REG - 88 Energy Limited - Quarterly Activities Report and Appendix 5B
25/01/2023 07:00
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RNS Number : 8035N 88 Energy Limited 25 January 2023
88 Energy Limited
Quarterly Activities Report
For the quarter ended 31 December 2022
88 Energy Limited (ASX:88E, AIM:88E, OTC:EEENF) (88 Energy or the Company)
provides the following report for the quarter ended 31 December 2022.
Highlights
Project Phoenix (formally Icewine East, ~75% WI)
· Hickory-1 exploration well scheduled to spud on or around 1 March
2023 targeting 647 million barrels of oil(1,2)
· Well location informed by extensive data suite analysis
Ø Located in the sweet spot of interpreted AVO anomalies
Ø Focused on the oil-bearing conventional reservoirs identified in adjacent
acreage and during the drilling and logging of Icewine 1
Ø Designed to appraise six targets within SMD, SFS, BFF and Kuparuk
reservoirs
Ø Strategically located proximate to significant, established infrastructure
· Drilling rig contract executed with Nordic Calista for Rig-2
· Permitting and planning on schedule to be completed end of
January 2023 or shortly thereafter, with the final well cost anticipated to be
lower than the previous Icewine wells on the acreage
Project Leonis (100% WI)
· Project Leonis secured as part of the North Slope Areawide 2022W
Oil and Gas lease sale
· Acreage includes ten leases covering ~25,600 contiguous acres,
subject to an adjudication process, regulatory approvals and formal award
expected in 1H 2023
· Project Leonis is covered by the existing Storms 3D seismic data
suite and contains the historical exploration well Hemi Springs Unit #3
(drilled by ARCO in 1985)
· A review of the Hemi Springs Unit #3 well indicated over 200 feet
of logged net pay in the Upper Schrader Bluff (USB) reservoir, with good
porosity and oil shows evident over the interval
· Initial internal interpretation of the Storms 3D indicates a
prospect at the USB reservoir interval that appears to be bound by faults on
three sides
Project Longhorn (~73% WI)
· Successful completion of the final two planned workovers
scheduled for 2022
· Quarterly cash flow distribution of A$1.5M received in December
2022
Corporate
· Cash of A$14.1M and no debt (as at 31 December 2022)
Cautionary Statement: The estimated quantities of petroleum that may be
potentially recovered by the application of a future development project
relate to undiscovered accumulations. These estimates have both an associated
risk of discovery and a risk of development. Further exploration, appraisal
and evaluation are required to determine the existence of a significant
quantity of potentially movable hydrocarbons.
1. Net mean total unrisked prospective resource.
2. Refer to the ASX release dated 23 August 2022 for full
details with respect to the Prospective Resource estimate, associated risking
and applicable Cautionary Statement.
Project Phoenix (formally Icewine East, ~75% WI)
The former Icewine East area was renamed Project Phoenix to reflect the
Company's refreshed exploration strategy for this acreage. Since its
acquisition in 2014, exploration on the acreage targeted the unconventional
HRZ play. Project Phoenix is focused on the oil-bearing conventional
reservoirs identified during the drilling and logging of Icewine-1 and
recently flow tested by Pantheon Resources(3). Project Phoenix is
strategically located on the Dalton Highway with the Trans-Alaska Pipeline
System running through the acreage.
The Company has received notice from the Alaska Department of Natural
Resources (DNR) that a recently submitted unit application covering the
Project Phoenix acreage was open for public comment until 31 December 2022.
The DNR is expected to issue a decision no later than 1 March 2023. The unit
approval will extend the leases for Project Phoenix beyond their primary term
and provide an agreed program to assess commercialisation of the acreage and a
pathway to development and production.
Hickory-1 Exploration Well
The Hickory-1 well is designed to appraise six conventional plays within the
SMD, SFS, BFF and KUP reservoirs targeting 647 million barrels of oil(1,2).
Spud of Hickory-1 is scheduled to occur in early March 2023 to a permitted
total depth of 12,500 feet. The well has been significantly de-risked by
recent Pantheon Resources(3) drilling and flow tests, interpretation of the
Icewine-1 well logs and modern Franklin Bluffs 3D seismic data (FB3D) and
associated AVO analysis.
The optimised drilling location intersects and will test, the substantial
potential oil volumes noted across all mapped play fairways, particularly the
SMD, SFS and BFF reservoirs.
Significant progress has been made on permitting and planning of Hickory-1 by
project manager, Fairweather, LLC. All long lead items have been secured with
the tendering process nearing completion. Further details of the drilling
program will be announced by the Company in the lead-up to the scheduled spud
on or around 1 March 2023, which remains subject to relevant approvals that
are anticipated to be received by end of January 2023 or shortly thereafter.
Drilling location for Hickory-1 was informed by analysis of an extensive data
suite and chosen to:
§ Provide optimal appraisal of six stacked reservoir targets
§ Ensure closest possible position to the Shelf Edge
§ Be of a relative down-dip position
§ Potentially unlock up-dip optionality across the remaining acreage
§ Within the sweet spot of interpreted AVO anomalies relative to Icewine-1
which the FB3D data confirms was drilled outside of interpreted AVO anomalies
at the target horizons
§ Maximise the strategic location proximate to existing infrastructure
1. Refer Cautionary statement
2. Mean unrisked resource - Net Entitlement to 88 Energy.
Refer announcement released to ASX on 23 August 2022
3. Refer to Pantheon Resources AIM releases 7 February, 21
February and 24 March 2022 for details in relation to flow tests
Project Leonis (100% WI)
On the 9 November 2022, the Company's wholly-owned subsidiary Captivate Energy
Alaska, Inc. was declared the highest bidder for select acreage offered as
part of the North Slope Areawide 2022W Oil and Gas lease sale. The Company's
new acreage will be known as Project Leonis (the Project) comprising ten
leases covering approximately 25,600 contiguous acres.
The new Project Leonis leases remain subject to an adjudication process,
regulatory approvals and formal award which is expected in 1H 2023. The
Project is superbly located adjacent to TAPS and the Dalton Highway, enhancing
future potential development commercialisation.
Figure 1: New Acreage awarded, named Project Leonis in relation to exiting 88E
acreage
Project Leonis is covered by the existing, recently purchased, Storms 3D
seismic data suite. The acreage contains the historical exploration well
Hemi Springs Unit #3, drilled by ARCO in 1985 to target the deep Kuparuk and
Ivishak reservoirs. At the time, these were the main producing intervals in
the giant northern fields.
An initial review of the Hemi Springs Unit #3 well indicated over 200 feet of
low resistivity bypassed log pay within the Upper Schrader Bluff (USB)
reservoir, with good porosity and oil shows evident over the interval. The USB
reservoir has been successfully developed at the nearby Orion, Polaris, West
Sak and Milne Point oil fields.
A preliminary internal review and interpretation of the Storms 3D seismic data
reveals a strong seismic-well tie and a clear seismic amplitude at the USB
prospect level. Encouragingly, the prospect appears to be bound by faults on
three sides which potentially serve as the trapping mechanism. Further
analysis will determine further potential of the acreage and define a possible
exploration program and timeline for the project.
Figure 2: Hemi Springs Unit #3 well and initial interpretation of regional
faulting
Project Peregrine (100% WI)
Similarly, to Merlin-1, the Merlin-2 High Resolution Gas Chromatography side
wall core results show definitive evidence of hydrocarbons at Project
Peregrine.
Results of a recent, independent basin modelling study, coupled with abundant
oil shows across Merlin-1 and Merlin-2, are encouraging for untested Harrier
and Harrier Deep prospects to the North.
The Company is currently assessing possible forward work-programs, which will
be subject to potential future farm-out.
Project Longhorn (~73% WI)
During the quarter, the operator and ~24% net working interest partner,
Lonestar I, LLC (Lonestar), successfully completed the final two planned
workovers scheduled for 2022. The workovers were completed on time and
commenced production, with plans in place to optimise oil and gas rates from
each well.
Production from the Longhorn wells averaged ~420 BOE per day gross (~70% oil)
during the quarter, peaking at 580 BOE per day gross.
Since acquisition, the Longhorn investment has resulted in net cash flow
returns to 88E of A$4.3M. Net cash flows from operations before capital
investment, generated A$6.5M in 2022. The Company's share of capital invested
in the six completed work overs for 2022 was A$9.1M of which A$2.2M was paid
in cash and the remaining A$6.9M (US$4.6M) in 88E shares(1,2)
Four workovers and at least six new drill targets remain on the acreage, with
the forward work program and timing for future capital investments to be
determined by the Joint Venture in 2023.
1. Refer ASX announcement 21 February 2022 - working capital
share issue of US$1.6 million
2. Refer ASX announcement 27 June 2022 - working capital share
issue of US$3.0 million
Finance
The ASX Appendix 5B attached to this quarterly report contains the Company's
cash flow statement for the quarter. The material cash flows for the period
were:
§ Project Longhorn quarterly cash distribution of A$1.5M
§ Exploration and evaluation expenditure of A$3.3M (September 2022 quarter:
A$5.7M), primarily associated with planning, securing long lead items, and
permitting for Hickory-1 exploration well
§ Lease rental payments of A$0.3M, including bid deposit for Project Leonis
acreage
§ Fees paid to Directors and consulting fees paid to Directors of A$0.2M
§ Administration, staff, and other costs of A$1.2M (incl A$0.2M director
related payments)
At quarter end, the Company had cash reserves of A$14.1M and no debt.
Information required by ASX Listing Rule 5.4.3
Project Name Location Net Area (acres) Interest at beginning of Quarter Interest at end of Quarter
Project Phoenix Onshore, North Slope Alaska 62,324 ~75% ~75%
Project Icewine West Onshore, North Slope Alaska 121,996 ~75% ~75%
Project Peregrine Onshore, North Slope Alaska (NPR-A) 195,373 100% 100%
Project Longhorn Onshore, Permian Basin Texas 964 ~73% ~73%
Project Leonis(1) Onshore, North Slope Alaska 25,600 0% 100%
Umiat Unit Onshore, North Slope Alaska (NPR-A) 17,633 100% 100%
Yukon Leases Onshore, North Slope Alaska 15,235 100% 100%
Pursuant to the requirements of the ASX Listing Rules Chapter 5 and the AIM
Rules for Companies, the technical information and resource reporting
contained in this announcement was prepared by, or under the supervision of,
Dr Stephen Staley, who is a Non-Executive Director of the Company. Dr Staley
has more than 35 years' experience in the petroleum industry, is a Fellow of
the Geological Society of London, and a qualified Geologist / Geophysicist who
has sufficient experience that is relevant to the style and nature of the oil
prospects under consideration and to the activities discussed in this
document. Dr Staley has reviewed the information and supporting documentation
referred to in this announcement and considers the prospective resource
estimates to be fairly represented and consents to its release in the form and
context in which it appears. His academic qualifications and industry
memberships appear on the Company's website and both comply with the criteria
for "Competence" under clause 3.1 of the Valmin Code 2015. Terminology and
standards adopted by the Society of Petroleum Engineers "Petroleum Resources
Management System" have been applied in producing this document.
1. leases remain subject to an adjudication process,
regulatory approvals and formal award which is expected in 1H 2023.
This announcement has been authorised by the Board.
Media and Investor Relations:
88 Energy Ltd
Ashley Gilbert, Managing Director
Tel: +61 8 9485 0990
Email:investor-relations@88energy.com
Fivemark Partners, Investor and Media Relations
Andrew Edge Tel: +61 410 276 744
Michael Vaughan Tel: +61 422 602 720
EurozHartleys Ltd
Dale Bryan Tel: + 61 8 9268 2829
Cenkos Securities Plc Tel: +44 (0)20 7397 8900
Derrick Lee Tel: +44 (0)131 220 6939
Pearl Kellie Tel: +44 (0)131 220 9775
Appendix 5B
Mining exploration entity or oil and gas exploration entity
quarterly cash flow report
Name of entity
88 Energy Limited
ABN Quarter ended ("current quarter")
80 072 964 179 31 December 2022
Consolidated statement of cash flows Current quarter Year to date (12 months)
$A'000
$A'000
1. Cash flows from operating activities - -
1.1 Receipts from customers
1.2 Payments for - -
(a) exploration & evaluation
(b) development - -
(c) production - -
(d) staff costs (561) (2,388)
(e) administration and corporate costs (618) (2,519)
1.3 Dividends received (see note 3) - -
1.4 Interest received 13 20
1.5 Interest and other costs of finance paid - -
1.6 Income taxes paid - -
1.7 Government grants and tax incentives - -
1.8 Other - -
1.9 Net cash from / (used in) operating activities (1,166) (4,887)
2. Cash flows from investing activities - (10,694)
2.1 Payments to acquire or for:
(a) entities
(b) tenements (326) (3,369)
(c) property, plant and equipment - -
(d) exploration & evaluation (3,343) (49,275)
(e) investments - -
(f) other non-current assets - -
2.2 Proceeds from the disposal of: - -
(a) entities
(b) tenements - -
(c) property, plant and equipment - -
(d) investments - -
(e) other non-current assets - -
2.3 Cash flows from loans to other entities - -
2.4 Dividends received (see note 3) - -
2.5 Other - Joint Venture Contributions 19 1,079
Other - Distribution from Project Longhorn 1,465 4,282
Other - Return of Bond - 138
2.6 Net cash from / (used in) investing activities (2,185) (57,839)
3. Cash flows from financing activities - 47,053
3.1 Proceeds from issues of equity securities (excluding convertible debt
securities)
3.2 Proceeds from issue of convertible debt securities - -
3.3 Proceeds from exercise of options - -
3.4 Transaction costs related to issues of equity securities or convertible debt - (3,150)
securities
3.5 Proceeds from borrowings - -
3.6 Repayment of borrowings - -
3.7 Transaction costs related to loans and borrowings - -
3.8 Dividends paid - -
3.9 Other (provide details if material) - -
3.10 Net cash from / (used in) financing activities - 43,903
4. Net increase / (decrease) in cash and cash equivalents for the period
4.1 Cash and cash equivalents at beginning of period 17,525 32,317
4.2 Net cash from / (used in) operating activities (item 1.9 above) (1,166) (4,887)
4.3 Net cash from / (used in) investing activities (item 2.6 above) (2,185) (57,839)
4.4 Net cash from / (used in) financing activities (item 3.10 above) 0 43,903
4.5 Effect of movement in exchange rates on cash held (51) 629
4.6 Cash and cash equivalents at end of period 14,123 14,123
5. Reconciliation of cash and cash equivalents Current quarter Previous quarter
at the end of the quarter (as shown in the consolidated statement of cash
$A'000
$A'000
flows) to the related items in the accounts
5.1 Bank balances 14,123 17,525
5.2 Call deposits - -
5.3 Bank overdrafts - -
5.4 Other (provide details) - -
5.5 Cash and cash equivalents at end of quarter (should equal item 4.6 above) 14,123 17,525
6. Payments to related parties of the entity and their associates Current quarter
$A'000
6.1 Aggregate amount of payments to related parties and their associates included 201
in item 1
6.2 Aggregate amount of payments to related parties and their associates included -
in item 2
Note: if any amounts are shown in items 6.1 or 6.2, your quarterly activity
report must include a description of, and an explanation for, such payments.
6.1 Payments relate to Director and consulting fees paid to
Directors. All transactions involving directors and associates were on normal
commercial terms.
7. Financing facilities Total facility amount at quarter end Amount drawn at quarter end
Note: the term "facility' includes all forms of financing arrangements
$US'000
$US'000
available to the entity.
Add notes as necessary for an understanding of the sources of finance
available to the entity.
7.1 Loan facilities - -
7.2 Credit standby arrangements - -
7.3 Other (please specify) - -
7.4 Total financing facilities - -
7.5 Unused financing facilities available at quarter end -
7.6 Include in the box below a description of each facility above, including the
lender, interest rate, maturity date and whether it is secured or unsecured.
If any additional financing facilities have been entered into or are proposed
to be entered into after quarter end, include a note providing details of
those facilities as well.
8. Estimated cash available for future operating activities $A'000
8.1 Net cash from / (used in) operating activities (item 1.9) (1,166)
8.2 (Payments for exploration & evaluation classified as investing activities) (3,343)
(item 2.1(d))
8.3 Total relevant outgoings (item 8.1 + item 8.2) (4,509)
8.4 Cash and cash equivalents at quarter end (item 4.6) 14,123
8.5 Unused finance facilities available at quarter end (item 7.5) -
8.6 Total available funding (item 8.4 + item 8.5) 14,123
8.7 Estimated quarters of funding available (item 8.6 divided by item 8.3) 3.1
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7.
8.8 If item 8.7 is less than 2 quarters, please provide answers to the following
questions:
8.8.1 Does the entity expect that it will continue to have the current
level of net operating cash flows for the time being and, if not, why not?
Answer:
8.8.2 Has the entity taken any steps, or does it propose to take any
steps, to raise further cash to fund its operations and, if so, what are those
steps and how likely does it believe that they will be successful?
Answer:
8.8.3 Does the entity expect to be able to continue its operations and
to meet its business objectives and, if so, on what basis?
Answer:
Note: where item 8.7 is less than 2 quarters, all of questions 8.8.1, 8.8.2
and 8.8.3 above must be answered.
Compliance statement
1 This statement has been prepared in accordance with accounting
standards and policies which comply with Listing Rule 19.11A.
2 This statement gives a true and fair view of the matters
disclosed.
Date: 25 January 2023
Authorised by: By the Board
(Name of body or officer authorising release - see note 4)
Notes
1. This quarterly cash flow report and the accompanying
activity report provide a basis for informing the market about the entity's
activities for the past quarter, how they have been financed and the effect
this has had on its cash position. An entity that wishes to disclose
additional information over and above the minimum required under the Listing
Rules is encouraged to do so.
2. If this quarterly cash flow report has been prepared in
accordance with Australian Accounting Standards, the definitions in, and
provisions of, AASB 6: Exploration for and Evaluation of Mineral Resources and
AASB 107: Statement of Cash Flows apply to this report. If this quarterly cash
flow report has been prepared in accordance with other accounting standards
agreed by ASX pursuant to Listing Rule 19.11A, the corresponding equivalent
standards apply to this report.
3. Dividends received may be classified either as cash flows
from operating activities or cash flows from investing activities, depending
on the accounting policy of the entity.
4. If this report has been authorised for release to the
market by your board of directors, you can insert here: "By the board". If it
has been authorised for release to the market by a committee of your board of
directors, you can insert here: "By the [name of board committee - eg Audit
and Risk Committee]". If it has been authorised for release to the market by a
disclosure committee, you can insert here: "By the Disclosure Committee".
5. If this report has been authorised for release to the
market by your board of directors and you wish to hold yourself out as
complying with recommendation 4.2 of the ASX Corporate Governance Council's
Corporate Governance Principles and Recommendations, the board should have
received a declaration from its CEO and CFO that, in their opinion, the
financial records of the entity have been properly maintained, that this
report complies with the appropriate accounting standards and gives a true and
fair view of the cash flows of the entity, and that their opinion has been
formed on the basis of a sound system of risk management and internal control
which is operating effectively.
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