Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAboutDIO 043DISPOSAL INJECTION ORDER NO. 43
West McArthur River Unit
1. December 12, 2018 Cook Inlet Energy’s application for a DIO West
McArthur River Unit
2. December 20, 2018 Notice of Public Hearing, Affidavit of
Publication and Bulk Mailing
3. February 5, 2019 Transcript and Sign-in sheet
4. February 19, 2019 Transcript and Sign-in sheet
5. April 17, 2019 Affidavit of Notification
6. ---------------------- Emails
7. May 16, 2019 Notice of Public Hearing, Affidavit of
Publication and Bulk Mailing
8. February 24, 2022 CIE request for additional time lost due to suspension
of operations and production at WMRU (DIO 43.001)
9. July 7, 2022 CIE DIO 43 confirmation request (DIO 43.002)
10. July 20, 2023 CIE admin approval convert WMRU-08 to injection
(DIO 43.003)
11. ------------------------ Monthly reports
12. July 1, 2024 Monthly reporting emails
13. August 20, 2024 GLA request approval to convert well to an injection
Well (DIO 43.004)
(Confidential items held in secure storage)
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION
333 West 71" Avenue
Anchorage, Alaska 99501
Re: THE APPLICATION OF Cook Inlet
Energy, LLC. for disposal of Class II
oil field wastes by underground
injection in the Hemlock Formation
in wells located in the West
McArthur River Unit Section 10
T8N, R14W S.M.
IT APPEARING THAT:
Disposal Injection Order No. 43
Docket No. DIO-18-004
Hemlock Formation
West McArthur River Oil Pool
West McArthur River Field
West McArthur River Unit
June 5, 2019
By application received December 13, 2018, Cook Inlet Energy, LLC (CIE) requested
authorization for underground disposal of Class II oil field waste fluids into existing wells
(Class II wells) in the West McArthur River Unit (WMRU).
2. Pursuant to 20 AAC 25.540, the Alaska Oil and Gas Conservation Commission (AOGCC)
scheduled a public hearing for February 5, 2019. On December 19, 2018, the AOGCC
published notice of the opportunity for that hearing on the State of Alaska's Online Public
Notice website, on the AOGCC's website, and physically mailed the notice to those that have
requested AOGCC use the United States Postal Service (USPS). On December 20, 2018, the
notice was published in the ANCHORAGE DAILY NEWS.
3. At the February 5, 2019 hearing, CIE was unprepared to present evidence in support of its
application and the hearing was continued to February 19, 2019. At the February 19, 2019
hearing CIE provided testimony and presented evidence in support of its Application. The
record was closed at the end of the hearing.
4. On April 1, 2019 AOGCC determined that CIE did not provide the required affidavit showing
that a copy of the application for disposal was provided to all the surface owners within % mile
radius. Pursuant to 20 AAC 25.540, the AOGCC tentatively scheduled a public hearing for
June 18, 2019. On May 15, 2019, the AOGCC published notice of the opportunity for that
hearing on the State of Alaska's Online Public Notice website, on the AOGCC's website, and
physically mailed the notice to those that have requested AOGCC use the USPS. On May 16,
2019, the notice was published in the ANCHORAGE DAILY NEWS.
5. CIE sent by certified mail a copy of the application for disposal to all operators and surface
owners within '/a mile radius of the proposed disposal wells — i.e, the State of Alaska, Alaska
Department of Natural Resources (ADNR) (offshore surface and subsurface owner), Salamatof
Disposal Injection Order 43
June 5, 2019
Page 2 of 10
Native Association, Inc (the only onshore surface owner), and Cook Inlet Region, Inc (the only
onshore subsurface owner). CIE provided AOGCC an affidavit affirming that ADNR,
Salamatof Native Association, Inc, and Cook Inlet Region, Inc were provided a copy of the
DIO application. CIE provided the names and addresses to which the DIO application was
delivered.
6. On May 29, 2019 Mike Munger, Executive Director, Cook Inlet Regional Citizens Advisory
Council (CIRCAC) requested that AOGCC hold the tentatively scheduled public hearing.
AOGCC forwarded to CIRCAC the application and the February 19, 2019 hearing presentation
and testimony transcript. On May 31, 2019 CIRCAC rescinded its hearing request based on
the additional information AOGCC provided. No other comments or request for hearing were
received regarding the CIE application.
7. The tentatively scheduled public hearing was vacated.
8. The information submitted by CIE, hearing presentation material and testimony, and public
records for WMRU wells are the basis for this order.
FINDINGS:
1. Location of Adjacent Wells (20 AAC 25.252(c)(1))
Currently, CIE has identified three candidate wells for possible conversion to disposal injection
operations: W. McArthur Unit IA, 7A, and 8 (Fig. 1).
Figure 2, below, displays the eight wells that fall within a 1/4 mile radius of the three disposal
well candidates where they intersect the top Hemlock formation. These wells include: West
McArthur Unit 1, 2A, 213, 3, 5, 6, 7, and Sword 1. Only WMRU 213, 6, and Sword 1 are
currently producing. The other wells are shut in.
2. Notification of Operators/Surface Owners (20 AAC 25.252(c)(2) and 20 AAC 25.252(c)(3))
Within'/4-mile radius of the proposed disposal wells, CIE is the only operator and the State of
Alaska, Alaska Department of Natural Resources (ADNR) is the only offshore surface and
subsurface owner. Within '/<-mile radius of the proposed disposal wells, Salamatof Native
Association, Inc is the only onshore surface owner, and Cook Inlet Region, Inc is the only
onshore subsurface owner. CIE has provided AOGCC an affidavit affirming that ADNR,
Salamatof Native Association, Inc, and Cook Inlet Region, Inc were provided a copy of the
DIO application.
Disposal Injection Order 43
June 5, 2019
Page 3 of 10
1
m
West McArthur R\er Unit Outline -
8 14VV
Gla-lef 00 �d Ga
VJ!4U=u».41b.vc• ftp.:
�1
L'ILES
Figure 1: West McArthw River knit Potential Disposal Wells; WN'IKU IA, W'N1RU 7A, and W.\4RU S.
Disposal Injection Order 43
June 5,2019
Page 4 of 10
Figure l Plat showing all Wh4R[; wells. Circle=_ with Y mile radius are around polenlial disposal wells
inlcrm:lion widr the top of lite Ilerrilock Formation,
Disposal Injection Order 43
June 5, 2019
Page 5 of 10
3. Geological Information on Disposal and Confinine Zones (20 AAC 25.252(c)(4))
The target reservoir for disposal in the WMRU is the Oligocene Hemlock formation
(Hemlock), which unconformably overlies the West Foreland formation and averages 400-
500' thick. The Hemlock consists of a thick sequence of conglomerates and sandstones
separated by thin interbeds of impermeable claystones and siltstones. Coal beds are found
between some facies of the Hemlock, which overall is very uniform in thickness but not in
individual lithofacies components. The stratigraphic variation among lithofacies is typical of
a braided stream depositional environment.
The Hemlock can be divided into three stratigraphic units: Upper, Middle, and Lower which
are composed of six lithofacies:
1. Pebble conglomerate with porosity ranging 7-11%
2. Pebble/gravel sandstone with porosity ranging from 10-16%.
3. Medium to coarse-grained sandstone with porosity ranging from 12-18%.
4. Fine-grained sandstone with porosity ranging from 12-14%.
5. Very fine-grained siltstones. Nonpermeable with 14% porosity.
6. Highly carbonaceous claystones, which are nonpermeable, have no porosity, and act as
seals for the reservoir intervals.
The Hemlock reservoir is heterogeneous due to its large braided stream depositional
environment. Sediments were sourced from the northwest, and the general orientation of the
facies is from northwest to southeast. This trend creates a pattern for preferential flow from
southeast to northwest within the Hemlock, a strong water -drive reservoir. Overall average
porosity range of these Hemlock sandstones is 7-18% with corresponding permeabilities of
100-300 md.
In brief, the WMRU structure is a southwest to northeast trending anticline that has been
bisected by both east -west and north -south trending faults. Due to lack of pressure differences
across the faults within WMRU, CIE concludes that these faults are not sealing. Hemlock
sandstone and conglomerate reservoir facies are in juxtaposition against comparable pay
intervals within the Hemlock.
4. Evaluation of Fluid Confinement (20 AAC 25.252(c)(9))
Due to the braided stream depositional character of the Hemlock, numerous permeability
barriers are present to provide containment both above and below the zones to be used for
disposal operations. The confining intervals are bound by continuous tight shales and coals
(non -reservoir). These confining intervals are not only present in the Hemlock but also in the
overlying Tyonek formation and in the underlying West Foreland formation.
Disposal Injection Order 43
June 5, 2019
Page 6 of 10
5. Aquifer Exemption (20 AAC 25.252(c)(11)); Standard Laboratory Water Analysis of the
Formation (20 AAC 25.252(c)(10))
EPA AE05-II exempts aquifers '/ mile beyond and directly below oil and gas producing
McArthur River Field as per 40 CFR 147.102(b)(2)(ii). CIE presented water sample analysis
results for the Hemlock from Sword 1 (27,640 mg/1) and from the Redoubt Unit (17,085 mg/1
produced water).
6. Well Logs (20 AAC 25.252(c)(5))
Log data from existing wells in WMRU are on file with the AOGCC. The representative well,
WMRU No. 1, has a complete set of logs.
7. Demonstration of Mechanical Integrity and Disposal Zone Isolation (20 AAC 25.252(c)(6))
CIE proposes to convert existing wells into Hemlock disposal injection wells. Conversion of
each existing well to a disposal well will require approval by AOGCC of an Application for
Sundry Approvals (Form 10-403). No disposal is authorized until the well meets AOGCC's
well integrity requirements and demonstrates zonal isolation.
A casing mechanical integrity test will be performed in accordance with 20 AAC 25.412 prior
to initiation of disposal operations. CIE will perform mechanical integrity tests of the tubing
and tubing -casing annulus (including packer) before disposal injection commences.
Additional baseline assessments and subsequent evaluations may be necessary to confirm the
wells have the proper mechanical integrity for disposal injection as proposed.
8. Disposal Fluid Type, Composition, Source, Volume, and Compatibility with Disposal Zone
(20 AAC 25.252(c)(7))
Injected fluids are expected to be compatible with the lithology and in-situ formation water of
the proposed disposal injection zone based on operating experience and past performance of
WMRU Class I disposal well 413, Redoubt Unit (RU) Dl Class I disposal well, and Class II
RU EOR wells (e.g., pressures, rates, and volumes). No compatibility issues have been
reported associated with disposal injection into the Hemlock at WMRU or RU or other fields
in the Cook hilet.
9. Estimated Injection Pressures (20 AAC 25.252(c)(8))
CIE estimates maximum surface injection pressure could reach 4,000 psig if sporadic plugging
of perforations or fracture -flow channels occurs. Accordingly, CIE requested 4,000 psig as
the maximum allowed surface injection pressure.
10. Mechanical Condition of Wells Penetrating the Disposal Zone Within a '/4 -Mile Radius of the
proposed disposal wells (20 AAC 25.2520(12))
Currently, Cook Inlet Energy (CIE) has three potential wells to be converted to disposal wells
including W. McArthur Unit IA, 7A, and 8 (Fig. 1). Figure 2 shows the eight wells that fall
within a quarter mile radius of the three disposal well candidates where they intersect the top
Hemlock formation. CIE, in the disposal well Application for Sundry Approvals (Form 10-
Disposal Injection Order 43
June 5, 2019
Page 7 of 10
403) will review the well and surrounding wells for integrity and demonstrate zonal isolation.
Prior to disposal injection, CIE shall ensure a cement bond log or equivalent will be run or that
cementing records and calculations confirm the cement tops and that casing strings have
adequate cement to prevent vertical migration of disposed fluids.
CONCLUSIONS:
1. The requirements of 20 AAC 25.252 for approval of underground disposal are met.
2. Hemlock formation water samples from the area exceed 10,000 mg/I total dissolved solids.
3. EPA AE05-II exempts aquifers '/ mile beyond and directly below oil and gas producing
McArthur River Field as per 40 CFR 147.102(b)(2)(ii).
4. Confining intervals, both upper and lower, exist within the Hemlock braided stream
depositional complex. These confining zones are composed of continuous tight shales and
non -reservoir coals. These impermeable barriers occur within the Hemlock, the overlying
Tyonek, and the underlying West Foreland formations.
5. Due to lack of pressure differences across the faults within WMRU, the operator has concluded
that the faults are not sealing
6. No compatibility issues are to be expected by disposing of produced water from the Hemlock
by injecting it back into the Hemlock.
7. A fracture gradient greater than 0.86 psi/ft can be estimated based on multiple in -field
Formation Integrity Tests (FIT) and Leak Off Tests (LOT) above and below the Hemlock.
CIE's requested surface pressure of up to 4,000 psi while injecting produced water predicts
that fractures will not penetrate the upper confining zone or breach the lower confining zone.
Disposed waste fluids will be contained within the receiving interval by confining lithologies,
cement isolation of the well bore, and planned operating conditions.
8. Supplemental mechanical integrity demonstrations and regularly scheduled surveillance of
injection operations—including baseline and subsequent temperature surveys, monitoring of
injection performance (i.e., pressures and rates), and analyses of the data for indications of
anomalous events—will ensure that waste fluids remain within the disposal interval and ensure
appropriate operation of the field.
9. Future wells within 1/2 -mile of the proposed injection interval in each of the disposal wells
must be constructed to ensure they do not serve as a conduit for fluid migration from the
disposal zone.
NOW, THEREFORE, IT IS ORDERED THAT CIE's request for authorization for
underground disposal of Class II oil field waste fluids into existing wells (Class II wells) in the
West McArthur River Unit (WMRU) is GRANTED. The following rules, in addition to statewide
requirements under AS 31.05 and 20 AAC 25 (to the extent not superseded by these rules), govern
Class II disposal injection operations into the Hemlock within the WMRU:
Disposal Injection Order 43
June 5, 2019
Page 8 of 10
RULE 1: Iniection Strata for Disposal
Underground disposal of Class II oil field waste fluids is permitted into the Hemlock Formation in
the interval that is common to, and correlative with, the West McArthur River oil pool interval
from 13,174 ft to 13,660 ft measured depth in well WMRU No. 1.
RULE 2: Authorized Fluids
This authorization is limited to Class II oil field waste fluids generated during drilling, production,
workover, or abandonment operations, including:
Drilling fluids; drill cuttings; well workover fluids; stimulation fluids and solids; produced
water; rig wash water; formation materials; naturally occurring radioactive materials; scale;
tracer materials; glycol dehydration; reserve pit fluids; chemicals used in the well or for
production processing at the surface (in direct contact with produced fluids); and
precipitation accumulating in drilling and production impoundment areas.
The eligibility of other fluids for Class II waste disposal injection will be considered by the
AOGCC on a case-by-case basis upon application by the operator.
This order does not authorize commercial Class II disposal injection.
RULE 3: Iniection Rate and Pressure
Injection rates and pressures must be maintained such that the injected fluids will not initiate or
propagate fractures through the confining intervals or migrate out of the approved injection
stratum. Disposal injection is authorized at wellhead injection pressures that do not exceed 4,000
psig while pumping water.
RULE 4: Demonstration of Mechanical Integrity
An AOGCC-witnessed mechanical integrity test must be performed after injection is commenced
for the first time in the well, to be scheduled when injection conditions (temperature, pressure,
rate, etc.) have stabilized. Subsequent mechanical integrity tests must be performed at least once
every two years after the date of the first AOGCC-witnessed test if the well injects solids laden
slurries, and at least once every four years if the well only injects solids -free fluids.
RULE 5: Well Integrity Failure and Confinement
The Operator shall immediately shut in the well if continued operation would be unsafe or threaten
contamination of freshwater, or if so directed by the AOGCC. If fluids are found to be fracturing
through a confining interval or migrating out of the approved injection stratum, the operator must
immediately shut in the well. Upon discovery of such an event, the operator must immediately
notify the AOGCC, provide details of the operation, and propose actions to prevent recurrence.
Injection may not be restarted until approved by the AOGCC. A monthly report of daily tubing
and casing annuli pressures and injection rates must be provided to the AOGCC if the well
indicates any well integrity failure or lack of injection zone isolation. The AOGCC may
immediately suspend, revoke, or modify this authorization if injected fluids fail to be confined to
the approved disposal interval.
Disposal Injection Order 43
June 5, 2019
Page 9 of 10
An existing well may not be converted to a disposal well absent prior AOGCC approval of an
Application for Sundry Approvals (Form 10-403). The well must meet the AOGCC well integrity
requirements and demonstrate zonal isolation prior to disposal approval. CIE will be required to
perform the mechanical integrity tests and injection testing to confirm feasibility of utilization for
disposal operations.
RULE 6: Surveillance
The operator shall run a baseline temperature log and perform a baseline step -rate test prior to
initial injection. A subsequent temperature log must be run one month after injection begins to
delineate the receiving zone of the injected fluids. CIE shall perform an annual reservoir pressure
survey of the disposal zone. Surface pressures and rates must be monitored continuously during
injection for any indications of anomalous conditions. Results of daily wellhead pressure
observations must be documented and available to the AOGCC upon request. The conduct of
subsequent temperature surveys or other surveillance logging (e.g., water flow; acoustic) will be
based on the results of the initial and follow-up temperature surveys and injection performance
monitoring data.
The annual report of underground injection (Form 10-413) shall also include data sufficient to
characterize the disposal operation, including, among other information, the following: injection
and annuli pressures (i.e., daily average, maximum, and minimum pressures); fluid volumes
injected (i.e., in disposal and clean fluid sweeps); injection rates; an assessment of the fracture
geometry, a description of any anomalous injection results; a calculated zone of influence for the
injected fluids; and an assessment of the applicability of the disposal order findings, conclusions,
and rules based on actual performance.
The annual report shall also include a section titled "Induced Seismicity" in which CIE shall detail
its monitoring efforts and evaluate the risks.
RULE 7: Notification of Imnroner Class II Iniection
Injection of fluids other than those listed in Rule 2 without prior authorization is considered
improper Class II injection. Upon discovery of such an event, the operator must immediately
notify the AOGCC, provide details of the operation, and propose actions to prevent recurrence.
Notification or other legal requirements of any other State or Federal agency remain the operator's
responsibility.
RULE 8: Administrative Action
Upon proper application, or its own motion, and unless notice and public hearing are otherwise
required, the AOGCC may administratively waive the requirements of any rule stated herein or
administratively amend this order as long as the change does not promote waste or jeopardize
correlative rights, is based on sound engineering and geoscience principles, and will not result in
an increased risk of fluid movement into freshwater or outside of the authorized injection zone.
Disposal Injection Order 43
June 5, 2019
Page 10 of 10
DONE at Anchorage, Alaska, and dated June 5, 2019.
x W -----
Daniel T. Seamount, Jr. Js ee�ielowski
Commissioner Commissioner
AND APPEAL NOTICE
As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC
grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by
it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the
order or decision is believed to be erroneous.
The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it
within 10 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of
reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the
AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by
inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed.
If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on
reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed
within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on
reconsideration.
In computing a period of time above, the date of the event or default after which the designated period begins to not is not included in the period;
the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day
that does not fall on a weekend or state holiday.
Bernie Karl
K&K Recycling Inc.
P.O. Box 58055
Fairbanks, AK 99711
Gordon Severson
3201 Westmar Cir.
Anchorage, AK 99508-4336
Penny Vadla
399 W. Riverview Ave.
Soldotna, AK 99669-7714
George Vaught, Jr. Darwin Waldsmith Richard Wagner
P.O. Box 13557 P.O. Box 39309 P.O. Box 60868
Denver, CO 80201-3557 Ninilchik, AK 99639 Fairbanks, AK 99706
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
ADMINISTRATIVE APPROVAL
DISPOSAL INJECTION ORDER 43.001
March 18, 2022
Mr. David Pascal, Chief Operating Officer
Cook Inlet Energy, LLC.
188 W. Northern Lights Blvd., Suite 510
Anchorage, AK 99503
Re: Docket Number: DIO-22-001
Request for Additional Time Lost Due to Suspension of Operations and Production
Administrative Approval to Disposal Injection Order 43
West McArthur River Unit, West McArthur River Oil Pool
Dear Mr. Pascal:
In December 2018, Cook Inlet Energy, LLC (CIE) applied for approval to dispose of excess produced
water into the West McArthur River Unit (WMRU) reservoir by converting select shut-in wells into
disposal wells to aid in maximum recovery out of the WMRU. The Alaska Oil and Gas Conservation
Commission (AOGCC) issued Disposal Injection Order (DIO) No. 43 on June 5, 2019. Because CIE did
not begin disposal operations within two years, under 20 AAC 25.556(c), the DIO expired on June 5,
2021.
By emailed letter dated February 24, 2022, CIE requested approval for additional time lost due to
Suspension of Operations and Production (SOP) at the WMRU. CIE’s request is based in part on the
SOP being necessitated by the constraints and impacts imposed by the COVID-19 pandemic. Due to the
unique circumstances surrounding the impact of the pandemic on production operations, the AOGCC
will toll the two-year period contained in 20 AAC 25.556(c)(1) for the period of the SOP, 525 days.
DIO 43 shall hereby expire on November 12, 2022, unless disposal operations authorized under DIO 43
commence.
DONE at Anchorage, Alaska and dated March 18, 2022.
Jeremy M. Price Daniel T. Seamount, Jr. Jessie L. Chmielowski
Chair, Commissioner Commissioner Commissioner
Dan
Seamount
Digitally signed by
Dan Seamount
Date: 2022.03.17
15:26:47 -08'00'
Jeremy Price
Digitally signed by
Jeremy Price
Date: 2022.03.17
15:56:51 -08'00'
Jessie L.
Chmielowski
Digitally signed by
Jessie L. Chmielowski
Date: 2022.03.18
16:17:00 -04'00'
DIO 43.001
March 18, 2022
Page 2 of 2
RECONSIDERATION AND APPEAL NOTICE
As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as
the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of
the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration
must set out the respect in which the order or decision is believed to be erroneous.
The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to
act on it within 10 days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision
and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days
after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying
reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on
which the application for reconsideration was filed.
If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision
on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal
MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the
order or decision on reconsideration.
In computing a period of time above, the date of the event or default after which the designated period begins to run is not included
in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs
until 5:00 p.m. on the next day that does not fall on a weekend or state holiday.
From:Salazar, Grace (OGC)
To:AOGCC_Public_Notices
Subject:AOGCC Disposal Injection Order No. 43.001
Date:Friday, March 18, 2022 12:45:00 PM
Attachments:DIO 43.001.pdf
The Alaska Oil and Gas Conservation Commission has issued the attached administrative approval
granting Cook Inlet Energy, LLC’s request for additional time to fulfill obligations under Disposal
Injection Order No. 43.
Grace
____________________________________
Respectfully,
M. Grace Salazar, Special Assistant
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue
Anchorage, AK 99501
Direct: (907) 793-1221
Email: grace.salazar@alaska.gov
https://www.commerce.alaska.gov/web/aogcc/
From:Salazar, Grace (OGC)
To:David Pascal
Cc:Wallace, Chris D (OGC)
Subject:Disposal Injection Order No. 43.001
Date:Friday, March 18, 2022 12:38:00 PM
Attachments:DIO 43.001.pdf
Dear Mr. Pascal,
The Alaska Oil and Gas Conservation Commission has issued the attached administrative approval
granting Cook Inlet Energy, LLC’s request for additional time to fulfill obligations under Disposal
Injection Order No. 43.
If you have any questions, please feel free to contact Mr. Chris Wallace, Senior Petroleum Engineer,
at (907) 793-1250 or via email at chris.wallace@alaska.gov.
Grace
____________________________________
Respectfully,
M. Grace Salazar, Special Assistant
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue
Anchorage, AK 99501
Direct: (907) 793-1221
Email: grace.salazar@alaska.gov
https://www.commerce.alaska.gov/web/aogcc/
AOGCC
333 W 7th Avenue, Anchorage, AK 99501
TO: BERNIE KARL
K&K RECLYCLING, INC.
PO BOX 58055
FAIRBANKS, AK 99711
Mailed 3/21/22 gs
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
ADMINISTRATIVE APPROVAL
DISPOSAL INJECTION ORDER 43.002
Mr. Scott Begins, Production and Facilities Engineer
Cook Inlet Energy, LLC.
188 W. Northern Lights Blvd., Suite 510
Anchorage, AK 99503
Re: Docket Number: DIO-23-001
Request for removal of expiration condition
Administrative Approval to Disposal Injection Order (DIO) 43
West McArthur River Unit (WMRU), West McArthur River Oil Pool
Dear Mr. Begins:
By emailed letter dated January 11, 2023, Cook Inlet Energy, LLC (CIE) requested confirmation that
DIO 43 is still in effect.
DIO 43.001, issued March 18, 2022, authorized a toll of the expiration date of DIO 43 due to COVID-
19 operational shutdown. DIO 43.001 stated “DIO 43 shall hereby expire on November 12, 2022, unless
disposal operations authorized under DIO 43 commence.”
CIE is performing well work authorized by AOGCC under Sundry 322-403 that includes injectivity step
rate tests designed to evaluate the authorized disposal zone. AOGCC believes these are good faith efforts
towards the commencement of disposal operations under DIO 43, and therefore removal of the DIO
43.001 November 12, 2022, expiration is prudent.
As per 20 AAC 25.556(c)(2), the DIO 43 expiration will be “two years after injection operations
authorized in that order conclude.”
DONE at Anchorage, Alaska and dated January 31, 2023.
Brett W. Huber, Sr Jessie L. Chmielowski
Chair, Commissioner Commissioner
GregRU\ C. Wilson
Commissioner
Gregory
Wilson
Digitally signed by
Gregory Wilson
Date: 2023.01.30
15:38:36 -09'00'
Jessie L.
Chmielowski
Digitally signed by
Jessie L. Chmielowski
Date: 2023.01.30
15:43:36 -09'00'
Brett W.
Huber. Sr.
Digitally signed by
Brett W. Huber. Sr.
Date: 2023.01.30
15:49:46 -09'00'
DIO 43.002
January 31, 2023
Page 2 of 2
RECONSIDERATION AND APPEAL NOTICE
As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as
the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of
the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration
must set out the respect in which the order or decision is believed to be erroneous.
The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to
act on it within 10 days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision
and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days
after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying
reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on
which the application for reconsideration was filed.
If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision
on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal
MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the
order or decision on reconsideration.
In computing a period of time above, the date of the event or default after which the designated period begins to run is not included
in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs
until 5:00 p.m. on the next day that does not fall on a weekend or state holiday.
1
Carlisle, Samantha J (OGC)
From:Carlisle, Samantha J (OGC) <samantha.carlisle@alaska.gov>
Sent:Tuesday, January 31, 2023 8:24 AM
To:AOGCC_Public_Notices
Subject:[AOGCC_Public_Notices] Disposal Injection Order 43.002 (WMRU)
Attachments:dio43.002.pdf
Docket Number: DIO-23-001
Request for removal of expiration condition
Administrative Approval to Disposal Injection Order (DIO) 43
West McArthur River Unit (WMRU), West McArthur River Oil Pool
Samantha Carlisle
AOGCC Special Assistant
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue
Anchorage, AK 99501
(907) 793-1223
__________________________________
List Name: AOGCC_Public_Notices@list.state.ak.us
You subscribed as: samantha.carlisle@alaska.gov
Unsubscribe at: https://list.state.ak.us/mailman/options/aogcc_public_notices/samantha.carlisle%40alaska.gov
Bernie Karl
K&K Recycling Inc.
P.O. Box 58055
Fairbanks, AK 99711
mailed 1/31/23
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
ADMINISTRATIVE APPROVAL
DISPOSAL INJECTION ORDER 43.003
Mr. Mike Fairbanks
Geologist, Exploration Manager
Cook Inlet Energy, LLC.
188 W. Northern Lights Blvd., Suite 510
Anchorage, AK 99503
Re: Docket Number: DIO-23-002
Request for Administrative Approval to Disposal Injection Order (DIO) 43; Water Injection
West McArthur River Unit (WMRU) 8 (PTD 2131520), West McArthur River Oil Pool
Dear Mr. Fairbanks:
By emailed letter dated July 20, 2023, Cook Inlet Energy, LLC (CIE) requested approval to continue
disposal injection with known tubing by inner annulus (TxIA) and IA pressure communications.
In accordance with 20AAC 25.556(d), the Alaska Oil and Gas Conservation Commission (AOGCC)
hereby GRANTS, subject to conditions, CIE’s request for administrative approval to continue Class II
primarily produced water disposal injection in the subject well.
CIE has converted this producer into a Class II disposal well under Sundry 322-403. CIE has demonstrated
a TxIA pressure communication after multiple unsuccessful attempts to seal the jet pump cavity at 13,481
ft. CIE was able to demonstrate tubing (T) integrity by testing against a plug set above the jet pump cavity.
The well will not pass a standard mechanical integrity test (MIT) of the inner annulus, with the probable
communication being the production packer at 13,523 ft. CIE will complete a static and injecting
temperature survey to demonstrate fluid entry is below the packer and into the authorized zone. Reported
results of CIE diagnostic procedures and wellhead pressure trend plots will ensure injection is confined to
the authorized zone. CIE will maintain live transmitters on the inner and outer annulus and alarm functions
in the Supervisory Control and Data Acquisition (SCADA) system that create layers of protection from
an over-pressure event. AOGCC believes CIE can safely manage the TxIA and IA communication with
periodic pressure bleeds by maintaining the inner annulus to a pressure not to exceed 3,000 psi and the
outer annulus not to exceed 300 psi. Accordingly, the AOGCC believes that the well’s condition does not
compromise overall well integrity so as to threaten human safety or the environment.
AOGCC’s approval to continue Class II, solids free, primarily produced water disposal injection in
WMRU 8 is conditioned upon the following:
1) CIE shall record wellhead pressures and injection rate daily;
DIO 43.003
August 9, 2023
Page 2 of 2
2) CIE shall submit to the AOGCC a monthly report of well pressures, injection rates, and
pressure bleeds for all annuli. Bleeds to be flagged on the report;
3) CIE shall perform a baseline temperature survey prior to injection and within one month
after disposal begins. A temperature survey shall be run every two years to confirm
injection is confined to the authorized zone. CIE shall report to AOGCC the temperature
survey data, results, and interpretation;
4) CIE shall limit the well’s inner annulus operating pressure to 3,000 psi and the outer
annulus operating pressure to 300 psi. Audible control room alarms shall be set at or below
these limits;
5) CIE shall monitor the inner and outer annulus pressures in real time with its automated
system;
6) CIE shall immediately shut in the well and notify the AOGCC if there is any change in the
well's mechanical condition; and
7) After well shut in due to a change in the well's mechanical condition, AOGCC approval
shall be required to restart disposal injection.
DONE at Anchorage, Alaska and dated August 9, 2023.
Brett W. Huber, Sr Jessie L. Chmielowski Gregory C. Wilson
Chair, Commissioner Commissioner Commissioner
RECONSIDERATION AND APPEAL NOTICE
As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as
the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of
the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration
must set out the respect in which the order or decision is believed to be erroneous.
The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to
act on it within 10 days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision
and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days
after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying
reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on
which the application for reconsideration was filed.
If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision
on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal
MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the
order or decision on reconsideration.
In computing a period of time above, the date of the event or default after which the designated period begins to run is not included
in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs
until 5:00 p.m. on the next day that does not fall on a weekend or state holiday.
Gregory
Wilson
Digitally signed by
Gregory Wilson
Date: 2023.08.09
14:41:06 -08'00'
Jessie L.
Chmielowski
Digitally signed by
Jessie L. Chmielowski
Date: 2023.08.09
14:56:07 -08'00'
Brett W.
Huber, Sr.
Digitally signed by
Brett W. Huber, Sr.
Date: 2023.08.09
15:40:51 -08'00'
From:Carlisle, Samantha J (OGC)
To:AOGCC_Public_Notices
Subject:[AOGCC_Public_Notices] Disposal Injection Order 43.003 (WMRU)
Date:Thursday, August 10, 2023 9:26:42 AM
Attachments:dio 43.003.pdf
Docket Number: DIO-23-002
Request for Administrative Approval to Disposal Injection Order (DIO) 43; Water Injection
West McArthur River Unit (WMRU) 8 (PTD 2131520), West McArthur River Oil Pool
Samantha Carlisle
Special Assistant
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue
Anchorage, AK 99501
(907) 793-1223
__________________________________
List Name: AOGCC_Public_Notices@list.state.ak.us
You subscribed as: samantha.carlisle@alaska.gov
Unsubscribe at:
https://list.state.ak.us/mailman/options/aogcc_public_notices/samantha.carlisle%40alaska.gov
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
ADMINISTRATIVE APPROVAL
DISPOSAL INJECTION ORDER 43.004
Mr. Mike Fairbanks, Geologist, Exploration Manager
Cook Inlet Energy, LLC.
188 W. Northern Lights Blvd., Suite 510
Anchorage, AK 99503
Re: Docket Number: DIO-24-004
Request for Administrative Approval to Disposal Injection Order (DIO) 43; Water
Injection
West McArthur River Unit (WMRU) 1A (PTD 195-118), West McArthur River Oil Pool
Dear Mr. Fairbanks:
By emailed letter dated August 20, 2024, Cook Inlet Energy, LLC (CIE) requested approval to
continue disposal injection with known tubing by inner annulus (TxIA) pressure communication.
In accordance with 20AAC 25.556(d), the Alaska Oil and Gas Conservation Commission
(AOGCC) hereby GRANTS, subject to conditions, CIE’s request for administrative approval to
continue Class II primarily produced water disposal injection in the subject well.
CIE has converted this producer into a Class II disposal well under Sundry 323-084. CIE has
demonstrated a TxIA pressure communication after multiple unsuccessful attempts to seal the jet
pump cavity at 13,343 ft. CIE was able to demonstrate IA integrity to the packer with a passing
combination mechanical integrity test of the tubing and IA by testing against a plug set below the
jet pump cavity. The well will not pass a standard mechanical integrity test (MIT) of the inner
annulus, with the probable communication being wear on the sealing surfaces of the jet pump
cavity or the tubing pup joint above the jet pump cavity. CIE will complete a static and injecting
temperature survey to demonstrate fluid entry is below the packer and into the authorized zone.
Reported results of CIE diagnostic procedures and wellhead pressure trend plots will ensure
injection is confined to the authorized zone. CIE will maintain live transmitters on the inner and
outer annulus and alarm functions in the Supervisory Control and Data Acquisition (SCADA)
system that create layers of protection from an over-pressure event. AOGCC believes CIE can
safely manage the TxIA communication with periodic pressure bleeds by maintaining the inner
annulus to a pressure not to exceed 3,000 psi and the outer annulus not to exceed 300 psi.
Accordingly, the AOGCC believes that the well’s condition does not compromise overall well
integrity so as to threaten human safety or the environment.
DIO 43.004
September 6, 2024
Page 2 of 2
AOGCC’s approval to continue Class II, solids free, primarily produced water disposal injection
in WMRU 1A is conditioned upon the following:
1) CIE shall record wellhead pressures and injection rate daily;
2) CIE shall submit to the AOGCC a monthly report of well pressures, injection rates,
and pressure bleeds for all annuli. Bleeds to be flagged on the report;
3) CIE shall perform a baseline temperature survey prior to injection and within one
month after disposal begins. A temperature survey shall be run every two years to
confirm injection is confined to the authorized zone. CIE shall report to AOGCC
the temperature survey data, results, and interpretation;
4) CIE shall limit the well’s inner annulus operating pressure to 3,000 psi and the outer
annulus operating pressure to 300 psi. Audible control room alarms shall be set at
or below these limits;
5) CIE shall monitor the inner and outer annulus pressures in real time with its
automated system;
6) CIE shall immediately shut in the well and notify the AOGCC if there is any change
in the well's mechanical condition; and
7) After well shut in due to a change in the well's mechanical condition, AOGCC
approval shall be required to restart disposal injection.
DONE at Anchorage, Alaska and dated September 6, 2024.
Jessie L. Chmielowski Gregory C. Wilson
Commissioner Commissioner
RECONSIDERATION AND APPEAL NOTICE
As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as
the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of
the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration
must set out the respect in which the order or decision is believed to be erroneous.
The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to
act on it within 10 days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision
and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days
after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying
reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on
which the application for reconsideration was filed.
If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision
on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal
MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the
order or decision on reconsideration.
In computing a period of time above, the date of the event or default after which the designated period begins to run is not included
in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs
until 5:00 p.m. on the next day that does not fall on a weekend or state holiday.
Jessie L.
Chmielowski
Digitally signed by
Jessie L. Chmielowski
Date: 2024.09.05
21:53:05 -08'00'
Gregory Wilson Digitally signed by Gregory Wilson
Date: 2024.09.06 09:31:05 -08'00'
From:Coldiron, Samantha J (OGC)
To:AOGCC_Public_Notices
Subject:[AOGCC_Public_Notices] Disposal Injection Order 43.004 (CIE)
Date:Friday, September 6, 2024 9:41:23 AM
Attachments:dio43.004.pdf
Docket Number: DIO-24-004
Request for Administrative Approval to Disposal Injection Order (DIO) 43; Water Injection
West McArthur River Unit (WMRU) 1A (PTD 195-118), West McArthur River Oil Pool
Samantha Coldiron
AOGCC Special Assistant
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue
Anchorage, AK 99501
(907) 793-1223
__________________________________
List Name: AOGCC_Public_Notices@list.state.ak.us
You subscribed as: samantha.coldiron@alaska.gov
Unsubscribe at:
https://list.state.ak.us/mailman/options/aogcc_public_notices/samantha.coldiron%40alaska.go
v
13
188 W. Northern Lights Blvd., Suite 510, Anchorage, Alaska 99503.
Main (907) 334-6745 | Fax (907) 334-6735
Aug 20, 2024
Alaska Oil and Gas Conservation Commission (AOGCC)
333 W 7th AVE
Anchorage, AK 99501
(907) 279-1433
Dear Commissioner,
Cook Inlet Energy, LLC, a Glacier Oil and Gas company (GLA) requests Administrative
Approval to convert the West McArthur River Unit 1A (WMRU-1A) well, API
50133204190100, to an injection well as per DIO 43, and to remain in service with a
known tubing by inner annulus (IA) communication. Utilizing definitive geologic
confining zones and the proposed operating and monitoring plan, the well will meet
the criteria of 20 AAC 25.412 for disposal injection. GLA intends to re-inject primarily
produced water from the West McArthur River Field into this well to ease the burden
of water handling operations and optimize oil production.
Should you have any questions or need additional information regarding this request,
please contact me at (907) 433-3811.
Sincerely,
Michael Fairbanks
Geologist and Exploration Manager
Glacier Oil and Gas
Enclosures:
Technical Summary
Exhibit A – Wellbore Schematic of WMRU-1A
Exhibit B – Correlation Section Depicting Arresting and Confining Zones
By Samantha Coldiron at 3:37 pm, Aug 20, 2024
Michael
Fairbanks
Digitally signed by Michael
Fairbanks
Date: 2024.08.20 14:45:42
-08'00'
Technical Summary in Conjunction with Request for Administrative Approval
Well History:
WMRU-1 was spudded in June 1991 and initially intended to encounter oil reserves
in the Hemlock sands and conglomerates. Initial production was by Jet Pump
completion and was unsteady with 69% water cut. It was believed that water was
channeling behind casing and a workover was designed to squeeze initial perforated
intervals, followed by subsequent uphole perforations. The wellbore was abandoned
in Nov 1995 after producing 355K BBLs Oil and redrilled as WMRU-1A. WMRU-1A
was TD’d in December 1995 to a position slightly updip of WMRU-1, and across a fault
that is believed to be non-sealing. Peak production reach 2500 BOPD and the well
Cum’d 1,488K bbls of oil before going offline on December 11, 2012 due to the
perforations watering out.
WMRU-1A was selected as a potential injector to handle produced water from the
WMRU field. WMRU-1A is currently unable to pass a standard annular mechanical
integrity test (MIT). The current wellbore schematic is included as Exhibit A. As a
producer, WMRU-1A was completed with a Weatherford Jet Pump design. To convert
the well into an injector, the jet pump was removed, a standing valve set at the bottom
of the jet pump cavity and a tubing/IA bundle test to 3,000 psi was successfully
conducted on 2/26/2023 to confirm good casing and packer integrity. An injectivity
test below 3,000 psi was conducted finding the well capable of extrapolated injection
rates up to 2,000 bwpd at 3,000 psi surface injection pressure (maximum injection
pressure during the injectivity test was 2,739 psi). After long delays in procuring a
blanking sleeve, one was installed to isolate the tubing from the IA. Multiple MIT test
attempts were conducted with two different blanking sleeves (first attempt in May
2024 and the second attempt in August 2024), both of which failed to pass MIT
pressure criteria. Since no changes in outer annulus pressure were observed during
failed MIT attempts, GLA suspects that failures are due to wear on the sealing surfaces
of the jet pump cavity (upper sealing surfaces) or the tubing pup joint above the jet
pump cavity and cannot establish tubing integrity in this well.
Geology of West McArthur River Field:
The West McArthur River Field is located near the southern extent of the current
proven oil production in the Cook Inlet. The field is situated on a south-plunging
normally faulted Plio-Pliestocene anticline. Oil is believed to be sourced from the
Jurassic section and is produced from the prolific Oligocene Hemlock formation while
gas is produced from sands within the Oligocene-Miocene Tyonek formation. The
Hemlock formation is nearly 600’ thick and consists primarily of fine to course, poorly
sorted volcaniclastic sandstones and pebble to cobble conglomerates of 12%
porosity. Most of the oil is produced from the Upper and Middle Hemlock formation.
Generally, the Lower Hemlock and West Forelands formation are considered to be
wet. The West McArthur River Field has been on production since August 1993 and
has produced nearly 15.8 MMBO and over 4 BCF of gas. Currently, the field is
producing 400 BBLS oil per day and 4,100 BBLS water per day.
There are currently only two injection wells in the field, WMRU-4D which is a class I
disposal well that is being used sporadically, and WMRU-08 which was recently
approved as an injector in August 9, 2023 as per DIO-23-002. Established water
injection from WMRU-4D occurs within the Upper Tyonek formation, which consists
of non-marine clean sands, volcaniclastic and shaly sands, siltstones, shales, and coals.
Of the various lithotypes, shales are the most regionally correlatable between wells
and because of the high clay content, become the best candidates for confinement of
permeability, providing flow isolation across the interval.
Geologic Confinement Zone Justification:
The Upper Tyonek contains many correlatable shale intervals that contain sufficient
thickness and regional extent to be serviceable as primary and secondary
confinement zones. One established zone which defines the injection interval for the
WMRU-4D well is found at 4,855’ MD to 4,935’ MD and is correlatable to the offset
log in the Pan Am West Foreland Unit 2 Well. This 80’ section is characterized as
siltsone and shale, bounded on the top and bottom by coals. Similarly, the WMRU 8
has at least 5 distinct, regionally correlatable shales, the bottom 4 serving as
‘arresting’ zones and the shallowest as a ‘confinement’ zone, preventing the upward
migration of fluids. The deepest of these arresting zones is encountered on the
WMRU-08 Gamma Ray (GR) log at 5,670-5,743 MD (4,387-4,431 TVD). This zone is
characterized by a 44’ thick, section of highly radioactive shale bounded by thin coal
seams. Up section from this lies another arresting shale interval of high radioactivity
encountered at 4,994-5,005 MD (3,986-4,022 TVD) on the WMRU-08 GR log. The
thickest arresting zone is determined to be 62’ thick, characterized by interbedded
siltstones and shales, bounded by two well defined coals, readily identified in offset
logs, and located at 4,670-4,776 MD (3,794-3,856 TVD) on the WMRU-08 GR log. The
shallowest ‘arresting’ zone is characterized by interbedded siltstones and shales
found on the WMRU-08 GR log at 4,032-4,080 MD (3,444-3,415 TVD). Up section from
the ‘arresting’ zones is a regionally extensive, 60 foot thick ‘confining’ radioactive
shale with few interbedded coals encountered at 3,554-3,653 MD (3,128-3,188 TVD).
This final zone isolates all underlying zones and fluids from overlying formations.
Exhibit B is a correlation section depicting the above mentioned shale confining and
arresting zones in the WMRU-1A well along with nearby offset wells.
Proposed Operating and Monitoring Plan:
In order to ensure compliance to criteria of 20 AAC 25.412 for disposal injection, GLA
commits to the following prescribed operating and monitoring plan for this well:
1) Well will be used as an injector as per DIO 43.
2) IA pressure not to exceed 3,000 psi.
3) OA pressure will be maintained as low as hydrostatic pressure allows, not to
exceed 300 psi.
4) Submit monthly reports of daily pressures (IA, OA, tubing), injection volumes,
and any pressure bleeds on any annuli.
5) Shut-in the well and notify the AOGCC should any problems or issues arise.
6) Run baseline P/T surveys before and one month after injection operations are
initiated and once every 2 years afterward.
Recommendation:
GLA affirms that it is in the best interest of the AOGCC and the State of Alaska to grant
Administrative Approval for GLA to proceed with injection in WMRU-1A well as per
DIO 43. Based on the geological and technical justifications provided in this request,
along with the monitoring plan presented, GLA will be able to safely and properly
inject produced water into the Hemlock formation. By mitigating water handling
operational burdens GLA can optimize oil production in the West McArthur River Unit
furthering the mission statement of the AOGCC to “enhance greater ultimate recovery,
and protection of health, safety, fresh ground waters, and the rights of all owners to
recover their share of the resource.” GLA hereby requests that the AOGCC approve
this request for Administrative Approval to convert WMRU-1A to an injection well
and remain in service with a known tubing by IA communication.
Exhibit A
12
Outer AnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Bleed Time (Hours: Min)Total Pressure Bled (bbl)Total Volume Bled (psi)Avg. Pressure (psi)6/1/20242384 178 2751 0 0 0 26/2/20242363 190 2728 0 0 0 26/3/20242368 183 2736 0 0 0 26/4/20242395 180 2750 0 0 0 26/5/20242410 180 2770 0 0 0 26/6/20242438 182 2790 0 0 0 26/7/20242453 184 2810 0 0 0 26/8/20242200 139 2400 0 0 0 26/9/20242323 177 2630 0 0 0 26/10/20242273 172 2670 0 0 0 26/11/20242222 159 2620 0 0 0 26/12/20242163 153 2560 0 0 0 26/13/20242172 138 2533 0 0 0 16/14/20242174 139 2545 0 0 0 16/15/20242177 137 2545 0 0 0 16/16/20242161 141 2540 0 0 0 26/17/20242139 135 2513 0 0 0 16/18/20242150 121 2396 0 0 0 16/19/20242124 114 2513 0 0 0 26/20/20242394 136 2637 0 0 0 26/21/20242413 146 2773 0 0 0 26/22/20242419 143 2782 0 0 0 26/23/20242440 142 2799 0 0 0 26/24/20242315 136 2721 0 0 0 26/25/20242278 141 2677 0 0 0 26/26/20242329 140 2663 0 0 0 26/27/20242355 141 2711 0 0 0 26/28/20242358 138 2714 0 0 0 16/29/2024141 39 976 0 0 0 06/30/2024111 0 435 0 0 0 0Well Name: WMRU‐08Inner Annulus
11
Inner Annulus Outer AnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Hours: Min)Total Pressure Bled (psi)Total Volume Bled (bbls) IA or OA?1/1/20262783 257 2816 40 0 0 01/2/20262804 267 2836 43 0 0 01/3/20262799 278 2831 45 0 0 01/4/20262800 275 2832 46 0 0 01/5/20262808 289 2839 49 0 0 01/6/20262818 294 2848 50 0 0 01/7/20262821 295 2852 47 0 0 01/8/20262821 295 2852 47 0 0 01/9/20262821 298 2852 51 0 0 01/10/20262829 294 2860 50 0 0 01/11/20262820 294 2850 49 0 0 01/12/20262209 136 2253 17 0 0 01/13/20262096 18 2139 14 0 0 01/14/20262051 17 2092 12 0 0 01/15/20262389 23 2430 13 0 0 01/16/20262640 60 2680 15 0 0 01/17/20262658 90 2696 16 0 0 01/18/20262756 143 2792 23 0 0 01/19/20262794 182 2829 28 0 0 01/20/20262788 199 2827 31 0 0 01/21/20262797 219 2839 35 0 0 01/22/20262804 223 2835 37 0 0 01/23/20262826 226 2842 40 0 0 01/24/20262823 251 2858 43 0 0 01/25/20262808 259 2851 47 0 0 01/26/20262812 263 2841 49 0 0 01/27/20262826 266 2839 49 0 0 01/28/20262807 284 2839 52 0 0 01/29/20262810 287 2844 54 0 0 01/30/20262804 286 2837 55 0 0 01/31/20262800 289 2834 56 0 0 0Well Name: WMRU‐1ABleeds (all annuli)
Inner Annulus Outer AnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Hours: Min)Total Pressure Bled (bbl)Total Volume Bled (psi)IA or OA?1/1/20262832 94 2733 3 0 0 01/2/20262815 93 2703 3 0 0 01/3/20262812 93 2696 4 0 0 01/4/20262813 92 2712 4 0 0 01/5/20262780 91 2784 4 0 0 01/6/20262914 98 2698 4 0 0 01/7/20262855 99 2674 4 0 0 01/8/20262816 95 2698 3 0 0 01/9/20262820 96 2740 4 0 0 01/10/20262821 95 2751 4 0 0 01/11/20262808 93 2683 4 0 0 01/12/20262099 69 2057 3 0 0 01/13/20261634 257 1940 3 0 0 01/14/20261495 245 2099 3 0 0 01/15/20262653 249 1753 3 0 0 01/16/20262808 194 1991 3 0 0 01/17/20262557 74 2541 3 0 0 01/18/20262808 82 2791 3 0 0 01/19/20262807 83 2789 3 0 0 01/20/20262877 88 2859 3 0 0 01/21/20262887 87 2886 3 0 0 01/22/20262916 87 2888 3 0 0 01/23/20262826 86 2890 3 0 0 01/24/20262919 86 2893 4 0 0 01/25/20262927 85 2907 4 0 0 01/26/20262929 85 2908 4 0 0 01/27/20262932 86 2911 4 0 0 01/28/20262905 84 2885 4 0 0 01/29/20262882 84 2865 4 0 0 01/30/20262865 81 2847 4 0 0 01/31/20262874 81 2853 4 0 0 0Well Name: WMRU‐08Bleeds (all annuli)
Inner Annulus Outer AnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Hours: Min)Total Pressure Bled (psi)Total Volume Bled (bbls) IA or OA?12/1/20252821 176 2855 33 0 0 012/2/20252826 176 2862 34 0 0 012/3/20252826 173 2867 34 0 0 012/4/20252816 174 2856 35 0 0 012/5/20252823 176 2862 34 0 0 012/6/20252836 173 2865 31 0 0 012/7/20252828 173 2861 30 0 0 012/8/20252840 175 2870 31 0 0 012/9/20252848 176 2879 31 0 0 012/10/20252839 180 2877 31 0 0 012/11/20252837 182 2870 32 0 0 012/12/20252832 184 2867 33 0 0 012/13/20252831 185 2866 32 0 0 012/14/20252832 182 2870 31 0 0 012/15/20252834 182 2867 31 0 0 012/16/20252847 182 2879 31 0 0 012/17/20252844 183 2877 31 0 0 012/18/20252824 183 2857 30 0 0 012/19/20252824 176 2858 31 0 0 012/20/20252829 181 2863 31 0 0 012/21/20252826 179 2861 30 0 0 012/22/20252823 183 2857 31 0 0 012/23/20252783 203 2818 33 0 0 012/24/20252784 219 2816 35 0 0 012/25/20252778 222 2813 36 0 0 012/26/20252802 238 2836 39 0 0 012/27/20252796 251 2825 39 0 0 012/28/20252791 247 2824 37 0 0 012/29/20252786 249 2820 38 0 0 012/30/20252794 252 2826 38 0 0 012/31/20252784 256 2816 38 0 0 0Well Name: WMRU‐1ABleeds (all annuli)
Inner Annulus Outer AnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Hours: Min) Total Pressure Bled (bbl)Total Volume Bled (psi) IA or OA?12/1/20252868 105 2852 4 0 0 012/2/20252887 106 2860 4 0 0 012/3/20252905 104 2879 3 0 0 012/4/20252881 104 2869 4 0 0 012/5/20252876 104 2854 4 0 0 012/6/20252812 97 2773 4 0 0 012/7/20252913 105 2900 4 0 0 012/8/20252889 105 2900 3 0 0 012/9/20252895 103 2872 3 0 0 012/10/20252897 102 2823 3 0 0 012/11/20252874 103 2834 3 0 0 012/12/20252884 102 2814 3 0 0 012/13/20252885 102 2763 3 0 0 012/14/20252890 102 2786 4 0 0 012/15/20252884 102 2781 4 0 0 012/16/20252873 102 2786 4 0 0 012/17/20252860 100 2789 3 0 0 012/18/20252828 100 2743 3 0 0 012/19/20252853 99 2764 3 0 0 012/20/20252916 101 2733 3 0 0 012/21/20252905 103 2733 3 0 0 012/22/20252890 101 2725 3 0 0 012/23/20252895 103 2741 3 0 0 012/24/20252901 102 2741 3 0 0 012/25/20252876 100 2746 3 0 0 012/26/20252857 99 2802 3 0 0 012/27/20252834 97 2757 4 0 0 012/28/20252861 95 2736 3 0 0 012/29/20252844 95 2778 3 0 0 012/30/20252847 96 2725 3 0 0 012/31/20252839 94 2725 3 0 0 0Well Name: WMRU‐08Bleeds (all annuli)
Inner Annulus Outer AnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Hours: Min)Total Pressure Bled (bbl)Total Volume Bled (psi) IA or OA?11/1/20252876 126 2860 4 0 0 011/2/20252882 126 2868 4 0 0 011/3/20252860 132 2844 4 0 0 011/4/20252829 127 2810 4 0 0 011/5/20252836 124 2821 4 0 0 011/6/20252840 122 2829 4 0 0 011/7/20252839 121 2824 3 0 0 011/8/20252842 119 2828 3 0 0 011/9/20252826 117 2810 4 0 0 011/10/20252831 116 2816 4 0 0 011/11/20252826 115 2813 3 0 0 011/12/20252799 113 2784 4 0 0 011/13/20252873 115 2852 4 0 0 011/14/20252871 117 2857 4 0 0 011/15/20252885 116 2873 4 0 0 011/16/20252882 116 2868 4 0 0 011/17/20252882 116 2868 4 0 0 011/18/20252871 115 2855 4 0 0 011/19/20252869 116 2850 4 0 0 011/20/20252865 120 2848 4 0 0 011/21/20252881 117 2863 4 0 0 011/22/20252836 113 2820 4 0 0 011/23/20252853 112 2839 3 0 0 011/24/20252845 109 2829 3 0 0 011/25/20252857 108 2839 3 0 0 011/26/20252873 108 2857 3 0 0 011/27/20252874 108 2857 3 0 0 011/28/20252863 107 2847 3 0 0 011/29/20252869 107 2855 3 0 0 011/30/20252871 106 2855 4 0 0 0Well Name: WMRU‐08Bleeds (all annuli)
Inner Annulus Outer AnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Hours: Min)Total Pressure Bled (psi)Total Volume Bled (bbls) IA or OA?11/1/20252813 115 2848 23 0 0 011/2/20252791 117 2826 23 0 0 011/3/20252797 94 2834 21 0 0 011/4/20252810 103 2845 22 0 0 011/5/20252842 126 2876 24 0 0 011/6/20252818 132 2852 25 0 0 011/7/20252820 135 2853 25 0 0 011/8/20252815 139 2848 26 0 0 011/9/20252824 144 2858 27 0 0 011/10/20252823 154 2857 28 0 0 011/11/20252815 154 2848 28 0 0 011/12/20252807 156 2840 29 0 0 011/13/20252813 157 2847 29 0 0 011/14/20252813 158 2847 30 0 0 011/15/20252797 161 2831 30 0 0 011/16/20252788 165 2821 30 0 0 011/17/20252808 180 2840 32 0 0 011/18/20252808 182 2840 33 0 0 011/19/20252780 126 2815 26 0 0 011/20/20252757 118 2794 27 0 0 011/21/20252794 146 2831 28 0 0 011/22/20252807 144 2847 29 0 0 011/23/20252812 162 2845 30 0 0 011/24/20252804 164 2839 30 0 0 011/25/20252802 166 2836 30 0 0 011/26/20252804 171 2839 31 0 0 011/27/20252810 167 2845 31 0 0 011/28/20252799 166 2832 31 0 0 011/29/20252808 163 2842 31 0 0 011/30/20252802 161 2839 31 0 0 0Well Name: WMRU‐1ABleeds (all annuli)
Glacier Oil & Gas Corporation | 188 W. Northern Lights Blvd. Ste. 510
Anchorage, AK 99503
November 5, 2025
Ms. Jessie Chmielowski
Commissioner
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501-3572
Subject: DIO 43.003 Monthly Reporting
Commissioner Chmielowski,
As required by Disposal Injection Order No. 43 issued by the AOGCC on August 9, 2023, the
monthly report detailing well pressures, injection rates, and pressure bleeds for all annuli for the
well WMRU-8 during October 2025 is provided to the Commission for review. WMRU-8
injected 31 days this month. No bleeds were conducted this month.
Please contact production and wells engineer Stan Porhola at sporhola@glacieroil.com or
(907) 433-3820 if you have any questions.
Sincerely,
David Pascal
Chief Operating Officer
Glacier Oil & Gas
Attachments: WMRU-8 Injection Log
Inner Annulus Outer AnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Hours: Min)Total Pressure Bled (bbl)Total Volume Bled (psi) IA or OA?10/1/20252879 126 2863 4 0 0 010/2/20252893 126 2881 3 0 0 010/3/20252890 127 2873 3 0 0 010/4/20252890 129 2877 3 0 0 010/5/20252840 125 2824 3 0 0 010/6/20252840 127 2826 3 0 0 010/7/20252876 130 2853 3 0 0 010/8/20252796 130 2872 3 0 0 010/9/20252857 127 2829 3 0 0 010/10/20252844 128 2841 3 0 0 010/11/20252845 128 2850 3 0 0 010/12/20252816 123 2799 3 0 0 010/13/20252890 91 1829 3 0 0 010/14/20252858 137 2836 3 0 0 010/15/20252812 130 2822 4 0 0 010/16/20252874 126 2816 4 0 0 010/17/20252869 129 2852 4 0 0 010/18/20252815 127 2828 4 0 0 010/19/20252871 126 2846 4 0 0 010/20/20252836 130 2831 4 0 0 010/21/20252892 137 2874 4 0 0 010/22/20252802 133 2786 4 0 0 010/23/20252823 131 2808 4 0 0 010/24/20252830 129 2816 4 0 0 010/25/20252869 129 2855 4 0 0 010/26/20252850 129 2834 4 0 0 010/27/20252818 127 2805 3 0 0 010/28/20252905 128 2892 4 0 0 010/29/20252887 128 2871 4 0 0 010/30/20252876 128 2860 4 0 0 010/31/20252869 126 2857 4 0 0 0Well Name: WMRU‐08Bleeds (all annuli)
Glacier Oil & Gas Corporation | 188 W. Northern Lights Blvd. Ste. 510
Anchorage, AK 99503
November 5, 2025
Ms. Jessie Chmielowski
Commissioner
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501-3572
Subject: DIO 43.004 Monthly Reporting
Commissioner Chmielowski,
As required by Disposal Injection Order No. 43 issued by the AOGCC on September 6, 2024, the
monthly report detailing well pressures, injection rates, and pressure bleeds for all annuli for the
well WMRU-1A during October 2025 is provided to the Commission for review. WMRU-1A
injected 31 days this month. No bleeds were conducted this month.
Please contact production and wells engineer Stan Porhola at sporhola@glacieroil.com or
(907) 433-3820 if you have any questions.
Sincerely,
David Pascal
Chief Operating Officer
Glacier Oil & Gas
Attachments: WMRU-1A Injection Log
Inner Annulus Outer AnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Hours: Min)Total Pressure Bled (psi)Total Volume Bled (bbls) IA or OA?10/1/20252837 144 2869 29 0 0 010/2/20252824 144 2857 29 0 0 010/3/20252813 142 2845 29 0 0 010/4/20252810 142 2842 29 0 0 010/5/20252839 153 2871 29 0 0 010/6/20252839 151 2873 30 0 0 010/7/20252828 127 2878 28 0 0 010/8/20252884 121 2852 25 0 0 010/9/20252824 130 2861 27 0 0 010/10/20252807 129 2854 27 0 0 010/11/20252807 127 2850 27 0 0 010/12/20252775 117 2813 25 0 0 010/13/20252834 72 1728 19 0 0 010/14/20252810 139 2830 24 0 0 010/15/20252810 171 2829 27 0 0 010/16/20252839 193 2852 32 0 0 010/17/20252807 197 2846 34 0 0 010/18/20252780 180 2799 34 0 0 010/19/20252770 185 2809 34 0 0 010/20/20252829 118 2850 26 0 0 010/21/20252829 50 2866 21 0 0 010/22/20252792 57 2831 20 0 0 010/23/20252840 65 2877 20 0 0 010/24/20252831 69 2869 20 0 0 010/25/20252802 71 2840 19 0 0 010/26/20252796 68 2834 19 0 0 010/27/20252786 67 2824 18 0 0 010/28/20252818 78 2853 19 0 0 010/29/20252800 81 2837 19 0 0 010/30/20252828 92 2865 21 0 0 010/31/20252855 104 2890 22 0 0 0Well Name: WMRU‐1ABleeds (all annuli)
Inner Annulus Outer AnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Hours: Min)Total Pressure Bled (psi)Total Volume Bled (bbls) IA or OA?9/1/20252754 141 2786 29 0 0 09/2/20252754 137 2786 28 0 0 09/3/20252823 164 2853 33 0 0 09/4/20252836 201 2865 37 0 0 09/5/20252831 210 2861 39 0 0 09/6/20252840 204 2869 41 0 0 09/7/20252852 146 2885 32 0 0 09/8/20252784 84 2821 24 0 0 09/9/20252815 51 2852 21 0 0 09/10/20252829 56 2866 20 0 0 09/11/20252845 74 2881 21 0 0 09/12/20252831 81 2866 21 0 0 09/13/20252855 91 2889 22 0 0 09/14/20252845 99 2879 23 0 0 09/15/20252834 104 2868 24 0 0 09/16/20252826 109 2858 24 0 0 09/17/20252829 113 2863 25 0 0 09/18/20252842 120 2874 27 0 0 09/19/20252836 129 2869 27 0 0 09/20/20252837 131 2869 28 0 0 09/21/20252816 141 2848 29 0 0 09/22/20252821 151 2853 30 0 0 09/23/20252832 155 2863 31 0 0 09/24/20252807 160 2839 30 0 0 09/25/20252804 152 2837 32 0 0 09/26/20252829 164 2861 33 0 0 09/27/20252857 129 2890 25 0 0 09/28/20252837 124 2869 28 0 0 09/29/20252816 132 2848 29 0 0 09/30/20252836 135 2869 29 0 0 0Well Name: WMRU‐1ABleeds (all annuli)
Inner Annulus Outer AnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Hours: Min)Total Pressure Bled (bbl)Total Volume Bled (psi) IA or OA?9/1/20252816 102 2804 3 0 0 09/2/20252813 102 2800 3 0 0 09/3/20252879 106 2866 3 0 0 09/4/20252869 107 2858 3 0 0 09/5/20252874 107 2858 3 0 0 09/6/20252887 109 2876 3 0 0 09/7/20252858 105 2844 3 0 0 09/8/20252807 108 2794 3 0 0 09/9/20252903 107 2890 4 0 0 09/10/20252889 107 2874 4 0 0 09/11/20252746 110 2735 4 0 0 09/12/20252853 105 2840 3 0 0 09/13/20252889 106 2873 3 0 0 09/14/20252873 105 2858 4 0 0 09/15/20252876 105 2863 4 0 0 09/16/20252860 105 2847 3 0 0 09/17/20252860 102 2844 3 0 0 09/18/20252858 101 2845 4 0 0 09/19/20252866 102 2852 4 0 0 09/20/20252863 102 2848 4 0 0 09/21/20252863 102 2847 4 0 0 09/22/20252876 104 2861 4 0 0 09/23/20252868 106 2855 4 0 0 09/24/20252868 107 2853 4 0 0 09/25/20252866 108 2852 4 0 0 09/26/20252861 107 2847 4 0 0 09/27/20252905 90 2889 3 0 0 09/28/20252890 124 2874 4 0 0 09/29/20252842 124 2828 4 0 0 09/30/20252866 125 2850 4 0 0 0Well Name: WMRU‐08Bleeds (all annuli)
Inner AnnulusOuter AnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Hours: Min)Total Pressure Bled (bbl)Total Volume Bled (psi) IA or OA?8/1/2025143 0 11 0 0 0 08/2/2025139 0 10 0 0 0 08/3/20252563 128 2100 2 0 0 08/4/20252869 131 2650 2 0 0 08/5/20252832 126 2823 3 0 0 08/6/20252901 115 2890 3 0 0 08/7/20252855 109 2845 3 0 0 08/8/20252818 96 2400 3 0 0 08/9/20252865 110 2850 3 0 0 08/10/20252901 104 2887 3 0 0 08/11/20252848 108 2839 3 0 0 08/12/20252837 100 2823 3 0 0 08/13/20252839 98 2829 3 0 0 08/14/20252876 93 2863 3 0 0 08/15/20252873 101 2860 3 0 0 08/16/20252890 100 2879 3 0 0 08/17/20252901 101 2889 3 0 0 08/18/20252900 102 2890 3 0 0 08/19/20252909 103 2895 3 0 0 08/20/20252884 103 2869 3 0 0 08/21/20252900 103 2887 3 0 0 08/22/20252889 104 2877 3 0 0 08/23/20252873 103 2867 3 0 0 08/24/20252857 102 2844 3 0 0 08/25/20252889 102 2874 3 0 0 08/26/20252857 103 2844 3 0 0 08/27/20252842 102 2829 3 0 0 08/28/20252804 99 2791 3 0 0 08/29/20252821 99 2808 3 0 0 08/30/20252815 102 2802 3 0 0 08/31/20252810 101 2797 3 0 0 0Well Name: WMRU‐08Bleeds (all annuli)
Inner AnnulusOuter AnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Hours: Min)Total Pressure Bled (psi)Total Volume Bled (bbls) IA or OA?8/1/20250014 0 0 0 08/2/20250014 0 0 0 08/3/20252581 126 2300 4 0 0 08/4/20252800 347 2640 17 0 0 08/5/20252768 403 2791 27 0 0 08/6/20252794 391 2816 37 0 0 08/7/20252816 407 2837 44 0 0 08/8/20252831 299 2100 33 0 0 08/9/20252826 251 2855 35 0 0 08/10/20252808 225 2837 29 0 0 08/11/20252804 258 2834 35 0 0 08/12/20252802 257 2831 38 0 0 08/13/20252807 252 2837 41 0 0 08/14/20253842 207 2873 34 0 0 08/15/20252805 188 2836 35 0 0 08/16/20252847 190 2876 37 0 0 08/17/20252824 197 2855 37 0 0 08/18/20252869 212 2900 40 0 0 08/19/20252866 216 2897 41 0 0 08/20/20252837 200 2868 40 0 0 08/21/20252837 192 2869 38 0 0 08/22/20252842 193 2874 40 0 0 08/23/20252845 193 2875 40 0 0 08/24/20252850 187 2882 38 0 0 08/25/20252861 183 2895 35 0 0 08/26/20252858 179 2889 36 0 0 08/27/20252844 182 2874 36 0 0 08/28/20252751 178 2786 30 0 0 08/29/20252760 125 2794 28 0 0 08/30/20252759 145 2794 29 0 0 08/31/20252749 140 2783 29 0 0 0Well Name: WMRU‐1ABleeds (all annuli)
Inner AnnuluOuter AnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Hours: Min)Total Pressure Bled (psi)Total Volume Bled (bbls) IA or OA?7/1/20252807 212 2832 42 0 0 07/2/20252813 206 2840 42 0 0 07/3/20252823 205 2850 43 0 0 07/4/20252829 179 2857 33 0 0 07/5/20252794 231 2821 40 0 0 07/6/20252805 237 2832 45 0 0 07/7/20252775 236 2804 45 0 0 07/8/20252789 221 2818 45 0 0 07/9/20252802 225 2831 44 0 0 07/10/20252808 221 2836 45 0 0 07/11/20252820 218 2847 46 0 0 07/12/20252820 216 2848 44 0 0 07/13/20252836 217 2863 45 0 0 07/14/20252848 215 2877 43 0 0 07/15/20252869 212 2897 43 0 0 07/16/20252876 210 2905 44 0 0 07/17/20252881 211 2895 44 0 0 07/18/20252879 209 2908 45 0 0 07/19/202507324 5 0 0 07/20/20252579 151 2610 14 0 0 07/21/20252733 248 2717 26 0 0 07/22/20251097 244 1097 12 0 0 07/23/20250014 3 0 0 07/24/20250016 2 0 0 07/25/20250016 1 0 0 07/26/20250016 1 0 0 07/27/20250016 0 0 0 07/28/20250016 0 0 0 07/29/2025000 0 0 0 07/30/20250013 0 0 0 07/31/20250014 0 000Well Name: WMRU‐1ABleeds (all annuli)
Inner AnnuluAnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Min)Total Pressure Bled (PSI)Total Volume Bled (BBL) IA or OA?7/1/20252813 114 2797 3 0 0 07/2/20252804 112 2786 3 0 0 07/3/20252802 112 2788 3 0 0 07/4/20252901 161 2885 3 0 0 07/5/20252898 140 2882 3 0 0 07/6/20252905 139 2890 3 0 0 07/7/20252845 138 2831 3 0 0 07/8/20252855 138 2840 3 0 0 07/9/20252874 139 2858 3 0 0 07/10/20252861 140 2847 3 0 0 07/11/20252868 142 2850 3 0 0 07/12/20252869 143 2855 3 0 0 07/13/20252882 142 2866 3 0 0 07/14/20252879 143 2863 3 0 0 07/15/20252877 142 2863 3 0 0 07/16/20252890 142 2874 3 0 0 07/17/20252901 142 2873 3 0 0 07/18/20252895 147 2879 3 0 0 07/19/2025240 56 253 1 0 0 07/20/20252437 22 2422 2 0 0 07/21/20252733 85 2717 3 0 0 07/22/2025779 81 820 3 0 0 07/23/2025141 0 127 1 0 0 07/24/2025147 0 66 0 0 0 07/25/2025144 0 45 0 0 0 07/26/2025149 0 32 0 0 0 07/27/2025155 0 24 0 0 0 07/28/2025147 0 21 0 0 0 07/29/2025147 0 18 0 0 0 07/30/2025143 0 17 0 0 0 07/31/2025147 0 14 0 000Well Name: WMRU‐08Bleeds (all annuli)
Inner Annulus Outer AnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Hours: Min)Total Pressure Bled (psi)Total Volume Bled (bbls)IA or OA?6/1/20252831 219 2855 36 0 0 06/2/20252814 221 2842 35 0 0 06/3/20252837 220 2861 34 0 0 06/4/20252852 228 2876 33 0 0 06/5/20252848 235 2871 37 0 0 06/6/20252858 233 2882 38 0 0 06/7/20252857 227 2881 35 0 0 06/8/20252829 221 2855 36 0 0 06/9/20252808 194 2834 33 0 0 06/10/20252832 192 2858 34 0 0 06/11/20252837 202 2863 35 0 0 06/12/20252861 209 2885 37 0 0 06/13/20252860 208 2885 37 0 0 06/14/20252871 204 2897 37 0 0 06/15/20252831 197 2858 34 0 0 06/16/20252839 176 2865 33 0 0 06/17/20252850 178 2871 32 0 0 06/18/20252850 180 2876 33 0 0 06/19/20252839 184 2872 34 0 0 06/20/20252845 182 2871 33 0 0 06/21/20252852 180 2874 34 0 0 06/22/20252855 179 2878 34 0 0 06/23/20252860 177 2883 34 0 0 06/24/20252857 176 2882 34 0 0 06/25/20252845 172 2873 32 0 0 06/26/20252789 194 2839 35 0 0 06/27/20252764 208 2817 38 0 0 06/28/20252783 221 2813 41 0 0 06/29/20252794 223 2815 42 0 0 06/30/20252772 219 2803 41 0 0 0Well Name: WMRU‐1ABleeds (all annuli)
Inner Annulus Outer AnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Min)Total Pressure Bled (PSI)Total Volume Bled (BBL) IA or OA?6/1/20252576 113 2733 2 300 2571 33 IA6/2/20252557 111 2691 2 270 846 30 IA6/3/20252658 107 2792 2 0 0 06/4/20252698 110 2834 2 0 0 06/5/20252688 113 2818 2 30 404 6 IA6/6/20252722 114 2850 2 0 0 06/7/20252703 118 2820 2 40 640 15.9 IA6/8/20252658 110 2773 2 0 0 06/9/20252610 103 2728 2 0 0 06/10/20252631 101 2744 2 0 0 06/11/20252738 104 2853 2 0 0 06/12/20252759 107 2876 2 0 0 06/13/20252744 109 2853 2 0 429 8.02 IA6/14/2025205 90 1500 2 298.8 1840 40.98 IA6/15/20252361 31 500 1 0 0 06/16/20252751 131 2824 2 0 0 06/17/20252765 131 2833 2 0 0 06/18/20252784 130 2841 2 75 590 10 IA6/19/20252778 135 2833 2 135 1150 20 IA6/20/20252767 139 2813 3 220 1200 31 IA6/21/20252767 130 2788 2 90 380 11 IA6/22/20252784 131 2784 3 85 400 11 IA6/23/20252781 129 2779 3 0 0 06/24/20252828 139 2793 3 50 1915 16 IA6/25/20252805 144 2791 3 0 0 06/26/20252773 106 2773 3 0 0 06/27/20252794 109 2775 3 0 0 06/28/20252826 108 2791 3 0 0 06/29/20252829 109 2803 3 0 0 06/30/20252775 110 2773 3 0 0 0Well Name: WMRU‐08Bleeds (all annuli)
Inner AnnuluAnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Hours: Min)Total Pressure Bled (psi)Total Volume Bled (bbls) IA or OA?5/1/20252881 163 2901 36 0 0 05/2/20252882 164 2902 36 0 0 05/3/20252887 164 2905 36 0 0 05/4/20252890 165 2907 35 0 0 05/5/20252893 162 2911 36 0 0 05/6/20252897 161 2917 37 0 0 05/7/20252893 159 2916 35 0 0 05/8/20252832 149 2855 27 0 0 05/9/20252743 98 2768 24 0 0 05/10/20252832 122 2857 27 0 0 05/11/20252813 134 2837 27 0 0 05/12/20252821 121 2848 27 0 0 05/13/20252815 121 2842 27 0 0 05/14/20252824 117 2850 26 0 0 05/15/20252824 115 2850 26 0 0 05/16/20252832 116 2856 26 0 0 05/17/20252837 113 2861 26 0 0 05/18/20252857 124 2882 27 0 0 05/19/202504024 3 0 0 05/20/20252823 78 2847 15 0 0 05/21/20252802 202 2824 22 0 0 05/22/20252821 214 2844 27 0 0 05/23/20252810 224 2832 31 0 0 05/24/20252812 221 2834 33 0 0 05/25/20252781 221 2807 33 0 0 05/26/20252800 217 2826 35 0 0 05/27/20252804 221 2828 36 0 0 05/28/20252812 223 2836 37 0 0 05/29/20252820 226 2844 36 0 0 05/30/20252824 226 2848 36 0 0 05/31/20252820 222 2844 35 0 0 0Well Name: WMRU‐1ABleeds (all annuli)
Inner AnnulusOuter AnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Min)Total Pressure Bled (PSI)Total Volume Bled (BBL)IA or OA?5/1/202500 2 0 0 0 05/2/202500 3 0 0 0 05/3/202500 3 0 0 0 05/4/202500 3 0 0 0 05/5/202500 2 0 0 0 05/6/202500 2 0 0 0 05/7/202500 2 0 0 0 05/8/202500 2 0 0 0 05/9/202500 2 0 0 0 05/10/20250 40 150 0 0 0 05/11/20252509 125 2860 0 0 0 05/12/20252502 282 2853 1 30 628 3 IA5/13/20252515 280 2868 2 0 0 05/14/20252488 274 2840 2 0 0 05/15/20252478 268 2826 2 35 470 5 IA5/16/20252483 245 2832 2 0 0 05/17/20252491 238 2839 2 0 0 05/18/20252526 124 2876 2 0 0 05/19/20250 36 127 0 0 0 05/20/20252217 43 2393 1 0 0 05/21/20252573 129 2911 2 120 370 11 IA5/22/20252520 127 2844 2 325 886 36 IA5/23/20252468 123 2765 2 460 1640 43 IA5/24/20252483 118 2756 2 380 1520 47 IA5/25/20252485 116 2736 2 265 1063 32 IA5/26/20252494 117 2725 2 485 1468 41 IA5/27/20252539 119 2741 2 415 1422 55 IA5/28/20252571 106 2768 2 0 0 05/29/20252579 104 2775 2 0 0 05/30/20252581 103 2781 2 0 0 05/31/20252557 109 2741 2 220 1521 18Well Name: WMRU‐08Bleeds (all annuli)
Inner Annulus Outer AnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Hours: Min)Total Pressure Bled (psi)Total Volume Bled (bbls) IA or OA?4/1/20252865 229 2881 50 0 0 04/2/20252867 230 2879 50 0 0 04/3/20252712 199 2733 41 0 0 04/4/20252746 191 2765 40 0 0 04/5/20252804 235 2820 44 0 0 04/6/20252813 245 2829 46 0 0 04/7/20252797 251 2813 47 0 0 04/8/20252783 244 2800 46 0 0 04/9/20252767 241 2784 44 0 0 04/10/20252776 240 2794 44 0 0 04/11/20252792 240 2810 39 0 0 04/12/20252791 235 2808 41 0 0 04/13/20252791 236 2810 42 0 0 04/14/20252776 227 2794 42 0 0 04/15/20252764 220 2781 42 0 0 04/16/20252869 215 2890 36 0 0 04/17/20252734 179 2853 36 0 0 04/18/20252850 174 2869 37 0 0 04/19/20252823 169 2844 35 0 0 04/20/20252844 163 2865 36 0 0 04/21/20252848 167 2869 36 0 0 04/22/20252845 162 2867 36 0 0 04/23/20252848 167 2869 37 0 0 04/24/20252850 167 2870 36 0 0 04/25/20252860 166 2875 37 0 0 04/26/20252868 169 2881 37 0 0 04/27/20252868 167 2884 36 0 0 04/28/20252869 164 2887 35 0 0 04/29/20252871 163 2890 35 0 0 04/30/20252881 164 2896 34 0 0 0Well Name: WMRU‐1ABleeds (all annuli)
Inner Annulus Outer AnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Hours: Min)Total Pressure Bled (bbl)Total Volume Bled (psi)IA or OA?4/1/20252414 40 2765 2 0 0 04/2/20252429 39 2778 2 0 0 04/3/20252405 39 2756 2 0 0 04/4/20252509 43 2860 2 0 0 04/5/20252565 39 2913 2 0 0 04/6/20252533 33 2882 2 0 0 04/7/20252536 31 2887 2 0 0 04/8/20252547 30 2895 2 0 0 04/9/20252533 29 2882 2 0 0 04/10/20252549 28 2897 2 0 0 04/11/20252560 28 2908 1 0 0 04/12/20252539 27 2889 2 0 0 04/13/20252517 26 2863 2 0 0 04/14/20252570 12 2858 2 0 0 04/15/20252486 5 2834 2 0 0 04/16/20250 0 311 0 0 0 04/17/20250 0 223 0 0 0 04/18/20250 0 175 0 0 0 04/19/20250 0 169 0 0 0 04/20/20250 0 138 0 0 0 04/21/20250 0 104 0 0 0 04/22/202500 77 0 0 0 04/23/202500 69 0 0 0 04/24/202500 56 0 0 0 04/25/202500 38 0 0 0 04/26/202500 27 0 0 0 04/27/202500 23 0 0 0 04/28/202500 13 0 0 0 04/29/202500 9 0 0 0 04/30/202500 5 0 0 0 0Well Name: WMRU‐08Bleeds (all annuli)
Inner AnnulusOuter AnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Hours: Min)Total Pressure Bled (psi)Total Volume Bled (bbls)IA or OA?3/1/20252826 251 2841 41 0 0 03/2/20252826 256 2840 42 0 0 03/3/20252829 255 2842 41 0 0 03/4/20252807 246 2834 42 0 0 03/5/20252826 261 2837 42 0 0 03/6/20252820 257 2836 43 0 0 03/7/20252837 254 2846 43 0 0 03/8/20252840 252 2850 44 0 0 03/9/20252840 242 2851 44 0 0 03/10/20252842 256 2857 45 0 0 03/11/20252844 254 2858 45 0 0 03/12/20252824 261 2837 46 0 0 03/13/20252826 264 2840 46 0 0 03/14/20252839 262 2848 46 0 0 03/15/20252844 264 2860 47 0 0 03/16/20252840 262 2853 46 0 0 03/17/20252861 272 2876 47 0 0 03/18/20252884 255 2898 45 0 0 03/19/20252879 244 2893 46 0 0 03/20/20252879 240 2893 46 0 0 03/21/20252869 241 2884 47 0 0 03/22/20252869 243 2884 47 0 0 03/23/20252874 249 2889 50 0 0 03/24/20252871 259 2885 49 0 0 03/25/20252861 259 2872 50 0 0 03/26/20252868 264 2882 54 0 0 03/27/20252874 270 2889 55 0 0 03/28/20252892 277 2905 56 0 0 03/29/20252892 270 2909 56 0 0 03/30/20252890 245 2905 52 0 0 03/31/20252871 234 2882 51 0 0 0Well Name: WMRU‐1ABleeds (all annuli)
Inner AnnuluAnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Hours: Min)Total Pressure Bled (bbl)Total Volume Bled (psi)IA or OA?3/1/20252502 55 2847 2 0 0 03/2/20252515 55 2862 2 0 0 03/3/20252531 54 2871 2 0 0 03/4/20252522 53 2873 2 0 0 03/5/20252522 53 2874 2 0 0 03/6/20252531 52 2879 2 0 0 03/7/20252530 52 2882 2 0 0 03/8/20252547 52 2896 2 0 0 03/9/20252539 50 2894 2 0 0 03/10/20252528 51 2883 2 0 0 03/11/20252544 50 2898 2 0 0 03/12/20252546 50 2898 2 0 0 03/13/20252543 50 2893 2 0 0 03/14/20252522 49 2876 2 0 0 03/15/20252525 48 2874 2 0 0 03/16/20252525 48 2879 2 0 0 03/17/20252466 48 2816 2 0 0 03/18/20252517 47 2866 2 0 0 03/19/20252491 47 2842 2 0 0 03/20/20252507 46 2858 2 0 0 03/21/20252491 46 2844 2 0 0 03/22/20252488 45 2840 2 0 0 03/23/20252522 46 2871 2 0 0 03/24/20252504 48 2853 2 0 0 03/25/20252531 48 2884 2 0 0 03/26/20252525 47 2876 2 0 0 03/27/20252526 47 2877 2 0 0 03/28/20252478 45 2828 2 0 0 03/29/20252482 44 2829 2 0 0 03/30/20252469 43 2820 2 0 0 03/31/20252418 42 2770 2 0 0 0Well Name: WMRU‐08Bleeds (all annuli)
Inner AnnuluAnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Hours: Min)Total Pressure Bled (psi)Total Volume Bled (bbls) IA or OA?2/1/20252834 224 2850 28 0 0 02/2/20252839 226 2855 29 0 0 02/3/20252877 218 2893 30 0 0 02/4/20252869 214 2885 30 0 0 02/5/20252865 218 2881 31 0 0 02/6/20252873 219 2889 32 0 0 02/7/20252858 212 2874 31 0 0 02/8/20252866 215 2881 32 0 0 02/9/20252874 222 2890 32 0 0 02/10/20252885 231 2900 34 0 0 02/11/20252861 228 2877 34 0 0 02/12/20252868 208 2882 33 0 0 02/13/20252852 209 2868 33 0 0 02/14/20252869 210 2885 34 0 0 02/15/20252848 217 2863 34 0 0 02/16/20252844 207 2860 35 0 0 02/17/20252858 211 2873 35 0 0 02/18/20252869 223 2884 36 0 0 02/19/20252869 212 2885 34 0 0 02/20/20252865 214 2879 36 0 0 02/21/20252850 224 2865 36 0 0 02/22/20252877 229 2892 39 0 0 02/23/20252892 238 2905 41 0 0 02/24/20252876 245 2890 42 0 0 02/25/20252858 258 2881 42 0 0 02/26/20252832 259 2866 41 0 0 02/27/20252824 248 2839 41 0 0 02/28/20252824 247 2840 41 0 0 0Well Name: WMRU‐1ABleeds (all annuli)
DATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Hours: Min)Total Pressure Bled (bbl)Total Volume Bled (psi)IA or OA?2/1/20252502 70 2855 1 0 0 02/2/20252510 70 2863 1 0 0 02/3/20252517 69 2871 1 0 0 02/4/20252526 69 2881 2 0 0 02/5/20252469 67 2823 1 0 0 02/6/20252512 64 2861 2 0 0 02/7/20252506 64 2852 1 0 0 02/8/20252438 61 2786 1 0 0 02/9/20252469 58 2816 1 0 0 02/10/20252486 60 2834 1 0 0 02/11/20252482 58 2828 2 0 0 02/12/20252531 59 2881 2 0 0 02/13/20252523 55 2873 2 0 0 02/14/20252523 56 2871 2 0 0 02/15/20252485 54 2836 2 0 0 02/16/20252512 53 2860 2 0 0 02/17/20252525 55 2874 2 0 0 02/18/20252504 55 2853 2 0 0 02/19/20252482 52 2829 2 0 0 02/20/20252538 52 2885 2 0 0 02/21/20252456 53 2805 2 0 0 02/22/20252486 51 2839 2 0 0 02/23/20252501 51 2855 2 0 0 02/24/20252148 59 2772 2 0 0 02/25/20252483 68 2803 2 0 0 02/26/20252501 63 2839 2 0 0 02/27/20252491 60 2847 2 0 0 02/28/20252474 57 2834 2 0 0 0
Glacier Oil & Gas Corporation | 188 W. Northern Lights Blvd. Ste. 510
Anchorage, AK 99503
February 4, 2025
Ms. Jessie Chmielowski
Commissioner
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501-3572
Subject: DIO 43.004 Monthly Reporting
Commissioner Chmielowski,
As required by Disposal Injection Order No. 43 issued by the AOGCC on September 6, 2024, the
monthly report detailing well pressures, injection rates, and pressure bleeds for all annuli for the
well WMRU-1A during January 2025 is provided to the Commission for review. WMRU-1A
injected 29 days this month. No bleeds were conducted this month.
Please contact production and wells engineer Stan Porhola at sporhola@glacieroil.com or
(907) 433-3820 if you have any questions.
Sincerely,
David Pascal
Chief Operating Officer
Glacier Oil & Gas
Attachments: WMRU-1A Injection Log
Inner Annulus Outer AnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Hours: Min)Total Pressure Bled (psi)Total Volume Bled (bbls) IA or OA?1/1/20252754 294 2768 23 0 0 0 N/A1/2/20252708 284 2724 23 0 0 0 N/A1/3/20252741 278 2756 24 0 0 0 N/A1/4/20252749 272 2764 24 0 0 0 N/A1/5/20252749 268 2764 24 0 0 0 N/A1/6/20252757 266 2772 24 0 0 0 N/A1/7/20252770 264 2784 24 0 0 0 N/A1/8/20252772 263 2784 25 0 0 0 N/A1/9/20252768 264 2783 25 0 0 0 N/A1/10/20252775 267 2789 25 0 0 0 N/A1/11/20250 77 18 0 0 0 0 N/A1/12/20250 0 13 0 0 0 0 N/A1/13/20250 0 13 0 0 0 0 N/A1/14/20250 42 55 0 0 0 0 N/A1/15/20252667 80 2685 0 0 0 0 N/A1/16/20252796 242 2810 14 0 0 0 N/A1/17/20252828 256 2840 18 0 0 0 N/A1/18/20252823 263 2837 21 0 0 0 N/A1/19/20252823 265 2836 23 0 0 0 N/A1/20/20252844 263 2858 26 0 0 0 N/A1/21/20252848 257 2863 28 0 0 0 N/A1/22/20252839 256 2855 29 0 0 0 N/A1/23/20252855 252 2869 28 0 0 0 N/A1/24/20252852 245 2866 27 0 0 0 N/A1/25/20252855 240 2871 26 0 0 0 N/A1/26/20252881 239 2897 24 0 0 0 N/A1/27/20252879 235 2895 24 0 0 0 N/A1/28/20252876 231 2890 26 0 0 0 N/A1/29/20252860 234 2874 26 0 0 0 N/A1/30/20252861 241 2879 26 0 0 0 N/A1/31/20252815 244 2831 27 0 0 0 N/AWell Name: WMRU‐1ABleeds (all annuli)
Glacier Oil & Gas Corporation | 188 W. Northern Lights Blvd. Ste. 510
Anchorage, AK 99503
February 4, 2025
Ms. Jessie Chmielowski
Commissioner
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501-3572
Subject: DIO 43.003 Monthly Reporting
Commissioner Chmielowski,
As required by Disposal Injection Order No. 43 issued by the AOGCC on August 9, 2023, the
monthly report detailing well pressures, injection rates, and pressure bleeds for all annuli for the
well WMRU-8 during January 2025 is provided to the Commission for review. WMRU-8
injected 29 days this month. No bleeds were conducted this month.
Please contact production and wells engineer Stan Porhola at sporhola@glacieroil.com or
(907) 433-3820 if you have any questions.
Sincerely,
David Pascal
Chief Operating Officer
Glacier Oil & Gas
Attachments: WMRU-8 Injection Log
Inner Annulus Outer AnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Hours: Min)Total Pressure Bled (bbl)Total Volume Bled (psi)IA or OA?1/1/20252366 293 2727 0 0 0 0 N/A1/2/20252352 281 2712 0 0 0 0 N/A1/3/20252390 278 2752 0 0 0 0 N/A1/4/20252392 277 2751 0 0 0 0 N/A1/5/20252496 279 2858 0 0 0 0 N/A1/6/20252501 286 2863 0 0 0 0 N/A1/7/20252504 284 2863 0 0 0 0 N/A1/8/20252518 283 2876 0 0 0 0 N/A1/9/20252520 280 2881 0 0 0 0 N/A1/10/20252533 277 2892 0 0 0 0 N/A1/11/2025170 79 508 0 0 0 0 N/A1/12/2025254 0 328 0 0 0 0 N/A1/13/20250 0 221 0 0 0 0 N/A1/14/202513 79 258 0 0 0 0N/A1/15/20252057 117 2414 0 0 0 0 N/A1/16/20252248 88 2607 0 0 0 0 N/A1/17/20252403 90 2760 1 0 0 0 N/A1/18/20252427 93 2784 1 0 0 0 N/A1/19/20252446 89 2804 1 0 0 0 N/A1/20/20252466 88 2826 1 0 0 0 N/A1/21/20252474 87 2863 2 0 0 0 N/A1/22/20252461 82 2820 1 0 0 0 N/A1/23/20252491 80 2848 1 0 0 0 N/A1/24/20252485 77 2842 2 0 0 0 N/A1/25/20252490 75 2848 2 0 0 0 N/A1/26/20252501 76 2855 2 0 0 0 N/A1/27/20252517 79 2874 1 0 0 0 N/A1/28/20252517 77 2874 1 0 0 0 N/A1/29/20252526 77 2884 1 0 0 0 N/A1/30/20252522 76 2879 1 0 0 0 N/A1/31/20252466 74 2823 1 0 0 0 N/AWell Name: WMRU‐08Bleeds (all annuli)
Inner Annulus Outer AnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Hours: Min)Total Pressure Bled (psi)Total Volume Bled (bbls) IA or OA?12/1/20242664 379 2672 13 0 0 012/2/20242744 446 2749 20 0 0 012/3/20242756 437 2760 22 0 0 012/4/20242719 392 2750 18 0 0 012/5/20242840 365 2830 20 0 0 012/6/20242839 361 2850 20 0 0 012/7/20242857 354 2868 22 0 0 012/8/20242855 352 2865 21 0 0 012/9/20242866 350 2870 20 0 0 012/10/20242881 355 2885 21 0 0 012/11/20242879 364 2887 22 0 0 012/12/20242861 357 2871 23 0 0 012/13/20242868 348 2877 24 0 0 012/14/20242858 352 2868 24 0 0 012/15/20242893 350 2895 23 0 0 012/16/20242853 331 2863 21 0 0 012/17/20242865 307 2877 18 0 0 012/18/20242857 286 2870 18 0 0 012/19/20242855 286 2866 16 0 0 012/20/20242861 288 2869 17 0 0 012/21/20242863 289 2872 16 0 0 012/22/20242871 284 2878 15 0 0 012/23/20242857 221 2687 5 0 0 012/24/20242826 293 2837 12 0 0 012/25/20242802 298 2827 13 0 0 012/26/20242647 256 2747 9 0 0 012/27/20240 99 1070 5 0 0 012/28/20240 0 374 0 0 0 012/29/20242778 124 1978 0 0 0 012/30/20242762 273 2776 16 0 0 012/31/20242748 293 2760 21 0 0 0Well Name: WMRU‐1ABleeds (all annuli)
Inner Annulus Outer AnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Hours: Min) Total Pressure Bled (bbl)Total Volume Bled (psi) IA or OA?12/1/20242289 125 2651 2 0 0 012/2/20242344 126 2706 2 0 0 012/3/20242334 127 2690 2 0 0 012/4/20242275 128 2800 2 0 0 012/5/20242395 126 2755 2 0 0 012/6/20242397 123 2750 2 0 0 012/7/20242357 120 2720 2 0 0 012/8/20242355 119 2718 2 0 0 012/9/20242358 117 2720 2 0 0 012/10/20242427 121 2784 2 0 0 012/11/20242390 121 2748 2 0 0 012/12/20242438 122 2797 2 0 0 012/13/20242413 123 2773 2 0 0 012/14/20242395 122 2754 2 0 0 012/15/20242416 122 2775 2 0 0 012/16/20242397 120 2755 2 0 0 012/17/20242387 121 2744 2 0 0 012/18/20242363 119 2722 2 0 0 012/19/20242363 119 2722 2 0 0 012/20/20242374 119 2728 2 0 0 012/21/20242371 120 2731 2 0 0 012/22/20242384 120 2737 2 0 0 012/23/20242418 110 2572 2 0 0 012/24/20242373 122 2732 1 0 0 012/25/20242382 119 2737 2 0 0 012/26/20242238 113 2649 2 0 0 012/27/2024215 75 1274 1 0 0 012/28/20240 0 574 0 0 0 012/29/20242212 86 1811 1 0 0 012/30/20242277 215 2634 1 0 0 012/31/20242328 287 2690 1 0 0 0Well Name: WMRU‐08Bleeds (all annuli)
Inner Annulus Outer AnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Hours: Min)Total Pressure Bled (psi)Total Volume Bled (bbls) IA or OA?11/1/20242898 595 2896 31 0 0 011/2/20242901 609 2906 36 0 0 011/3/20242901 642 2904 41 0 0 011/4/20242909 614 2909 41 0 0 011/5/20242900 608 2908 38 0 0 011/6/20242903 596 2904 40 0 0 011/7/20242906 598 2908 39 0 0 011/8/20242903 601 2906 41 0 0 011/9/20242909 598 2909 42 0 0 011/10/20242909 600 2909 41 0 0 011/11/20242908 603 2909 39 0 0 011/12/20242913 587 2914 32 0 0 011/13/20242911 586 2911 32 0 0 011/14/20242863 495 2866 19 0 0 011/15/20242897 599 2898 31 0 0 011/16/20242913 586 2914 34 0 0 011/17/20242909 587 2909 34 0 0 011/18/20242903 578 2905 30 0 0 011/19/20242913 566 2914 28 0 0 011/20/20242914 575 2914 32 0 0 011/21/20242903 549 2903 34 0 0 011/22/20242901 550 2903 37 0 0 011/23/20242913 545 2913 41 0 0 011/24/20242917 544 2917 42 0 0 011/25/20242922 542 2924 44 0 0 011/26/20242897 512 2900 37 0 0 011/27/20242903 508 2905 32 0 0 011/28/20242429 123 2443 2 0 0 011/29/20242410 225 2424 4 0 0 011/30/20242615 283 2624 8 0 0 0Well Name: WMRU‐1ABleeds (all annuli)
Inner Annulus Outer AnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Hours: Min)Total Pressure Bled (bbl)Total Volume Bled (psi) IA or OA?11/1/20242416 108 2763 2 0 0 011/2/20242427 108 2782 2 0 0 011/3/20242440 111 2793 2 0 0 011/4/20242445 106 2804 2 0 0 011/5/20242437 105 2805 2 0 0 011/6/20242416 104 2784 2 0 0 011/7/20242408 101 2770 2 0 0 011/8/20242510 104 2871 2 0 0 011/9/20242538 112 2900 2 0 0 011/10/20242517 110 2877 2 0 0 011/11/20242458 107 2818 2 0 0 011/12/20242469 107 2832 2 0 0 011/13/20242414 102 2773 1 0 0 011/14/20242390 107 2752 2 0 0 011/15/20242384 112 2744 2 0 0 011/16/20242429 109 2791 2 0 0 011/17/20242418 108 2780 1 0 0 011/18/20242536 109 2893 1 0 0 011/19/20242469 112 2829 1 0 0 011/20/20242469 108 2828 1 0 0 011/21/20242461 106 2820 1 0 0 011/22/20242459 106 2818 2 0 0 011/23/20242434 104 2794 2 0 0 011/24/20242426 103 2788 2 0 0 011/25/20242438 103 2799 2 0 0 011/26/20242418 102 2776 1 0 0 011/27/20242410 100 2768 1 0 0 011/28/20242139 59 2499 1 0 0 011/29/20242206 130 2565 1 0 0 011/30/20242270 127 2632 1 0 0 0Well Name: WMRU‐08Bleeds (all annuli)
Inner Annulus Outer AnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Hours: Min)Total Pressure Bled (psi)Total Volume Bled (bbls) IA or OA?10/1/20242884 1210 2877 87 0 0 010/2/20242901 1181 2897 113 0 0 010/3/20242913 1125 2909 112 0 0 010/4/20242917 1131 2913 110 0 0 010/5/20242921 1136 2914 120 0 0 010/6/20242922 1127 2914 115 0 0 010/7/20242924 1133 2917 130 0 0 010/8/20242921 1092 2914 127 0 0 010/9/20242927 1077 2921 71 0 0 010/10/20242929 1082 2919 96 0 0 010/11/20242929 1084 2919 87 0 0 010/12/20242922 1065 2911 87 0 0 010/13/20242921 1052 2911 101 0 0 010/14/20242927 1035 2916 114 0 0 010/15/20242925 1023 2913 117 0 0 010/16/20242929 1018 2916 113 0 0 010/17/20242873 973 2865 83 0 0 010/18/20242895 927 2885 80 0 0 010/19/20242898 992 2890 71 0 0 010/20/20242906 914 2893 67 0 0 010/21/20242905 898 2899 58 0 0 010/22/20242909 878 2898 47 0 0 010/23/20242916 844 2907 35 0 0 010/24/20242919 830 2911 27 0 0 010/25/20242921 805 2913 22 0 0 010/26/20242913 783 2911 22 0 0 010/27/20242921 774 2913 30 0 0 010/28/20242905 767 2906 40 0 0 010/29/20242903 750 2897 38 0 0 010/30/20242903 530 1859 27 0 0 010/31/20242890 574 2891 24 0 0 0Well Name: WMRU‐1ABleeds (all annuli)
Inner Annulus Outer AnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Hours: Min)Total Pressure Bled (psi)Total Volume Bled (bbl) IA or OA?10/1/20242458 142 2821 2 0 0 010/2/20242435 137 2799 2 0 0 010/3/20242411 130 2776 2 0 0 010/4/20242408 122 2760 2 0 0 010/5/20242401 115 2773 2 0 0 010/6/20242410 112 2776 2 0 0 010/7/20242413 108 2781 2 0 0 010/8/20242406 105 2770 2 0 0 010/9/20242400 102 2762 2 0 0 010/10/20242390 98 2757 2 0 0 010/11/20242397 97 2762 2 0 0 010/12/20242520 107 2885 2 0 0 010/13/20242575 106 2877 2 0 0 010/14/20242486 103 2850 2 0 0 010/15/20242551 102 2913 2 0 0 010/16/20242536 105 2898 2 0 0 010/17/20242518 103 2879 2 0:15 255 2 IA 10/18/20242512 103 2876 1 0 0 010/19/20242502 102 2865 2 0 0 010/20/20242512 103 2872 2 0 0 010/21/20242502 103 2865 2 0 0 010/22/20242490 104 2856 2 0 0 010/23/20242493 109 2853 2 0 0 010/24/20242496 113 2854 1 0 0 010/25/20242486 115 2856 1 0 0 010/26/20242416 110 2817 2 0 0 010/27/20242402 107 2771 1 0 0 010/28/20242405 106 2767 1 0 0 010/29/20242394 105 2764 2 0 0 010/30/20242414 98 1677 1 0 0 010/31/20242390 112 2759 2 0 0 0Well Name: WMRU‐08Bleeds (all annuli)
Inner Annulus Outer AnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Hours: Min)Total Pressure Bled (bbl)Total Volume Bled (psi) IA or OA?9/1/20242397 170 2731 1 0 0 09/2/20242430 169 2779 1 0 0 09/3/20242466 168 2810 1 0 0 09/4/20242494 170 2845 2 0 0 09/5/20242509 166 2866 2 0 0 09/6/20242520 166 2878 2 0 0 09/7/20242493 167 2871 2 0 0 09/8/20242403 157 2822 2 0 0 09/9/20242350 149 2731 2 0 0 09/10/20242245 138 1611 2 0 0 09/11/20241119 124 1284 2 0 0 09/12/20242313 108 2679 2 0 0 09/13/20242086 85 2453 2 0 0 09/14/20242259 113 2626 2 0 0 09/15/20242533 136 2897 2 0 0 09/16/20242429 135 2796 2 0 0 09/17/20242483 138 2845 2 0 0 09/18/20242450 135 2812 2 0 0 09/19/20242434 136 2800 2 0 0 09/20/20242392 131 2757 2 0 0 09/21/20242438 125 2800 2 0 0 09/22/20242482 139 2845 2 0 0 09/23/20242466 130 2828 2 0 0 09/24/20242466 124 2820 2 0 0 09/25/20242523 121 2887 0 0 0 09/26/20242414 121 2781 0 0 0 09/27/20242371 109 2736 2 0 0 09/28/20242394 111 2757 2 0 0 09/29/20242381 104 2744 2 0 0 09/30/20242448 127 2813 2 0 0 0Well Name: WMRU‐08Bleeds (all annuli)
Inner Annulus Outer AnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Avg. Pressure (psi)Bleed Time (Hours: Min)Total Pressure Bled (psi)Total Volume Bled (bbls) IA or OA?9/1/20249/2/20249/3/20249/4/20249/5/20249/6/202400 0 0 0 0 09/7/202400 0 0 0 0 09/8/202400 0 0 0 0 09/9/202400 3 0 0 0 09/10/20241878 590 1874 10 0 0 09/11/20241941 1356 1878 22 0 0 09/12/20242243 1157 2241 65 0 0 09/13/20242448 1158 2438 87 0 0 09/14/20242615 1400 2600 135 0 0 09/15/20242717 1430 2695 156 0 0 09/16/20242507 1453 2416 173 0 0 09/17/20242507 1477 2413 182 0 0 09/18/20242591 1426 2528 218 0 0 09/19/20242666 1534 2623 268 0 0 09/20/20242752 1561 2690 47 0:30 260 2.97 OA9/21/20242770 1480 2756 21 0:05 45 0.11 OA9/22/20242796 1443 2781 13 0 0 09/23/20242786 1493 2773 56 0 0 09/24/20242828 1516 2790 92 0 0 09/25/2024160 1371 213 0 0 0 09/26/20242410 109 2406 7 0 0 09/27/20242784 1313 2775 47 0 0 09/28/20242861 1241 2852 74 0 0 09/29/20242853 1262 2845 88 0 0 09/30/20242873 1193 2868 87 0 0 0Well Name: WMRU‐1ABleeds (all annuli)
Outer AnnulusDATEWellhead Pressure (psi)Injected Volume (bbls)Avg. Pressure (psi)Bleed Time (Hours: Min)Total Pressure Bled (bbl)Total Volume Bled (psi)Avg. Pressure (psi)8/1/20242368 128 2000 0 0 0 18/2/20242443 145 2600 0 0 0 18/3/20242459 147 2600 0 0 0 18/4/20242363 148 2600 0 0 0 18/5/20242549 167 2800 0 0 0 18/6/20242470 166 2850 0 0 0 18/7/20242364 151 2780 0 0 0 18/8/20242433 148 2780 0 0 0 18/9/20242394 151 2780 0 0 0 18/10/20242392 149 2760 0 0 0 18/11/20242371 148 2750 0 0 0 28/12/20242377 147 2740 0 0 0 28/13/20242390 149 2755 0 0 0 28/14/20242326 136 2690 0 0 0 18/15/20242345 143 2700 0 0 0 18/16/20242339 143 2700 0 0 0 18/17/20242336 138 2700 0 0 0 18/18/20242352 144 2710 0 0 0 18/19/20242357 149 2720 0 0 0 18/20/20242411 156 2776 0 0 0 18/21/20242389 167 2750 0 0 0 18/22/20242454 180 2810 0 0 0 28/23/20242432 179 2795 0 0 0 28/24/20242430 179 2790 0 0 0 28/25/20242424 181 2785 0 0 0 28/26/20242451 181 2805 0 0 0 28/27/20242458 178 2814 0 0 0 28/28/20242466 179 2828 0 0 0 18/29/20242472 179 2831 0 0 0 28/30/2024477 166 860 0 0 0 18/31/20242305 121 2669 0 0 0 1Well Name: WMRU‐08Inner Annulus
By Samantha Coldiron at 10:03 am, Aug 06, 2024
Glacier Oil & Gas Corporation | 188 W. Northern Lights Blvd. Ste. 510
Anchorage, AK 99503
June 10, 2024
Ms. Jessie Chmielowski
Commissioner
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501-3572
Subject: DIO 43.003 Monthly Reporting
Commissioner Chmielowski,
As required by Disposal Injection Order No. 43 issued by the AOGCC on August 9, 2023, the
monthly report detailing well pressures, injection rates, and pressure bleeds for all annuli for the
well WMRU-8 during May 2024 is provided to the Commission for review. WMRU-8 injected
19 days this month. No bleeds were conducted.
Please contact production and wells engineer Stan Porhola at sporhola@glacieroil.com or
(907) 433-3820 if you have any questions.
Sincerely,
David Pascal
Chief Operating Officer
Glacier Oil & Gas
Attachments: WMRU-8 Injection Log
By Samantha Coldiron at 7:33 am, Jun 12, 2024
David
Pascal
Digitally signed
by David Pascal
Date: 2024.06.10
15:00:15 -08'00'
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tĞůůEĂŵĞ͗tDZhͲϬϴ /ŶŶĞƌŶŶƵůƵƐ
188 W. Northern Lights Blvd., Suite 510, Anchorage, Alaska 99503.
Main (907) 334-6745 | Fax (907) 334-6735
July 20, 2023
Alaska Oil and Gas Conservation Commission (AOGCC)
333 W 7th AVE
Anchorage, AK 99501
(907) 279-1433
Dear Commissioner,
Cook Inlet Energy, LLC, a Glacier Oil and Gas company (GLA) requests Administrative
Approval to convert the West McArthur River Unit 08 (WMRU-08) well, API
501332062000, to an injection well as per DIO 43, and to remain in service with a
known tubing by inner annulus (IA) communication. Utilizing definitive geologic
confining zones and the proposed operating and monitoring plan, the well will meet
the criteria of 20 AAC 25.412 for disposal injection. GLA intends to re-inject primarily
produced water from the West McArthur River Field into this well to ease the burden
of water handling operations and optimize oil production.
Should you have any questions or need additional information regarding this request,
please contact me at (907) 433-3811.
Sincerely,
Michael Fairbanks
Geologist and Exploration Manager
Glacier Oil and Gas
Enclosures:
Technical Summary
Exhibit A – Wellbore Schematic of WMRU-08
Exhibit B – Correlation Section Depicting Arresting and Confining Zones
Michael Fairbanks Digitally signed by Michael Fairbanks
Date: 2023.07.20 16:09:27 -08'00'
Technical Summary in Conjunction with Request for Administrative Approval
Well History:
WMRU-08 was initially intended to encounter oil reserves in Fault Block “C” of the
West McArthur River Field (WMRU). The primary target interval was the Hemlock
formation, but was also intended to test the underlying Jurassic age section. The well
was spud in November 2013, and completed in March 2014 with first production in
April 2014. The well has produced 71,439 Bbls of oil from 239 perforated feet in the
Upper, Middle, and Lower Hemlock formation. In April 2016 the well was shut-in and
production ceased due to low productivity.
WMRU-08 was selected as a potential injector to handle produced water from the
WMRU field. WMRU-08 is currently unable to pass a standard annular mechanical
integrity test (MIT). The current wellbore schematic is included as Exhibit A. As a
producer, WMRU-08 was completed with a Weatherford Jet Pump design. To convert
the well into an injector, the jet pump was removed, and a blanking sleeve was
installed to isolate the tubing from the IA. Multiple MIT and tubing/IA bundle test
attempts were conducted with two different blanking sleeves and multiple tubing
plug designs; all of which failed to pass MIT pressure criteria. However, a passing
tubing pressure test with a plug above the jet pump cavity indicated good tubing
integrity above the jet pump cavity. Since no changes in outer annulus pressure were
observed during failed MIT attempts, GLA suspects that failures are due to a leaking
packer.
Geology of West McArthur River Field:
The West McArthur River Field is located near the southern extent of the current
proven oil production in the Cook Inlet. The field is situated on a south-plunging
normally faulted Plio-Pliestocene anticline. Oil is believed to be sourced from the
Jurassic section and is produced from the prolific Oligocene Hemlock formation while
gas is produced from sands within the Oligocene-Miocene Tyonek formation. The
Hemlock formation is nearly 600’ thick and consists primarily of fine to course, poorly
sorted volcaniclastic sandstones and pebble to cobble conglomerates of 12%
porosity. Most of the oil is produced from the Upper and Middle Hemlock formation.
Generally, the Lower Hemlock and West Forelands formation are considered to be
wet. The West McArthur River Field has been on production since August 1993 and
has produced nearly 15.8 MMBO and over 4 BCF of gas. Currently, the field is
producing 400 BBLS oil per day and 4,100 BBLS water per day.
There is currently only one injection well (WMRU-4D) at WMRU that is a class 1
dispoal well that is being used sporadically. Established water injection from WMRU-
4D occurs within the Upper Tyonek formation, which consists of non-marine clean
sands, volcaniclastic and shaly sands, siltstones, shales, and coals. Of the various
lithotypes, shales are the most regionally correlatable between wells and because of
the high clay content, become the best candidates for confinement of permeability,
providing flow isolation across the interval.
Geologic Confinement Zone Justification:
The Upper Tyonek contains many correlatable shale intervals that contain sufficient
thickness and regional extent to be serviceable as primary and secondary
confinement zones. One established zone which defines the injection interval for the
WMRU-4D well is found at 4,855’ MD to 4,935’ MD and is correlatable to the offset
log in the Pan Am West Foreland Unit 2 Well. This 80’ section is characterized as
siltsone and shale, bounded on the top and bottom by coals. Similarly, the WMRU 8
has at least 5 distinct, regionally correlatable shales, the bottom 4 serving as
‘arresting’ zones and the shallowest as a ‘confinement’ zone, preventing the upward
migration of fluids. The deepest of these arresting zones is encountered on the
WMRU-08 Gamma Ray (GR) log at 5,670-5,743 MD (4,387-4,431 TVD). This zone is
characterized by a 44’ thick, section of highly radioactive shale bounded by thin coal
seams. Up section from this lies another arresting shale interval of high radioactivity
encountered at 4,994-5,005 MD (3,986-4,022 TVD) on the WMRU-08 GR log. The
thickest arresting zone is determined to be 62’ thick, characterized by interbedded
siltstones and shales, bounded by two well defined coals, readily identified in offset
logs, and located at 4,670-4,776 MD (3,794-3,856 TVD) on the WMRU-08 GR log. The
shallowest ‘arresting’ zone is characterized by interbedded siltstones and shales
found on the WMRU-08 GR log at 4,032-4,080 MD (3,444-3,415 TVD). Up section from
the ‘arresting’ zones is a regionally extensive, 60 foot thick ‘confining’ radioactive
shale with few interbedded coals encountered at 3,554-3,653 MD (3,128-3,188 TVD).
This final zone isolates all underlying zones and fluids from overlying formations.
Exhibit B is a correlation section depicting these shale confining and arresting zones
in the WMRU-08 well along with nearby offset wells.
Proposed Operating and Monitoring Plan:
In order to ensure compliance to criteria of 20 AAC 25.412 for disposal injection, GLA
commits to the following prescribed operating and monitoring plan for this well:
1) Well will be used as an injector as per DIO 43.
2) IA pressure not to exceed 3,000 psi.
3) OA pressure will be maintained as low as hydrostatic pressure allows, not to
exceed 300 psi.
4) Submit monthly reports of daily pressures (IA, OA, tubing), injection volumes,
and any pressure bleeds on any annuli.
5) Shut-in the well and notify the AOGCC should any problems or issues arise.
6) Run baseline P/T surveys before and after injection operations are initiated.
Recommendation:
It is the opinion of GLA that it is in the best interest of the AOGCC and the State of
Alaska to grant Administrative Approval for GLA to proceed with injection in WMRU-
8 well as per DIO 43. Based on the geological and technical justifications provided in
this request, along with the monitoring plan presented, GLA will be able to safely and
properly inject produced water into the Hemlock formation. By mitigating water
handling operational burdens GLA can optimize oil production in the West McArthur
River Unit furthering the mission statement of the AOGCC to “enhance greater
ultimate recovery, and protection of health, safety, fresh ground waters, and the
rights of all owners to recover their share of the resource.” GLA hereby requests that
the AOGCC approve this request for Administrative Approval to convert WMRU-08 to
an injection well and remain in service with a known tubing by IA communication.
NS
WFU 2 WMRU-1A WMRU-6 WMRU-8
(Datum)
South to North correlation
section of the West McArthur
River Unit showing regional
extent and competency of the
upper confining zone (Confining
Zone A) and 4 arresting zones in
the Tyonek formation (Arresting
Zones B-E). The index map on
the right shows the location of
the wells and section line
through the field.
Exhibit B CONFIDENTIAL
S
N.5 Mile
West McArthur River Unit
N
From:Mike Fairbanks
To:Wallace, Chris D (OGC)
Cc:David Pascal; Zack Hundrup; Carlisle, Samantha J (OGC); Roby, David S (OGC)
Subject:RE: Request for Administrative Authorization DIO 43 WMRU 8 (PTD 2131520)
Date:Thursday, July 27, 2023 2:07:16 PM
Attachments:image001.png
You don't often get email from mfairbanks@glacieroil.com. Learn why this is important
Hi Chris,
As a follow-up:
The max injection pressure from our injection pumps (as limited by High Pressure Swithces and
PSV’s) is 4500 psi.
Hope this helps,
Mike Fairbanks
O: (907) 433-3811 | M: (432) 254-8389
From: Mike Fairbanks
Sent: Thursday, July 27, 2023 2:04 PM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: David Pascal <dpascal@glacieroil.com>; Zack Hundrup <ZHundrup@glacieroil.com>; Carlisle,
Samantha J (OGC) <samantha.carlisle@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>
Subject: RE: Request for Administrative Authorization DIO 43 WMRU 8 (PTD 2131520)
Hi Chris,
Thanks for reaching out. Please see below in red the responses to your questions.
Please confirm the packer mentioned as a possible leak is as 13523 ft deep?
Yes, the retrievable packer is at 13523
I am interested in what monitoring for the IA and OA looks like? SCADA real time, operator visual
and record once a day? DIO 43 Rule 6 says continuously – how is that achieved in actuality?
We plan to install pressure transmitters on each of the IA and OA. The transmitters will continuously
communicate IA and OA pressures to the HMI for remote operator visibility. In addition, operators
will visually monitor locally on their daily rounds.
Any failsafes on the injection stream or well triggered by the IA/OA monitoring/limits established at
3000 psi and 300 psi? Any alarms /remote or all manual operator intervention?
With the pressure transmitters mentioned above, we can set high pressure alarms. We will confirm
the system pressures to validate the 3000 psi PSV and get back to you. We plan to have operator
soft alarms at the indicated high pressure limit and shutdowns will be at the operator’s discretion.
For ongoing testing, is there value in an MITOA or is it an open shoe etc?
It is an open shoe so MITOA would not be possible.
As per DIO 43, the baseline temperature test shall be run prior to injection, and the follow up test
shall be run one month after injection begins. A temperature survey has been acceptable in Cook
Inlet in the past and my initial thought is a 2 year requirement with operator provided comparison
against previous logging results looking for anomalies.
Are you suggesting that we test every 2 years in addition to the one month follow-up or in lieu of
the one month follow-up?
An oxygen activation/waterflow/acoustic logging program has been required for some wells with
TxIA and potential masked missinjection zones. Please describe why this type of log is appropriate or
not for this well, and what frequency could/should it be run?
We are exploring appropriate logging programs to monitor where the water is being injected in the
wellbore. We will start with the most commonly used temperature logs which we have used
successfully in several of our wells to identify where water is being injected. We will be looking at an
annual basis for this type of production logging. We will consider additional logging methods,
including oxygen activation/waterflow/acoustic as needed.
I am thinking of implementing a MITT requirement every two years as the well will not sustain a
MITIA. I am interested in your opinion of its results/value in conjunction with the overall plan of
monitoring and temperature logging, and potential oxygen activation testing?
We are open to an MITT every two years, as appropriate. Logging will give us a better understanding
of where we are injecting.
Let me know what other questions arise.
Thanks,
Mike Fairbanks
O: (907) 433-3811 | M: (432) 254-8389
From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Sent: Thursday, July 27, 2023 11:23 AM
To: Mike Fairbanks <MFairbanks@glacieroil.com>
Cc: David Pascal <dpascal@glacieroil.com>; Zack Hundrup <ZHundrup@glacieroil.com>; Carlisle,
Samantha J (OGC) <samantha.carlisle@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>
Subject: RE: Request for Administrative Authorization DIO 43 WMRU 8 (PTD 2131520)
External Sender: Proceed with Caution
Mike,
I am looking for more specifics on the proposed monitoring and testing to assure fluids are disposing
into the approved interval and remain there.
I see your proposed operating and monitoring plan includes:1) Well will be used as an injector as per DIO 43.2) IA pressure not to exceed 3,000 psi.3) OA pressure will be maintained as low as hydrostatic pressure allows, not to exceed 300 psi.4) Submit monthly reports of daily pressures (IA, OA, tubing), injection volumes, and anypressure bleeds on any annuli.5) Shut-in the well and notify the AOGCC should any problems or issues arise.6) Run baseline P/T surveys before and after injection operations are initiated.
Please confirm the packer mentioned as a possible leak is as 13523 ft deep?
I am interested in what monitoring for the IA and OA looks like? SCADA real time, operator visual
and record once a day? DIO 43 Rule 6 says continuously – how is that achieved in actuality?
Any failsafes on the injection stream or well triggered by the IA/OA monitoring/limits established at
3000 psi and 300 psi? Any alarms /remote or all manual operator intervention?
For ongoing testing, is there value in an MITOA or is it an open shoe etc?
As per DIO 43, the baseline temperature test shall be run prior to injection, and the follow up test
shall be run one month after injection begins. A temperature survey has been acceptable in Cook
Inlet in the past and my initial thought is a 2 year requirement with operator provided comparison
against previous logging results looking for anomalies.
An oxygen activation/waterflow/acoustic logging program has been required for some wells with
TxIA and potential masked missinjection zones. Please describe why this type of log is appropriate or
not for this well, and what frequency could/should it be run?
I am thinking of implementing a MITT requirement every two years as the well will not sustain a
MITIA. I am interested in your opinion of its results/value in conjunction with the overall plan of
monitoring and temperature logging, and potential oxygen activation testing?
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: Roby, David S (OGC) <dave.roby@alaska.gov>
Sent: Wednesday, July 26, 2023 11:03 AM
To: Mike Fairbanks <MFairbanks@glacieroil.com>; Carlisle, Samantha J (OGC)
<samantha.carlisle@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: David Pascal <dpascal@glacieroil.com>; Zack Hundrup <ZHundrup@glacieroil.com>
Subject: RE: Request for Administrative Authorization
Hi Mike,
Thanks for the call this morning, this email is to memorialize it for our well file. I checked the well
file and did see that we have approved a sundry to convert this well already, I didn’t look far enough
back in the well file to see it before I sent the email below, about a year ago so you do not need to
submit a 10-403 as I requested below and we’ll process your administrative approval request to
allow the well to be online with a known TxIA leak.
Regards,
Dave Roby
(907)793-1232
From: Roby, David S (OGC)
Sent: Tuesday, July 25, 2023 1:39 PM
To: Mike Fairbanks <MFairbanks@glacieroil.com>; Carlisle, Samantha J (OGC)
<samantha.carlisle@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: David Pascal <dpascal@glacieroil.com>; Zack Hundrup <ZHundrup@glacieroil.com>
Subject: RE: Request for Administrative Authorization
Hi Mike,
Actually to convert a well from a producer, as the WRMU 08 is currently classified, to an injector
requires the submission of a sundry application (AOGCC Form 10-403) for the conversion. So, we’ll
need a sundry application from you. The allowing the well to be used for injection with a known
TxIA leak portion of the request does require an administrative approval from us.
Regards,
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.
Dave Roby
(907)793-1232
From: Mike Fairbanks <MFairbanks@glacieroil.com>
Sent: Thursday, July 20, 2023 4:18 PM
To: Roby, David S (OGC) <dave.roby@alaska.gov>; Carlisle, Samantha J (OGC)
<samantha.carlisle@alaska.gov>
Cc: David Pascal <dpascal@glacieroil.com>; Zack Hundrup <ZHundrup@glacieroil.com>
Subject: Request for Administrative Authorization
Hi Dave,
Please find attached a request for Administrative Authorization to convert the WestMcArthur River Unit 08 well to an injector and to remain in service with a known tubing byinner annulus communication. Please let me know if you need any additional information regarding this request. Thank you,
Mike Fairbanks
Geologist | Exploration Manager
mfairbanks@glacieroil.com
O: (907) 433-3811 | M: (432) 254-8389
188 W. Northern Lights Blvd., Suite 510
Anchorage, AK 99503
9
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From:Wallace, Chris D (OGC)
To:Carlisle, Samantha J (OGC)
Subject:FW: Permit Active Glacier DIO 43.001 WMRU-08 Conversion to Disposal Well Injection
Date:Thursday, January 12, 2023 12:03:50 PM
Attachments:AOGCC Well 8 Step Up Test 12-17-2022 .xlsx
AOGCC 221229 Well 8 Step Up Test 12-29-2022.xlsx
From: Scott Begins <sbegins@glacieroil.com>
Sent: Wednesday, January 11, 2023 11:13 AM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Wallace, Chris D (OGC)
<chris.wallace@alaska.gov>
Cc: Zack Hundrup <ZHundrup@glacieroil.com>
Subject: Permit Active Glacier DIO 43.001 WMRU-08 Conversion to Disposal Well Injection
Good afternoon Chris and Bryan,
Thank you for meeting with Zack and I yesterday to discuss the recent activities on WMRU-08 under
DIO 043.
Attached please find the injection data from the 12/17/22 and 12/29/22 injections respectively.
Step Rate Test 12/17/22: Total of 204.54bbls injected. Limited tankage resulted in
inconclusive results
Max Rate Test 12/29/22: Total of 297.62bbls injected. This secondary test was performed to
collected data at max anticipated injection rates
Between 3000psi and 3500psi WHP the well appears to be able to handle an injection
rate of ~1.1 BPM (~1584bpd)
Due to limited tankage we were unable to perform a longer duration test
Anticipated addition water increases associated with planned workovers and field water cut
increases is ~4000-4700bpd of produced water
Based on the limited data collected, we will plan to submit respective Sundries for the additional two
candidate wells WMRU-1A and WMRU-7A, as identified in DIO 043.001. These sundries will include
establishing a rate test on the respective candidate well in order to determine the best path forward
to meet the anticipated water volumes increases associated with maximizing recoverability for this
field.
If you could please confirm, as per discussions in yesterdays meeting, that DIO 43 is in now in effect
and the permit is active. We will plan to include the recent injection volumes on our 10-406 monthly
injection report.
Thank you and we look forward to hearing back,
Scott BeginsProduction & Facilities Engineer | Glacier Oil and Gas Corporation188 W. Northern Lights Blvd., Suite 510, Anchorage,AK 99503907-433-3820 (Direct)| 907-394-4254 (Mobile)907-334-6745 (Main) | Email:sbegins@glacieroil.com
From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Sent: Monday, December 12, 2022 4:44 PM
To: Scott Begins <sbegins@glacieroil.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: Zack Hundrup <ZHundrup@glacieroil.com>
Subject: RE: Glacier DIO 43.001 WMRU-08 Conversion to Disposal Well Proposed Plan Forward
Scott,
CIE has approval to proceed with the plan forward in the email below on the condition that during
the step rate test, the Outer Annulus Pressure is monitored and the pumping is stopped if there are
signs that the 9-5/8” casing is communicating to the OA.
Regards
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
333 W 7th Ave
Anchorage, AK 99501
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
From: Scott Begins <sbegins@glacieroil.com>
Sent: Monday, December 12, 2022 12:37 PM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Wallace, Chris D (OGC)
<chris.wallace@alaska.gov>
Cc: Zack Hundrup <ZHundrup@glacieroil.com>
Subject: RE: Glacier DIO 43.001 WMRU-08 Conversion to Disposal Well Proposed Plan Forward
Good afternoon Bryan,
Please find attached FIT tests from 2014 for the casing. Pressure test was to 4000psi surface
pressure. The injectability test will be to 3500psi never to exceed 4000psi surface pressure.
Thank you and please let us know once the proposed plan forward has been reviewed and if it is
acceptable to proceed with the injectability test as proposed below.
Thank you and please reach out with any questions or comments if needed,
Have a good afternoon,
Scott BeginsProduction & Facilities Engineer | Glacier Oil and Gas Corporation188 W. Northern Lights Blvd., Suite 510, Anchorage,AK 99503907-433-3820 (Direct)| 907-394-4254 (Mobile)907-334-6745 (Main) |Email:sbegins@glacieroil.com
From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Sent: Thursday, December 8, 2022 11:49 AM
To: Scott Begins <sbegins@glacieroil.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: Zack Hundrup <ZHundrup@glacieroil.com>
Subject: RE: Glacier DIO 43.001 WMRU-08 Conversion to Disposal Well Proposed Plan Forward
External Sender: Proceed with Caution
Scott,
During this injection test, I believe your Inner Annulus will see up to 4000 psi. What has the casing
been pressure tested to? When was it last tested?
Thanks
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
333 W 7th Ave
Anchorage, AK 99501
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
From: Scott Begins <sbegins@glacieroil.com>
CAUTION: This email originated from outside the State of Alaska mail system.
Do not click links or open attachments unless you recognize the sender and know
the content is safe.
Sent: Thursday, December 8, 2022 11:22 AM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Wallace, Chris D (OGC)
<chris.wallace@alaska.gov>
Cc: Zack Hundrup <ZHundrup@glacieroil.com>
Subject: Glacier DIO 43.001 WMRU-08 Conversion to Disposal Well Proposed Plan Forward
Good afternoon Bryan,
I recently had discussions with Chris in regards to our current WMRU-08 well operations to convert
to water disposal well per the attached sundry and AIO 043.
Chris can likely catch you up to speed if needed or I can share with you a synopsis of operations to
date. In summary, we performed a tubing test using a wireline tubing pack off and verified
mechanical integrity of the tubing down to the jet pump cavity on the well. We then reran the
blanking sleeve to establish mechanical integrity between the IA and tubing.
Unfortunately, the blanking sleeve appears to be allowing bypass and we are unable to isolate the
tubing and IA with the current sleeve. In addition, we observed a significant pressure increase on the
tubing that is concerning in the sense that it may suggest that the well may pose injectability issues
once converted. With this said, we would like to perform the injectability test prior to the MIT. In the
attached Sundry comments it appears this is acceptable and was part of the original proposed
Sundry but just wanted to confirm.
In addition, we plan to run a subsequent flowing pressure temperature survey to compare with the
static pressure temperature log that was just recently done to determine fluid flow direction.
The results of the injectability test will allow us to determine if we need to select an alternative well
if the data suggests unfavorable injection conditions. We would like to discuss those results
following the injectability test for determining the best path forward.
We are actively looking at sourcing an alternative blanking sleeve at this time but we would like to
move forward with the injectability test in the interim in order to de-inventory our water injection
lines with the current freezing conditions on location.
We look forward to hearing back at your earliest convenience, please find the proposed procedure
below:
Proposed Detailed Procedure
Requirements of 20 AAC 25.005
1.Conduct pre-job safety meeting with all personnel on location.
2.Record Tubing and IA pressure prior to job start.
3.Line up for injection test.
4.Perform baseline step rate test.
Step rate test will be done in 500psi increments up to a max injection pressure of
3500psi not to exceed 4000psi per Per AOGCC order AIO 043
Time Flow (bpd) Pressure
500
1000
1500
2000
2500
3000
3500
*Do Not Exceed 4000psi at any time per AIO 043
5.Determine minimum stabilized flow rate possible and record pressure and rate
This will be used for establishing flowing P/T gauge parameters to determine fluid
movement
6.Rig up Slickline. Test lubricator to 5,000 psi.
7.RIH and retrieve 3-1/2” sleeve flapper holder to lock out SSSV
8.RIH and retrieve G-stop above blanking sleeve ~13,541’ KB
9.RIH and retrieve blanking sleeve
10.RIH and retrieve gutted standing valve
11.RIH with pressure temperature gauges to ~13920’ RKB
12.Perform flowing pressure temperature survey. At minimum stabilized flow rate
previously established.
13.Review step rate test and flowing pressure temperature data with state to determine best
path forward
Thank you and regards,
Scott BeginsProduction & Facilities Engineer | Glacier Oil and Gas Corporation188 W. Northern Lights Blvd., Suite 510, Anchorage,AK 99503907-433-3820 (Direct)| 907-394-4254 (Mobile)907-334-6745 (Main) |Email:sbegins@glacieroil.com
Time Delta Minutes Tubing psi IA psi OA psi bbls injected bpm BPD13:00 0 13 0 0 014:45 105.00 6 0.057143 82.2857114:53 8.00 44 5.5 792015:09 16.00 552 760 0 22 1.375 198016:48 99.00 620 920 0 27 0.272727 392.727316:53 5.00 1020 1300 0 5 1 144017:08 15.00 998 1325 0 1 0.066667 9617:15 7.00 1507 1880 2 8 1.142857 1645.71417:30 15.00 1433 1780 0 6 0.4 57617:40 10.00 1930 2280 0 6.00 0.6 86418:00 20.00 2010 2360 0 16.00 0.8 115218:05 5.00 2498 2550 0 6.00 1.2 172818:20 15.00 2505 2830 0 12.00 0.8 115218:25 5.00 2851 3200 0 4.50 0.9 129618:38 13.00 2980 3380 0 25.50 1.961538 2824.615018:52 14.00 0 018:59 7.00 100 500 0 0 019:03 4.00 152 526 0 2.23 0.558445 804.160819:05 2.00 525 675 0 0.00 0 019:10 5.00 1000 1320 0 2.97 0.593452 854.570919:13 3.00 1460 1800 0 3.40 1.13356 1632.32619:18 5.00 1990 2300.000 0 2.10 0.420084 604.92119:27 9.00 2440 2780.000 0 1.63 0.181518 261.385619:35 8.00 2910 3220.000 0 0.80 0.10002 144.028819:45 10.00 3330 3740.000 0 1.07 0.106688 153.630719:58 13.00 3420 3760.000 0 1.33 0.102585 147.7218Sum Total 204.54Injection Pump S/D on motor overload fault @ 19:58Injection pump online @ 19:03Swapping to additional water storage tankageReached min levels in water tank, Swapping to additional water storage tankageSwapping to additional water storage tankageCommentsWMRU‐08 Step Rate Test 12/17/22Injection Pump online @ 14:5201234560500100015002000250030003500400014:24 15:36 16:48 18:00 19:12 20:24BPMPressureTime (hh:mm)12/17/22 WMRU‐08 Step Rate Pressure TestTubing psiIA psiOA psibpm
Time delta time (min) Tubing psi IA psi OA psi bbls injected bpm BPD Comments10:30:00 0 13 0 0 0.000 012:45:00 135.00 11 0.081 117.3333 Filling wellbore via charge pump13:25:00 40.00 0 0.000 0 Filling wellbore via charge pump13:30:00 5.00‐13.7 0 0 0 0.000 0 Filling wellbore via charge pump13:45:00 15.00‐13.7 0 0 38 2.533 3648 Filling wellbore via charge pump14:00:00 15.00‐13.7 400 0 21.5 1.433 2064 Filling wellbore via charge pump14:15:00 15.00 81 550 0 4.5 0.300 432 Filling wellbore via charge pump14:30:00 15.00 81 550 0 3 0.200 288 Filling wellbore via charge pump14:45:00‐14 360 0Injection Pump online 14:48.START OF TEST15:00:00 15.00 1200 16 0 15.40 1.027 1478.415:15:00 15.00 1960 2350 0 20.60 1.373 1977.615:30:00 15.00 2050 2430 0 10.00 0.667 96015:45:00 15.00 2410 2800 0 25.49 1.699 2447.0416:00:00 15.00 2580 3000 0 14.51 0.967 1392.9616:15:00 15.00 2909 3250 0 20.00 1.333 192016:30:00 15.00 3268 3600 0 20.00 1.333 192016:45:00 15.00 3455 3800 0 15.00 1.000 144017:00:00 15.00 3050 3200 0 10.60 0.707 1017.80417:15:00 15.00 3530 3890 0 20.80 1.387 1997.19917:30:00 15.00 3415 3750 0 18.20 1.214 1747.54917:45:00 15.00 3330 3700 0 13.20 0.880 1267.45317:55:00 10.00 3500 3900 0 15.80 1.580 2275.655 Ended test due to low tank volume and IA pressure climbing in order to not exceed 4000psiSum Total 297.62WMRU‐08 Max Pressure Rate Testy = 0.6006x + 0.75400.20.40.60.811.21.41.61.8‐15500101515302045256030753590410514:24:00 14:52:48 15:21:36 15:50:24 16:19:12 16:48:00 17:16:48 17:45:36 18:14:24TimeBPM (bbl/min)Pressure12/29/22 WMRU‐08 Max Injection Pressure TestTubing psiIA psiOA psibpmLinear (bpm)
8
By Samantha Carlisle at 10:01 am, Feb 25, 2022
Notice of Public Hearing
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION
Re: Docket Number: DIO-18-004
West McArthur River Unit, Hemlock Undefined Oil Pool
The application for Disposal Injection Order
Cook Inlet Energy (CIE), by letter dated December 12, 2018, requests the Alaska Oil and Gas
Conservation Commission (AOGCC) issue a Disposal Injection Order to allow the disposal of
produced water from the West McArthur River Unit (WMRU) and Redoubt Unit in the Hemlock
formation in the WMRU.
The AOGCC has tentatively scheduled a public hearing on this application for June 18, 2019 at
10:00 a.m. at 333 West 7a' Avenue, Anchorage, Alaska 99501. To request that the tentatively
scheduled hearing be held, a written request must be filed with the AOGCC no later than 4:30 p.m.
on June 1, 2019.
If a request for a hearing is not timely filed, the AOGCC may consider the issuance of an order
without a hearing. To learn if the AOGCC will hold the hearing, call (907) 793-1221 after June 5,
2019.
In addition, written comments regarding this application may be submitted to the AOGCC, at 333
West 7s' Avenue, Anchorage, Alaska 99501. Comments must be received no later than 4:30 p.m.
on June 17, 2019, except that, if a hearing is held, comments must be received no later than the
conclusion of June 18, 2019 hearing.
If, because of a disability, special accommodations may be needed to comment or attend the
hearing, contact the AOGCC's Special Assistant, Jody Colombie, at (907) 793-1221, no later than
June 17, 2019.
Je ie L. Chmielows ki
Chair, Commissioner
Notice of Public Hearing
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Re: Docket Number: DIO-18-004
West McArthur River Unit, Hemlock Undefined Oil Pool
The application for Disposal Injection Order
Cook Inlet Energy (CIE), by letter dated December 12, 2018, requests the Alaska Oil and Gas
Conservation Commission (AOGCC) issue a Disposal Injection Order to allow the disposal of
produced water from the West McArthur River Unit (WMRU) and Redoubt Unit in the Hemlock
formation in the WMRU.
The AOGCC has tentatively scheduled a public hearing on this application for June 18, 2019 at
10:00 a.m. at 333 West 7a' Avenue, Anchorage, Alaska 99501. To request that the tentatively
scheduled hearing be held, a written request must be filed with the AOGCC no later than 4:30 p.m.
on June 1, 2019.
If a request for a hearing is not timely filed, the AOGCC may consider the issuance of an order
without a hearing. To learn if the AOGCC will hold the hearing, call (907) 793-1221 after June 5,
2019.
In addition, written comments regarding this application may be submitted to the AOGCC, at 333
West 7' Avenue, Anchorage, Alaska 99501. Comments must be received no later than 4:30 p.m.
on June 17, 2019, except that, if a hearing is held, comments must be received no later than the
conclusion of June 18, 2019 hearing.
If, because of a disability, special accommodations may be needed to comment or attend the
hearing, contact the AOGCC's Special Assistant, Jody Colombie, at (907) 793-1221, no later than
June 17, 2019.
//signature on file//
Jessie L. Chmielowski
Chair, Commissioner
STATE OF ALASKA
ADVERTISINGNOTICE
ORDER
TO PUBLISHER
SUBMIT INVOICE SHOWING ADVERTISING ORDER NO., CERTIFIED
AFFIDAVITOFPUBLICATION ATTACHED COPY OF
DVERTISMENT
ADVERTISING ORDER NUMBER
AO-19-022
FROM: AGENCY CONTACT:
Jody Colombie/Samantha Carlisle
Alaska Oil and Gas Conservation Commission DATE OF A.O.AGENCY PHONE:
333 West 7th Avenue 5/15/2019 907 279-1433
Anchors e, Alaska 99501
DATES ADVERTISEMENT REQUIRED:
COMPANY CONTACT NAME:
PHONE NUMBER: ASAP
FAX NUMBER:
907 276-7542
TO PUBLISHER:
Anchorage Daily News, LLC
SPECIAL INSTRUCTIONS:
PO Box 140147
Anchorage, Alaska 99514-0174
TYPE OF ADVERTISEMENT:
1� LEGAL r- DISPLAY rV CLASSIFIED r OTHER (Specify below)
DESCRIPTION PRICE
DIO-I8-004
Initials of who prepared AO:
Alaska Non -Taxable 92-600185
SUBMIT INVOICE SHOWING ADVERTISING
ORDER NO., CERTIFIED AFFIDAVIT OF
PUBLICATION WITH ATFACHED COPY OF
ADVERTISMENT TO:
AOGCC
333 West 7th Avenue
Anchorage, Alaska 99501
Pae I OP1
TO[al of
All Pa CS
REF Tye Number
Amount Date Comments
I PVN VCO21795
2 AO AO -19-022
3
4
FLY AMOUNT SV Act Tcrops PGM LGR Object FY DIST LIQ
I 19 A14100 3046 19
2
3
4
5
Purch
u'ty Ti
Purchasing Authority's Signature Telephone Number
1. .O cat, g encynalre, must appear on all invoices and documents relating to this purchase.
2. In stateisregist for tax free transactions under Chapter 32, IRS code. Registration number 92-73-0006 K. Items are for the exclusive use of the state and
n f resale.
DISTRIBUTION:
Division Fiscal/Original AO
Copies: Publisher (faxed), Division Fiscal, Receiving
Form: 02-901
Revised: 5/15/2019
Bernie Karl
M Recycling Inc.
P.O. Box 58055
Fairbanks, AK 99711
Gordon Severson
3201 Westmar Cir.
Anchorage, AK 99508-4336
Penny Vadla
399 W. Riverview Ave.
Soldotna, AK 99669-7714
George Vaught, Jr. Darwin Waldsmith Richard Wagner
P.O. Box 13557 P.O. Box 39309 P.O. Box 60868
Denver, CO 80201-3557 Ninilchik, AK 99639 Fairbanks, AK 99706
.ANCHORAGE DAILY NEWS
EC
AFFIDAVIT OF PUBLICATION MAY 2 3 Z019
Account#: 270227
ST OF AK/AK OIL AND GAS Order#
CONSERVATION COMMISSION Cost
333 WEST 7TH AVE STE 100
eurunannc AIC0o5niil io
STATE OF ALASKA
THIRD JUDICIAL DISTRICT
Joleesa Stepetin
being first duly sworn on oath deposes and says
that he/she is a representative of the Anchorage
Daily News, a daily newspaper. That said
newspaper has been approved by the Third
Judicial Court, Anchorage, Alaska, and it now
and has been published in the English language
continually as a daily newspaper in Anchorage,
Alaska, and it is now and during all said time
was printed in an office maintained at the
aforesaid place of publication of said newspaper
That the annexed is a copy of an advertisement
as it was published in regular issues (and not in
supplemental form) of said newspaper on
May 16, 2019
and that such newspaper was regularly
distributed to its subscribers during all of said
period. That the full amount of the fee charged
for the foregoing publication is not in excess of
the rate charged private individuals.
Signed
Jnsa Stenetin
Subscribed and swom to before me
th's� day of MM
N ry Public in and for
e State of Alaska.
Third Division
Anchorage, Alaska
MY C�OMIyI �i>� N�XP� S
AOGCC
0001438269 Product ADN -Anchorage Daily News
$214.16 Placement 0300
Position 0301
Notice of Public Nearing
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Re: Docket Number: DIO-18-004
West McArthur River Unit Hemlock Undefined Oil Pool
The application for Disposal Injection Order
Cook Inlet Energy (CIE), by letter dated December 12, 2018,
requests the Alaska Oil and Gas Conservation Commission
(AOGCC) issue a Disposal Injection Order to allow the disposal of
produced water from the West McArthur River Unit (WMRU) and
Redoubt Unit in the Hemlock formation in the WMRU.
The AOGCC has tentatively scheduled a public hearing on this
application for June 18, 2019 at 10:00 a.m. at 333 West 7th
Avenue, Anchors a, Alaska 99501. To request that the
tentatively schedured hearing be held, a written request must be
filed with the AOGCC no later than 4:30 p.m. on June 1, 2019.
If a request for a hearing is not timely filed, the AOGCC may
consider the issuance of an order without a hearing. To learn if
the AOGCC will hold the hearing, call (907) 793-1221 after lune 5,
2019.
In addition, written comments regarding this application may be
submitted to the AOGCC, at 333 West 7th Avenue, Anchorage;
Alaska 99501. Comments must be received n0 later than 4:30
p.m. on lune 17, 2019, except that, if a hearing is held,
comments must be received no later than the conclusion of June
18, 2019 hearing.
If, because of a disability, special accommodations may be
needed to comment or attend the hearing, contact the AOGCC's
Special Assistant Jody Colombia, at (907) 793-1221, no later than
June 17, 2019.
//signature on file//
Jessie L. Chmielowski
Chair, Commissioner
Published: May 16, 2019
s
NOTARY v
I'OSLIC
✓oaa L. NowC�o9
Colombie, Jody J (CED)
From: Mike Munger <mikemunger@circac.org>
Sent: Friday, May 31, 2019 2:31 PM
To: Colombie, Jody 1 (CED)
Subject: RE: DIO-18-004
Jody: Based on the additional information recently provided by AOGCC, I believe that there is no need from CIRCAC's
perspective, to request a public hearing regarding the West McArthur River Unit, Hemlock Undefined Oil Pool,
application for Disposal Injection Order, Docket Number:DIO-18-004. Thanks.
Michael L. Munger
Executive Director
Cook Inlet Regional Citizens Advisory Council
From: Colombie, JodyJ (CED) [mailto:jody.colombie@alaska.gov]
Sent: Friday, May 31, 2019 1:09 PM
To: Mike Munger <mikemunger@circac.org>
Subject: RE: DIO-18-004
No problem!
Jody
From: Mike Munger <mikemunger@circac.org>
Sent: Friday, May 31, 2019 1:08 PM
To: Colombie, Jody J (CED) <]ody.colombiePalaska.gov>
Subject: RE: DIO-18-004
I saw that after I read through the transcript. Sorry for the additional request.
From: Colombie, Jody J (CED)[mailto:!ody.colombie@alaska.gov]
Sent: Friday, May 31, 2019 12:54 PM
To: Mike Munger <mikemuneerC@circac.org>
Subject: RE: DIO-18-004
I sent it to you as one document.
Jody
From: Mike Munger <mikemunger@circac.org>
Sent: Friday, May 31, 2019 10:50 AM
To: Colombie, Jody 1 (CED) <iody.colombie@alaska.gov>
Subject: RE: DIO-18-004
Goc.: morning Jody- Thanks for the transcript. I also wanted a copy of the presentation if you could forward that it
would be helpful. Thanks and I hope you have a great weekend. Mike
Michael L. Munger
Executive Director
Cook Inlet Regional Citizens Advisory Council
From: Colombie, Jody J (CED)[mailto:iodv.colombie@alaska.eov]
Sent: Friday, May 31, 2019 10:36 AM
To: Mike Munger <mikemunser@circac.org>
Subject: DIO-18-004
Mike -
Per your request!
Jody J. Colombie
Special Assistant
Alaska Oil and Gas Conservation Commission
333 West 74 Avenue
Anchorage, AK 99501
(907) 793-1221 Direct
(907) 276-7542 Fax
Colombie, Jody J (CED)
From: Mike Munger <mikemunger@circac.org>
Sent: Wednesday, May 29, 2019 2:29 PM
To: Colombie, Jody J (CED)
Subject: Request for hearing: Docket Number: DIO-18-004
Importance: High
Good afternoon: On behalf of CIRCAC and our 49 member organizations, I respectfully request a public hearing
regarding the West McArthur River Unit, Hemlock Undefined Oil Pool, application for Disposal Injection Order, Docket
NUmber:DIO-18-004. There will be a CIRCAC staff member at the hearing. Thank you.
Michael L. Munger
Executive Director
Cook Inlet Regional Citizens Advisory Council
Colombie, Jody J (DOA)
0
From: Wallace, Chris D (DOA)
Sent: Thursday, May 9, 2019 3:28 PM
To: Colombie, Jody 1 (DOA)
Subject: FW: Cook Inlet Energy - DIO Application / West McArthur River Unit
Jody,
Please re -notice the hearing and we will see if either CIRI or Salamatof wish for the hearing to proceed.
Not sure if this opens a different docket or not as we closed the last hearing?
Thanks
Chris
From: Charles Underwood <cunderwood@glacieroil.com>
Sent: Thursday, May 9, 2019 12:44 PM
To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov>
Cc: George Morris <gmorris@glacieroil.com>; Heather Beat <hbeat @glacieroiLcom>; Barbara Kruk
<bkruk@glacieroil.com>; Charles Underwood <cunderwood@glacieroil.com>
Subject: Re: Cook Inlet Energy - DIO Application / West McArthur River Unit
Chris,
I have not heard anything with regard to submitting a letter of non -objection from CIRI and think that it is
going to be easier, and ultimately quicker, to go with Option #2 and re -notice the hearing.
Please initiate this process and advise whether any new information is required from Cook Inlet Energy, LLC
(Glacier Oil & Gas) to facilitate.
Regards,
Chick Underwood, RPL
GLA Consulting Landman
907.231.0329
From: Wallace, Chris D (DOA) <chris.wallace@alaska.gov>
Sent: Thursday, May 9, 2019 8:17 AM
To: Charles Underwood
Cc: George Morris; Heather Beat; Barbara Kruk
Subject: RE: Cook Inlet Energy - DIO Application / West McArthur River Unit
Charles,
Please give me an update on the progress CIE has had getting "no objection" letters from CIRI and Salamatof
as per 1. below.
AOGCC wishes to close this matter so please let me know.
Thanks and Regards,
Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West Th Avenue, Anchorage, AK 99501,
(907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.eov
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: Wallace, Chris D (DOA)
Sent: Wednesday, April 24, 2019 10:07 AM
To: Charles Underwood <cunderwood@glacieroil.com>
Cc: George Morris <gmorris@glacieroil.com>; Heather Beat <hbeat@glacieroil.com>; Barbara Kruk
<bkruk@glacieroil.com>
Subject: RE: Cook Inlet Energy - DIO Application / West McArthur River Unit
Charles,
Looking at the information provided I can now see that Glacier has defined a X mile radius around the
intersection of each well with the Hemlock (disposal zone) - whereas the AOGCC regulation requires the X
mile radius be around the entire wellbore.
The % mile radius around the whole wellbore would dictate the notification go to Salamatof and depending if
CIRI is acting as onshore operator over their subsurface rights, or if you have an agreement with CIRI for access
through their subsurface it would be beneficial to notify CIRI.
Without Salamatof and CIRI being provided a copy of the application prior to AOGCC receiving the application,
and not having normal notice of a hearing, and not being offered opportunity to testify - we have two possible
remedies.
1. CIRI and Salamatof can provide AOGCC letters stating they have been notified, waive their right to
participate in a hearing, and have no objection to the CIE disposal plans as outlined in the application.
As per 20 AAC 25.537 AOGCC can re -notice the hearing and allow the 30 day comment period, and if
no comment is received or no person lets AOGCC know within 15 days that they wish to have the
hearing, AOGCC can decide not to hold the hearing and go to issuing the order based on the
application and information we already have.
Thanks and Regards,
Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7t" 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.aov.
From: Charles Underwood <cunderwood@Rlacieroil.com>
Sent: Wednesday, April 17, 2019 9:32 AM
To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov>
Cc: George Morris <gmorris@Rlacieroil.com>; Heather Beat <hbeat@elacieroil.com>; Barbara Kruk
<bkruk@glacieroil.com>; Charles Underwood <cunderwood@alacieroil.com>
Subject: Cook Inlet Energy - DIO Application / West McArthur River Unit
Chris,
I am sending you notification that the Affidavit of Landowner Notification is going out via certified mail today
to you/AOGCC from Cook Inlet Energy, LLC for the DIO application submitted in December 2018.
Notifications are also going out to Cook Inlet Region, Inc., Salamatof Native Association, Inc., and to the State
of Alaska, Commissioners Office (Anchorage).
I have spoken with Colleen Miller at CIRI and left a voice message with Chris Monfor at Salamatof regarding
the mailings and what these entail.
Regards,
Chick Underwood, RPL
GLA Consulting Landman
907.433.3811 (o)
907.231.0329 (c)
RIE-CEIVED
APR 1 E, 7919
GLACIER
AOGCC
April 17, 2019
Via Certified Mail
Mr. Chris Wallace, Jr.
Alaska Oil & Gas Conservation Commission
333 W 7th Avenue
Anchorage, AK 99501
RE: Cook Inlet Energy, LLC
Disposal Injection Order Application; Affidavit of Notification
Dear Mr. Wallace,
Cook Inlet Energy, LLC (CIE) is submitting the Affidavit confirming notification of the nearest interest
owners and State of Alaska for the disposal activity being permitted for the West McArthur River Unit.
Also enclosed is Figure 1A that has been included with each notification letter.
The State of Alaska, Department of Natural Resources, is the only interest owner affected by the
planned disposal injection operation and this is for lease ADL 359111 held by CIE that is a part of the
West McArthur River Unit.
If you have questions or require additional information you may call me at (907) 433-3811 or contact me
via email at cunderwood@glacieroil.com.
Regards,
'�74,� It"I
Charles A. Underwood Jr., RPL
GLA Consulting Landman
Cook Inlet Energy, LLC
West McArthur River Unit
Affidavit Confirming Location of Surface
Owners and Other Operators
The proposed disposal well and bottom -hole locations where injection will take place have no other
operators or ownership identified within a one-quarter mile radius around the proposed well bores
located on the top of the Hemlock Structure in ADL 359111. Three existing West McArthur River Unit
(WMRU) wells are identified as candidate wells for conversion to produced water disposal: WMRU 1A,
WMRU 7A, and WMRU 8. Refer to Figure 1A enclosed with this notification.
The West McArthur River Production Facility, onshore, is where the produced water storage and
injection activity will commence. Salamatof Native Association (SNA), Inc. is the surface owner and the
subsurface owner is Cook Inlet Region, Inc. (CIRI). The subsurface owner at the point of disposal
offshore (Hemlock Formation) is the State of Alaska. Cook Inlet Energy has agreements with SNA and
CIRI for WMRU operations.
I, George R. Morris, as agent for Cook Inlet Energy, LLCdeclare and affirm that I have knowledge of the
matters set forth in this application and that on V114.1 Za'9 the following surface and
subsurface owners were provided a copy of this application for Underground Disposal of Oil Field
Wastes.
Cook Inlet Region, Inc.
PO Box 93330
Anchorage, AK 99509-3330
Attn: Ms. Colleen Miller
State of Alaska
Department of Natural Resources
Office of the Commissioner
550 W 7th Ave, Suite 1400
Anchorage, AK 99501-3560
George . Morris
EVP & COO
Cook Inlet Energy, LLC
Salamatof Native Association, Inc.
PO Box 2682
Kenai, AK 99611
Mr. Chris Monfor
State Of Alaska
5 u
s
ADL 359111
53 State Of
g 9 Alaska
Cook Inlet
Shoreline q
s
17 oar 6 2 15 14
West McArthur Ri it Outline - 1997-11-I n
20 21`-' 1 4W Fig 1A
22
Glacier Oil and Gas
lid,*radius wck at am Timm
Salmatof Native Association (Surface) M�'
Cook Inlet Region Inc (Subsurface)
NpvpmXri5.1018
AOGCC
2/19/2019ITMO: APPLICATION OF COOK INLET ENERGY
DIO 18-004
ALASKA OIL AND GAS CONSERVATION COMMISSION
In the Matter of the Application of Cook )
Inlet Energy for a Disposal Injection )
Order in the West McArthur River Unit )
and Redoubt Unit in the Hemlock Formation
in the West McArthur River Unit.
Docket Number DIO 18-004
PUBLIC HEARING
Anchorage, Alaska
February 19, 2019
9:00 o'clock a.m.
BEFORE: Cathy Foerster, Commissioner
Daniel T. Seamount, Commissioner
Computer Matrix, LLC Phone: 907-243-0668
135 Christensen Dr., Ste. 2., Anch. AK 99501 Fax: 907-243-1473 Email: sahile@gci.net
AOGCC 2/19/2019ITMO: APPLICATION OF COOKINLET ENERGY
DIO 18-004
Page 2
1 TABLE OF CONTENTS
2 Opening remarks by Commissioner Foerster 03
3 Testimony by Mr. Morris 06
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
Computer Matrix, LLC Phone: 907-243-0668
135 Christensen Dr., Ste. 2., Anch. AK99501 Fax: 907-243-1473 Email: sahile@gci.net
AOGCC
2/19/2019ITMO: APPLICATION OF COOK INLET ENERGY
DIO 18-004
Page 3
1 P R O C E E D I N G S
2 (On record - 9:00 a.m.)
3 COMMISSIONER FOERSTER: I'll call this hearing
4 to order. Today is February 19th, 2019. We -- it is
5 -- well, it is approximately 9:00 a.m. And we're in
6 the offices of the Alaska Oil and Gas Conservation
7 Commission at 333 West Seventh Avenue, Anchorage,
8 Alaska. To my left is Commissioner Dan Seamount and
9 I'm Commissioner Cathy Foerster.
10 We are here today in regards to docket number
11 DIO 18-004, West McArthur River Unit, Hemlock Undefined
12 Oil Pool. The application is for a disposal injection
13 order. Cook Inlet Energy by letter dated December
14 12th, 2018 requests that the Alaska Oil and Gas
15 Conservation Commission issue a disposal injection
16 order to allow the disposal of produced water from the
17 West McArthur River Unit and the Redoubt Unit in the
18 Hemlock Formation in the West McArthur River Unit.
19 This is a continuation of the hearing that
20 opened and closed on February 5th, 2019.
21 Computer Matrix will be recording today's
22 proceedings and you can get a copy of the transcript
23 from them.
24 Let's see. It appears that one and possibly
25 more than one person from Cook Inlet intends to
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1 testify. Commissioners will ask questions during the
2 testimony and we may also take a recess to consult with
3 staff to determine whether additional questions are
4 needed. And if a member of the audience has a question
5 that he or she feels should be asked please submit it
6 to Jody Colombie, float wave, and she'll provide the
7 question to the Commissioners. And if we feel that
8 asking the question will assist us in making our
9 decision we will ask it.
10 Keep in mind that you need to speak into the
11 microphone and -- so that people in the audience and
12 the court reporter can hear you. And be sure that the
13 little green light is shining. Also remember to
14 reference your slides so that someone reading the
15 public record in the future can follow along.
16 Testimony must be relevant to the purposes of
17 the hearing that I outlined a few minutes ago and to
18 the statutory authority of the AOGCC. I don't think
19 the rest of this is going to apply to you guys.
20 Commissioner Seamount, do you have anything to
21 add?
22 COMMISSIONER SEAMOUNT: Before we proceed
23 there's a preliminary matter that needs to be
24 addressed. I need to disclose as I have every time
25 I've participated in a hearing with Cook Inlet Energy
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1 or Glacier that my wife works for Cook Inlet Energy.
2 Notwithstanding that fact I feel I can make a fair and
3 impartial decision on this matter. However the
4 Commission needs to inquire whether Cook Inlet Energy
5 or anyone else present today has any objection to my
6 continued participation.
7 MR. MORRIS: We have no objection.
8 COMMISSIONER FOERSTER: Would you introduce
9 yourself for the.....
10 MR. MORRIS: Yes, my name is George Morris.
11 COMMISSIONER FOERSTER: Okay.
12 COMMISSIONER SEAMOUNT: Okay. Thank you, Mr.
13 Morris.
14 COMMISSIONER FOERSTER: Thank you. All right.
15 So I'll swear the witnesses in and since -- David, if
16 you think you might be a witness we'll just go ahead
17 and swear you in together so it makes it easy.
18 Please raise your right hand.
19 (Oath administered)
20 IN UNISON: Yes.
21 COMMISSIONER FOERSTER: Okay. And, Mr. Morris,
22 do you desire to be recognized as a witness -- I mean,
23 as a expert witness in any particular area?
24 MR. MORRIS: No, ma'am.
25 COMMISSIONER FOERSTER: Okay. Well, then
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1 please proceed with your testimony.
2 MR. MORRIS: Okay.
3 GEORGE MORRIS
4 previously sworn, called as a witness on behalf of Cook
5 Inlet Energy, testified as follows on:
6 DIRECT EXAMINATION
7 MR. MORRIS: Good morning. We have a handout.
8 COMMISSIONER SEAMOUNT: Thank you.
9 COMMISSIONER FOERSTER: Thank you.
10 MR. MORRIS: I'll give you a quick synopsis of
11 myself. Again my name is George Morris. I'm here
12 today representing Cook Inlet Energy which is a
13 operating company for Glacier Oil and Gas. I am
14 currently the chief operating officer for the company.
15 I've been with the company since 2016. I have a
16 mechanical engineering degree from Colorado State
17 University, received that degree in 1977. I have over
18 40 years of experience as an engineer, asset manager,
19 company executive.
20 I have with me today some of my team members in
21 the event we have questions and discussion and we need
22 to bring them into the discussion.
23 Cook Inlet Energy has requested that the Oil
24 and Gas Conservation Commission issue a disposal
25 injection order to allow the disposal of produced water
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1 from West McArthur River Unit and Redoubt Unit into the
2 Hemlock formation at West McArthur River Unit. We are
3 here today to review the application and address any
4 questions.
5 We have a supplementary Power Point
6 presentation that we'd like to go through to address
7 key points and explain the logic of -- behind our
8 request.
9 With that I'll start the Power Point, everyone
10 has copies.
11 Moving to page 2 of the Power Point I would
12 consider this the preamble for purpose of the
13 application. We show here on the right a locator map.
14 It is -- it is at the 10,000 foot, but it's important
15 to understand when we're talking about West McArthur
16 River which the accumulation is shown here on the map,
17 we also have to consider and understand the impact of
18 the Redoubt Unit which is currently a waterflood and
19 also our production facility of Kustatan which is the
20 Kustatan production facility.
21 West McArthur and Redoubt both flow into
22 Kustatan. Total production is processed there and
23 total production right now at Kustatan is about 1,900
24 barrels of oil a day and 4,100 barrels of water a day.
25 That's the sum of the two fields together. In part
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1 West McArthur River currently produces 600 barrels of
2 oil a day and 2,800 barrels of water per day. We're at
3 83 percent water cut coming out of the reservoir. And
4 the key point here is our production is curtailed
5 because of our water handling limitations which is why
6 we're here. If we were uncurtailed at West McArthur we
7 could easily produce around a thousand barrels of oil a
8 day and up to 5,000 barrels of water per day.
9 All water in -- is handled through Kustatan and
10 then back to Redoubt Unit which is a waterflood. At
11 Redoubt Unit we inject water for the waterflood and
12 then what's left over we dispose of it. The Redoubt
13 Unit injection for the waterflood is currently at
14 capacity as is our disposal at capacity.
15 And again what we're seeking today is a permit
16 to dispose of excess produced water into that Hemlock
17 formation at West McArthur River Unit.
18 Moving to page 2, a little bit of history and
19 overview of the field. West McArthur River was
20 discovered in 1975 with the initial well drilled by
21 Inexco. A second exploratory well was drilled in 1991
22 by Stewart. Initial production started in 1991 from
23 the Hemlock formation. This property has passed
24 through multiple hands. Today Cook Inlet Energy, a sub
25 of Glacier Oil and Gas owns the property at 100 percent
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1 working interest. Our only royalty owner is the State
2 of Alaska.
3 Most significantly in recent history we have
4 the consolidation of West McArthur River to the
5 Kustatan facility which occurred in 2016. In doing
6 that all production is now processed at Kustatan. We
7 shut down at the time West McArthur had an artificial
8 lift system which was a power oil driven jet pump
9 artificial lift system. It had become antiquated, it
10 was a safety hazard and also an environmental hazard.
11 We shut that down and cleaned it up. In the process we
12 worked over four wells and converted them to ESP
13 artificial lift, a much cleaner artificial lift system.
14 Today West McArthur functions only as a satellite pad
15 producing to KPF, Kustatan. Cumulative production to
16 date from West McArthur is a little over 15 million
17 barrels of oil, 3.9 BCF and almost 26 million barrels
18 of water have been produced through West McArthur.
19 Historically 14 wells have been drilled. Currently we
20 have three wells on production, four producing wells
21 that are currently shut-in and we have one class I
22 disposal well known as the 4D.
23 COMMISSIONER FOERSTER: Have the other six
24 wells been plugged and abandoned?
25 MR. MORRIS: All the remaining wells have been
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1 plugged and abandoned already. There are no unattended
2 wells other than what are listed here.
3 COMMISSIONER FOERSTER: Other than the four
4 shut-in producers?
5 MR. MORRIS: Yes, ma'am.
6 COMMISSIONER SEAMOUNT: It's funny when I
7 worked at Unical we -- Unical thought there was only
8 one and a half million barrels there and Unical
9 wouldn't take it over.
10 COMMISSIONER FOERSTER: And do you have plans
11 for the four shut-in producers?
12 MR. MORRIS: I didn't.....
13 COMMISSIONER FOERSTER: Do you have plans for
14 the four shut-in producers?
15 MR. MORRIS: Yes, ma'am. The -- three of the
16 four shut-in producers are wells that are contained
17 within the request. We would like to convert one or
18 all of them to the disposal -- to become disposal
19 wells. Given the ability to produce more and handle
20 more water we would put one of these wells back on
21 production and that would be the number 5 well.
22 The next slide is a little bit more detailed
23 about each of the wells. The key points here are the
24 1, the 4D, 5, 7 and 8 are the shut-in wells and then it
25 shows the current production rate and the current water
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1 cut of the three producing wells. At the time the
2 number 5 was shut-in it was also producing at about an
3 85 percent water cut. What we show here is the sum of
4 the current curtailed production rates. You see we're
5 almost at the 600 barrels of oil a day and 2,700, 2,800
6 barrels of water a day and if we were uncurtailed we
7 could achieve a thousand barrels of oil a day and 5,000
8 barrels of water a day.
9 Shown on the sheet is also the Redoubt field
10 production which is four producing wells on ESP. We're
11 currently producing just under 1,300 barrels of oil a
12 day and just under 1,300 barrels of water a day at a 47
13 percent water cut. This field is being flooded with
14 the same Hemlock water that we want to dispose of. The
15 Redoubt field current injection capacity for the
16 waterflood is 3,950 a day and then the excess which
17 totals 250 in this case, we put into the Redoubt class
18 I disposal well 250 barrels of water a day.
19 The point on this slide is we are
20 underproducing by over 400 barrels of oil a day because
21 of our current constraint which is the problem we're
22 working to solve.
23 Moving to slide number 5 let's talk for a
24 minute about the geology and reservoir
25 characterization. At West McArthur River Unit we do
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1 want to dispose of the water into the Hemlock
2 formation. The Hemlock formation is a Oligocene aged
3 sequence of braided stream deposits. In the field here
4 we're looking at a Hemlock section of four to 500 feet
5 thick with the top of structure being around 9,000
6 feet. We have within the four to 500 feet we have
7 reservoir and nonreservoir facies. Reservoir facings
8 are 7 to 18 percent porosity and 100 to 300
9 millidarcies permeability. It's very good rock.
10 Layered in between we do have nonreservoir facies of
11 siltstones, claystones and coal, basically impervious
12 nano permeability and almost no porosity.
13 On the next two slides we will look at some
14 geologic structure map and I will note the select
15 faults that cut the Hemlock within the main fault block
16 they do not seal. And I'll point those out. The --
17 you know, we have the trapping faults, I'll point those
18 out, but the interior faults to the field do not seal.
19 This is a fairly strong water drive reservoir.
20 Initial pressure at 4,095 PSI and most recently we have
21 a pressure of 3,345 taken out of one of the shut-in
22 producing wells. A difference of about 750 pounds
23 after 14.7 and 24.7 million barrels of fluids have been
24 taken out of the reservoir. So it's a pretty strong
25 reservoir for a waterdrive. That difference, 750
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1 pounds, is more likely -- more likely seen because the
2 single well we took the pressure from is among the
3 other producing wells and so there's a current pressure
4 sink (ph). If we shut-in the whole field I would
5 expect it would approach initial reservoir pressure in
6 a short period of time.
7 I would note that the 14.7 million barrels of
8 oil and the 24.7 million barrels of water coming from
9 the main fault block do not include the Sword
10 production which is the fault to the north. I'll point
11 that out on the next slide.
12 Moving to page 6, here we have a structure map
13 on the top of the Hemlock formation. You'll note in
14 the map I've designated the faults FA, FB, FC, FD and
15 FE. The faults are in green. The well numbers are in
16 blue starting with the Sword number 1 to the north.
17 That would be right here. Coming down you see 8, 6, 5,
18 213, 7A and well number 1. The green circles closed in
19 denote the wells TD on the map. The clear, black
20 circles are shut-in producers and again denote the
21 well's TD. You know, for example on well number 8 you
22 see the circle is fault, the well TD'd below the fault.
23 COMMISSIONER FOERSTER: So is that one clear or
24 green for that one? That was.....
25 MR. MORRIS: It should be clear.....
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1 COMMISSIONER FOERSTER: Clear.
2 MR. MORRIS: .....as well as shut-in.
3 COMMISSIONER FOERSTER: Yeah.
4 MR. MORRIS: Looking -- looking to the north
5 I'll just mention this is the Sword trap. Showing well
6 number 1 it trap up -- it traps against the FA fault
7 which is the sealing fault about two to 300 foot of
8 throw in this fault. Going further, I will not focus
9 on this area as what we are most interested in is the
10 main fault block to the south that traps behind the FB
11 fault which is also a sealing fault with, you know, at
12 least 500 feet of throw across that fault.
13 Let me move to the next slide, next page. This
14 slide focuses in more on the main fault block. Key
15 points here, we also -- we also point out the faults by
16 name as on the previous page, but also you see a black
17 box on the well path of each well. This is the -- this
18 represents the penetration point of that well at this
19 structural depth.
20 Starting with fault B, we just mentioned that
21 it had 500 feet of throw and it is a sealing fault.
22 The FC fault does not seal and has probably 100 to less
23 than 100 foot of throw across it. Again our section is
24 four to 500 feet with juxtapose sand on sand. You
25 know, historically this fault has never sealed. The FD
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1 fault to the south has even less throw, less than a
2 hundred feet of throw. Again juxtapose position, sand
3 on sand, the fault does not seal. Both of these faults
4 -- I failed to mention the FC fault dies out at the
5 shallower depth around 6,000 to 6,300 feet. The FD
6 fault dies out around 8,000 feet as you look at it
7 coming to the -- up. Then we have the F3 -- FE fault
8 which is -- I would call it a -- somewhat like a
9 scissor fault. The FE fault has almost no throw where
10 it intersects with fault FB and then as you -- as this
11 runs out and soles (ph) out at depth, it probably has a
12 hundred to 200 feet of throw, well below the Hemlock
13 into the west (indiscernible).
14 I'll also use this map to point out the three
15 wells that we are proposing to convert to disposal
16 wells. We have the number 8 shown here on the west
17 side of fault FE, and then we have wells lA and 7A
18 shown here to the south in the main fault block.
19 We'll move now to page 8. We have a statement
20 on the geologic confining intervals that would confine
21 the fluids that we are injecting into the Hemlock
22 formation. First things first I'd like to talk about
23 the West McArthur River Unit 4D well which is our
24 permitted class I disposal well. This well disposes
25 into the Tyonek formation. We have perforations -- 300
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1 foot of perforations starting at about 4,944 tvd
2 subsea. This well has -- had up to 13,500,000 barrels
3 of water injected into it through its life. There's
4 3,700 feet of separation between where we're disposing
5 of water in the 4D and the top of the Hemlock. That
6 3,700 feet is made up of the silts, the sands, the
7 shales and the coals and in itself should create a
8 barrier between where we will inject into the Hemlock
9 and any of the shallow -- shallower sands.
10 Additionally 2 wanted to point out that in the
11 EPA permit the EPA permit defines confining zones, an
12 upper confining zone above our disposal area at 4,228
13 to 4,295, considered impervious, protecting all of the
14 shallow sands above. Just below that there's another
15 buffer zone at 4,295 to 4,384. And then below that the
16 EPA permit defines a lower confining zone at 5,431 to
17 5,511. All of this points to if we're disposing of
18 water into the Hemlock, if we feel that, you know,
19 there should be no -- no ability for that water to
20 migrate up.
21 I'll point finally here point to the West
22 McArthur 4D well is currently shut-in. We shut-in this
23 well when we did the reconsolidation to Kustatan.
24 Moving to slide number 9, a comment on the
25 mechanical integrity of the three wells we want to
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1 consider for use as disposal wells, the West McArthur
2 River 8, the lA and the 7A well. These are our
3 proposed disposal candidates. All three wells are
4 currently shut-in as depleted producers.
5 COMMISSIONER FOERSTER: When you say depleted
6 do you mean watered out?
7 MR. MORRIS: Yes. Yes, they were all -- well,
8 I'll take you through individually. The number 8 well
9 was never -- it -- I don't know that that side of the
10 fault is just very tight or that well was heavily
11 damaged. That well was never a good producer compared
12 to the wells on the east side of the fault. The number
13 8 well when we took it off production was making 20
14 barrels a day and just did not produce.
15 COMMISSIONER FOERSTER: So are you planning any
16 stimulation to try to.....
17 MR. MORRIS: Well.....
18 COMMISSIONER FOERSTER: .....get injectivity in
19 that well?
20 MR. MORRIS: .....you know, with approval and
21 the -- if the well -- first let's make sure the well
22 passes all the MIT testing.....
23 COMMISSIONER FOERSTER: Uh-huh.
24 MR. MORRIS: .....you know, we would -- and
25 it's my last statement on this slide. You know, we
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1 want to do an injectivity test of all three wells to
2 determine their capabilities for injection.
3 Mechanically the number 8 is the youngest well and
4 mechanically the number 8 would be the best candidate.
5 But if the number 8 won't take any water for disposal
6 then it's no good to me. And so we need to do an
7 injectivity test on all three wells to see if -- to see
8 if they'll work.
9 COMMISSIONER FOERSTER: All right. And the lA
10 and the 7A are they watered out?
11 MR. MORRIS: Yes, the sec -- the Al and the 7A,
12 both of them watered out in 95 percent water cut.
13 COMMISSIONER FOERSTER: Okay. Thank you.
14 MR. PASCAL: Just to add to West (indiscernible
15 - simultaneous speech).....
16 COMMISSIONER FOERSTER: Well, introduce
17 yourself for the record.
18 MR. PASCAL: I'm David Pascal, VP operations,
19 Glacier Oil and Gas. Just to answer your question of
20 West Bank 8. West Bank 8 was drilled in 2014 I believe
21 and it was a low oil cut producer with high water
22 cuts. And Cook Inlet Energy did do a simulation job
23 on a mechanical simulation which didn't work.
24 COMMISSIONER FOERSTER: Thank you.
25 MR. MORRIS: Finishing up on slide 9 I'll just
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1 make these quick statements. All three wells for
2 consideration were drilled, cased and cemented as per
3 the regulations. And all three wells, you know, are
4 currently equipped with tubing and packers and tubing
5 design criteria that exceed the regulations that are
6 required for them to be an injection well. And so they
7 meet the requirements from that side of the fence. We
8 just need to see if they'll -- if they'll work out for
9 us.
10 Moving to page 10, fluids and disposal. We
11 intend to dispose of excess produced water into the
12 Hemlock formation. The Hemlock and a little bit of
13 Tyonek water is produced at West McArthur Sword and
14 Redoubt. Due to the water being Hemlock in general we
15 feel there's no compatibility issues. We're basically
16 putting the same water back into the reservoir that it
17 came out. Fresh water exemption is not applicable
18 because of the Hemlock not being a fresh water
19 interval.
20 Discussing the maximum surface pressure for
21 disposal will limit that to 4,000 PSI. We looked at
22 FIT and -- or formation integrity tests and leak off
23 tests above and below the Hemlock and calculated a frac
24 gradient in excess of a .86 PSI per foot. And so in
25 calculating the 4,000 PSI I've used the .86 which is
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1 less than frac gradient.
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2 We're run through this fairly quickly. This
3 brings us -- brings us to the end of our Power Point
4 presentation. We're requesting permission, requesting
5 that the Oil and Gas Commission issue a disposal
6 injection order to allow us to dispose of the Hemlock
7 produced water into the Hemlock reservoir.
8 COMMISSIONER FOERSTER: Thank you. And thank
9 you for being very diligent about referring to the
10 slides by number. That will be helpful to people in
11 the future.
12 Commissioner Seamount, do you have any
13 questions?
14 COMMISSIONER SEAMOUNT: Yes. You say that West
15 McArthur River has a strong water drive and does that
16 -- I guess you don't have any enhanced recovery
17 operations there then, right?
18 MR. MORRIS: No, sir.
19 COMMISSIONER SEAMOUNT: Okay. So that's why
20 you're not asking for an area injection order, you're
21 asking for a disposal injection order?
22 MR. MORRIS: Yes, sir.
23 COMMISSIONER SEAMOUNT: It's totally compatible
24 because it's the same water you're pulling out, right?
25 MR. MORRIS: Yes, sir.
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8
Page 21
1 COMMISSIONER
SEAMOUNT:
I guess that's logical.
2 COMMISSIONER
FOERSTER:
Okay. Well, along.....
3 COMMISSIONER
SEAMOUNT:
Thank you.
4 COMMISSIONER
FOERSTER:
.....along the same
5 lines. Would you pull
the page
7 structure map back
6 up? Okay. So fault
FE, is it
-- you said it was not
7 sealing?
FOERSTER: Okay.
14
8
MR. MORRIS:
Fault FE, this is the engineer
9
talking,
I would consider
it a scissor fault. As fault
10
FE approaches fault FB
it dies out.....
11
COMMISSIONER
FOERSTER: Okay.
12
MR. MORRIS:
.....it has no throw.
13
COMMISSIONER
FOERSTER: Okay.
14
MR. MORRIS:
As fault FE runs away.....
15
COMMISSIONER
FOERSTER: Okay.
16
MR. MORRIS:
.....it scissors into greater
17
throw.
But again through
the section that we're
18
looking
at it's still
juxtaposed.
19
COMMISSIONER
FOERSTER: Okay. So 1A, 7A and 8,
20
are they
-- are they
all below where you think the
21
current
water contact
is?
22 MR. MORRIS: In a 83 percent water cut the
23 water contact is -- you know, I don't think we have an
24 established water cut anymore, we're just -- we're just
25 running fluid through the reservoir and sweeping --
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2/19/2019ITMO: APPLICATION OF COOK INLET ENERGY
DIO 18-004
Page 22
1 sweeping oil as we go. The orig -- there was -- there
2 was no original water content found in this reservoir.
3 We had a lowest -- historically this is what I've
4 determined. We have mapping that go -- that will go
5 down to highest known water and we have mapping that
6 goes to lowest known oil. So the oil water contact is
7 in that swath somewhere. And so all of our reserve
8 calculations are based on those maps.
9 COMMISSIONER FOERSTER: Uh-huh.
10 MR. MORRIS: In fact, anymore I'm looking at
11 the maps that show highest known water because we've
12 recovered in the high 30s, high 30 percent, 36 percent
13 of the oil in place so far down to highest known water.
14 COMMISSIONER FOERSTER: So where -- where was
15 that swath originally of lowest known oil and highest
16 known water?
17
MR. MORRIS:
A good --
a good number right now
18
would be highest known water
was around 9,500 feet.....
19
COMMISSIONER
FOERSTER:
Okay.
20
MR. MORRIS:
.....and
lowest known oil was set
21
up by the original wells. I
would -- I'd have -- I'd
22
have to go look, but
I would
say around 9,200 feet.
23
COMMISSIONER
FOERSTER:
Okay. So somewhere
24
between 92 and 9,500
was your
water contact?
25
MR. MORRIS:
Was the
water -- original water
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1 contact.
2/19/2019ITMO: APPLICATION OF COOK INLET ENERGY
DIO 18-004
Page 23
2
COMMISSIONER
FOERSTER:
Original water contact.
3
And lA and 7A and 8 are all below
9,200 feet so they're
4
in that -- all in that swath?
MR. MORRIS:
5
MR. MORRIS:
Yes.
COMMISSIONER
6
COMMISSIONER
FOERSTER:
Okay.
7
MR. MORRIS:
And lA and
7A both watered out in
8
excess of 95 percent
water cut
at the time they were
9
taken off production.
21
to be disposing into
10
COMMISSIONER
FOERSTER:
And 8 is lower on
11
structure than.....
23
MR. MORRIS:
12
MR. MORRIS:
And 8 is
lower structurally on
13
the.....
25
MR. MORRIS:
14
COMMISSIONER
FOERSTER:
.....down
15
(indiscernible) side?
16
MR. MORRIS:
.....west
side of that fault.
17
COMMISSIONER
FOERSTER:
Okay. Okay. You know
18
what I'm getting at.....
19
MR. MORRIS:
Yes.
20
COMMISSIONER
FOERSTER:
.....you're not going
21
to be disposing into
an area that's
going to create
22
waste of.....
23
MR. MORRIS:
No. No,
in fact.....
24
COMMISSIONER
FOERSTER:
.....hydrocarbons?
25
MR. MORRIS:
.....if I
can dispose of more
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2/19/2019ITMO: APPLICATION OF COOK INLET ENERGY
DIO 18-004
Page 24
1 water then I can basically flush more fluids through
2 and recover more oil. It enhances -- being able to
3 recover and dispose of more water enhances my ability
4 to deplete the reservoir more effectively.
5 COMMISSIONER FOERSTER: Okay. Okay. That --
6 that answered my question. I'm going to look to the
7 back of the room and see if staff nods their heads up
8 and down wanting a recess or nods their heads left and
9 right saying I've got all my information.
10 (No comments)
11 COMMISSIONER FOERSTER: Nobody.....
12 COMMISSIONER SEAMOUNT: No response.
13 COMMISSIONER FOERSTER: This means we're fine,
14 this means we need a recess.
15
UNIDENTIFIED
VOICE: Take a recess.
16
COMMISSIONER
FOERSTER:
Okay. All
right.
17
We're going to recess
at 9:37.
Five minutes.
18
(Off record)
19
(On record)
20
COMMISSIONER
FOERSTER:
All right.
We're back
21
on the record at 9:46.
22
Commissioner
Seamount,
do you have
any
23
questions?
24
COMMISSIONER
SEAMOUNT:
Yes. Mr.
Morris, do
25
you have a geologist
on staff
now?
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AOGCC
2/19/2019ITMO: APPLICATION OF COOK INLET ENERGY
DIO 18-004
Page 25
1 MR. MORRIS: Yes, we do.
2 COMMISSIONER SEAMOUNT: Okay. Who would that
3 be?
4 MR. MORRIS: Heather Beat, senior geologist.
5 COMMISSIONER SEAMOUNT: Oh, you're a geologist.
6 Okay. Nice to meet you.
7 Okay. I've got a geological question. Is
8 there a permeability trend like.....
9 COMMISSIONER FOERSTER: Directional you mean?
10 COMMISSIONER SEAMOUNT: .....the directional
11 permeability, is it like north, west, south, east or is
12 there one, is it -- or is it just a blob?
13 MS. BEAT: This is Heather Beat. I am unaware
14 if there is a permeability trend. We do know that
15 deposition has a depositional trend from the northwest
16 to the southeast.
17 COMMISSIONER SEAMOUNT: Okay.
18 MS. BEAT. So potentially there could be a
19 permeability trend there, but.....
20 COMMISSIONER SEAMOUNT: Okay. And sometimes
21 the trend is along the access of the anticline too. So
22 I guess it would be hard to tell, right?
23 MS. BEAT: It would. The faulting could lead
24 to changes in permeability trends as well.
25 COMMISSIONER SEAMOUNT: Okay. And is there any
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DIO 18-004
Page 26
1 concern that injecting into well number 8 would disrupt
2 the reservoir since it's sort of higher on the
3 structure?
4 COMMISSIONER
FOERSTER: It's
lower.
5 COMMISSIONER
SEAMOUNT: Huh?
It's hard to say because of that
6 COMMISSIONER
FOERSTER: It's
lower.
7 COMMISSIONER
SEAMOUNT: Oh,
it's lower.
8 MR. MORRIS:
It's almost --
it's almost flat
9 right there.
16
10
COMMISSIONER
FOERSTER: That was.....
11
MR. MORRIS:
It's hard to say because of that
12
fault.
13
COMMISSIONER
SEAMOUNT: But -- yeah, but it's
14
-- okay. You were saying that 8 had some permeability
15
problems, correct?
16
MR. MORRIS:
Yes.
17
COMMISSIONER
SEAMOUNT: Okay. So.....
18
MR. MORRIS:
I would -- I would surmise that
19
well number 6, well
number 5 and well number 213 which
20
are all at about an
83 percent water cut, I do not
21
think that injecting
water into well number 8 would
22
significantly impact
these wells. Two reasons. First
23
things first, our --
our volume of water, incremental
24
water to inject here
is probably not that great at
25
2,000 barrels a day.
We're not going to -- it's not
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2/19/2019ITMO: APPLICATION OF COOK INLET ENERGY
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Page 27
1 like we were going to put in 10,000 barrels a day and
2 reestablish a pressure pull pushing in the direction of
3 the -- of the pressure sink. Plus the number 8 has had
4 some permeability issues. I don't think we'll get to
5 2,000 barrels a day in that well.
6 COMMISSIONER SEAMOUNT: Is it possible you
7 could improve production by injecting into 8?
8 MR. MORRIS: If the -- again at the high water
9 cut that we're at right now and the fact that, you
10 know, we really don't have that much of a pressure
11 sink, I don't see that we would -- we would see a -- as
12 in a waterflood, I don't think that we would see an oil
13 kick from injecting into the number 8 well.
14 COMMISSIONER SEAMOUNT: Okay. Thank you.
15 That's all I have.
16 COMMISSIONER FOERSTER: Your D1 well is
17 currently taking 250 barrels of water a day.....
18 MR. MORRIS: Yes.
19 COMMISSIONER FOERSTER: .....about.....
20 MR. MORRIS: Yes.
21 COMMISSIONER FOERSTER: .....and is that
22 capacity?
23 MR. MORRIS: That is a capacity that we have
24 self-limited. We had some trouble with the D1 well mid
25 year last year and -- and at that time we were putting
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17 UNIDENTIFIED VOICE: (Indiscernible - away from
18 microphone).....
lg COMMISSIONER FOERSTER: I'm not going to put
20 you on the spot, I was just teasing. But if you want
21 to say something come on up.
22 UNIDENTIFIED VOICE: No, no, no.
23 (Indiscernible - away from microphone).....
24 COMMISSIONER FOERSTER: Oh, of the mechanical
25 engineering?
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Page 28
1
more fluid into it. This is our
only class I disposal
2
well and if we lose this well we
are in deep trouble.
3
And so to that end we've cut it
back to something in
4
the range of a maximum 250 barrels
of fluid a day.
5
COMMISSIONER FOERSTER:
Okay. All right. And
6
if we put a rule into the order
that requires any
7
conversion to receive approval through
a sundry
8
process, is that going to cause
you any problems?
g
MR. MORRIS: No, ma'am.
10
COMMISSIONER FOERSTER:
Okay. Any other
11
questions?
12
COMMISSIONER SEAMOUNT:
That's it.
13
COMMISSIONER FOERSTER:
All right. I have no
14
other questions either. And is
there anyone in the
15
audience, maybe a UAA student who
has anything he wants
16
to say?
17 UNIDENTIFIED VOICE: (Indiscernible - away from
18 microphone).....
lg COMMISSIONER FOERSTER: I'm not going to put
20 you on the spot, I was just teasing. But if you want
21 to say something come on up.
22 UNIDENTIFIED VOICE: No, no, no.
23 (Indiscernible - away from microphone).....
24 COMMISSIONER FOERSTER: Oh, of the mechanical
25 engineering?
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AOGCC
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UNIDENTIFIED VOICE: (Indiscernible - away from
microphone).....
COMMISSIONER FOERSTER: Okay. Well, then if
there's nothing else for the good of the order for this
subject then we will adjourn at 9:51.
MR. MORRIS: Thank you very much.
COMMISSIONER SEAMOUNT: Thank you.
(Hearing adjourned - 9:51 a.m.)
(END OF PROCEEDINGS)
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Page 3 0 1
TRANSCRIBER'S CERTIFICATE
I, Salena A. Hile, hereby certify that the
foregoing pages numbered 02 through 30 are a true,
accurate, and complete transcript of proceedings in
Docket Number DIO 18-004, transcribed under my
direction from a copy of an electronic sound recording
to the best of our knowledge and ability.
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NAME
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Docket Number: DIO-18-004
West McArthur River Unit, Hemlock Undefined Oil Pool
The application for Disposal Injection Order
February 19, 2019 at 9:00 am
AFFILIATION
Testify (yes or no)
GLACIER Glacier Oil &Gas Corp
West McArthur River Unit
Hemlock Undefined Oil Pool
Application for Disposal Injection Order
Docket Number: DIO-18-004
Supplemental 'Testimony to Application
2/19/2Q19
Oe
GLACIER Purpose for Application
• West McArthur River Unit (WMRU) and
Redoubt Unit (RU) produce through Kustatan
Production Facility (KPF)
• Total production from both fields is —1900
BOPD and 4100 BWPD
• WMRU current production 600 BOPD and
2800 BWPD
• Water cut - 83%
• Production is curtailed due to water handling
limitations
• Un -curtailed WMRU production ^'1000+ BOPD
and 5000+ BWPD
• All produced water is injected at RU
• Waterflood support
• Disposal
• RU is operating at injection capacity
• Cook Inlet Energy (CIE) is seeking a permit to
dispose of excess produced water via disposal
into the Hemlock Formation at WMRU
GLACIER WMRU Overview
• WMRU Discovered — 1975
• Discovery Well: Inexco Oil Co — West McArthur River Unit 1
• Second exploration well (1991): Stewart Petroleum — West McArthur River Unit 1
• Initial Production: 1991 from Hemlock Formation
• Cook Inlet Energy (Glacier Oil & Gas) — 100% W.I.
• WMRU — KPF Consolidation: 2016
• All production processing moved from WMRU to KPF
• Shut down Jet Pump artificial lift system
• Converted 4 wells to ESP artificial lift
• WMRU functions as satellite pad producing to KPF
• Cumulative Production (Through 12/2018)
• 15.4 M M BO
• 3.9 BCF
• 25.9 MMBW
• Historical total of 14 wells
• Current well status
• 3 Producers (26, 6, Sword)
• 4 SI Producers (1A, 5, 7A, 8)
• 1 Class I Disposal (4D)
WMRU Well Status, Rates, & Capacities
GLACIER
We I I
Status
WMRU #1A
Shut -In [12/2012]
WMRU #2B
Producing - ESP
WMRU #413
Shut -In Class 1 Disposal [9/2017]
WMRU #5
SI -ESP [10/2018]
WMRU #6
Producing - ESP
WMRU #7A
Shut -In [1/2011]
WMRU #8
Shut -In [4/2016]
Sword #1
Producing - ESP
Curtailed Production Rate
Un -Curtailed Production Rate
RU Field Production 4 Producing Wells - ESP
RU Field Injection Water -flood Capacity
RU Water Disposal D1 Class 1 Disposal
Total water Disposal/Injection Cap
BOPD BWPD Water Cut Remarks
212 1054 83% Curtailed
Cum Injection 13.5 MM BW
Curtailed-- SI 10/2018
155 739 83% Curtailed
219 996 82% Curtailed
586 2789
-1000 -5000
1274 1247
3950
250
4200
49%
GLACIER WMRU Geology & Reservoir Characterization
• Disposal will occur into the Hemlock Formation
• Hemlock Formation — Oligocene -aged sequence of braided stream deposits
• In area of interest, 400'-500' thick, with shallowest point around 9000' TVDSS
• Hemlock Formation consists of interbedded lithologies (Reservoir and Non -
Reservoir)
• Reservoir Facies — Sandstones
• 7-18% porosity
• 100-300md permeability
• Non -Reservoir Facies — Siltstones, Claystones, and Coals
• 1-4% porosity
• Nano -permeability
• Faults that cut Hemlock Formation
• Non -sealing due to juxtaposition of Hemlock against Hemlock
• Strong water -drive reservoir
• 4095psi - initial reservoir pressure
• 3345psi — current reservoir pressure
• 14.7 MMBO and 24.7 MMBW main fault block cumulative production
WMRU Current Wells
GLACIER
FA <
I FB
.10`
.9700
FC
1
cD
O /
9600 FD
-9?0p /
900 , 93 9poo OO�
o ^O
o a o
FE
0
a
0
Glacier Oil and Gas
West MCAMh.r River Unit
Hembck Srmnure Mep
0 0.44
MILES
WELL SYMBOLS
• Oil Wo
Suspended Well
S Nlw Well
reerue, 12. 2018
WMRU Current Well Hemlock Penetration Point
GLACIER
FB
9i0
0
N
/ n
FC
59
. on
1�
0
FD
n
o
1
FE •ZA o
00
a
-9600
0
0
`9joo 00
a`D
9B0
Glacier Oil and Gas
West McArthur River Unit
hembck Slmclme Mao
1.
0 0.2
MIS
WELL SYMBOLS
• ORWO
SueGeooee Well
Hemlock Penetration Point
FeEruery 12.2018
Potential Disposal Wells
WMRU 1A
WMRU 7A
WMRU 8
7
00,
GLACIER WMRU Geologic Confining Intervals
• Current EPA Permitted Class I Disposal - WMRU 4D
• Disposal into Upper Tyonek Formation
• Over 300' of perforations starting at 4944' TVDSS
• 13.5 MMB cumulative injection
• 3700' separation between lower extent of disposal into Tyonek and the
Hemlock Formation
• Separation consists of alternating sandstones, siltstone, claystones, and coals
• EPA defined containment barriers above and below injection interval
• Upper confining zone considered impervious — 4228'-4295' TVDSS
• Upper confining zone buffered by an arresting zone — 4295'-4384' TVDSS
• Lower confining zone beneath injection interval — 5431'-5511' TVDSS
• The stratigraphic character of these confining zones correlate with other
offset well in the surrounding area
9 WMRU 4D SI when field was consolidated in 2016
GLACIER
Proposed Disposal Well — Mechanical Integrity
• WMRU 8, 1A, and 7A — Proposed disposal well candidates
• All 3 wells are currently SI depleted producers
• Drilled, cased, and cemented as per 20. AAC 25.030
• Equipped with tubing and packers as required by 20 AAC 25.412 (b)
• Equipped with tubing that exceeds the requirements of 20 AAC 25.412 (b)
• All 3 wells have Hemlock perforations that are isolated by the existing
completion
• CIE requires a MIT and injection test to confirm feasibility of utilization for
water disposal
4 Fluid and Disposal
GLACIER
• CIE intends to dispose excess produced water into the Hemlock
Formation
• Hemlock and Lower Tyonek produced water from WMRU wells, Sword, and RU
wells
• Due to produced water being from the Hemlock and disposal occurring into the
Hemlock, water compatibility will not be an issue
• Water analysis reports verify this
• Freshwater exemption is not applicable due to the Hemlock not being a
freshwater interval
• Measured Total Dissolved Solids-27,600mg/L in Sword 1
• Maximum surface pressure for disposal will be limited to 4000psi
• Fracture gradient greater than 0.86psi/ft based on multiple in -field FIT and LOT
above and below the Hemlock Formation
• Surface pressure of or less than 4000psi will ensure we do not fracture the
Hemlock Formation
Conclusions
GLACIER
Cook Inlet Energy is requesting the Alaska Oil and Gas
Conservation Commission issue a Disposal Injection Order (DIO-
18-004) to allow for disposal of produced water from West
McArthur River Unit and Redoubt Unit into the Hemlock
Formation at West McArthur River Unit.
GLACIER
Appendix
WMRU Potential Disposal Well Area of Interest
GLACIER
0
77
�I
i \
y� /
f 1 p
o� I
F95Q
` 900p�` 1O
Glacier Oil and Gas
West MWtlher River Und
6amw suvcn•e Aiao
0 0.16
MILES
WELL SYMBOLS
• OdWM
SHMbM WO
s. re wee
Fe , 12.1018
Area of Interest
Quarter mile radius
GLACIER OIL AND GAS
FACILITY & PIPELINE SCHEMATIC
GLACIER
oiL a GAS
CIGGS
PIPELINE
KFFe• reeotalm rum
���-A• AOOIX® TAM
9.9ee' I 10.420'
1o.eoe
f rt orae
400'
um-WOO
oo
� YOODOQD eSAMN ULT' -L200 CIPL,
----
LLvnDn
IAM -f
E
� IACf-IZ
g 3
�rt 7M
c -"PAD
•
1
b
,PEST
FORELAND
C
PAD
•
�
I
+ ',
n 'raj s..n
KFFe• reeotalm rum
���-A• AOOIX® TAM
9.9ee' I 10.420'
1o.eoe
AOGCC
2/5/2019 ITMO: APPLICATION OF COOK INLET ENERGY
DIO 18-004
ALASKA OIL AND GAS CONSERVATION COMMISSION
In the Matter of the Application of Cook )
Inlet Energy for a Disposal Injection )
Order in the West McArthur River Unit )
and Redoubt Unit in the Hemlock Formation
in the West McArthur River Unit.
Docket Number DIO 18-004
PUBLIC HEARING
February 5, 2019
10:00 o'clock a.m.
BEFORE: Cathy Foerster, Commissioner
Daniel T. Seamount, Commissioner
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AOGCC 2/5/2019ITMO: APPLICATION OF COOK INLET ENERGY
DIO 18-004
Page 2
1 TABLE OF CONTENTS
2 Opening remarks by Commissioner Foerster 03
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
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2/5/2019 ITMO: APPLICATION OF COOK INLET ENERGY
DIO 18-004
Page 3
1 P R O C E E D I N G S
2 (On record)
3 COMMISSIONER FOERSTER: Okay. I'll call this
4 hearing to order. Today is February 5th, 2019, it's
5 10:00 a.m. We're located at 333 West Seventh Avenue,
6 Anchorage, Alaska, the offices of the Alaska Oil and
7 Gas Conservation Commission. To my left is
8 Commissioner Dan Seamount and I'm Commissioner Cathy
9 Foerster.
10 We're meeting in regard to docket number DIO
11 18-004, West McArthur River Unit, Hemlock River
12 Undefined Oil Pool application for a disposal injection
13 order. Cook Inlet Energy by letter dated December
14 12th, 2018 requests the AOGCC issue a disposal
15 injection order to allow disposal of produced water
16 from the West McArthur River Unit and Redoubt Unit in
17 the Hemlock Formation in the West McArthur River Unit.
18 Computer Matrix will be recording today's
19 proceedings and you can get a copy of the transcript
20 from them.
21 I don't see anyone signed up to testify. Do I
22 have an incomplete?
23 (No comments)
24 COMMISSIONER FOERSTER: Is anyone from Cook
25 Inlet planning to present the data in your application?
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2/5/2019 ITMO: APPLICATION OF COOK INLET ENERGY
DIO 18-004
Page 4
1 MR. RADCLIFF: We're not planning to.
2 COMMISSIONER FOERSTER: I think we need to take
3 a recess so I can ask our Assistant Attorney General
4 how we proceed since a hearing is required for a
5 disposal injection order and it's expected that the
6 applicant will present.
7 All right. We're going to recess at 10:02.
8 (Off record)
9 (On record)
10 COMMISSIONER FOERSTER: All right. We're back
11 on the record at 10:05.
12 We're required to hold hearings on disposal
13 injection orders and the applicant must provide
14 testimony. So what we're going to do is we're going to
15 continue the hearing until such time as you're prepared
16 to present your application to us.
17 Could you give us an estimate -- could you tell
18 us how long it'll take you to be prepared to present
19 your application to us in a hearing and testimony?
20 MR. RADCLIFF: Yes, thank you. Okay. Thank
21 you for having us here. Yes, Stephen Radcliff, Glacier
22 oil and Gas on behalf of Cook Inlet Energy.
23 If we could request a two week extension we'll
24 come back at that point.
25 COMMISSIONER FOERSTER: Okay. What would be
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2/5/2019ITMO: APPLICATION OF COOK INLET ENERGY
DIO 18-004
Page 5
1 two weeks from today, Sam?
2
MS. CARLISLE:
That's
the 19th
of February.....
3
COMMISSIONER
FOERSTER:
19th of
February.
4
MS. CARLISLE:
.....Tuesday.
MS. CARLISLE:
Okay.
5
COMMISSIONER
FOERSTER:
Do you
-- is there
6
anything on the calendar that
day?
20
7
MS. CARLISLE:
No.
21
They'll be getting ahold of you.
8
COMMISSIONER
FOERSTER:
Okay.
Is that okay
9
with you?
Okay.
Thank you.
24
10
COMMISSIONER
SEAMOUNT:
What's
the date?
11
COMMISSIONER
FOERSTER:
Tuesday
the 19th.
12
COMMISSIONER
SEAMOUNT:
That's
fine with me.
13
I'm.....
14
MS. CARLISLE:
That's
the day after a holiday.
15
Monday the 18th is a
holiday.
So.....
16
COMMISSIONER
FOERSTER:
Okay. That's fine.
17
MS. CARLISLE:
Okay.
18
COMMISSIONER
SEAMOUNT:
And then get together
19
with our staff and they can tell
you about hearing
20
guidelines and stuff
like that.
It's on the website.
21
They'll be getting ahold of you.
22
COMMISSIONER
FOERSTER:
Okay. So.....
23
MR. RADCLIFF:
Okay.
Thank you.
24
COMMISSIONER
FOERSTER:
.....are we adjourned
25
or are we continued?
Computer Matrix, LLC Phone: 907-243-0668
135 Christensen Dr., Ste. 2., Anch. AK99501 Fax: 907-243-1473 Email: sahile@gci.net
AOGCC
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2/5/2019 ITMO: APPLICATION OF COOK INLET ENERGY
DIO 18-004
Page 6
COMMISSIONER SEAMOUNT: Continued.
COMMISSIONER FOERSTER: We're continued until
February 19th. Do you want to do it at 9:00 or 10:00?
COMMISSIONER SEAMOUNT: You're chairing the
meeting.
COMMISSIONER FOERSTER: Let's do it at 9:00
a.m. February 19th at 9:00 a.m. we will reconvene to
complete this hearing. And we're continuing at 10:08.
(Off record)
(PROCEEDINGS TO BE CONTINUED)
Computer Matrix, LLC Phone: 907-243-0668
135 Christensen Dr., Ste. 2., Anch. AK 99501 Fax: 907-243-1473 Email: sahile@gci.net
AOGCC
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2/5/2019ITMO: APPLICATION OF COOKINLET ENERGY
DIO 18-004
Page 7 1
TRANSCRIBER'S CERTIFICATE
I, Salena A. Hile, hereby certify that the
foregoing pages numbered 02 through 07 are a true,
accurate, and complete transcript of proceedings in
Docket Number DIO 18-004, transcribed under my
direction from a copy of an electronic sound recording
to the best of our knowledge and ability.
Computer Matrix, LLC Phone: 907-243-0668
135 Christensen Dr., Ste. 2., Anch. AK99501 Fax: 907-243-1473 Email: sahile@gci.net
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
Docket Number: DIO-18-004
West McArthur River Unit, Hemlock Undefined Oil Pool
February 5, 2019
AFFILIATION
N prmF n &F g -r (ILPLA &f- 40
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Notice of Public Hearing
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Re: Docket Number: DIO-18-004
West McArthur River Unit, Hemlock Undefined Oil Pool
The application for Disposal Injection Order
Cook Inlet Energy (CIE), by letter dated December 12, 2018, requests the Alaska Oil and Gas
Conservation Commission (AOGCC) issue a Disposal Injection Order to allow the disposal of
produced water from the West McArthur River Unit (WMRU) and Redoubt Unit in the Hemlock
formation in the WMRU.
The AOGCC has scheduled a public hearing on this application for February 5, 2019, at 10:00
a.m. at 333 West 7'h Avenue, Anchorage, Alaska 99501.
Written comments regarding this application may be submitted to the AOGCC, at 333 West 7`h
Avenue, Anchorage, Alaska 99501. Comments must be received no later than 4:30 p.m. on the
conclusion of the February 5, 2019 hearing.
If, because of a disability, special accommodations may be needed to comment or attend the
hearing, contact the AOGCC's Special Assistant, Jody Colombie, at (907) 793-1221, no later than
January 24, 2019.
Hollis S. French
Chair, Commissioner
Notice of Public Hearing
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Re: Docket Number: DIO-18-004
West McArthur River Unit, Hemlock Undefined Oil Pool
The application for Disposal Injection Order
Cook Inlet Energy (CIE), by letter dated December 12, 2018, requests the Alaska Oil and Gas
Conservation Commission (AOGCC) issue a Disposal Injection Order to allow the disposal of
produced water from the West McArthur River Unit (WMRU) and Redoubt Unit in the Hemlock
formation in the WMRU.
The AOGCC has scheduled a public hearing on this application for February 5, 2019, at 10:00
a.m. at 333 West 7' Avenue, Anchorage, Alaska 99501.
Written comments regarding this application may be submitted to the AOGCC, at 333 West 7d'
Avenue, Anchorage, Alaska 99501. Comments must be received no later than 4:30 p.m. on the
conclusion of the February 5, 2019 hearing.
If, because of a disability, special accommodations may be needed to comment or attend the
hearing, contact the AOGCC's Special Assistant, Jody Colombie, at (907) 793-1221, no later than
January 24, 2019.
//signature on file//
Hollis S. French
Chair, Commissioner
STATE OF ALASKA
ADVERTISING
ORDER
NOTICE TO PUBLISHER
SUBMIT INVOICE SHOWING ADVERTISING ORDER NO.CERTIFIED
AFFIDAVIT OF PUBLICATION WITH ATTACHED COPY OFADVERTISMENT.
ADVERTISING ORDER NUMBER
p
AO -I9 -0I7
FROM: AGENCY CONTACT:
Jody Colombie/Samantha Carlisle
Alaska Oil and Gas Conservation Commission DATE OF A.O.AGENCY PHONE:
333 West 7th Avenue 12/19/2018 907 279-1433
Anchorage, Alaska 99501
DATES ADVERTISEMENT REQUIRED:
COMPANY CONTACT NAME:
PHONE NUMBER: ASAP
FAX NUMBER:
(907)276-7542
TO PUBLISHER:
Anchorage Daily News, LLC
SPECIAL INSTRUCTIONS:
PO Box 140147
Anchorage, Alaska 99514-0174
TYPE OF ADVERTISEMENT:
(V- LEGAL 1— DISPLAY IV CLASSIFIED I— OTHER (Specify below)
DESCRIPTION PRICE
DIO-18-004
Initials of who prepared AO:
Alaska Non -Taxable 92-600185
:SDHM{T{NYOIC¢ SHOWING agvEAT.00:
ORD 6RNU;,CEI2TIPIEISA:FQIDAYITOF:: -
PHBEICATton:Wfailn.Trgcxeamryop:
wnyERtuMSNTn
AOGCC
333 West 7th Avenue
Anchorage, Alaska 99501
Pae 1 of I
Total of
All Pa es $
REF Type Number
Amount Date Comments
I pvN VCO21795
2 AD AO -19-017
3
4
FIN AMOUNT SY AcG Template I PGM LCR Object FY I DIST LIQ
N 19 A14100 3046 19
2
3
4 r;
5
Purchasing u lhoInto
r
'e
Purchasing Authority's Signature Telephone Number
1. A.O. iiand a* n must appear on all invoices and documents relating to this purchase.
2. The state is registered for tax Bee transactions under Chapter 32, IRS code. Registration number 92-73-0006 K. Items are for the exclusive use of the state and not for
Mai
DI51RIB.UTION. .,, ..,:. .. ,..:..
Dlvwian Fi¢cal/Ortgmal AOCoples
.. ... .,_, .,..,. .. ...
Pti6lsher tfaxedj Drvlsion6:iseal, ReCeWjng
Form: 02-901
Revised: 12/19/2018
Bernie Karl
K&K Recycling Inc. Gordon Severson Penny Vadla
P.O. Box 58055 3201 Westmar Cir. 399 W. Riverview Ave.
Fairbanks, AK 99711 Anchorage, AK 99508-4336 Soldotna, AK 99669-7714
George Vaught, Jr. Darwin Waldsmith Richard Wagner
P.O. Box 13557 P.O. Box 39309 P.O. Box 60868
Denver, CO 80201-3557 Ninilchik, AK 99639 Fairbanks, AK 99706
ANCHORAGE DIY �►�EWE:- ..y;TjT�1�pF.:
dna F;� 9nm� :i C✓ 2 ral
AFFIDAVIT OF PUBLICATION DEC 3 1 ' v io
A G C +...R
Account#: 270227
ST OFAKIAK OILAND OAS Order# 0001432072 Product ADN -Anchorage Daily News
CONSERVATION COMMISSION Cost $179.30 Placement 0300
333 WEST 7TH AVE STE 100 Position 0301
eurunonrc All UoAniiAlo
STATE OF ALASKA
THIRD JUDICIAL DISTRICT
Joleesa Stepetin
being first duly sworn on oath deposes and says
that he/she is a representative of the Anchorage
Daily News, a daily newspaper. That said
newspaper has been approved by the Third
Judicial Court, Anchorage, Alaska, and it now
and has been published in the English language
continually as a daily newspaper in Anchorage,
Alaska, and it is now and during all said time
was printed in an office maintained at the
aforesaid place of publication of said newspaper.
That the annexed is a copy of an advertisement
as it was published in regular issues (and not in
supplemental form) of said newspaper on
December 20, 2018
and that such newspaper was regularly
distributed to its subscribers during all of said
period. That the full amount of the fee charged
for the foregoing publication is not in excess of
the ratecha ed private individuals.
Signed
JOI&1sa Steoetin
Subscribed and sworn to before me
this 20th day of December, 2018
Notary Public' Od for
The State of Aladka.
Third Division
Anchorage, Alaska
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Re: Docket Number: DIO-18-004
West McArthur River Unit, Hemlock Undefined Oil Pool
The application for Disposal Injection Order
Cook Inlet Energy (CIE), by letter dated December 12,2018,
requests . the Alaska Oil and Gas Conservation Commission
(AOGCC) Issue a Disposal Injection Order to allow the disposal Of
produced water from the West McArthur River Unit (WMRU) and
Redoubt Unit in the Hemlock formation in the WMRU.
The AOGCC has scheduled a public hearmon this application
for February 5, 2019, at 10:00 a.m. at 3A West 7th Avenue,
Anchorage, Alaska 99501.
Written comments regarding this application may be submitted
to the AOGCC, at 333 West 7th Avenue, AnchareBa, Alaska
99501. Comments must be received no later than 4;30 p.m. on
the conclusion of the February 5, 2019 hearing.
If. because of a disability, special accommodations may be
24,
//si nature on file//
Hollis S. French
Chair, Commissioner
MY COMMISSION qXPIRESIc
'11PSON
rv7� Commission
Of .tiIska
1 ommission Expires Feb 23, 2019 i
_ Cook Inlet Energy_
Dec 12, 2018
Mr. Hollis French,
Chair, CommissionersCl _ 4.1,'-r
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501-3572
Subject: Application for Area Injection Order
West McArthur River Unit (WMRU)
Dear Commissioner French,
Cook Inlet Energy (CIE), a Glacier Oil & Gas Corporation, is submitting this request and
supporting documentation to commence permitting through the Alaska Oil and Gas Conservation
Commission for approval to engage in the Underground Disposal of Oil Field Wastes within the
above -referenced Unit operated by Cook Inlet Energy. This operating practice is authorized under
the Alaska Administrative Code, 20 AAC 25.252
The proposed operation, when approved, will allow for the disposal of increasing water
production, that in turn supports increased recovery of remaining crude oil reserves in this existing
Cook hilet field. This project can be accomplished with the construction of a new dedicated
pipeline segment to the WMRU Production Facility, modifications to tankage and pumping
capacity and conversion of select shut in WMRU wells to water injection.
CIE acknowledges that the approval process must be followed and would like to initiate
this request in order to facilitate progressing the project forward in 2019.
If necessary, I am available at your convenience to discuss this submission or provide
additional documentation. I can be contacted at (907) 433-3836 or via email at
grnorris(aWacieroil.com
Sincerely,
0�
George R. MoorrisG /
EVP & COO
Cook Inlet Energy
601 W. 50 Avenue, Suite 310, Anchorage, AK 99501
(907)334-6745 Main 1 (907) 334-6735 Fax
Page l of l U R I GI -NA t
Enclosures
1. West McArthur River Unit AIO Application
2. WMRU land plats with potential disposal wells
3. WMRU land plat with all WMRU wells within a'/< mile radius around disposal zones
4. WMRU well casing properties
5. Sword 1 water analysis
6. Redoubt 5 water analysis
601 W. 51h Avenue, Suite 310, Anchorage, AK 99501
(907)334-6745 Main 1 (907) 334-6735 Fax
Page 2 of 2
20 AAC 25.252
Underground Disposal of Oil Field Wastes and Underground Storage of Hydrocarbons
Introduction -- Description of Operation for which approval is Requested.
Cook Inlet Energy (CIE) is requesting approval to dispose of excess produced water by
converting select shut-in wells into water disposal wells and injecting the excess produced water
into the Hemlock Formation at West McArthur River Unit (WMRU).
WMRU presently consists of 3 producing wells (WMRU 213, WMRU 6 and Sword 1) and 4 shut
in wells. Surface production facilities for the field are located on the west side of the Cook Inlet.
All wells are directionally drilled and completed in the Hemlock Formation. Producing wells are
on artificial lift (ESPs). Current production at WMRU is 564 BOPD and 2,980 BWPD. The
water -cut of the producing wells ranges from 80%-90% water. The Hemlock Formation at
WMRU is a very strong water drive reservoir. Production from WMRU is currently curtailed
because of CIE's lack of ability to dispose of the produced water.
Production from CIE's WMRU and Redoubt Unit (RU) wells goes to the Kustatan Processing
Facility (KPF). Current total production at KPF is 1,854 BOPD and 4,120 BWPD. Oil at KPF is
commingled and sold, and water is commingled and injected into the RU waterflood or injected
into our Class I disposal well, RU -Dl.
Produced water disposal capacity is limited to approximately 4,200 BWPD and is split between
RU waterflood injection (3,950 BWPD) plus disposal well volumes (250 BFPD). Due to lack of
water disposal capacity, CIE has been curtailing production at WMRU. WMRU 5 was choked
back starting in mid-August and finally shut-in in mid-October 2018. WMRU 6 and WMRU 2B
are currently curtailed as well. The curtailment has resulted in a loss of over 30,000 BO as of
December 1, 2018.
As CIE continues to produce and deplete both RU and WMRU, the RU waterflood will increase
overall water production as injected produced water displaces oil, and WMRU water -cut will
steadily increase as the strong water drive flushes oil to producing wells. Additional disposal
wells will increase water handling capacity, leading to increased ultimate hydrocarbon recovery.
1) Location Plat
Attached are two plats, the first (Fig. 1) shows the location of the proposed WMRU disposal
wells. Currently, CIE has 3 potential wells that could be converted into disposal wells. These
wells include West McArthur River Unit IA, West McArthur River Unit 7A, and West
McArthur River Unit 8. Prior to conversion, Sundry Applications will be submitted to the state
The second plat (Fig. 2) shows all wells within WMRU. There are circles with one quarter mile
radius drawn around the disposal well's intersection with the top of the Hemlock Formation.
There are 8 wells that fall within one quarter mile radius of these 3 potential disposal wells.
These wells include;
West McArthur River Unit 1
West McArthur River Unit 2A
West McArthur River Unit 2B
West McArthur River Unit 3
West McArthur River Unit 5
West McArthur River Unit 6
West McArthur River Unit 7
Sword 1
i
I
8 g
A
A
Shoreline
16 15
West McArthur R er Unit Outline -
!8 14W
!r��
Glacier Of antl Gas
WURU Potenwtl jAdw Weis
1
MILES
Wv bh 15,5018
Figure 1: West McArthur River Unit Potential Disposal Wells; WMRU IA, WMRU 7A, and WMRU 8.
Figure 2: Plat showing all WMRU wells. Circles with 1/4 mile radius are around potential disposal wells
intersection with the top of the Hemlock Formation.
2) Operators and Surface Owners
There are no other operators or surface owners besides CIE within one quarter mile radius of the
proposed disposal well's injection location.
3) Affidavit Showing Notification of Surface Owners and Other Operators
There are no other nearby owners or operators at the proposed injection well's zone of injection;
therefore, affidavits were not gathered. The surface is comprised of the waters of the Cook Inlet
(State) and the subsurface is also under the control of the State of Alaska. There are no federal
lands or Native interests. The Alaska Oil and Gas Conservation Commission is charged with
administering and regulating the subsurface activity.
4) Geologic Description
The name, description, depth, and thickness of the formation into which fluids are to be injected
and appropriate geological data on the injection zone including lithologic descriptions and
geologic names have been previously submitted to the AOGCC.
The reservoir of interest for disposal at WMRU is the Hemlock Formation. The Hemlock
Formation unconformably overlies the West Foreland and consists of a thick sequence of
interbedded conglomerates and sandstones separated by thin interbeds of impermeable
claystones and siltstones. Thin coal beds are found between some facies of the Hemlock. The
Hemlock Formation is very uniform in thickness although there is considerable variation
between the individual benches. For this reason, the Hemlock has been subdivided into 3 units,
the Upper, Middle, and Lower. The stratigraphic variation between lithofacies is typical of a
braided stream depositional environment.
Hemlock Formation
The Upper, Middle, and Lower Hemlock at WMRU are composed of 6 lithofacies. Porosity
within the Hemlock is intergranular, and the rocks are well cemented and competent. The
lithofacies are listed below from coarsest to finest.
Reservoir Facies
1. Pebble/conglomerate — conglomerates range from clast-supported to very sandy and
matrix supported. Cobbles and pebbles in the conglomerates are well rounded, and
moderately sorted, indicating considerable transport distance from their source. Porosities
are relatively uniform, ranging from 7-11 %.
2. Pebble/gravel sandstone — facies is more uniform in grain size and is entirely matrix
supported. Porosity ranges from 10-16%.
3. Medium to coarse grained sandstone — facies is moderately well sorted and matrix
supported. Porosity ranges from 12-18%
4. Fine-grained sandstone — facies is well sorted. Porosity ranges from 12-14%
Non -Reservoir Facies
5. Very fine-grained siltstones — facies is non -permeable and rocks generally have little to
no porosity (14%).
6. Highly carbonaceous claystones — facies is non -permeable and rocks generally have no
porosity. Cuttings and log response in these zones resemble coals. Along with siltstone
facies, these facies generally act as seals for the overlying and underlying reservoir rocks.
Depositional Environment
Extensive core analysis indicates that the Hemlock was deposited in a fluvial environment,
dominated by a large braided stream complex. An excellent analogy of the depositional
environment of the Hemlock Formation is the present-day Matanuska River with its braided
stream complex. The Matanuska River displays bars and islands composed of conglomerates,
while the channels between these islands are composed of fine to coarse-grained sandstones.
There is a high degree of heterogeneity both laterally and vertically in a system of this nature,
and this is seen clearly in well log correlations at WMRU. Distribution of lithofacies is variable
within the Upper, Middle and Lower Hemlock. Based on log correlations, horizontal and vertical
continuity of individual lithofacies is generally difficult to determine, but in this type of system
porous rocks are in contact with porous rocks both vertically and horizontally. FMS and
dipmeter data from the west side of the Cook Inlet show the depositional trend of the braided
stream complex was generally NW -SE, and the source of sediment of the Hemlock is from the
NW.
Hemlock Reservoir Characterization
As previously stated, the Hemlock reservoir at WMRU is heterogeneous due to the depositional
environment. The source of sediments for Hemlock was from the NW, and the general trend of
the facies is NW -SE, which creates a pattern for preferential flow from SE -NW within the
reservoir.
Porosities in the sandstone facies of the Hemlock are between 12-18%, with some small sands
displaying higher averages. This includes the fine-grained sandstone, medium to coarse-grained
sandstone, and the pebble/coarse-grained sandstone facies. Permeabilities in these same facies
range from 100-300md. The conglomerate facies are slightly less porous, with porosities ranging
from 7-11% and permeabilities ranging from 10-50md. The contrast in porosities and
permeabilities between reservoir facies affects fluid flow.
Structure
The structures on the west side of the Cook Inlet were formed by tectonic events as a series of
en -echelon structures related to the Bruin Bay and Castle Mountain -Lake Clark Fault Systems.
These faults are major strike -slip and wrench faults that have influenced the structural and
stratigraphic development of the Cook Inlet Basin. Wrench faults controlled sedimentation as
early as Late Jurassic time. The greatest structural development was probably during Plio-
Pleistocene time. However, structures may have been present in the Early Oligocene time, as
indicated by thinning to the crest of several units within the West Foreland and Hemlock at
WMRU.
The WMRU structure is a NW -SE trending anticline that has been bisected by E -W and N -S
trending faults. It is also separated from the McArthur River Field's Norwest feature by a major
NW -SE trending fault, the Dolly Varden fault, which displays approximately 100-150' of down
to the south throw. Due to the lack of pressure differences across the faults within WMRU we
have concluded they are not sealing faults.
Confining Intervals
Due to the depositional nature of the Hemlock Formation, numerous boundaries are available to
provide containment both above and below the zones to be used for disposal operations. These
confining intervals are composed of continuous tight shales and coals (non -reservoir lithofacies)
that are present not only within the Hemlock Formation, but in the Tyonek and West Foreland
Formations above a below the Hemlock respectively.
5) Logs of Injection Wells
All WMRU logs are on file with the AOGCC.
6) Mechanical Integrity of Casing and Tubing for Disposal Wells
The attached table provides existing casing properties for the 3 wells under consideration for
converting to water disposal. The casing by tubing annulus will be pressure tested to 0.25
psi/TVD ft to confirm mechanical integrity for each well. Sufficient notice will be given to the
AOGCC so a witness maybe present for the mechanical integrity tests. Injection will not begin
until the pressure tests are complete and approval for the conversion is granted.
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7) Type of Fluid to be Injected
Produced Hemlock Formation water from WMRU and RU is commingled at KPF and used at
RU for water flood purposed. Excess produced water will be injected for disposal in to the
Hemlock formation at WMRU. Since all water is sourced from the Hemlock, compatibility is not
an issue.
8) Injection Pressure
The fracture gradient at WMRU is estimated to be greater than 0.86 psi/ft based on; 1) in -field
FIT and LOT above and below the Hemlock Formation and; 2) facture work done in the
Hemlock Formation at Redoubt Unit. Based on this fracture gradient, the maximum allowable
surface pressure for injection of produced water will be 4000 psi to avoid fracturing the Hemlock
Formation [ 0.86 x 9500' TVD — 0.433psi/ft hydrostatic gradient x 9500' TVD].
9) Protection of Freshwater Strata
The mechanical integrity of casing and tubing along with cementing for all wells within WMRU
will ensure that no injection water will be able to migrate from the Hemlock to freshwater strata
near the surface.
10) Water Analysis
Water analysis of produced water from Sword I and RU -5 is attached.
11) Freshwater Exemption
A freshwater exemption is not applicable because the Hemlock Formation injection zone in
questions, is not a freshwater interval.
12) Mechanical Condition of Wells within WMRU
WMRU has 4 wells capable of production from the Hemlock formation via ESP artificial lift.
These wells are monitored by the personnel manning the facility 24 hours per day. WMRU has 3
wells which are shut in and are potential candidates for water injection. The mechanical
condition of the shut-in wells is addressed in section 6.
p�,E•■ Paci0c Coast Area Laboratory
BAKER 3901 Fanucchi Way E,
HUGHES Shafter, California 93263
COMPLETE WATER ANALYSIS REPORT SIP V.2010
Upstream Chemicals
REPORT DATE: 11/21/2016
CUSTOMER:
COOK INLET ENERGY LLC
ACCOUNT REP:
JOEL BEATTIE
DISTRICT:
ALASKA
SAMPLE ID:
201606043890
AREA/LEASE:
WEST MCARTHUR RIVER UNIT
SAMPLE DATE:
11/3/2016
SAMPLE POINT NAME
SWIG
ANALYSIS GATE
11/21/2016
SITE TYPE:
238.0
ANALYST:
ER/IL
SAMPLE POINT DESCRIPTION:
2.9 Potassium (K4):
109.3
2.8
Initial Pressure (psi):
COOK INLET ENERGY LLC,
WEST MCARTHUR RIVER
UNIT, SWD-1
FIELD DATA
FIELD PROVIDED
DATA; FUTHER
MODELING MAY
BE REQUIRED
FOR VALIDATION
OF SCALE PREDICTION RESULTS.
ANWNS:
mg/l.
mel CATIONS,
fall
meq/L
Initial Temperature (T):
187 Chloride (Cl):
16790.7
473.6 Sodium (Il
5468.7
238.0
Final Temperature (°F):
100 Sulfate (SOc27:
137.0
2.9 Potassium (K4):
109.3
2.8
Initial Pressure (psi):
600 Borate (H,BO,):
NO
Magnesium (Mg24);
56.0
4.6
Final Pressure (pal
45 Fluoride (I):
NO
Calcium (Cal
4757.5
237.4
0.57
Bromide (Br):
NO
Strontium (SIF+):
61.0
1.4
PH:
Nitrite (Noah
NO
uni(Ba24):
3.7
0.1
PH at time of sampling:
6.5 Nitrate (NO,):
NO
Iron fit
0.9
0.0
129-F
Phosphate fP03J:
10.2
0.3 Manganese fail
2.7
0.1
-0.77
Silica (Sil
46.3
Lead (P624):
NO
292 psi
041
1326
079
Zinc (2.24):
NO
0.000
AtxauwD rv7rtwuroH: al
meq/l
148-F
353 psi
0.36
1.235
Bicarbonate(HCOl 206.0
3.4
-015
Aluminum (Al'*):
NO
0000
Carbonate (COl ND
415 psi
0.33
Chromium (Cl
NO
36.977
Hydroxide (OH ): NO
0,000
062
Cobalt (Cil
NET
477 psi
029
ORGANIC ADDS:
mg/L
nal Copper(Cu24):
NO
0000
aqueous CO2 (ppm):
174.) Formic Acid:
NO
Molybdenum (M,l
NO
0.975
aqueous HS(ppm):
4.0 Acetic Add:
NO
Nickel(Ni24):
NO
0000
aqueous 02(ppb):
NO Propionic Acid:
NO
Tin(Sn24):
NO
41.332
0.70
Butyric Acid:
NO
Titanium(Tt2'):
NO
Calculated TDS fmg/L):
27640 Valeric Acid:
NO
Vanadium(V2'N
NO
Press.
Density/Specific Gravity (g/cm2):
1.0177
Index
Zirconium (Zr2'):
NO
Amt(FILE
Measured Specific Gravity
NO
100-F
45 psi
-0.98
0000
Conductivity hron ):
44.7
0.04
Total Hardness:
12197
N/A
Resistivity:
NO
-0.97
0.000
-2.90
0.000
MCF/D:
No Data
1.31
0000
119-F
168 psi
FJORD:
No Data
-2.90
0,000
0.01
0.010
BWPD:
No Data Anion/Cation Baltic:
129-F
0.99 NO = Not Determined
-0.95
SCALE PREDICTIONS BASED ON
FIELD PROVIDED
DATA; FUTHER
MODELING MAY
BE REQUIRED
FOR VALIDATION
OF SCALE PREDICTION RESULTS.
Condition
Barhe(Ba50,7
Calcite Jeri
Gyp..(Ca50e2H,0)
Anhyddte(Cal
Temp
Press.
Index
Amt(ptb)
Index
Amt(ptb)
Ind.
Amt Ul
Index
Amt fptb)
100-F
45 psi
0.63
1.675
056
26.154
-0.79
0000
-0.94
0,000
110-F
107 psi
0.57
1.592
060
27.665
-018
0.000
-089
0000
119-F
168 psi
0.51
1.506
067
29354
-0.78
0.000
-0.84
0.000
129-F
230 psi
046
1A16
073
31.726
-0.77
0.000
-019
0000
139-F
292 psi
041
1326
079
33.584
-076
0.000
-014
0000
148-F
353 psi
0.36
1.235
0.86
35.333
-015
0.000
-0.68
0000
ll
415 psi
0.33
1.146
0.92
36.977
-074
0,000
062
0000
16FF
477 psi
029
1.059
099
38.521
012
0000
0.56
0000
177-F
538 psi
026
0.975
1.06
39.971
0.71
0,000
0.50
0000
187-F
600 psi
023
0895
1.12
41.332
0.70
0,000
-0.43
0000
Condleon
Celeal(S60d
Helite(NatO
Iron Sulfide(fe5)
Iron Catbnnss fix(Cy
Temp
Press.
Index
Ams fial
Index
Al(ptb)
Index
Amt(FILE
Index
Amt (pi
100-F
45 psi
-0.98
0000
-2.89
0.000
0.04
0.000
1.39
0,000
1101
107 psi
-0.97
0.000
-2.90
0.000
0.03
0.000
1.31
0000
119-F
168 psi
-0.96
0.000
-2.90
0,000
0.01
0.010
-1.23
0000
129-F
230 psi
-0.95
0.000
-2.91
0.000
0.05
0,050
1.14
0000
139-F
292 psi
-0.94
0.00)
-2.92
0000
0.10
0090
-106
0000
148-F
353 psi
-0.92
0.000
-292
0000
0.14
0.127
-098
0000
158-F
415 psi
0.91
0.000
-292
0000
0.19
0.162
-091
0,000
168-F
477 psi
0.89
0,000
-292
0000
024
0.195
-El
0,000
177-F
538 psi
087
0,000
-292
0000
029
0,226
-076
0.000
187-F
600 psi
084
0000
-292
0000
0.34
0254
-070
0.000
For 1'.wMn aoi iha-ty.T. title vrowem.Ea. F-UraLon..a.(10 xM amwni olsral.-nes-OvOr.
xme 2 F.e6Pp#mo oI exn care la aonnaama uva.neN Total lose nT be has al iM win Of me aa -of To zlgm (el -111
For, 3'.Alu.alion IMoo Gammon an tnn Aeet ou Fn aN alJaanity,s .'1, not innoaea In ih'Ooaaooa
Comments:
e. ml•
SculeSnHPiDer^t
SSP2uln
SAMPLE ID: 201606043890 COOK INLET ENERGY LLC, WEST MCARTHUR RIVER UNIT, SWD-1
Barite (BaSO4) Calcite (CaCO3)
Preuure (,d) Pressure (w)
45 107 I68 230 292 353 415 477 538 600 45 107 168 230 292 353 415 9]] 538 GCO
07 60 1.2 140
06 50 q 1.0 120 a
os
E 100 E
0 p 9 08 p
c o4«
ii 30 `0 06 'd
0.3 2� 60
e 2.0 04 S
n2 40
m 01 l0 $ N 0.2 20
n
'a00 00 °
IM 110 119 129 139 198 158 168 3]] 187 100 I10 119 139 339 148 158 368 V] 187
TamperaWre (F) TempemWre (n
Gypsum (CaSO4.2H2O) Anhydrite (CaSO4)
Preuure (pap Pnuure (,D
45 107 168 230 292 353 415 9]] 538 600 45 IW 168 230 292 353 415 9]] 538 600
06 10 00 10
07 09
0.8 08 E
y 0.7 m E z .0.3 07
o
OJ 06 = c OA 06 _
c .m
0.5 « c 05 os
.0] 0n 0 e -0.6 _ - 04
03 > 03 03
q 0.8 02 m 08 02
„ .0.8 — __. _ 01 : 09 - Ol
0.8 00 d -10 00 p
100 110 119 129 139 148 158 168 1]] 187 100 110 119 129 139 148 158 168 V] 197
TemPemwm (F) TemperaW re (F)
—51--m9/L'
Celestite (SrSO4) Halite (NaCl)
Prenure (Mo Premura (PFO
45 107 168 230 292 353 415 477 538 600 45 102 168 230 292 353 415 477 538 600
-0.8 10 .2.9 __ __ _.__ 10
0.9 d_ 09
J. C.B d, -$9 - 08 E
0.7
z9
O9 06 p 06
C 0.5 a c 2.9 O5 _
C
% _0,9 04 r 0.4am
6
03 .1 9' E9 03 y
0.2 02 -
0 29
01 S 0.1 n
-I p 00 -29 00
100 110 119 129 139 148 158 168 1]] 187 1W IW 119 129 139 148 158 168 127 387
Temperatum (n Temperature (F)
Iron Sulfide (FeS) Iron Carbonate (FeCO3)
F pure (pap Pressure (ps)
45 107 64 1 230 292 )53 415 4]] 538 600 45 107 168 DO 292 353 415 4]] 538 600
04 08 00
0.4 07 E .02 1 a
03 E
06 04
03 —
02 05 y 06 1 0
0.2 04 c 09 1 G
n
t
Q 01 0.3 w -10 °
01 _ ' L
0.2 12 a
00 ° n
0.1 00 16 °
100 110 119 129 139 148 158 168 177 187 In 110 119 129 139 148 158 168 172 187
TemperaW re (n Temperature (n
SCALE PREDICTIONS BASED ON FIELD PROVIDED DATA FUTHER MODELING MAY BE REQUIRED FOR VALIDATION OF SCALE PREDICTION RESULTS.
FIELD DATA
Initial Temperature ('F)
Final Temperature (T):
Initial Pressure (psi);
Final Pressure (psi);
PH:
PH at time of sans Piing
Redoubt Water Analysis
meq/L
MiFie5.
Upstream Chemicals
BAKER
_
3901 Fanucchi Way E, a ory
mg/L
HUGHES
Shaffer, California 93263
REPORT DATE: 7/9/2018
COMPLETE WATER ANALYSIS REPORT ssp y2olo
3790.0
CUSTOMER:
COOK INLET ENERGY LLC ACCOUNT REP:
JOEL BEATFIE
DISTRICT:
ALASKA SAMPLE ID:
201806026682
AREA/LEASE:
KUSTATAN PRODUCTION FACILITY SAMPLE DATE:
6/11/2018
SAMPLE POINT NAME
BLD. E - 8" OSP 3-PHASE - CC:KO1 ANALYSIS DATE:
6/28/2018
SITE TYPE:
ANALYST:
SPAL
SAMPLE POINT DESCRIPTION:
WATER DUMP LEG
ND
COOK INLET ENERGY LLC, KUSTATAN PRODUCTION FACILITY, BLD. E
- 8" OSP 3-PHASE - CCX01
FIELD DATA
Initial Temperature ('F)
Final Temperature (T):
Initial Pressure (psi);
Final Pressure (psi);
PH:
PH at time of sans Piing
uauNIYBY1rrI .N:
mg/L
meq/L
ANIONS:
mg/L
ANALYSIS OF SAMPLE
meq/L CATIONS:
mg/L
meq/L
250 Chloride (CI "):
10388.0
293.0 Sodium (Na'):
3790.0
164.9
52 Sulfate (SON2):
16.6
0.3 Potassium (K'):
76.2
1.9
100 Borate (14311
NO
Magnesium (Mai
16.6
IA
109 Fluoride III
ND
Calcium (G°'):
2470.0
123.3
Bromide(Br):
ND
Strontium (Be*):
39.7
0.9
Nitrite (1402):
ND
Badum(Ba2'):
7.5
0.1
6.8 Nitrate(NOO:
ND
Ina. (F.a'):
3.3
0.1
Phosphate (PO,'
1.8
0.1 Manganese(Mn°');
1.3
0.0
Sills (SIOJ:
48.4
Lead fixii
ND
1.0 Acetic Acid:
NO
Zinc Wl:
ND
uauNIYBY1rrI .N:
mg/L
meq/L
Bk rbonate(HCI
227.0
3.7
Aluminum(AII
NO
Carbonate (COsr):
ND
Chromium (Crs};
ND
Hydroxide (ON);
ND
cobalt(Co2'):
ND
ORGANICACIDi:
ni
meglL
Copper (Cu'*):
ND
aqueous CO, (ppm):
338.0 formic Acid:
NO
Molybdenum (Mor*):
ND
aqueous H2S (ppm):
1.0 Acetic Acid:
NO
Nickel (Nir):
ND
aqueous 02 (ppb):
ND Propionic Acid:
NO
Tin(Sn2'):
ND
Butyric Acid:
NO
Titanium (71"):
ND
Calculated TDS(mg/L):
17085 Valedc Acid:
NO
Vanadium (V2'):
ND
Density/Specific Gravity(g/cros4
1.0097
Zirconium WI:
ND
Measured Specific Gravity
ND
Lithium (I
NO
Conductivity (mmhm):
30.4
Resistivity:
ND
Total Hardness:
6294 N/A
MCF/D:
No Data
BOPS:
No Data
BWPD:
No Data Anion/Cation Ratio:
1.02
NO = Not Determined
SCALE PREDICTIONS BASED ON
FIELD PROVIDED DATA FUTHER MODELING MAY BE REQUIRED FOR VALIDATION OF
SCALE PREDICTION
RESULTS.
CeMBions
%,ae(saw.)
Okite(CeCOJ
Gypmm(CaSOC21120)
Anbyddo(CaSWJ
Temp
P..
Index And(ptb)
Index
Anit(FIE)
Index
Ant(atb)
Index
Amt(ptb)
52-F
109 psi
0.69 3.268
0.33
16.934
-1.78
0.000
-2.12
0000
74-F
108 psi
0.46 2.580
0.47
23.260
-1.79
0.000
-2.05
0.000
96-F
107 psi
0.28 1.785
0.62
29.134
-1.7e
0.000
-1.96
(L000
1181
106 psi
0.13 0.953
0.77
34.419
-1.77
0.000
-1.85
0.000
140-F
105 psi
0.02 0.151
0.93
39.168
-1.75
0.000
-1.73
0.000
11
104 psi
-0.07 Dow
TAPS
43.306
-1.72
DIDDO
ASS)
0.000
184'F
103 psi
-0.14 0.000
1.26
46.901
-1.69
0.000
-1A4
0.000
206-F
102 psi
-0.19 0.000
TAB
50.001
-1.66
0000
-129
0.000
228-F
101 psi
-0.22 0.000
1.60
52.655
-1.62
0000
-1.13
0.000
251PF
100psi
125 0.000
1.77
54.910
-159
0.000
-098
0.000
Conditions
CWftlte{660J
MR.
MaCD
Iron Sulfide(FeS) Iran Carbonate(FeCOJ
Tema
Pros.
Index Amt(II
IMax
Amt(ptb)
Index
Anal (II
Index
Ams Lada)
52'1`
109 psi
-1.88 0.000
-3.16
0.000
0.37
0.587
-0.92
0.000
74'F
108 psi
-1.89 DODO
-3.20
0.000
0.38
0.606
-0.69
0.000
96-F
iW Psi
1.88 Dow
-3.22
0.000
CAB
0.668
-0.46
0,000
118-F
106 psi
-1.86 0.1100
-3.24
0.000
0.50
0.752
-024
0.000
14WF
105 psi
-1.83 0,000
-3.25
DOW
(1.58
D.845
-0.04
0.000
162'F
104 psi
-1]9 0.000
-3.26
0.000
ON
D'Sall
0.15
0.673
184'F
103 psi
-1.73 0.000
-3.25
0,000
0l9
1.034
0.33
1.240
206'F
102 psi
-1.67 0.000
-325
0,000
0.90
1.124
0.50
1.607
228-F
101 psi
-1.00 0.000
-3.23
0.000
1.02
1.208
0.65
1.848
250-F
100 psi
-1.52 0.000
-3.22
0.000
1.16
1.285
0.79
2.009
Note I: Wren xxxv, are seuMry of lin xak pWd Mlle IN, .a- ndn 611 am mwN ofxek mKl. edu-d
Nox,z "vipiltl'rvn Of eah ccae is miniaelM x,exely, Tax Rale will ax, ex Ilan ex vm of IN, araw,, of ne eam lel WAM
NWe15 1.kn lick. 11.... WSNeel-uHaw ffialiria,.0,'n n. dyed in Me rLalarlom
Zn<0.1
Comments:
!, Ip •
SsvleS 1OerTse
RSP202010
08
06
04
p02
N 00
02
a4
SAMPLE ID: 2 01 806 0266 82 COOK INLET ENERGY LLC, KUSTATAN PRODUCTION FACILITY. BLD. E - 8" OSP 3-PHA5E- CCKOI
Barite (BaSC4)
P ....... (pui)
109 100 107 106 IDS 104 103 102 101 100
S2 74 96 118 140 162 IM 206 220 250
T.mperaW. (n
Gypsum (CaSO4.2H2O)
Prerru.(0)
109 108 102 106 105 104 103 102 101 100
1.5 10
1.5 09 a
00 E
x .16 02
-16 06 $
-1] OS 4
t2 04
03
-le 02
B 01
19 00 6
52 24 96 110 140 162 184 206 228 250
Tempera.. (F)
..-SI ...m9/L'
Celestite (SrSO4)
P.s.. (psi)
109 100 1D2 106 105 104 103 102 101 100
00 10
D.2 09
04 OR a
E
06 02
x c
9 -OB 06 -
10 0.5 y
a -12 04 Q
10 03
16
02 •y-
10 01 G
20 00
52 24 96 118 140 162 104 206 220 250
TempemWre (F)
Iron Sulfide (FeS)
P.,;.. (0)
,D9 108 102 106 105 104 103 1 101 100
,q 4D a
x 12 35 E
30
0 -
c 2520
_
OB
06 ,ay
PID a
D4
02 05 It
0o
00
52 24 96 118 140 162 IM 206 228 250
Tempera.re (F)
-•-SI ...m9/1
52 74 M 118 140 162 184 206 220 250
Te.,.W. (n
_.-51 -.-mNL
Anhydrite (CaSO4)
Pressure (,I)
109 108 107 106 105 104 103 102 101 100
00 10
09
os 08 E
O]
9 10 06 O
05
P 1.5 - - p4 I
03 p
m -20 02
0.1 :
-is 00 n
52 24 96 118 140 162 181 206 228 2S0
Tempemture(n
-.-.51 --mg/P
Halite (NaCl)
P'.,Iu.(pal
109 108 102 106 105 104 1D3 102 101 100
31 10
31 09
31 08 E
x 32 02
06 3 32
Q OS G
z -32 04 u
-32 03
ol
32 02
33 0.1 6
d.3 0.0
52 24 96 118 140 162 184 2% us 250
Temperature (n
Iron Carbonate (FeCO3)
Pre55um(w)
109 108 102 1% 105 104 103 102 101 100
10 2
oe
O6
04
v02
—` Do
`s -02
-04
N -06
00
,0
12
52 24 96 110 140 162 IM 206 220 250
Temp.I.W.(F)
SCALE PREDICTIONS BASED ON FIELD PROVIDED DATA WITHER MODELING MAY 5E REQUIRED FOR VALIDATION OF SCALE PREDICTION RESULTS.
4
2
D
2
Calcite (CaCO3)
Pressve (,i)
109 108 107 106 L. 104 103 102 101 100
100
20
1.
90
..
1B160
eo
E
16
140
20
x 14120
0
v
c t2
.2
00
0LL
a 10
a
4.0
6
E O.BW
00
6
3
a
.6.0
'q
60 9
20
1.0
02
20 C
d
00
6
0.0
0
1.5 10
1.5 09 a
00 E
x .16 02
-16 06 $
-1] OS 4
t2 04
03
-le 02
B 01
19 00 6
52 24 96 110 140 162 184 206 228 250
Tempera.. (F)
..-SI ...m9/L'
Celestite (SrSO4)
P.s.. (psi)
109 100 1D2 106 105 104 103 102 101 100
00 10
D.2 09
04 OR a
E
06 02
x c
9 -OB 06 -
10 0.5 y
a -12 04 Q
10 03
16
02 •y-
10 01 G
20 00
52 24 96 118 140 162 104 206 220 250
TempemWre (F)
Iron Sulfide (FeS)
P.,;.. (0)
,D9 108 102 106 105 104 103 1 101 100
,q 4D a
x 12 35 E
30
0 -
c 2520
_
OB
06 ,ay
PID a
D4
02 05 It
0o
00
52 24 96 118 140 162 IM 206 228 250
Tempera.re (F)
-•-SI ...m9/1
52 74 M 118 140 162 184 206 220 250
Te.,.W. (n
_.-51 -.-mNL
Anhydrite (CaSO4)
Pressure (,I)
109 108 107 106 105 104 103 102 101 100
00 10
09
os 08 E
O]
9 10 06 O
05
P 1.5 - - p4 I
03 p
m -20 02
0.1 :
-is 00 n
52 24 96 118 140 162 181 206 228 2S0
Tempemture(n
-.-.51 --mg/P
Halite (NaCl)
P'.,Iu.(pal
109 108 102 106 105 104 1D3 102 101 100
31 10
31 09
31 08 E
x 32 02
06 3 32
Q OS G
z -32 04 u
-32 03
ol
32 02
33 0.1 6
d.3 0.0
52 24 96 118 140 162 184 2% us 250
Temperature (n
Iron Carbonate (FeCO3)
Pre55um(w)
109 108 102 1% 105 104 103 102 101 100
10 2
oe
O6
04
v02
—` Do
`s -02
-04
N -06
00
,0
12
52 24 96 110 140 162 IM 206 220 250
Temp.I.W.(F)
SCALE PREDICTIONS BASED ON FIELD PROVIDED DATA WITHER MODELING MAY 5E REQUIRED FOR VALIDATION OF SCALE PREDICTION RESULTS.
4
2
D
2
