TIDMSOUC
RNS Number : 8935A
Southern Energy Corp.
30 May 2023
SOUTHERN ENERGY CORP. ANNOUNCES FIRST QUARTER 2023 FINANCIAL AND
OPERATING RESULTS
Calgary, Alberta - May 30, 2023 - Southern Energy Corp.
("Southern" or the "Company") (TSXV:SOU) (AIM:SOUC)(OTCQX:SOUTF),
an established producer with natural gas and light oil assets in
Mississippi, announces its first quarter financial and operating
results for the three months ended March 31, 2023. Selected
financial and operational information is outlined below and should
be read in conjunction with the Company's unaudited consolidated
financial statements (the "Financial Statements") and related
management's discussion and analysis (the "MD&A") for the three
months ended March 31, 2023, which are available on the Company's
website at www.southernenergycorp.com and have been filed on
SEDAR.
All figures referred to in this news release are denominated in
U.S. dollars, unless otherwise noted.
FIRST QUARTER 2023 HIGHLIGHTS
-- Generated $1.7 million of adjusted funds flow from
operations[1] in Q1 2023 ($0.01 per share basic and diluted)
-- Net loss of $1.1 million in Q1 2023 ($0.01 loss per share
basic and diluted), compared to a net loss of $1.9 million in Q1
2022
-- Petroleum and natural gas sales were $5.2 million in Q1 2023
-- Maintained balance sheet strength with net debt(1) to
adjusted funds flow from operations ratio of 1.2x on a trailing
twelve month basis down from 2.6x in the first quarter of 2022
-- Average production of 15,643 Mcfe/d[2] (2,607 boe/d) (95%
natural gas) during Q1 2023, an increase of 36% from the same
period in 2022
-- Average realized natural gas and oil prices for Q1 2023 of
$3.25/Mcf and $75.73/bbl, respectively, reflecting the benefit of
strategic access to premium-priced U.S. sales hubs in a geographic
region with strong industrial and power generation natural gas
demand
-- Drilled six net wells at Gwinville in Q1 2023 from three
padsites, with each subsequent pad drilling operation resulting in
fewer drilling days per well depth adjusted
-- 2022 Year End Reserves Upgrade:
o Highlights of the Company's year end independent oil and gas
reserves evaluation as at December 31, 2022 (the "NSAI Report")
prepared by independent qualified reserves evaluator Netherland,
Sewell & Associates, Inc. ("NSAI") include:
-- an increase in proved developed producing ("PDP") reserves of
25% to 6.2 MMboe
-- an increase in total proved ("1P") reserves of 44% to 14.1
MMboe
-- an increase in total proved plus probable ("2P") reserves by
31% to 25.5 MMboe in 2022
-- before-tax net present value ("NPV") of 2P reserves,
discounted at 10% ("NPV10"), of $142.5 million (an increase of 61%
on year end 2021)
-- Top performing energy stock in the 2023 TSX Venture 50(TM)
based on equal weighting of performance during 2022 across three
key indictors: market capitalization growth, share price
appreciation, and trading volume
SUBSEQUENT EVENTS
-- As announced on May 23, 2023, Southern entered into a
strategic and highly synergistic purchase and sale agreement to
acquire 400 boe/d (99% natural gas) for cash consideration of $3.2
million in Gwinville with an expected close date of June 1, 2023
(the "Acquisition")
Ian Atkinson, President and CEO of Southern, commented:
"Q1 2023 was a great operational quarter for Southern as we
wrapped up our seven horizontal well drilling program at Gwinville,
with improved drilling time and cost efficiencies, which will lead
to future cost savings when we re-ignite our organic growth at more
supportive commodity prices. We are encouraged by the outlook of
supply and demand dynamics for U.S. natural gas and are well set to
immediately capitalize on gas prices with production behind pipe
which can be brought on stream in a very short time scale.
Additionally, we are extremely excited to consolidate the Gwinville
field with the recently announced asset Acquisition. This
Acquisition, which will be seamlessly incorporated with our current
operations and staff, provides significant cost synergies, stable,
low-decline production and additional high quality drilling
locations to compliment our current drilling inventory. These are
precisely the type of accretive transactions that we are looking
for to expedite reaching our goal to reach 25,000 boe/d. As a
low-cost producer attracting premium pricing, we feel that we have
the right assets in the right locations that will provide long term
value to shareholders and continue to look for further comparable
opportunities."
Financial Highlights
Three months ended March 31,
(000s, except $ per share) 2023 2022
--------------------------------------------------- --------------- --------------
Petroleum and natural gas sales $ 5,189 $ 5,925
Net loss (1,120) (1,855)
Net loss per share
Basic (0.01) (0.02)
Fully diluted (0.01) (0.02)
Adjusted funds flow from operations (1) 1,745 2,234
Adjusted funds flow from operations per share (1)
Basic 0.01 0.03
Fully diluted 0.01 0.03
Capital expenditures 34,892 6,872
Weighted average shares outstanding
Basic 138,591 78,153
Fully diluted 138,591 78,153
As at period end
Basic common shares outstanding 139,010 78,200
Total assets 108,609 48,534
Non-current liabilities 14,543 11,777
Net debt (1) $ (19,731) $ (10,745)
--------------------------------------------------- --------------- --------------
Note:
(1) See "Reader Advisories - Specified Financial Measures".
Operational Update
On March 29, 2023, the Company concluded operations on the
current drilling campaign which included seven new horizontal wells
into three separate productive horizons from three distinct
padsites in the Gwinville Field. The program added three Upper
Selma Chalk wells, two Lower Selma Chalk wells and two City Bank
wells. The drilling campaign was initially planned for 13
horizontal wells, but the Company paused the capital program in
response to the weaker natural gas pricing in the first quarter of
the year to maintain balance sheet discipline.
Southern is extremely happy with the field execution performance
from this program, highlighted by drilling efficiencies which saw
the average time from spud to total depth of the Selma Chalk wells
reduced from approximately 20 days in Southern's three well
appraisal program in 2022 to below 10 days by the final padsite in
Q1 2023. The majority of the wells in the program came in at or
below the initial drilling and completion cost estimates, despite
more than 80% of the cost structure being fixed due to long term
contracts for materials and major services locked in during the
highly inflationary second half of 2022. With the learnings and
efficiencies achieved in this campaign, Southern is planning for
all future horizontal drilling in Gwinville to utilize an optimized
wellbore design change that will remove the intermediate casing
string and all associated costs which the Company expects will
reduce the per-well drilling costs by 20-25%. This will allow the
Company to reinitiate its organic growth plans at lower future gas
prices than what was previously contemplated.
Comparing key performance indicators from the drilling and
completion operations in this program to the appraisal program from
2022, Southern achieved a 6% reduction in drilling costs per
lateral foot (down to $644/ft) and a greater than 22% reduction in
completion costs per lateral foot (down to $615/ft). Further,
compared to the early generation horizontal activity between 2005
and 2009 on the asset by the previous operator, one of the largest
independent upstream oil and natural gas companies in the U.S., on
an inflation adjusted basis, Southern achieved a greater than 30%
reduction in both drilling and completion costs per lateral
foot.
The Company continues to flow back its first City Bank Hz well
at Gwinville 18-10 #1, with load fluid recovery of approximately
13%. Based on historical vertical and early generation horizontal
well completions in the City Bank reservoir in Gwinville, peak gas
rates are not expected until the load fluid recovery is closer to
20+%, which is expected to be towards the end of Q2 2023. Gas rates
are encouraging and continue to improve and Southern is excited to
provide further operational updates in Q2 2023 as the modern
generation City Bank type curve results are established.
Remediation plans for the 18-10 #3 Upper Selma Chalk well that
experienced a mechanical integrity issue with the production casing
during completion operations continue to be finalized, with field
execution expected in late Q2 2023. The 18-10 #3 well was drilled
to a total lateral length of 5,091 ft, achieved 80% of the lateral
placed in the targeted porosity zone and was successfully completed
in 44 stages prior to the mechanical issue.
The four wells that are awaiting completion include the first
two Lower Selma Chalk laterals, along with the second City Bank
lateral and one Upper Selma Chalk lateral. These four wells are
some of Southern's longest laterals to-date. They were drilled with
an average lateral length of approximately 5,400 ft and were
steered within the high-graded intervals for an average of 95% of
the wellbore length. The two padsites can be brought on production
within a matter of weeks once completion operations are resumed. At
current strip pricing, Southern could commence completion
operations in Q4 2023.
Outlook
With a moderated capital program due to low commodity prices,
Southern has left four drilled, uncompleted wells ("DUCs") that can
be quickly completed and brought online through Southern's 100%
owned equipment at higher natural gas prices. After closing the
above-mentioned Acquisition anticipated on June 1, 2023, Southern
expects to have approximately $14.5 million of unused capacity on
its senior secured term loan (the "Credit Facility"), which can be
utilized to complete the DUCs at supportive natural gas prices.
As part of its risk management and sustainability strategy,
Southern has entered into both a fixed basis and a fixed price swap
in order to mitigate some of the volatility of the natural gas
prices going forward. In Q1 2023, Southern entered into a basis
swap transaction to secure a premium to NYMEX of $0.32 per MMBtu on
1,000 MMBtu/d from April 1, 2023 to October 31, 2023. Subsequent to
March 31, 2023, Southern entered into a fixed price hedge on 1,000
MMBtu/d of production at a price of $3.88/MMBtu from January 1,
2024 to December 31, 2025. To further protect against the
volatility, the Company continues to monitor the basis differential
prices and is prepared to hedge additional basis exposure at
elevated basis premiums.
Southern thanks all of its stakeholders for their ongoing
support and looks forward to providing future updates on
operational activities and continuing to create shareholder
value.
Qualified Person's Statement
Gary McMurren, COO, who has over 22 years of relevant experience
in the oil industry, has approved the technical information
contained in this announcement. Mr. McMurren is registered as a
Professional Engineer with the Association of Professional
Engineers and Geoscientists of Alberta and received a Bachelor of
Science degree in Chemical Engineering (with distinction) from the
University of Alberta.
For further information about Southern, please visit our website
at www.southernenergycorp.com or contact :
Southern Energy Corp.
Ian Atkinson (President and CEO) +1 587 287 5401
Calvin Yau (CFO) +1 587 287 5402
Strand Hanson Limited - Nominated & Financial
Adviser
James Spinney / James Bellman +44 (0) 20 7409 3494
Canaccord Genuity - Joint Broker
Henry Fitzgerald-O'Connor / James Asensio +44 (0) 20 7523 8000
Stifel Nicolaus Europe Limited - Joint Broker
Callum Stewart / Ashton Clanfield +44 (0) 20 7710 7600
Tennyson Securities - Joint Broker
Peter Krens / Pav Sanghera +44 (0) 20 7186 9033
Camarco
Owen Roberts / Billy Clegg / Hugo Liddy +44 (0) 20 3757 4980
About Southern Energy Corp.
Southern Energy Corp. is a natural gas exploration and
production company characterized by a stable, low-decline
production base, a significant low-risk drilling inventory and
strategic access to premium commodity pricing in North America.
Southern has a primary focus on acquiring and developing
conventional natural gas and light oil resources in the southeast
Gulf States of Mississippi, Louisiana, and East Texas. Our
management team has a long and successful history working together
and have created significant shareholder value through accretive
acquisitions, optimization of existing oil and natural gas fields
and the utilization of re-development strategies utilizing
horizontal drilling and multi-staged fracture completion
techniques.
READER ADVISORY
MCFE Disclosure . Natural gas liquids volumes are recorded in
barrels of oil (bbl) and are converted to a thousand cubic feet
equivalent (Mcfe) using a ratio of six (6) thousand cubic feet to
one (1) barrel of oil (bbl). Natural gas volumes recorded in
thousand cubic feet (Mcf) are converted to barrels of oil
equivalent (boe) using the ratio of six (6) thousand cubic feet to
one (1) barrel of oil (bbl). Mcfe and boe may be misleading,
particularly if used in isolation. A boe conversion ratio of 6
mcf:1 bbl or a Mcfe conversion ratio of 1 bbl:6 Mcf is based in an
energy equivalency conversion method primarily applicable at the
burner tip and does not represent a value equivalency at the
wellhead. In addition, given that the value ratio based on the
current price of oil as compared with natural gas is significantly
different from the energy equivalent of six to one, utilizing a boe
conversion ratio of 6 Mcf:1 bbl or a Mcfe conversion ratio of 1
bbl:6 Mcf may be misleading as an indication of value.
Throughout this press release, "crude oil" or "oil" refers to
light and medium crude oil product types as defined by National
Instrument 51-101 - Standards of Disclosure for Oil and Gas
Activities ("NI 51-101"). References to "NGLs" throughout this
press release comprise pentane, butane, propane, and ethane, being
all NGLs as defined by NI 51-101. References to "natural gas"
throughout this press release refers to conventional natural gas as
defined by NI 51-101.
Unit Cost Calculation. For the purpose of calculating unit
costs, natural gas volumes have been converted to a boe using six
thousand cubic feet equal to one barrel unless otherwise stated. A
boe conversion ratio of 6:1 is based upon an energy equivalency
conversion method primarily applicable at the burner tip and does
not represent a value equivalency at the wellhead. This conversion
conforms with National Instrument 51 101 - Standards of Disclosure
for Oil and Gas Activities. Boe may be misleading, particularly if
used in isolation.
Reserves and Future Net Revenue Disclosure. All reserves values,
future net revenue and ancillary information contained in this
press release are derived from the NSAI Report unless otherwise
noted. The NSAI Report was prepared in accordance with definitions,
standards and procedures contained in NI 51-101 and the most recent
publication of the Canadian Oil and Gas Evaluation Handbook (the
"COGEH"). Additional reserves information as required under NI
51-101 is included in the Company's Annual Information Form for the
year ended December 31, 2022 (the "AIF"), which is available on the
Company's SEDAR profile at www.sedar.com.
All reserve references in this press release are "Company gross
reserves". Company gross reserves are the Company's total working
interest reserves before the deduction of any royalties payable by
the Company. There is no assurance that the forecast price and cost
assumptions applied by NSAI in evaluating Southern's reserves will
be attained, and variances could be material. All reserves assigned
in the NSAI Report are located in the State of Mississippi and
presented on a consolidated basis.
All evaluations and summaries of future net revenue are stated
prior to the provision for interest, debt service charges or
general and administrative expenses and after deduction of
royalties, operating costs, estimated well abandonment and
reclamation costs and estimated future capital expenditures. It
should not be assumed that the estimates of future net revenues
represent the fair market value of the reserves. The recovery and
reserve estimates of Southern's crude oil, natural gas liquids and
natural gas reserves provided herein are estimates only and there
is no guarantee that the estimated reserves will be recovered.
Actual crude oil, natural gas and natural gas liquids reserves may
be greater than or less than the estimates provided herein. There
are numerous uncertainties inherent in estimating quantities of
crude oil, reserves and the future cash flows attributed to such
reserves. The reserve and associated cash flow information set
forth herein are estimates only.
Proved reserves are those reserves that can be estimated with a
high degree of certainty to be recoverable. It is likely that the
actual remaining quantities recovered will exceed the estimated
proved reserves. Probable reserves are those additional reserves
that are less certain to be recovered than proved reserves. It is
equally likely that the actual remaining quantities recovered will
be greater or less than the sum of the estimated proved plus
probable reserves. Proved developed producing reserves are those
reserves that are expected to be recovered from completion
intervals open at the time of the estimate. These reserves may be
currently producing or, if shut-in, they must have previously been
on production, and the date of resumption of production must be
known with reasonable certainty. Undeveloped reserves are those
reserves expected to be recovered from known accumulations where a
significant expenditure (e.g., when compared to the cost of
drilling a well) is required to render them capable of production.
They must fully meet the requirements of the reserves category
(proved, probable, possible) to which they are assigned. Certain
terms used in this press release but not defined are defined in NI
51-101, CSA Staff Notice 51-324 - Revised Glossary to NI 51-101,
Standards of Disclosure for Oil and Gas Activities ("CSA Staff
Notice 51-324") and/or the COGEH and, unless the context otherwise
requires, shall have the same meanings herein as in NI 51-101, CSA
Staff Notice 51-324 and the COGEH, as the case may be.
Abbreviations . Please see below for a list of abbreviations
used in this press release.
bbl barrels
bbl/d barrels per day
boe barrels of oil
boe/d barrels of oil per day
Mcf thousand cubic feet
Mcf/d thousand cubic feet per day
MMcf million cubic feet
MMcf/d million cubic feet per day
Mcfe thousand cubic feet equivalent
Mcfe/d thousand cubic feet equivalent per day
MMBtu million British thermal units
MMBtu/d million British thermal units per day
Forward Looking Statements . Certain information included in
this press release constitutes forward-looking information under
applicable securities legislation. Forward-looking information
typically contains statements with words such as "anticipate",
"believe", "expect", "plan", "intend", "estimate", "propose",
"project" or similar words suggesting future outcomes or statements
regarding an outlook. Forward-looking information in this press
release may include, but is not limited to, statements concerning
the Company's asset base including the development of the Company's
assets, oil and natural gas production levels, including the
objective of achieving production of 25,000 boe/d, the Company's
capital budget, expectations regarding material reserves,
anticipated operational results in 2023 including, but not limited
to, capital expenditures and drilling plans, expectations regarding
commodity prices, the performance characteristics of the Company's
oil and natural gas properties, the Company's hedging strategy, the
ability of the Company to achieve drilling success consistent with
management's expectations, the sources of funding for the Company's
activities, the effect of market conditions and the COVID-19
pandemic on the Company's performance, Southern's planned ESG
initiatives, expectations regarding the use of proceeds from all
sources, including the Company's credit facilities, the
availability and renewal of the Credit Facility and future
amendments thereto, future organic and inorganic growth and
acquisition opportunities within the resource market, and
costs/debt reducing activities. Statements relating to "reserves"
and "recovery" are also deemed to be forward- looking statements,
as they involve the implied assessment, based on certain estimates
and assumptions, that the reserves described exist in the
quantities predicted or estimated and that the reserves can be
profitably produced in the future.
The forward-looking statements contained in this press release
are based on certain key expectations and assumptions made by
Southern, including the timing of and success of future drilling,
development and completion activities, the performance of existing
wells, the performance of new wells, the availability and
performance of drilling rigs, facilities and pipelines, the
geological characteristics of Southern's properties, the
characteristics of the Company's assets, the successful application
of drilling, completion and seismic technology, the benefits of
current commodity pricing hedging arrangements, Southern's ability
to enter into future derivative contracts on acceptable terms,
Southern's ability to secure financing on acceptable terms,
prevailing weather conditions, prevailing legislation, as well as
regulatory and licensing requirements, affecting the oil and gas
industry, the Company's ability to obtain all requisite permits and
licences, prevailing commodity prices, price volatility, price
differentials and the actual prices received for the Company's
products, royalty regimes and exchange rates, the impact of
inflation on costs, the application of regulatory and licensing
requirements, the Company's ability to obtain all requisite permits
and licences, the availability of capital, labour and services, the
creditworthiness of industry partners, and the Company's ability to
source and complete asset acquisitions.
Although Southern believes that the expectations and assumptions
on which the forward-looking statements are based are reasonable,
undue reliance should not be placed on the forward-looking
statements because Southern can give no assurance that they will
prove to be correct. Since forward-looking statements address
future events and conditions, by their very nature they involve
inherent risks and uncertainties. Actual results could differ
materially from those currently anticipated due to a number of
factors and risks. These include, but are not limited to, risks
associated with the oil and gas industry in general (e.g.,
operational risks in development, exploration and production; the
uncertainty of reserve estimates; the uncertainty of estimates and
projections relating to production, costs and expenses, regulatory
risks, and health, safety and environmental risks), constraint in
the availability of labour, supplies, or services, the impact of
COVID-19 and variant strains of the virus, commodity price and
exchange rate fluctuations, geo-political risks, political and
economic instability abroad, wars (including the Russo-Ukrainian
War), hostilities, civil insurrections, inflationary risks
including potential increases to operating and capital costs,
changes in legislation impacting the oil and gas industry, adverse
weather or break-up conditions, and uncertainties resulting from
potential delays or changes in plans with respect to exploration or
development projects or capital expenditures. The Russo-Ukrainian
War is particularly noteworthy, as this conflict has the potential
to disrupt the global supply of oil and gas, and its full impact
remains uncertain. These and other risks are set out in more detail
in Southern's MD&A and AIF.
The forward-looking information contained in this press release
is made as of the date hereof and Southern undertakes no obligation
to update publicly or revise any forward-looking information,
whether as a result of new information, future events or otherwise,
unless required by applicable securities laws. The forward-looking
information contained in this press release is expressly qualified
by this cautionary statement.
Future Oriented Financial Information . This press release
contains future-oriented financial information and financial
outlook information (collectively, "FOFI") about Southern's
prospective results of operations, cash flow, increased capacity
under the credit facility, capital expenditures and payout of
wells, all of which are subject to the same assumptions, risk
factors, limitations, and qualifications as set forth in the above
paragraphs. FOFI contained in this document was approved by
management as of the date of this document and was provided for the
purpose of providing further information about Southern's future
business operations. Southern and its management believe that FOFI
has been prepared on a reasonable basis, reflecting management's
best estimates and judgments, and represent, to the best of
management's knowledge and opinion, the Company's expected course
of action. However, because this information is highly subjective,
it should not be relied on as necessarily indicative of future
results. Southern disclaims any intention or obligation to update
or revise any FOFI contained in this document, whether as a result
of new information, future events or otherwise, unless required
pursuant to applicable law. Readers are cautioned that the FOFI
contained in this document should not be used for purposes other
than for which it is disclosed herein. Changes in forecast
commodity prices, differences in the timing of capital
expenditures, and variances in average production estimates can
have a significant impact on the key performance measures included
in Southern's guidance. The Company's actual results may differ
materially from these estimates.
Specified Financial Measures. This press release provides
various financial measures that do not have a standardized meaning
prescribed by IFRS, including non-IFRS financial measures, non-IFRS
financial ratios and capital management measures. These specified
financial measures may not be comparable to similar measures
presented by other issuers. Southern's method of calculating these
measures may differ from other companies and accordingly, they may
not be comparable to measures used by other companies. Adjusted
funds flow from operations, operating netback, adjusted working
capital and net debt are not recognized measures under IFRS.
Readers are cautioned that these specified financial measures
should not be construed as alternatives to other measures of
financial performance calculated in accordance with IFRS. These
specified financial measures provide additional information that
management believes is meaningful in describing the Company's
operational performance, liquidity and capacity to fund capital
expenditures and other activities. Please see below for a brief
overview of all specified financial measures used in this release
and refer to the Company's MD&A for additional information
relating to specified financial measures, which is available on the
Company's website at www.southernenergycorp.com and filed on
SEDAR.
"Adjusted Funds Flow from Operations" (non-IFRS financial
measure) is calculated based on cash flow from operative activities
before changes in non-cash working capital and cash decommissioning
expenditures. Management uses adjusted funds flow from operations
as a key measure to assess the ability of the Company to finance
operating activities, capital expenditures and debt repayments.
"Adjusted Funds Flow from Operations per Share" (non-IFRS
financial measure) is calculated by dividing Adjusted Funds Flow
from Operations by the number of Southern shares issued and
outstanding.
"Operating Netback" (non-IFRS financial measure) equals total
oil and natural gas sales less royalties, production taxes,
operating expenses, transportation costs and realized gain / (loss)
on derivatives. Management considers operating netback an important
measure to evaluate its operational performance, as it demonstrates
field level profitability relative to current commodity prices.
"Positive Net Cash (Net Debt)" (capital management measure) is
monitored by Management, along with adjusted working capital, as
part of its capital structure in order to fund current operations
and future growth of the Company. Net debt is defined as long-term
debt plus adjusted working capital surplus or deficit. Adjusted
working capital is calculated as current assets less current
liabilities, removing current derivative assets/liabilities, the
current portion of bank debt, and the current portion of lease
liabilities.
Neither the TSX Venture Exchange nor its Regulation Services
Provider (as that term is defined in the policies of the TSX
Venture Exchange) accepts responsibility for the adequacy or
accuracy of this release.
[1] See "Reader Advisory - Specified Financial Measures"
[2] Comprised of 114 bbl/d light and medium crude oil, 13 bbl/d
NGLs and 14,881 Mcf/d conventional natural gas
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END
QRFALMITMTITBAJ
(END) Dow Jones Newswires
May 30, 2023 02:00 ET (06:00 GMT)
Southern Energy (LSE:SOUC)
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