NewzIntel.com

Category: Energy

  • MIL-OSI: Valeura Energy Inc.: 2024 Sustainability Report Released

    Source: GlobeNewswire (MIL-OSI)

    SINGAPORE, July 31, 2025 (GLOBE NEWSWIRE) — Valeura Energy Inc. (TSX:VLE, OTCQX:VLERF) (“Valeura” or the “Company”) announces the release of its 2024 Sustainability Report. 

    Dr. Sean Guest, President and CEO commented:

    “Our 2024 Sustainability Report underscores our commitment to transparency in everything we do.  We are proud of our performance on the important dimensions of environmental stewardship, social responsibility, and governance.  This includes having reduced our greenhouse gas emissions intensity by 20% in 2024, our first full year of operations in Thailand.  Our 2024 Sustainability Report elaborates on this achievement and demonstrates our progress across a wide array of sustainability-related metrics, as measured against the baseline data we presented in our inaugural sustainability report, last year.”

    Valeura’s 2024 Sustainability Report was approved by the Company’s Board of Directors, and has been made available on the Valeura website, under the Sustainability section.  The Company has also published a report on its compliance with the Fighting Against Forced Labour and Child Labour in Supply Chains Act (commonly referred to as Canada’s Modern Slavery Act) and has uploaded its latest annual report in accordance with Canada’s Extractive Sector Transparency Measures Act. 

    For further information, please contact:

    Valeura Energy Inc. (General Corporate Enquiries)
    Sean Guest, President and CEO
    Yacine Ben-Meriem, CFO
    Contact@valeuraenergy.com    		 +65 6373 6940
       
    Valeura Energy Inc. (Investor and Media Enquiries)
    Robin James Martin, Vice President, Communications and Investor Relations
    IR@valeuraenergy.com    		 +1 403 975 6752 / +44 7392 940495
       

    Contact details for the Company’s advisors, covering research analysts and joint brokers, including Auctus Advisors LLP, Canaccord Genuity Ltd (UK), Cormark Securities Inc., Research Capital Corporation, and Stifel Nicolaus Europe Limited, are listed on the Company’s website at www.valeuraenergy.com/investor-information/analysts/.

    About the Company

    Valeura Energy Inc. is a Canadian public company engaged in the exploration, development and production of petroleum and natural gas in Thailand and in Türkiye. The Company is pursuing a growth-oriented strategy and intends to re-invest into its producing asset portfolio and to deploy resources toward further organic and inorganic growth in Southeast Asia. Valeura aspires toward value accretive growth for stakeholders while adhering to high standards of environmental, social and governance responsibility.

    Additional information relating to Valeura is also available on SEDAR+ at www.sedarplus.ca.

    This news release does not constitute an offer to sell or the solicitation of an offer to buy securities in any jurisdiction, including where such offer would be unlawful. This news release is not for distribution or release, directly or indirectly, in or into the United States, Ireland, the Republic of South Africa or Japan or any other jurisdiction in which its publication or distribution would be unlawful.

    Neither the Toronto Stock Exchange nor its Regulation Services Provider (as that term is defined in the policies of the Toronto Stock Exchange) accepts responsibility for the adequacy or accuracy of this news release.

    This information is provided by Reach, the non-regulatory press release distribution service of RNS, part of the London Stock Exchange. Terms and conditions relating to the use and distribution of this information may apply. For further information, please contact rns@lseg.com or visit www.rns.com.

    The MIL Network –

  • MIL-OSI: Shell plc publishes second quarter 2025 press release

    Source: GlobeNewswire (MIL-OSI)

    London, July 31, 2025

    “Shell generated robust cash flows reflecting strong operational performance in a less favourable macro environment​. We continued to deliver on our strategy by enhancing our deep-water portfolio in Nigeria and Brazil, and achieved a key milestone by shipping the first cargo from LNG Canada.

    Our continued focus on performance, discipline and simplification helped deliver $3.9 billion of structural cost reductions since 2022, with the majority delivered through non-portfolio actions. This focus enables us to commence another $3.5 billion of buybacks for the next three months, the 15th consecutive quarter of at least $3 billion in buybacks.”

    Shell plc Chief Executive Officer, Wael Sawan

    ROBUST CASH GENERATION; STRONG OPERATIONAL PERFORMANCE

    • Adjusted Earnings1 of $4.3 billion despite lower trading contribution in a weaker margin environment.
    • Robust CFFO of $11.9 billion, supported by strong operational performance, enables commencement of another $3.5 billion share buyback programme for the next three months.
    • Strong balance sheet, with gearing of 19%. 2025 cash capex outlook unchanged at $20 – 22 billion. Total shareholder distributions paid over the last 4 quarters were 46% of CFFO.
    • Achieved $0.8 billion of structural cost reductions in the first half of 2025, of which $0.5 billion is through non-portfolio actions; cumulative reductions since 2022 are $3.9 billion, against CMD25 target of $5 – 7 billion by end of 2028.
    • First cargo shipped from LNG Canada, strengthening our leading LNG position and supporting our ambition to achieve LNG sales cumulative annual growth rate of 4 – 5% to 2030.
    • Further enhanced peer-leading deep-water position with start-up of Mero-4 (Brazil) and announced increase of interests in Gato do Mato (Brazil) and Bonga (Nigeria); continued to high-grade Downstream and R&ES portfolio.
    $ million1 Adj. Earnings Adj. EBITDA CFFO Cash capex
    Integrated Gas 1,737 3,875 3,629 1,196
    Upstream 1,732 6,638 6,500 2,826
    Marketing 1,199 2,181 2,718 429
    Chemicals & Products2 118 864 1,372 775
    Renewables & Energy Solutions (R&ES) (9) 102 1 555
    Corporate (463) (346) (2,283) 36
    Less: Non-controlling interest (NCI) 50      
    Shell Q2 2025 4,264 13,313 11,937 5,817
    Q1 2025 5,577 15,250 9,281 4,175

    1Income/(loss) attributable to shareholders for Q2 2025 is $3.6 billion. Reconciliation of non-GAAP measures can be found in the unaudited results, available at www.shell.com/investors.
    2Chemicals & Products Adjusted Earnings at a subsegment level are as follows – Chemicals $(0.2) billion and Products $0.3 billion.

    • CFFO excluding working capital of $12.3 billion is helped by derivative inflows and JV dividends received.
    • Working capital outflow of $0.4 billion reflects a reduction in JV deposits. $1.7 billion of the JV dividends received were previously held in deposit in the Corporate segment.
    • Net debt excluding leases is $14.3 billion.
    $ billion1 Q2 2024 Q3 2024 Q4 2024 Q1 2025 Q2 2025
    Working capital (0.3) 2.7 2.4 (2.7) (0.4)
    Divestment proceeds 0.8 0.2 0.8 0.6 (0.0)
    Free cash flow 10.2 10.8 8.7 5.3 6.5
    Net debt 38.3 35.2 38.8 41.5 43.2

    1Reconciliation of non-GAAP measures can be found in the unaudited results, available at www.shell.com/investors.

    Q2 2025 FINANCIAL PERFORMANCE DRIVERS

    INTEGRATED GAS

    Key data Q1 2025 Q2 2025 Q3 2025 outlook
    Realised liquids price ($/bbl) 64 60 —
    Realised gas price ($/thousand scf) 7.4 7.2 —
    Production (kboe/d) 927 913 910 – 970
    LNG liquefaction volumes (MT) 6.6 6.7 6.7 – 7.3
    LNG sales volumes (MT) 16.5 17.8 —
    • Adjusted Earnings were lower than in Q1 2025, reflecting lower prices and significantly lower trading and optimisation results.

    UPSTREAM

    Key data Q1 2025 Q2 2025 Q3 2025 outlook
    Realised liquids price ($/bbl) 71 64 —
    Realised gas price ($/thousand scf) 7.4 6.9 —
    Liquids production (kboe/d) 1,335 1,334 —
    Gas production (million scf/d) 3,020 2,310 —
    Total production (kboe/d) 1,855 1,732 1,700 – 1,900
    • Adjusted Earnings were lower than in Q1 2025, reflecting lower prices.

    MARKETING

    Key data Q1 2025 Q2 2025 Q3 2025 outlook
    Marketing sales volumes (kb/d) 2,674 2,813 2,600 – 3,100
    Mobility (kb/d) 1,964 2,044 —
    Lubricants (kb/d) 87 85 —
    Sectors & Decarbonisation (kb/d) 623 684 —
    • Adjusted Earnings were higher than in Q1 2025, driven mainly by improved Mobility unit margins and seasonally higher volumes.

    CHEMICALS & PRODUCTS

    Key data Q1 2025 Q2 2025 Q3 2025 outlook
    Refinery processing intake (kb/d) 1,362 1,156 —
    Chemicals sales volumes (kT) 2,813 2,164 —
    Refinery utilisation (%) 85 94 88 – 96
    Chemicals manufacturing plant utilisation (%) 81 72 78 – 86
    Indicative refining margin (Updated1 $/bbl) 6.2 8.9 —
    Indicative chemical margin (Updated1 $/t) 126 166 —

    1Q2 2025 indicative margins reflect the divestment of Singapore Energy and Chemicals (E&C) Park.
    Q2 2025 indicative margins if including Singapore E&C Park would have been: Refining – 7.5$/bbl, Chemicals – 143$/t.

    • Adjusted Earnings were lower than in Q1 2025 with significantly lower trading and optimisation results, reflecting a disconnect between market volatility and supply-demand fundamentals. Chemicals results were impacted by unplanned downtime and a continued weak margin environment.

    RENEWABLES & ENERGY SOLUTIONS

    Key data Q1 2025 Q2 2025
    External power sales (TWh) 76 70
    Sales of pipeline gas to end-use customers (TWh) 184 132
    Renewables power generation capacity (GW)* 7.5 7.6
    • in operation (GW)
    		 3.5 3.9
    • under construction and/or committed for sale (GW)
    		 4.0 3.8

    *Excludes Shell’s equity share of associates where information cannot be obtained.

    • Adjusted Earnings were in line with Q1 2025 with seasonally lower trading and marketing margins, offset by lower opex.

    Renewables and Energy Solutions includes activities such as renewable power generation, the marketing and trading and optimisation of power and pipeline gas, as well as carbon credits, and digitally enabled customer solutions. It also includes the production and marketing of hydrogen, development of commercial carbon capture and storage hubs, investment in nature-based projects that avoid or reduce carbon emissions, and Shell Ventures, which invests in companies that work to accelerate the energy and mobility transformation.

    CORPORATE

    Key data Q1 2025 Q2 2025 Q3 2025 outlook
    Adjusted Earnings ($ billion) (0.5) (0.5) (0.7) – (0.5)

    UPCOMING INVESTOR EVENTS

    October 30, 2025 Third quarter 2025 results and dividends

    USEFUL LINKS

    Results materials Q2 2025
    Quarterly Databook Q2 2025
    Webcast registration Q2 2025
    Dividend announcement Q2 2025
    Capital Markets Day 2025 materials

    ALTERNATIVE PERFORMANCE (NON-GAAP) MEASURES

    This announcement includes certain measures that are calculated and presented on the basis of methodologies other than in accordance with generally accepted accounting principles (GAAP) such as IFRS, including Adjusted Earnings, Adjusted EBITDA, CFFO excluding working capital movements, free cash flow, Divestment proceeds and Net debt. This information, along with comparable GAAP measures, is useful to investors because it provides a basis for measuring Shell plc’s operating performance and ability to retire debt and invest in new business opportunities. Shell plc’s management uses these financial measures, along with the most directly comparable GAAP financial measures, in evaluating the business performance.

    This announcement may contain certain forward-looking non-GAAP measures such as Adjusted Earnings and divestments. We are unable to provide a reconciliation of these forward-looking non-GAAP measures to the most comparable GAAP financial measures because certain information needed to reconcile the non-GAAP measures to the most comparable GAAP financial measures is dependent on future events some of which are outside the control of the company, such as oil and gas prices, interest rates and exchange rates. Moreover, estimating such GAAP measures with the required precision necessary to provide a meaningful reconciliation is extremely difficult and could not be accomplished without unreasonable effort. Non-GAAP measures in respect of future periods which cannot be reconciled to the most comparable GAAP financial measure are estimated in a manner which is consistent with the accounting policies applied in Shell plc’s consolidated financial statements.

    CAUTIONARY STATEMENT

    The companies in which Shell plc directly and indirectly owns investments are separate legal entities. In this announcement, “Shell”, “Shell Group” and “Group” are sometimes used for convenience to reference Shell plc and its subsidiaries in general. Likewise, the words “we”, “us” and “our” are also used to refer to Shell plc and its subsidiaries in general or to those who work for them. These terms are also used where no useful purpose is served by identifying the particular entity or entities. “Subsidiaries”, “Shell subsidiaries” and “Shell companies” as used in this announcement refer to entities over which Shell plc either directly or indirectly has control. The terms “joint venture”, “joint operations”, “joint arrangements”, and “associates” may also be used to refer to a commercial arrangement in which Shell has a direct or indirect ownership interest with one or more parties. The term “Shell interest” is used for convenience to indicate the direct and/or indirect ownership interest held by Shell in an entity or unincorporated joint arrangement, after exclusion of all third-party interest.

    This announcement contains forward-looking statements (within the meaning of the U.S. Private Securities Litigation Reform Act of 1995) concerning the financial condition, results of operations and businesses of Shell. All statements other than statements of historical fact are, or may be deemed to be, forward-looking statements. Forward-looking statements are statements of future expectations that are based on management’s current expectations and assumptions and involve known and unknown risks and uncertainties that could cause actual results, performance or events to differ materially from those expressed or implied in these statements. Forward-looking statements include, among other things, statements concerning the potential exposure of Shell to market risks and statements expressing management’s expectations, beliefs, estimates, forecasts, projections and assumptions. These forward-looking statements are identified by their use of terms and phrases such as “aim”; “ambition”; “anticipate”; “aspire”; “aspiration”; ‘‘believe’’; “commit”; “commitment”; ‘‘could’’; “desire”; ‘‘estimate’’; ‘‘expect’’; ‘‘goals’’; ‘‘intend’’; ‘‘may’’; “milestones”; ‘‘objectives’’; ‘‘outlook’’; ‘‘plan’’; ‘‘probably’’; ‘‘project’’; ‘‘risks’’; “schedule”; ‘‘seek’’; ‘‘should’’; ‘‘target’’; “vision”; ‘‘will’’; “would” and similar terms and phrases. There are a number of factors that could affect the future operations of Shell and could cause those results to differ materially from those expressed in the forward-looking statements included in this announcement, including (without limitation): (a) price fluctuations in crude oil and natural gas; (b) changes in demand for Shell’s products; (c) currency fluctuations; (d) drilling and production results; (e) reserves estimates; (f) loss of market share and industry competition; (g) environmental and physical risks, including climate change; (h) risks associated with the identification of suitable potential acquisition properties and targets, and successful negotiation and completion of such transactions; (i) the risk of doing business in developing countries and countries subject to international sanctions; (j) legislative, judicial, fiscal and regulatory developments including tariffs and regulatory measures addressing climate change; (k) economic and financial market conditions in various countries and regions; (l) political risks, including the risks of expropriation and renegotiation of the terms of contracts with governmental entities, delays or advancements in the approval of projects and delays in the reimbursement for shared costs; (m) risks associated with the impact of pandemics, regional conflicts, such as the Russia-Ukraine war and the conflict in the Middle East, and a significant cyber security, data privacy or IT incident; (n) the pace of the energy transition; and (o) changes in trading conditions. No assurance is provided that future dividend payments will match or exceed previous dividend payments. All forward-looking statements contained in this announcement are expressly qualified in their entirety by the cautionary statements contained or referred to in this section. Readers should not place undue reliance on forward-looking statements. Additional risk factors that may affect future results are contained in Shell plc’s Form 20-F and amendment thereto for the year ended December 31, 2024 (available at www.shell.com/investors/news-and-filings/sec-filings.html and www.sec.gov). These risk factors also expressly qualify all forward-looking statements contained in this announcement and should be considered by the reader. Each forward-looking statement speaks only as of the date of this announcement, July 31, 2025. Neither Shell plc nor any of its subsidiaries undertake any obligation to publicly update or revise any forward-looking statement as a result of new information, future events or other information. In light of these risks, results could differ materially from those stated, implied or inferred from the forward-looking statements contained in this announcement.

    All amounts shown throughout this announcement are unaudited. The numbers presented throughout this announcement may not sum precisely to the totals provided and percentages may not precisely reflect the absolute figures, due to rounding.

    Shell’s Net Carbon Intensity

    Also, in this  announcement, we may refer to Shell’s “net carbon intensity” (NCI), which includes Shell’s carbon emissions from the production of our energy products, our suppliers’ carbon emissions in supplying energy for that production and our customers’ carbon emissions associated with their use of the energy products we sell. Shell’s NCI also includes the emissions associated with the production and use of energy products produced by others which Shell purchases for resale. Shell only controls its own emissions. The use of the terms Shell’s “net carbon intensity” or NCI is for convenience only and not intended to suggest these emissions are those of Shell plc or its subsidiaries.

    Shell’s Net-Zero Emissions Target

    Shell’s operating plan and outlook are forecasted for a three-year period and ten-year period, respectively, and are updated every year. They reflect the current economic environment and what we can reasonably expect to see over the next three and ten years. Accordingly, the outlook reflects our Scope 1, Scope 2 and NCI targets over the next ten years. However, Shell’s operating plan and outlook cannot reflect our 2050 net-zero emissions target, as this target is outside our planning period. Such future operating plans and outlooks could include changes to our portfolio, efficiency improvements and the use of carbon capture and storage and carbon credits. In the future, as society moves towards net-zero emissions, we expect Shell’s operating plans and outlooks to reflect this movement. However, if society is not net zero in 2050, as of today, there would be significant risk that Shell may not meet this target.

    The content of websites referred to in this announcement does not form part of this announcement.

    We may have used certain terms, such as resources, in this announcement that the United States Securities and Exchange Commission (SEC) strictly prohibits us from including in our filings with the SEC. Investors are urged to consider closely the disclosure in our Form 20-F and any amendment thereto, File No 1-32575, available on the SEC website www.sec.gov.

    The financial information presented in this announcement does not constitute statutory accounts within the meaning of section 434(3) of the Companies Act 2006 (the “Act”). Statutory accounts for the year ended December 31, 2024 were published in Shell’s Annual Report and Accounts, a copy of which was delivered to the Registrar of Companies for England and Wales. The auditor’s report on those accounts was unqualified, did not include a reference to any matters to which the auditor drew attention by way of emphasis without qualifying the report and did not contain a statement under sections 498(2) or 498(3) of the Act.

    The information in this announcement does not constitute the unaudited condensed consolidated financial statements which are contained in Shell’s second quarter 2025 unaudited results available on www.shell.com/investors.

    CONTACTS

    • Media: International +44 207 934 5550; U.S. and Canada: Contact form

    The MIL Network –

  • MIL-OSI Europe: The Government’s participation in UN Climate Change Conference COP28

    Source: Government of Sweden

    From 30 November to 12 December, the world is gathering in Dubai for the UN Climate Change Conference (COP28). The Swedish Government is being be represented there by Prime Minister Ulf Kristersson, Minister for Energy, Business and Industry Ebba Busch, Minister for Climate and the Environment Romina Pourmokhtari and Minister for International Development Cooperation and Foreign Trade Johan Forssell.

    MIL OSI Europe News –

  • MIL-OSI Africa: Petrofund Launches Flagship Scholarship to Empower Namibian Youth in Oil and Gas

    Source: APO

    Namibia’s Petroleum Training and Education Fund (Petrofund) officially launched its flagship scholarship program during the 2nd Youth in Oil and Gas Summit, reinforcing its commitment to building a highly skilled national workforce for the country’s burgeoning oil and gas sector. The new scholarship complements the Namibian government’s free tertiary education policy by fully funding undergraduate and postgraduate students in engineering, geosciences, paramedics and technical vocational training disciplines relevant to upstream oil and gas operations. Courses will be offered at accredited institutions across the Southern African Development Community region and internationally.

    As the voice of the African energy sector, the African Energy Chamber (AEC) commends Petrofund’s leadership and forward-thinking strategy to anchor Namibian youth at the core of the country’s growing energy economy. With major discoveries in the Orange Basin and increasing momentum towards first oil, initiatives like this are essential to ensure local capacity meets international operational standards.

    In addition to its flagship scholarship program, Petrofund has introduced several strategic initiatives to accelerate youth integration into Namibia’s oil and gas industry. Through its expanded on-the-job training program, more than 82 young professionals have been deployed across various technical roles in collaboration with premier service and operating companies including TechnipFMC, SBM, Subsea 7, Baker Hughes, Halliburton, SLB, BW Energy, Shell, ReconAfrica, TotalEnergies and QatarEnergy. Petrofund has also signed ten memoranda of understanding to deepen these partnerships and enhance practical industry exposure. Additionally, the government-led fund is developing a national oil and gas CV repository – set to launch in Q4 2025 – to bridge the gap between skilled graduates and industry demand.

    Petrofund is also strengthening its collaboration with Namibian institutions of higher learning. Partners include the Namibia University of Science and Technology and University of Namibia, along with regulatory authorities such as the Namibia Qualifications Authority; National Council for Higher Education; Namibia Training Authority; and Ministry of Education, Innovation, Youth, Sports, Art and Culture. This initiative aims to introduce and accredit more oil and gas-related programs locally, enhancing access to technical education aligned with global industry standards. To date, Petrofund has invested over N$115 million to support 438 Namibians in petroleum-related studies, achieving a 90% internship and employment placement rate for its Master’s level beneficiaries.

    As Namibia progresses towards final investment decisions for high-impact offshore projects led by operators such as TotalEnergies and Shell, this program ensure that Namibians are equipped with the technical expertise to actively participate and lead in-country value creation. Imminent first production means Petrofund’s holistic approach to human capital development can align with the country’s Local Content Policy and sets the foundation for long-term, inclusive growth. The AEC supports these efforts as a model for Africa’s youth empowerment in energy.

    “Petrofund is setting the standard for what youth empowerment in Africa’s energy sector should look like. By aligning skills development with industry demand and embracing inclusivity, Namibia is not just preparing its young people for jobs – it’s preparing them for leadership. The Chamber fully supports these efforts, which will ensure that Namibians are not just bystanders, but key drivers of their energy future,” states NJ Ayuk, Executive Chairman, AEC.

    Distributed by APO Group on behalf of African Energy Chamber.

    Media files

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    MIL OSI Africa –

  • MIL-OSI Africa: Op-Ed: Financing Energy Access in Africa: Leveraging Fossil Fuel Revenues to End Energy Poverty

    Source: APO

    NJ Ayuk, Executive Chairman of the African Energy Chamber
     

    In an emissions-focused world, do oil and gas revenues have a role to play in ending energy poverty in Africa? It may sound counterintuitive, but many would argue that they do, albeit as enablers of a future powered by alternative energy sources.  

    The key lies in recognizing that Africa’s situation is unique, and solutions take time, building on what we have and what we can do with it. This means that, in working towards a just energy transition, the continent’s oil and gas resources shouldn’t be viewed as obstacles that need to be immediately replaced by renewable energy sources. Instead, rather than prematurely phasing out fossil fuels in response to global pressure, Africa should harness these revenues responsibly to finance its energy transition and ultimately eradicate energy poverty. 

    Prioritizing Development Alongside Sustainability 

    Nearly 600 million Africans still live without access to electricity (https://apo-opa.co/3IV6Rd8). This access is a fundamental human right, yet energy poverty remains one of the continent’s most significant barriers to development. This undermines health systems, education, industrialization, and dignity. As the world debates how to rapidly achieve net-zero, Africa’s priority is different: how to power its people now, while building a sustainable future. 

    Measuring Africa’s energy transition progress against external calls for an abrupt end to fossil fuels risks leaving millions behind. Our continent contributes less than 4% (https://apo-opa.co/40Ilfvu) to global emissions, yet we are expected to decarbonize at the same pace as industrialized nations that built their wealth on hydrocarbons. 

    Instead, the continent’s abundance of fossil fuels should be viewed as a bridge, not a barrier. The African Energy Chamber (AEC) Africa-Paris Declaration (https://apo-opa.co/4l4JTO2) underscores this principle – Africa’s oil and gas revenues can and must be used as a financial lever to invest in electrification, clean energy, and infrastructure projects. This pragmatic and just approach prioritizes development alongside sustainability, not instead of.  

    There are several ways to achieve this. First, reinvesting oil and gas revenues into rural electrification can transform communities. Decentralized solutions like off-grid solar and mini-grids offer practical ways to reach remote areas. Although urban dwellers do experience power outages, for many rural populations, it’s a way of life. For the mother cooking with firewood or the student studying by candlelight, a small solar grid is life-changing. Fossil fuel revenues can finance these systems at scale, bridging the immediate access gap while longer-term grid expansions are in progress.  

    Second, establishing innovative financing mechanisms is essential. For instance, the fledgling Africa Energy Bank (https://apo-opa.co/4laFrh1) aims to bridge the continent’s estimated $31 billion to $50 billion annual energy funding gap by focusing predominantly on financing energy projects. Launched in 2025, the bank is poised to play a transformative role in mobilizing capital for African energy projects. Additionally, global investors are increasingly exploring energy investment opportunities in Africa. In support of this, development finance institutions, such as the African Development Bank, the World Bank, and the International Finance Corporation, are de-risking investments by offering concessional loans, guarantees, and technical assistance, making investment in African energy projects more attractive.  

    Third, policy reforms that create enabling environments are critical. Here, governments have a role to play in prioritizing revenue-generating projects, creating stable regulatory frameworks, and offering incentives for public-private partnerships. This will support investment, reduce risks, and unlock the transformative power of energy access. 

    These solutions demonstrate the importance of a fair and equitable transition and the vital role that fossil fuels will continue to play in achieving this goal. They also prove that this goal is achievable, even if it is on the continent’s own terms. 

    Unique Solutions to Africa’s Energy Challenges 

    Africa’s path to net-zero has the same end goal as the rest of the world, but it can’t mirror their journey. Our starting points are different, and our development needs are urgent. We understand that climate action can’t be delayed. But it can be just, inclusive, and rooted in African realities. And it can also be supported by revenues from our abundant natural resources.   

    The Africa-Paris Declaration notes that ‘a fair transition recognizes that fossil fuels remain valuable for Africa’s development, prosperity, and energy access goals. Africa doesn’t need to choose between oil and gas or renewables. Given our current position, all are important and require both strategic and sensible deployment. Fossil fuels generate the revenues to invest in solar, wind, hydropower, and grid infrastructure. They fuel industries that create jobs. They support healthcare, education, and innovation. 

    When managed responsibly, Africa’s fossil fuel revenue can serve as a bridge to a brighter, greener, and more prosperous continent. Will it be quick and easy? No. Will some question the approach? Most certainly. But the alternative is leaving hundreds of millions of people in the dark. 

    Distributed by APO Group on behalf of TotalEnergies.

    Media files

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    MIL OSI Africa –

  • MIL-OSI Russia: Alexander Novak made a working visit to the Kingdom of Saudi Arabia

    Translation. Region: Russian Federal

    Source: Government of the Russian Federation – Government of the Russian Federation –

    An important disclaimer is at the bottom of this article.

    Meeting of Alexander Novak with the co-chairman of the Joint Russian-Saudi Intergovernmental Commission on Trade, Economic, Scientific and Technical Cooperation, Minister of Energy of Saudi Arabia Prince Abdulaziz bin Salman Al Saud

    Deputy Prime Minister of the Russian Federation Alexander Novak made a working visit to the Kingdom of Saudi Arabia. He met with the co-chairman of the Joint Russian-Saudi Intergovernmental Commission on Trade, Economic, Scientific and Technical Cooperation, Minister of Energy of Saudi Arabia Prince Abdulaziz bin Salman Al Saud.

    The participants discussed cooperation within the Joint Russian-Saudi Intergovernmental Commission on Trade, Economic, Scientific and Technical Cooperation and the results of the implementation of the instructions of the co-chairs of the commission following the last meeting. The parties noted with satisfaction the recent opening of direct flights between the two countries, the signing of several memorandums of understanding in various areas, such as industry, education, media, as well as in terms of organizing the Hajj.

    During the talks, the parties discussed prospects for increasing trade turnover and expanding cooperation in key economic sectors of mutual interest. The parties also discussed preparations for the ninth meeting of the intergovernmental commission, which will be held in Riyadh on November 6 this year.

    Another topic of negotiations was the situation on the oil market and the prospects for cooperation between the two countries within OPEC.

    Please note: This information is raw content obtained directly from the source of the information. It is an accurate report of what the source claims and does not necessarily reflect the position of MIL-OSI or its clients.

    .

    MIL OSI Russia News –

  • MIL-OSI Europe: Joint statement by Canada and Sweden on sustained engagement on critical raw materials, battery value chains and emerging technologies

    Source: Government of Sweden

    The countries are working together to build economic resiliency and provide new market opportunities for Canadian and Swedish businesses. The Honourable François-Philippe Champagne, Minister of Innovation, Science and Industry, and Ebba Busch, Minister for Energy, Business and Industry and Deputy Prime Minister of Sweden made the following statement.

    MIL OSI Europe News –

  • MIL-OSI United Kingdom: New members appointed to OPSS Advisory Board

    Source: United Kingdom – Executive Government & Departments

    News story

    New members appointed to OPSS Advisory Board

    New members appointed to the Office for Product Safety and Standards Advisory Board.

    Five new members have been appointed to the Office for Product Safety and Standards (OPSS) Advisory Board. They are:

    • Jen Dinmore – Legal Director, Digital, Commerce and Creative team, Lewis Silk 
    • Frank Given – Founder, Close Focus
    • Amanda Long – Chief Executive, Construction Product Information
    • Professor John Loughhead – Industrial Professor of Clean Energy at the University of Birmingham and Chair of the Redwheel-Turquoise ClimateTech fund
    • John McDermid – Professor of Software Engineering, University of York

    OPSS welcomes these new members of its Advisory Board, who have a wealth of experience in areas including engineering, regulation, research and standards development.

    The OPSS Advisory Board typically meets once a quarter. Its members act as critical friends, providing external challenge and bringing fresh perspectives and ideas, ensuring OPSS is best prepared to deal with current and future challenges. The group is not involved in operational decisions, such as handling individual regulatory incidents.

    Updates to this page

    Published 31 July 2025

    MIL OSI United Kingdom –

  • MIL-OSI Europe: Written question – Legal risks of EU proposal to ban Russian natural gas imports – E-003014/2025

    Source: European Parliament

    Question for written answer  E-003014/2025
    to the Commission
    Rule 144
    Fabio De Masi (NI)

    According to the Oxford Institute for Energy Studies, the proposal for a regulation on phasing out Russian natural gas imports, improving the monitoring of potential energy dependencies and amending Regulation (EU) 2017/1938 raises unresolved legal issues that ‘place a significant burden on importers and other stakeholders, while risking regulatory overreach […] thus potentially increasing costs and preventing legitimate gas imports’. The analysts also argue that the amendment of the rules creates legal uncertainty, in particular as regards the application of force majeure clauses and contract termination. The proposal does not guarantee that an import ban will be recognised as a case of force majeure under the relevant contract, leaving buyers exposed to potential claims for compensation or ongoing obligations under long-term Russian gas and LNG contracts, even if the EU ban is in place.

    How will the European Commission take account of the criticism of the Oxford Institute for Energy Studies[1] that the proposal to phase out Russian gas imports creates legal uncertainties and exposes importers to possible claims for compensation?

    Submitted: 19.7.2025

    • [1] https://www.oxfordenergy.org/wpcms/wp-content/uploads/2025/07/The-EU-Proposal-To-Ban-Russian-Gas-Imports-roadblock-more-than-roadmap-NG-199.pdf
    Last updated: 31 July 2025

    MIL OSI Europe News –

  • MIL-OSI: Prospera Energy Inc. Provides Operations Update

    Source: GlobeNewswire (MIL-OSI)

    CALGARY, Alberta, July 31, 2025 (GLOBE NEWSWIRE) — Prospera Energy Inc. (TSX.V: PEI, OTC: GXRFF) (“Prospera”, “PEI” or the “Corporation”)

    Operations Update
    Prospera continues to demonstrate strong operational performance, averaging gross production of 859 boe/d (97% oil) from July 1st to July 23rd. This sustained growth follows the successful completion of numerous projects across the company’s properties including well reactivations, rod repairs, sand control upgrades, engine maintenance and tune-ups, lease upgrades, mineral rights acquisitions, coil-tubing cleanouts, and waterflood optimizations. Nine additional wells have come online in the last 10 days and are currently in stages of load fluid recovery or initial optimization.

    Notably, these figures exclude production from the recently acquired White Tundra Petroleum assets, which remains subject to TSXV acceptance. Comprehensive well-by-well analysis is now being conducted weekly, with production enhancement changes implemented on a daily basis through communication with field operations personnel. Concurrently, Prospera’s service rig continues to systematically work through a robust inventory of over 150 remaining workover and reactivation candidates across its heavy oil properties, further enhancing operational efficiency.

    Prospera’s predominantly heavy oil production base continues to operate in favorable pricing conditions with WCS (Western Canadian Select) differentials in an optimal range, contributing to enhanced revenue and cash flow. The Corporation’s high netbacks support our strategy to reallocate capital efficiently into high-impact and reliable projects, with 50+ projects now completed and plans finalized for its Q3 and Q4 service rig programs including nine Luseland reactivations that have completed engineering and planning stages.

    Cuthbert
    Production at the Cuthbert pool has been rising steadily, averaging 356 boe/d (100% oil) from July 1st to July 23rd. This sustained growth is supported by ongoing waterflood optimization, increased pump speeds, and the completion of critical maintenance across wellsite and battery infrastructure.

    A high-impact remediation project on the 16-28 HZ well has been successfully completed, involving the installation of a downhole bridge plug to isolate a section of the well previously drilled into coal and water-bearing part of the formation. Additionally, a high-impact remediation project on the 08-02 HZ well has been fully funded and is awaiting mobilization after lease conditions dry up. This project includes a casing cut and cementing to block water production from the heel of the well.

    Hearts Hill
    Production at the Hearts Hill pool remains stable, averaging 230 boe/d (91% oil) from July 1st to 23rd. The Corporation is actively advancing waterflood pattern optimization and fluid level drawdown initiatives to enhance reservoir performance. A comprehensive line-by-line review of all pipelines in the area has been completed to confirm injection volumes, validate pipeline integrity, and support the development of a final field reactivation and workover plan. Earlier Sparky zone recompletions continue to deliver consistent oil production, with future Sparky waterflood development held in inventory. Prospera is also actively evaluating uphole recompletion opportunities in the Waseca and Rex zones to further unlock production potential.

    Luseland
    The Corporation continues to advance its growth trajectory at the Luseland pool, averaging production of 193 boe/d (100% oil) from July 1st to 23rd. This performance is supported by ongoing workovers, well reactivations, and field optimizations. In the past 10 days, five reactivated wells have been brought online, with two additional wells recently completed under Single Well Battery setups and awaiting start-up.

    Numerous other wells are currently undergoing optimization, including the installation of recycle pumps, application of sand suspension chemical treatments, increased pump speeds to accelerate fluid drawdown, flushby operations, and well loads to bring sand up the wellbore. These efforts are complemented by various initiatives aimed at reducing operating costs. Prospera’s engineering team is focused on well-by-well monitoring of all new reactivations to maximize production rates and enhance reservoir understanding while minimizing well failures and decline rates.

    Several high-performing Luseland wells are featured in the accompanying Key Wells Report, demonstrating the success of Prospera’s strategic focus on revitalizing legacy wells with significant original oil in place (OOIP). By reactivating these assets, the company is effectively converting wells previously classified as No Reserves Associated (NRA) and burdened solely with Asset Retirement Obligations (ARO) into actively producing wells with meaningful Proved Developed Producing (PDP) reserves—resulting in sustainable revenue generation and positive cash flow.

    Production, Workover Tracker, and Key Wells Report
    Prospera is enhancing its transparency measures with the publishing of its updated production, workover tracker, and key wells report. Production volumes on each field will continue to be reported on a monthly basis, along with corporate revenue information. A detailed workover tracker will share production rates from all workovers and reactivations completed, with information on capital spend and cumulative production since start-up to be added to the August iteration of this report. Additionally, numerous key wells and their production graphs are explained in detail as the company further proves out its highly capital-efficient workover and reactivation business model.

    Price Hedging
    The Corporation is pleased to announce that it has entered into a contract to hedge a portion of its oil production. From September 2025 through February 2026, Prospera has hedged 100 barrels of oil per day at an average price of approximately USD $67.00 per barrel of WTI. This strategic initiative is aimed at providing improved cash flow stability, strengthening corporate governance through proactive risk management, and capitalizing on current favorable market pricing. It represents a disciplined approach to managing commodity price exposure while preserving upside potential across the remainder of PEI’s production.

    Shares for Debt
    Prospera has entered into agreements with two vendors to settle outstanding trade payables through the issuance of common shares. The first vendor has agreed to settle a total of $28,900.45 through the issuance of 125,000 common shares at a deemed price of $0.231 per share. The second vendor has agreed to settle $7,392.55 through the issuance of 40,000 common shares at a deemed price of $0.185 per share. The shares will be subject to a trading restriction of four months and a day from the date of issuance and are subject to TSXV acceptance.

    Loan Amendment
    The Corporation announces a further amendment to its $11,000,000 promissory note, originally dated June 7, 2024, in collaboration with its principal lender. Following previous increases, an additional $2,000,000 has been added, bringing the total principal amount to $18,700,000. The note retains its original terms, including a 12% interest rate and a two-year maturity, with no other changes. The proceeds are earmarked specifically towards production-increasing capital projects. This amendment remains subject to acceptance by the TSXV.

    Promissory Note Update
    The Corporation provides an update regarding the previously disclosed one-year secured promissory note on January 9th, 2025. The promissory note component of the offering will now be unsecured. The placement closed with four subscribers, raising aggregate gross proceeds of $900,000. Each unit, priced at $1,000, consists of: (i) a one-year unsecured promissory note with a principal amount of $1,000, carrying a 12% annual interest rate, and (ii) 5,000 common share purchase warrants of the Corporation, exercisable at $0.05 for a period of one year, for a total of 4,500,000 warrants. Subscribers are entitled to a 5% gross overriding royalty (GORR) for every $1,000,000 of principal investment on revenue from all Prospera properties on incremental production above 1,363 barrels per day, calculated on a monthly average until the principal debt is fully repaid. Interest on the notes will accrue and be paid quarterly, accompanied by a 2% facility fee. This offering has been accepted by the TSX Venture Exchange.

    Insiders have participated in this offering for a principal amount of $800,000, which results in this being a Related Party Transaction pursuant to TSXV Policy 5.9 and MI 61-101. The Corporation is relying upon numerous exemptions under these policies with respect to minority approval and valuation requirements, including those found in section 5.5 (a), (b), and (c) and 5.7 (a) and (b). The following reporting Insiders have participated in this offering:

    Summerhill Investments Corp. subscribed for $500,000 and was issued an aggregate of 2,500,000 warrants, each exercisable at $0.05 per share for a period of one year from the date of issuance.

    Mantl Canada Inc. subscribed for $200,000 and was issued an aggregate of 1,000,000 warrants, each exercisable at $0.05 per share for a period of one year from the date of issuance.

    Countryman Investments Ltd. subscribed for $100,000 and was issued an aggregate of 500,000 warrants, each exercisable at $0.05 per share for a period of one year from the date of issuance.

    About Prospera
    Prospera Energy Inc. is a publicly traded Canadian energy company specializing in the exploration, development, and production of crude oil and natural gas. Headquartered in Calgary, Alberta, Prospera is dedicated to optimizing recovery from legacy fields using environmentally safe and efficient reservoir development methods and production practices. The company’s core properties are strategically located in Saskatchewan and Alberta, including Cuthbert, Luseland, Hearts Hill, and Brooks. Prospera Energy Inc. is listed on the TSX Venture Exchange under the symbol PEI and the U.S. OTC Market under GXRFF.

    Prospera reports gross production at the first point of sale, excluding gas used in operations and volumes from partners in arrears, even if cash proceeds are received. Gross production represents Prospera’s working interest before royalties, while net production reflects its working interest after royalty deductions. These definitions align with ASC 51-324 to ensure consistency and transparency in reporting.

    For Further Information:

    Shawn Mehler, PR
    Email: investors@prosperaenergy.com

    Chris Ludtke, CFO
    Email: cludtke@prosperaenergy.com

    Shubham Garg, Chairman of the Board
    Email: sgarg@prosperaenergy.com

    FORWARD-LOOKING STATEMENTS
    This news release contains forward-looking statements relating to the future operations of the Corporation and other statements that are not historical facts. Forward-looking statements are often identified by terms such as “will,” “may,” “should,” “anticipate,” “expects” and similar expressions. All statements other than statements of historical fact included in this release, including, without limitation, statements regarding future plans and objectives of the Corporation, are forward-looking statements that involve risks and uncertainties. There can be no assurance that such statements will prove to be accurate and actual results and future events could differ materially from those anticipated in such statements.

    Although Prospera believes that the expectations and assumptions on which the forward-looking statements are based are reasonable, undue reliance should not be placed on the forward-looking statements because Prospera 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, and health, safety and environmental risks), commodity price and exchange rate fluctuations and uncertainties resulting from potential delays or changes in plans with respect to exploration or development projects or capital expenditures.

    The reader is cautioned that assumptions used in the preparation of any forward-looking information may prove to be incorrect. Events or circumstances may cause actual results to differ materially from those predicted, as a result of numerous known and unknown risks, uncertainties, and other factors, many of which are beyond the control of Prospera. As a result, Prospera cannot guarantee that any forward-looking statement will materialize, and the reader is cautioned not to place undue reliance on any forward- looking information. Such information, although considered reasonable by management at the time of preparation, may prove to be incorrect and actual results may differ materially from those anticipated. Forward-looking statements contained in this news release are expressly qualified by this cautionary statement. The forward-looking statements contained in this news release are made as of the date of this news release, and Prospera does not undertake any obligation to update publicly or to revise any of the included forward-looking statements, whether as a result of new information, future events or otherwise, except as expressly required by Canadian securities law.

    Neither TSXV nor its Regulation Services Provider (as that term is defined in the policies of the TSXV) accepts responsibility for the adequacy or accuracy of this release.

    The MIL Network –

  • MIL-OSI: Cenovus announces second-quarter 2025 results

    Source: GlobeNewswire (MIL-OSI)

    CALGARY, Alberta, July 31, 2025 (GLOBE NEWSWIRE) — Cenovus Energy Inc. (TSX: CVE) (NYSE: CVE) today announced its second-quarter 2025 financial and operating results. The company generated approximately $2.4 billion in cash from operating activities, $1.5 billion of adjusted funds flow and $355 million of free funds flow. Total upstream production was 765,900 barrels of oil equivalent per day (BOE/d)1, reflecting planned turnarounds at the Foster Creek and Sunrise oil sands assets, maintenance at offshore facilities and short-term production impacts from wildfire activity at Christina Lake. Downstream crude throughput was 665,800 barrels per day (bbls/d), representing an overall utilization rate of 92% and including the successful completion of a turnaround at the Toledo Refinery 11 days ahead of schedule.

    Highlights

    • Achieved first oil at Narrows Lake in July, with production expected to ramp up to peak incremental rates of 20,000 bbls/d – 30,000 bbls/d by the end of the year.
    • Delivered major milestones on the West White Rose project, with the concrete gravity structure (CGS) installed on the seabed in June and the topsides placed atop the CGS in mid-July. Hookup and commissioning work has commenced, with drilling expected to begin by year end.
    • Advanced the Foster Creek optimization project, with four new boilers brought online in July, which will add approximately 80,000 bbls/d of steam capacity to the facility.
    • Completed major turnarounds at Toledo, Sunrise and Foster Creek in the quarter, with exceptional execution, resulting in production at all assets resuming ahead of schedule.
    • Returned $819 million to shareholders, including $301 million through common share purchases, $368 million through common and preferred share dividends and $150 million through the redemption of Cenovus’s Series 7 preferred shares on June 30, 2025.

    “Operating performance this quarter was exceptional, with turnaround execution exceeding our targets, major project milestones achieved on time and on budget, and our staff safely and efficiently restoring Christina Lake production following disruption from a wildfire,” said Jon McKenzie, Cenovus President & Chief Executive Officer. “Through the hard work and determination of our people, we have arrived at an inflection point, nearing completion of numerous growth projects and successfully concluding significant maintenance events. As investment in these initiatives is completed, we expect to generate increasing free funds flow.”

    Financial summary

    ($ millions, except per share amounts) 2025 Q2 2025 Q1 2024 Q2
    Cash from (used in) operating activities 2,374 1,315 2,807
    Adjusted funds flow2 1,519 2,212 2,361
    Per share (diluted)2 0.84 1.21 1.26
    Capital investment 1,164 1,229 1,155
    Free funds flow2 355 983 1,206
    Excess free funds flow2 (306) 373 735
    Net earnings (loss) 851 859 1,000
    Per share (diluted) 0.45 0.47 0.53
    Long-term debt, including current portion 7,241 7,524 7,275
    Net debt 4,934 5,079 4,258


    Production and throughput

    (before royalties, net to Cenovus) 2025 Q2 2025 Q1 2024 Q2
    Oil and NGLs (bbls/d)1 624,000 670,900 656,300
    Conventional natural gas (MMcf/d) 851.4 887.9 867.2
    Total upstream production (BOE/d)1 765,900 818,900 800,800
    Total downstream crude throughput (bbls/d) 665,800 665,400 622,700

    1See Advisory for production by product type and by operating segment.
    2Non-GAAP financial measure or contains a non-GAAP financial measure. See Advisory.

    Second-quarter results

    Operating1

    Cenovus’s total revenues were $12.3 billion in the second quarter, down from $13.3 billion in the first quarter of 2025. Upstream revenues were $6.8 billion, a decrease from $8.3 billion in the previous quarter, while Downstream revenues were $7.7 billion, in line with the previous quarter.

    Total operating margin3 was $2.1 billion, compared with $2.8 billion in the previous quarter. Upstream operating margin4 was $2.1 billion, down from $3.0 billion in the first quarter due to lower benchmark oil prices, as well as lower production and sales volumes. The company had a Downstream operating margin4 shortfall of $71 million compared with a shortfall of $237 million in the previous quarter, benefiting from rising U.S. market crack spreads and a higher Canadian upgrading differential, as well as lower run-rate operating costs, excluding turnarounds, in both businesses. Operating margin in the U.S. Refining segment was a shortfall of $178 million, which included a $62 million inventory holding loss and $238 million of turnaround expenses.

    Total Upstream production was 765,900 BOE/d in the second quarter, a decrease from 818,900 BOE/d in the first quarter. Christina Lake production was 217,900 bbls/d compared with 237,800 bbls/d in the prior quarter, as a wildfire near the facility temporarily impacted production in the second quarter. The field was shut in on May 29 and operations were restarted safely on June 3, with a return to full production about one week later. Foster Creek production was 186,100 bbls/d compared with 202,700 bbls/d in the first quarter, reflecting planned maintenance during the quarter that was successfully completed with production returning earlier than forecasted. Sunrise production was 50,300 bbls/d compared with 52,100 bbls/d in the first quarter due to planned maintenance at the facility.

    Production from the Lloydminster thermal assets was 97,800 bbls/d, a decrease from 109,900 bbls/d in the prior quarter due to an unplanned outage at the Rush Lake facilities in west-central Saskatchewan. The company responded in early May to a steam release from a casing failure in an injection well and as a result, the Rush Lake facilities have been temporarily shut-in. The well has been brought under control, and the company is undertaking an investigation and developing a plan to safely restart production. Lloydminster conventional heavy oil output of 25,000 bbls/d increased from 21,800 bbls/d in the first quarter. Production in the Conventional segment was 119,800 BOE/d, down from 123,900 BOE/d in the previous quarter due in part to third-party outages.

    In the Offshore segment, production was 66,300 BOE/d compared with 68,800 BOE/d in the first quarter. In Asia Pacific, production volumes were 53,800 BOE/d, lower than the 57,200 BOE/d in the previous quarter, primarily due to planned maintenance at the Liwan Gas Project. In the Atlantic region, production was 12,500 bbls/d, an increase from 11,600 bbls/d in the prior quarter, due to a full quarter of production from the White Rose field, offset in part by maintenance at the partner-operated Terra Nova field in June.

    Total Downstream crude throughput in the second quarter was 665,800 bbls/d, up from 665,400 bbls/d in the first quarter. Crude throughput in Canadian Refining was 112,400 bbls/d, representing a utilization rate of 104%, compared with 111,900 bbls/d in the previous quarter.

    In U.S. Refining, crude throughput was 553,400 bbls/d, representing a utilization rate of 90%, compared with 553,500 bbls/d in the first quarter, reflecting early completion of a planned turnaround at the Toledo Refinery. U.S. Refining revenues were $6.5 billion, slightly higher than $6.4 billion in the previous quarter. Adjusted market capture5 in U.S. Refining was 58%, compared with 62% in the first quarter, due primarily to a narrower heavy oil price differential.

    3Non-GAAP financial measure. Total operating margin is the total of Upstream operating margin plus Downstream operating margin. See Advisory.
    4Specified financial measure. See Advisory.
    5Adjusted market capture excludes the impact of inventory holding gains or losses. Contains a non-GAAP financial measure. See Advisory.

    Financial

    Cash from operating activities in the second quarter increased to approximately $2.4 billion from $1.3 billion in the first quarter. Adjusted funds flow was $1.5 billion, compared with $2.2 billion in the prior quarter, and excess free funds flow (EFFF) was a shortfall of $306 million, compared with a surplus of $373 million in the first quarter. Net earnings in the second quarter declined slightly to $851 million from $859 million in the previous quarter. Second-quarter financial results were impacted by lower benchmark oil prices, lower Upstream production and higher planned maintenance costs relative to the first quarter.

    Long-term debt, including the current portion, was $7.2 billion as at June 30, 2025. Net debt was $4.9 billion as at June 30, 2025, slightly reduced from the previous quarter, as free funds flow of $355 million and a $923 million release of non-cash working capital more than offset returns to shareholders of $819 million, including the redemption of Cenovus’s Series 7 preferred shares on June 30, 2025 for $150 million. Subsequent to the quarter on July 15, the company repaid its 5.38% unsecured notes with a principal of US$133 million in full. The company continues to steward toward net debt of $4.0 billion and returning 100% of EFFF to shareholders over time, in accordance with its financial framework.

    Growth projects

    In the Oil Sands segment, Narrows Lake achieved first oil in mid-July and will continue ramping up through the remainder of the year. The optimization project at Foster Creek is approximately 87% complete and four new boilers that will add approximately 80,000 bbls/d of steam capacity were brought online in July. The project is expected to produce first oil in early 2026. At Sunrise, one well pad was started up early in the quarter and the drilling program remains on track to increase production and fully utilize the asset’s steam capacity.

    Significant progress has been made on the West White Rose project. The CGS was towed out and installed on the seabed ahead of schedule during the second quarter and the project’s topsides were safely lifted and set in place atop the CGS in mid-July. Hookup and commissioning have commenced, and the project is approximately 92% complete. Drilling is expected to begin by the end of the year and the project remains on schedule to produce first oil in the second quarter of 2026.

    2025 guidance update

    Cenovus has revised its 2025 corporate guidance to reflect the company’s updated outlook for the remainder of the year. It is available on cenovus.com under Investors.

    Changes to the company’s 2025 guidance include:

    • Total upstream production of 805,000 BOE/d to 825,000 BOE/d, a decrease of 10,000 BOE/d at the midpoint. This includes the impacts of the temporary shut in of the Rush Lake facilities.
    • Canadian downstream throughput of 105,000 bbls/d to 110,000 bbls/d, an increase of 5,000 bbls/d at the midpoint, reflecting strong year-to-date performance.
    • Reducing the range of Canadian Refining per-unit operating expenses, excluding turnaround costs, to $11.00/bbl to $12.00/bbl, as a result of higher throughput rates and lower expected costs.
    • Downstream turnaround expenses of $420 million to $450 million have been reduced by $45 million at the midpoint, primarily due to early completion of the Toledo turnaround.

    The company has also updated its commodity price assumptions and guidance range for cash taxes. Cenovus continues to execute its capital program and there has been no change to the expected capital investment range of $4.6 billion to $5.0 billion.

    Sustainability
    Cenovus’s 2024 Corporate Social Responsibility report, highlighting the company’s performance in safety, Indigenous reconciliation, and acceptance and belonging, was released today and is now available on the company’s website.

    Dividend declarations and share purchases

    The Board of Directors has declared a quarterly base dividend of $0.20 per common share, payable on September 29, 2025, to shareholders of record as of September 15, 2025.

    In addition, the Board has declared a quarterly dividend on each of the Cumulative Redeemable First Preferred Shares – Series 1 and Series 2 – payable on October 1, 2025 to shareholders of record as of September 15, 2025, as follows:

    Preferred shares dividend summary

    Share series Rate (%) Amount ($/share)
    Series 1 2.577 0.16106
    Series 2 4.374 0.27562

    All dividends paid on Cenovus’s common and preferred shares will be designated as “eligible dividends” for Canadian federal income tax purposes. Declaration of dividends is at the sole discretion of the Board and will continue to be evaluated on a quarterly basis.

    In the second quarter, the company returned $819 million to shareholders, composed of $301 million from its purchase of 17.2 million shares through its normal course issuer bid, $368 million through common and preferred share dividends, and $150 million through the redemption of Cenovus’s Series 7 preferred shares. Subsequent to the quarter, the company purchased 6.6 million common shares through July 28, 2025 for $129 million.

    2025 planned maintenance

    The following table provides details on planned maintenance activities at Cenovus assets in 2025 and anticipated production or throughput impacts.

    Potential quarterly production/throughput impact (Mbbls/d or MBOE/d)

    (MBOE/d or Mbbls/d) Q3 Q4 Annualized impact
    Upstream
    Oil Sands 5 – 7 – 7 – 9
    Offshore 2 – 4 – 1 – 2
    Conventional – – –
    Downstream
    Canadian Refining – – –
    U.S. Refining – 10 – 15 12 – 14


    Potential turnaround expenses

    ($ millions) Q3 Q4 Annualized impact
    Downstream
    Canadian Refining – – –
    U.S. Refining 55 – 70 45 – 60 420 – 450


    Conference call today

    Cenovus will host a conference call today, July 31, 2025, starting at 9 a.m. MT (11 a.m. ET).

    For analysts wanting to join the call, please register in advance.

    To participate in the live conference call, you must complete the online registration form in advance of the conference call start time. Register ahead of time to receive a unique PIN to access the conference call via telephone. Once registered, participants can dial into the conference call from their telephone via the unique PIN or click on the “Call Me” option to receive an automated call directly on their telephone.

    An audio webcast will also be available and archived for approximately 30 days.

    Advisory

    Basis of Presentation

    Cenovus reports financial results in Canadian dollars and presents production volumes on a net to Cenovus before royalties basis, unless otherwise stated. Cenovus prepares its financial statements in accordance with International Financial Reporting Standards (IFRS) Accounting Standards.

    Barrels of Oil Equivalent

    Natural gas volumes have been converted to barrels of oil equivalent (BOE) on the basis of six thousand cubic feet (Mcf) to one barrel (bbl). BOE may be misleading, particularly if used in isolation. A conversion ratio of one bbl to six Mcf is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil compared with natural gas is significantly different from the energy equivalency conversion ratio of 6:1, utilizing a conversion on a 6:1 basis is not an accurate reflection of value.

    Product types

    Product type by operating segment Three months ended
    June 30, 2025
    Oil Sands
    Bitumen (Mbbls/d) 552.1
    Heavy crude oil (Mbbls/d) 25.0
    Conventional natural gas (MMcf/d) 16.5
    Total Oil Sands segment production (MBOE/d) 579.8
    Conventional
    Light crude oil (Mbbls/d) 4.5
    Natural gas liquids (Mbbls/d) 20.4
    Conventional natural gas (MMcf/d) 569.2
    Total Conventional segment production (MBOE/d) 119.8
    Offshore
    Light crude oil (Mbbls/d) 12.5
    Natural gas liquids (Mbbls/d) 9.5
    Conventional natural gas (MMcf/d) 265.7
    Total Offshore segment production (MBOE/d) 66.3
    Total Upstream production (MBOE/d) 765.9


    Forward‐looking Information

    This news release contains certain forward‐looking statements and forward‐looking information (collectively referred to as “forward‐looking information”) within the meaning of applicable securities legislation about Cenovus’s current expectations, estimates and projections about the future of the company, based on certain assumptions made in light of the company’s experiences and perceptions of historical trends. Although Cenovus believes that the expectations represented by such forward‐looking information are reasonable, there can be no assurance that such expectations will prove to be correct. Forward‐looking information in this document is identified by words such as “anticipate”, “continue”, “deliver”, “expect”, “plan”, “steward”, and “will” or similar expressions and includes suggestions of future outcomes, including, but not limited to, statements about: Net Debt target; returning Excess Free Funds Flow to shareholders; growth plans and projects; maximizing value; production guidance; timing of startup of the Foster Creek optimization project; ramping up production at Narrows Lake; investigating the Rush Lake incident and developing a plan to restart production; the Sunrise drilling program; the hookup and commissioning of, and timing of drilling at the West White Rose project; executing the capital program; 2025 planned maintenance; and dividend payments.

    Developing forward‐looking information involves reliance on a number of assumptions and consideration of certain risks and uncertainties, some of which are specific to Cenovus and others that apply to the industry generally. The factors or assumptions on which the forward‐looking information in this news release are based include, but are not limited to: the allocation of free funds flow; commodity prices, inflation and supply chain constraints; Cenovus’s ability to produce on an unconstrained basis; Cenovus’s ability to access sufficient insurance coverage to pursue development plans; Cenovus’s ability to deliver safe and reliable operations and demonstrate strong governance; and the assumptions inherent in Cenovus’s updated 2025 corporate guidance available on cenovus.com.

    The risk factors and uncertainties that could cause actual results to differ materially from the forward‐looking information in this news release include, but are not limited to: the accuracy of estimates regarding commodity production and operating expenses, inflation, taxes, royalties, capital costs and currency and interest rates; risks inherent in the operation of Cenovus’s business; and risks associated with climate change and Cenovus’s assumptions relating thereto and other risks identified under “Risk Management and Risk Factors” and “Advisory” in Cenovus’s Management’s Discussion and Analysis (MD&A) for the year ended December 31, 2024.

    Except as required by applicable securities laws, Cenovus disclaims any intention or obligation to publicly update or revise any forward‐looking statements, whether as a result of new information, future events or otherwise. Readers are cautioned that the foregoing lists are not exhaustive and are made as at the date hereof. Events or circumstances could cause actual results to differ materially from those estimated or projected and expressed in, or implied by, the forward‐looking information. For additional information regarding Cenovus’s material risk factors, the assumptions made, and risks and uncertainties which could cause actual results to differ from the anticipated results, refer to “Risk Management and Risk Factors” and “Advisory” in Cenovus’s MD&A for the periods ended December 31, 2024 and June 30, 2025 and to the risk factors, assumptions and uncertainties described in other documents Cenovus files from time to time with securities regulatory authorities in Canada (available on SEDAR+ at sedarplus.ca, on EDGAR at sec.gov and Cenovus’s website at cenovus.com).

    Specified Financial Measures

    This news release contains references to certain specified financial measures that do not have standardized meanings prescribed by IFRS Accounting Standards. Readers should not consider these measures in isolation or as a substitute for analysis of the company’s results as reported under IFRS Accounting Standards. These measures are defined differently by different companies and, therefore, might not be comparable to similar measures presented by other issuers. For information on the composition of these measures, as well as an explanation of how the company uses these measures, refer to the Specified Financial Measures Advisory located in Cenovus’s MD&A for the period ended June 30, 2025 (available on SEDAR+ at sedarplus.ca, on EDGAR at sec.gov and on Cenovus’s website at cenovus.com) which is incorporated by reference into this news release.

    Upstream Operating Margin and Downstream Operating Margin

    Upstream Operating Margin and Downstream Operating Margin, and the individual components thereof, are included in Note 1 to the interim Consolidated Financial Statements.

    Total Operating Margin

    Total Operating Margin is the total of Upstream Operating Margin plus Downstream Operating Margin.

      Upstream (6) Downstream (6) Total
    ($ millions) Q2 2025 Q1 2025 Q2 2024 Q2 2025 Q1 2025 Q2 2024 Q2 2025 Q1 2025 Q2 2024
    Revenues
    Gross Sales 7,394 9,252 8,715 7,743 7,705 8,750 15,137 16,957 17,465
    Less: Royalties (621) (906) (859) — — — (621) (906) (859)
      6,773 8,346 7,856 7,743 7,705 8,750 14,516 16,051 16,606
    Expenses
    Purchased Product 1,111 1,167 815 6,878 7,082 7,796 7,989 8,249 8,611
    Transportation and Blending 2,621 3,247 3,043 — — — 2,621 3,247 3,043
    Operating 896 893 889 947 854 1,099 1,843 1,747 1,988
    Realized (Gain) Loss on Risk Management 8 (9) 20 (11) 6 8 (3) (3) 28
    Operating Margin 2,137 3,048 3,089 (71) (237) (153) 2,066 2,811 2,936

    6Found in Note 1 of the June 30, 2025, or the March 31, 2025, interim Consolidated Financial Statements. Revenues and purchased product for Q2 2024 Downstream operations were revised. See Note 21 of our June 30, 2025, interim Consolidated Financial Statements.

    Adjusted Funds Flow, Free Funds Flow and Excess Free Funds Flow

    The following table provides a reconciliation of cash from (used in) operating activities found in Cenovus’s interim Consolidated Financial Statements to Adjusted Funds Flow, Free Funds Flow and Excess Free Funds Flow. Adjusted Funds Flow per Share – Basic and Adjusted Funds Flow per Share – Diluted are calculated by dividing Adjusted Funds Flow by the respective basic or diluted weighted average number of common shares outstanding during the period and may be useful to evaluate a company’s ability to generate cash.

      Three Months Ended
    ($ millions) June 30, 2025 March 31, 2025 June 30, 2024
    Cash From (Used in) Operating Activities (7) 2,374 1,315 2,807
    (Add) Deduct:      
    Settlement of Decommissioning Liabilities (68) (36) (48)
    Net Change in Non-Cash Working Capital 923 (861) 494
    Adjusted Funds Flow 1,519 2,212 2,361
    Capital Investment 1,164 1,229 1,155
    Free Funds Flow 355 983 1,206
    Add (Deduct):      
    Base Dividends Paid on Common Shares (364) (327) (334)
    Purchase of Common Shares under Employee Benefit Plan (15) (58) —
    Dividends Paid on Preferred Shares (4) (6) (9)
    Settlement of Decommissioning Liabilities (68) (36) (48)
    Principal Repayment of Leases (94) (83) (75)
    Acquisitions, Net of Cash Acquired (129) (100) (5)
    Proceeds From Divestitures 13 — —
    Excess Free Funds Flow (306) 373 735

    7Found in the June 30, 2025, or the March 31, 2025, interim Consolidated Financial Statements.

    Adjusted Market Capture

    Adjusted market capture contains a non-GAAP financial measure and is used in the company’s U.S. Refining segment to provide an indication of margin captured relative to what was available in the market based on widely-used benchmarks. Cenovus defines adjusted market capture as refining margin, net of holding gains and losses, divided by the weighted average 3-2-1 market benchmark crack, net of RINs, expressed as a percentage. The weighted average crack spread, net of RINs, is calculated on Cenovus’s operable capacity-weighted average of the Chicago and Group 3 3-2-1 benchmark market crack spreads, net of RINs.

    The company previously disclosed market capture which did not exclude the effect of inventory holding gains or losses. Cenovus replaced market capture with adjusted market capture to exclude the impact of inventory holding gains or losses. The company believes this metric provides more comparability and accuracy when measuring the cash generating performance of our downstream operations. Comparative periods were revised to conform with our current presentation.

    ($ millions) Three months ended
    June 30, 2025    		 Three months ended
    March 31, 2025
    Revenues (8) 6,455 6,423
    Purchased Product (8) 5,838 6,006
    Gross Margin 617 417
    Inventory Holding (Gain) Loss 62 23
    Adjusted Gross Margin 679 440
    Total Processed Inputs (Mbbls/d) 594.2 581.0
    Adjusted Gross Margin ($/bbl) 12.57 8.41
    Operable Capacity (Mbbls/d) 612.3 612.3
    Operable Capacity by Regional Benchmark (percent)
    Chicago 3-2-1 Crack Spread Weighting 81 81
    Group 3 3-2-1 Crack Spread Weighting 19 19
    Benchmark Prices and Exchange Rate
    Chicago 3-2-1 Crack Spread (US$/bbl) 21.64 13.68
    Group 3 3-2-1 Crack Spread (US$/bbl) 23.07 16.48
    RINs (US$/bbl) 6.12 4.76
    US$ per C$1 – Average 0.723 0.697
    Weighted Average Crack Spread, Net of RINs ($/bbl) 21.86 13.58
    Adjusted Market Capture (percent) 58 62

    8Found in Note 1 of the June 30, 2025, or the March 31, 2025, interim Consolidated Financial Statements.

    Cenovus Energy Inc.

    Cenovus Energy Inc. is an integrated energy company with oil and natural gas production operations in Canada and the Asia Pacific region, and upgrading, refining and marketing operations in Canada and the United States. The company is committed to maximizing value by developing its assets in a safe, responsible and cost-efficient manner, integrating environmental, social and governance considerations into its business plans. Cenovus common shares and warrants are listed on the Toronto and New York stock exchanges, and the company’s preferred shares are listed on the Toronto Stock Exchange. For more information, visit cenovus.com.

    Find Cenovus on Facebook, LinkedIn, YouTube and Instagram.

    Cenovus contacts

    Investors
    Investor Relations general line
    403-766-7711

    Media
    Media Relations general line
    403-766-7751

    The MIL Network –

  • Govt consistently increased budget allocation for science and research in last five years: Jitendra Singh

    Source: Government of India

    Source: Government of India (4)

    The government has consistently increased the budget allocation for science and research, with the highest allocation made in FY 2025-26 over the last five years, Union Minister of State for Science and Technology Jitendra Singh informed Parliament on Thursday.

    In a written reply in the Rajya Sabha, Singh said that “more than ₹65,307 crore has been allocated to six scientific agencies for research in FY 2025-26.” In comparison, ₹41,581.96 crore was allocated for science and research in 2024-25, and ₹39,843 crore in 2023-24.

    In 2022-23, the government allocated ₹37,828 crore, while ₹37,823 crore was allocated in 2021-22.

    The six major scientific agencies/departments are the Department of Science and Technology (DST), the Department of Scientific and Industrial Research/Council of Scientific and Industrial Research (DSIR/CSIR), the Department of Biotechnology (DBT), the Department of Space (DoS), the Department of Atomic Energy (DAE), and the Ministry of Earth Sciences (MoES).

    “DST received the highest allocation of ₹28,508.90 crore in FY 2025-26, followed by DoS with ₹13,416.20 crore,” Singh said. These agencies have received their highest allocations this year since FY 2021-22.

    Additionally, the Minister informed that the government has been implementing several fellowships offering direct benefits to young scientists and researchers.

    Some of the key schemes include the INSPIRE Fellowship, INSPIRE Faculty Fellowship, Women in Science and Engineering (WISE)-PhD, WISE-Post Doctoral Fellowship (PDF), and the Scheme for Young Scientists and Technologists (SYST).

    To provide high-level strategic direction for research, innovation, and entrepreneurship in the country, the government has established the Anusandhan National Research Foundation (ANRF) through the ANRF Act of 2023, Singh added.

    Under the Act, special provisions have been made to encourage public sector enterprises as well as private sector entities to invest in ANRF-led initiatives.

    Recently, the government launched the Research, Development and Innovation (RDI) scheme with a financial outlay of ₹1 lakh crore over five years. This DST-led scheme aims to promote private sector participation in sunrise sectors, thereby driving growth and innovation.

    Singh also informed the House about the steps taken by the government to enhance private sector participation in research and development.

    Key efforts include incentivising private sector investment to increase their share in Gross Expenditure on Research and Development (GERD), and creating avenues for collaborative science, technology, and innovation (STI) funding through portfolio-based mechanisms such as public-private partnerships and other innovative hybrid funding models, the Minister said.

    IANS

  • MIL-OSI: Axi Honoured with Five Awards by World Business Outlook Awards for 2025

    Source: GlobeNewswire (MIL-OSI)

    SYDNEY, July 31, 2025 (GLOBE NEWSWIRE) — Axi, an industry-leading global broker, has been recognised with five awards* from the World Business Outlook Awards for 2025, marking a significant milestone in its continued growth and commitment to excellence:

    Best CFD Provider Australia

    Best Forex Trading Platform Australia

    Best 24/7 Customer Service Provider Australia

    Best Forex Broker Australia

    Most User-Friendly Trading Experience Australia

    “We are beyond proud and humbled to receive five awards from World Business Outlook Awards,” said Louis Cooper, CCO at Axi. “This recognition reflects and reinforces our mission to help our traders and partners gain the edge they need to stay ahead in this rapidly evolving industry. From providing the best-in-class trading platform and backing it up with top-tier customer service, we’re incredibly excited to see our efforts reaffirmed.”

    The latest accolade follows a series of other notable achievements for Axi. Earlier this year, Global Business and Finance Magazine Awards recognised Axi with the ‘Best Financial Institution 2025’ award for the UK, Middle East, and LatAm markets. In 2024, the broker received widespread industry acclaim with the ‘Innovator of the Year’ award at the 2024 Dubai Forex Expo. That same year, Axi was named Best Broker (MENA), Most Trusted Broker (LatAm), Most Reliable Broker (Europe), and Best Introducing Broker Program (Asia) by Global Forex Awards.

    About Axi

    Axi is a global online FX and CFD trading company, with thousands of customers in 100+ countries worldwide. Axi offers CFDs for several asset classes including Forex, Shares, Gold, Oil, Coffee, and more.

    For more information or additional comments from Axi, please contact: mediaenquiries@axi.com

    *These awards are granted to the Axi group of companies.

    The MIL Network –

  • MIL-OSI: TC Energy reports strong second quarter 2025 operating and financial results

    Source: GlobeNewswire (MIL-OSI)

    Solid execution and asset performance support higher 2025 financial outlook

    Market fundamentals drive customer demand for incremental capacity projects

    CALGARY, Alberta, July 31, 2025 (GLOBE NEWSWIRE) — TC Energy Corporation (TSX, NYSE: TRP) (TC Energy or the Company) released its second quarter results today. François Poirier, TC Energy’s President and Chief Executive Officer commented, “Our commitment to safety and operational excellence continues to drive strong reliability, availability and financial performance, and we now expect our 2025 comparable EBITDA1 outlook to be higher, in the range of $10.8 to $11.0 billion.” Poirier continued, “Compelling fundamentals are unlocking further growth opportunities across our North American portfolio. To meet this unprecedented demand, we have announced $4.5 billion of new growth projects over the past nine months, including requests for incremental capacity on projects already announced — a trend we’re seeing on several projects currently in development. Our focus on project execution is also delivering tangible results and we expect to place approximately $8.5 billion of capital projects into service this year, on time and are tracking approximately 15 per cent below budget. We remain highly confident in our disciplined strategy and our ability to capture high-value, low-risk opportunities across North America that drive long-term shareholder value.”

    Financial Highlights
    (All financial figures are unaudited and in Canadian dollars unless otherwise noted)

    • Second quarter 2025 financial results from continuing operations2:
      • Comparable earnings1 of $0.8 billion or $0.82 per common share compared to $0.8 billion or $0.79 per common share in second quarter 2024
      • Net income attributable to common shares of $0.9 billion or $0.83 per common share compared to $0.8 billion or $0.78 per common share in second quarter 2024
      • Comparable EBITDA of $2.6 billion, compared to $2.3 billion in second quarter 2024
      • Segmented earnings of $2.0 billion compared to $1.7 billion in second quarter 2024
    • 2025 outlook:
      • Comparable EBITDA is now expected to be higher, in the range of $10.8 to $11.0 billion3, compared to previous outlook of $10.7 to $10.9 billion
      • Comparable earnings per common share (EPS) outlook remains consistent with our 2024 Annual Report, and is expected to be lower than 2024
      • Capital expenditures are anticipated to be $6.1 to $6.6 billion on a gross basis, or $5.5 to $6.0 billion of net capital expenditures4
    • Declared a quarterly dividend of $0.85 per common share for the quarter ending September 30, 2025.

    Operational Highlights

    • Canadian Natural Gas Pipelines deliveries averaged 23.4 Bcf/d, up five per cent compared to second quarter 2024
      • Total NGTL System receipts set a new record of 15.5 Bcf on April 13, 2025
      • Canadian Mainline – Western receipts averaged 4.4 Bcf/d, up seven per cent compared to second quarter 2024
    • U.S. Natural Gas Pipelines daily average flows were 25.7 Bcf/d, in line with second quarter 2024
      • Deliveries to LNG facilities averaged 3.5 Bcf/d, up six per cent compared to second quarter 2024
    • Mexico Natural Gas Pipelines flows averaged 3.6 Bcf/d, three per cent higher than second quarter 2024
      • Set a daily flow record of 4.4 Bcf on April 22, 2025
    • Bruce Power achieved 98 per cent availability in second quarter 2025
    • Cogeneration power plant fleet achieved 93.4 per cent availability in second quarter 2025.

    Project Highlights

    • The Southeast Gateway pipeline is in service and we commenced the collection of tolls from the Comisión Federal de Electricidad (CFE) beginning May 2025. In July 2025, the newly constituted Comisión Nacional de Energía (CNE) approved our regulated rates required to provide service to potential future interruptible service users on the Southeast Gateway pipeline other than the CFE
    • The East Lateral XPress (ELXP) project, an expansion project on the Columbia Gulf system that connects supply to U.S. Gulf Coast LNG export markets, was placed in service in May 2025, with total project costs of approximately US$0.3 billion
    • On July 1, 2025, Columbia Gas notified FERC that it has reached a settlement-in-principle on the Columbia Gas Section 4 Rate Case. Columbia Gas expects the final settlement to include an increase relative to pre-filed rates, subject to revision following completion and approval of settlement terms, anticipated in fourth quarter 2025
    • Upsized capacity on the previously announced Maysville and Pulaski projects — mainline extension projects off Columbia Gulf — to support incremental load growth in the region, including data centre development
    • Reached positive FID on $0.4 billion of expansion projects as part of the Multi-Year Growth Plan (MYGP). With in-service dates expected in 2027, the projects are designed to serve system demand growth and new supply on the NGTL System.
     
      three months ended
    June 30    		   six months ended
    June 30
    (millions of $, except per share amounts)   2025       20241       2025       20241  
                   
    Income              
    Net income (loss) attributable to common shares from continuing operations   862       804       1,840       1,792  
    per common share – basic $ 0.83     $ 0.78     $ 1.77     $ 1.73  
                   
    Segmented earnings (losses)              
    Canadian Natural Gas Pipelines   551       514       1,067       1,015  
    U.S. Natural Gas Pipelines   907       762       2,016       1,805  
    Mexico Natural Gas Pipelines   191       266       402       478  
    Power and Energy Solutions   312       220       447       472  
    Corporate   (7 )     (26 )     (12 )     (87 )
    Total segmented earnings (losses)   1,954       1,736       3,920       3,683  
                   
    Comparable EBITDA from continuing operations              
    Canadian Natural Gas Pipelines   923       846       1,813       1,692  
    U.S. Natural Gas Pipelines   1,089       1,003       2,456       2,309  
    Mexico Natural Gas Pipelines   319       286       552       500  
    Power and Energy Solutions   301       227       525       547  
    Corporate   (7 )     (14 )     (12 )     (30 )
    Comparable EBITDA from continuing operations   2,625       2,348       5,334       5,018  
    Depreciation and amortization   (671 )     (633 )     (1,349 )     (1,268 )
    Interest expense   (847 )     (783 )     (1,687 )     (1,563 )
    Allowance for funds used during construction   114       184       362       341  
    Foreign exchange gains (losses), net included in comparable earnings   55       (51 )     45       (8 )
    Interest income and other   49       68       100       143  
    Income tax (expense) recovery included in comparable earnings   (294 )     (143 )     (586 )     (424 )
    Net (income) loss attributable to non-controlling interests included in comparable earnings   (155 )     (141 )     (332 )     (312 )
    Preferred share dividends   (28 )     (27 )     (56 )     (50 )
    Comparable earnings from continuing operations   848       822       1,831       1,877  
    Comparable earnings per common share from continuing operations $ 0.82     $ 0.79     $ 1.76     $ 1.81  

    1          Results reflect continuing operations.

           
      three months ended
    June 30    		   six months ended
    June 30
    (millions of $, except per share amounts)   2025     2024     2025     2024
                   
    Cash flows1              
    Net cash provided by operations2   2,173     1,655     3,532     3,697
    Comparable funds generated from operations2,3   1,964     1,874     3,913     4,310
    Capital spending4   1,379     1,591     3,188     3,488
    Disposition of equity interest, net of transaction costs5   —     464     —     426
    Dividends declared              
    per common share $ 0.85 6 $ 0.96   $ 1.70 6 $ 1.92
    Basic common shares outstanding(millions)              
    – weighted average for the period   1,040     1,037     1,040     1,037
    – issued and outstanding at end of period   1,040     1,037     1,040     1,037
    1. Includes continuing and discontinued operations.
    2. Includes Liquids Pipelines earnings for the three and six months ended June 30, 2024 compared to Liquids Pipelines earnings of nil for the same periods in 2025. Refer to the 2024 Annual Report for additional information.
    3. Comparable funds generated from operations is a non-GAAP measure used throughout this news release. This measure does not have any standardized meaning under GAAP and therefore is unlikely to be comparable to similar measures presented by other companies. The most directly comparable GAAP measure is net cash provided by operations. For more information on non-GAAP measures, refer to the Non-GAAP and Supplementary financial measure section of this news release.
    4. Capital spending reflects cash flows associated with our Capital expenditures, Capital projects in development and Contributions to equity investments. Refer to Note 4, Segmented information, of our Condensed consolidated financial statements for additional information.
    5. Included in the Financing activities section of the Condensed consolidated statement of cash flows.
    6. Reflects dividends declared following the Spinoff Transaction.

    CEO Message
    Through the first half of 2025, TC Energy safely and reliably delivered energy across North America, maximizing asset value through safety and operational excellence. Despite the volatility in commodity markets and a complex macroeconomic backdrop, our business continues to demonstrate resiliency, achieving 12 per cent growth in comparable EBITDA and 13 per cent growth in segmented earnings compared to second quarter 2024. Driven by strong performance and focused execution, we now expect our 2025 comparable EBITDA outlook to be higher, in the range of $10.8 to $11.0 billion, compared to the original outlook of $10.7 to $10.9 billion. We continue to advance our strategic priorities – executing a selective portfolio of growth projects, maintaining financial strength and agility, while maximizing the value of our assets through safety and operational excellence. Our performance continues to underscore the strength of our business model and our ability to consistently deliver solid growth, low risk and repeatable performance. TC Energy’s Board of Directors approved a quarterly common share dividend of $0.85 per common share for the quarter ending September 30, 2025, equivalent to $3.40 per common share on an annualized basis.

    Following the completion of the Southeast Gateway pipeline on schedule and under budget in the second quarter, we commenced the collection of tolls from the CFE beginning May 2025. This event represents a significant operational and financial milestone, and an important step for Mexico’s energy landscape and economic development. The Southeast Gateway pipeline is a transformative infrastructure project – serving as a critical artery for delivering natural gas to underserved regions in Southeast Mexico, driving economic growth and energy security while supporting the country’s transition to lower-emitting, more reliable sources of energy. In July, the newly constituted Comisión Nacional de Energía (CNE) approved our regulated rates required to provide service to potential future interruptible service users on the Southeast Gateway pipeline other than the CFE.

    As part of our ongoing efforts to maximize the value of our assets, on July 1, 2025, Columbia Gas notified FERC that it has reached a settlement-in-principle on the Columbia Gas Section 4 Rate Case. Columbia Gas expects the final settlement to include an increase relative to pre-filed rates, subject to revision following completion and approval of settlement terms, which we anticipate in fourth quarter 2025. This outcome on our second-largest pipeline asset demonstrates our ongoing commitment to enhance system integrity and service reliability while ensuring timely capital recovery to maximize our long-term cash flow profile.

    We continue to execute our growth projects on-time and are tracking 15 per cent below budget on approximately $8.5 billion of assets expected to be placed into service this year. Year to date, we have placed into service approximately $5.8 billion of natural gas pipeline capacity projects, including the Southeast Gateway pipeline. In May, we successfully placed the East Lateral XPress (ELXP) project into service. As a strategic expansion of the Columbia Gulf Transmission system, ELXP delivers approximately 0.7 Bcf/d of firm natural gas capacity directly to Venture Global’s Plaquemines LNG terminal in Louisiana, reinforcing our role in enabling reliable, long-term energy supply to global markets.

    Fundamentals continue to drive significant growth opportunities for the incremental build-out of natural gas infrastructure across LNG export, coal-to-gas conversions, data centre demand and LDC reliability. Reflecting this momentum, we reached a positive FID on $0.4 billion of expansion facilities as part of MYGP; a program comprised of multiple distinct projects with targeted in-service dates between 2027 and 2030, subject to final company and regulatory approvals. Once complete, MYGP is expected to enable approximately 1.0 Bcf/d of incremental system throughput – further enhancing our ability to connect natural gas supply from competitive, low-cost basins to critical demand markets across North America. Additionally, we have upsized capacity on our previously announced Maysville and Pulaski projects. In aggregate, over the past nine months we have announced $4.5 billion of new capital projects, each underpinned by long-term take or pay contracts with strong counterparties and delivering a weighted average build multiple5 in the 5-7 times range. Our origination pipeline remains robust, with both the volume and scale of opportunities continuing to grow. We are seeing increased demand across multiple end-use sectors, with customers seeking additional capacity to upsize their projects. We believe this trend reflects strong underlying market fundamentals and reinforces our confidence in the long-term need for safe, reliable and affordable natural gas infrastructure.

    Looking ahead, we have clear visibility into a steady cadence of project announcements in the second half of 2025 and into 2026. Maintaining commitment to our annual net capital expenditure range of $6.0 to $7.0 billion, the majority of incremental capital is expected to be allocated toward the latter part of the decade. Our strategy remains centred on advancing low-risk, brownfield projects, underpinned by long-term contracts with strong counterparties, delivering attractive build multiples. This disciplined approach supports organic comparable EBITDA growth, underpins our three to five per cent annual dividend growth target, and enables ongoing deleveraging as we manage to our long-term target of 4.75 times debt-to-EBITDA6 ratio. These efforts collectively reinforce our commitment to sustainable, long-term value creation for shareholders.

    Finally, we released our 2025 Report on Sustainability. The report reaffirms TC Energy’s role in a collective effort to advance a lower-emissions energy system and demonstrates how we’re aiming to strike a balance between meeting growing energy demand and addressing rising global emissions, while collaborating closely with Indigenous rights holders, customers, neighbors and governments across Canada, the U.S. and Mexico. Key highlights include:

    • Reduced absolute methane emissions by 12 per cent between 2019 and 2024 while increasing natural gas throughput by 15 per cent and comparable EBITDA in our natural gas business by 40 per cent
    • A continued focus on methane intensity reduction, targeting cost-effective abatement across jurisdictions
    • Achieved a five-year low in our High Energy Serious Injury and Fatality rate, demonstrating tangible progress in safeguarding our people and operations
    • Signed over 40 relationship agreements with Indigenous communities across NGTL and Foothills pipeline systems since 2020.

    Teleconference and Webcast
    We will hold a teleconference and webcast on Thursday, July 31, 2025 at 6:30 a.m. (MT) / 8:30 a.m. (ET) to discuss our second quarter 2025 financial results and Company developments. Presenters will include François Poirier, President and Chief Executive Officer; Sean O’Donnell, Executive Vice-President and Chief Financial Officer; and other members of the executive leadership team.

    Members of the investment community and other interested parties are invited to participate by calling 1-833-752-3826 (Canada/U.S. toll free) or 1-647-846-8864 (International toll). No passcode is required. Please dial in 15 minutes prior to the start of the call. Alternatively, participants may pre-register for the call here. Upon registering, you will receive a calendar booking by email with dial in details and a unique PIN. This process will bypass the operator and avoid the queue. Registration will remain open until the end of the conference call.

    A live webcast of the teleconference will be available on TC Energy’s website at TC Energy — Events and presentations or via the following URL: https://www.gowebcasting.com/13943. The webcast will be available for replay following the meeting.

    A replay of the teleconference will be available two hours after the conclusion of the call until midnight ET on August 7, 2025. Please call 1-855-669-9658 (Canada/U.S. toll free) or 1-412-317-0088 (International toll) and enter passcode 6101975.

    The unaudited interim Condensed consolidated financial statements and Management’s Discussion and Analysis (MD&A) are available on our website at www.TCEnergy.com and will be filed today under TC Energy’s profile on SEDAR+ at www.sedarplus.ca and with the U.S. Securities and Exchange Commission on EDGAR at www.sec.gov.

    About TC Energy
    We’re a team of 6,500+ energy problem solvers connecting the world to the energy it needs. Our extensive network of natural gas infrastructure assets is one-of-a-kind. We seamlessly move, generate and store energy and deliver it to where it is needed most, to home and businesses in North America and across the globe through LNG exports. Our natural gas assets are complemented by our strategic ownership and low-risk investments in power generation.

    TC Energy’s common shares trade on the Toronto (TSX) and New York (NYSE) stock exchanges under the symbol TRP. To learn more, visit us at www.TCEnergy.com.

    Forward-Looking Information
    This release contains certain information that is forward-looking and is subject to important risks and uncertainties and is based on certain key assumptions. Forward-looking statements are usually accompanied by words such as “anticipate”, “expect”, “believe”, “may”, “will”, “should”, “estimate” or other similar words. Forward-looking statements in this document may include, but are not limited to, statements related to expectations with respect to expected comparable EBITDA, comparable earnings in total and per common share and the sources thereof and anticipated capital expenditures, expectations with respect to the targeted debt-to-EBITDA leverage metric, expectations with respect to MYGP, including associated capital expenditures, timelines, and outcomes, expectations with respect to completed projects and expected impacts thereof, expectations with respect to the approximate value of projects to be placed in-service in 2025, expectations with respect to identified FERC rate cases, including timelines, processes and outcomes, expectations with respect to our strategic priorities, and the execution thereof, expectations with respect to our ability to maximize the value of our assets through safety and operational excellence, expected cost and schedules for planned projects, including projects under construction and in development and the associated capital expenditures, expectations about energy demand levels and drivers thereof, expectations about our ability to execute our identified portfolio of growth projects and ensure financial strength and agility, our ability to deliver solid growth, low risk and repeatable performance, our expected net capital expenditures, including timing, and expected industry, market and economic conditions, and ongoing trade negotiations, including their expected impact on our business, customers and suppliers. Our forward-looking information is subject to important risks and uncertainties and is based on certain key assumptions. Forward-looking statements and future-oriented financial information in this document are intended to provide TC Energy security holders and potential investors with information regarding TC Energy and its subsidiaries, including management’s assessment of TC Energy’s and its subsidiaries’ future plans and financial outlook. All forward-looking statements reflect TC Energy’s beliefs and assumptions based on information available at the time the statements were made and as such are not guarantees of future performance. As actual results could vary significantly from the forward-looking information, you should not put undue reliance on forward-looking information and should not use future-oriented information or financial outlooks for anything other than their intended purpose. We do not update our forward-looking information due to new information or future events, unless we are required to by law. For additional information on the assumptions made, and the risks and uncertainties which could cause actual results to differ from the anticipated results, refer to the most recent Quarterly Report to Shareholders and the 2024 Annual Report filed under TC Energy’s profile on SEDAR+ at www.sedarplus.ca and with the U.S. Securities and Exchange Commission at www.sec.gov and the “Forward-looking information” section of our Report on Sustainability which is available on our website at www.TCEnergy.com.

    Non-GAAP and Supplementary Financial Measure
    This release contains references to the following non-GAAP measures: comparable EBITDA, comparable earnings, comparable earnings per common share and comparable funds generated from operations. It also contains references to debt-to-EBITDA,a non-GAAP ratio, which is calculated using adjusted debt and adjusted comparable EBITDA, each of which are non-GAAP measures. These non-GAAP measures do not have any standardized meaning as prescribed by GAAP and therefore may not be comparable to similar measures presented by other entities. These non-GAAP measures are calculated by adjusting certain GAAP measures for specific items we believe are significant but not reflective of our underlying operations in the period. These comparable measures are calculated on a consistent basis from period to period and are adjusted for specific items in each period, as applicable except as otherwise described in the Condensed consolidated financial statements and MD&A. Refer to: (i) each business segment and the discontinued operations section for a reconciliation of comparable EBITDA to segmented earnings (losses); (ii) Consolidated results section and the discontinued operations section for reconciliations of comparable earnings and comparable earnings per common share to Net income attributable to common shares and Net income per common share, respectively; and (iii) Financial condition section for a reconciliation of comparable funds generated from operations to Net cash provided by operations. Refer to the Non-GAAP Measures section of the MD&A in our most recent quarterly report for more information about the non-GAAP measures we use. The MD&A is included with, and forms part of, this release. The MD&A can be found on SEDAR+ at www.sedarplus.ca under TC Energy’s profile.

    This release contains references to build multiple, which is non-GAAP ratio which is calculated using capital expenditures and comparable EBITDA, of which comparable EBITDA is a non-GAAP measure. We believe build multiple provides investors with a useful measure to evaluate capital projects.

    With respect to non-GAAP measures used in the calculation of debt-to-EBITDA, adjusted debt is defined as the sum of Reported total debt, including Notes payable, Long-term debt, Current portion of long-term debt and Junior subordinated notes, as reported on our Consolidated balance sheet as well as Operating lease liabilities recognized on our Consolidated balance sheet and 50 per cent of Preferred shares as reported on our Consolidated balance sheet due to the debt-like nature of their contractual and financial obligations, less Cash and cash equivalents as reported on our Consolidated balance sheet and 50 per cent of Junior subordinated notes as reported on our Consolidated balance sheet due to the equity-like nature of their contractual and financial obligations. Adjusted comparable EBITDA is calculated as the sum of comparable EBITDA from continuing operations and comparable EBITDA from discontinued operations excluding Operating lease costs recorded in Plant operating costs and other in our Consolidated statement of income and adjusted for Distributions received in excess of (income) loss from equity investments as reported in our Consolidated statement of cash flows which we believe is more reflective of the cash flows available to TC Energy to service our debt and other long-term commitments. We believe that debt-to-EBITDA provides investors with useful information as it reflects our ability to service our debt and other long-term commitments. See the Reconciliation section for reconciliations of adjusted debt and adjusted comparable EBITDA for the years ended December 31, 2022, 2023 and 2024.

    This release also contains references to net capital expenditures, which is a supplementary financial measure. Net capital expenditures represent capital costs incurred for growth projects, maintenance capital expenditures, contributions to equity investments and projects under development, adjusted for the portion attributed to non-controlling interests in the entities we control. Net capital expenditures reflect capital costs incurred during the period, excluding the impact of timing of cash payments. We use net capital expenditures as a key measure in evaluating our performance in managing our capital spending activities in comparison to our capital plan.

    Reconciliation
    The following is a reconciliation of adjusted debt and adjusted comparable EBITDAi.

      year ended December 31
    (millions of Canadian $) 2024     2023     2022  
               
    Reported total debt 59,366     63,201     58,300  
    Management adjustments:          
    Debt treatment of preferred sharesii 1,250     1,250     1,250  
    Equity treatment of junior subordinated notesiii (5,524 )   (5,144 )   (5,248 )
    Cash and cash equivalents (801 )   (3,678 )   (620 )
    Operating lease liabilities 511     457     430  
    Adjusted debt 54,802     56,086     54,112  
               
    Comparable EBITDA from continuing operationsiv 10,049     9,472     8,483  
    Comparable EBITDA from discontinued operationsiv 1,145     1,516     1,418  
    Operating lease costs 117     105     95  
    Distributions received in excess of (income) loss from equity investments 67     (123 )   (29 )
    Adjusted Comparable EBITDA 11,378     10,970     9,967  
               
    Adjusted Debt/Adjusted Comparable EBITDAi 4.8     5.1     5.4  
    i Adjusted debt and adjusted comparable EBITDA are non-GAAP measures. The calculations are based on management methodology. Individual rating agency calculations will differ.
    ii 50 per cent debt treatment on $2.5 billion of preferred shares as of December 31, 2024.
    iii 50 per cent equity treatment on $11.0 billion of junior subordinated notes as of December 31, 2024. U.S. dollar-denominated notes translated at December 31, 2024, USD/CAD foreign exchange rate of 1.44.
    iv Comparable EBITDA from continuing operations and Comparable EBITDA from discontinued operations are non-GAAP financial measures. See the Forward-looking information and Non-GAAP measures sections in our 2024 Annual Report for more information. Comparable EBITDA from discontinued operations represents nine months of Liquids Pipelines earnings in 2024 compared to a full year of Liquids Pipelines earnings in 2023. Refer to the Discontinued operations section in our 2024 Annual Report for additional information.
       

    Media Inquiries:
    Media Relations
    media@tcenergy.com
    403.920.7859 or 800.608.7859

    Investor & Analyst Inquiries:
    Gavin Wylie / Hunter Mau
    investor_relations@tcenergy.com
    403.920.7911 or 800.361.6522

    Download full report here: https://www.tcenergy.com/siteassets/pdfs/investors/reports-and-filings/annual-and-quarterly-reports/2025/tce-2025-q2-quarterly-report.pdf

    1 Comparable EBITDA, comparable earnings and comparable earnings per common share are non-GAAP measures used throughout this news release. These measures do not have any standardized meaning under GAAP and therefore are unlikely to be comparable to similar measures presented by other companies. The most directly comparable GAAP measures are Segmented earnings, Net income attributable to common shares and Net income per common share, respectively. We do not forecast Segmented earnings. For more information on non-GAAP measures, refer to the Non-GAAP and Supplementary financial measure section of this news release.

    2 Prior year results have been recast to reflect the Liquids Pipelines business as a discontinued operation as a result of the Spinoff Transaction.

    3 Based on USD/CAD foreign exchange rate of 1.35 for the second half of 2025.

    4 Net capital expenditures are adjusted for the portion attributed to non-controlling interests and is a supplementary financial measure used throughout this news release. For more information on non-GAAP measures and the supplementary financial measure, refer to the Non-GAAP and Supplementary financial measure section of this news release.

    5 Build multiple is a non-GAAP ratio calculated by dividing capital expenditures by comparable EBITDA. Please note our method for calculating build multiple may differ from methods used by other entities. Therefore, it may not be comparable to similar measures presented by other entities. For more information on non-GAAP measures and the supplementary financial measure, refer to the Non-GAAP and Supplementary financial measure section of this news release.

    6 Debt-to-EBITDA is a non-GAAP ratio. Adjusted debt and adjusted comparable EBITDA are non-GAAP measures used to calculate debt-to-EBITDA. For more information on non-GAAP measures, refer to the non-GAAP and Supplementary financial measure section of this news release. These measures do not have any standardized meaning under GAAP and therefore are unlikely to be comparable to similar measures presented by other companies.

    The MIL Network –

  • MIL-OSI: Brazil’s Grupo Petrópolis Uses Descartes Routing Solution to Optimize Nationwide Beverage Distribution

    Source: GlobeNewswire (MIL-OSI)

    SÃO PAULO and ATLANTA, July 31, 2025 (GLOBE NEWSWIRE) — Descartes Systems Group (Nasdaq:DSGX) (TSX:DSG), the global leader in uniting logistics-intensive businesses in commerce, announced that Brazil’s Grupo Petrópolis is using Descartes’ routing and fleet management solution to enhance its nationwide beverage distribution operations using approximately 2,900 vehicles. The Descartes solution helped Grupo Petrópolis achieve an on-time delivery rate of 98%, reduce overtime hours by 9% and decrease fuel consumption by 5%. These improvements reflect more efficient and sustainable fleet operations.

    “To better meet customer needs, we wanted a fleet management platform to enhance on-time performance, improve service in case of returns or customer concerns and advance sustainability goals by reducing carbon emissions,” said Luís Moura, Manager at Grupo Petrópolis. “The Descartes solution gives us a new level of control and visibility into our large distribution network. Across 160 locations, routes are now more intelligent and efficient, and we track all routes in real-time. If a driver goes off a planned route, the system immediately signals the detour so our team can respond quickly, which is critical to providing reliable service. And, because we can act with much more delivery precision and agility, we have lowered fuel and maintenance costs, gained visibility into idle vehicles and overcome challenges with product and delivery traceability.”

    Part of Descartes’ routing, mobile and telematics solution suite, the Descartes routing and fleet management solution helps retail food and beverage distribution companies, like Grupo Petrópolis, manage routes for optimal efficiency and minimize the impact of unforeseen events on customer service levels, mileage and costs. By continually re-optimizing route plans based on real-time traffic data and other variables, the solution enhances customer service by improving on-time delivery performance, lowers mileage by guiding drivers through shorter route paths, and decreases total route time and costs by helping drivers navigate through heavy traffic with alternate routes and stop sequences. The solution also monitors planned vs. actual deliveries, product traceability, journey control (including lunch breaks, overnights and overtime), route deviations, unplanned stops and departure or arrival delays.

    “Our collaboration with Grupo Petrópolis highlights how advanced routing solutions can help transform complex distribution environments into highly efficient, sustainable, and customer-focused logistics operations,” said Douglas Alves, Sales Executive at Descartes. “As food and beverage distributors look for opportunities to enhance last mile performance, our solution suite can help rebalance distribution networks; improve route productivity, execution and sustainability; respond more dynamically to demand; and accelerate cash flow with electronic proof-of-delivery.”

    Learn more about Descartes’ route execution and fleet performance management solutions and its Routing, Mobile and Telematics solution suite.

    About Grupo Petrópolis

    Grupo Petrópolis is the only major company in the beer sector with 100% Brazilian capital. It produces the beer brands Itaipava, Crystal, Petra, Black Princess, Cacildis, Cabaré, Lokal, and Weltenburger; the vodkas Blue Spirit Ice and Nordka; Cabaré Ice; the energy drinks TNT Energy Drink and Magneto; the liquid dietary supplement TNT Sports Drink; Petra mineral water; Petra tonic; and the soft drink It!. Through environmental projects, it promotes the planting and maintenance of thousands of trees, as well as sustainability initiatives and environmental education projects for public schools. Learn more at www.grupopetropolis.com.br and on LinkedIn.

    About Descartes

    Descartes (Nasdaq:DSGX) (TSX:DSG) is the global leader in providing on-demand, software-as-a-service solutions focused on improving the productivity, security and sustainability of logistics-intensive businesses. Customers use our modular, software-as-a-service solutions to route, track and help improve the safety, performance and compliance of delivery resources; plan, allocate and execute shipments; rate, audit and pay transportation invoices; access global trade data; file customs and security documents for imports and exports; and complete numerous other logistics processes by participating in the world’s largest, collaborative multimodal logistics community. Our headquarters are in Waterloo, Ontario, Canada and we have offices and partners around the world. Learn more at www.descartes.com, and connect with us on LinkedIn and Twitter.

    Global Media Contact
    Cara Strohack                                                                     
    Tel: 226-750-8050                                 
    cstrohack@descartes.com  

    Cautionary Statement Regarding Forward-Looking Statements

    This release contains forward-looking information within the meaning of applicable securities laws (“forward-looking statements”) that relate to Descartes’ routing, mobile and telematics solution offerings and potential benefits derived therefrom; and other matters. Such forward-looking statements involve known and unknown risks, uncertainties, assumptions and other factors that may cause the actual results, performance or achievements to differ materially from the anticipated results, performance or achievements or developments expressed or implied by such forward-looking statements. Such factors include, but are not limited to, the factors and assumptions discussed in the section entitled, “Certain Factors That May Affect Future Results” in documents filed with the Securities and Exchange Commission, the Ontario Securities Commission and other securities commissions across Canada including Descartes’ most recently filed management’s discussion and analysis. If any such risks actually occur, they could materially adversely affect our business, financial condition or results of operations. In that case, the trading price of our common shares could decline, perhaps materially. Readers are cautioned not to place undue reliance upon any such forward-looking statements, which speak only as of the date made. Forward-looking statements are provided for the purposes of providing information about management’s current expectations and plans relating to the future. Readers are cautioned that such information may not be appropriate for other purposes. We do not undertake or accept any obligation or undertaking to release publicly any updates or revisions to any forward-looking statements to reflect any change in our expectations or any change in events, conditions or circumstances on which any such statement is based, except as required by law.

    The MIL Network –

  • MIL-OSI United Kingdom: Dr Simone Lowthe-Thomas reappointed to The National Lottery Community Fund

    Source: United Kingdom – Executive Government & Departments

    News story

    Dr Simone Lowthe-Thomas reappointed to The National Lottery Community Fund

    The Secretary of State has reappointed Dr Simone Lowthe-Thomas as Board Member to The National Lottery Community Fund and Chair of the Wales Committee for 4 years from 1 July 2025 to 30 June 2029.

    Dr Simone Lowthe-Thomas

    Starting life as an ecologist and then working on sustainable energy, community

    regeneration and sustainable development, Simone has been working with communities, businesses, government and academia for over 25 years. Currently Director for Nature and Climate at Bannau Brycheiniog (Brecon Beacons) National Park, Simone is working in partnership to accelerate a response to our climate, water and nature crises, in a way that works for both people and the natural world.

    Previous experience and roles include CEO at Severn Wye Energy Agency (a Fuel Poverty and Sustainable Energy Charity), Vice-President of Fedarene (European Federation of Energy Agencies), Founding Member of Community Energy Wales and as a Research Associate and Manager of Wales Biomass Centre (Cardiff University Research Centre on Bioenergy).

    Simone brings a very practical community based background and expertise in developing approaches to engagement and involvement having supported and developed some of the first community owned energy schemes, ‘Cynefin’ a Welsh Government Programme which demonstrate co-production and place-based approaches, and working with the Wellbeing of Future Generations Commissioners Office to develop guidance for the ways of working (Sustainable Development Principles).She has held voluntary roles including as Chair of Governors and has been a STEM Ambassador for 25 years.

    Updates to this page

    Published 31 July 2025

    MIL OSI United Kingdom –

  • MIL-OSI: Glasswing Ventures Expands Exclusive Advisory Network to Accelerate AI-Native Portfolio Success

    Source: GlobeNewswire (MIL-OSI)

    BOSTON, July 31, 2025 (GLOBE NEWSWIRE) — Glasswing Ventures, a first capital-in investor in startups applying AI and frontier technology to the enterprise and cybersecurity markets, today announced the appointment of 12 distinguished business and security leaders to its Connect and Protect Advisory Councils. The appointments bring the firm’s exclusive advisor count to 62, reinforcing Glasswing’s position as the definitive catalyst for founders building the next generation of intelligent enterprise and security solutions.

    The AI-Native & Vertical AI Advantage
    Glasswing Ventures invests in AI-native companies — companies that build AI into their core, leveraging proprietary models, deep workflow intelligence, and unique data access to unlock new revenue models and customer ROI that is unattainable with traditional SaaS models. Glasswing portfolio companies deliver purpose-built platforms designed to execute complex, multi-step tasks that redefine how enterprises operate across critical verticals, including supply chain orchestration, threat intelligence, procurement optimization, and data productivity acceleration.

    ABI Research projects that the AI market will surge to $467 billion by 2030. As demand for enterprise automation accelerates, vertical AI agents are emerging as critical differentiators that seamlessly integrate industry expertise with advanced automation capabilities. This convergence creates unprecedented opportunities for startups that understand both the technology and the domain-specific challenges they are solving.

    The Collective Advisor Impact
    Glasswing’s Advisory Councils are an exclusive, curated network of technologists, AI visionaries, successful entrepreneurs, and Fortune 500 executives who share strategic insight and operational expertise with the firm. Advisors include technology leaders and go-to-market executives from companies such as Google, Meta, and Salesforce, and academics from top-tier universities like the Massachusetts Institute of Technology, Harvard Business School, and the University of California, Berkeley.

    Glasswing advisors have founded 48 companies, secured 305 patents, and published 4,582 papers, culminating in an unmatched depth of intellectual property and thought leadership in AI and frontier technologies.

    “We invest in exceptional entrepreneurs who aren’t just applying AI—they are harnessing it to revolutionize enterprise and security software across vertical industries, delivering superior customer value that creates sustainable competitive advantages,” said Rudina Seseri, Founder and Managing Partner of Glasswing Ventures. “The appointment of our 12 additional Advisory Council members reinforces our commitment to maintaining a leadership position in the AI and frontier tech investment space, ensuring portfolio companies have access to the strategic guidance and industry connections necessary to transform their respective markets.”

    Beyond Capital: The Glasswing Multiplier Effect
    As prototypical end users for many of the firm’s portfolio companies, Glasswing’s advisors serve as a critical resource for accelerating the adoption of new AI and frontier tech products. They help founders prioritize the right product improvements, foster connections within the industry, and drive revenue. This hands-on approach creates a multiplier effect, where portfolio companies benefit from the combined decades of industry experience and extensive professional networks.

    “Our commitment to our companies extends beyond capital,” said Rick Grinnell, Founder and Managing Partner, Glasswing Ventures. “We aim to be our founders’ most trusted resource, fostering alignment and mutual success. Through our deep advisor relationships, we provide unparalleled access to customers, talent, and expertise, enabling our portfolio companies to achieve their full potential as they reinvent entire industries.”

    Glasswing Ventures’ Advisory Councils
    Glasswing’s advisors serve as an extension of the firm, providing tactical and nuanced guidance throughout every phase of the startup journey. They include:

    • Connect Council: Business leaders, academics, and AI pioneers providing expertise across business functions, from go-to-market strategy to breakthrough technological innovation.
    • Protect Council: Cybersecurity, regulatory compliance, and risk management leaders dedicated to leveraging frontier technology to secure enterprise organizations.

    Advisor Executive Appointments:

    • Wendy Batchelder, Senior Vice President & Chief Data Officer, Centene Corporation
    • Anand Devendran, Chief Growth Officer, Inrupt
    • Didi Dotan, Senior Director of Engineering, Cisco
    • Derya Isler, Vice President, AI Applications, Salesforce
    • Michael Israel, Chief Information & Technology Officer, The Kraft Group & Affiliates
    • Rich James, Senior Staff Software Engineer, Google
    • Jigar Kadakia, SVP, Head of Information and Data Security, GeneDx
    • Jayanthi Pillutla, SVP of Data, AI/ML, Engineering, Stitch Fix
    • Alyssa Robinson, Chief Information Security Officer, HubSpot
    • Kevin Routhier, Former Founder, President & CEO, Coretelligent
    • Dwayne Smith, Senior Vice President, Information Security and Global Chief Information Security Officer, Vensure Employer Solutions
    • Aaron Weismann, Chief Information Security Officer, Main Line Health

    “Glasswing’s advisors consistently go above and beyond in helping us navigate the complexities of our business environment, from refining our data strategies to identifying innovative solutions aligned with our goals and providing introductions to key decision-makers,” said Scott Matthews, CEO of Verusen, an AI platform purpose-built to optimize inventory spend and risk for asset-intensive manufacturers’ MRO (maintenance, repair and operations) supply chain. “Their expertise is pivotal to addressing today’s key challenges, particularly leveraging new technology and fostering meaningful partnerships that drive growth and operational excellence.”

    “The contributions from Glasswing’s Protect Council advisors have been transformative,” said Paul Paget, CEO of Black Kite, the AI-native platform for cyber risk detection and response in companies’ supply chains. “The advisors have introduced us to more than a dozen enterprises and large prospects, the majority of whom have become customers.”

    About Glasswing Ventures:
    Glasswing Ventures is a first-capital-in venture capital firm dedicated to investing in startups applying AI and frontier technology to enterprise and cybersecurity markets. The firm was founded by visionary partners with decades of experience in these markets, a disciplined investment approach, and a strong track record of industry-leading returns. Glasswing leverages its deep domain expertise and world-leading advisory councils to invest in exceptional founders who transform markets and revolutionize industries. Visit Glasswing Ventures for more information.

    PR Contact:
    Ilona Mohacsi
    PenVine for Glasswing Ventures
    ilonam@penvine.com
    +1 631 764 3729

    The MIL Network –

  • MIL-OSI Africa: Op-Ed: Financing Energy Access in Africa: Leveraging Fossil Fuel Revenues to End Energy Poverty (By NJ Ayuk)

    Source: APO – Report:

    NJ Ayuk, Executive Chairman of the African Energy Chamber (https://EnergyChamber.org)

    In an emissions-focused world, do oil and gas revenues have a role to play in ending energy poverty in Africa? It may sound counterintuitive, but many would argue that they do, albeit as enablers of a future powered by alternative energy sources.

    The key lies in recognizing that Africa’s situation is unique, and solutions take time, building on what we have and what we can do with it. This means that, in working towards a just energy transition, the continent’s oil and gas resources shouldn’t be viewed as obstacles that need to be immediately replaced by renewable energy sources. Instead, rather than prematurely phasing out fossil fuels in response to global pressure, Africa should harness these revenues responsibly to finance its energy transition and ultimately eradicate energy poverty.

    Prioritizing Development Alongside Sustainability

    Nearly 600 million Africans still live without access to electricity (https://apo-opa.co/3U6V4uH). This access is a fundamental human right, yet energy poverty remains one of the continent’s most significant barriers to development. This undermines health systems, education, industrialization, and dignity. As the world debates how to rapidly achieve net-zero, Africa’s priority is different: how to power its people now, while building a sustainable future.

    Measuring Africa’s energy transition progress against external calls for an abrupt end to fossil fuels risks leaving millions behind. Our continent contributes less than 4% (https://apo-opa.co/4odEQxF) to global emissions, yet we are expected to decarbonize at the same pace as industrialized nations that built their wealth on hydrocarbons.

    Instead, the continent’s abundance of fossil fuels should be viewed as a bridge, not a barrier. The African Energy Chamber (AEC) Africa-Paris Declaration (https://apo-opa.co/3GO1ImM) underscores this principle – Africa’s oil and gas revenues can and must be used as a financial lever to invest in electrification, clean energy, and infrastructure projects. This pragmatic and just approach prioritizes development alongside sustainability, not instead of.

    There are several ways to achieve this. First, reinvesting oil and gas revenues into rural electrification can transform communities. Decentralized solutions like off-grid solar and mini-grids offer practical ways to reach remote areas. Although urban dwellers do experience power outages, for many rural populations, it’s a way of life. For the mother cooking with firewood or the student studying by candlelight, a small solar grid is life-changing. Fossil fuel revenues can finance these systems at scale, bridging the immediate access gap while longer-term grid expansions are in progress.

    Second, establishing innovative financing mechanisms is essential. For instance, the fledgling Africa Energy Bank (https://apo-opa.co/4l5R2Of) aims to bridge the continent’s estimated $31 billion to $50 billion annual energy funding gap by focusing predominantly on financing energy projects. Launched in 2025, the bank is poised to play a transformative role in mobilizing capital for African energy projects. Additionally, global investors are increasingly exploring energy investment opportunities in Africa. In support of this, development finance institutions, such as the African Development Bank, the World Bank, and the International Finance Corporation, are de-risking investments by offering concessional loans, guarantees, and technical assistance, making investment in African energy projects more attractive. 

    Third, policy reforms that create enabling environments are critical. Here, governments have a role to play in prioritizing revenue-generating projects, creating stable regulatory frameworks, and offering incentives for public-private partnerships. This will support investment, reduce risks, and unlock the transformative power of energy access.

    These solutions demonstrate the importance of a fair and equitable transition and the vital role that fossil fuels will continue to play in achieving this goal. They also prove that this goal is achievable, even if it is on the continent’s own terms.

    Unique Solutions to Africa’s Energy Challenges

    Africa’s path to net-zero has the same end goal as the rest of the world, but it can’t mirror their journey. Our starting points are different, and our development needs are urgent. We understand that climate action can’t be delayed. But it can be just, inclusive, and rooted in African realities. And it can also be supported by revenues from our abundant natural resources.  

    The Africa-Paris Declaration notes that ‘a fair transition recognizes that fossil fuels remain valuable for Africa’s development, prosperity, and energy access goals. Africa doesn’t need to choose between oil and gas or renewables. Given our current position, all are important and require both strategic and sensible deployment. Fossil fuels generate the revenues to invest in solar, wind, hydropower, and grid infrastructure. They fuel industries that create jobs. They support healthcare, education, and innovation.

    When managed responsibly, Africa’s fossil fuel revenue can serve as a bridge to a brighter, greener, and more prosperous continent. Will it be quick and easy? No. Will some question the approach? Most certainly. But the alternative is leaving hundreds of millions of people in the dark.

    – on behalf of African Energy Chamber.

    Media files

    .

    MIL OSI Africa –

  • MIL-OSI: Orrön Energy announces the sale of a 76 MW solar project in Germany

    Source: GlobeNewswire (MIL-OSI)

    Orrön Energy AB (“Orrön Energy” or “the Company”) is pleased to announce that it has entered into an agreement with Saxovent Renewables to sell a 76 MW solar project in Germany, for a total consideration of MEUR 4.0. The consideration paid at closing is MEUR 2.0, with the remaining consideration contingent upon municipal and legislative approvals.

    The project is located in the northeastern part of Germany, and is being developed as an agrivoltaic (Agri-PV) project, enabling agricultural activities to take place alongside solar power generation. Half of the total consideration of MEUR 4.0 is paid at closing, which is expected imminently. The contingent consideration of MEUR 2.0 is subject to the fulfilment of two conditions: (i) municipal approval of the zoning plan (Satzungsbeschluss) and (ii) EU Commission approval of the German Solar Package 1 legislation.

    The transaction forms part of the Company’s strategy to monetise early-stage projects from its greenfield portfolio to diversify and enhance revenue streams.

    Daniel Fitzgerald, CEO for Orrön Energy commented;
    “I am very pleased to announce the first sale from our greenfield portfolio in Germany, which demonstrates our ability to unlock value early in the development cycle and marks an important step in delivering on our strategy. Germany remains one of our key markets for greenfield projects, with a strong demand for renewable energy and a supportive regulatory framework. I expect this to be the first in a series of project sales, as we continue to develop and mature our greenfield pipeline and deliver long-term value from this platform.”

    The Company’s CEO, Daniel Fitzgerald, and CFO, Espen Hennie, will host a webcast to comment on the six-month financial report on 6 August 2025 at 14:00 CEST. During the webcast, they will present this transaction along with the latest developments at Orrön Energy, followed by a question-and-answer session.

    Registration for the webcast presentation is available on the website and the below link:
    https://orron-energy.events.inderes.com/q2-report-2025

    For further information, please contact:

    Robert Eriksson
    Corporate Affairs and Investor Relations
    Tel: +46 701 11 26 15
    robert.eriksson@orron.com

    Jenny Sandström
    Communications Lead
    Tel: +41 79 431 63 68
    jenny.sandstrom@orron.com

    This is information that Orrön Energy AB is required to make public pursuant to the EU Market Abuse Regulation. The information was submitted for publication, through the contact person set out above, at 13.25 (CEST) on 31 July 2025.

    Orrön Energy is an independent, publicly listed (Nasdaq Stockholm: “ORRON”) renewable energy company within the Lundin Group of Companies. Orrön Energy’s core portfolio consists of high quality, cash flow generating assets in the Nordics, coupled with greenfield growth opportunities in the Nordics, the UK, Germany, and France. With significant financial capacity to fund further growth and acquisitions, and backed by a major shareholder, management and Board with a proven track record of investing into, leading and growing highly successful businesses, Orrön Energy is in a unique position to create shareholder value through the energy transition.

    Saxovent Renewables GmbH & Co. KG is an independent project developer, operator, and investor in renewable energy based in Berlin and a wholly owned subsidiary of the investment company Saxovent Smart Eco Investments GmbH. As an experienced full-line provider, Saxovent Renewables covers the entire value chain in the field of renewable energies, from development and implementation to the long-term operation of the plants.

    Forward-looking statements
    Statements in this press release relating to any future status or circumstances, including statements regarding future performance, growth and other trend projections, are forward-looking statements. These statements may generally, but not always, be identified by the use of words such as “anticipate”, “believe”, “expect”, “intend”, “plan”, “seek”, “will”, “would” or similar expressions. By their nature, forward-looking statements involve risk and uncertainty because they relate to events and depend on circumstances that could occur in the future. There can be no assurance that actual results will not differ materially from those expressed or implied by these forward-looking statements due to several factors, many of which are outside the company’s control. Any forward-looking statements in this press release speak only as of the date on which the statements are made and the company has no obligation (and undertakes no obligation) to update or revise any of them, whether as a result of new information, future events or otherwise.

    Attachment

    The MIL Network –

  • MIL-OSI: DT Midstream Reports Strong Second Quarter 2025 Results

    Source: GlobeNewswire (MIL-OSI)

    DETROIT, July 31, 2025 (GLOBE NEWSWIRE) — DT Midstream, Inc. (NYSE: DTM) today announced second quarter 2025 reported net income of $107 million, or $1.04 per diluted share. For the second quarter of 2025, Operating Earnings were also $107 million, or $1.04 per diluted share. Adjusted EBITDA for the quarter was $277 million.

    Reconciliations of Operating Earnings and Adjusted EBITDA (non-GAAP measures) to reported net income are included at the end of this news release.

    The company also announced that the DT Midstream Board of Directors declared a $0.82 per share dividend on its common stock payable October 15, 2025 to stockholders of record at the close of business September 15, 2025.

    “We had another strong quarter, and the business is performing on track with our full-year plan,” said David Slater, President and CEO. “We continue to make great progress advancing organic projects from our backlog, with $0.6 billion of projects reaching final investment decisions during the second quarter.”

    Slater noted the following significant business updates:

    • Reached a final investment decision on Guardian Pipeline “G3” expansion of approximately 210 MMcf/d
    • Finalized our investment plan for the initial phase of modernization across our new interstate pipelines
    • Achieved an investment-grade credit rating with all three rating agencies
    • Established a record high quarterly gathering volume for our Haynesville system

    “Our second quarter results put us in a strong position to meet our financial goals for 2025 and we are reaffirming our 2025 Adjusted EBITDA guidance of $1.095 to $1.155 billion and our 2026 Adjusted EBITDA early outlook range of $1.155 to $1.225 billion,” said Jeff Jewell, Executive Vice President and CFO.

    The company has scheduled a conference call to discuss results for 9:00 a.m. ET (8:00 a.m. CT) today. Investors, the news media and the public may listen to a live internet broadcast of the call at this link. The participant toll-free telephone dial-in number in the U.S. and Canada is 888.596.4144, and the toll number is 646.968.2525; the passcode is 9881735. International access numbers are available here. The webcast will be archived on the DT Midstream website at investor.dtmidstream.com.

    About DT Midstream

    DT Midstream (NYSE: DTM) is an owner, operator and developer of natural gas interstate and intrastate pipelines, storage and gathering systems, compression, treatment and surface facilities. The company transports clean natural gas for utilities, power plants, marketers, large industrial customers and energy producers across the Southern, Northeastern and Midwestern United States and Canada. The Detroit-based company offers a comprehensive, wellhead-to-market array of services, including natural gas transportation, storage and gathering. DT Midstream is transitioning towards net zero greenhouse gas emissions by 2050, including a plan of achieving 30% of its carbon emissions reduction by 2030. For more information, please visit the DT Midstream website at www.dtmidstream.com.

    Why DT Midstream Uses Operating Earnings, Adjusted EBITDA and Distributable Cash Flow

    Use of Operating Earnings Information – Operating Earnings exclude non-recurring items, certain mark-to-market adjustments and discontinued operations. DT Midstream management believes that Operating Earnings provide a more meaningful representation of the company’s earnings from ongoing operations and uses Operating Earnings as the primary performance measurement for external communications with analysts and investors. Internally, DT Midstream uses Operating Earnings to measure performance against budget and to report to the Board of Directors.

    Adjusted EBITDA is defined as GAAP net income attributable to DT Midstream before expenses for interest, taxes, depreciation and amortization, and loss from financing activities, further adjusted to include the proportional share of net income from equity method investees (excluding interest, taxes, depreciation and amortization), and to exclude certain items the company considers non-routine. DT Midstream believes Adjusted EBITDA is useful to the company and external users of DT Midstream’s financial statements in understanding operating results and the ongoing performance of the underlying business because it allows management and investors to have a better understanding of actual operating performance unaffected by the impact of interest, taxes, depreciation, amortization and non-routine charges noted in the table below. We believe the presentation of Adjusted EBITDA is meaningful to investors because it is frequently used by analysts, investors and other interested parties in the midstream industry to evaluate a company’s operating performance without regard to items excluded from the calculation of such measure, which can vary substantially from company to company depending on accounting methods, book value of assets, capital structure and the method by which assets were acquired, among other factors. DT Midstream uses Adjusted EBITDA to assess the company’s performance by reportable segment and as a basis for strategic planning and forecasting.

    Distributable Cash Flow (DCF) is calculated by deducting earnings from equity method investees, depreciation and amortization attributable to noncontrolling interests, cash interest expense, maintenance capital investment (as defined below), and cash taxes from, and adding interest expense, income tax expense, depreciation and amortization, certain items we consider non-routine and dividends and distributions from equity method investees to, Net Income Attributable to DT Midstream. Maintenance capital investment is defined as the total capital expenditures used to maintain or preserve assets or fulfill contractual obligations that do not generate incremental earnings. We believe DCF is a meaningful performance measurement because it is useful to us and external users of our financial statements in estimating the ability of our assets to generate cash earnings after servicing our debt, paying cash taxes and making maintenance capital investments, which could be used for discretionary purposes such as common stock dividends, retirement of debt or expansion capital expenditures.

    In this release, DT Midstream provides 2025 and 2026 Adjusted EBITDA guidance. The reconciliation of net income to Adjusted EBITDA as projected for full-year 2025 and 2026 is not provided. DT Midstream does not forecast net income as it cannot, without unreasonable efforts, estimate or predict with certainty the components of net income. These components, net of tax, may include, but are not limited to, impairments of assets and other charges, divestiture costs, acquisition costs, or changes in accounting principles. All of these components could significantly impact such financial measures. At this time, DT Midstream is not able to estimate the aggregate impact, if any, of these items on future period reported earnings. Accordingly, DT Midstream is not able to provide a corresponding GAAP equivalent for Adjusted EBITDA.

    Forward-looking Statements

    This release contains statements which, to the extent they are not statements of historical or present fact, constitute “forward-looking statements” under the securities laws. These forward-looking statements are intended to provide management’s current expectations or plans for our future operating and financial performance, business prospects, outcomes of regulatory proceedings, market conditions, and other matters, based on what we believe to be reasonable assumptions and on information currently available to us.

    Forward-looking statements can be identified by the use of words such as “believe,” “expect,” “expectations,” “plans,” “strategy,” “prospects,” “estimate,” “project,” “target,” “anticipate,” “will,” “should,” “see,” “guidance,” “outlook,” “confident” and other words of similar meaning. The absence of such words, expressions or statements, however, does not mean that the statements are not forward-looking. In particular, express or implied statements relating to future earnings, cash flow, results of operations, uses of cash, tax rates and other measures of financial performance, future actions, conditions or events, potential future plans, strategies or transactions of DT Midstream, and other statements that are not historical facts, are forward-looking statements.

    Forward-looking statements are not guarantees of future results and conditions, but rather are subject to numerous assumptions, risks, and uncertainties that may cause actual future results to be materially different from those contemplated, projected, estimated, or budgeted. Many factors may impact forward-looking statements of DT Midstream including, but not limited to, the following: changes in general economic conditions, including increases in interest rates and associated Federal Reserve policies, a potential economic recession, and the impact of inflation on our business; industry changes, including the impact of consolidations, alternative energy sources, technological advances, infrastructure constraints and changes in competition; changes in global trade policies and tariffs; global supply chain disruptions; actions taken by third-party operators, producers, processors, transporters and gatherers; changes in expected production from Expand Energy and other third parties in our areas of operation; demand for natural gas gathering, transmission, storage, transportation and water services; the availability and price of natural gas to the consumer compared to the price of alternative and competing fuels; our ability to successfully and timely implement our business plan; our ability to complete organic growth projects on time and on budget; our ability to finance, complete, or successfully integrate acquisitions; our ability to realize the anticipated benefits of the Midwest Pipeline Acquisition and our ability to manage the risks of the Midwest Pipeline Acquisition; the price and availability of debt and equity financing; restrictions in our existing and any future credit facilities and indentures; the effectiveness of our information technology and operational technology systems and practices to detect and defend against evolving cyber attacks on United States critical infrastructure; changing laws regarding cybersecurity and data privacy, and any cybersecurity threat or event; operating hazards, environmental risks, and other risks incidental to gathering, storing and transporting natural gas; geologic and reservoir risks and considerations; natural disasters, adverse weather conditions, casualty losses and other matters beyond our control; the impact of outbreaks of illnesses, epidemics and pandemics, and any related economic effects; the impacts of geopolitical events, including the conflicts in Ukraine and the Middle East; labor relations and markets, including the ability to attract, hire and retain key employee and contract personnel; large customer defaults; changes in tax status, as well as changes in tax rates and regulations; the effects and associated cost of compliance with existing and future laws and governmental regulations, such as the Inflation Reduction Act and the One Big Beautiful Bill Act; changes in environmental laws, regulations or enforcement policies, including laws and regulations relating to pipeline safety, climate change and greenhouse gas emissions; changes in laws and regulations or enforcement policies, including those relating to construction and operation of new interstate gas pipelines, ratemaking to which our pipelines may be subject, or other non-environmental laws and regulations; our ability to qualify for federal income tax credits by Clean Fuels Gathering; our ability to develop low carbon business opportunities and deploy greenhouse gas reducing technologies; changes in insurance markets impacting costs and the level and types of coverage available; the timing and extent of changes in commodity prices; the success of our risk management strategies; the suspension, reduction or termination of our customers’ obligations under our commercial agreements; disruptions due to equipment interruption or failure at our facilities, or third-party facilities on which our business is dependent; the effects of future litigation; and the risks described in our Annual Report on Form 10-K for the year ended December 31, 2024 and our reports and registration statements filed from time to time with the SEC.

    The above list of factors is not exhaustive. New factors emerge from time to time. We cannot predict what factors may arise or how such factors may cause actual results to vary materially from those stated in forward-looking statements, see the discussion under the section entitled “Risk Factors” in our Annual Report for the year ended December 31, 2024, filed with the SEC on Form 10-K and any other reports filed with the SEC. Given the uncertainties and risk factors that could cause our actual results to differ materially from those contained in any forward-looking statement, you should not put undue reliance on any forward-looking statements.

    Any forward-looking statements speak only as of the date on which such statements are made. We are under no obligation to, and expressly disclaim any obligation to, update or alter our forward-looking statements, whether as a result of new information, subsequent events or otherwise.

    DT Midstream, Inc.
    Reconciliation of Reported to Operating Earnings (non-GAAP, unaudited)
                                   
      Three Months Ended
      June 30,   March 31,
        2025     2025
      Reported
    Earnings    		   Pre-tax
    Adjustments    		   Income
    Taxes    (1)    		   Operating Earnings   Reported
    Earnings    		   Pre-tax
    Adjustments    		   Income
    Taxes    (1)    		   Operating
    Earnings
      (millions)
    Adjustments     $ —     $ —             $ —     $ —      
    Net Income Attributable to DT Midstream $ 107     $ —     $ —     $ 107     $ 108     $ —     $ —     $ 108  
                                   
      Six Months Ended
      June 30,   June 30,
        2025     2024
      Reported
    Earnings    		   Pre-tax
    Adjustments    		   Income
    Taxes    (1)    		   Operating
    Earnings    		   Reported
    Earnings    		   Pre-tax Adjustments   Income
    Taxes    (1)    		   Operating
    Earnings
      (millions)
    Adjustments     $ —     $ —             $ —     $ —      
    Net Income Attributable to DT Midstream $ 215     $ —     $ —     $ 215     $ 193     $ —     $ —     $ 193  
                                   
    (1) Excluding tax related adjustments, the amount of income taxes was calculated based on a combined federal and state income tax rate, considering the applicable jurisdictions of the respective segments and deductibility of specific operating adjustments
                                   
                                   
    DT Midstream, Inc.
    Reconciliation of Reported to Operating Earnings per diluted share(1)(non-GAAP, unaudited)
                                   
      Three Months Ended
      June 30,   March 31,
        2025     2025
      Reported
    Earnings    		   Pre-tax Adjustments   Income
    Taxes    (2)    		   Operating
    Earnings    		   Reported
    Earnings    		   Pre-tax Adjustments   Income
    Taxes    (2)    		   Operating
    Earnings
      (per share)
    Adjustments     $ —     $ —             $ —     $ —      
    Net Income Attributable to DT Midstream $ 1.04     $ —     $ —     $ 1.04     $ 1.06     $ —     $ —     $ 1.06  
                                   
      Six Months Ended
      June 30,   June 30,
        2025     2024
      Reported
    Earnings    		   Pre-tax Adjustments   Income
    Taxes    (2)    		   Operating
    Earnings    		   Reported
    Earnings    		   Pre-tax Adjustments   Income
    Taxes    (2)    		   Operating
    Earnings
      (per share)
    Adjustments     $ —     $ —             $ —     $ —      
    Net Income Attributable to DT Midstream $ 2.10     $ —     $ —     $ 2.10     $ 1.97     $ —     $ —     $ 1.97  
                                   
    (1) Per share amounts are divided by Weighted Average Common Shares Outstanding — Diluted, as noted on the Consolidated Statements of Operations
    (2) Excluding tax related adjustments, the amount of income taxes was calculated based on a combined federal and state income tax rate, considering the applicable jurisdictions of the respective segments and deductibility of specific operating adjustments
                                   
                                   
    DT Midstream, Inc.
    Reconciliation of Net Income Attributable to DT Midstream to Adjusted EBITDA (non-GAAP, unaudited)
                   
      Three Months Ended Six Months Ended
      June 30,   March 31,   June 30,   June 30,
        2025       2025       2025       2024  
    Consolidated (millions)
    Net Income Attributable to DT Midstream $ 107     $ 108     $ 215     $ 193  
    Plus: Interest expense   40       40       80       79  
    Plus: Income tax expense   34       35       69       64  
    Plus: Depreciation and amortization   63       63       126       103  
    Plus: EBITDA from equity method investees(1)   64       73       137       142  
    Less: Interest income   —       (1 )     (1 )     (1 )
    Less: Earnings from equity method investees   (30 )     (37 )     (67 )     (85 )
    Less: Depreciation and amortization attributable to noncontrolling interests   (1 )     (1 )     (2 )     (2 )
    Adjusted EBITDA $ 277     $ 280     $ 557     $ 493  
                   
    (1) Includes share of our equity method investees’ earnings before interest, taxes, depreciation and amortization, which we refer to as “EBITDA.” A reconciliation of earnings from equity method investees to EBITDA from equity method investees follows:
     
      Three Months Ended Six Months Ended
      June 30,   March 31,   June 30,   June 30,
        2025       2025       2025       2024  
      (millions)
    Earnings from equity method investees $ 30     $ 37     $ 67     $ 85  
    Plus: Depreciation and amortization attributable to equity method investees   19       22       41       41  
    Plus: Interest expense attributable to equity method investees   15       14       29       16  
    EBITDA from equity method investees $ 64     $ 73     $ 137     $ 142  
                   
                   
    DT Midstream, Inc.
    Reconciliation of Net Income Attributable to DT Midstream to Adjusted EBITDA
    Pipeline Segment (non-GAAP, unaudited)
                   
      Three Months Ended Six Months Ended
      June 30,   March 31,   June 30,   June 30,
        2025       2025       2025       2024  
    Pipeline (millions)
    Net Income Attributable to DT Midstream $ 93     $ 92     $ 185       145  
    Plus: Interest expense   11       13       24       25  
    Plus: Income tax expense   29       30       59       48  
    Plus: Depreciation and amortization   28       28       56       37  
    Plus: EBITDA from equity method investees(1)   64       73       137       142  
    Less: Interest income   —       (1 )     (1 )     (1 )
    Less: Earnings from equity method investees   (30 )     (37 )     (67 )     (85 )
    Less: Depreciation and amortization attributable to noncontrolling interests   (1 )     (1 )     (2 )     (2 )
    Adjusted EBITDA $ 194     $ 197     $ 391     $ 309  
                   
    (1)  Includes share of our equity method investees’ earnings before interest, taxes, depreciation and amortization, which we refer to as “EBITDA.” A reconciliation of earnings from equity method investees to EBITDA from equity method investees follows:
     
      Three Months Ended Six Months Ended
      June 30,   March 31,   June 30,   June 30,
        2025       2025       2025       2024  
      (millions)
    Earnings from equity method investees $ 30     $ 37     $ 67     $ 85  
    Plus: Depreciation and amortization attributable to equity method investees   19       22       41       41  
    Plus: Interest expense attributable to equity method investees   15       14       29       16  
    EBITDA from equity method investees $ 64     $ 73     $ 137     $ 142  
                   
                   
    DT Midstream, Inc.
    Reconciliation of Net Income Attributable to DT Midstream to Adjusted EBITDA
    Gathering Segment (non-GAAP, unaudited)
                   
      Three Months Ended Six Months Ended
      June 30,   March 31,   June 30,   June 30,
        2025       2025       2025       2024  
    Gathering (millions)
    Net Income Attributable to DT Midstream $ 14     $ 16     $ 30     $ 48  
    Plus: Interest expense   29       27       56       54  
    Plus: Income tax expense   5       5       10       16  
    Plus: Depreciation and amortization   35       35       70       66  
    Less: Interest income   —       —       —       —  
    Adjusted EBITDA $ 83     $ 83     $ 166     $ 184  
                   
                   
    DT Midstream, Inc.
    Reconciliation of Net Income Attributable to DT Midstream to Distributable Cash Flow (non-GAAP, unaudited)
                   
      Three Months Ended Six Months Ended
      June 30,   March 31,   June 30,   June 30,
        2025       2025       2025       2024  
    Consolidated (millions)
    Net Income Attributable to DT Midstream $ 107     $ 108     $ 215     $ 193  
    Plus: Interest expense   40       40       80       79  
    Plus: Income tax expense   34       35       69       64  
    Plus: Depreciation and amortization   63       63       126       103  
    Less: Earnings from equity method investees   (30 )     (37 )     (67 )     (85 )
    Less: Depreciation and amortization attributable to noncontrolling interests   (1 )     (1 )     (2 )     (2 )
    Plus: Dividends and distributions from equity method investees   30       48       78       125  
    Less: Cash interest expense   (76 )     —       (76 )     (74 )
    Less: Cash taxes   (4 )     2       (2 )     (3 )
    Less: Maintenance capital investment(1)   (6 )     (8 )     (14 )     (13 )
    Distributable Cash Flow $ 157     $ 250     $ 407     $ 387  
                   
    (1)  Maintenance capital investment is defined as the total capital expenditures used to maintain or preserve assets or fulfill contractual obligations that do not generate incremental earnings.
                   
                   

    The MIL Network –

  • MIL-OSI United Kingdom: Cardiff Capital Region backed by £30m to unlock innovation and growth

    Source: United Kingdom – Executive Government & Departments

    Press release

    Cardiff Capital Region backed by £30m to unlock innovation and growth

    Cardiff Capital Region is one of three UK cities and regions supported through the UK Government’s £500m local innovation fund.

    Aerial view of Cardiff.

    • Local partnerships will direct funding to range of priorities, from life sciences to AI, or could capitalise on Cardiff Capital Region’s existing strengths such as in automotive technology to support a greener future
    • Builds on record £86bn R&D settlement until 2030 and backs local skills to deliver economic growth as part of our Plan for Change

    Cardiff Capital Region is among three UK cities and regions receiving at least £30m each from the UK Government to unlock new, locally led innovation that can improve lives across the country, UK Science Minister Lord Vallance has announced today (Tuesday 29 July). 

    Partnerships between the city region authority, businesses and research organisations will work with UK Research and Innovation (UKRI) to invest the funding into a range of regional and national priorities in science and technology – from life sciences to green energy solutions, AI to engineering, and beyond.

    It could even build on the existing strengths of Cardiff, and Wales more widely, from its role in developing electric vehicle components that will help us build a greener world to its data science capabilities which can improve lives from better public services to improving our health. 

    The funding forms part of the Local Innovation Partnerships Fund (LIPF) of up to £500m, announced ahead of last month’s Spending Review to empower local leaders with skin in the game. It will help target innovation investment and make the most of their communities’ expertise to unleash discoveries that benefit us all and grow the economy as part of our Plan for Change.

    The decision to earmark at least £30m to three high-potential areas in Glasgow, Belfast-Derry/Londonderry and Cardiff was reached following collaboration between the UK Government and the governments of Scotland, Northern Ireland and Wales. Seven regions of England were also announced as recipients last month – spanning the North-East to Greater Manchester, Liverpool to London.

    The funding was announced as part of a record £86bn R&D settlement until 2030 and will help the Government to deliver our modern Industrial Strategy by backing high growth sectors and bolstering partnerships with industry for long-term economic growth.

    UK Science Minister Lord Vallance said: 

    From driving the development of electric vehicle components that will help deliver a greener planet to cutting-edge data science work, the Cardiff Capital Region playing a leading role in the technologies of the future that can benefit people throughout the UK.

    By targeting this funding with local leaders to a range of science and technology sectors we can make the most of the expertise across Cardiff and wider Wales to grow the economy as part of our Plan for Change.

    Secretary of State for Wales Jo Stevens said:

    This funding from the UK Government is vital to support Wales’s leading science and technology sectors. We are already punching above our weight in areas where there is huge potential for even more growth. 

    Wales has the talent and expertise to develop high tech solutions to a range of challenges, and this investment will help kickstart innovation, create new well-paid jobs and grow the Welsh economy.

    Welsh Government Cabinet Secretary for Economy, Energy and Planning, Rebecca Evans, said:

    This investment represents another vote of confidence in the Cardiff capital region and builds on our work supporting its growth, strong university research ecosystem, industry base and innovation clusters over a number of years.

    We will continue working closely with the South East Wales Corporate Joint Committee and the UK Government to build on the region’s strengths, attract significant private investment, strengthen regional partnerships and deliver real benefits for people across South East Wales and beyond.

    High potential innovation clusters in places that have not been earmarked for funding will also be able to bid into a competition, with UKRI publishing guidance on this competition soon.

    The Local Innovation Partnerships Fund represents a significant shift in place-based innovation policy, giving regions greater control over how research and development investment is directed to maximise their innovation potential and drive economic growth.

    It builds on the lessons learned from programmes already underway to support high potential innovation clusters in regions across the UK, including the Strength in Places Fund and the Innovation Accelerator pilot scheme and Innovate UK Launchpads.  

    The Innovation Accelerator pilot scheme alone has leveraged more than

    £140 million in new private investment, created hundreds of jobs across the West Midlands, Greater Manchester and Glasgow City Region, and supported a range of new technologies.

    It includes those developed by the Greater Manchester advanced diagnostic accelerator, delivering quicker and cheaper detection for liver, heart and lung diseases, whilst Moonbility from the West Midlands is using AI software helping train companies to simulate, in real time, potential disruption to the network so they can alert passengers on delay length, giving advice on replanning journeys.

    Updates to this page

    Published 31 July 2025

    MIL OSI United Kingdom –

  • MIL-OSI: SHARC Energy Ships SHARC WET Systems to US Government-Affiliated Project

    Source: GlobeNewswire (MIL-OSI)

    VANCOUVER, British Columbia, July 31, 2025 (GLOBE NEWSWIRE) — SHARC International Systems Inc. (CSE: SHRC) (FSE: IWIA) (OTCQB: INTWF) (“SHARC Energy” or the “Company”), a world leader in wastewater energy transfer (“WET”), is proud to announce the shipment of two SHARC 880 WET Systems to a U.S. government-affiliated project. Further information about the project will be released at a later stage.

    SHARC Energy’s Wastewater Energy Transfer technology continues to gain momentum in the United States and beyond. Most recently, SHARC Energy’s innovative systems were featured in a Wall Street Journal article spotlighting the emerging role of WET in sustainable infrastructure.

    This milestone shipment underscores the Company’s expanding influence and highlights the increasing adoption of WET solutions as cities and governments seek scalable, low-carbon alternatives for heating, cooling and potable hot water.

    For more information regarding SHARC Energy and its projects, please visit www.sharcenergy.com.

    About SHARC Energy
      
    SHARC International Systems Inc. is a world leader in energy recovery from the wastewater we send down the drain every day. SHARC Energy’s systems recycle thermal energy from wastewater, generating one of the most energy-efficient and economical systems for heating, cooling & hot water production for commercial, residential, and industrial buildings along with thermal energy networks, commonly referred to as “District Energy”.

    SHARC Energy is publicly traded in Canada (CSE: SHRC), the United States (OTCQB: INTWF) and Germany (Frankfurt: IWIA) and you can find out more on our SEDAR profile.

    Learn more about SHARC Energy: Website | Investor Page | LinkedIn | YouTube | PIRANHA | SHARC

    ON BEHALF OF THE BOARD

    Fred Andriano
    Chairman

    The Canadian Securities Exchange does not accept responsibility for the adequacy or accuracy of this release.

    Forward-Looking Statements 

    Certain statements contained in this news release may constitute forward-looking information. Forward-looking information is often, but not always, identified using words such as “anticipate”, “plan”, “estimate”, “expect”, “may”, “will”, “intend”, “should”, and similar expressions. Forward-looking information involves known and unknown risks, uncertainties and other factors that may cause actual results or events to differ materially from those anticipated in such forward-looking information. SHARC Energy’s actual results could differ materially from those anticipated in this forward-looking information because of regulatory decisions, competitive factors in the industries in which the Company operates, prevailing economic conditions, and other factors, many of which are beyond the control of the Company. SHARC Energy believes that the expectations reflected in the forward-looking information are reasonable, but no assurance can be given that these expectations will prove to be correct and such forward-looking information should not be unduly relied upon. Any forward-looking information contained in this news release represents the Company’s expectations as of the date hereof and is subject to change after such date. The Company disclaims any intention or obligation to update or revise any forward-looking information whether because of new information, future events or otherwise, except as required by applicable securities legislation. 

    The MIL Network –

  • MIL-OSI: ReconAfrica Provides a Corporate Update and Announces That the Kavango West 1X Well Has Started Drilling

    Source: GlobeNewswire (MIL-OSI)

    CALGARY, Alberta, July 31, 2025 (GLOBE NEWSWIRE) — Reconnaissance Energy Africa Ltd. (the “Company” or “ReconAfrica”) (TSXV: RECO) (OTCQX: RECAF) (Frankfurt: 0XD) (NSX: REC) announces that the Kavango West 1X exploration well is currently drilling and provides a corporate update on ongoing operations.

    Kavango West 1X (Prospect I) – Well Spud on July 31st

    The Kavango West 1X exploration prospect spud on July 31st. The well is planned to reach total depth (TD) of approximately 3,800 metres (12,500 feet) by the end of November 2025 and is expected to penetrate over 1,500 metres of Otavi carbonate reservoir section, which is the primary target of the Damara Fold Belt play.   The prospect is a large structural fold identified on modern 2D seismic data, which extends over 22 kilometers long by 3 kilometers wide. The Company has identified over 19 prospects and four leads mapped in the Damara Fold Belt trend, with an additional 5.0 million acres captured in a recently executed Memorandum of Understanding in offsetting Angola. More information about the Damara Fold Belt Play, and the Kavango West 1X well, can be found in the Corporate Presentation available on the Company’s website.

    Brian Reinsborough, President and CEO stated: “We are pleased to announce that we have started drilling the Kavango West 1X well. This is an exciting time for everyone at the Company, our partners and stakeholders in Namibia and, of course, shareholders alike. Originally, the Kavango West 1X location was not scheduled to be the next well, but the location was reprioritized after the results of our last well, Naingopo. While this reprioritizing resulted in a slightly longer lead time to spud this location, the Company prioritizes rigorous technical appraisal with respect to location selection to ensure we have the best possible chance for commercial success. We think that the Kavango West 1X prospect represents our best opportunity in the Damara Fold Belt to unlock the potential of this play and we look forward to reporting results expected before year-end 2025.”

    Chris Sembritzky, SVP Exploration commented: “By utilizing our learnings from the Naingopo well, Kavango West 1X represents the best opportunity we have identified on seismic in the Damara Fold Belt play due to its size, hydrocarbon migration pathway and well defined four-way closure.  With our new subsurface learnings, highly experienced drilling crew and optimized, built for purpose drill bits, we believe that we have captured the best possible chance for drilling an efficient, safe and commercially successful well.”

    Corporate Update

    Due to our ongoing drilling activities, the previously announced 3D seismic program that had been scheduled for the second half of 2025 has been moved to the 2026 operating program.The Company is continually reviewing potential investment opportunities that may include acquisition of further acreage for exploration, development and producing properties and joint venture transactions that target acceleration of production and free cash flow, particularly due to the Company’s concentrated asset risk profile.

    Stock Option Grants

    As part of the annual compensation review, the Company has granted incentive stock options (the “Options”) to certain directors, officers, employees and consultants of the Company to acquire an aggregate of 6,960,000 common shares at an exercise price of $0.60 per share. The Options are exercisable for a five-year term expiring July 31, 2030, and will be subject to certain vesting provisions as determined by the Board of Directors of the Company in accordance with the Company’s Stock Option Plan. The Options granted to insiders are subject to restrictions on resale until November 30, 2025, in accordance with the policies of the TSX Venture Exchange.     

    About ReconAfrica

    ReconAfrica is a Canadian oil and gas company engaged in the exploration of the Damara Fold Belt and Kavango Rift Basin in the Kalahari Desert of northeastern Namibia, southeastern Angola and northwestern Botswana, where the Company holds petroleum licences comprising ~13 million contiguous acres. In all aspects of its operations, ReconAfrica is committed to minimal disturbance of habitat in line with international standards and implementing environmental and social best practices in its project areas.

    Neither the TSXV nor its Regulation Services Provider (as that term is defined in policies of the TSXV) accepts responsibility for the adequacy or accuracy of this release.

    For further information contact:

    Brian Reinsborough, President and Chief Executive Officer
    Mark Friesen, Managing Director, Investor Relations & Capital Markets

    IR Inquiries Email: investors@reconafrica.com

    Media Inquiries Email: media@reconafrica.com

    Cautionary Note Regarding Forward-Looking Statements:

    Certain statements contained in this press release constitute forward-looking information under applicable Canadian, United States and other applicable securities laws, rules and regulations, including, without limitation, statements with respect to the expected timing of spud of the Kavango West 1X well, the well being drilled to a planned total depth of approximately 3,800 metres (12,500 feet), timing to reach total depth of the well, the planning, timing and commencement of a 3D seismic program, identifying and capturing potential opportunities and the Company’s commitment to minimal disturbance of habitat, in line with best international standards and its implementation of environmental and social best practices in its project areas. These statements relate to future events or future performance. The use of any of the words “could”, “intend”, “expect”, “believe”, “will”, “projected”, “estimated” and similar expressions and statements relating to matters that are not historical facts are intended to identify forward-looking information and are based on ReconAfrica’s current belief or assumptions as to the outcome and timing of such future events. There can be no assurance that such statements will prove to be accurate, as the Company’s actual results and future events could differ materially from those anticipated in these forward-looking statements as a result of the factors discussed in the “Risk Factors” section in the Company’s annual information form (“AIF”) dated April 29, 2025 for the financial period ended December 31, 2024, available under the Company’s profile at www.sedarplus.ca. Actual future results may differ materially. Various assumptions or factors are typically applied in drawing conclusions or making the forecasts or projections set out in forward-looking information. Those assumptions and factors are based on information currently available to ReconAfrica. The forward-looking information contained in this release is made as of the date hereof and ReconAfrica undertakes no obligation to update or revise any forward-looking information, whether as a result of new information, future events or otherwise, except as required by applicable securities laws. Because of the risks, uncertainties and assumptions contained herein, investors should not place undue reliance on forward-looking information. The foregoing statements expressly qualify any forward-looking information contained herein.

    The MIL Network –

  • MIL-OSI Africa: ‘Evolution of energy landscape’ requires deepening government, industry collaboration

    Source: Government of South Africa

    ‘Evolution of energy landscape’ requires deepening government, industry collaboration

    The success of South Africa’s energy transition depends, in part, on deepening and stronger collaboration between government and the renewable energy industry to fill out policy implementation gaps and drive investment.

    This according to Chief Executive Officer of the South African Wind Energy Association (SAWEA), Niveshen Govender, who participated in a panel discussion on the sidelines of the third G20 Energy Transitions Working Group (ETWG) meeting held in the North West.

    “From an industry perspective… there are a number of requirements that we have to work on with government to ensure that we implement. I think we are doing a good job… We have the energy one stop shop that is now a single point of access to all permitting. You have the Department of Energy and Electricity with a minister [Dr Kgosientsho Ramokgopa] who is very active in unblocking [challenges]. 

    “We have seen government’s readiness of market and allowing for business to come in, invest [and] implement on cost, on time – as quickly as possible – to get those electrons into place,” Govender said.

    He noted that the industry and government stand at the same point with a “lot of commonalities” between the two.

    “[This is] in terms of ensuring that we have access to energy per country, we have affordable energy to actually use, we have security of supply so we don’t go back to load shedding and we have sustainability in the long-term for reducing our carbon emissions.

    “The Minister [Dr Kgosientsho Ramokgopa] very succinctly articulated… the importance of the energy mix and the importance of renewable energy being central to the decarbonisation of that energy mix,” Govender said.

    However, despite these commonalities, misalignments still remain.

    “We have very good policies in South Africa, top tier policies. They give good direction and good guidance. It takes everything into consideration… for the people of South Africa to make sure that we’re leaving no one behind.

    “Where we do struggle is implementation of these policies. I think the biggest one of those is investor readiness. If you are not engaging industries, your readiness is going to [be impacted] as to what does the investor need to make that policy a reality,” the industry expert said.

    He described the current developmental pace of the industry as an “evolution of the energy landscape”.

    “We’ve moved from, essentially, the monopoly that Eskom was into public procurement of renewable energy and IPPs [Independent Power Producers]. Now we’re moving into bilateral agreements between these IPPs and… users. We’re even moving one step further into a liberalised energy market where you have traders and aggregators playing a role.

    “We see this evolution of the electricity space that’s changing how we do business. It’s changing how we look at the landscape and energy planning,” Govender said. – SAnews.gov.za

    NeoB

    MIL OSI Africa –

  • MIL-OSI Africa: Government launches project for investors in energy sector

    Source: Government of South Africa

    Government launches project for investors in energy sector

    As part of ongoing efforts to unlock infrastructure investments and strengthen the energy sector, government is calling on investors to invest in the country’s transmission infrastructure through the Independent Transmission Projects (ITPs) Programme.

    This initiative marks the first time private investment will be allowed in South Africa’s transmission infrastructure, paving the way for a faster rollout of new high-voltage power lines across the country.

    “This will support the efforts already underway by the National Transmission Company of South Africa to implement the Transmission Development Plan, which calls for more than 14 000 km of new lines to be built over the next decade.

    “The introduction of ITPs is a key objective of Operation Vulindlela Phase II and will play an important role in the broader reform of the energy system. This reform includes the introduction of a competitive electricity market, which will allow multiple generators and traders to compete to provide electricity to consumers at the lowest cost and with the greatest efficiency,” Deputy Minister of Finance Dr David Masondo said on Thursday.

    Addressing the launch of the Request for Pre-Qualifications for Independent Transmission Projects (ITPs) in Johannesburg, the Deputy Minister said the reform of the energy system is advancing rapidly, and its commitment remains unwavering. 

    “We will not allow any vested interests to delay or obstruct this reform process, including Eskom itself. Indeed, today’s release of the Request for Quotation (RFQ) demonstrates that government, led by [Electricity] Minister Dr [Kgosientsho] Ramokgopa and his team, is working hard to implement the reforms that are needed to ensure long-term energy security and expand access to affordable electricity for all South Africans.

    “National Treasury has supported this process through the design of a Credit Guarantee Vehicle, as an innovative mechanism to unlock private capital and complement public financing for infrastructure while minimising contingent liabilities,” he said.

    South Africa is faced with a significant infrastructure financing need. 

    It is estimated that South Africa’s infrastructure gap is around R3.5 to R4 trillion by 2025, or around R400 billion per annum. 

    “This substantial need calls for scaling up of public financing for infrastructure as well as crowding in private capital through public-private partnerships (PPP). The objective of the Credit Guarantee Vehicle is to mobilise and leverage private capital to address South Africa’s infrastructure financing gap by mitigating offtake risk for private investors. 

    “This vehicle will also support the efficient deployment of development partner funding under the Just Energy Transition Partnership (JETP) and the achievement of the country’s decarbonisation commitments,” the Deputy Minister said.

    While the Credit Guarantee Vehicle will focus on the initial phase on enabling investments in transmission infrastructure, it will be expanded into other areas such as logistics and water over time. 

    “The vehicle will be incorporated as a private company in South Africa, regulated by the Prudential Authority. It will operate as a standalone entity with an independent balance sheet and will target a minimum credit rating of AAA.

    “A professional executive management team and board of directors with relevant experience and expertise will be appointed to operate and manage the fund,” he said.

    The Credit Guarantee Vehicle will issue a combination of payment and termination guarantees to a Special Purpose Vehicle established for the project. 

    This will substantially derisk early investments in ITPs until the model has been proven and established.

    “We are targeting an initial capital raise of US$500 million for the vehicle, spread across a range of development partners. National Treasury has committed to providing first loss capital of 20%, which will be an initial US$100 million increasing to US$500 million (R9 billion) if needed.

    “In February 2025, the Minister of Finance [Enoch Godongwana] wrote to a range of development partners asking them to submit an expression of interest to invest in the vehicle. The responses received have been overwhelmingly positive, with 32 development partners engaged thus far,” the Deputy Minister said.

    Formal engagements with participating partners are continuing and will lead to the delivery of conditional equity participation commitment letters in the third quarter of 2025.

    This will enable the Credit Guarantee Vehicle to be operationalized by July 2026 to align with the first phase of ITP projects.

    “South Africa’s ITP programme, backed by credit guarantees, represents a globally innovative model which has been designed with our own context and needs in mind. 

    “It will not only result in massive new investment in infrastructure but will enable thousands of megawatts of new renewable energy capacity to be connected in areas where grid capacity is limited. This will support economic growth, create jobs, and power our economy into the future,” Masondo said. –SAnews.gov.za

    nosihle

    MIL OSI Africa –

  • MIL-OSI United Nations: 31 July 2025 Departmental update Redefining the HIV response in Africa through local production of medicines and diagnostics

    Source: World Health Organisation

    While Sub-Saharan Africa bears the highest HIV burden globally and is home to almost 65% of all people living with HIV, for decades, access to HIV treatment across the African region depended almost entirely on imports of lifesaving drugs and diagnostic tests manufactured thousands of miles away. 

    To boost supply chain resilience and regional self-reliance, WHO’s Global HIV, Hepatitis and Sexually Transmitted Infections Programmes Department, in collaboration with the Regulation and Prequalification Department, has been actively advocating for locally manufactured quality-assured medicines and diagnostics. This work is carried out in close partnership with countries, manufacturers in Africa and partners such as the Global Fund and Unitaid. 

    In 2023, Universal Corporation Ltd (UCL), a Kenya-based pharmaceutical company led by Mr Palu Dhanani, became the first African manufacturer to receive WHO prequalification to produce tenofovir disoproxil fumarate, lamivudine and dolutegravir (TLD), a WHO-recommended first-line antiretroviral therapy for HIV infection.

    “Local production of quality-assured health products is an urgent priority. With every African manufacturer that meets WHO prequalification standards, we move closer to a more self-reliant, resilient, and equitable health system. Regulation and prequalification are not just technical processes; they are catalysts for health sovereignty and timely access to lifesaving medicines and diagnostics,” said Dr Rogerio Gaspar, WHO Director for Regulation and Prequalification.

    A first for the continent

    As recently announced, the Global Fund now procures UCL’s TLD for Mozambique, marking the first time TLD is manufactured on African soil. This milestone reflects ongoing collaboration between WHO and the Global Fund to support essential HIV services, through the NextGen market shaping approach.

    “The procurement of the African-manufactured first-line HIV treatment by the Global Fund for Mozambique is a great milestone towards strengthening supply chain systems in Africa. This will contribute to better health outcomes for people living with HIV who need uninterrupted medicine supplies,” said Dr Meg Doherty, Director of WHO’s Global HIV, Hepatitis and STIs Programmes.  

    However, production alone isn’t enough. To ensure sustainable and resilient supply chains, critical enablers are needed, such as advanced market commitments, fair procurement policies and continued technical support.

    WHO shares the vision of a world where every region has the capacity to secure its own health. Locally manufactured TLD is a major step towards that goal, but more action is needed. African manufacturers should be prioritized in global supply chains, and  guaranteed equitable access to health technologies that meet quality, safety and efficacy/performance standards.

    HIV testing: another critical frontline

    HIV testing is a critical health service and a vital gateway to both prevention and treatment. With current shifts in donor funding, many countries are facing financial strain, putting testing programmes at risk. Keeping people living with HIV on treatment is important and requires affordable and reliable access to HIV rapid tests. 

    WHO is urging governments to shift towards low-cost, quality-assured HIV rapid tests, especially the first test in their national testing algorithms, for significant cost savings. 

    Codix Bio, a Nigerian in-vitro diagnostics company, has received a sublicense to manufacture rapid diagnostic tests (RDTs), with an initial focus on RDTs for HIV, using technology transferred from the global in-vitro diagnostics company SD Biosensor. Thanks to the collaborative efforts of WHO’s Health Technology Access Programme and the Medicines Patent Pool, this new local manufacture of HIV RDTs will improve access to affordable diagnostic tests and help mitigate disruptions of HIV testing services.

    “Having locally produced HIV RDTs will help increase affordability, and more broadly address supply chain vulnerabilities and delays in access to diagnostics,” said Dr Meg Doherty, Director of WHO’s Global HIV, Hepatitis and STIs Programmes.

    In addition to switching to low-cost quality-assured HIV tests, WHO encourages countries to use HIV self-tests to mitigate gaps in human resources for health as well as stockouts for the first RDT in national algorithms.

    MIL OSI United Nations News –

  • MIL-OSI United Nations: Nuclear Science and Nuclear Security Infrastructure to Protect Rare Rhinos: IAEA-Supported Project Marks a Milestone

    Source: International Atomic Energy Agency (IAEA)

    In a pioneering effort to combat wildlife trafficking of the threatened rhinoceros, a South African University today began implementing a project supported by the International Atomic Energy Agency (IAEA). The project combines the safe insertion of radioactive isotopes into rhino horns and available nuclear security infrastructure to deter and detect illegal poaching.

    With over 10,000 rhinos lost to poaching in the past decade, South Africa – home to the world’s largest population of rhinos – remains a target for criminals driven by the illegal trade of rhino horn. In the first quarter of 2025 alone, the South African Ministry of Forestry, Fisheries and the Environment reported 103 rhinos poached. In response, this project run by the University of the Witwatersrand is using radiation to support conservation and enforcement efforts.

    After two years of initial tests, the Rhisotope Project was created in 2021 with the idea to tag rhino horns with radioactive material. This makes the horns detectable by radiation portal monitors (RPMs) already deployed at borders, ports and airports worldwide. These RPMs, commonly used to detect nuclear and other radioactive material, can now be harnessed against wildlife crime.

    The IAEA’s support to the Rhisotope Project leverages its central role in strengthening the global nuclear security framework. With millions of vehicles and people crossing borders every day, the use of an estimated 10,000 RPMs worldwide has become a critical tool for detecting unauthorized transboundary movements of nuclear and other radioactive material.

    “The Rhisotope Project shows how nuclear science and nuclear security infrastructure can be used in new ways to address global challenges,” said IAEA Director General Rafael Mariano Grossi. “The IAEA is supporting countries to maximize the benefits of nuclear. By using already installed nuclear security infrastructure in novel ways, we can help protect one of the world’s most iconic and endangered species.”

    At an event today in the Waterberg, Limpopo, about 250 kilometres north of Johannesburg, the University of Witwatersrand announced the results of the rigorous safety assessments conducted during the pilot phase of the project. In June last year, radioisotopes were inserted into 20 rhinos. Health monitoring and cytological examinations of 15 treated animals and a comparison of five animals not treated were conducted by Ghent University in Belgium. The test results proved that the method is non-invasive and does not pose a risk to the rhinos’ health.

    “This has been an international collaboration of likeminded individuals who are trying to make a real difference to this poaching crisis,” said James Larkin, Director, Radiation and Health Physics Unit at the University of the Witwatersrand. “We started with the question – what if radiation could protect rather than harm, by turning rhino horns into traceable markers that stop poachers before they trade? After two years of digital modelling, safety testing and detection simulations, we’re ready to roll out a solution that could truly reduce rhino poaching.”

    The success of project also opens the door for future applications to other endangered species.

    “The methodology could be adapted to protect other endangered species like elephants or pangolins,” said Larkin.

    The IAEA is providing both technical and financial support to the project under its Coordinated Research Project titled Facilitation of Safe and Secure Trade Using Nuclear Detection Technology – Detection of RN and Other Contraband. As part of the project, the Agency also supports countries in their efforts to optimize the detection of radiation by the use of its Minimum Detectable Quantity and Alarm Threshold Estimation Tool, thereby allowing detection of the tagged with radiation rhino horns.

    “The Rhisotope Project brings the entire global nuclear security network into play,” said Elena Buglova, Director of the IAEA Division of Nuclear Security. “The nuclear security infrastructure that exists in many countries around the world to detect smuggling of nuclear and other radioactive material can be used to pick up the trafficking of rhino horn, and any other contraband that might be carried alongside it. Committing to nuclear security pays off in multiple ways.”

    B-roll and photos will be made available here.

    MIL OSI United Nations News –

  • MIL-OSI Security: Nuclear Science and Nuclear Security Infrastructure to Protect Rare Rhinos: IAEA-Supported Project Marks a Milestone

    Source: International Atomic Energy Agency – IAEA

    The Rhisotope Project team inserting radioactive isotopes into rhino horns. (Martin Klinenboeck/IAEA)

    In a pioneering effort to combat wildlife trafficking of the threatened rhinoceros, a South African University today began implementing a project supported by the International Atomic Energy Agency (IAEA). The project combines the safe insertion of radioactive isotopes into rhino horns and available nuclear security infrastructure to deter and detect illegal poaching.

    With over 10,000 rhinos lost to poaching in the past decade, South Africa – home to the world’s largest population of rhinos – remains a target for criminals driven by the illegal trade of rhino horn. In the first quarter of 2025 alone, the South African Ministry of Forestry, Fisheries and the Environment reported 103 rhinos poached. In response, this project run by the University of the Witwatersrand is using radiation to support conservation and enforcement efforts.

    After two years of initial tests, the Rhisotope Project was created in 2021 with the idea to tag rhino horns with radioactive material. This makes the horns detectable by radiation portal monitors (RPMs) already deployed at borders, ports and airports worldwide. These RPMs, commonly used to detect nuclear and other radioactive material, can now be harnessed against wildlife crime.

    The IAEA’s support to the Rhisotope Project leverages its central role in strengthening the global nuclear security framework. With millions of vehicles and people crossing borders every day, the use of an estimated 10,000 RPMs worldwide has become a critical tool for detecting unauthorized transboundary movements of nuclear and other radioactive material.

    “The Rhisotope Project shows how nuclear science and nuclear security infrastructure can be used in new ways to address global challenges,” said IAEA Director General Rafael Mariano Grossi. “The IAEA is supporting countries to maximize the benefits of nuclear. By using already installed nuclear security infrastructure in novel ways, we can help protect one of the world’s most iconic and endangered species.”

    At an event today in the Waterberg, Limpopo, about 250 kilometres north of Johannesburg, the University of Witwatersrand announced the results of the rigorous safety assessments conducted during the pilot phase of the project. In June last year, radioisotopes were inserted into 20 rhinos. Health monitoring and cytological examinations of 15 treated animals and a comparison of five animals not treated were conducted by Ghent University in Belgium. The test results proved that the method is non-invasive and does not pose a risk to the rhinos’ health.

    “This has been an international collaboration of likeminded individuals who are trying to make a real difference to this poaching crisis,” said James Larkin, Director, Radiation and Health Physics Unit at the University of the Witwatersrand. “We started with the question – what if radiation could protect rather than harm, by turning rhino horns into traceable markers that stop poachers before they trade? After two years of digital modelling, safety testing and detection simulations, we’re ready to roll out a solution that could truly reduce rhino poaching.”

    The success of project also opens the door for future applications to other endangered species.

    “The methodology could be adapted to protect other endangered species like elephants or pangolins,” said Larkin.

    The IAEA is providing both technical and financial support to the project under its Coordinated Research Project titled Facilitation of Safe and Secure Trade Using Nuclear Detection Technology – Detection of RN and Other Contraband. As part of the project, the Agency also supports countries in their efforts to optimize the detection of radiation by the use of its Minimum Detectable Quantity and Alarm Threshold Estimation Tool, thereby allowing detection of the tagged with radiation rhino horns.

    “The Rhisotope Project brings the entire global nuclear security network into play,” said Elena Buglova, Director of the IAEA Division of Nuclear Security. “The nuclear security infrastructure that exists in many countries around the world to detect smuggling of nuclear and other radioactive material can be used to pick up the trafficking of rhino horn, and any other contraband that might be carried alongside it. Committing to nuclear security pays off in multiple ways.”

    B-roll and photos will be made available here.

    MIL Security OSI –

  • MIL-OSI: CleanCounts Announces former EPA lead James Critchfield as Head of Registry and Market Integrity

    Source: GlobeNewswire (MIL-OSI)

    ASPEN, Colo., July 31, 2025 (GLOBE NEWSWIRE) — Aspen Energy Forum – CleanCounts, a nonprofit with the industry leading environmental attribute certificate (EAC) tracking platform for voluntary and compliance claims of renewable energy projects across North America, today announced James Critchfield as the Head of Registry & Market Integrity. In his role, Critchfield will lead the development and governance of high-fidelity registries that safeguard transparency and trust across clean-energy and carbon markets. CleanCounts shared the news on Critchfield joining the team from Aspen Energy Forum, where the nonprofit is taking part in discussions on decarbonization and renewable energy strategies.

    Critchfield joins CleanCounts after spending two decades at the U.S. Environmental Protection Agency, where he was an authority on energy-attribute certificates, registry architecture, and greenhouse-gas accounting, advising Fortune 500 companies, state regulators, and international bodies. Most recently, Critchfield scaled the EPA’s Green Power Partnership from its infancy to hundreds of organizations, pushing annual voluntary green-power procurement to more than 100 billion KWh annually and catalyzing nearly 19 GW of new renewable capacity nationwide.

    “CleanCounts has advocated for standards in the renewable energy market and the environmental attribute tracking industry to drive better decision making by corporate buyers and provide transparency for regulators,” said James Critchfield, CleanCount’s Head of Registry & Market Integrity. “I look forward to stepping into this new role to bring my experience to support CleanCounts’ continued reputation as the true validator for environmental markets.”

    CleanCounts, formerly known as M-RETS, tracks generated energy outputs across North America, enabling market participants to place a dollar value on the environmental benefits of renewable energy and renewable thermal outputs. Through rigorous validation of the environmental benefits, verifiable data, and unbiased third-party verification, CleanCounts is now North America’s leading platform to obtain, transfer, or retire renewable energy certificates (RECs), renewable thermal certificates (RTCs), and alternative energy certificates (AECs).

    “James Critchfield’s work in the federal government to support tracking system infrastructure for clean energy in the United States has led to the development of next generation tracking capabilities that feature the granularity needed for market transparency,” said Benjamin Gerber, CEO of CleanCounts. “With James joining our executive team, we look forward to engaging stakeholders throughout North America for conversations about how a continuity-first, climate-aligned, and tech-forward clean energy registry can create benefits for, and strengthen trust in, both the voluntary and compliance markets.”

    Prior to joining CleanCounts full time on August 21, Critchfield will join an upcoming webinar with senior leaders from Singularity Energy and EnergyTag titled, How Western States Can Achieve Grid Decarbonization, on August 13, 2025 at 9:00 AM PT / 12:00 PM ET. The energy industry leaders will discuss how granular energy data and verified certificates can enable the hourly electricity accounting needed to drive investment and deployment of decarbonization technologies for an around-the-clock clean grid. Those interested in attending can register here.

    To learn more about CleanCounts, please visit www.cleancounts.org

    About CleanCounts
    CleanCounts, formerly known as Midwest Renewable Energy Tracking System (M‑RETS) Inc., is North America’s most expansive clean energy registry and a trusted gateway to environmental markets. As a nonprofit organization, CleanCounts empowers participants across the energy ecosystem to track, trade, and validate clean energy production and consumption with confidence and transparency.

    Media Contact:
    FischTank PR
    cleancounts@fischtankpr.com

    A photo accompanying this announcement is available at
    https://www.globenewswire.com/NewsRoom/AttachmentNg/dd918d85-5f5a-493e-9a32-31974fc5a615

    The MIL Network –

  • MIL-OSI NGOs: Nuclear Science and Nuclear Security Infrastructure to Protect Rare Rhinos: IAEA-Supported Project Marks a Milestone

    Source: International Atomic Energy Agency (IAEA) –

    The Rhisotope Project team inserting radioactive isotopes into rhino horns. (Martin Klinenboeck/IAEA)

    In a pioneering effort to combat wildlife trafficking of the threatened rhinoceros, a South African University today began implementing a project supported by the International Atomic Energy Agency (IAEA). The project combines the safe insertion of radioactive isotopes into rhino horns and available nuclear security infrastructure to deter and detect illegal poaching.

    With over 10,000 rhinos lost to poaching in the past decade, South Africa – home to the world’s largest population of rhinos – remains a target for criminals driven by the illegal trade of rhino horn. In the first quarter of 2025 alone, the South African Ministry of Forestry, Fisheries and the Environment reported 103 rhinos poached. In response, this project run by the University of the Witwatersrand is using radiation to support conservation and enforcement efforts.

    After two years of initial tests, the Rhisotope Project was created in 2021 with the idea to tag rhino horns with radioactive material. This makes the horns detectable by radiation portal monitors (RPMs) already deployed at borders, ports and airports worldwide. These RPMs, commonly used to detect nuclear and other radioactive material, can now be harnessed against wildlife crime.

    The IAEA’s support to the Rhisotope Project leverages its central role in strengthening the global nuclear security framework. With millions of vehicles and people crossing borders every day, the use of an estimated 10,000 RPMs worldwide has become a critical tool for detecting unauthorized transboundary movements of nuclear and other radioactive material.

    “The Rhisotope Project shows how nuclear science and nuclear security infrastructure can be used in new ways to address global challenges,” said IAEA Director General Rafael Mariano Grossi. “The IAEA is supporting countries to maximize the benefits of nuclear. By using already installed nuclear security infrastructure in novel ways, we can help protect one of the world’s most iconic and endangered species.”

    At an event today in the Waterberg, Limpopo, about 250 kilometres north of Johannesburg, the University of Witwatersrand announced the results of the rigorous safety assessments conducted during the pilot phase of the project. In June last year, radioisotopes were inserted into 20 rhinos. Health monitoring and cytological examinations of 15 treated animals and a comparison of five animals not treated were conducted by Ghent University in Belgium. The test results proved that the method is non-invasive and does not pose a risk to the rhinos’ health.

    “This has been an international collaboration of likeminded individuals who are trying to make a real difference to this poaching crisis,” said James Larkin, Director, Radiation and Health Physics Unit at the University of the Witwatersrand. “We started with the question – what if radiation could protect rather than harm, by turning rhino horns into traceable markers that stop poachers before they trade? After two years of digital modelling, safety testing and detection simulations, we’re ready to roll out a solution that could truly reduce rhino poaching.”

    The success of project also opens the door for future applications to other endangered species.

    “The methodology could be adapted to protect other endangered species like elephants or pangolins,” said Larkin.

    The IAEA is providing both technical and financial support to the project under its Coordinated Research Project titled Facilitation of Safe and Secure Trade Using Nuclear Detection Technology – Detection of RN and Other Contraband. As part of the project, the Agency also supports countries in their efforts to optimize the detection of radiation by the use of its Minimum Detectable Quantity and Alarm Threshold Estimation Tool, thereby allowing detection of the tagged with radiation rhino horns.

    “The Rhisotope Project brings the entire global nuclear security network into play,” said Elena Buglova, Director of the IAEA Division of Nuclear Security. “The nuclear security infrastructure that exists in many countries around the world to detect smuggling of nuclear and other radioactive material can be used to pick up the trafficking of rhino horn, and any other contraband that might be carried alongside it. Committing to nuclear security pays off in multiple ways.”

    B-roll and photos will be made available here.

    MIL OSI NGO –