REG - 88 Energy Limited - Quarterly Report and Appendix 5B
14/07/2022 07:00
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RNS Number : 4625S 88 Energy Limited 14 July 2022
14 July 2022
QUARTERLY ACTIVITIES REPORT
For the quarter ended 30 June 2022
88 Energy Limited (ASX:88E, AIM:88E, OTC:EEENF) (88 Energy or the Company)
provides the following report for the quarter ended 30 June 2022.
Highlights
Project Icewine (~75% WI)
· Icewine East third-party evaluation of the Shelf Margin Delta (SMD),
Slope Fan Set (SFS) and Basin Floor Fan (BFF) play fairways was completed in
May 2022, which interpreted all of Pantheon reservoir units (SMD, SFS, BFF) to
extend onto 88 Energy's Icewine East acreage.
· Completed in-depth petrophysical re-evaluation of Icewine-1 and
the broader Icewine East acreage, with results indicating comparable, or
better, reservoir quality in some reservoir units relative to those of
Pantheon's tested intervals which flowed oil.
· Licensing agreement executed with SAExploration, Inc. (SAE) for use of
SAE's Franklin Bluffs 3D seismic survey data (FB3D), covering a significant
area over the Icewine East leases, inculding areas over the SMD, SFS and BFF
reservoir units.
· Completion of independent resource report ongoing, scheduled in
early Q3 2022.
· Planning underway for a new exploration well expected to spud in
2023.
Project Peregrine (100% WI)
· Ongoing Merlin-2 post well studies to assess future exploration
potential.
· Multiple independent drill ready targets remain untested
(Harrier-1 & Merlin-1A).
· Merlin-2 demobilisation completed in April and majority of
invoices paid before quarter end.
Project Longhorn (~73% WI)
· Production (~70% oil) has increased over 70% since acquisition in
mid-February 2022
· Successful completion of two work-overs, with three of seven
planned for 2022 now completed.
· Quarterly cash flow distribution of A$1.3M received in June 2022.
Umiat Oil Field (100% WI)
· Studies commenced with an Alaskan drilling operator regarding use of a
new light-weight rig and optimised operations to drill a cost effective
exploration well designed to unlock further upside in Umiat Unit.
Corporate
· Cash of A$10.5M and no debt (as at 30 June 2022).
Project Icewine (~75% WI)
During the quarter, 88 Energy progressed further studies and analysis across
the Icewine East acreage, which included completing the mapping of the SMD,
SFS and BFF play fairways onto the Project Icewine East acreage. In May, the
Company announced that Jordan & Pay completed an independent evaluation of
the play fairways, utilising available well information from presentations
publicly released by neighbouring project proponent, Pantheon Resources plc
(AIM:PANR) (Pantheon) This was coupled with internal Company data (including
Icewine-1 and Icewine-2 well logs and existing 2D seismic) and concluded that
all Pantheon reservoir units (SMD, SFS, BFF) extended onto the Project Icewine
acreage.
Also during the quarter, the Company commissioned an in-depth petrophysical
re-evaluation of Icewine-1 and the broader Icewine East area by independent
petrophysical consultants (Stimulation Petrophysics Consulting, LLC and
Snowfall Energy LLC). The consultants focussed on assessing Icewine-1 logs
against intervals that flowed oil in Pantheon's acreage to the north.
Pleasingly, a comparison of the tested interval in Alkaid-1 against a similar
interval in Icewine-1 indicated favourable potential for a flow test of the
same zone in the Icewine East acreage.
Pantheon's wells - Alkaid-1, Talitha-A and Theta West-1 - all flowed 35 to
40⁰ API oil from multiple Brookian reservoirs. Pantheon's testing has
confirmed reservoir deliverability of light, sweet oil (see Pantheon releases
of 7 February and 21 February 2022), which 88 Energy believes is positive for
the prospectivity of the adjacent Project Icewine acreage. Data from the
Talitha-A and Theta West-1 wells are not yet publicly available and as a
result, only a qualitative comparison of these logs against Icewine-1 logs
have been carried out to date.
Given the favourable petrophysical comparison between Icewine-1 and Alkaid-1,
the Company is optimistic that a production test in the Icewine East acreage
could potentially yield a similar or better result than seen during the
testing of Alkaid-1. The Company also notes Pantheon's announcement of 7 July
2022 that it has spudded a horizontal production well in Alkaid, named
Alkaid#2, to prove up the development concept (see also Pantheon release of 24
January 2022 and Figure 2).
At the end of June, the Company signed a licensing agreement with SAE for the
use of SAE's Franklin Bluffs 3D seismic survey data (FB3D). The FB3D seismic
data was acquired in 2015 by SAE and covers approximately 86 square miles,
predominantly over the Icewine East acreage. More importantly, the FB3D
extends across an area where the SMD, SFS and BFF play fairways have been
independently mapped on the Icewine East acreage.
The FB3D data will assist the Company with carrying out its forthcoming
analysis, including Amplitude- The FB3D data will assist the Company with
carrying out its forthcoming analysis, including
Amplitude-variation-with-offset analysis (AVO analysis) and simultaneous
seismic inversion. These studies will aid the Company in defining 'sweet
spots' for each play and determining optimal drilling locations for future
exploration and appraisal wells.
88 Energy's initial license fee included US$2.0 in cash and US$1.0 million in
fully paid new ordinary shares in 88 Energy (approximately 181 million shares
at an issue price of A$0.008 per share, being the closing price of 88 Energy
shares on the ASX on 24 June 2022).
Other activities that the Company undertook in Q2 2022 included:
· Progressing the maiden Project Icewine East prospective resource
estimate, scheduled for completion early Q3 2022.
· Planning operations for 2023, which are targeted to include an
exploration well to be drilled in the Icewine East acreage, and at least one
flow test from the multiple Brookian reservoirs that have been mapped on the
Icewine East acreage. These are the same reservoirs that nearby Pantheon wells
- Alkaid-1, Talitha-A and Theta West-1 - have flowed 35⁰ to 40⁰ API oil.
Project Peregrine (100% WI)
The Merlin-2 well was designed to appraise the N20, N19 and N18 horizons which
were encountered in the Merlin-1 well drilled in 2021. The well was spudded on
7(th) Match 2022 and reached Total Depth (TD) of 7,334 feet on 22nd March
2022. All three Nanushuk targets (N20, N19 and N18) were penetrated during
drilling, with Logging While Drilling (LWD) data and physical cuttings
collected throughout the Merlin-2 program. Observations of LWD logs and drill
cuttings collected during drilling revealed target intervals were thicker than
those encountered in Merlin-1. Plugging, abandonment and demobilisation of the
Merlin-2 well was completed in April 2022.
The results of Merlin-2 are largely consistent with the Merlin-1 exploration
well drilled in 2021. Strong fluorescence, oil sheen, petroliferous odour and
cut noted in the drilling cuttings, elevated C2-C5 mud gas readings over the
target zones with total gas significantly above background gas readings and
also evidence from the reservoir sampling tool of moveable hydrocarbons.
Both Merlin wells were drilled on sparse, vintage 2D seismic data, which
provides a narrow field of view of the reservoir and limited optionality on
driling locations. 88 Energy will assess the merits of a future 3D seismic
acquisition program or an in-fill 2D program in order to define optimal play
fairways and determine the potential commerciality of the Project Peregrine
acreage.
The Company has commenced detailed analysis of all data obtained from the
Merlin-2 drilling program and will evaluate potential future appraisal
activities within the Project Peregrine acreage, which include independent
drilling locations such as the Harrier-1 prospect to test the N14 and N15
horizons.
In particular, during the quarter, the Company commenced an independent NPRA
basin modelling study to further improve 88 Energy's understanding of the
geological history and how it pertains to the Nanushuk reservoir quality
across Project Peregrine. Coupled with petrographic studies of Merlin
side-wall cores, the modelling will utilise available maximum Brookian uplift
/ erosion and burial depth data to produce qualitative reservoir risk maps of
the Nanushuk Formation which, will help inform how the Project Peregrine
reservoir quality varies Northward, away from the Merlin-1 and 2 locations.
This study is anticipated to be completed by Q3, 2022.
Yukon Leases (100% WI)
The Yukon Leases contain the 82 million barrel1 Cascade Prospect, which was
intersected peripherally by Yukon Gold-1 and classified as a historic oil
discovery. The Company continues to complete due diligence and commercial
assessment of a joint development with near-by resource owners.
1. Refer to 88 Energy release dated 7th November 2018. Note
cautionary statement on page 6.
Umiat Oil Field (100% WI)
In Q1 2021, 88 Energy acquired the Umiat Oil Field. As part of the
acquisition, the Company received the Umiat data pack which includes Umiat 3D
seismic data. The Umiat 3D survey abuts the southern edge of the Project
Peregrine lease blocks. Integrating the Linc/Malamute seismic interpretation
has provided a better understanding of the Peregrine reservoir geometries to
the north as well as enriching the Company's petrophysical database with
additional well control (Umiat-8 and Umiat-23H).
Internal reinterpretation of modern 3D seismic is suggestive of untested
reservoirs at Umiat. Prospects have been mapped in the footwall of the Umiat
structure as well as downdip from the proven oil zone in the hanging wall.
Initial internal volumetric calculations suggest there may be multi-million
barrels of potentially recoverable oil combined in the hanging wall and
footwall. Both prospects are deeper than the current reserves at Umiat which
the Company expects will have a positive impact on producibility.
Initial development studies, focusing on the potential integration of Ultra
Low Sulphur Diesel (ULSD) production, suggests that this development option
adds further value to a future Umiat development, considering the high cost of
diesel (~US$6-7/gal) on the North Slope of Alaska.
A separate Umiat-23H well performance review concluded that this well
significantly underperformed due to poor drilling and completion techniques.
This well was drilled in 2014 by a previous owner and flowed at a sustained
rate of 200 BOPD with no water, and a maximum rate of 800 BOPD. Further review
of the historical data includes a more conventional trajectory and completion
design for a 5,000ft horizontal section that was modelled to produce at
stabilised rates of between 800 and 1,600 BOPD. The Company believes an
opportunity exists for the optimisation of historic subsurface development
plans.
During the quarter, the Company commenced discussions with an Alaskan drilling
operator regarding use of a new light weight rig and optimised operations to
drill a cost-effective exploration well designed to unlock further upside in
Umiat.
Project Longhorn (~73% WI)
On 21 February 2022, 88 Energy executed a binding Securities Purchase
Agreement (SPA) for the acquisition of a ~73% average net working interest in
established conventional oil and gas production assets in the proven Permian
Basin, onshore Texas, U.S. The oil and gas assets, collectively known as
Project Longhorn contain certified net 2P reserves of 2.05MMBOE(1). The
purchase price for the acquisition was US$9.7M, consisting of US$7.2M cash and
US$2.5M in 88 Energy shares (~98.1 million shares at an issue price of A$0.035
per share). The acquisition represents the Company's first move into producing
oil and gas assets and is in line with Company's strategy to build a
successful oil and gas exploration and production Company.
During the quarter, the Company has been pleased with the progress at Project
Longhorn as the operator and ~24% net working interest partner, Lonestar I,
LLC (Lonestar), successfully completed the second and third of seven planned
capital-efficient work-overs scheduled in 2022. In line with the first
work-over, these were completed on time and on budget and have delivered a
significant increase to the total oil and gas production rates of Project
Longhorn.
Production from the Longhorn wells exceeded 650 BOE per day gross (over ~475
BOE per day net, approximately 70% oil) following completion of the third
work-over at the end of May, at initial production rates. Daily production
rates are anticipated to settle at around ~500 BOE per day gross (over ~365
BOE per day net, of which approximately 70% is oil) in Q3 2022, which
represents an overall output increase of ~70% since the completion of the
acquisition in mid-February 2022.
The production increase provides additional direct exposure to the higher WTI
oil and gas price environment and accelerates payback on both the acquisition
of the assets and the capital investment in the work-overs.
Given the success of the initial three work-overs this year, as well as the
continued high oil and gas price environment, during the quarter, the joint
venture participants agreed to accelerate the capital development program and
the completion of the remaining four planned work-overs this year. As part of
this agreement, 88 Energy has agreed to part fund its share of the anticipated
US$3.5 million (net) in development capital through the issuance of US$3.0
million in 88 Energy shares (approximately 544 million shares at an issue
price of A$0.008 per share, being the closing price of 88 Energy shares on the
ASX on 24 June 2022) to Lonestar, to fund Longhorn's working capital
contributions towards the remaining CY2022 capital development program
(Capital Development Shares).
Project Longhorn is now scheduled to complete the targeted seven capital
development activities earlier than planned during Q4 2022.
1. Further ASX Listing Rule 5.31 Information (Notes to Reserves) related to
these Reserves is provided in Appendix 1 of the announcement dated 21 February
2022 as released on ASX, AIM and OTCQB markets.
Reserves Cautionary Statement: Oil and gas reserves and resource estimates are
expressions of judgment based on knowledge, experience, and industry practice.
Estimates that were valid when originally calculated may alter significantly
when new information or techniques become available. Additionally, by their
very nature, reserve and resource estimates are imprecise and depend to some
extent on interpretations, which may prove to be inaccurate. As further
information becomes available through additional drilling and analysis, the
estimates are likely to change. This may result in alterations to development
and production plans which may, in turn, adversely impact the Company's
operations. Reserves estimates and estimates of future net revenues are, by
nature, forward looking statements and subject to the same risks as other
forward-looking statements.
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:
· Exploration and evaluation expenditure of (A$23.8M) [March 2022
quarter: A$16.4M], primarily associated with Merlin-2 drilling activities and
demobilisation. During the quarter, most of the final costs associated with
the Merlin-2 program were paid. US$2.0M was also paid to SAE as part of the
initial license fee for the FB3D data.
· Project Longhorn quarterly cash distribution of A$1.3M.
· Lease rental payments of A$0.5M, offset by Project Icewine joint
venture contributions of A$0.8M.
· Administration, staff, and other costs of A$1.3M.
At quarter end, the Company had cash reserves of A$10.5M and no debt.
Information required by ASX Listing Rule 5.4.3
Project Name Location Interest at beginning of Quarter Interest at end of Quarter
Net Area (acres)
Project Icewine Onshore, North Slope Alaska 192,830 ~75% ~75%
Project Peregrine Onshore, North Slope Alaska (NPR-A) 195,373 100% 100%
Project Longhorn Onshore, Permian Basin Texas 964 ~73% ~73%
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.
The graphics below can be viewed in the pdf version of this announcement,
which is available on the Company's website www.88energy.com:
· Figure 1: Third-party mapping indicates extension of all PANR prospect
play fairways into Project Icewine.
· Figure 2: The FB3D seismic data covers an area over the third-party
mapped SMD, SFS and BFF play fairways, which 88 Energy believes is an
extension of all Pantheon's prospect play fairways onto Icewine East.
· Figure 3: remaining Yukon acreage retained on State lands after
relinquishment of Tract 29 in ANWR. Tract 29 relinquished in Q2 2022 given
ongoing restrictions and inability to explore in lease / uncertainty when
drilling could occur - all fees were refunded to 88 Energy.
· Figure 4: Conceptual 3D model of Umiat Structure.
· Figure 5: Project Longhorn acreage.
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 Tel: +61 410 276 744
Andrew Edge / Michael Vaughan Tel: +61 422 602 720
EurozHartleys Ltd Tel: + 61 8 9268 2829
Dale Bryan
Cenkos Securities Tel: + 44 131 220 6939
Neil McDonald / Derrick Lee / Pearl Kellie
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 30 June 2022
Consolidated statement of cash flows Current quarter Year to date (6 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 (504) (1,326)
(e) administration and corporate costs (848) (1,755)
1.3 Dividends received (see note 3) - -
1.4 Interest received - 2
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 (1,352) (3,079)
2. Cash flows from investing activities - (10,694)
2.1 Payments to acquire or for:
(a) entities
(b) tenements (462) (1,311)
(c) property, plant and equipment - -
(d) exploration & evaluation (23,806) (40,245)
(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 822 831
- Distribution from Project Longhorn 1,324 1,921
2.6 Net cash from / (used in) investing activities (22,122) (49,498)
3. Cash flows from financing activities - 32,153
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 - (2,152)
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 - 30,001
4. Net increase / (decrease) in cash and cash equivalents for the period
4.1 Cash and cash equivalents at beginning of period 32,631 32,317
4.2 Net cash from / (used in) operating activities (item 1.9 above) (1,352) (3,079)
4.3 Net cash from / (used in) investing activities (item 2.6 above) (22,122) (49,498)
4.4 Net cash from / (used in) financing activities (item 3.10 above) - 30,001
4.5 Effect of movement in exchange rates on cash held 1,312 728
4.6 Cash and cash equivalents at end of period 10,469 10,469
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 flows) to the related items in the accounts
$A'000
$A'000
5.1 Bank balances 10,469 32,631
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) 10,469 32,631
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 198
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 available to the entity.
$US'000
$US'000
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) (1,352)
8.2 (Payments for exploration & evaluation classified as investing activities) (23,806)
(item 2.1(d))
8.3 Total relevant outgoings (item 8.1 + item 8.2) (25,158)
8.4 Cash and cash equivalents at quarter end (item 4.6) 10,469
8.5 Unused finance facilities available at quarter end (item 7.5) -
8.6 Total available funding (item 8.4 + item 8.5) 10,469
8.7 Estimated quarters of funding available (item 8.6 divided by item 8.3) 0.4
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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: 8.2 consists of Merlin-2 program costs which were fully covered by
existing cash reserves. Merlin 2 was plugged and demobilised in April 2022 and
final invoices will be paid in July 2022.
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: There is no requirement to raise further cash based on anticipated
expenditure and cash distributions from Project Longhorn in 2022.
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: The business expects to continue to meet its business objectives
including assessing opportunities across its Alaska portfolio and its rental
obligations as well as operating objectives for Project Longhorn
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: 14 July 2022
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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