them – was the direction of some of their targeted 90’s which were
installed backwards. Hilcorp will address this at MPU R-105 and for future set-ups.
Attachments: Photos (6)
9
9
9
9
9
9
9
9
James B. Regg Digitally signed by James B. Regg
Date: 2025.05.21 12:48:34 -08'00'
2025-0517_Flowback_Unmanned_MPU_R-105_ksj Page 2 of 4 MPU R-105 Unmanned Flowback Photos by AOGCC Inspector K. StJohn 5/17/2025 Well Sign Flowline in MPU R-105 Well House; Surface Safety Valve in Vertical Run of Tree (upper left)
2025-0517_Flowback_Unmanned_MPU_R-105_ksj Page 3 of 4 Power Fluid Flowline with Actuated Block Valve; Pressure Safety Sensors in Background Flowlines from Well House to Header
2025-0517_Flowback_Unmanned_MPU_R-105_ksj Page 4 of 4 Flowback Manifold and Tie-in to Headers Manifold to Cleanup Tanks
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:Brett Anderson - (C)
To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Wallace, Chris D (OGC)
Cc:Frank Roach; Nathan Sperry; Taylor Wellman; Jacob Thompson; Brad Gorham; Oliver Amend - (C)
Subject:MPU R-105 MIT IA Form 10-426
Date:Saturday, May 10, 2025 8:33:41 AM
Attachments:MPU R-105 MIT IA Form 10-426 - 05-10-2025.xlsx
Please see attached 10-426 for MPU R-105, initial MIT IA.
Brett Anderson
Hilcorp DSM, Parker 273
Office: 907-659-5673
Mobile: 907-240-6258
brett.anderson@hilcorp.com
Alternate: Brian LaFleur
Bryan.Lafleur@hilcorp.com
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.
0LOQH3RLQW8QLW5
37'
initial MIT IA.
Submit to:
OOPERATOR:
FIELD / UNIT / PAD:
DATE:
OPERATOR REP:
AOGCC REP:
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD2250170Type InjWTubing0000 Type TestP
Packer TVD 3951 BBL Pump 7.8 IA 0 2850 2800 2780 Interval I
Test psi 2750 BBL Return 7.8 OA 130 130 130 130 Result P
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes
W = Water P = Pressure Test I = Initial Test P = Pass
G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail
S = Slurry V = Required by Variance I = Inconclusive
I = Industrial Wastewater O = Other (describe in notes)
N = Not Injecting
Notes:
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
MMechanical Integrity Test
jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov
Notes:
Notes:
Notes:
Hilcorp Alaska
MPU R-105
Brett Anderson
05/10/25
Notes:9-5/8" Casing x 3-1/2" Upper Completion w/ 7" Seal Assembly at 11,378' MD, 3951' TVD. MIT IA to 2750 psi per email approval from Mel Rixse 05/08/2025. Witness
Waived by Austin McLeod 05/08/2025.
Notes:
Notes:
Notes:
R-105
Form 10-426 (Revised 01/2017)2025-0510_MIT_MPU_R-105
9
9
9
9
999
99
9 99
9
-5HJJ
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: Unmanned Inj. Flowback
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?
Yes No
9. Property Designation (Lease Number): 10. Field:
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
±23,347 N/A
Casing Collapse
Conductor N/A
Surface 2,260psi
Production 3,090psi
Slotted Liner N/A
Slotted Liner N/A
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: Hayden Moser
Contact Email:Hayden.Moser@hilcorp.com
Contact Phone:907-793-1231
Authorized Title:
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other Conditions of Approval:
Post Initial Injection MIT Req'd? Yes No
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
±23,347'
Perforation Depth MD (ft):
±11,847'
See Schematic
±8,500'
See Schematic
4-1/2"
80' 34" x 20"
13-3/8"
9-5/8"
3,632'
5-1/2"ѷ430'
11,523'
N/A
5,020psi
5,750psi
±X,XXX'
±X,XXX'
±3,969'
Size
Proposed Pools:
80' 80'
Nikaitchuq & Schrader Bluff Oil N/A
MD
N/A
N/A
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL 025509, 355018, 388235 & 390615
±X,XXX'
3,632'
11,523'
Length
AOGCC USE ONLY
9.3# / L-80 / TXP ±11,4173-1/2"
SLZXP LTP and N/A ±11,417 MD / ±X,XXX' TVD
5/10/2025
Subsequent Form Required:
Suspension Expiration Date:
225-017
3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23815-00-00
Hilcorp Alaska LLC
C.O 477.005
TVD Burst
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:
Tubing Size:
PRESENT WELL CONDITION SUMMARY
MPU R-105
Milne Point
Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft):
±3,969' N/A N/A N/A N/A
Will perfs require a spacing exception due to property boundaries?
Current Pools:
MPSP (psi): Plugs (MD):
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
Wells Manager
Digitally signed by Taylor
Wellman (2143)
DN: cn=Taylor Wellman (2143)
Date: 2025.05.07 10:58:46 -
08'00'
Taylor Wellman
(2143)
325-284
By Grace Christianson at 1:55 pm, May 07, 2025
* 24 hour notice for AOGCC to witness SSV configuration prior to POP.
MGR09MAY2025
10-407 -
Original completion
DSR-5/8/25
1371
A.Dewhurst 09MAY25*&:
Jessie L.
Chmielowski
Digitally signed by Jessie L.
Chmielowski
Date: 2025.05.12 08:06:10 -08'00'05/12/25
RBDMS JSB 051225
New Drill Injector
Well: MPU R-105
Date: 05/06/2025
Well Name:MPU R-105 API Number:50-029-23815-00-00
Current Status:Drilling Rig:N/A
Estimated Start Date:05/10/2025 Estimated Duration:1day
Reg.Approval Req’d?Yes Date Reg. Approval Rec’vd:TBD
Regulatory Contact:Tom Fouts Permit to Drill Number:225-017
First Call Engineer:Taylor Wellman 907-947-9533
Second Call Engineer:Hayden Moser 479-899-8940
Current Bottom Hole Pressure:N/A
Max. Proposed Surface Pressure:N/A
Min ID:2.813” @ TBD’ XN Nipple
Brief Well Summary and Objective
MPU R-105 is currently being drilled as a lateral injector in the Schrader OA. It is currently approved for a 30 day
flowback. With the recent approval from the AOGCC on unmanned flowbacks, we would like to obtain approval for
this well.
Notes on Well Condition
x SSV Pilot Settings:
o Production SSV low pressure trip will be set to 25% of FTP or 50% of inlet separator pressure.
o Production SSV high pressure trip will be set at 1100 psig.
o Power fluid XV low pressure trip will be set to 50% of header pressure.
o Power Fluid XV to be actuated if vertical run tubing SSV is actuated (within 2 minutes).
x AOGCC will be notified for opportunity to witness before production begins.
x Visual leak check by pad operator performed at least once per tower (i.e. ~ every 12 hours).
x SCADA screen available in control room for pressure and flow sensors on injection line and well’s flow
line.
x Pilot trip pressures, both high and low, documented in permitting documents for Hilcorp pad operators
and AOGCC inspectors.
Post-Rig Work (Sundried Step):
1. MU surface lines from power fluid header to the tubing. Rig up piping and instrumentation per
Unmanned Injector Flowback Diagram.
a. Pressure test lines at existing power fluid head pressure (3,500 psi)
2. Rig up piping and instrumentation to the production header per Unmanned Injector Flowback
Diagram. Pressure test to 3,500 psi.
Attachments:
1. Unmanned Injector Flowback Diagram
New Drill Injector
Well: MPU R-105
Date: 05/06/2025
CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders.
From:Rixse, Melvin G (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: [EXTERNAL] PTD 225-017 MPU R-105 Sundry 325-284 well schematic
Date:Friday, May 9, 2025 1:41:15 PM
From: Hayden Moser <hayden.moser@hilcorp.com>
Sent: Friday, May 9, 2025 1:37 PM
To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Cc: Tom Fouts <tfouts@hilcorp.com>; Taylor Wellman <twellman@hilcorp.com>
Subject: RE: [EXTERNAL] PTD 225-017 MPU R-105 Sundry 325-284 well schematic
Mr. Rixse,
Here is the MPSP for MPU R-105
TVDss = 3940 ft
Reservoir pressure at depth = 1765 psi
MPSP = 1765 – 0.1*3940 = 1371 psi
Thanks,
Hayden Moser
Operations Engineer | Milne Point
Hilcorp Alaska, LLC | 3800 Centerpoint Drive | Anchorage, AK 99503
O: (907) 564-4389 | C: (479) 899-8940 | Hayden.Moser@hilcorp.com
From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Sent: Friday, May 9, 2025 10:08 AM
To: Hayden Moser <hayden.moser@hilcorp.com>
Subject: RE: [EXTERNAL] PTD 225-017 MPU R-105 Sundry 325-284 well schematic
Hayden,
AOGCC needs an MPSP for this sundry. Let me know MPSP = Reservoir Pore
Pressure – (0.1 * SSTVD)
Mel Rixse
Senior Petroleum Engineer (PE)
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.
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: Hayden Moser <hayden.moser@hilcorp.com>
Sent: Friday, May 9, 2025 9:37 AM
To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Cc: Taylor Wellman <twellman@hilcorp.com>
Subject: RE: [EXTERNAL] PTD 225-017 MPU R-105 Sundry 325-284 well schematic
Mr. Rixse,
Please see attached for proposed well schematic for MPU R-105. And yessir understood
I will make sure this is included in sundry requests going forward.
Thanks,
Hayden Moser
Operations Engineer | Milne Point
Hilcorp Alaska, LLC | 3800 Centerpoint Drive | Anchorage, AK 99503
O: (907) 564-4389 | C: (479) 899-8940 | Hayden.Moser@hilcorp.com
From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Sent: Friday, May 9, 2025 9:17 AM
To: Hayden Moser <hayden.moser@hilcorp.com>
Cc: Taylor Wellman <twellman@hilcorp.com>
Subject: [EXTERNAL] PTD 225-017 MPU R-105 Sundry 325-284 well schematic
Hayden,
Please send a proposed well schematic for this sundry.
For the future, almost all sundry requests should include at least a proposed
schematic and existing well schematic. I think for this sundry I just need the proposed
schematic.
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. Taylor
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.
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 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:Taylor Wellman
Cc:Wallace, Chris D (OGC); DOA AOGCC Prudhoe Bay
Subject:20250508 1548 APPROVAL MPU R-105 (PTD 225-017) Annulus Test and Flowback Operating Pressure Change Request
Date:Thursday, May 8, 2025 4:02:24 PM
Attachments:image001.png
RE Milne Point Proposed Flowback Diagram (Unmanned).msg
Taylor,
Hilcorp is approved to reduce the initial IA test pressure on new well MPU R-105 to 2750 psi upon
initial packer set. Please assure the Management of Change information form (Page 8 of the PTD) is
filled out with the relevant change and submitted with the initial 10-407.
Approval for this change also requires signage on the wells production tree clearly stating that the
well is not to be operated above 2750 psi AND there are pressure limit controls on injection fluids for
an initial flow back.
As stated in the PTD, 24/7 man watch is required for the 30 day flow back period. If Hilcorp wants to
operate the flow back with unmanned production, a separate 10-403 will be required as similarly
described in the attached email.
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. Chris Wallace, AOGCC Inspectors
From: Taylor Wellman <twellman@hilcorp.com>
Sent: Thursday, May 8, 2025 3:19 PM
To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Subject: MPU R-105 (PTD 225-017) Annulus Test and Flowback Operating Pressure Change Request
Mr. Rixse,
This is in refence to the new drill well MPU R-105 (PTD 225-017 / API 50-029-23815-00). In the approved PTD, step
20.9 (below) outlines to perform an MIT-IA to 3,500psi. This is driven by the powerfluid pressure to be used
to flowback the well. I would like to reduce MIT-IA to 2,750psi. The maximum powerfluid pressure would be
accordingly adjusted and restricted to a maximum of 2,750psi. This would be achieved by restricting the
output of the ESP’s (pumps supplying the powerfluid pressure).
If this acceptable please let me know. Thank you,
Taylor
Taylor Wellman
Hilcorp Alaska, LLC: Wells Manager – Milne Point
Office: (907) 777-8449
Cell: (907) 947-9533
Email: twellman@hilcorp.com
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity namedabove. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy ofthis 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 numberis 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 regardand the recipient should carry out such virus and other checks as it considers appropriate.
From:Rixse, Melvin G (OGC)
To:Taylor Wellman
Cc:Hayden Moser; Boman, Wade C (OGC); Regg, James B (OGC); Lau, Jack J (OGC)
Subject:RE: Milne Point Proposed Flowback Diagram (Unmanned)
Date:Thursday, May 1, 2025 4:51:00 PM
Attachments:Milne Point Proposed Injector Flowback Diagram.pptx
Taylor,
AOGCC will approve the attached proposed piping and instrumentation for MPU
Shrader Bluff new well injector 30 day flowbacks on jet pump with the following
conditions.
1. Attached piping diagram to be included in a new well’s Permit to Drill or a
separate 10-403.
2. AOGCC notified for opportunity to witness before production begins.
3. Power Fluid XV to be actuated if vertical run tubing SSV is actuated (within 2
minutes).
4. Visual leak check by pad operator performed at least once per tower (i.e. ~
every 12 hours).
5. SCADA screen available in control room for pressure and flow sensors on
injection line and well’s flow line.
6. Pilot trip pressures, both high and low, documented in permitting documents
for Hilcorp pad operators and AOGCC inspectors.
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. Haden Moser, Wade Boman, Jim Regg, Jack Lau
From: Taylor Wellman <twellman@hilcorp.com>
Sent: Tuesday, April 29, 2025 9:54 AM
To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Cc: Hayden Moser <Hayden.Moser@hilcorp.com>
Subject: Milne Point Proposed Flowback Diagram (Unmanned)
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.
Mr. Rixse,
We briefly discussed a chance to talk more about a proposed setup to be able to have the flowbacks
performed be unmanned. We feel that by using this setup it can provide equivalent and in some
portions better prevention against leaks. Hayden is a new Operations Engineer joining the Milne
Point Team and has been our point person on this. See the attached diagram and we would be
more than happy to come across to answer any questions that you may have. We are available
Wednesday (all day) or Thurs (10-2) if either of those work for you or we can arrange later.
Thank you,
Taylor
Taylor Wellman
Hilcorp Alaska, LLC: Wells Manager – Milne Point
Office: (907) 777-8449
Cell: (907) 947-9533
Email: twellman@hilcorp.com
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.
MPU Injector (Flowback)
From
Power Fluid
Header
Swab
SSV
(Actuated)
Master
Power Fluid XV
(Actuated)
Check
Choke
To
Production
Header
ChokeWing
Csg
Wing
Needle Valve
& PI
PIT PSLL***
PSHH*PSLL**
Reverse Circulating Jet Pump
Red components are temporary
3” hardline piping preferred
*set per pad
**set @ 25% of FTP or 50% of inlet separator
pressure (per AOGCC regulations)
***set @ 50% of power fluid header pressure
(per sundries)
FIT
PIT
Permanent
or temporary
SVS Panel
PIT
Unmanned Injector Flowback
Diagram
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: 5/08/2025
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20250508
Well API #PTD #Log Date Log
Company Log Type AOGCC
E-Set#
BRU 241-26 50283201970000 224068 4/15/2025 AK E-LINE Perf
BRU 244-27 50283201850000 222038 4/19/2025 AK E-LINE Perf
IRU 11-06 50283201300000 208184 4/14/2025 AK E-LINE CIBP
PBU S-22B 50029221190200 197051 4/15/2025 AK E-LINE IPROF
SRU 231-33 50133101630100 223008 4/13/2025 AK E-LINE CIBP
PBU 14-33B 50029210020200 223067 1/22/2025 BAKER MRPM
END 1-65A 50029226270100 203312 4/15/2025 HALLIBURTON COILFLAG
END 2-72 50029237810000 224016 4/11/2025 HALLIBURTON LDL
END 2-72 50029237810000 224016 4/11/2025 HALLIBURTON MFC40
MPU R-105 50029238150000 225017 4/20/2025 HALLIBURTON CAST-CBL
NS-19 50029231220000 202207 4/12/2025 HALLIBURTON RBT
PBU 06-12B 50029204560200 211115 3/22/2025 HALLIBURTON RBT
PBU 07-22A 50029209250200 212085 3/31/2025 HALLIBURTON RBT
PBU B-30B 50029215420100 201105 4/9/2025 HALLIBURTON RBT-COILFLAG
PBU H-17A 50029208620100 197152 4/10/2025 HALLIBURTON RBT-COILFLAG
PBU H-29B 50029218130200 225005 5/1/2025 HALLIBURTON RBT
PBU J-10B 50029204440200 215112 4/15/2025 HALLIBURTON RBT
PBU M-207 50029238070000 224141 4/21/2025 HALLIBURTON IPROF
PBU Z-25 50029219020000 188159 4/23/2025 HALLIBURTON IPROF
PBU Z-31 50029218710000 188112 4/25/2025 HALLIBURTON IPROF
Please include current contact information if different from above.
T40372
T40373
T40374
T40375
T40376
T40377
T40378
T40379
T40379
T40380
T40381
T40382
T40383
T40384
T40385
T40386
T40387
T40388
T40389
T40390
MPU R-105 50029238150000 225017 4/20/2025 HALLIBURTON CAST-CBL
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2025.05.08 12:42:44 -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:Rixse, Melvin G (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: MPU R-105 Intermediate Cement Slurry Change (PTD: 225-017)
Date:Thursday, April 10, 2025 2:12:31 PM
Attachments:image001.png
image003.png
From: Rixse, Melvin G (OGC)
Sent: Thursday, April 10, 2025 1:28 PM
To: Frank Roach <Frank.Roach@hilcorp.com>
Cc: Joe Lastufka (joseph.lastufka@hilcorp.com) <joseph.lastufka@hilcorp.com>
Subject: RE: MPU R-105 Intermediate Cement Slurry Change (PTD: 225-017)
Frank,
Intermediate casing cement program changes approved as you described below.
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. Joe Lastufka
From: Frank Roach <Frank.Roach@hilcorp.com>
Sent: Thursday, April 10, 2025 12:04 PM
To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Cc: Joseph Lastufka <Joseph.Lastufka@hilcorp.com>
Subject: MPU R-105 Intermediate Cement Slurry Change (PTD: 225-017)
Mel,
Thanks for the phone call yesterday. As discussed, we are looking to change the planned
cement slurries on the 9-5/8” intermediate casing. The original design was to have a 12.0ppg
lead with a 15.8ppg tail. The proposed change is to have a 14.0ppg lead with a 15.3ppg tail. New
cement calculations and Slurry parameters are as follows:
Note: The excess and volumes remain the same for lead and tail. Sacks are different due to the
different yields.
The main purpose for this change is to provide higher resolution for cement to be picked up by
the CBL for top-of-cement determination.
Let me know if you need anything additional.
Regards,
Frank V Roach
Drilling Engineer
Hilcorp Alaska, LLC
907.854.2321 mobile
907.777.8413 office
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual orentity 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 onwardtransmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by thecompany in this regard and the recipient should carry out such virus and other checks as it considers appropriate.
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________MILNE PT UNIT R-105
JBR 06/10/2025
MISC. INSPECTIONS:
FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK:
ACCUMULATOR SYSTEM:MUD SYSTEM:
P/F P/F
P/FP/FP/F
Visual Alarm
QuantityQuantity
Time/Pressure
SizeQuantity
Number of Failures:0
good test
Test Results
TEST DATA
Rig Rep:Brandon Davis/Kaleo EOperator:Hilcorp Alaska, LLC Operator Rep:Brian LaFleur/Oliver Amen
Rig Owner/Rig No.:Parker 273 PTD#:2250170 DATE:4/20/2025
Type Operation:DRILL Annular:
250/3000Type Test:BIWKLY
Valves:
250/3000
Rams:
250/3000
Test Pressures:Inspection No:bopAGE250425102005
Inspector Adam Earl
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 4
MASP:
1344
Sundry No:
Control System Response Time (sec)
Time P/F
Housekeeping:P
PTD On Location P
Standing Order Posted P
Well Sign P
Hazard Sec.P
Test Fluid W
Misc NA
Upper Kelly 1 P
Lower Kelly 1 P
Ball Type 2 P
Inside BOP 1 P
FSV Misc 0 NA
15 PNo. Valves
1 PManual Chokes
1 PHydraulic Chokes
0 NACH Misc
Stripper 0 NA
Annular Preventer 1 13 5/8 P
#1 Rams 1 3 1/2 x 5 1/2 P
#2 Rams 1 Blind P
#3 Rams 1 3 1/2 x 5 1/2 P
#4 Rams 0 NA
#5 Rams 0 NA
#6 Rams 0 NA
Choke Ln. Valves 1 3 1/8 P
HCR Valves 2 3 1/8 P
Kill Line Valves 2 2 1/16 & 3 1/8 P
Check Valve 0 NA
BOP Misc 0 NA
System Pressure P3100
Pressure After Closure P1900
200 PSI Attained P15
Full Pressure Attained P72
Blind Switch Covers:PAll Stations
Bottle precharge P
Nitgn Btls# &psi (avg)P14@2246
ACC Misc NA0
P PTrip Tank
P PPit Level Indicators
P PFlow Indicator
P PMeth Gas Detector
P PH2S Gas Detector
0 NAMS Misc
Inside Reel Valves 0 NA
Annular Preventer P21
#1 Rams P6
#2 Rams P6
#3 Rams P6
#4 Rams NA0
#5 Rams NA0
#6 Rams NA0
HCR Choke P1
HCR Kill P1
9
9
9999
9
9
9
1
Dewhurst, Andrew D (OGC)
From:Dewhurst, Andrew D (OGC)
Sent:Tuesday, 25 March, 2025 13:21
To:Graham Emerson; Frank Roach; Taylor Wellman
Cc:Davies, Stephen F (OGC); Guhl, Meredith D (OGC); Rixse, Melvin G (OGC); Wallace, Chris
D (OGC)
Subject:RE: [EXTERNAL] Confidentiality of Supporting Analyses
Graham,
The content in the March 6th slides includes well locaƟons and logs from public wells and TDS analyses from the
produced water at F-pad (which are also included in the public applicaƟon for the expansion to the aquifer exempƟon).
These data are not aīorded conĮdenƟality, therefore the provided jusƟĮcaƟon is not accepted. The slides will be
included with these emails into the public well Įle for MPU R-105.
Please respond soon if you wish to discuss this further; we are expediƟng the processing of the PTD to try and meet the
approaching spud date.
Andy
From: Graham Emerson <Graham.Emerson@hilcorp.com>
Sent: Monday, 24 March, 2025 12:42
To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Frank Roach <Frank.Roach@hilcorp.com>; Taylor
Wellman <twellman@hilcorp.com>
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Rixse,
Melvin G (OGC) <melvin.rixse@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Subject: RE: [EXTERNAL] Confidentiality of Supporting Analyses
Andy,
Hilcorp aims to keep Ʋuid data conƱdential and out of the public domain wherever possible and that was the basis
for the “conƱdential tags”.
Thanks
Graham
From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Sent: Monday, March 24, 2025 11:16 AM
To: Graham Emerson <Graham.Emerson@hilcorp.com>; Frank Roach <frank.roach@hilcorp.com>
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Rixse,
Melvin G (OGC) <melvin.rixse@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Subject: [EXTERNAL] Confidentiality of Supporting Analyses
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.
2
Graham,
I do have one other quesƟon. The slides that you provided on March 6 th were labelled with “ConĮdenƟal” tags. As they
provide key informaƟon regarding the presence of freshwater at MPU R-105, would you provide jusƟĮcaƟon as to why
they are conĮdenƟal? There are some restricƟons aīorded to conĮdenƟality as described in 20 AAC 25.537(e).
Andy
Andrew Dewhurst
Senior Petroleum Geologist
Alaska Oil and Gas ConservaƟon Commission
333 W. 7th Ave, Anchorage, AK 99501
andrew.dewhurst@alaska.gov
Direct: (907) 793-1254
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 d issemination, 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: External sender. DO NOT open links or attachments from UNKNOWN senders.
1
Dewhurst, Andrew D (OGC)
From:Dewhurst, Andrew D (OGC)
Sent:Monday, 24 March, 2025 10:00
To:Graham Emerson; Frank Roach
Cc:Davies, Stephen F (OGC)
Subject:RE: [EXTERNAL] MPU R-105 PTD (225-017): Questions
Graham,
A call is not necessary. This is suĸcient documenta Ɵon.
Thanks,
Andy
From: Graham Emerson <Graham.Emerson@hilcorp.com>
Sent: Monday, 24 March, 2025 09:41
To: Frank Roach <Frank.Roach@hilcorp.com>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>
Subject: RE: [EXTERNAL] MPU R-105 PTD (225-017): Questions
Hey Andy,
Do you want to do a call? I am available this morning.
The basis is back calculating Rw from the Archie equation assuming the zone is wet. Wet assumption due to the
oƯset ‘water source wells’ in F pad a mile away.. as below….
Salinity calculations were determined using the wireline log method for determining water salinity based on the
Humble and Archie Method equation:
Sw^n = a*Rw .Porosity ^m * Rt
I determine the approximate base of freshwater is 200’ TVD above the Top LA3, hence our cement design for R-
105.
Thanks
Graham
From: Frank Roach <Frank.Roach@hilcorp.com>
Sent: Monday, March 24, 2025 9:18 AM
To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Graham Emerson <Graham.Emerson@hilcorp.com>
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Wallace,
Chris D (OGC) <chris.wallace@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Joseph Lastufka
<Joseph.Lastufka@hilcorp.com>
Subject: RE: [EXTERNAL] MPU R-105 PTD (225-017): Questions
Andy,
2
We could be spudding as early as Saturday/Sunday if we don’t have any issues with the rig move.
For the depth interval and determination of shallow freshwater oƯ R-103 logs, I’ll let Graham answer that
question.
Regards,
Frank V Roach
Drilling Engineer
Hilcorp Alaska, LLC
907.854.2321 mobile
907.777.8413 office
From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Sent: Monday, March 24, 2025 9:10 AM
To: Graham Emerson <Graham.Emerson@hilcorp.com>; Frank Roach <Frank.Roach@hilcorp.com>
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Wallace,
Chris D (OGC) <chris.wallace@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Subject: [EXTERNAL] MPU R-105 PTD (225-017): Questions
Frank and Graham,
We have received the revised PTD for MPU R-105. We also were noƟĮed that this well has advanced in the schedule.
x What is the current anƟcipated spud date?
x I see that the depth of the intermediate TOC was picked using log data from R-103. What is the depth interval of
the shallow freshwater zone in R-103? And how was that determined? What are you using for the base of
freshwater in R-105?
Thanks,
Andy
From: Graham Emerson <Graham.Emerson@hilcorp.com>
Sent: Wednesday, 5 March, 2025 12:41
To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Frank Roach <Frank.Roach@hilcorp.com>
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Wallace,
Chris D (OGC) <chris.wallace@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Subject: RE: [EXTERNAL] MPU R-105 PTD (225-017): Questions
Thank you Andy,
I will follow up with Chris Wallace.
Graham
From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Sent: Wednesday, March 5, 2025 9:31 AM
CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders.
1
Dewhurst, Andrew D (OGC)
From:Graham Emerson <Graham.Emerson@hilcorp.com>
Sent:Friday, 7 March, 2025 08:17
To:Dewhurst, Andrew D (OGC); Frank Roach
Cc:Taylor Wellman; Wallace, Chris D (OGC); Rixse, Melvin G (OGC); Guhl, Meredith D (OGC)
Subject:RE: [EXTERNAL] MPU R-105 PTD (225-017): Questions
Thanks Andy for your quick response.
The team are discussing our options on R-105 and will get back to you.
Thanks for the guidance on the AEO expansion. We’ll get an AEO expansion application progressing.
Thanks
Graham
From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Sent: Thursday, March 6, 2025 3:25 PM
To: Graham Emerson <Graham.Emerson@hilcorp.com>; Frank Roach <Frank.Roach@hilcorp.com>
Cc: Taylor Wellman <twellman@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Rixse, Melvin G
(OGC) <melvin.rixse@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Subject: RE: [EXTERNAL] MPU R-105 PTD (225-017): Questions
Graham,
The long-term plans proposed below sound good.
For the short term of the PTD, the primary outstanding issue is that Hilcorp needs to demonstrate that the freshwater
zones are protected. There are many regs that address this including general well casing and cemen Ɵng requirements
(20 AAC 25.030) and ones speciĮc for enhanced recovery wells (20 AAC 25.402 and 20 AAC 25.412). That protecƟon also
extends to the plugging and abandonment phase, where the regs (20 AAC 25.112) are even more speciĮc about dealing
with freshwater. We would like to see how Hilcorp plans on meeƟng these requirements. Right now, the PTD doesn’t
idenƟfy the presence of a freshwater zone (see #27) or how it will be isolated/protected, which I see as a gap.
CemenƟng the zone would accomplish the requirements unƟl such Ɵme as an exempƟon were in place. But in any case,
we would like to see your analyses and plans.
Regarding the AEO expansion process, the sooner the beƩer. Based on recent aquifer exempƟon order processing and
Ɵmes to get EPA checklists and concurrence, you should expect a 30 day noƟce and comment period, the potenƟal of a
hearing if comments are received or a request to hold the hearing is received, then it may take AOGCC a several weeks
to determine if the expansion request is approved or denied and issue an order. If approved by AOGCC, EPA then has 30
days for concurrence or denial before an AOGCC issued expansion would take eīect.
Andy
CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders.
R-105 PTD follow up
6th March 2025
CONFIDENTIAL
These slides contain location and well log data from public wells
and TDS water analyses from produced water at F-pad. This
information is not afforded confidentiality. See attached emails.
-A.Dewhurst 25MAR25
F pad water source wells
F pad water
source wells
highlighting the
perforated zones
in the Prince
Creek (‘UG4’,
‘UG4A’, ‘SV1’)
CONFIDENTIAL
F pad water source
wells in relation to R
pad wells
Green ball is
UG4 pick CONFIDENTIAL
Total Dissolved Solids (F pad water source wells -Prince Creek)
Sample
Number Sample Date
Sample
Facility SW Name
Sample
Type
Sam
ple
Cate
gory
Sample
Descriptio
n
Sample
Point Analysis Name Analysis Result
Analysis
Result
Text Analysis Units
mg/L
conversion
PC00561 9/4/2006 MILNE PT MPF-02
PRODUCE
D WATER
WAT
ER_
PRO
D
PRODUC
ED
WATER
TEST
SEPARAT
OR
TOTAL DISSOLVED
SOLIDS 3160.0000 PPM 3156
PC01480 10/6/2006 MILNE PT MPF-21
PRODUCE
D WATER
WAT
ER_
PRO
D
PRODUC
ED
WATER
TEST
SEPARAT
OR
TOTAL DISSOLVED
SOLIDS 3200.0000 PPM 3196
PC01482 10/6/2006 MILNE PT MPF-77
PRODUCE
D WATER
WAT
ER_
PRO
D
PRODUC
ED
WATER
TEST
SEPARAT
OR
TOTAL DISSOLVED
SOLIDS 4300.0000 PPM 4295
PC01481 10/6/2006 MILNE PT MPF-58
PRODUCE
D WATER
WAT
ER_
PRO
D
PRODUC
ED
WATER
TEST
SEPARAT
OR
TOTAL DISSOLVED
SOLIDS 4850.0000 PPM 4844
CONFIDENTIAL
2
From: Graham Emerson <Graham.Emerson@hilcorp.com>
Sent: Thursday, 6 March, 2025 09:50
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: Taylor Wellman <twellman@hilcorp.com>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Frank
Roach <Frank.Roach@hilcorp.com>
Subject: RE: [EXTERNAL] MPU R-105 PTD (225-017): Questions
Hey Chris,
Thanks for the discussion yesterday. Attached is a table with the Total Dissolved Solids data for the F pad wells I
showed to Andy and Steve this week (water source wells). *Note that our lab data is reported in ppm, I have done
the conversion to mg/L. You can see the conversion in the attached spreadsheet.
These four wells are perforated in the SV1, UG4A and UG4 (Prince Creek) (see attached logs) and are used to mix
with our polymer on surface and is then injected into the Schrader BluƯ Formation as well as for waterƲood
injection into the Kuparuk Formation.
Going forward, I would propose we (Hilcorp) work with the AOGCC to expand the AEO 2 to encompass the
expanded (since 1987) Milne Point Unit.
The future expanded area would still meet the criteria outlined by Conoco (1987 application).
x This water does not currently or in the future plan to be a source of drinking water due to this being
economically unfeasible.
x The TDS content of this groundwater is more than 3000mg/L and less than 10000 mg/L. The F pad data
attached is in line with the data provided in the 1987 application.
In the short term, we have Parker 273 rig operations to start on well R-105 within a few weeks. Please let me know
how we can get the R-105 PTD worked in a timely manner.
Thanks and happy to chat/ screen share as necessary.
Graham
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ǣΪͳȋͻͲȌͻ͵Ͳ͵ͳͷ
ǣΪͳȋͻͲȌͷͶͷʹͶʹ
Ǥ̷ Ǥ
From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Sent: Wednesday, March 5, 2025 1:19 PM
To: Graham Emerson <Graham.Emerson@hilcorp.com>
Subject: RE: [EXTERNAL] MPU R-105 PTD (225-017): Questions
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3
Graham,
Call me whenever convenient to you.
My interest is in updaƟng AEO 2 with the new informaƟon on saliniƟes and wells. UpdaƟng the Įndings and conclusions
etc as they are the basis for the AEO issuance.
This may even result in the need to cancel the AEO if the new informa Ɵon is in direct conŇict with the requirements of
Alaska Admin Code
My thinking is Hilcorp should review this issue thoroughly and approach AOGCC informally with a path
forward. Separately, whatever AOGCC decides, EPA has a process we need to follow to allow them to make a
concurrence decision or to deny any aquifer exempƟon.
Thanks and Regards,
Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-
7542 (fax), chris.wallace@alaska.gov
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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov.
From: Graham Emerson <Graham.Emerson@hilcorp.com>
Sent: Wednesday, March 5, 2025 12:45 PM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Subject: RE: [EXTERNAL] MPU R-105 PTD (225-017): Questions
Hey Chris,
Do you have a couple of minutes to chat on the phone to clarify the issue Andy mentioned with the AEO 2?
Thanks
Graham
From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Sent: Wednesday, March 5, 2025 9:31 AM
To: Graham Emerson <Graham.Emerson@hilcorp.com>; Frank Roach <frank.roach@hilcorp.com>
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Wallace,
Chris D (OGC) <chris.wallace@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Subject: RE: [EXTERNAL] MPU R-105 PTD (225-017): Questions
Graham and Frank,
Thank you for meeƟng the other day and the follow-up informaƟon. That answers my quesƟon about signiĮcant
hydrocarbons.
The presence of freshwater at the area of current R-pad development does bring up a separate discussion. Are the
freshwater sands covered by an exisƟng aquifer exempƟon order? It appears that these wells are outside the aīected
area of AEO 2. If outside an aquifer exempƟon order, Hilcorp needs to demonstrate that these zones are protected.
You don't often get email from graham.emerson@hilcorp.com. Learn why this is important
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4
AddiƟonally, the F-pad produced water salinity data, that show values less than 3,000 mg/l TDS, appear to be
inconsistent with the basis of AEO 2. Please contact Chris Wallace who is CC’d to update/correct AEO 2.
Thanks,
Andy
From: Graham Emerson <Graham.Emerson@hilcorp.com>
Sent: Monday, 3 March, 2025 17:40
To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Cc: Frank Roach <Frank.Roach@hilcorp.com>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D
(OGC) <meredith.guhl@alaska.gov>
Subject: RE: [EXTERNAL] MPU R-105 PTD (225-017): Questions
Andy and Steve,
Here is some follow up material on the discussion of the Upper Ugnu resistivity response in relation to the R-105
Permit to Drill. It is requested this material remain conƱdential and not be put in the public domain.
Hilcorp does not think the Ugnu is hydrocarbon bearing in the interval of the Ugnu Coal1-> Top UG4A (8900-
4215’md ref R-103PB1 wellbore).
As shown in the attached slides, salinity signiƱcantly decreases from the Schrader/ Lower Ugnu through to the
Upper Ugnu (Ugnu Coal1 ->UG4A). The fresher water causes a higher Resistivity response. The Hilcorp logmodel
adjusts for this by putting in a salinity and Rw (water resisitivity) gradient into the logmodel that is tied to Ʊeld
salinity data (e.g. water source wells and deeper Schrader producers). Albeit, the model has a smooth gradient
and the changes in salinity might be more step change related to diƯerent stratigraphy.
In addition, much of the mentioned Upper Ugnu zone is actively used for source water production and therefore
not found to be hydrocarbon bearing (see slides).
Thanks
Graham
From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Sent: Monday, March 3, 2025 10:24 AM
To: Graham Emerson <Graham.Emerson@hilcorp.com>
Cc: Frank Roach <Frank.Roach@hilcorp.com>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D
(OGC) <meredith.guhl@alaska.gov>
Subject: RE: [EXTERNAL] MPU R-105 PTD (225-017): Questions
Graham,
Yes, would you please schedule a discussion with me, Steve, and Meredith (cc’d)? We are available in the a Ōernoon
today and tomorrow.
Thanks,
Andy
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From: Graham Emerson <Graham.Emerson@hilcorp.com>
Sent: Monday, 3 March, 2025 10:01
To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Cc: Frank Roach <Frank.Roach@hilcorp.com>
Subject: RE: [EXTERNAL] MPU R-105 PTD (225-017): Questions
Andy,
Happy to discuss on the phone if easier. I can screenshare on Teams if better too.
My view on the Ugnu at Raven pad is that the Ugnu M sands are wet with some residual, hydrocarbons at the top
that relates to historic charge of oil updip (these residual HC’s do not show a common contact). These
hydrocarbons will be high viscosity. I don’t think these are signiƱcant, unlike other parts of the Ʊeld where the
Ugnu is Ʊlled to the bottom of the sands.
Below is an older regional map (marked conƱdential) of the Ugnu MB to show how the asset does not view the
Ugnu a signiƱcant hydrocarbon zone in north west Milne.
Thanks
Graham
7
ȁ
ǣΪͳȋͻͲȌͻ͵Ͳ͵ͳͷ
ǣΪͳȋͻͲȌͷͶͷʹͶʹ
Ǥ̷ Ǥ
From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Sent: Friday, February 28, 2025 5:01 PM
To: Frank Roach <Frank.Roach@hilcorp.com>; Graham Emerson <Graham.Emerson@hilcorp.com>
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Rixse,
Melvin G (OGC) <melvin.rixse@alaska.gov>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com>
Subject: RE: [EXTERNAL] MPU R-105 PTD (225-017): Questions
Frank and Graham,
The Ugnu appears to be hydrocarbon bearing and was cemented at R-141 and R-142. Do you have informaƟon to
support the Ugnu is not a signiĮcant HC zone here?
Andy
From: Frank Roach <Frank.Roach@hilcorp.com>
Sent: Friday, 28 February, 2025 14:34
To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Rixse,
Melvin G (OGC) <melvin.rixse@alaska.gov>; Graham Emerson <Graham.Emerson@hilcorp.com>; Joseph Lastufka
<Joseph.Lastufka@hilcorp.com>
Subject: RE: [EXTERNAL] MPU R-105 PTD (225-017): Questions
Andy,
Spoke with Graham (our asset geologist for the R-Pad wells, also CC’d on this reply). Joe already
answered the last bullet point so this is in reference the Ʊrst two:
x Shallowest anticipated signiƱcant hydrocarbon- bearing zone is the Schrader N sands (Top Na).
This was determined using resistivity logs from the near oƯsets (MPU R-101, MPU R-103, MPU F-
96).
x Correct. There have not been any occurrences of gas hydrates while drilling MPU R-101 through
MPU R-104.
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CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open
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8
Let me know if you need anything additional.
Regards,
Frank V Roach
Drilling Engineer
Hilcorp Alaska, LLC
907.854.2321 mobile
907.777.8413 office
From: Joseph Lastufka <Joseph.Lastufka@hilcorp.com>
Sent: Thursday, February 27, 2025 11:03 AM
To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Frank Roach <Frank.Roach@hilcorp.com>
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Rixse,
Melvin G (OGC) <melvin.rixse@alaska.gov>
Subject: RE: [EXTERNAL] MPU R-105 PTD (225-017): Questions
Andy,
I can answer the third bullet point: Yes, that is a typo – I swapped the depths, sorry about that – attached is an
updated page 1 if you’d prefer not to strikeout. Your other questions will be answered soon. Please let me know if
you have any questions.
Thanks,
Joe Lastufka
Sr. Drilling Technologist
Hilcorp North Slope, LLC
Office: (907)777-8400, Cell:(907)227-8496
From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Sent: Thursday, February 27, 2025 10:54 AM
To: Frank Roach <frank.roach@hilcorp.com>
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Rixse,
Melvin G (OGC) <melvin.rixse@alaska.gov>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com>
Subject: [EXTERNAL] MPU R-105 PTD (225-017): Questions
Frank,
I’m reviewing the MPU R-105 PTD and have a few quesƟons:
x What is the shallowest anƟcipated signiĮcant hydrocarbon-bearing zone? How was that determined?
x Would you conĮrm that there have not been any occurrences of gas hydrates while drilling the MPU R-101
through R-104 wells?
x Would you conĮrm the typo (and correcƟon) on the 10-401 form as shown below?
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9
Thanks,
Andy
Andrew Dewhurst
Senior Petroleum Geologist
Alaska Oil and Gas ConservaƟon Commission
333 W. 7th Ave, Anchorage, AK 99501
andrew.dewhurst@alaska.gov
Direct: (907) 793-1254
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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
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WELL PERMIT CHECKLISTCompanyHilcorp Alaska, LLCWell Name:MILNE PT UNIT R-105Initial Class/TypeSER / 1WINJGeoArea890Unit11328On/Off ShoreOnProgramSERField & PoolWell bore segAnnular DisposalPTD#:2250170MILNE POINT, SCHRADER BLFF OIL - 525140 NIKAITCHUQ, SCHRADER BLUNA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)NA1 Permit fee attachedYes ADL025509, ADL388235, ADL355018, and ADL3906152 Lease number appropriateYes3 Unique well name and numberYes MILNE POINT, SCHRADER BLFF OIL - CO 477.005 and NIKAITCHUQ, SCHRADER BLUFF OIL - CO 6394 Well located in a defined poolNo Proposed well crosses from MPU into Nikiaitchuq Unit. Ownership is the same.5 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 waitNo Pending expansion of AIO 10C14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For servYes15 All wells within 1/4 mile area of review identified (For service well only)Yes Pre-produced injector: up to 30 days16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)Yes 20" 129.5# X-52 grouted to 80'18 Conductor string providedYes 13-3/8" L-80 68# to 2281' TVD19 Surface casing protects all known USDWsYes20 CMT vol adequate to circulate on conductor & surf csgNo Cemented from 9-5/8" shoe to 6470' MD21 CMT vol adequate to tie-in long string to surf csgYes Surface casing fully cemented.22 CMT will cover all known productive horizonsYes23 Casing designs adequate for C, T, B & permafrostYes Parker 273 rig has adequate tankage and good trucking support24 Adequate tankage or reserve pitNA This is a grassroots well.25 If a re-drill, has a 10-403 for abandonment been approvedYes Halliburton collision scan shows no close approaches to existing wells with HSE risk.26 Adequate wellbore separation proposedYes 16" Diverter ~120' in length27 If diverter required, does it meet regulationsYes All fluids overbalanced to expected pore pressure.28 Drilling fluid program schematic & equip list adequateYes 1 annular, 3 ram stack tested to 3000 psi.29 BOPEs, do they meet regulationYes 13-5/8" , 5000 psi stack tested to 3000 psi.30 BOPE press rating appropriate; test to (put psig in comments)Yes Parker 273 has 14 x 3-1/8" manual gate valves, 1 x 3-1/8" manual choke and 1 x 3-1/16" remote hydraulic choke.31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownNo Monitoring still required33 Is presence of H2S gas probableYes34 Mechanical condition of wells within AOR verified (For service well only)Yes H2S not anticipated; however, rig will have H2S sensors and alarms.35 Permit can be issued w/o hydrogen sulfide measuresYes Anticipating normally pressured reservoir. MPD to mitigate any abnormal pressures.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]ApprADDDate3/24/2025ApprMGRDate3/20/2025ApprADDDate2/25/2025AdministrationEngineeringGeologyGeologic Commissioner:GCWDate:3/26/2025Engineering Commissioner:JLCDate3/26/2025Public CommissionerDateProposed well crosses from MPU into Nikiaitchuq Unit. Ownership is the same. Pending expansion of AIO 10C.
NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)NA1 Permit fee attachedYes ADL025509, ADL388235, ADL355018, and ADL3906152 Lease number appropriateYes3 Unique well name and numberYes MILNE POINT, SCHRADER BLFF OIL - CO 477.005 and NIKAITCHUQ, SCHRADER BLUFF OIL - CO 6394 Well located in a defined poolNo Proposed well crosses from MPU into Nikiaitchuq Unit. Ownership is the same.5 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 waitNo Pending expansion of AIO 10C14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For servYes15 All wells within 1/4 mile area of review identified (For service well only)Yes Pre-produced injector: up to 30 days16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)Yes 20" 129.5# X-52 grouted to 80'18 Conductor string providedYes 13-3/8" L-80 68# to 2281' TVD19 Surface casing protects all known USDWsYes20 CMT vol adequate to circulate on conductor & surf csgNo Cemented from 9-5/8" shoe to 6470' MD21 CMT vol adequate to tie-in long string to surf csgYes Surface casing fully cemented.22 CMT will cover all known productive horizonsYes23 Casing designs adequate for C, T, B & permafrostYes Parker 273 rig has adequate tankage and good trucking support24 Adequate tankage or reserve pitNA This is a grassroots well.25 If a re-drill, has a 10-403 for abandonment been approvedYes Halliburton collision scan shows no close approaches to existing wells with HSE risk.26 Adequate wellbore separation proposedYes 16" Diverter ~120' in length27 If diverter required, does it meet regulationsYes All fluids overbalanced to expected pore pressure.28 Drilling fluid program schematic & equip list adequateYes 1 annular, 3 ram stack tested to 3000 psi.29 BOPEs, do they meet regulationYes 13-5/8" , 5000 psi stack tested to 3000 psi.30 BOPE press rating appropriate; test to (put psig in comments)Yes Parker 273 has 14 x 3-1/8" manual gate valves, 1 x 3-1/8" manual choke and 1 x 3-1/16" remote hydraulic choke.31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownNo Monitoring still required33 Is presence of H2S gas probableYes34 Mechanical condition of wells within AOR verified (For service well only)Yes H2S not anticipated; however, rig will have H2S sensors and alarms.35 Permit can be issued w/o hydrogen sulfide measuresYes Anticipating normally pressured reservoir. MPD to mitigate any abnormal pressures.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]ApprADDDate3/24/2025ApprMGRDate3/20/2025ApprADDDate2/25/2025AdministrationEngineeringGeologyGeologic Commissioner:GCWDate:3/26/2025Engineering Commissioner:JLCDate3/26/2025Public CommissionerDateProposed well crosses from MPU into Nikiaitchuq Unit. Ownership is the same. Pending expansion of AIO 10C.
