Deal positions Bloom as a preferred power provider for Brookfield’s global AI factories and marks Brookfield’s first investment in its dedicated AI Infrastructure strategy
Shares of Bloom Energy (NYSE: BE) surged more than 20% in early trading Monday after the company announced a $5 billion strategic partnership with Brookfield Asset Management (NYSE: BAM, TSX: BAM) to develop and power next-generation AI infrastructure.
Under the agreement, Brookfield will invest up to $5 billion to deploy Bloom’s advanced fuel cell technology as the companies collaborate on the design and construction of “AI factories” — large-scale data centers purpose-built to meet the surging compute and energy demands of artificial intelligence. Bloom Energy will serve as Brookfield’s preferred onsite power provider for these facilities worldwide.
The partnership marks the first phase of a joint AI infrastructure vision and represents Brookfield’s inaugural investment through its newly established AI Infrastructure strategy, which focuses on power, compute, and capital integration for AI data centers. The two companies plan to announce their first European site before the end of the year.
“AI infrastructure must be built like a factory — with purpose, speed, and scale,” said KR Sridhar, Founder, Chairman and CEO of Bloom Energy. “AI factories demand massive power, rapid deployment and real-time responsiveness that legacy grids cannot support. Together with Brookfield, we’re creating a new blueprint for powering AI at scale.”
“Behind-the-meter power solutions are essential to closing the grid gap for AI factories,” added Sikander Rashid, Global Head of AI Infrastructure at Brookfield. “Bloom’s advanced fuel cell technology gives us the unique capability to design and construct modern AI factories with a holistic and innovative approach to power needs.”
A Blueprint for the AI Era
AI data centers are projected to require over 100 gigawatts of power in the U.S. alone by 2035, according to industry estimates. Bloom Energy’s solid oxide fuel cells generate electricity through chemical reactions rather than combustion, providing clean, resilient, and rapidly deployable onsite power — an attractive alternative to traditional grid dependency.
Bloom has already installed hundreds of megawatts of fuel cell systems supporting data centers for American Electric Power, Equinix, and Oracle. The company’s systems can be scaled modularly, reducing construction timelines and improving energy efficiency for high-demand AI applications.
Brookfield, one of the world’s largest alternative asset managers with over $1 trillion in assets under management, has been expanding aggressively into digital and energy infrastructure. Recent commitments include $9.98 billion to develop an AI data center in Sweden and €20 billion for AI projects in France. The firm also holds major stakes in Compass Datacenters, Duke Energy Florida, Colonial Enterprises, and Hotwire Communications, and recently inked a deal to supply Google with up to 3 GW of hydro power in the U.S.
Strategic Implications
The partnership underscores a growing convergence between energy technology and AI infrastructure. As the global race to build AI data centers accelerates, the need for reliable, low-carbon power sources has become a critical bottleneck. Brookfield’s capital and infrastructure expertise, combined with Bloom’s clean power solutions, could provide a scalable model for sustainable AI expansion.
For Bloom Energy, the partnership offers both near-term revenue visibility and long-term positioning at the center of AI-driven energy demand growth. For Brookfield, it establishes a strategic foothold in the AI ecosystem— one that aligns with its global energy transition and infrastructure investment priorities.
Transaction strengthens IsoEnergy’s top-tier uranium portfolio with Toro’s flagship Wiluna Project and expands presence in key global jurisdictions amid rising nuclear demand
IsoEnergy Ltd. (NYSE American: ISOU) and Toro Energy Ltd. (ASX: TOE) have entered into a scheme implementation deed under which IsoEnergy will acquire all issued and outstanding ordinary shares of Toro. The all-stock transaction will create a globally diversified uranium developer with significant resources and near-term production potential across Canada, the United States, and Australia.
Under the terms of the agreement, Toro shareholders will receive 0.036 IsoEnergy shares for each Toro share held, representing a 79.7% premium to Toro’s last traded price and a 92.2% premium to its 20-day volume-weighted average price (VWAP). Upon completion, IsoEnergy and Toro shareholders will own approximately 92.9% and 7.1%, respectively, of the combined company on a fully diluted basis. The deal values Toro at approximately AUD 75 million (CAD 68 million / USD 49 million) and is expected to close in the first half of 2026, subject to shareholder and regulatory approvals.
A Strengthened Uranium Platform
The merger will add Toro’s Wiluna Uranium Project in Western Australia — comprising the Centipede-Millipede, Lake Way, and Lake Maitland deposits — to IsoEnergy’s existing portfolio, which includes the ultra-high-grade Hurricane deposit in Canada’s Athabasca Basin, several past-producing U.S. uranium mines, and other exploration assets across North America and Australia.
The combined resource base will include:
55.2 million pounds U₃O₈ (M&I) and 4.9 million pounds U₃O₈ (Inferred) compliant under NI 43-101
78.1 million pounds U₃O₈ (M&I) and 34.6 million pounds U₃O₈ (Inferred) compliant under JORC standards
Historical resources totaling 154.3 million pounds U₃O₈ (M&I) and 88.2 million pounds U₃O₈ (Inferred)
This creates one of the largest and most geographically diversified uranium portfolios among mid-tier developers.
Strategic and Market Rationale
The merger comes amid growing confidence in the uranium market’s long-term outlook. The World Nuclear Association’s 2025 Fuel Report projects uranium demand to rise roughly 30% by 2030 and more than double by 2040. IsoEnergy’s expanded scale and jurisdictional diversification position it to capture value from this structural supply-demand imbalance.
Australia, home to the Wiluna Project, ranks #1 globally for uranium resources and is among the Top 5 producers worldwide. Western Australia is emerging as a key uranium jurisdiction alongside Cameco’s Kintyre and Yeelirrie projects and Deep Yellow’s Mulga Rock development.
“The acquisition of Toro Energy marks another important step in advancing IsoEnergy’s strategy to build a globally diversified, development-ready uranium platform,” said Philip Williams, CEO and Director of IsoEnergy. “The Wiluna Uranium Project strengthens our portfolio with a large, previously permitted asset in a top-tier jurisdiction at a time when global nuclear demand is accelerating.”
Richard Homsany, Executive Chairman of Toro, added, “This transaction creates significant value for our shareholders and provides an opportunity to participate in a larger, leading uranium company listed on the TSX and NYSE. Toro shareholders will gain exposure to a diverse uranium portfolio with strong growth potential and enhanced access to capital.”
Positioned for Growth
The merged entity will have enhanced balance sheet strength, improved access to global capital markets, and a broader platform for value-accretive growth opportunities across the uranium cycle. Following completion, Toro will be delisted from the Australian Securities Exchange (ASX), while IsoEnergy will remain publicly traded in Toronto and New York.
The deal follows IsoEnergy’s previously announced — and later terminated — plan to acquire Anfield Energy in early 2024, reflecting the company’s continued pursuit of strategic, scale-building opportunities in the uranium sector. Major Toro shareholders, including Mega Uranium Ltd. (12.7%) and its associate Mega Redport Pty Ltd., have indicated their intention to vote in favor of the scheme, provided no superior proposal emerges.
Shares of Lithium Americas (NYSE: LAC) soared nearly 100% on Wednesday after reports that the Trump administration is considering taking a stake in the company as part of a renegotiated federal loan package tied to the development of the Thacker Pass lithium mine in Nevada.
According to Reuters, the administration is seeking as much as a 10% equity stake in the Vancouver-based miner. The proposed arrangement comes as Lithium Americas works through terms of a $2.26 billion loan from the Department of Energy, originally granted during the first Trump administration.
Under the current negotiations, the company has offered the government no-cost warrants for up to 10% of its common stock. At the same time, the administration is reportedly pressing General Motors (NYSE: GM) — which owns a 38% stake in Thacker Pass and has invested $625 million — for purchase guarantees that would help shore up demand for the lithium produced at the site. GM shares ticked higher by more than 2% on the news.
A Strategic Lithium Project
Thacker Pass is expected to play a central role in U.S. energy security. Once operational, the project is projected to be the largest lithium mining operation in the Western Hemisphere. Its first production phase, slated for 2028, is forecast to produce more than 40,000 metric tons of lithium carbonate annually — enough to power batteries for roughly 800,000 electric vehicles.
For perspective, Albemarle’s (NYSE: ALB) Silver Peak mine in Nevada, currently the only operating lithium mine in the U.S., produces fewer than 5,000 metric tons per year. This makes Thacker Pass a significant leap in domestic production capacity at a time when global demand for electric vehicles, battery storage, and clean energy technologies is surging.
China currently dominates the global lithium industry, producing more than 40,000 metric tons per year and refining more than 65% of the world’s supply. By comparison, the U.S. refines less than 3%. This imbalance has made lithium one of the most strategically sensitive commodities in the energy transition.
“Lithium is the new oil,” said one energy analyst, noting that securing supply has become a cornerstone of U.S. industrial policy. “Without it, you can’t scale EV adoption or battery storage, and that makes projects like Thacker Pass crucial to long-term energy independence.”
The government’s interest in Lithium Americas follows similar moves to shore up domestic supply chains for other critical materials. In July, MP Materials (NYSE: MP) announced a multibillion-dollar deal with the Department of Defense that made the government its largest shareholder, boosting MP’s stock more than 50%. Meanwhile, Intel (NASDAQ: INTC) has climbed over 25% since talks of a potential government stake in the chipmaker became public.
This pattern underscores the administration’s strategy of leveraging federal investment to reduce reliance on foreign sources of essential resources, from rare earth elements to semiconductors.
Lithium Americas stock traded at $6.09 as of 2:08 p.m. EDT, up more than 98% on the day. The sharp rally comes despite ongoing weakness in lithium prices, which have fallen over the past year amid oversupply from China. Futures for lithium carbonate are down more than 12%, while lithium hydroxide has dropped more than 4.5%.
Those price pressures have raised concerns about the financial viability of large-scale U.S. mining projects. The administration’s involvement could provide a stabilizing force, ensuring that key projects like Thacker Pass remain on track. The first loan draw is expected this month, with construction at the Nevada site already underway.
For now, investors appear to be betting that federal backing — and a potential government equity stake — could cement Lithium Americas’ role as a cornerstone of America’s clean energy future.
The U.S. oil industry is facing a sharp slowdown, with layoffs and spending cuts rippling across the sector as lower crude prices and industry consolidation squeeze margins. The wave of belt-tightening could mark the end of the rapid production growth that helped the United States overtake other producers to become the world’s top oil supplier in recent years.
International crude prices have fallen roughly 12% this year, dragged lower in part by rising output from OPEC and its allies, who have been steadily ramping up supply to reclaim market share lost to U.S. shale producers. Prices are now hovering just above $62 a barrel, uncomfortably close to breakeven levels for many U.S. operators. For companies already grappling with higher costs and trade-related tariffs, the weaker pricing environment is forcing tough decisions.
ConocoPhillips, the nation’s third-largest oil producer, recently announced plans to cut up to a quarter of its workforce. The move follows Chevron’s decision earlier this year to trim about 20% of its staff, amounting to roughly 8,000 jobs. Oilfield service providers such as SLB and Halliburton have also been cutting jobs, underscoring how the slowdown is spreading beyond producers to the broader energy ecosystem.
The cuts aren’t limited to people. According to a Reuters review of second-quarter results, 22 publicly traded U.S. producers—including ConocoPhillips, Diamondback Energy, and Occidental Petroleum—have reduced their combined capital spending by about $2 billion. Industry insiders say those pullbacks, along with falling rig counts, are early warning signs that production growth is set to level off. Baker Hughes data shows that the U.S. oil rig count has dropped by nearly 70 so far this year, down to just over 400.
In the Permian Basin, the heart of America’s shale boom, the tone has shifted from aggressive expansion to cautious retrenchment. “We’ve gone from ‘drill, baby, drill’ to ‘wait, baby, wait,’” said one Texas producer, pointing out that prices need to stabilize closer to $70–$75 a barrel before rig activity rebounds. Without that, analysts warn that U.S. output will plateau and could even begin to decline, with OPEC quickly stepping in to fill the gap.
Research firms are already forecasting slower momentum. Energy Aspects expects U.S. onshore production to drop by 300,000 barrels per day in 2025, while Wood Mackenzie projects only modest growth of 200,000 barrels per day—far below the record-setting pace of recent years.
Adding to the pressure are rising costs, much of it tied to tariffs on steel and other inputs. Diamondback Energy expects the price of steel casing for wells to climb by nearly 25% this year, inflating breakeven costs across the industry. For ConocoPhillips, controllable costs have already risen by $2 per barrel since 2021, making profitability harder to sustain.
The impact on employment is significant. Texas labor data shows U.S. oil and gas production jobs fell by nearly 5,000 in the first half of 2025, while energy services jobs have dropped by about 23,000 since January. Even with gains in drilling efficiency, industry analysts caution that technology alone won’t be enough to offset the slowdown.
For now, the U.S. oil industry remains a global leader. But with lower prices, higher costs, and fewer rigs in action, the sector’s once-rapid growth story appears to be entering a more uncertain chapter.
CALGARY, AB, September 2, 2025 /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 $0.09 per common share payable on September 30, 2025, to shareholders of record at the close of business on September 15, 2025. 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.
For further information please contact: Doug Bartole, President and Chief Executive Officer, InPlay Oil Corp., Telephone: (587) 955-0632; Darren Dittmer, Chief Financial Officer, InPlay Oil Corp., Telephone: (587) 955-0634
In one of the largest utility deals of the year, Black Hills Corp. (NYSE: BKH) and NorthWestern Energy Group, Inc. (Nasdaq: NWE) announced a definitive agreement to merge in an all-stock, tax-free transaction that gives the combined company an enterprise value of roughly $15.4 billion. The boards of both companies approved the deal unanimously, setting the stage for the creation of a new regulated electric and natural gas utility with operations across eight states.
Together, the companies will serve about 2.1 million customers, including more than 700,000 electric customers and 1.4 million natural gas customers. Their combined footprint will stretch across Arkansas, Colorado, Iowa, Kansas, Montana, Nebraska, South Dakota, and Wyoming, supported by nearly 97,000 miles of transmission and distribution lines and close to 3 gigawatts of generation capacity from a mix of thermal, hydro, and wind resources. The companies expect the deal to nearly double their combined rate base to $11.4 billion, providing the scale needed to meet rising energy demand and expand infrastructure for new industries such as data centers.
Management emphasized that the merger would create long-term value for both shareholders and customers. The new utility is projected to deliver annual earnings-per-share growth in the range of 5 to 7 percent, a pace that exceeds what either company had targeted on a standalone basis. Executives also pointed to stronger access to capital, a more balanced regulatory profile, and improved financial flexibility as key benefits of the transaction. Shareholders of Black Hills will own about 56 percent of the merged company, while NorthWestern shareholders will hold the remaining 44 percent.
The combined company will be headquartered in Rapid City, South Dakota, but leadership responsibilities will be shared. NorthWestern’s chief executive Brian Bird will serve as CEO, while Black Hills’ senior vice president and chief utility officer Marne Jones will become chief operating officer. Crystal Lail, currently CFO of NorthWestern, will take the same role in the new company, and Kimberly Nooney, CFO of Black Hills, will become chief integration officer. The board of directors will include six members from Black Hills and five from NorthWestern.
Both companies said they remain committed to safety, reliability, and sustainability, and they plan to continue investing heavily in grid modernization and renewable energy. With more than $7 billion in planned investments between 2025 and 2029, the new entity expects to play a central role in supporting the energy transition while keeping costs manageable for customers.
The merger, which is subject to shareholder approval, regulatory review in several states, and clearance from the Federal Energy Regulatory Commission, is expected to close within 12 to 15 months. If approved, it would establish a premier mid-cap regulated utility with diversified operations, predictable cash flows, and the capacity to pursue growth opportunities across an expanding energy landscape.
Mark Reichman, Managing Director, Equity Research Analyst, Natural Resources, Noble Capital Markets, Inc.
Hans Baldau, Associate Analyst, Noble Capital Markets, Inc.
Refer to the full report for the price target, fundamental analysis, and rating.
Second quarter financial results. Hemisphere reported oil and gas revenue of C$24.4 million in the second quarter, down 15.7% from the prior year period but ahead of our estimate of C$20.9 million. Net income was C$7.1 million, or C$0.07 per share, compared to C$10.4 million, or C$0.10 per share, last year, and above our forecast of C$5.8 million, or C$0.06 per share. Average daily production rose to 3,826 boe/d, up from 3,628 in Q2 2024 and modestly ahead of our estimate of 3,800 boe/d. The company realized an average sales price of C$70.06/boe, compared to C$87.65/boe in the prior year quarter. Adjusted funds flow totaled C$10.3 million, or C$0.10 per diluted share, versus C$13.6 million, or C$0.14 per diluted share, a year ago. This result exceeded our estimate of C$8.9 million, or C$0.09 per diluted share.
Updating estimates. Given the stronger-than-expected second quarter, we are raising our 2025 revenue forecast to C$97.7 million from C$95.0 million. Our operating expense assumption has been modestly increased to C$38.8 million from C$38.4 million. We now project net income of C$29.6 million, or C$0.30 per share, up from our prior forecast of C$28.7 million, or C$0.28 per share. Adjusted funds flow is expected to reach C$43.3 million, compared to our earlier estimate of C$42.2 million. For 2026, we forecast revenue of C$93.7 million, net income of C$27.5 million, or C$0.28 per share, and AFF of C$39.6 million, reflecting our expectation of a softer commodity price environment relative to 2025.
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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, Aug. 13, 2025 /CNW/ – InPlay Oil Corp. (TSX: IPO) (OTCQX: IPOOF) (“InPlay” or the “Company“) announces its financial and operating results for the three and six months ended June 30, 2025 which is our first quarter following the April 7, 2025 closing date of the strategic acquisition of Cardium focused light oil assets in the Pembina area of Alberta (the “Acquisition“). InPlay’s condensed unaudited interim financial statements and notes, as well as its Management’s Discussion and Analysis (“MD&A”) for the three and six months ended June 30, 2025 will be available at “www.sedarplus.ca” and on our website at “www.inplayoil.com“. An updated corporate presentation is available on our website.
We are excited about InPlay’s future following the highly accretive acquisition completed in the second quarter. This transformative transaction has significantly enhanced the Company’s scale, market capitalization, and long-term sustainability. With a longer reserve life and an expanded inventory of high quality drilling locations, the combined Company is well positioned to generate strong free adjusted funds flow (“FAFF”)(3) for many years to come.
InPlay is off to a very strong start with second quarter production exceeding expectations by approximately 1,000 boe/d. This outperformance was driven by base production performing above expectations and seven (7.0 net) wells brought onstream in March significantly outperforming our type curves by ~135% on average based on the first 120 days of initial production (“IP”). Notably, three wells brought onstream in March ranked among the top ten Cardium producers in April with two of them holding the number one and two spots in April and May, and ranking second and third in June. These wells achieved payout in under 90 days in a US$60 WTI pricing environment. As a result of this outperformance, current production based on field estimates remains at 19,400 boe/d even though no new wells have been brought on since March. We now expect 2025 average production to be at the upper end of our guidance range. In addition, strong capital efficiencies are expected to result in capital spending landing in the lower half of our previously announced capital budget of $53 – $60 million. The Company continues to prioritize free cash flow generation to be used for debt reduction and the continued return of capital to shareholders through our monthly dividend.
Another exciting development is the recent announcement that Delek Group Ltd. (“Delek”) has become a 32.7% strategically aligned shareholder of InPlay. Delek brings a proven track record of value creation in the energy sector. They hold a 45% working interest in the largest natural gas field in the Mediterranean, with an estimated 23 TCF of recoverable natural gas. Additionally, Delek has been instrumental in the growth of Ithaca Energy plc, where they hold a 52% equity stake and have overseen production growth from 30,000 boe/d to over 120,000 boe/d since 2019.
For the remainder of 2025, InPlay plans to drill 5.0 – 5.5 net Cardium wells in Pembina. InPlay’s second half drilling campaign recently commenced in August, with the spudding of a three well pad which are in close proximity to the Company’s top producing Cardium wells and are expected to be on production near the beginning of October. The application of InPlay’s drilling and completion techniques to the acquired assets is expected to drive continued strong performance from new wells with additional capital directed to facility upgrades, optimization and required infrastructure projects.
InPlay will continue to be disciplined and timely in capital spending in the current commodity price environment, maintaining a focus on strong FAFF, debt reduction, per share growth and continuation of our return to shareholder strategy. To further enhance stability and mitigate risk, the Company has secured commodity hedges extending through 2025 and into 2026. InPlay has hedged over 70% of natural gas production and approximately 60% of light crude oil production for the second half of 2025.
Second Quarter 2025 Highlights
Successfully closed the strategic acquisition of Cardium focused light oil assets at highly accretive metrics, enhancing FAFF by 65% on a per share basis, expanding our drilling inventory to over 400 locations, lowering our corporate base decline rate to 24% and strengthening dividend sustainability (2025 forecasted FAFF equal to 2.5 times base dividend).
Achieved average quarterly production of 20,401 boe/d(1) (62% light crude oil and NGLs), a 125% increase from Q1 2025, including a 13% increase to light crude oil and liquids weighting to 62% from 55% and a 35% increase in light oil weighting to 51% from 38% in the first quarter of 2025 with oil being the main driver behind our netbacks.
Generated strong quarterly Adjusted Funds Flow (“AFF”)(2) of $40.1 million ($1.49 per basic share(3)).
Achieved significant FAFF of $35.5 million ($1.32 per basic share(3)) allowing the Company to reduce net debt by approximately $26 million, more than originally forecasted, resulting in a quarterly annualized net debt to earnings before interest, taxes and depreciation (“EBITDA”)(3) ratio of 1.2 times.
Realized operating income of $50.5 million(3), an increase of 140% compared to Q1 2025 leading to a strong operating income profit margin(3) of 55%, up from 54% in Q1 2025.
Improved field operating netbacks(3) to $27.20/boe, a 6% increase compared to Q1 2025 despite an 11% decrease to WTI pricing (13% decrease to realized crude oil pricing) and a 22% decrease in AECO natural gas pricing compared to Q1 2025.
Returned $7.9 million to shareholders via monthly dividends, representing a 10% yield relative to the current share price. Since November 2022, InPlay has distributed $52 million in dividends (including dividends declared to date in the third quarter).
Second Quarter 2025 Financial & Operations Overview:
InPlay’s second quarter results exceeded expectations and marked the first reporting period incorporating the recently acquired assets, with pro forma operations effective April 8, 2025. Due to the outstanding efforts of our team and InPlay’s strong knowledge and focus in the area, the acquired assets were seamlessly integrated with no disruption to the Company’s ongoing operations.
Quarterly production averaged 20,401 boe/d(1) (62% light crude oil and NGLs) which was approximately 1,000 boe/d above internal forecasts. Base production exceeded expectations, and the seven (7.0 net) wells drilled on the combined assets in the first quarter significantly outperformed internal forecasts by approximately 135% (based on IP 120) as highlighted in the table below.
02-25 Pad (per well average)
14-33 Pad (per well average)
08-01 Pad (per well average)
boe/d
Oil and NGLs %
boe/d
Oil and NGLs %
boe/d
Oil and NGLs %
IP 30
887
88 %
680
75 %
265
89 %
IP 60
937
87 %
493
66 %
290
87 %
IP 90
922
85 %
569
63 %
288
86 %
IP 120
892
85 %
430
60 %
285
83 %
IP 150
N/A
N/A
487
58 %
275
82 %
Current
791
82 %
299
44 %
217
77 %
>300% above type curve
>75% above type curve
>25% above type curve
InPlay generated AFF of $40.1 million ($1.49 per basic share) a 138% increase from the first quarter of 2025. Limited capital spending in the second quarter of $4.6 million, resulted in $35.5 million of FAFF ($1.32 per basic share), highlighting the strong FAFF generation of the combined Company. These strong results were achieved despite an 11% decrease to WTI pricing (13% decrease to realized crude oil pricing) and a 22% decrease in AECO natural gas pricing compared to Q1 2025. The Company paid $7.9 million ($12.0 million in the first half of 2025) in dividends during the quarter.
During the quarter InPlay generated a net loss of $3.2 million. After excluding one-time transaction costs and the impact of unrealized mark-to-market hedging gains/losses, InPlay generated adjusted net income(3) of $2.0 million ($0.08 per basic share) in the quarter.
Strong results had net debt levels at the end of the quarter at $223 million, $5 million lower than originally anticipated. The quarterly annualized net debt to EBITDA ratio for the second quarter of 1.2x is evidence that our post-Acquisition accelerated debt reduction goals are well on track.
Operating synergies and stronger production allowed InPlay to maintain operating costs per boe in the second quarter in line with pre-acquisition levels and synergies have started to show a reduction in G&A cost per boe.
On behalf of the entire InPlay team and our Board of Directors, we thank our shareholders for their ongoing support as we execute our strategy of disciplined growth, reliable returns, and long-term value creation. We would like to send a special thanks to our employees for their significant effort in enabling a smooth integration of the new assets. We are very optimistic about building on the momentum from our strategic Acquisition that has transformed the future of the Company.
Notes:
1.
See “Production Breakdown by Product Type” at the end of this press release.
2.
Capital management measure. See “Non-GAAP and Other Financial Measures” contained within this press release.
3.
Non-GAAP financial measure or ratio that does not have a standardized meaning under International Financial Reporting Standards (IFRS) and GAAP and therefore may not be comparable with the calculations of similar measures for other companies. Please refer to “Non-GAAP and Other Financial Measures” contained within this press release and in our most recently filed MD&A.
4.
Supplementary measure. See “Non-GAAP and Other Financial Measures” contained within this press release.
5.
Common share and per common share amounts have been updated to reflect the six for one (6:1) common share consolidation effective April 14, 2025.
For further information please contact:
Doug Bartole President and Chief Executive Officer InPlay Oil Corp. Telephone: (587) 955-0632
Vancouver, British Columbia–(Newsfile Corp. – August 14, 2025) – Hemisphere Energy Corporation (TSXV: HME) (OTCQX: HMENF) (“Hemisphere” or the “Company”) provides its financial and operating results for the second quarter ended June 30, 2025, declares a quarterly dividend payment to shareholders, and provides operations update.
Q2 2025 Highlights
Attained quarterly production of 3,826 boe/d (99% heavy oil).
Generated $24.4 million, or $70.06/boe, in revenue.
Achieved total operating and transportation costs of $14.18/boe.
Delivered an operating field netback1 of $14.9 million, or $42.77/boe.
Realized quarterly adjusted funds flow from operations (“AFF”)1 of $10.3 million, or $29.47/boe.
Executed a $2.2 million capital expenditure1 program, including preparatory spending for Hemisphere’s upcoming drilling program.
Generated free funds flow1 of $8.1 million, or $0.07/share.
Distributed $2.4 million, or $0.025/share, in base dividends to shareholders during the quarter.
Distributed $2.9 million, or $0.03/share, in special dividends to shareholders during the quarter.
Purchased and cancelled 1.3 million shares for $2.3 million under the Company’s Normal Course Issuer Bid (“NCIB”).
Renewed the Company’s $35 million two-year extendible credit facility.
Exited the first quarter with positive working capital1 of $13.9 million.
(1) Operating field netback, adjusted funds flow from operations (AFF), free funds flow, capital expenditure, and working capital are non-IFRS measures, or when expressed on a per share or boe basis, non-IFRS ratio, that do not have any standardized meaning under IFRS and therefore may not be comparable to similar measures presented by other entities. Non-IFRS financial measures and ratios are not standardized financial measures under IFRS and may not be comparable to similar financial measures disclosed by other issuers. Refer to the section “Non-IFRS and Other Specified Financial Measures”.
Selected financial and operational highlights should be read in conjunction with Hemisphere’s unaudited condensed interim consolidated financial statements and related notes, and the Management’s Discussion and Analysis for the three months ended June 30, 2025 which are available on SEDAR+ at www.sedarplus.ca and on Hemisphere’s website at www.hemisphereenergy.ca. All amounts are expressed in Canadian dollars unless otherwise noted.
Quarterly Dividend
Hemisphere is pleased to announce that its Board of Directors has approved a quarterly base cash dividend of $0.025 per common share in accordance with the Company’s dividend policy. The dividend will be paid on September 12, 2025 to shareholders of record as of the close of business on August 29, 2025. The dividend is designated as an eligible dividend for income tax purposes.
Operations Update
With significant volatility in the economy and oil markets earlier this year, Hemisphere elected to defer the majority of its capital spending into the latter third of the year. With relatively flat base production, the Company has focused on balance sheet strength and shareholder returns through its share buyback program, base quarterly dividends, and the announcements of two special dividends year-to-date.
The Company’s drilling program is now scheduled to commence late in the third quarter. It will include several development wells in Atlee Buffalo in addition to at least one new well in Marsden, which will test a second oil-bearing zone on Hemisphere’s lands adjacent to its oil treating facilities and active polymer pilot project.
Management will continue to closely monitor oil market volatility and adjust capital spending accordingly. With almost $14 million in working capital, an undrawn credit line, and stable cash flow from its production base, Hemisphere is in a unique position to act on potential acquisition opportunities and continued shareholder returns in addition to executing its drilling program.
EnerCom Denver Conference
Ms. Ashley Ramsden-Wood, Chief Development Officer of Hemisphere, will be presenting at the EnerCom Denver Conference on Tuesday, August 19 at 2:45 pm Mountain Daylight Time (1:45 pm Pacific Daylight Time). The presentation will be livestreamed on EnerCom’s website at www.enercomdenver.com/webcast (Confluence C) and archived on Hemisphere’s website at www.hemisphereenergy.ca.
About Hemisphere Energy Corporation
Hemisphere is a dividend-paying Canadian oil company focused on maximizing value-per-share growth with the sustainable development of its high netback, ultra-low decline conventional heavy oil assets through polymer flood enhanced oil recovery methods. Hemisphere trades on the TSX Venture Exchange as a Tier 1 issuer under the symbol “HME” and on the OTCQX Venture Marketplace under the symbol “HMENF”.
For further information, please visit the Company’s website at www.hemisphereenergy.ca to view its corporate presentation or contact:
Don Simmons, President & Chief Executive Officer Telephone: (604) 685-9255 Email: info@hemisphereenergy.ca
Certain statements included in this news release constitute forward-looking statements or forward-looking information (collectively, “forward-looking statements”) within the meaning of applicable securities legislation. Forward-looking statements are typically identified by words such as “anticipate”, “continue”, “estimate”, “expect”, “forecast”, “may”, “will”, “project”, “could”, “plan”, “intend”, “should”, “believe”, “outlook”, “potential”, “target” and similar words suggesting future events or future performance. In particular, but without limiting the generality of the foregoing, this news release includes forward-looking statements including that Hemisphere’s drilling program is now scheduled to commence late in the third quarter and will include several development wells in Atlee Buffalo in addition to at least one new well in Marsden, which will test a second oil-bearing zone on Hemisphere’s lands; that Hemisphere may adjust capital spending depending on oil market volatility; that Hemisphere is in a unique position to act on potential acquisition opportunities and continued shareholder returns; and that a dividend will be paid September 12, 2025 to shareholders of record as of the close of business on August 29, 2025.
Forward‐looking statements are based on a number of material factors, expectations or assumptions of Hemisphere which have been used to develop such statements and information but which may prove to be incorrect. Although Hemisphere believes that the expectations reflected in such forward‐looking statements or information are reasonable, undue reliance should not be placed on forward‐looking statements because Hemisphere can give no assurance that such expectations will prove to be correct. In addition to other factors and assumptions which may be identified herein, assumptions have been made regarding, among other things: the current and go-forward oil price environment; that Hemisphere will continue to conduct its operations in a manner consistent with past operations; that results from drilling and development activities are consistent with past operations; the quality of the reservoirs in which Hemisphere operates and continued performance from existing wells; the continued and timely development of infrastructure in areas of new production; the accuracy of the estimates of Hemisphere’s reserve volumes; certain commodity price and other cost assumptions; continued availability of debt and equity financing and cash flow to fund Hemisphere’s current and future plans and expenditures; the impact of increasing competition; the general stability of the economic and political environment in which Hemisphere operates; the general continuance of current industry conditions; the timely receipt of any required regulatory approvals; the ability of Hemisphere to obtain qualified staff, equipment and services in a timely and cost efficient manner; drilling results; the ability of the operator of the projects in which Hemisphere has an interest in to operate the field in a safe, efficient and effective manner; the ability of Hemisphere to obtain financing on acceptable terms; field production rates and decline rates; the ability to replace and expand oil and natural gas reserves through acquisition, development and exploration; the timing and cost of pipeline, storage and facility construction and expansion and the ability of Hemisphere to secure adequate product transportation; future commodity prices; currency, exchange and interest rates; regulatory framework regarding royalties, taxes and environmental matters in the jurisdictions in which Hemisphere operates; and the ability of Hemisphere to successfully market its oil and natural gas products.
The forward‐looking statements included in this news release are not guarantees of future performance and should not be unduly relied upon. Such information and statements, including the assumptions made in respect thereof, involve known and unknown risks, uncertainties and other factors that may cause actual results or events to defer materially from those anticipated in such forward‐looking statements including, without limitation: changes in commodity prices; changes in the demand for or supply of Hemisphere’s products, the early stage of development of some of the evaluated areas and zones; unanticipated operating results or production declines; changes in tax or environmental laws, royalty rates or other regulatory matters; changes in development plans of Hemisphere or by third party operators of Hemisphere’s properties, increased debt levels or debt service requirements; inaccurate estimation of Hemisphere’s oil and gas reserve volumes; limited, unfavourable or a lack of access to capital markets; increased costs; a lack of adequate insurance coverage; the impact of competitors; and certain other risks detailed from time‐to‐time in Hemisphere’s public disclosure documents, (including, without limitation, those risks identified in this news release and in Hemisphere’s Annual Information Form).
The forward‐looking statements contained in this news release speak only as of the date of this news release, and Hemisphere does not assume any obligation to publicly update or revise any of the included forward‐looking statements, whether as a result of new information, future events or otherwise, except as may be required by applicable securities laws.
CALGARY, AB, Aug. 7, 2025 /CNW/ – InPlay Oil Corp. (TSX: IPO) (OTCQX: IPOOF) (“InPlay” or the “Company“) announces that Delek Group Ltd. (“Delek“) has closed the previously announced acquisition of all 9,139,784 common shares in the capital of InPlay previously held by Obsidian Energy Ltd. (“Obsidian“) (the “Transaction“). Further details regarding the Transaction can be found in InPlay’s press release dated August 4, 2025.
In connection with closing of the Transaction, InPlay has appointed Ehud (Udi) Erez and Tamir Polikar to the Board of Directors of InPlay (the “Board“). Mr. Erez has served as the Chairman of the board of Delek since 2020 and has over 30 years of experience in the energy and real estate sectors. Mr. Polikar has served as the Chief Financial Officer of Delek since 2020 and has over 30 years of experience in the energy and real estate sectors.
InPlay also announces that with in connection with closing of the Transaction, Stephen Loukas and Peter Scott have stepped down from the Board. InPlay management and Board would like to thank Mr. Loukas and Mr. Scott for their contribution to InPlay’s Board and wish them, and Obsidian, continued success.
About InPlay Oil Corp.
InPlay Oil Corp. is a growth-oriented, sustainable oil and gas producer focused on long-term value creation for its shareholders. The Company’s operations are centered in the Western Canadian Sedimentary Basin, where InPlay holds a diverse portfolio of oil and natural gas assets. InPlay is committed to delivering strong per-share growth, maintaining a disciplined approach to capital investment, and providing consistent returns to shareholders.
About Delek Group
Delek is an independent E&P and the pioneering visionary behind the development of the East Med. With major finds in the Levant Basin, including Leviathan (21.4 TCF) and Tamar (11.2 TCF no longer owned by Delek) and others, Delek is leading the region’s development into a major natural gas export hub. In addition, Delek has significant presence s in the North Sea, with its subsidiary, Ithaca Energy (LSE: ITH). Delek is one of Israel’s largest and most prominent companies with a consistent track record of growth. Its shares are traded on the Tel Aviv Stock Exchange (TASE: DLEKG) and are part of the TA 35 Index.
SOURCE InPlay Oil Corp.
For further information please contact: Doug Bartole, President and Chief Executive Officer, InPlay Oil Corp., Telephone: (587) 955-0632; Kevin Leonard, Vice President, Business & Corporate Development, InPlay Oil Corp., Telephone: (587) 893-6804
CALGARY, AB, Aug. 3, 2025 /CNW/ – InPlay Oil Corp. (TSX: IPO) (OTCQX: IPOOF) (“InPlay” or the “Company“) announces that Obsidian Energy Ltd. (“Obsidian“) has entered into a definitive agreement with Delek Group Ltd. (“Delek“) in respect of the sale of all 9,139,784 common shares (“Common Shares“) in the capital of InPlay currently held by Obsidian (the “Transaction“).
“We are thrilled to welcome the Delek Group to our organization as part of their impressive oil and gas portfolio,” said Doug Bartole, President and CEO of InPlay Oil Corp. “Delek holds a 45% working interest in the largest natural gas field in the Mediterranean, with an estimated 23 TCF of recoverable natural gas. They have also played a key role in the growth of Ithaca Energy plc, where they hold a 52% equity stake, increasing production from 30,000 boe/d to over 120,000 boe/d since their initial investment. We look forward to partnering with Delek to continue building InPlay into a long-term, sustainable, growth-oriented Canadian oil and gas producer, with a strong focus on per-share growth and consistent returns to shareholders.”
“Delek is excited to partner with InPlay as our investment in the Canadian energy sector,” said Ehud (Udi) Erez, Chairman of the Board of the Delek Group. “We identified Canada as a strong and stable jurisdiction for our oil and gas investment, and InPlay stood out with its dynamic team and deep expertise in the Canadian market. InPlay has built a formidable track record through strong operational performance and strategic, accretive acquisitions. We look forward to seeing InPlay’s continued growth and continued success.”
The Transaction is expected to occur in the first half of August 2025 and remains subject to customary conditions to closing.
In connection with the Transaction, InPlay has entered into a registration rights agreement with Delek (the “Registration Rights Agreement“) and an investor rights agreement (the “Investor Rights Agreement“) substantially in the forms entered into between InPlay and Obsidian. The Registration Rights Agreement and Investor Rights Agreement are conditional upon closing of the Transaction.
The Investor Rights Agreement provides that, conditional upon closing of the Transaction, InPlay will appoint two nominees of Delek to the Board of Directors of InPlay (the “Board“) immediately following closing of the Transaction. For so long as Delek holds 20% or more of the issued and outstanding Common Shares and the Board is comprised of eight (8) members, Delek will be entitled to maintain two (2) board nominees. Delek has agreed that, subject to certain conditions, in respect of the election of directors and the appointment of the auditor’s at InPlay’s annual general meeting to be held in 2026 and the appointment of the auditor’s at InPlay’s annual general meeting to be held in 2027, Delek will vote (or, at Delek’s discretion, abstain or cause to be abstained from voting) all Common Shares held by it in accordance with the recommendations of the Board or management of InPlay. Additionally, the Investor Rights Agreement provides Delek with certain pre-emptive and participation rights with respect to certain equity offerings undertaken by InPlay.
The Registration Rights Agreement and the Investor Rights Agreement will be filed on InPlay’s SEDAR+ profile at www.sedarplus.com in due course.
About InPlay Oil Corp.
InPlay is a growth-oriented, sustainable oil and gas producer focused on long-term value creation for its shareholders. The Company’s operations are centered in the Western Canadian Sedimentary Basin, where InPlay holds a diverse portfolio of oil and natural gas assets. InPlay is committed to delivering strong per-share growth, maintaining a disciplined approach to capital investment, and providing consistent returns to shareholders.
About Delek Group
Delek is an independent E&P and the pioneering visionary behind the development of the East Med. With major finds in the Levant Basin, including Leviathan (21.4 TCF) and Tamar (11.2 TCF no longer owned by Delek) and others, Delek is leading the region’s development into a major natural gas export hub. In addition, Delek has invested in the North Sea, with its subsidiary, Ithaca Energy. Delek is one of Israel’s largest and most prominent companies with a consistent track record of growth. Its shares are traded on the Tel Aviv Stock Exchange (TASE:DLEKG) and are part of the TA 35 Index.
SOURCE InPlay Oil Corp.
For further information please contact: Doug Bartole, President and Chief Executive Officer, InPlay Oil Corp., Telephone: (587) 955-0632; Kevin Leonard, Vice President, Business & Corporate Development, InPlay Oil Corp., Telephone: (587) 893-6804
InPlay Oil 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.
Mark Reichman, Managing Director, Equity Research Analyst, Natural Resources, Noble Capital Markets, Inc.
Hans Baldau, Associate Analyst, Noble Capital Markets, Inc.
Refer to the full report for the price target, fundamental analysis, and rating.
Company strategy. Despite the recent improvement in oil prices, InPlay is maintaining its 2025 production guidance at 16,000 to 16,800 boe/d. Management reiterated that the strategy remains centered on capital discipline, prioritizing debt reduction over production growth. The company’s approach is supported by fluctuating oil prices and the performance of assets acquired from Obsidian Energy, which have demonstrated low decline rates and continue to well-exceed type curve expectations. Recall that as part of the transaction, Obsidian Energy received InPlay shares as part of the consideration.
Non-binding offer. InPlay Oil announced that Obsidian Energy has entered into a non-binding agreement with a third party for the sale of its entire position in InPlay, totaling 9,139,784 common shares. The proposed transaction is expected to occur at a premium to InPlay’s share price as of July 15, 2025. While the parties remain in discussions, no binding agreement has been finalized at this time.
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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.
Oil prices held relatively steady on Wednesday, July 16, as competing forces in the global energy market kept prices from making strong moves in either direction. West Texas Intermediate (WTI) crude hovered near $66 per barrel after an earlier dip in the session.
The market saw downward pressure from an unexpected rise in crude inventories at Cushing, Oklahoma, a key storage and pricing hub. At the same time, distillate fuel demand, which includes diesel, showed signs of softening. These developments signaled a possible easing of near-term consumption, raising concerns about oversupply.
Despite those pressures, oil has shown strength over the past several weeks. Seasonal demand, particularly during summer months when travel activity peaks, has provided a degree of support. At the same time, the broader financial markets saw a boost after political tensions appeared to ease in Washington, improving investor sentiment across risk assets.
Globally, oil supply continues to rise as major producers ramp up output. The OPEC+ group has been reintroducing volumes that were previously held back, while production across North and South America has also grown. This increase in supply has raised the potential for a looser market in the months ahead, especially if demand growth slows.
Even so, signs of tightness remain in the short term. U.S. crude inventories fell by nearly 4 million barrels in the most recent report, and distillate stockpiles remain at their lowest seasonal level in decades. These conditions suggest that supply constraints are still present in certain segments of the market.
The structure of oil futures continues to indicate firm short-term demand. The price for immediate delivery remains higher than later-dated contracts, a pattern known as backwardation. This typically reflects a market that is undersupplied in the near term, even if concerns about oversupply persist further out.
Globally, oil stockpiles have been increasing in some regions, though the build-up has been concentrated in markets that do not heavily influence futures prices. This uneven distribution of supply has helped keep benchmark prices relatively supported, especially in Atlantic-based markets where Brent crude is priced.
As the oil market navigates seasonal trends, evolving supply dynamics, and shifts in global demand, prices are likely to remain rangebound in the near term. While inventory changes and geopolitical developments can trigger short-term fluctuations, the overall outlook continues to be shaped by a complex balance of economic and physical market factors.
