Energy Fuels is a leading U.S.-based uranium mining company, supplying U3O8 to major nuclear utilities. Energy Fuels also produces vanadium from certain of its projects, as market conditions warrant, and is ramping up commercial-scale production of REE carbonate. Its corporate offices are in Lakewood, Colorado, near Denver, and all its assets and employees are in the United States. Energy Fuels holds three of America’s key uranium production centers: the White Mesa Mill in Utah, the Nichols Ranch in-situ recovery (“ISR”) Project in Wyoming, and the Alta Mesa ISR Project in Texas. The White Mesa Mill is the only conventional uranium mill operating in the U.S. today, has a licensed capacity of over 8 million pounds of U3O8 per year, has the ability to produce vanadium when market conditions warrant, as well as REE carbonate from various uranium-bearing ores. The Nichols Ranch ISR Project is on standby and has a licensed capacity of 2 million pounds of U3O8 per year. The Alta Mesa ISR Project is also on standby and has a licensed capacity of 1.5 million pounds of U3O8 per year. In addition to the above production facilities, Energy Fuels also has one of the largest NI 43-101 compliant uranium resource portfolios in the U.S. and several uranium and uranium/vanadium mining projects on standby and in various stages of permitting and development. The primary trading market for Energy Fuels’ common shares is the NYSE American under the trading symbol “UUUU,” and the Company’s common shares are also listed on the Toronto Stock Exchange under the trading symbol “EFR.” Energy Fuels’ website is www.energyfuels.com.
Michael Heim, Senior Vice President, Equity Research Analyst, Energy & Transportation, Noble Capital Markets, Inc.
Refer to the full report for the price target, fundamental analysis, and rating.
Energy Fuels reported 2023-1Q results in line with expectations absent non-recurring items. UUUU reported revenues of $19.6 million (versus our $18 million est.) largely due to the previously-announced sale of uranium to the government. Net income was $114.7 million ($0.72 per share) with a $116.5 million net gain on the sale of the Alta Mesa project. Absent the gain, the company would have reported a slight loss, in line with our projections.
UUUU’s rare earth elements (REE) plan is becoming clearer. Phase 1 of a plan to separate rare earth elements such as the valuable NdPr. has begun. When completed in 2023/24, UUUU will be able to produce 800-1,000 metric tons (0.8-1.0 million kg) of “commercial quantities of separated NdPr.” At the current spot price of $64 per kg, sales could approach $64 million. Sales of other separated REE would be incremental. And, production is expected to grow 2-3 times upon completion of Phase 2 in 2026 leading us to believe annual sales from REE could be several hundred million. For a company that has not generated annual revenues above $30 million the last ten years, the prospect of generating hundreds of million in sales is exciting.
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The Company sold 300,000 pounds of uranium at a gross margin of 58%, 79,344 pounds of vanadium at a gross margin of 37%, and the Alta Mesa property for a total gain of $116.45 million; Working capital increased, total assets increased, and total liabilities decreased.
LAKEWOOD, Colo., May 5, 2023 /CNW/ – Energy Fuels Inc. (NYSE American: UUUU) (TSX: EFR) (“Energy Fuels” or the “Company”) today reported its financial results for the quarter ended March 31, 2023. The Company’s Quarterly Report on Form 10-Q has been filed with the U.S. Securities and Exchange Commission (“SEC“) and may be viewed on the Electronic Document Gathering and Retrieval System (“EDGAR“) at www.sec.gov/edgar.shtml, on the System for Electronic Document Analysis and Retrieval (“SEDAR“) at www.sedar.com, and on the Company’s website at www.energyfuels.com. Unless noted otherwise, all dollar amounts are in U.S. dollars.
Financial Highlights:
As of March 31, 2023, the Company had a robust balance sheet with $143.61 million of working capital (versus $116.97 million at December 31, 2022), including $43.83 million of cash and cash equivalents, $60.44 million of marketable securities, $38.00 million of inventory, and no debt. At current commodity prices, the Company’s product inventory has a value of $52.53 million;
During the three months ended March 31, 2023, the Company realized net income of $114.26 million, or $0.72 per share, primarily due to: (i) a net gain of $116.45 million on the sale of the Company’s Alta Mesa in situ recovery (“ISR“) project in Texas; (ii) a net gain of $10.76 million on the sale of 300,000 pounds of uranium (“U3O8“) to the U.S. Uranium program; (iii) a net gain of $0.32 million on the sale of 79,344 pounds of vanadium (“V2O5“); (iv) increased expenses associated with preparing four (4) of our uranium mines for production; (v) expenses associated with developing commercial rare earth element (“REE“) separation capabilities; and (vi) a non-cash mark-to-market loss on investments accounted for at fair value of $2.96 million.
The Company realized a total gross margin of 57% on its product sales during Q1-2023, including 58% on its uranium sale and 37% on its vanadium sales.
At March 31, 2023, the Company’s total assets and current assets increased by 37% and 10%, respectively, and total liabilities and current liabilities decreased by 44% and 72%, respectively, as compared to December 31, 2022.
As of March 31, 2023, the Company held 847,000 pounds of finished U3O8, 906,000 pounds of finished V2O5, and 250 metric tons (“MT“) of finished high-purity, partially separated mixed REE carbonate (“RE Carbonate“) in inventory.
The Company holds an additional 394,000 lbs. of U3O8 as raw materials and work-in-progress inventory, along with 1 – 3 million pounds of solubilized V2O5 in tailings solutions that could be recovered in the future.
Uranium Highlights:
During Q1-2023, the Company completed the sale of 300,000 pounds of U3O8 to the U.S. Uranium Reserve realizing total gross proceeds of $18.47 million, or $61.57 per pound of U3O8. This sale resulted in a gross margin of approximately $35.85 per pound of uranium, or a gross margin of 58%.
During 2023, the Company expects to sell an additional 200,000 to 260,000 pounds of U3O8 into its current portfolio of supply agreements with U.S. nuclear utilities at an expected sales price of approximately $54 – $58 per pound, resulting in an estimated 46% – 50% gross margin.
During Q1-2023, the Company purchased a total of 120,000 pounds of U.S.-origin U3O8 on the spot market for a weighted-average price of $50.25 per pound.
Over the past several months, the Company has made significant progress in preparing four (4) of our conventional uranium and uranium/vanadium mines to be ready to resume ore production, including significant workforce expansion and performing needed rehabilitation and development of surface and underground infrastructure.
On February 15, 2023, the Company announced it had completed its previously announced sale of its Alta Mesa ISR Project to enCore Energy Corp. (“enCore“) for total consideration of $120 million, comprised of $60 million in cash and $60 million in a secured convertible note bearing interest at a rate of eight percent (8%) per annum, convertible into common shares of enCore at a price of $2.9103 per share. This sale of a lower priority project provides Energy Fuels with significant additional cash and working capital, enabling the Company to ramp-up its US industry-leading uranium and REE production, while avoiding dilution to shareholders.
In connection with the Alta Mesa Transaction, on May 3, 2023, the Company completed the sale of its Prompt Fission Neutron assets, including the underlying contracts, technology, licenses and intellectual property (collectively, the “PFN Assets“), to enCore in exchange for cash consideration received at closing of $3.10 million. At closing, the PFN Assets, which the Company had purchased in 2020 for cash consideration of $0.5 million, had a net book value of $0.35 million. The PFN Assets were used exclusively at the Alta Mesa ISR Project and are not required for any of the Company’s other properties. Should the Company have the need for the use of a PFN tool in the future, the Company retained a 20-year usage right, subject to the availability of the PFN Assets, to purchase, lease and/or license at least one PFN tool and all related and/or required equipment, technology and licenses on commercially reasonable terms.
As of April 28, the spot price of U3O8 was $53.75 per pound according to data from TradeTech.
Rare Earth Element Highlights:
During the three months ended March 31, 2023, the Company produced approximately 250 MT of high-purity, partially separated mixed RE Carbonate from monazite, containing approximately 115 MT of total rare earth oxides (“TREO“), which is the most advanced REE material being produced commercially in the U.S. today.
The Company has in circuit an additional 65 to 115 MT of RE Carbonate, containing 35 to 55 MT of TREO, which it expects to package for sale during the second quarter of 2023.
In early 2023, the Company began modifying and enhancing its existing solvent extraction (“SX“) circuits at the Mill to be able to produce separated REE oxides (“Phase 1“). The Company has begun this development work in its SX building and ordered most of the major components for this project, which are expected to be delivered to the Mill in Q3-2023. “Phase 1” is expected to be completed and fully commissioned by late 2023 or early 2024 and have the capacity to produce roughly 800 to 1,000 MT of recoverable separated neodymium-praseodymium (“NdPr“) oxide per year, subject to securing sufficient monazite feed. “Phase 1” is expected to position Energy Fuels as one of the world’s leading producers of NdPr outside of China. “Phase 1” capital costs are expected to total approximately $25 million. 1,000 MT of NdPr in permanent magnets could power up to 1 million electric vehicles (“EVs“) per year.
The Company is engineering further enhancements at the Mill to increase NdPr production capacity to up to approximately 3,000 MT per year by 2026 (“Phase 2“), and to produce separated dysprosium (“Dy“), terbium (“Tb“) and potentially other advanced REE materials in the future from monazite and potentially other REE process streams by 2027 (“Phase 3”).
On February 13, 2023, the Company announced it had completed its previously announced acquisition of a large heavy mineral sands project in Brazil (the “Bahia Project“), which has the potential to supply the Company’s growing REE business with 3,000 – 10,000 MT of REE-bearing natural monazite sand per year for decades. The Bahia Project also contains significant quantities of high-value titanium (ilmenite and rutile) and zirconium (zircon) minerals.
During Q1-2023, the Company completed 2,266 meters of sonic drilling at the Bahia Project to confirm and further delineate the rare earth, titanium, and zirconium mineralization. The Company expects to commence further sonic drilling in Q3-2023, announce drilling results later this year, and commence preparation of an SK-1300 and NI 43-101 compliant mineral resource estimate.
The Company continues active discussions with several additional suppliers of natural monazite around the world to significantly increase the supply of feed for our growing REE initiative.
As of April 28, the spot price of NdPr oxide was $64 per kg, according to data from Asian Metal.
Vanadium Highlights:
During Q1-2023, the Company sold approximately 79,344 pounds of existing V2O5 inventory, for an average weighted sales price of $10.98 per pound of V2O5, for a total gross margin of 37%.
Due to the high-purity of the Company’s vanadium product, these sales occurred at a premium to V2O5 spot prices prevailing at the time of the sales.
As of April 28, the spot price of V2O5 was $9.75 per pound, according to data from Fastmarkets.
Medical Isotope Highlights:
The Company continued advancing its program to evaluate the potential to recover radioisotopes from its process streams for use in emerging targeted alpha therapy (“TAT“) cancer therapeutics.
Mark S. Chalmers, Energy Fuels’ President and CEO, stated:
“Energy Fuels had an exceptional 1st quarter on several metrics, including earnings of $114.26 million, achieving healthy margins on our product sales, increasing our working capital position to $143.61 million, increasing our total assets, and reducing our total liabilities. We also significantly enhanced our fixed asset portfolio by selling the non-core Alta Mesa uranium property for $120.00 million and closing on the purchase of the Bahia Project in Brazil, which has the potential to feed our REE separation circuits with low-cost raw materials for several decades.
“On uranium, we sold 300,000 pounds of U3O8 to the newly established U.S. Uranium Reserve for $18.47 million, or $61.57 per pound, representing a significant premium to the current spot price of uranium, resulting in a $10.76 million gross margin. We are also getting ready to sell up to another 260,000 pounds of U3O8 into our utility contract portfolio, also at healthy operating margins. We are closely tracking uranium prices, which have shown recent strength, for opportunities to sell additional uranium under long-term contracts to nuclear utilities at increasingly higher prices.
“Energy Fuels realized a significant gain of $116.45 million on the sale of our non-core Alta Mesa ISR project in Texas. Total consideration included $60 million of cash and a $60 million 2-year convertible note bearing 8% interest per year, fully secured by the property. This transaction also resulted in us receiving an additional $3.48 million cash for the return of collateral on the project’s reclamation bonds and a reduction in our standby costs of approximately $2 million per year.
“At the same time, we continue to perform significant work at four of our conventional uranium mines to get them ready to resume ore production. This includes the La Sal and Beaver mines at the La Sal Complex in Utah, the Whirlwind mine in Colorado and the Pinyon Plain mine in Arizona. Energy Fuels currently has sufficient uranium in inventory to fulfill our current utility contract requirements into 2025. However, we are seeking additional contracts and spot sale opportunities, along with a continuation of uranium purchasing by the U.S. government. Therefore, we could begin ore production at one or more of these projects by 2024.
“We continued to build our REE business as well. We began modifications and enhancements at the White Mesa Mill expected to produce up to 1,000 MT per year of NdPr oxide by late 2023 or early 2024, subject to receipt of sufficient monazite feed. We ordered the REE SX cells from a fabricator, with delivery to the Mill expected in Q3 or Q4-2023. Following delivery, we expect to install, commission, and optimize these cells, complete other modifications and enhancements to the existing circuits, and begin commercial production of NdPr oxide, along with uranium, soon thereafter. Upon completion, we believe Energy Fuels’ White Mesa Mill in Utah will house one of the largest NdPr production circuits in the world, excluding China. We also expect to begin piloting ‘heavy’ REE separation later this year, which will provide valuable knowledge for designing and building our Phase 3 Dy, Tb and potentially other REE separation circuits.
“Monazite supply is of course critical to Energy Fuels’ rare earth plans. We continue to advance discussions with several existing monazite suppliers around the world. And, we completed the acquisition of the Bahia Project in Brazil, which will allow us to control our own low-cost REE supply. The Bahia Project has the potential to produce between 3,000 to 10,000 MT of monazite, containing 300 to 1,000 MT of NdPr oxide, per year. We are currently in the midst of a sonic drilling program on the property to confirm and better define the REE (monazite), titanium (ilmenite, rutile, leucoxene) and zirconium (zircon) resources, which will inform our mine plan and permitting. We hope to commence production in late 2025 or early 2026, and ramp-up from there.
“Finally, we sold a small quantity of our vanadium inventory into recent market strength, which saw spot prices reach $10.80 per pound in February, according to Fastmarkets. Because we produce a high-purity V2O5 product that is attractive to specialty alloy and chemical markets, we were able to execute this sale at a premium to reported prices. Accordingly, our realized sales price was $10.98 per pound of V2O5 on these sales.”
Conference Call and Webcast at 4:00 pm ET on May 9, 2023:
Energy Fuels will be hosting a conference call and webcast on May 9, 2023 at 4:00 pm ET (2:00 pm MT) to discuss its Q1-2023 financial results, the outlook for 2023, and its uranium, rare earths, vanadium, and medical isotopes initiatives.
To instantly join the conference call by phone, please use the following link to easily register your name and phone number. After registering, you will receive a call immediately and be placed into the conference call: RAPIDCONNECT
Alternatively, you may dial in to the conference call by calling 1-888-664-6392, and you will be connected to the call by an Operator.
You may also access viewer-controlled Webcast slides and/or stream the call by following this link: WEBCAST
A replay of the call will be available until May 24, 2023 by calling (888) 390-0541 or (416) 764-8677 and entering the replay code, 680506#.
Selected Summary Financial Information:
Three Months Ended
March 31,
$000’s, except per share data
2023
2022
Results of Operations:
Uranium concentrates revenues
$ 18,470
$ —
Vanadium concentrates revenues
871
2,412
Total revenues
19,613
2,937
Gross margin
11,347
45
Operating loss
(405)
(10,213)
Net income (loss)
114,264
(14,730)
Basic and diluted net income (loss) per common share
0.72
(0.09)
As of
As of
$000’s
March 31, 2023
December 31, 2022
Financial Position:
Working capital
$ 143,611
$ 116,966
Property, plant and equipment, net
14,635
12,662
Mineral properties
113,834
83,539
Current assets
148,914
135,590
Total assets
375,451
273,947
Current liabilities
5,303
18,624
Total liabilities
16,438
29,538
ABOUT ENERGY FUELS
Energy Fuels is a leading US-based critical minerals company. The Company, as the leading producer of uranium in the United States, mines uranium and produces natural uranium concentrates that are sold to major nuclear utilities for the production of carbon-free nuclear energy. Energy Fuels recently began production of advanced rare earth element (“REE“) materials, including mixed REE carbonate, and plans to produce commercial quantities of separated REE oxides in the future. Energy Fuels also produces vanadium from certain of its projects, as market conditions warrant, and is evaluating the recovery of radionuclides needed for emerging cancer treatments. Its corporate offices are in Lakewood, Colorado, near Denver, and substantially all its assets and employees are in the United States. Energy Fuels holds two of America’s key uranium production centers: the White Mesa Mill in Utah and the Nichols Ranch in-situ recovery (“ISR“) Project in Wyoming. The White Mesa Mill is the only conventional uranium mill operating in the US today, has a licensed capacity of over 8 million pounds of U3O8 per year, has the ability to produce vanadium when market conditions warrant, as well as REE products, from various uranium-bearing ores. The Nichols Ranch ISR Project is on standby and has a licensed capacity of 2 million pounds of U3O8 per year. The Company recently acquired the Bahia Project in Brazil, which is believed to have significant quantities of titanium (ilmenite and rutile), zirconium (zircon) and REE (monazite) minerals. In addition to the above production facilities, Energy Fuels also has one of the largest NI 43-101 compliant uranium resource portfolios in the US and several uranium and uranium/vanadium mining projects on standby and in various stages of permitting and development. The primary trading market for Energy Fuels’ common shares is the NYSE American under the trading symbol “UUUU,” and the Company’s common shares are also listed on the Toronto Stock Exchange under the trading symbol “EFR.” Energy Fuels’ website is www.energyfuels.com.
Daniel Kapostasy, P.G., Director of Technical Services for Energy Fuels, is a Qualified Person as defined by Canadian National Instrument 43-101 and has reviewed and approved the technical disclosure contained in this news release, including sampling, analytical, and test data underlying such disclosure.
The data collected and provided in this disclosure related to the Bahia Project is derived entirely from the exploration reports for each of the seventeen mineral process areas. Mr. Kapostasy has reviewed these reports in detail and discussed the methods used with the project geologist in charge of field and laboratory activities for the previous owners who is also currently an employee of Energy Fuels Brazil, Ltda. Heavy mineral concentrations were derived for every meter drilled using heavy liquid separations, a standard method of heavy mineral determination.
To determine the concentration of the various heavy minerals in a sample, the heavy fraction was separated from the silica sand by using heavy liquid separation. The heavy fraction was then mounted in epoxy or dispersed on slide glass and viewed under a microscope. A geologist can then identify the various minerals and determine the concentration of each mineral through a process called point counting, whereby the geologist identifies each sand grain individually, tallies the number of each mineral and then divides by the total.
Verification of the heavy mineral concentration was started by the Company in September 2022, when it hired a contract driller to collect samples using a sonic rig. While no laboratory analyses have been received to date, visual estimation of the heavy mineral quantity indicates that the historical values seen at the various process areas are valid.
Cautionary Note Regarding Forward-Looking Statements: This news release contains certain “Forward Looking Information” and “Forward Looking Statements” within the meaning of applicable United States and Canadian securities legislation, which may include, but are not limited to, statements with respect to: production and sales forecasts; costs of production; any expectation that the Company will be awarded any future sales under the U.S. Uranium Reserve; scalability, and the Company’s ability and readiness to re-start, expand or deploy any of its existing projects or capacity to respond to any improvements in uranium market conditions or in response to the Uranium Reserve; any expectation as to future uranium, vanadium, RE Carbonate, REE oxide, or REE market fundamentals or sales; any expectation as to recommencement of production at any of the Company’s uranium mines or the timing thereof; any expectation regarding any remaining dissolved vanadium in the Mill’s tailings facility solutions or the ability of the Company to recover any such vanadium at acceptable costs or at all; any expectation as to longer term fundamentals in the market and price projections; any expectation that the Company will maintain its position as a leading U.S.-based critical minerals company or as the leading producer of uranium in the U.S.; any expectation with respect to timelines to production; any expectation that the sale of the Alta Mesa project and the use of the proceeds from that sale will not result in any dilution to shareholders; any expectation that the Mill will be successful in producing RE Carbonate on a full-scale commercial basis; any expectation that Energy Fuels will be successful in developing U.S. separation, or other value-added U.S. REE production capabilities at the Mill, or otherwise, including the timing of any such initiatives and the expected production capacity or capital and operating costs associated with any such production capabilities; any expectation with respect to the quantities of monazite to be acquired by Energy Fuels, the quantities of RE Carbonate or REE oxides to be produced by the Mill or the quantities of contained TREO in the Mill’s RE Carbonate; any expectation that the Company may sell its separated NdPr oxide to electric vehicle manufacturers; any expectation that the Bahia Project has the potential to feed the Mill with REE and uranium-bearing monazite sand for decades or at all; any expectation that the Company will complete comprehensive sonic drilling and geophysical mapping at the Bahia Project or complete an Initial Assessment under SK-1300 (U.S.) and a Technical Report Technical Report under NI 43-101 (Canada) during 2023, or otherwise; any expectation that the Company’s evaluation of radioisotope recovery at the Mill will be successful; any expectation that the potential recovery of medical isotopes from any radioisotopes recovered at the Mill will be feasible; any expectation that any radioisotopes can be recovered at the Mill will be sold on a commercial basis; any expectation as to the quantities to be delivered under existing uranium sales contracts; and any expectation that the Company will be successful in completing any additional contracts for the sale of uranium to U.S. utilities on commercially reasonable terms or at all. Generally, these forward-looking statements can be identified by the use of forward-looking terminology such as “plans,” “expects,” “does not expect,” “is expected,” “is likely,” “budgets,” “scheduled,” “estimates,” “forecasts,” “intends,” “anticipates,” “does not anticipate,” or “believes,” or variations of such words and phrases, or state that certain actions, events or results “may,” “could,” “would,” “might” or “will be taken,” “occur,” “be achieved” or “have the potential to.” All statements, other than statements of historical fact, herein are considered to be forward-looking statements. Forward-looking statements involve known and unknown risks, uncertainties and other factors which may cause the actual results, performance or achievements of the Company to be materially different from any future results, performance or achievements express or implied by the forward-looking statements. Factors that could cause actual results to differ materially from those anticipated in these forward-looking statements include risks associated with: commodity prices and price fluctuations; engineering, construction, processing and mining difficulties, upsets and delays; permitting and licensing requirements and delays; changes to regulatory requirements; legal challenges; the availability of sources of Alternate Feed Materials and other feed sources for the Mill; competition from other producers; public opinion; government and political actions; available supplies of monazite; the ability of the Mill to produce RE Carbonate, REE oxides or other REE products to meet commercial specifications on a commercial scale at acceptable costs or at all; market factors, including future demand for REEs; the ability of the Mill to be able to separate radium or other radioisotopes at reasonable costs or at all; market prices and demand for medical isotopes; and the other factors described under the caption “Risk Factors” in the Company’s most recently filed Annual Report on Form 10-K, which is available for review on EDGAR at www.sec.gov/edgar.shtml, on SEDAR at www.sedar.com, and on the Company’s website at www.energyfuels.com. Forward-looking statements contained herein are made as of the date of this news release, and the Company disclaims, other than as required by law, any obligation to update any forward-looking statements whether as a result of new information, results, future events, circumstances, or if management’s estimates or opinions should change, or otherwise. There can be no assurance that forward-looking statements will prove to be accurate, as actual results and future events could differ materially from those anticipated in such statements. Accordingly, the reader is cautioned not to place undue reliance on forward-looking statements. The Company assumes no obligation to update the information in this communication, except as otherwise required by law.
SOURCE Energy Fuels Inc.
For further information: Investor Inquiries: Energy Fuels Inc., Curtis Moore, SVP – Marketing and Corporate Development, (303) 974-2140 or Toll free: (888) 864-2125, [email protected], www.energyfuels.com
CALGARY, AB, May 4, 2023 /CNW/ – Alvopetro Energy Ltd. (TSXV: ALV) (OTCQX: ALVOF) announces April 2023 average sales volumes and an operational update and timing for release of our Q1 2023 results and earnings call.
April 2023 Sales Volumes
April sales volumes averaged 1,972 boepd, including natural gas sales of 11.3 MMcfpd and associated natural gas liquids sales from condensate of 84 bopd, based on field estimates. Sales volumes in April declined from our average Q1 2023 of 2,767 boepd. April sales volumes were lower due to reduced demand during the month from Bahiagás as well as higher nominated volumes from our partner at the Caburé unit. We anticipate May sales volumes to continue at rates similar to average volumes in April. Future sales volumes will be dependent on available Caburé unit production, production additions from our Murucututu field with the development work planned this year and overall demand from Bahiagás.
Operational Update
In March, we commenced stimulation operations at our 197(1) well on our Murucututu natural gas field. While operations have progressed slower than initially scheduled, we have now successfully stimulated three of four planned intervals at the well, injecting a total of 89 tonnes of sand into the formation. Stimulation of the final interval is expected to be completed shortly and we expect the well to be on production this month. Following completion of stimulation operations, we plan to drill two Murucututu fit-for-purpose development wells in the second half of 2023.
On our Bom Lugar field, we spud our first development well (BL-06) on April 30th and drilling is underway. The BL-06 well is targeting the Caruaçu Formation with additional potential in the deeper Gomo and Agua Grande Formations. We expect drilling to be completed late in the second quarter.
Upcoming Q1 2023 Results and Live Webcast
Alvopetro anticipates announcing first quarter 2023 results on May 10, 2023, after markets close, and will host a live webcast to discuss the results at 8:00 am Mountain time, on May 11, 2023. Details for joining the event are as follows:
The webcast will include a question and answer period. Online participants will be able to ask questions through the Zoom portal. Dial-in participants can email questions directly to [email protected].
Alvopetro Energy Ltd.’svision is to become a leading independent upstream and midstream operator in Brazil. Our strategy is to unlock the on-shore natural gas potential in the state of Bahia in Brazil, building off the development of our Caburé natural gas field and our strategic midstream infrastructure.
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 news release.
All amounts contained in this new release are in United States dollars, unless otherwise stated and all tabular amounts are in thousands of United States dollars, except as otherwise noted.
Abbreviations:
bbls
=
barrels
boepd
=
barrels of oil equivalent (“boe”) per day
bopd
=
barrels of oil and/or natural gas liquids (condensate) per day
MMcf
=
million cubic feet
MMcfpd
=
million cubic feet per day
Q1 2023
=
three months ended March 31, 2023
BOE Disclosure. The term barrels of oil equivalent (“boe”) may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet per barrel (6Mcf/bbl) of natural gas to barrels of oil equivalence is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. All boe conversions in this news release are derived from converting gas to oil in the ratio mix of six thousand cubic feet of gas to one barrel of oil.
Forward-Looking Statements and Cautionary Language. This news release contains “forward-looking information” within the meaning of applicable securities laws. The use of any of the words “will”, “expect”, “intend” and other similar words or expressions are intended to identify forward-looking information. Forward–looking statements involve significant risks and uncertainties, should not be read as guarantees of future performance or results, and will not necessarily be accurate indications of whether or not such results will be achieved. A number of factors could cause actual results to vary significantly from the expectations discussed in the forward-looking statements. These forward-looking statements reflect current assumptions and expectations regarding future events. Accordingly, when relying on forward-looking statements to make decisions, Alvopetro cautions readers not to place undue reliance on these statements, as forward-looking statements involve significant risks and uncertainties. More particularly and without limitation, this news release contains forward-looking information concerning the anticipated timing of completion of the 197(1) stimulation and drilling of the BL-06 well, anticipated timing of production commencement from the 197(1) well, expected natural gas allocations from the Caburé unit, natural gas sales and gas deliveries under the Company’s long-term gas sales agreement, plans relating to the Company’s operational activities, proposed exploration development activities and the timing for such activities and exploration and development prospects of Alvopetro. The forward–looking statements are based on certain key expectations and assumptions made by Alvopetro, including but not limited to expectations and assumptions concerning the performance of producing wells and reservoirs, foreign exchange rates, well development and operating performance, the timing of regulatory licenses and approvals, equipment availability, the success of future drilling, completion, testing, recompletion and development activities, expectations regarding Alvopetro’s working interest and the outcome of any redeterminations, environmental regulation, including regulation relating to hydraulic fracturing and stimulation, the ability to monetize hydrocarbons discovered, the outlook for commodity markets and ability to access capital markets, general economic and business conditions, the impact of the COVID-19 pandemic, weather and access to drilling locations, the availability and cost of labour and services, the regulatory and legal environment and other risks associated with oil and gas operations. The reader is cautioned that assumptions used in the preparation of such information, although considered reasonable at the time of preparation, may prove to be incorrect. Actual results achieved during the forecast period will vary from the information provided herein as a result of numerous known and unknown risks and uncertainties and other factors. Although Alvopetro believes that the expectations and assumptions on which such forward-looking information is based are reasonable, undue reliance should not be placed on the forward-looking information because Alvopetro can give no assurance that it will prove to be correct. Readers are cautioned that the foregoing list of factors is not exhaustive. Additional information on factors that could affect the operations or financial results of Alvopetro are included in our annual information form which may be accessed on Alvopetro’s SEDAR profile at www.sedar.com. The forward-looking information contained in this news release is made as of the date hereof and Alvopetro undertakes no obligation to update publicly or revise any forward-looking information, whether as a result of new information, future events or otherwise, unless so required by applicable securities laws.
Largo has a long and successful history as one of the world’s preferred vanadium companies through the supply of its VPURE™ and VPURE+™ products, which are sourced from one of the world’s highest-grade vanadium deposits at the Company’s Maracás Menchen Mine in Brazil. Aiming to enhance value creation at Largo, the Company is in the process of implementing a titanium dioxide pigment plant using feedstock sourced from its existing operations in addition to advancing its U.S.-based clean energy division with its VCHARGE vanadium batteries. Largo’s VCHARGE vanadium batteries contain a variety of innovations, enabling an efficient, safe and ESG-aligned long duration solution that is fully recyclable at the end of its 25+ year lifespan. Producing some of the world’s highest quality vanadium, Largo’s strategic business plan is based on two pillars: 1.) leading vanadium supplier with an outlined growth plan and 2.) U.S.-based energy storage business support a low carbon future.
Michael Heim, Senior Vice President, Equity Research Analyst, Energy & Transportation, Noble Capital Markets, Inc.
Refer to the full report for the price target, fundamental analysis, and rating.
Largo, Inc. will release 2023-1Q financial results on May 10th and hold a conference call to discuss results on May 11th. The company has previously (4/18/23) disclosed quarterly V2O5 production of 2,111 tonnes and sales of 2,849 tonnes. Sales were significantly above previous guidance of 2,300-2,500 tonnes. Consequently, we expect result to show improvement over the first quarter of last year when Largo sold 2,232 tonnes. We would note that 2023-1Q sales include 245 tonnes of purchased material, which we assume was done at a higher cost than produced V2O5.
Management’s guidance for the second quarter shows a build back of inventory. Management projects 2023-2Q production of 3,000-3,200 tonnes and sales of 2,300-2,500 tonnes. The reduction in sales and increase in production versus the first quarter could mean second quarter results will be below that reported in the first quarter. Importantly, some cost incurred during any quarter’s production may carry over into the next quarter when sales are completed. This will partially offset the impact of rising production and falling sales.
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*Analyst certification and important disclosures included in the full report. NOTE: investment decisions should not be based upon the content of this research summary. Proper due diligence is required before making any investment decision.
Michael Heim, Senior Vice President, Equity Research Analyst, Energy & Transportation, Noble Capital Markets, Inc.
Refer to the full report for the price target, fundamental analysis, and rating.
Indonesia Energy Filed Its 20-F (Foreign) Document with the SEC Providing Financial Data. Due to drilling and production delays, revenue growth has been slower than projected. The company continues to report negative cash flow and earnings as limited revenues are hard pressed to cover G&A costs. The result was a $4.5 million loss from operations for the year, an EBITDA loss of $3.5 million, and negative net income of $3.1 million ($0.35 per share). The results were below our expectations, although the Indo story is really one of operating developments, not near-term results.
Operations are quiet. The filing largely repeated previously stated plans for drilling in the Kruh Block (4 in 2024, 6 in 2025, and 4 in 2026). INDO has drilled four wells in the Kruh Block, the last of which is still awaiting final flow test results but expected to be put in production mid 2023. After the last well, the company put new drilling on hold to complete additional seismic studies. Importantly, limited production has meant that it may not be able to fully recover costs spent under the revenue sharing agreement (INDO has filed for an extension).
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*Analyst certification and important disclosures included in the full report. NOTE: investment decisions should not be based upon the content of this research summary. Proper due diligence is required before making any investment decision.
Michael Heim, Senior Vice President, Equity Research Analyst, Energy & Transportation, Noble Capital Markets, Inc.
Refer to the full report for the price target, fundamental analysis, and rating.
CEO/P Mehran Ehsan made a presentation at the Planet Microcap Showcase on April 26. The short, ten-minute presentation largely restated the company’s case that there is a disconnect between its asset value and its stock price. Mr. Ehsan once again pointed to a reserve study of its properties that values its properties at $428 million using a 10% discount rate versus the stock’s current enterprise value of $9 million. If one were to value the company based on just proved reserves, the value would still be $128 million. In fact, the value from only wells currently producing is $12 million, still above the current market capitalization.
Management believes the disconnect stems from its listing on the OTCQB exchange which limits manager investments in the company. The company has dropped plans to list on the New York Stock Exchange and now plans to list on the NASDAQ exchange. We believe such a move is prudent and that it will help reduce the valuation disconnect. This is especially important given Permex’s need for capital to drill out additional wells. Along those lines, management indicated that it plans to convert a vertical well drill last fall to a horizontal well. The drilling will use $1.1 million of the $1.67 million in cash on hand and take a few months to complete.
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*Analyst certification and important disclosures included in the full report. NOTE: investment decisions should not be based upon the content of this research summary. Proper due diligence is required before making any investment decision.
Michael Heim, Senior Energy & Transportation Analyst, Noble Capital Markets, Inc.
Refer to the full report for the price target, fundamental analysis, and rating.
Results demonstrate strong production growth and a sharp increase in cash flow and earnings. Production rates (preannounced) increased 55%. Increased production was partially offset by a drop in energy prices. Lower-than-expected prices were partially offset by a decrease in royalty rates. Production costs (excluding transportation costs) remain somewhat elevated as they were in the September quarter. We look for production costs per barrel to decrease modestly as new production comes on line in 2023.
As netbacks rose, so did the company’s Adjusted Fund Flow (AFF). The margin between prices and costs is high. Operating netbacks (realized prices less royalties and operating costs) is leading to strong cash flow which management is turning their focus toward returning to shareholders now that debt is virtually eliminated and drilling programs have been accelerated.
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This Company Sponsored Research is provided by Noble Capital Markets, Inc., a FINRA and S.E.C. registered broker-dealer (B/D).
*Analyst certification and important disclosures included in the full report. NOTE: investment decisions should not be based upon the content of this research summary. Proper due diligence is required before making any investment decision.
Largo has a long and successful history as one of the world’s preferred vanadium companies through the supply of its VPURE™ and VPURE+™ products, which are sourced from one of the world’s highest-grade vanadium deposits at the Company’s Maracás Menchen Mine in Brazil. Aiming to enhance value creation at Largo, the Company is in the process of implementing a titanium dioxide pigment plant using feedstock sourced from its existing operations in addition to advancing its U.S.-based clean energy division with its VCHARGE vanadium batteries. Largo’s VCHARGE vanadium batteries contain a variety of innovations, enabling an efficient, safe and ESG-aligned long duration solution that is fully recyclable at the end of its 25+ year lifespan. Producing some of the world’s highest quality vanadium, Largo’s strategic business plan is based on two pillars: 1.) leading vanadium supplier with an outlined growth plan and 2.) U.S.-based energy storage business support a low carbon future.
Michael Heim, Senior Vice President – Equity Research Analyst, Natural Resources, Noble Capital Markets, Inc.
Refer to the full report for the price target, fundamental analysis, and rating.
Largo announced reduced production but increased sales. Largo announced 2023-1Q V2O5 production of 2,111 tonnes (23 tonnes/day) near the upper end of guidance, albeit slightly below that in used our models. The 14% decrease in production versus the same period last year come due to heavy rain in the early part of the quarter, planned maintenance, and the transition of a mining contractor. These factors were known and reflected in our estimates. Production levels also reflect a decline in effective grade to 0.81% from 1.27% as less vanadium was produced despite a 13% increase in mined ore.
Sales rose despite lower production as the company sold inventory and purchased material. V2O5 equivalent sales were 2,849 tonnes in the quarter, up 28% over last year sales of 2,232 tonnes and well above guidance of 2,300-2,500 tonnes and our projections that assumed sales near production levels. Sales include 245 tonnes of purchased material versus only 79 tonnes last year.
Equity Research is available at no cost to Registered users of Channelchek. Not a Member? Click ‘Join’ to join the Channelchek Community. There is no cost to register, and we never collect credit card information.
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*Analyst certification and important disclosures included in the full report. NOTE: investment decisions should not be based upon the content of this research summary. Proper due diligence is required before making any investment decision.
CALGARY, AB, April 5, 2023 /CNW/ – Alvopetro Energy Ltd. (TSXV: ALV) (OTCQX: ALVOF) announces March 2023 average sales volumes of 2,690 boepd, including natural gas sales of 15.4 MMcfpd, associated natural gas liquids sales from condensate of 120 bopd and 8 bopd of oil sales, based on field estimates. Overall, our sales volumes averaged 2,767 boepd in the first quarter of 2023, an increase of 2% from the fourth quarter of 2022 and a new quarterly record for Alvopetro.
Alvopetro Energy Ltd.’svision is to become a leading independent upstream and midstream operator in Brazil. Our strategy is to unlock the on-shore natural gas potential in the state of Bahia in Brazil, building off the development of our Caburé natural gas field and our strategic midstream infrastructure.
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 news release.
All amounts contained in this new release are in United States dollars, unless otherwise stated and all tabular amounts are in thousands of United States dollars, except as otherwise noted.
Abbreviations:bbls = barrelsboepd = barrels of oil equivalent (“boe”) per daybopd = barrels of oil and/or natural gas liquids (condensate) per dayMMcf = million cubic feetMMcfpd = million cubic feet per day
BOE Disclosure. The term barrels of oil equivalent (“boe”) may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet per barrel (6Mcf/bbl) of natural gas to barrels of oil equivalence is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. All boe conversions in this news release are derived from converting gas to oil in the ratio mix of six thousand cubic feet of gas to one barrel of oil.
Forward-Looking Statements and Cautionary Language. This news release contains “forward-looking information” within the meaning of applicable securities laws. The use of any of the words “will”, “expect”, “intend” and other similar words or expressions are intended to identify forward-looking information. Forward–looking statements involve significant risks and uncertainties, should not be read as guarantees of future performance or results, and will not necessarily be accurate indications of whether or not such results will be achieved. A number of factors could cause actual results to vary significantly from the expectations discussed in the forward-looking statements. These forward-looking statements reflect current assumptions and expectations regarding future events. Accordingly, when relying on forward-looking statements to make decisions, Alvopetro cautions readers not to place undue reliance on these statements, as forward-looking statements involve significant risks and uncertainties. More particularly and without limitation, this news release contains forward-looking information concerning the expected natural gas sales and gas deliveries under the Company’s long-term gas sales agreement. The forward–looking statements are based on certain key expectations and assumptions made by Alvopetro, including but not limited to expectations and assumptions concerning the performance of producing wells and reservoirs, foreign exchange rates, well development and operating performance, the timing of regulatory licenses and approvals, equipment availability, the success of future drilling, completion, testing, recompletion and development activities, expectations regarding Alvopetro’s working interest and the outcome of any redeterminations, environmental regulation, including regulation relating to hydraulic fracturing and stimulation, the ability to monetize hydrocarbons discovered, the outlook for commodity markets and ability to access capital markets, general economic and business conditions, the impact of the COVID-19 pandemic, weather and access to drilling locations, the availability and cost of labour and services, the regulatory and legal environment and other risks associated with oil and gas operations. The reader is cautioned that assumptions used in the preparation of such information, although considered reasonable at the time of preparation, may prove to be incorrect. Actual results achieved during the forecast period will vary from the information provided herein as a result of numerous known and unknown risks and uncertainties and other factors. Although Alvopetro believes that the expectations and assumptions on which such forward-looking information is based are reasonable, undue reliance should not be placed on the forward-looking information because Alvopetro can give no assurance that it will prove to be correct. Readers are cautioned that the foregoing list of factors is not exhaustive. Additional information on factors that could affect the operations or financial results of Alvopetro are included in our annual information form which may be accessed on Alvopetro’s SEDAR profile at www.sedar.com. The forward-looking information contained in this news release is made as of the date hereof and Alvopetro undertakes no obligation to update publicly or revise any forward-looking information, whether as a result of new information, future events or otherwise, unless so required by applicable securities laws.
CALGARY, AB, April 3, 2023 /CNW/ – InPlay Oil Corp. (TSX: IPO) (OTCQX: IPOOF) (“InPlay” or the “Company”) is pleased to confirm that its Board of Directors has declared a monthly cash dividend of $0.015 per common share payable on April 28, 2023, to shareholders of record at the close of business on April 17, 2023. The monthly cash dividend is expected to be designated as an “eligible dividend” for Canadian federal and provincial income tax purposes.
About InPlay Oil Corp.
InPlay is a junior oil and gas exploration and production company with operations in Alberta focused on light oil production. The company operates long-lived, low-decline properties with drilling development and enhanced oil recovery potential as well as undeveloped lands with exploration possibilities. The common shares of InPlay trade on the Toronto Stock Exchange under the symbol IPO and the OTCQX Exchange under the symbol IPOOF.
Michael Heim, CFA, Senior Research Analyst, Noble Capital Markets, Inc.
Refer to the bottom of the report for important disclosures
OPEC cut boosts oil prices and energy stocks, offsetting last quarter’s underperformance in one day. OPEC announced a 1 million bbls./day voluntary production cut causing oil prices to rise 6.3% to a level near $80/bbl. and the XLE Energy Index to rise 4.5% the day after the announcement.
If domestic producers had the ability to expand production, they would have already. In the past, domestic production has risen in response to higher oil prices. In recent years, however, rig count has not increase as much as one would expect given the rise in oil prices. We believe the low rig count reflects a decrease in the number of economically feasible drilling locations. We would note that producers are generally able to produce oil at a cost of $30-$40/bbl. well below oil prices. If producers had the ability to ramp up drilling, we would have thought they would have done so even at $60/bbl. prices.
Horizontal drilling and fracking have increased production decline curves putting companies on a treadmill just to maintain production. More than half of domestic production comes from wells drilled in the last 24 months. The implication is that domestic oil producers are hard pressed to drill enough wells to offset production declines, let alone increase overall production to counter production declines by OPEC. As a result, we believe oil prices could remain high for many years.
Small producers and companies with a large drilling portfolio are best positioned. Larger producers continue to be constrained from expanding oil operations given political and shareholder pressures to move away from carbon-based energy. Smaller producers face less pressure. Companies with ample acreage and drilling prospects are best positioned to take advantage of a prolonged oil price upcycle.
Look for an increased focus on returning capital to shareholders. After several years of high energy prices, many companies have paid down debt and invested in infrastructure. With drilling prospects limited, we believe management will increasing look to raise dividends or repurchase shares.
Energy Stocks
Energy stocks, as measured by the XLE Energy Index, declined 5.3% in the 2023 first quarter. The decline was a sharp contrast to the 7.0% increase in the S&P 500 Index. The decline comes after several years of strong performances for energy stocks and reflects a 5.7% decrease in oil prices and a 50.5% decrease in natural gas prices. Worthy of note, as we are writing this report on April 3rd, oil prices have risen 6.3% and the XLE Energy Index is up 4.5% in response to an announcement by OPEC+ to reduce production by more than 1 million barrels per day. Following the announcement, oil prices settled above $80/bbl. almost reaching the price at the end of 2022.
Figure #1
If the cuts are adhered to, it will represent a significant increase in the excess production capacity of OPEC+. The surplus has grown steadily since the pandemic surpassing 5 million bbls./day according to the U.S. Energy Information Administration. That surplus had begun to decrease as the pandemic eased and global oil demand returned to normal levels. A reduction in production levels would return surplus capacity to pandemic levels.
Figure #2
With OPEC+ reducing production and oil prices rising, it will be interesting to see if producers in North America will respond by increasing production. In the past, when oil prices rose sharply, producers responded by drilling more wells. The advent of horizontal drilling and fracking over the last 15 years has greatly improved the economics of drilling in the basin by increasing the initial flow rates of oil and gas wells. As the chart below indicates, almost all wells drilled in North America are horizontal wells.
Figure #3
Unfortunately, one of the impacts of increased oil and gas flow is that production will decline at a higher rate after the initial production. That means more and more wells need to be drilled just to offset the drop in production. The chart below, while somewhat dated, shows Permian Basin oil production separated by the year wells came on-line. The chart shows that in 2022, more than half of all oil production came from wells drilled in 2021 or 2022. The implication is that domestic oil producers are hard pressed to drill enough wells to offset production declines, let alone increase overall production to counter production declines by OPEC+.
Figure #4
Source: Novi Labs
Without a rise in domestic production, it is likely that oil prices will remain at elevated levels. This is good news for producers who can produce oil at $30-$40 per barrel. The high netbacks (prices less royalties and operating costs) mean increased profits and cash flow for energy companies. And, if an energy company is fortunate enough to have a large acreage position with an abundance of potential drilling sites, growth rates will accelerate.
Natural Gas Prices
The outlook for natural gas, however, is not as rosy. Natural gas prices fell sharply this winter in response to warm weather and weak economic conditions.
Figure #5
Source: Natural Gas Intelligence
Storage levels, which were running below historical levels, are now at five-year highs for this time of year. With the winter heating season now coming to an end, storage levels are unlikely to reverse. As a result, natural gas prices could remain depressed until the fall heating season.
Figure #6
Outlook
A dismal quarter for the energy sector got a shot in the arm on the first day of the new quarter with a surprise OPEC+ production cut announcement. The announcement was welcomed news for producers that were already seeing profitable production margins and high returns on drilling investments. Cash flow levels are high and companies have been expanding operations and returning capital to shareholders. As investment opportunities become sparse and debt levels become low (or completely eliminated), we believe management will increase the focus on raising dividend levels and repurchasing shares. Share repurchases should support energy stock prices increases and an increased dividend yield should protect against any potential share price weakness.
We believe the case for smaller cap energy stocks is especially strong. Major oil companies are facing increasing pressure to focus on renewable energy instead of producing more carbon-based fuel. Smaller cap energy companies are less tethered and often able to acquire and exploit properties being ignored by the majors. If our belief that a world-wide recession is already factored into energy prices is correct, small cap energy companies will be in the best position to take advantage of any energy price increase resulting from OPEC+ production cuts.
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ANALYST CREDENTIALS, PROFESSIONAL DESIGNATIONS, AND EXPERIENCE
Senior Equity Analyst focusing on Basic Materials & Mining. 20 years of experience in equity research. BA in Business Administration from Westminster College. MBA with a Finance concentration from the University of Missouri. MA in International Affairs from Washington University in St. Louis. Named WSJ ‘Best on the Street’ Analyst and Forbes/StarMine’s “Best Brokerage Analyst.” FINRA licenses 7, 24, 63, 87
WARNING
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RESEARCH ANALYST CERTIFICATION
Independence Of View All views expressed in this report accurately reflect my personal views about the subject securities or issuers.
Receipt of Compensation No part of my compensation was, is, or will be directly or indirectly related to any specific recommendations or views expressed in the public appearance and/or research report.
Ownership and Material Conflicts of Interest Neither I nor anybody in my household has a financial interest in the securities of the subject company or any other company mentioned in this report.
Michael Heim, CFA, Senior Research Analyst, Noble Capital Markets, Inc.
Refer to the full report for the price target, fundamental analysis, and rating.
We believe the market is undervaluing Hemisphere Energy’s asset base cash flow generation. We believe the stock price will move towards our price target as the company generates operating cash flow that is used to expand operations and return capital to shareholders. We view the investment as fairly low risk because it is expanding operations is an area that is well known and already providing high returns on investment.
Strong production growth. Production increased 55% in 2022 and management expects production to grow another 10-15% in 2023 in response to the addition of new wells. Unless there is a dramatic drop in oil prices, we believe the company will be able to maintain a double-digit production growth rate for the foreseeable future. Longer-term growth may be dependent upon completing a step-out acquisition to increase the company’s drilling locations.
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CALGARY, AB, March 21, 2023 /CNW/ – Alvopetro Energy Ltd. (TSXV: ALV) (OTCQX: ALVOF) is pleased to announce a 17% increase in our quarterly dividend, to US$0.14 per common share, our financial results for the year ended December 31, 2022, filing of our annual information form, an automatic share repurchase plan, and an operational update.
All references herein to $ refer to United States dollars, unless otherwise stated and all tabular amounts are in thousands of United States dollars, except as otherwise noted.
President & CEO, Corey C. Ruttan commented:
“We are very pleased with our 2022 results, from revenues of $63.5 million we generated $49.9 million of funds flow from operations and net income of $31.7 million, increases of 82%, 102% and 467% respectively, year over year. This represents industry leading operating netback margins underpinning our disciplined capital allocation model that balances organic growth and stakeholder returns. Since commencing production from our Caburé project in 2020, we have repaid all outstanding debt and today’s announcement represents the third increase in our quarterly dividend since Q1 2022. With this, we will have already returned $22 million ($0.62/share) to shareholders in the form of dividends. We are also firmly focused on our next phase of growth and are looking forward to an exciting 2023 capital program.”
Quarterly Dividend Increased 17% to $0.14 per Share
Alvopetro is pleased to announce that our Board of Directors has approved a 17% increase in our quarterly dividend, to $0.14 per common share, payable in cash on April 14, 2023, to shareholders of record on March 31, 2023. This dividend is designated as an “eligible dividend” for Canadian income tax purposes.
Dividend payments to non-residents of Canada will be subject to withholding taxes at the Canadian statutory rate of 25%. Shareholders may be entitled to a reduced withholding tax rate under a tax treaty between their country of residence and Canada. For further information, see Alvopetro’s website at https://alvopetro.com/Dividends-Non-resident-Shareholders.
Operational Update
Our average daily sales have continued at strong rates in 2023, averaging 2,754 boepd in January and a new daily record of 2,866 boepd in February. Effective February 1, 2023, our natural gas price increased to BRL2.00/m3 and is effective for all natural gas sales from February 1 to July 31, 2023. Including recently approved and enhanced sales tax credits, our realized gas price, net of sales taxes, for the month of February was approximately $12.23/Mcf (based on our average heat content to date and the average February 2023 BRL/USD foreign exchange rate of 5.17).
On February 6, 2023, we announced our 2023 capital program, focused on lower risk development opportunities on our Murucututu natural gas project and our Bom Lugar oil field. We have commenced stimulation operations at our 197(1) well on Murucututu. The 197(1) well location has already been tied in to our 183(1) facility and we expect to commence production from the well in the second quarter. Following this stimulation, we plan to drill two follow-up wells at Murucututu, with one well having additional uphole exploration potential. We have budgeted total capital expenditures of $16 million for our Murucututu project in 2023.
On our Bom Lugar field, we plan to drill up to two development wells in 2023, targeting the Caruaçu Formation with additional potential in the deeper Gomo and Agua Grande Formations, the first of which is planned for the second quarter. Total capital expenditures of up to $11 million are budgeted at Bom Lugar.
Additional capital spending budgeted for 2023 includes $3 million on our Caburé field for the expansion of unit facilities and drilling two additional wells, $0.5 million at our Mãe-da-lua field for stimulation of the existing well and $0.4 million in capital expenditures at our 182-C2 and 183-B2 wells.
Automatic Share Repurchase Plan
In January 2023, we received approval from the TSX Venture Exchange (“TSXV”) for a normal course issuer bid (the “NCIB”) as more particularly described in our news release dated January 3, 2023. The terms of the NCIB permit Alvopetro to repurchase up to 2,876,414 common shares from January 6, 2023 to the earlier of January 5, 2024 or when the NCIB is completed or terminated by Alvopetro. No repurchases have been made under the NCIB to date.
Alvopetro intends to enter into an automatic share purchase plan (“ASPP”) with our designated broker, subject to the approval of the TSXV. The ASPP is intended to allow for the purchase of common shares under the NCIB at times when the Corporation may not ordinarily be permitted to purchase common shares due to regulatory restrictions and customary self-imposed blackout periods.
The ASPP is to be implemented upon TSXV approval and would allow the designated broker to purchase common shares pursuant to the proposed ASPP until the expiry of the NCIB on January 5, 2024. Such purchases will be determined by the broker at its sole discretion based on the purchasing parameters set out by the Corporation in accordance with the rules of the TSXV, applicable securities laws and the terms of the ASPP. The ASPP will terminate on the earlier of the date on which: (i) the NCIB expires; (ii) the maximum number of common shares have been purchased under the ASPP; and (iii) the Corporation terminates the ASPP in accordance with its terms.
Outside of the ASPP and outside of pre-determined blackout periods, common shares may continue to be purchased under the NCIB based on management’s discretion, in compliance with the rules of the TSXV and applicable securities laws. All purchases made under the ASPP will be included in the number of common shares available for purchase under the NCIB.
December 31, 2022 Reserves and Net Asset Value
On February 28, 2023, Alvopetro announced its December 31, 2022 reserves based upon the independent reserve assessment and evaluation prepared by GLJ Ltd. (“GLJ”) dated February 27, 2023 with an effective date of December 31, 2022 (the “GLJ Reserves and Resources Report”).
Key highlights from the GLJ Reserves and Resources Report1:
2P net present value before tax discounted at 10% (“NPV10”) increased 17% to $348.2 million.
Proved reserves (“1P”) decreased 12% to 3.9 MMboe and 2P reserves increased 3% to 9.0 MMboe after 0.9 MMboe of production in 2022.
2P production replacement ratio of 132%.
2P F&D costs of $28.66/boe.
2P recycle ratio of 2.1 times.
2P Net Asset Value of CAD$13.70/share ($9.99/share) before any potential from contingent or prospective resources.
Risked best estimate contingent resource of 2.9 MMboe (NPV10 $62.2 million) and risked best estimate prospective resource of 12.5 MMboe (NPV10 $259.1 million).
1 Refer to the section entitled “Oil and Natural Gas Advisories” for additional disclosures regarding oil and natural gas reserves, contingent resources and prospective resources. In addition refer to “Oil and – Natural Gas Advisories – Other Metrics” and “Non-GAAP and Other Financial Measures” for additional disclosures and assumptions used in calculating production replacement ratio, F&D costs, recycle ratio, net asset value and net asset value per share.
Financial and Operating Highlights – Fourth Quarter of 2022
Our average daily sales increased to a new quarterly record of 2,724 boepd (+3% from Q3 2022 and +12% from Q4 2021).
With natural gas sales in Q4 2022 continuing at the ceiling price in our contract, our average realized natural gas price was $11.18/Mcf (+58% from Q4 2021) and our average realized price per boe was $68.13 (+54% from Q4 2021). Higher realized prices and record daily sales volumes resulted in a 73% increase in our natural gas, condensate and oil revenue compared to Q4 2021.
Our operating netback was $60.08 per boe in Q4 2022, an improvement of $23.70 per boe from Q4 2021 (+65%) and $0.25 per boe from Q3 2022.
We generated funds flows from operations of $13.2 million ($0.36 per basic share and $0.35 per diluted share), an increase of $6.7 million compared to Q4 2021 and a decrease of $0.2 million compared to Q3 2022.
We reported net income of $5.2 million in Q4 2022, an increase of $2.4 million (+87%) compared to Q4 2021. Net income was impacted by impairment expense of $6.3 million recognized on exploration assets.
Capital expenditures totaled $5.9 million, including drilling and testing costs for our 182-C2 well, testing of the Unit-C well and facilities expenditures at the Caburé unit, testing costs for our 183-B1 well, development costs on our Murucututu project and long-lead purchases.
Our Q4 2022 dividend increased 50% to $0.12 per share. The Q4 2022 dividend was paid on January 13, 2023 to shareholders of record on December 30, 2022.
Our cash and working capital increased to $14.7 million, an improvement of $2.5 million compared to September 30, 2022 and an increase of $12.1 million compared to December 31, 2021 working capital net of debt of $2.6 million.
Financial and Operating Highlights – Year Ended December 31, 2022
Our annual sales averaged 2,557 boepd (95% natural gas, 4% NGLs from condensate and marginal crude oil production), an increase of 8% compared to 2021.
We reported net income of $31.7 million, compared to $5.6 million in 2021 (+467%).
We generated funds flow from operations of $49.9 million ($1.44 per basic share on $1.35 per diluted share) compared to $24.6 million in 2021 ($0.74 per basic share and $0.71 per diluted share).
Capital expenditures totaled $24.8 million in 2022.
In the third quarter of 2022, all outstanding warrants were exercised. Alvopetro received cash proceeds of $2.4 million and issued a total of 2,081,616 common shares on the exercise.
The credit facility was fully repaid in September 2022 and has been cancelled.
Dividends totaled $0.36 per share in 2022 compared to $0.12 per share in 2021 (+200%).
The following table provides a summary of Alvopetro’s financial and operating results for periods noted. The consolidated financial statements with the Management’s Discussion and Analysis (“MD&A”) are available on our website at www.alvopetro.com and will be available on the System for Electronic Document Analysis and Retrieval (SEDAR) website at www.sedar.com.
2022 Results Webcast
Alvopetro will host a live webcast to discuss 2022 financial results at 9:00 am Mountain time on Wednesday March 22, 2023. Details for joining the event are as follows:
The webcast will include a question and answer period. Online participants will be able to ask questions through the Zoom portal. Dial-in participants can email questions directly to [email protected].
Annual Information Form
Alvopetro has filed its annual information form (“AIF”) with the Canadian securities regulators on SEDAR. The AIF includes the disclosure and reports relating to oil and gas reserves data and other oil and gas information required pursuant to National Instrument 51-101 of the Canadian Securities Administrators. The AIF may be accessed electronically at www.sedar.com.
Corporate Presentation
Alvopetro’s updated corporate presentation is available on our website at:
Alvopetro Energy Ltd.’svision is to become a leading independent upstream and midstream operator in Brazil. Our strategy is to unlock the on-shore natural gas potential in the state of Bahia in Brazil, building off the development of our Caburé natural gas field and our strategic midstream infrastructure.
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 news release.
Oil and Natural Gas Advisories
Oil and Natural Gas Reserves
The disclosure in this news release summarizes certain information contained in the GLJ Reserves and Resources Report but represents only a portion of the disclosure required under National Instrument 51-101 (“NI 51-101”). For additional details, see our news release dated February 28, 2023. Full disclosure with respect to the Company’s reserves as at December 31, 2022 is contained in the Company’s annual information form for the year ended December 31, 2022 which has been filed on SEDAR (www.sedar.com). All net present values in this press release are based on estimates of future operating and capital costs and GLJ’s forecast prices as of December 31, 2022. The reserves definitions used in this evaluation are the standards defined by the Canadian Oil and Gas Evaluation Handbook (COGEH) reserve definitions, are consistent with NI 51-101 and are used by GLJ. The net present values of future net revenue attributable to the Alvopetro’s reserves estimated by GLJ do not represent the fair market value of those reserves. Other assumptions and qualifications relating to costs, prices for future production and other matters are summarized herein. The recovery and reserve estimates of the Company’s reserves provided herein are estimates only and there is no guarantee that the estimated reserves will be recovered. Actual reserves may be greater than or less than the estimates provided herein. Possible reserves are those additional reserves that are less certain to be recovered than probable reserves. There is a 10% probability that the quantities actually recovered will equal or exceed the sum of proved plus probable plus possible reserves.
Contingent Resources
This news release discloses estimates of Alvopetro’s contingent resources and the net present value associated with net revenues associated with the production of such contingent resources as included in the GLJ Reserves and Resources Report. There is no certainty that it will be commercially viable to produce any portion of such contingent resources and the estimated future net revenues do not necessarily represent the fair market value of such contingent resources. Estimates of contingent resources involve additional risks over estimates of reserves. For additional details with respect to Alvopetro’s contingent resources evaluated as at December 31, 2022, see our news release dated February 28, 2023 and additional details contained in the Company’s annual information form for the year ended December 31, 2022 which has been filed on SEDAR (www.sedar.com).
Prospective Resources
This news release discloses estimates of Alvopetro’s prospective resources included in the GLJ Reserves and Resources Report. There is no certainty that any portion of the prospective resources will be discovered and even if discovered, there is no certainty that it will be commercially viable to produce any portion. Estimates of prospective resources involve additional risks over estimates of reserves. The accuracy of any resources estimate is a function of the quality and quantity of available data and of engineering interpretation and judgment. While resources presented herein are considered reasonable, the estimates should be accepted with the understanding that reservoir performance subsequent to the date of the estimate may justify revision, either upward or downward. For additional details with respect to Alvopetro’s prospective resources evaluated as at December 31, 2022, see our news release dated February 28, 2023 and additional details contained in the Company’s annual information form for the year ended December 31, 2022 which has been filed on SEDAR (www.sedar.com).
Other Metrics
This press release contains metrics commonly used in the oil and natural gas industry, which have been prepared by management, including “F&D costs”, “net asset value”, “net asset value per share”, “production replacement ratio” and “recycle ratio”. These terms do not have a standardized meaning and may not be comparable to similar measures presented by other companies, and therefore should not be used to make such comparisons.
“F&D costs” are reflected on a per barrel of oil equivalent and are calculated as the sum of capital expenditures in the current year plus the change in FDC for the period, divided by the change in reserves in the period, before current year production. The 2022 F&D costs are computed as follows:
“Net asset value” is based on the before tax net present value of the Company’s reserves as at December 31, 2022, discounted at 10% plus the Company’s net working capital balance as of December 31, 2022. Net working capital is a capital management measure. See “Non-GAAP and Other Financial Measures” below for further details.
“Net asset value per share” is based on the computation of net asset value divided by basic shares outstanding of 36,311,579 adjusted to Canadian dollars based on the foreign exchange rate on March 21, 2023.
“Production replacement ratio” is calculated as total reserve additions divided by current year production. Alvopetro’s 2P production replacement ratio in 2022 is calculated as:
“Recycle ratio” is calculated by dividing the 2022 operating netback by F&D costs per boe for the year. The Company’s 2022 recycle ratio is calculated as follows:
Management uses these oil and gas metrics for its own performance measurements and to provide shareholders with measures to compare our operations over time. Readers are cautioned that the information provided by these metrics, or that can be derived from the metrics presented in this press release, should not be relied upon for investment or other purposes.
Non-GAAP and Other Financial Measures
This news release contains references to various non-GAAP financial measures, non-GAAP ratios, capital management measures and supplementary financial measures as such terms are defined in National Instrument 52-112 Non-GAAP and Other Financial Measures Disclosure. Such measures are not recognized measures under GAAP and do not have a standardized meaning prescribed by IFRS and might not be comparable to similar financial measures disclosed by other issuers. While these measures may be common in the oil and gas industry, the Company’s use of these terms may not be comparable to similarly defined measures presented by other companies. The non-GAAP and other financial measures referred to in this report should not be considered an alternative to, or more meaningful than measures prescribed by IFRS and they are not meant to enhance the Company’s reported financial performance or position. These are complementary measures that are used by management in assessing the Company’s financial performance, efficiency and liquidity and they may be used by investors or other users of this document for the same purpose. Below is a description of the non-GAAP financial measures, non-GAAP ratios, capital management measures and supplementary financial measures used in this news release. For more information with respect to financial measures which have not been defined by GAAP, including reconciliations to the closest comparable GAAP measure, see the “Non-GAAP Measures and Other Financial Measures” section of the Company’s MD&A which may be accessed through the SEDAR website at www.sedar.com.
Non-GAAP Financial Measures
Operating netback
Operating netback is calculated as natural gas, oil and condensate revenues less royalties and production expenses. This calculation is provided in the “Operating Netback” section of the Company’s MD&A using our IFRS measures. The Company’s MD&A may be accessed through the SEDAR website at www.sedar.com. Operating netback is a common metric used in the oil and gas industry used to demonstrate profitability from operations.
Non-GAAP Financial Ratios
Operating netback per boe
Operating netback is calculated on a per unit basis, which is per barrel of oil equivalent (“boe”). It is a common non-GAAP measure used in the oil and gas industry and management believes this measurement assists in evaluating the operating performance of the Company. It is a measure of the economic quality of the Company’s producing assets and is useful for evaluating variable costs as it provides a reliable measure regardless of fluctuations in production. Alvopetro calculated operating netback per boe as operating netback divided by total sales volumes (barrels of oil equivalent). This calculation is provided in the “Operating Netback” section of the Company’s MD&A using our IFRS measures. The Company’s MD&A may be accessed through the SEDAR website at www.sedar.com. Operating netback is a common metric used in the oil and gas industry used to demonstrate profitability from operations on a per unit basis (boe).
Operating netback margin
Operating netback margin is calculated as operating netback per boe divided by the realized sales price per boe. Operating netback margin is a measure of the profitability per boe relative to natural gas, oil and condensate sales revenues per boe and is calculated as follows:
Funds Flow from Operations Per Share
Funds flow from operations per share is a non-GAAP ratio that includes all cash generated from operating activities and is calculated before changes in non-cash working capital, divided by the weighted the weighted average shares outstanding for the respective period. For the periods reported in this news release the cash flows from operating activities per share and funds flow from operations per share is as follows:
Capital Management Measures
Funds Flow from Operations
Funds flow from operations is a non-GAAP capital management measure that includes all cash generated from operating activities and is calculated before changes in non-cash working capital. The most comparable GAAP measure to funds flow from operations is cash flows from operating activities. Management considers funds flow from operations important as it helps evaluate financial performance and demonstrates the Company’s ability to generate sufficient cash to fund future growth opportunities. Funds flow from operations should not be considered an alternative to, or more meaningful than, cash flows from operating activities however management finds that the impact of working capital items on the cash flows reduces the comparability of the metric from period to period. A reconciliation of funds flow from operations to cash flows from operating activities is as follows:
Net Working Capital
Net working capital is computed as current assets less current liabilities. Net working capital is a measure of liquidity, is used to evaluate financial resources, and is calculated as follows:
Working Capital Net of Debt
Working capital net of debt is computed as net working capital surplus decreased by the carrying amount of the Credit Facility. Working capital net of debt is used by management to assess the Company’s overall financial position.
Supplementary Financial Measures
“Average realized natural gas price – $/Mcf” is comprised of natural gas sales as determined in accordance with IFRS, divided by the Company’s natural gas sales volumes.
“Average realized NGL – condensate price – $/bbl” is comprised of condensate sales as determined in accordance with IFRS, divided by the Company’s NGL sales volumes from condensate.
“Average realized oil price – $/bbl” is comprised of oil sales as determined in accordance with IFRS, divided by the Company’s oil sales volumes.
“Average realized price – $/boe” is comprised of natural gas, condensate and oil sales as determined in accordance with IFRS, divided by the Company’s total natural gas, condensate and oil sales volumes (barrels of oil equivalent).
“Royalties per boe” is comprised of royalties, as determined in accordance with IFRS, divided by the total natural gas, condensate and oil sales volumes (barrels of oil equivalent).
“Production expenses per boe” is comprised of production expenses, as determined in accordance with IFRS, divided by the total natural gas, condensate and oil sales volumes (barrels of oil equivalent).
BOE Disclosure
The term barrels of oil equivalent (“boe”) may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet per barrel (6 Mcf/bbl) of natural gas to barrels of oil equivalence is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. All boe conversions in this news release are derived from converting gas to oil in the ratio mix of six thousand cubic feet of gas to one barrel of oil.
Forward-Looking Statements and Cautionary Language
This news release contains forward-looking information within the meaning of applicable securities laws. The use of any of the words “will”, “expect”, “intend” and other similar words or expressions are intended to identify forward-looking information. Forward–looking statements involve significant risks and uncertainties, should not be read as guarantees of future performance or results, and will not necessarily be accurate indications of whether or not such results will be achieved. A number of factors could cause actual results to vary significantly from the expectations discussed in the forward-looking statements. These forward-looking statements reflect current assumptions and expectations regarding future events. Accordingly, when relying on forward-looking statements to make decisions, Alvopetro cautions readers not to place undue reliance on these statements, as forward-looking statements involve significant risks and uncertainties. More particularly and without limitation, this news release contains forward-looking statements concerning plans relating to the Company’s operational activities, proposed exploration development activities and the timing for such activities, exploration and development prospects of Alvopetro, capital spending levels, future capital and operating costs, timing and taxation of dividends and plans for dividends in the future, plans for share repurchases under the NCIB and the duration of the NCIB, future production and sales volumes, the expected natural gas price, gas sales and gas deliveries under Alvopetro’s long-term gas sales agreement, the expected timing of production commencement from the 197(1) well, the proposed automatic share purchase plan, and projected financial results. Forward-looking statements are necessarily based upon assumptions and judgments with respect to the future including, but not limited to, expectations and assumptions concerning the timing of regulatory licenses and approvals, equipment availability, the success of future drilling, completion, testing, recompletion and development activities and the timing of such activities, the performance of producing wells and reservoirs, well development and operating performance, expectations regarding Alvopetro’s working interest and the outcome of any redeterminations, environmental regulation, including regulation relating to hydraulic fracturing and stimulation, the ability to monetize hydrocarbons discovered, the outlook for commodity markets and ability to access capital markets, foreign exchange rates, general economic and business conditions, forecasted demand for oil and natural gas, the impact of the COVID-19 pandemic, weather and access to drilling locations, the availability and cost of labour and services, the regulatory and legal environment and other risks associated with oil and gas operations. The reader is cautioned that assumptions used in the preparation of such information, although considered reasonable at the time of preparation, may prove to be incorrect. Actual results achieved during the forecast period will vary from the information provided herein as a result of numerous known and unknown risks and uncertainties and other factors. In addition, the declaration, timing, amount and payment of future dividends remain at the discretion of the Board of Directors. Although we believe 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 we 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; delays or changes in plans with respect to exploration or development projects or capital expenditures; the uncertainty of reserve estimates; the uncertainty of estimates and projections relating to production, costs and expenses, reliance on industry partners, availability of equipment and personnel, uncertainty surrounding timing for drilling and completion activities resulting from weather and other factors, changes in applicable regulatory regimes and health, safety and environmental risks), commodity price and foreign exchange rate fluctuations, market uncertainty associated with financial institution instability, and general economic conditions. The reader is cautioned that assumptions used in the preparation of such information, although considered reasonable at the time of preparation, may prove to be incorrect. Although Alvopetro believes that the expectations and assumptions on which such forward-looking information is based are reasonable, undue reliance should not be placed on the forward-looking information because Alvopetro can give no assurance that it will prove to be correct. Readers are cautioned that the foregoing list of factors is not exhaustive. Additional information on factors that could affect the operations or financial results of Alvopetro are included in our annual information form which may be accessed on Alvopetro’s SEDAR profile at www.sedar.com. The forward-looking information contained in this news release is made as of the date hereof and Alvopetro undertakes no obligation to update publicly or revise any forward-looking information, whether as a result of new information, future events or otherwise, unless so required by applicable securities laws.
