Category: Politics

  • MIL-OSI United Kingdom: Development Minister sets out new UK approach to development at G20 meeting in South Africa

    Source: United Kingdom – Executive Government & Departments

    Press release

    Development Minister sets out new UK approach to development at G20 meeting in South Africa

    The UK is resetting its relationship with countries in the Global South and helping countries exit the need for aid, as Baroness Chapman attends the G20 Development Ministerial Meeting in South Africa.

    • Development Minister Baroness Chapman will reset the UK’s approach to international development at the G20 Development Meeting in South Africa today (Friday, 25 July).
    • Economic development underpins the UK’s new approach, as the Minister visits a South African food producer supported by the FCDO’s development arm BII.
    • The UK is supporting countries to transition from traditional aid to innovative financing for development, as the Minister visits a centre for survivors of gender-based violence funded by both the UK and the private sector.

    The UK is resetting its relationship with countries in the Global South and helping countries exit the need for aid, as Baroness Chapman attends the G20 Development Ministerial Meeting in South Africa today (Friday 25 July 2025).

    This follows the publication of ODA allocations earlier this week (Tuesday 22 July 2025), which indicate how the UK is going to spend its aid budget for the next year.

    The UK will move from being a donor to a genuine partner and investor, ensuring every pound spent on aid delivers for the UK taxpayer and the people we support.

    Economic development underpins the UK’s new approach, to help countries grow fairer, more resilient economies and ultimately exit the need for aid, in support of the government’s Plan for Change.

    The Minister saw this in action yesterday (Thursday 24 July 2025) as she visited an Agristar farm which produces macadamia nuts in Mbombela, eastern South Africa. British International Investment (BII), the UK’s development finance institution, is supporting Agristar to expand – supporting jobs and growth and helping to stock British supermarket shelves. 

    The Minister also visited a UK supported care centre for survivors of gender-based violence in Mbombela, alongside South African Minister for Women, Youth and Persons with Disability, Sindisiwe Lydia Chikunga. The centre is supported by a multi-donor fund which has seen increased backing from South African and international private investors. The innovative funding approach has supported over 200 community-based organisations in South Africa working to prevent violence in schools and communities and provide response services for survivors of gender-based violence. This demonstrates the UK and South Africa’s shared commitment to gender equality and women’s empowerment.

    By mobilising private finance and empowering partners to take charge of their own development, the UK is moving away from a paternalistic approach to aid.

    Minister for Development, Baroness Chapman said:

    We want to help countries move beyond aid. In South Africa, I’ve seen the impact we can have with genuine partnerships, rather than paternalism. Our work is supporting jobs and generating global economic growth – and bringing high quality South African produce to UK shops. 

    At the G20 in South Africa, I have one simple message: the world has changed and so must we. The UK is taking a new approach to development, responding to the needs of our partners and delivering real impact and value for money for UK taxpayers.

    At the G20, the Minister is due to discuss the UK’s new approach to international development with counterparts from Egypt, India and Germany.

    The Agristar farm in Mbombela, which the Minister visited yesterday, has benefitted from UK investment as part of the Just Energy Transition Partnership (JETP). BII support has enabled the macadamia nut producer to expand its operations across Africa, invest in measures to mitigate climate risks, and support nearly 400 jobs. BII is also supporting Agristar’s expansion into Malawi.

    BII, which aims to make a return on its investments, has so far supported 92 companies in South Africa and over 35,000 jobs.   

    Its success highlights how the UK’s investment in international development is driving green growth and jobs, boosting global prosperity and stability to help create the conditions to deliver the government’s Plan for Change at home.   

    The Minister will also announce today a new £2 million commitment to support local agribusiness projects by partnering with South African investment funds to drive more private finance for the farming sector.

    In G20 talks on tackling illicit financial flows, the Minister will highlight how money and assets siphoned away as part of criminal activity deprive lower-income countries of vital resources which could otherwise support growth and development. The Foreign Secretary is leading a campaign against illicit finance, mobilising the best UK expertise and international partnerships, so dirty money has nowhere to hide. This is also vital to deterring threats to the safety and security of Britain, as part of the government’s Plan for Change.

    Media enquiries

    Email newsdesk@fcdo.gov.uk

    Telephone 020 7008 3100

    Email the FCDO Newsdesk (monitored 24 hours a day) in the first instance, and we will respond as soon as possible.

    Updates to this page

    Published 25 July 2025

    MIL OSI United Kingdom

  • MIL-OSI Canada: Prime Minister Carney and Inuit leadership meet as the Inuit-Crown Partnership Committee

    Source: Government of Canada – Prime Minister

    Today, the Prime Minister, Mark Carney, the President of Inuit Tapiriit Kanatami, Natan Obed, federal Cabinet ministers, and elected Inuit leadership from the Inuvialuit Regional Corporation, Nunavut Tunngavik Incorporated, Makivvik, and the Nunatsiavut Government gathered for a meeting of the Inuit-Crown Partnership Committee (ICPC) in Inuvik, Northwest Territories.

    Since the signing of the Inuit Nunangat Declaration in 2017, the Government of Canada and Inuit leaders have continued to meet three times annually and work together through the ICPC to advance shared priorities, strengthen the Inuit-Crown partnership, and create a more prosperous Inuit Nunangat.

    During today’s meeting, the leaders discussed the Building Canada Act and how to implement it effectively and consistently with Inuit Modern Treaties and in partnership with Inuit.

    In addition to the Building Canada Act, federal and Inuit leaders discussed the infrastructure needs in Inuit Nunangat, Canada’s Arctic Foreign Policy, and the need to further protect the security and sovereignty of the Arctic and Inuit Nunangat. They also addressed other urgent priorities, including health care and social issues such as housing in Inuit Nunangat. The leaders underscored opportunities to build together to address these challenges and deliver meaningful economic prosperity.

    In Inuvik, the Prime Minister announced the appointment of Virginia Mearns as Canada’s Arctic Ambassador, effective September 15, 2025. The Ambassador’s mandate will focus on reinforcing Canada’s Arctic engagement with like-minded partners and multilateral forums, bolstering Arctic sovereignty, and advancing opportunities for security and growth.

    Inuit leaders and the federal government reaffirmed their shared commitment to working together on priorities through the ICPC.

    Quotes

    “Today’s Inuit-Crown Partnership Committee meeting was about building our shared future and Inuit Nunangat’s full economic potential. In partnership, Inuit and the federal government will build major projects that connect and transform our economy, create greater prosperity and opportunities, and build a stronger Canada.”

    “Now in its ninth year, the Inuit-Crown Partnership Committee remains an essential tool for advancing shared priorities. This includes increasing investment in Inuit Nunangat through implementation of the Building Canada Act in a way that is consistent with Inuit treaties and in partnership with Inuit. We welcome the opportunity to continue this important work with Mark Carney, to strengthen our partnership and build lasting prosperity for Inuit in Inuit Nunangat and across Canada. We also celebrate today’s announcement of Virginia Mearns as Canada’s Arctic Ambassador, a position that was developed through the ICPC.”

    “In order to build stronger, healthier communities and a thriving economy, we must work together. For that reason, projects that move forward in Inuit Nunangat will do so in partnership with Inuit. We’re committed to engaging, listening, and working with local communities and Inuit leadership to ensure their priorities and perspectives are reflected in the work ahead. Today’s meeting is an important step forward in making sure the Building Canada Act supports a better future for Inuit across Inuit Nunangat.”

    “Canada will build major projects in true partnership with Inuit, and we’ll be guided by equity, inclusion, and shared prosperity. Through consultation and collaboration, Inuit voices are shaping the future of infrastructure, sovereignty, and economic opportunity across Inuit Nunangat.”

    “Canada is an Arctic nation, and we are at a critical moment, when it is imperative that we safeguard our sovereignty and defend our Arctic interests. Serving as Canada’s senior Arctic official, Ambassador Mearns will advance Canada’s polar interests in multilateral forums, engage with counterparts in Arctic and non-Arctic states, and serve as a representative in our diplomatic corps.”

    Quick facts

    • Inuit Nunangat is the Inuit homeland in Canada. It encompasses the land, water, and ice of four treaty regions represented by the Inuvialuit Settlement Region of the Northwest Territories, Nunavut, Nunavik in Northern Québec, and Nunatsiavut in Northern Labrador.
    • The Building Canada Act ensures consultation with Inuit and other Indigenous Peoples is built into the implementation process for determining whether a project is in the national interest and for the development of the conditions for permits and authorizations.
    • The Building Canada Act ensures respect for treaty rights, including modern treaties with Inuit Treaty Organizations. It does not alter processes established under modern treaties or the Government of Canada’s modern treaty obligations. It also respects treaty-based environmental assessment processes.
    • Canada’s new Arctic Ambassador, Virginia Mearns, is a respected Inuit leader with a long-standing commitment to advancing Inuit self-determination and community well-being in Nunavut. She currently serves as Senior Director of Inuit Relations at the Qikiqtani Inuit Association and has held senior roles in the Government of Nunavut and with Nunavut Tunngavik Inc. An active member of her community, she was awarded the King Charles III Coronation Medal for her exceptional contributions.
    • Since the signing of the Inuit Nunangat Declaration in 2017, Inuit leadership and the Government of Canada have continued to work together through the ICPC toward a renewed Inuit-Crown relationship based on the recognition of rights, respect, and co-operation.
    • The Inuit Nunangat Policy promotes Inuit self-determination and supports community and individual well-being throughout Inuit Nunangat, with the goal of achieving socio-economic equity between Inuit and all other people living in Canada. It provides a minimum standard for what can be expected from the relationship between Inuit and all federal departments and agencies, and includes guidance to federal departments and agencies on how to deliver programs, policies, and services in Inuit Nunangat.

    Biographical note

    MIL OSI Canada News

  • MIL-OSI New Zealand: Employment and Equity – Not Done Yet: Women’s Day of Action for Pay Equity – CTU

    Source: NZCTU

    On Saturday 20 September communities across Aotearoa will unite for a Women’s Day of Action for Pay Equity – taking place 132 years after New Zealand women secured the right to vote. This mobilisation responds directly to the Government’s gutting of pay equity.

    “This week, alongside our affiliated unions, we handed the Government a petition with 93,924 signatures demanding they stop this attack on workers. But we’re not done. The Women’s Day of Action is another opportunity for women to show the Government that this issue is not going to go away,” said NZCTU Secretary Melissa Ansell-Bridges.

    “These changes have hurt Māori, Pacific, migrant, and low-paid women – nurses, teachers, care and support workers and more who are the backbone of Aotearoa. We will keep fighting until pay equity is restored, and workers’ rights are respected.

    “Over 180,000 workers have already had their pay equity claims scrapped. The changes make it nearly impossible to lodge new claims and allow employers to opt out entirely.

    “Pay equity isn’t just the right thing to do – for many workers, it’s the difference between working one job or two, between feeding their kids or going without.

    “The Women’s Day of Action is both a protest and a celebration of women’s legacy, honouring the suffrage movement while amplifying collective power. The event is family-friendly and community-led, with kai, performances, and opportunities to hold politicians accountable. Participants are encouraged to wear purple, green, and white in honour of suffragists.

    “A range of actions all over the country are being planned. Whether you march in Auckland, gather in Porirua or Christchurch, raise your voice in Wellington, have a crafternoon in Invercargill or show support online – you are part of this movement.

    “On September 20, we are sending a clear message: pay equity is not optional, and we will not back down,” said Ansell-Bridges.

    MIL OSI New Zealand News

  • MIL-OSI USA: Gov. Pillen Touts Historic Income Tax Relief

    Source: US State of Nebraska

    . Pillen Touts Historic Income Tax Relief

    LINCOLN, NE – Governor Jim Pillen released the following statement after the Tax Rate Review Committee met to review the State’s fiscal position. The Committee has again supported the established tax rates. 

    “It’s pretty simple: Nebraskans should be able to keep more of what they earn,” said Gov. Pillen. “By signing historic income tax relief into law, we’re giving families and seniors in our state a boost. When we shrink government and cut spending, we can focus on providing better outcomes and improving services for everyone in our state. There’s more work to do to drive down taxes in this state, but our goal is to keep fighting to make Nebraska – for generations to come – the best place to live, work, and raise a family.”

    The Committee review is great news for Nebraska families and businesses who will see income tax rates fall from 5.2% to 4.55% this coming January, and down again to 3.99% beginning 2027. The reduced tax rates were set in motion in 2023 by legislation introduced on behalf of Governor Pillen.

    Today, the Committee reviewed end of year numbers for fiscal year 2025 and projections for the next two fiscal years. The July financial status report includes assumptions which will be updated prior to the October meeting of the Nebraska Economic Forecasting Advisory Board. State spending was under budget last year by $362 million. Some of this will be used for prior year obligations and $36 million is projected to lapse back to the General Fund. Compared with current projections, we are likely to see a higher lapse of unspent prior year funds, less mid-biennium spending, and higher reserve balances.

    The Committee also acknowledged a calculated variance from the required $337 million surplus reserve. The $47.7 million needed in each year to shore up the variance is equivalent to less than a percent of annual revenue and is well below Governor Pillen’s targeted budget reductions.  The total reserve, including the surplus reserve, is expected to remain above $1 billion. The impact of the Governor’s spending reductions will be finalized during the 2026 legislative session.

    MIL OSI USA News

  • MIL-OSI: Chang Development Company Founder Featured in Washington Times Editorial on Taiwan’s “Great Recall”

    Source: GlobeNewswire (MIL-OSI)

    NEW YORK, July 24, 2025 (GLOBE NEWSWIRE) — As Taiwan undergoes a historic wave of civic action known as the “Great Recall,” U.S.-based investment firm Chang Development Company and its founder Orina Chang are gaining recognition for championing democratic values through cross-border investment and thought leadership.

    In a July 22 Washington Times editorial titled “Why the U.S. Should Heed Taiwan’s Citizen-Led Recall Movement”, Chang framed the recall as “a public immune response to constitutional erosion,” emphasizing that “defense begins not at the border, but in the legislature, in the constitution, and in the resolve of ordinary citizens.”

    Chang, a former Wall Street investment manager turned civic entrepreneur, leads Chang Development Company with a dual focus: supporting democracy and advancing investment in frontier markets aligned with U.S. and Taiwan interests — including energy security and critical minerals. The firm is currently leading a strategic initiative in Somaliland with backing from international partners.

    This is not the first time Chang has used her financial platform to engage policy. Earlier this year, she penned another Washington Times editorial, “Building Taiwan’s Sovereign Wealth Fund”, which laid out a roadmap for Taiwan to secure its economic future through responsible and globally integrated investment mechanisms.

    “We don’t just invest in assets — we invest in resilience, institutions, and values,” said Chang. “What’s happening in Taiwan today isn’t just domestic news; it’s a global signal that democracies must act early to defend themselves from within.”

    About Chang Development Company

    Chang Development Company (CDC) is a cross-border investment firm based in New York. The firm focuses on critical minerals, economic diplomacy, and frontier market partnerships that align capital with democratic governance and long-term resilience.

    Contact:

    Orina Chang
    orinachang@me.com
    orinachang.com

    The MIL Network

  • MIL-OSI USA: Warner, 28 Senators Call on Administration to Conduct Independent, U.S.-Led Investigation into Death of American Citizen in West Bank

    US Senate News:

    Source: United States Senator for Commonwealth of Virginia Mark R Warner
    WASHINGTON – Today, U.S. Sen. Mark R. Warner (D-VA) joined Sen. Chris Van Hollen (D-MD) and 27 of their Senate Democratic colleagues in a letter to Secretary of State Marco Rubio and Attorney General Pam Bondi calling on the Administration to conduct an independent investigation into the death of Saifullah Kamel Musallet, an American citizen recently killed near the West Bank town of Sinjil. The Senators point to the repeated lack of accountability in the deaths of other American citizens killed in the West Bank since January 2022, including Shireen Abu Akleh, Omar Assad, Tawfic Abdel Jabbar, Mohammad Ahmed Mohammad Khdour, Aysenur Ezgi Eygi, and Amer Mohammad Saada Rabee. Given that, the Senators also ask for an update on the status of any investigations into the killings of these six other Americans.
    The Senators wrote, “We write with grave concern regarding the brutal killing of a Palestinian-American, Saifullah Kamel Musallet, near the West Bank town of Sinjil, on July 11, 2025. The U.S. government must conduct a credible and independent investigation into his death and hold all perpetrators accountable. Protecting and supporting U.S. citizens abroad is one of the foremost responsibilities of the U.S. government. The United States Government has failed to secure accountability for the killing of respected Palestinian American journalist Shireen Abu Akleh, or any of the other five American citizens – Omar Assad, Tawfic Abdel Jabbar, Mohammad Ahmed Mohammad Khdour, Aysenur Ezgi Eygi, and Amer Mohammad Saada Rabee – killed in the West Bank since January 2022. Following the Trump Administration’s sudden revocation of all U.S. sanctions against extremist settlers in the West Bank, the first five months of 2025 have seen the highest rate of settler attacks in years and the killing of another American. We urge you to pursue a different approach.” 
    “Saifullah Kamal Musallet is the seventh American citizen killed in the West Bank since January 2022 — and the fifth in just the last nineteen months. The killings of these Americans in the West Bank have been met by a lack of accountability from the Netanyahu government and an inability to secure justice by the U.S. government. These failures have contributed to an unacceptable culture of impunity when it comes to incidents where civilians have been killed in the West Bank, including Americans,” they continued. 
    The Senators noted, “The Netanyahu government has failed to hold anyone accountable for any of these seven killings of Americans and the United States government has failed in its responsibility to protect American citizens overseas and demand justice for their deaths.”  
    “It is long past time for the U.S. government to demand accountability in these killings of Americans. To that end, we urge you to immediately launch an independent investigation into the brutal killing of Saifullah Kamel Musallet, including the circumstances that blocked ambulances from reaching him. We also ask that you provide us with an update on the status of any investigations into the killings of the six other Americans who have been killed since January 2022, and provide us with a briefing on actions you are taking to ensure accountability for their deaths and to prevent future killings of Americans in the West Bank,” the Senators closed. 
    In addition to Sen. Warner, the letter was signed by Senators Van Hollen, Murray, Kaine, Durbin, Reed, Shaheen, Schatz, Merkley, Sanders, Warren, Cantwell, Welch, Smith, Baldwin, Markey, Warnock, Lujan, Ossoff, Kim, Heinrich, Duckworth, Klobuchar, Whitehouse, Hirono, Booker, Alsobrooks, Blunt Rochester, and Murphy. 
    The full text of the letter is available here and below.
    Dear Secretary Rubio and Attorney General Bondi, 
    We write with grave concern regarding the brutal killing of a Palestinian-American, Saifullah Kamel Musallet, near the West Bank town of Sinjil, on July 11, 2025. The U.S. government must conduct a credible and independent investigation into his death and hold all perpetrators accountable. Protecting and supporting U.S. citizens abroad is one of the foremost responsibilities of the U.S. government. The United States Government has failed to secure accountability for the killing of respected Palestinian American journalist Shireen Abu Akleh, or any of the other five American citizens – Omar Assad, Tawfic Abdel Jabbar, Mohammad Ahmed Mohammad Khdour, Aysenur Ezgi Eygi, and Amer Mohammad Saada Rabee – killed in the West Bank since January 2022. Following the Trump Administration’s sudden revocation of all U.S. sanctions against extremist settlers in the West Bank, the first five months of 2025 have seen the highest rate of settler attacks in years and the killing of another American. We urge you to pursue a different approach.
    Saifullah Kamal Musallet is the seventh American citizen killed in the West Bank since January 2022 — and the fifth in just the last nineteen months. The killings of these Americans in the West Bank have been met by a lack of accountability from the Netanyahu government and an inability to secure justice by the U.S. government. These failures have contributed to an unacceptable culture of impunity when it comes to incidents where civilians have been killed in the West Bank, including Americans.
    Saifullah Kamel Musallet, a 20-year-old U.S. citizen from Florida, was visiting family in the West Bank when he was beaten to death by extremist Israeli settlers during a settler attack on the town of Sinjil. Reports indicate that ambulances could not reach the injured for more than two hours, with eyewitness accounts stating that settlers and Israeli forces impeded ambulance access. In April of this year, a 14-year-old boy from New Jersey, Amer Mohammad Saada Rabee, was also killed in the West Bank. Amer was reportedly shot at the entrance to Turmus Ayya by Israeli security forces. Reports suggest that Amer was shot a total of 11 times and two other Americans were also shot in the incident. 
    Last year, three other U.S. citizens were killed in the West Bank, including two teenagers. Tawfic Abdel Jabbar and Mohammad Ahmed Mohammad Khdour were both 17-year-old U.S. citizens visiting their families in the West Bank when they were shot and killed in separate incidents. In both cases they were shot in the head while they were traveling in vehicles. The third U.S. citizen killed in the West Bank last year was Aysenur Ezgi Eygi, a 26-year-old American citizen raised in Seattle who, according to reports, was shot in the head by an Israeli soldier from a distance of 200 meters. 
    The Netanyahu government has failed to hold anyone accountable for any of these seven killings of Americans and the United States government has failed in its responsibility to protect American citizens overseas and demand justice for their deaths.
    It is long past time for the U.S. government to demand accountability in these killings of Americans. To that end, we urge you to immediately launch an independent investigation into the brutal killing of Saifullah Kamel Musallet, including the circumstances that blocked ambulances from reaching him. We also ask that you provide us with an update on the status of any investigations into the killings of the six other Americans who have been killed since January 2022, and provide us with a briefing on actions you are taking to ensure accountability for their deaths and to prevent future killings of Americans in the West Bank.
    We respectfully ask for a response within two weeks.
    Sincerely,

    MIL OSI USA News

  • MIL-OSI USA: Grassley Urges President Trump to Protect Whistleblowers While Cutting Federal Waste, Fraud and Abuse

    US Senate News:

    Source: United States Senator for Iowa Chuck Grassley
    WASHINGTON – In a letter to President Donald Trump, Sen. Chuck Grassley (R-Iowa), co-founder and co-chair of the Whistleblower Protection Caucus, praised the president’s efforts to eliminate waste and fraud and requested that the administration ensure whistleblowers are not terminated or retaliated against after making legally protected whistleblower disclosures.
    “For decades, my oversight work has exposed bloated government that’s broken faith with the American taxpayer. Trillions of dollars of taxpayer money have been lost to waste, fraud and abuse … However, I write today because it’s important that federal agencies aren’t using this downsizing initiative as an excuse to retaliate against federal workers who have made protected whistleblower disclosures. If that has happened, this would not only be unlawful but also have a severe chilling effect on federal employees who would otherwise blow the whistle,” Grassley wrote.
    Grassley asked the administration to identify potential federal employees who were terminated after making a legally protected whistleblower disclosure and whose firing was not part of the administration’s overall Reduction in Force initiative. In the letter, Grassley requested each case be individually reviewed to ensure the termination, or pending termination, was not done because of the protected disclosure.
    “Whistleblowers are the government’s most powerful tool to root out waste, fraud, and abuse … In many circumstances, the misconduct and wrongdoing these patriotic whistleblowers risk their careers, livelihoods, and reputations to bring to light would have never been known to Congress, the federal government, or the American people if they didn’t have the guts to come forward. Yet, in many instances, they aren’t thanked for coming forward; rather, they’re treated like skunks at a picnic,” Grassley continued.
    The Internal Revenue Service (IRS) whistleblowers who made legally protected disclosures about misconduct in the handling of the Hunter Biden investigation faced retaliation by the Biden IRS and several attempts to discredit their reputations and ruin their careers. After President Trump returned to office, Grassley worked with the Trump administration to secure the whistleblowers’ promotions at the Treasury Department.
    Grassley also worked with the Trump administration to secure promotions and back pay for three Customs and Border Protection employees: Mark Jones, Mike Taylor, and Fred Wynn. At Grassley’s urging, the Trump administration also restored law enforcement credentials, badges and firearms for Jones and Taylor after they were revoked by the Biden administration. All three were retaliated against by the Biden administration for blowing the whistle on that administration’s failure to secure the border.
    Background:
    Grassley has consistently worked to ensure federal agencies treat whistleblowers fairly and are held accountable for whistleblower retaliation. He coauthored and helped lead the introduction of the original Whistleblower Protection Act, which passed Congress unanimously and was signed into law by then-President George H.W. Bush.
    He also helped get the Whistleblower Protection Enhancement Act of 2012 signed into law, which included a Grassley-authored “anti-gag” provision. This makes federal agency nondisclosure policies, forms and agreements unenforceable unless they contain a provision notifying the employee that the agreement doesn’t prohibit them from making whistleblower disclosures to Congress, the Office of Special Counsel or an Inspector General.
    Full text of the letter is available HERE and below.
    July 24, 2025
    VIA ELECTRONIC TRANSMISSION
    The Honorable Donald J. TrumpPresident of the United StatesThe White House1600 Pennsylvania AveWashington D.C. 20500
    Dear President Trump:
    I applaud your efforts to eliminate waste and fraud within the federal government. For decades, my oversight work has exposed bloated government that’s broken faith with the American taxpayer. Trillions of dollars of taxpayer money have been lost to waste, fraud and abuse while some within the federal workforce ride the gravy train without actually doing the job for which they’re on payroll. As you work to eliminate government waste and fraud, it is necessary to reduce the federal workforce and federal building footprint. However, I write today because it’s important that federal agencies aren’t using this downsizing initiative as an excuse to retaliate against federal workers who have made protected whistleblower disclosures. If that has happened, this would not only be unlawful but also have a severe chilling effect on federal employees who would otherwise blow the whistle.
    Accordingly, I write to you concerning a potential subset of federal employees: federal employees outside of your administration’s Reduction in Force initiative who have been fired or otherwise retaliated against because they made legally protected whistleblower disclosures. If a federal employee fits within that category, it’s critically important that any individual personnel action and the federal agency’s investigation into allegations of reprisal are fair and comply with constitutional and statutory whistleblower protections. As a first step, I strongly encourage your administration to identify the universe of federal employees who were terminated outside of any Reduction in Force initiative and who made legally protected whistleblower disclosures. If federal employees within that universe do, in fact, exist, I further request that their case be individually reviewed to ensure that their termination, or pending termination, was not done because of that protected disclosure.
    Whistleblowers are the government’s most powerful tool to root out waste, fraud, and abuse. Indeed, our Founding Fathers recognized the significant importance of whistleblowers by enacting the first whistleblower protection legislation in our nation’s history in 1778 during the Second Continental Congress. In many circumstances, the misconduct and wrongdoing these patriotic whistleblowers risk their careers, livelihoods, and reputations to bring to light would have never been known to Congress, the federal government, or the American people if they didn’t have the guts to come forward. Yet, in many instances, they aren’t thanked for coming forward; rather, they’re treated like skunks at a picnic.
    For example, the brave Internal Revenue Service (IRS) whistleblowers who made legally protected disclosures about misconduct in the handling of the Hunter Biden investigation faced retaliation by the IRS and several attempts to discredit their reputations and ruin their careers. I was glad to see that your administration has done right by the IRS whistleblowers and promoted them, where the Biden administration retaliated against them. The same can be said of the Department of Homeland Security/Customs and Border Protection whistleblowers who faced years of retaliation for blowing the whistle on the government’s failure to collect DNA at the border. Your administration gave them their guns, badges, and retirement back. Many other whistleblowers from all over the federal government have done and continue to do the same, putting everything on the line to expose waste, fraud, abuse, and misconduct. These patriotic whistleblowers ought to be rewarded for their courage and sacrifices, not subjected to retaliation.
    Throughout my career I’ve committed to ensuring that federal agencies treat whistleblowers fairly and are held accountable for whistleblower retaliation. I coauthored and helped lead the introduction of the original Whistleblower Protection Act, which passed Congress unanimously and was signed into law by then-President George H.W. Bush. I also cosponsored and worked to get the Whistleblower Protection Enhancement Act of 2012 signed into law, which included language I authored, known as the “anti-gag” provision. This provision makes federal agency nondisclosure policies, forms, and agreements unenforceable unless they contain a provision notifying the employee that the agreement doesn’t prohibit them from making whistleblower disclosures to Congress, the Office of Special Counsel, or an Inspector General.
    Further, I’ve championed laws and legislation to expand whistleblower protections to employees of the Federal Bureau of Investigation and the Intelligence Community. But just because we’ve passed good laws does not mean we can stop paying attention to the issue. I founded the bipartisan Whistleblower Protection Caucus to encourage my Senate colleagues to further strengthen protections for whistleblowers and to recognize the sacrifices they make for our country. Those who fight waste, fraud, and abuse in government should be lauded for their patriotism. Accordingly, I strongly urge federal agencies to ensure all allegations of whistleblower retaliation are given fair and appropriate review, investigation, and consideration.
    And, finally, I kindly remind you of my outstanding request that you hold a Rose Garden ceremony for whistleblowers.
    Thank you for your attention to this important matter.
    Sincerely,
    Charles E. GrassleyChairmanCommittee on the Judiciary

    MIL OSI USA News

  • MIL-OSI USA: Durbin Reintroduced Bill To Combat Alarming Rise In Domestic Terrorism Threats

    US Senate News:

    Source: United States Senator for Illinois Dick Durbin
    July 24, 2025
    As the Trump Administration reallocates resources away from domestic terrorism prevention efforts to fund an illegal mass deportation campaign, the Domestic Terrorism Prevention Act would codify and bolster key tools and resources to combat domestic terrorist threats
    WASHINGTON – Today, U.S. Senate Democratic Whip Dick Durbin (D-IL), Ranking Member of the Senate Judiciary Committee, reintroduced legislation to address the growing domestic terrorism threat. The Domestic Terrorism Prevention Act of 2025 would enhance the federal government’s efforts to prevent domestic terrorism by establishing offices dedicated to combating this threat; requiring federal law enforcement agencies to regularly assess this threat; and providing training and resources to assist state, local, and tribal law enforcement in addressing it, among other things.
    “There is zero justification for discrimination and hate in our country—regardless of ideology. Tragically, we’re witnessing the Trump Administration reallocate resources away from domestic terrorism and hate crimes prevention efforts across the government, which are meant to protect Americans of all backgrounds against discrimination.
    “With the alarming rise in domestic terrorism threats in America, we need to bolster our government’s capabilities to detect, curb, and prevent potential attacks. I believe—and the American people believe—that’s a central responsibility of our government: to keep us safe, secure, and free. This should be a bipartisan solution, and I will again push for it to become law,” said Durbin.
    The Domestic Terrorism Prevention Act of 2025 authorizes the Department of Justice (DOJ), Department of Homeland Security (DHS), and Federal Bureau of Investigation (FBI) offices that are responsible for monitoring, analyzing, investigating, and prosecuting domestic terrorism. The bill also requires these offices to issue joint biannual reports to the House and Senate Judiciary, Homeland Security, and Intelligence Committees that assess the domestic terrorism threat posed by white supremacists; analyze domestic terrorism incidents that occurred in the previous six months; and provide transparency through a public quantitative analysis of domestic terrorism-related assessments, investigations, incidents, arrests, indictments, prosecutions, convictions, and weapons recoveries. DHS, DOJ, and FBI offices would be required to focus their limited resources on the most significant domestic terrorism threats, as determined by the number of domestic terrorism-related incidents outlined in the joint report.
    The legislation also:
    Codifies the Domestic Terrorism Executive Committee (DTEC), an interagency task force, which was originally created by the Department of Justice in the wake of the Oklahoma City bombing;
    Provides additional clarity regarding which federal law enforcement officials shall serve on the DTEC authorized by the bill; and
    Requires that the Executive Committee meet with local community groups to foster greater collaboration and dialogue to help combat domestic terrorism.
    Additionally, the bill requires DOJ, DHS, and the FBI to provide training and resources to assist state, local, and tribal law enforcement in understanding, detecting, deterring, and investigating acts of domestic terrorism. Finally, the legislation would establish an interagency task force to combat white supremacist and neo-Nazi infiltration of the uniformed services.
    In May 2022, Senate Republicans filibustered the House-passed Domestic Terrorism Prevention Act.
    Bill text is available here.
    During his tenure as Chair of the Senate Judiciary Committee, Durbin held a hearing entitled “A Threat to Justice Everywhere: Stemming the Tide of Hate Crimes in America.” The hearing examined the threats facing marginalized communities and how the federal government can better protect the civil rights and safety of all Americans, including Jewish, Arab, and Muslim Americans. Durbin also raised the issue in a March 2025 hearing on combatting antisemitism.
    Additionally, under Durbin’s leadership as Chair, the Committee held several other hearings to examine the issue of hate crimes and domestic terrorism, including a hearing on “Combating the Rise in Hate Crimes” shortly after the January 15, 2022, synagogue attack in Colleyville, Texas, and a hearing examining the “Metastasizing’ Domestic Terrorism Threat After the Buffalo Attack,” which explored the continued threat posed by violent white supremacists and other extremists, including those who have embraced the so-called “Great Replacement” conspiracy theory, after a mass shooting by a white supremacist in Buffalo on May 14, 2022. The white supremacist who murdered 11 people at the Tree of Life Synagogue in Pittsburgh in 2018 also embraced this conspiracy theory.
    Durbin first held a hearing on domestic terrorism threats in 2012, after a white supremacist murdered seven Sikh worshipers in Oak Creek, Wisconsin.
     
    -30-

    MIL OSI USA News

  • MIL-OSI USA: July 24th, 2025 Heinrich Criticizes Trump Administration for Working to Stall Energy Projects and Raise Costs on Families

    US Senate News:

    Source: United States Senator for New Mexico Martin Heinrich

    WASHINGTON — During a U.S. Senate Energy and Natural Resources Committee hearing on energy demand growth, U.S. Senator Martin Heinrich (D-N.M.), Ranking Member of the Committee, pressed Jeff Tench, Executive Vice President of Vantage Data Centers and Rob Gramlich, CEO and Founder of Grid Strategies LLC, on Trump Administration actions that are impacting grid reliability and driving up families’ energy costs.

    VIDEO: U.S. Senator Martin Heinrich (D-N.M), Ranking Member of the U.S. Energy and Natural Resources Committee questions Jeff Tench, Executive Vice President of Vantage Data Centers and Rob Gramlich, CEO and Founder of Grid Strategies LLC.

    On the Trump Administration Adding Burdensome Red Tape to Clean Energy Project Approvals

    Senator Heinrich began by asking Jeff Tench, Executive Vice President of Vantage Data Centers, how the Trump Administration adding additional reviews and red tape impacts businesses and grid reliability, “So Mr. Tench, you may be aware, the Department of the Interior recently released a memo that’s going to require the Secretary to review all wind and solar projects on federal lands. It adds just one more layer of red tape. Do you have opinions on what the potential business impacts of energy projects just being delayed in that regulatory process? How that further delays impact the business prospect?”

    Tench responded, affirming that new directives from the Trump Administration will negatively impact business and adding new generation to the grid, “Our observation and our requirement is for more electrons, as you called out in your opening remarks, Vantage is relatively agnostic as to the source of those electrons. So, in the case of rule making or regulatory action that slows down the process of approving new generation or new transmission, would definitely be a negative for our business.”

    Heinrich followed up, “Should in the, in the sort of five-year window like 2025 to 2030, shouldn’t we be focused on putting as many electrons, agnostic of generation source, on the grid as possible to be able to meet the kind of demand that you represent?”

    Tench answered, “Yes, our position is that efforts to move electrons around through enhanced transmission is important, necessary, but insufficient relative to the overall demand. We need more energy, more generation, and more generation, and we need more transmission independent of source. That said, it does need to be a reliable, grid dispatchable source, which I believe, you know, can be accomplished with the right combination of energy source for generation and energy storage.”

    Heinrich responded, alluding to the Trump Administration’s recent reckless actions that stall projects despite growing energy demands, “You know, one of my concerns is we have we have an existing pipeline that is the result of decisions that have been made over the course of the last decade. That pipeline is 95% clean energy plus storage. It’s about 5% gas. You know, a year or two ago, we had a couple of nuclear plants come online, which are great. I support that, but that’s kind of a one off. You know, in the next five years, if we start building new nuclear today, whether that’s SMRs or traditional light water reactors, that’s going to take longer than the five-year window. If I order a combined cycle natural gas turbine today, it’s probably going to come on the grid in 2032 2033 if we’re lucky. So, if you don’t allow the existing projects that are in the queue today, that are our renewables plus storage. What does that do to the price pressure on the grid? What’s the impact of that?”

    Tench answered, “As it relates to price pressure, I’ll probably defer to Rob on that question as more of a grid expert, but in the broader context, our goals are to encourage speed of change in regulatory process, to bring more electrons on the grid. And again, depending upon the site in which we’re developing, our access to proximate energy sources varies, and we are being very pragmatic about how we approach that and make available to ourselves whatever we can in order to meet the demand.”

    Heinrich followed, “Mr. Gramlich, do you want to address the price pressure issue?”

    Gramlich, CEO and Founder of Grid Strategies LLC, answered, confirming that the Administration’s actions to limit new generation is raising costs on consumers, “Sure. I mean, basically it’s supply and demand. There’s scarcity of generation. So, anything that is limiting new generation from coming on, whether it’s interconnection queues, permitting hold ups that Interior, or anything else that’s cutting off supply, and that is definitely raising prices. And we are seeing prices go up wholesale power prices are going up. That is required. Those higher costs are required to be incorporated by state public utility commissions into retail bills. So, retail consumers…”

    Heinrich intervened, “Are there places where prices have actually come down in recent years that you can point to and what was the reason why those prices came down?”

    Gramlich answered, “Sure. Well, I mean, if you just look at, say, the supply stack for some places like Texas. Texas, just over the last couple of days, has had a majority of their peak demands, not just, you know, overnight, not just winter peak, afternoon air conditioning, driven demand served by a majority renewables plus storage.”

    Heinrich pressed, “And were there rolling blackouts?”

    Gramlich answered, “There were not. Reliability. Reliability is better? Yeah, you probably heard about rolling blackouts in California, like five years ago. Honestly, they got behind on resource adequacy. But what did they do? They built a lot of solar and batteries. So same dynamic there. I’m sure we’re seeing a majority renewable energy. Any hour now it’s going to kick in, and then when the air conditioning load this afternoon is high, there’s going to be solar and then the sun will set, air conditioning load will still be high, but the batteries will then kick in and serve through the evening. So again, they don’t do everything.”

    On How the Trump Administration is Raising Families’ Electricity Costs

    Heinrich asked Gramlich, “One of the things we have to deal with here is these agencies and the role that they play in permitting new generation and transmission. So Mr. Gramlich, if, if our permitting agencies, for example, the Department of the Interior, which has added this new level of red tape stall or slow walk permits for generation projects, which we’re currently seeing, and those permit projects, as a result, don’t get on the grid, or they get on the grid slower. What’s the impact to people who pay retail electric prices?”

    Gramlich replied, testifying to how the Trump Administration is raising energy costs on consumers as a result of recent directives, “Sure. Well, obviously that will raise prices. And what’s happening is, you know, love it or hate it, many utilities with their state regulators have put in place plans for the next few years how they’re going to meet load. There might be retirements. There might be load growth. They routinely go through these plans. And just the reality is, it’s largely wind, solar and storage that are in those plans.”

    Heinrich followed, “About 95% in most cases.”

    Gramlich agreed, “Right.”

    Heinrich continued, “So if you take that 95% out, even some portion of it, say a third, what are you going to replace it with in year one, two or three, nothing.”

    Gramlich replied, “Curtailment.”

    Heinrich followed, “Curtailment, exactly. Exactly. Why I say capacity factors is because I’m an engineer, and I don’t remember a lot of the terms, the buzzwords that we get thrown at around a lot here now: firm, baseload, dispatchable. What I remember from my education is capacity factors, right? And if you look at generation today, you know, I have wind in my state that has a 40% capacity factor. It’s not perfect, but it’s pretty darn good. You know, what else has a 40% capacity factor, Mr. Gramlich? Coal today in the United States of America. Everybody says it’s firm and base load, and it’s not. It’s not because it’s expensive and it’s unreliable, and when you have a coal fire generating station go down, the whole thing goes down. Doesn’t go down 3%, it doesn’t go down 10% — you lose that generation until that thermal plant is back up and running. So, in your testimony, you talked about the increase in demand over time. DOE also is predicting a similar amount, about 2% a year, but they’re also claiming that there is somehow 100-fold increased risk of outage, and this relates to capacity factor issue. If forecasted retirements occur between now and 2030, as predicted, what were the assumptions that went into that, that were baked into that claim?”

    Gramlich answered, “Yeah, I think the Department of Energy, I mean, they provided useful analysis with this, this report, but I think they’ve vastly overstated the retirements of generation. And as I said earlier, we have processes, either through utility planning or market to you know, to discourage or prevent retirements, and that’s happening. But also on the supply addition side, there’s a lot more generation out there that could come onto the grid, and I think the Department of Energy study understated that new supply. So, if you understate supply, overstate retirement, suddenly you have a reliability crisis. But it might just be manufactured by those numbers.”

    Heinrich continued, “Yeah, we certainly haven’t seen that in New Mexico, and we haven’t seen that next door in Texas, where they have a totally separate grid from ours, but they’re bringing on lots of new sources of generation, lots of new solar and batteries in particular. You know, transmission lines are such an important piece of all this, because they do help us wield power around the country, and it’s hard to build transmission. It’s why we need to actually do permitting reform, which this Committee did last Congress but hasn’t done this Congress yet. You know, I worked on one transmission line for 17 years of my life, and today it is has facilitated, you know, tens of billions of dollars of economic output. It’s facilitated the largest renewable project in the continent’s history. But it wasn’t easy to get that done if you create a system where the politics can change overnight, where, for example, a loan from the Loan Program Office can be decided by politics rather than by metrics. What is the impact of that on reliability and on price pressure?”

    Gramlich answered, “Well, I mean, so many utilities have testified before this Committee over the years about the need for stability. They’re making 60-year investments, six zero, and if the policies change 180 degrees every four years, they simply can’t do that. So the point is well taken. We need some stability. I do think FERC is a great place for a lot of these orders as a bipartisan, non-partisan agency for permitting. They could do more in that regard, and but we need, we need to get that regulatory stability for investment.”

    MIL OSI USA News

  • MIL-OSI United Kingdom: expert reaction to systematic review and meta-analysis of long-term air pollution exposure and dementia

    Source: United Kingdom – Executive Government & Departments

    A systematic review and meta analysis published in Lancet Planetary Health looks at long-term air pollution exposure and dementia incidence.

    Dr Mark Dallas, Associate Professor in Cellular Neuroscience, University of Reading, said:

    “While air pollution joined dementia’s 14 modifiable risk factors in 2024, the specific culprits remain unclear. This new research examined existing data and identified three main culprits: tiny particles from car exhaust, nitrogen dioxide from vehicles and power plants, and black carbon from diesel engines. These findings strengthen the evidence that we can protect brain health through cleaner policies targeting diesel pollution and better city planning. However, we still need to understand exactly how these pollutants damage the brain and increase the diversity in dementia research participants. This will help us learn more about how air pollution affects different types of dementia and whether some communities face higher risks than others.”

     

    Dr Tom Russ, Reader in Old Age Psychiatry, University of Edinburgh, said:

    “This high quality article summarises the evidence in this rapidly-expanding area up to October 2023. This article improves on many previous reviews but is subject to similar limitations because of the way this research is often conducted; this reflects the quality of the studies it summarises rather than any shortcomings of this specific article. The review includes articles which examine the association of exposure to air pollution for at least one year (described as ‘long-term’ exposure) with the emergence of dementia diagnosed by a doctor. It includes more studies than any previous article and because of the large number of studies included, the authors can be more accurate in their estimate of the size of the effect of dementia – for instance, their data suggest that the risk of dementia resulting from exposure to air pollution would be 9% lower in Edinburgh compared to London.

    “It is helpful to see the effects of different pollutants examined – though the authors acknowledges that these pollutants may, in fact, interact with each other in having their harmful effects. This speaks to an area this article cannot deal with – if exposure to air pollution does indeed increase the risk of someone developing dementia, what is the mechanism by which this happens? This question has not yet been addressed – in contrast to air pollution and the cardiovascular system where we have a clear mechanistic understanding of the effects of air pollution exposure on the body through experiments where people are exposed to controlled levels of air pollution. We need a similar body of research focused on the brain.

    “The authors try to examine air pollution in relation to different subtypes of dementia – an important area – but because this is often poorly recorded in medical records, they were not able to really tackle this. Most of the time, dementia is simply recorded as ‘dementia’ rather than the specific diagnosis (e.g., Alzheimer dementia, vascular dementia, dementia with Lewy bodies). A further complication is that around half of people with dementia never receive a diagnosis and so don’t appear in medical records.

    “One limitation of all the studies included in the review is that they estimate the amount of air pollution exposure based on someone’s home address. This is not the most accurate measure of air pollution exposure but I am not aware of any studies which have done this any other way, though a better approach is sorely needed.

    “Finally, since we know that many conditions which result in dementia have their origins decades before the emergence of symptoms, studies really need to look at truly long-term air pollution exposure – much longer than one year. Researching this is challenging because few long-term studies have people’s home addresses from their whole lives and measurement or modelling of air pollution levels is rare before the 1990s.

    “This article answers the question of whether air pollution exposure is associated with dementia better than previous work, but we still need better research to clarify how and why air pollution might be bad for the brain. Dementia remains a public health priority but air pollution is just one of several important risk factors and stopping smoking, controlling diabetes, controlling blood pressure and cholesterol in mid-life (amongst other things) are crucial for individuals who want to reduce their own risk of dementia, as well as minimising exposure to air pollution.”

    Dr Ian Mudway, Associate Professor of Environmental Toxicology and Visiting Professor for Environmental Health, Gresham College, Imperial College London, said:

    “This aligns very closely with previous attempts to examine the association between air pollution and dementia. I worked on this back in 2019, and at that time, given the available evidence, we concluded it was too premature to perform a meta-analysis. There were simply too many inconsistencies between studies, particularly concerning exposure assessment.

    “While I believe the evidence base has improved since then, inherent challenges remain in linking long-term air pollution changes to dementia incidence due to the decades-long prodromal period of the disease. It raises the crucial question: “How far back must we look to capture the relevant long-term exposures impacting brain health?”

    “Additionally, as the authors acknowledge, distinguishing between vascular dementia and Alzheimer’s disease purely from medical records remains quite difficult, despite their efforts.

    “The robust associations observed for NO2, black carbon/PM2.5 absorbance, and PM2.5 itself suggest that the effect is related to both local-scale traffic emissions and more regional particulate matter sources. Overall, this paper strongly supports the contention outlined in the Lancet Commission’s dementia reviews that air pollution is a significant and modifiable risk factor for dementia, and addressing it would substantially improve brain health.”

    Prof Roy Harrison FRS, Professor of Environmental Health, University of Birmingham, said:

    “This combined analysis of 51 previously conducted independent studies gives a clear signal that the risk of developing dementia is strongly influenced by air pollution exposure.  This finding is consistent with other research showing associations between a number of measures of brain function and air pollution, and is particularly important given the devastating impacts of dementia both upon individuals and their families, and society as a whole.  It adds to our ever-increasing knowledge of the many diverse harmful effects of air pollution upon health and strengthens the case for firm action to further improve air quality.

    Dr Samuel Cai, Lecturer in Environmental Epidemiology, University of Leicester, said:

    “The press release is accurate, although it could also be mentioned that studies included in this meta-analysis are quite heterogeneous.

    “This is a comprehensive and timely review, including latest primary studies published over the last few years. The conclusion was generally backed by the data presented.

    “Air pollution was only recently identified as a new risk factor for dementia in a Lancet-commissioned research. At the time, evidence for the harmful effects of PM2.5  on dementia seems to be more certain, but evidence  for other pollutants is less conclusive. This review has significantly strengthened the current knowledge base, reporting that PM2.5, NO2 and soot are all adversely linked to dementia development, based on some of most recent publications.

    “This is a systematic review and meta-analysis, and therefore consideration of confounders are usually not applicable in this type of articles. There are two more limitations which may worth further investigation. First, in the studies included in this review, did the effects of air pollution on dementia incidence have been adjusted for other environmental exposures such as greenspace and traffic noise? These two exposures may interact with air pollution in a complex way, and therefore may affect the risk posed by air pollution leading to dementia onset?

    “Second, it is not very clear, at which life stage that air pollution exposure is relatively more important in triggering dementia?  There is some evidence that late-life air pollution exposures seem to be more relevant to dementia incidence, as compared to mid-life or early-life. I think the current evidence pool is still weak on this question, but certainly a direction warranting more research.

    “The implications mentioned by the authors are correct. Air pollution needs to be formally recognised as a risk factor for dementia in clinical practices, and that societal-wide policy actions are needed to tackle air pollution, particularly that from traffic in UK cities and towns, to protect brain health as UK population is ageing.”

     

    Prof Barbara Maher FRS, Professor of Environmental Magnetism, Lancaster University, said:

    “This is another meticulous and large study (~30 million people over 4 continents), which reviews and analyses other painstaking studies, attesting to the damage being done to our brains by breathing in air pollution particles. While this study links outdoor PM2.5 (fine particles less than 2.5 micrometres diameter) with increased dementia incidence, this might represent just the tip of the iceberg. Air pollution contains huge numbers of ultrafine particles (

    “It’s now 9 years since our discovery of huge numbers of traffic-derived, metal-rich nanoparticles inside the frontal cortex of human brains…anywhere between 900 million and 40 billion particles in a gramme of brain tissue. Similar particles have been found directly associated with the amyloid plaques typical of Alzheimer’s disease. And the likely health impacts of exposure to such small, toxic particles don’t end with the brain. They have now been found in human blood, heart, placenta, kidney, bone joints…the body has no effective defense against the ultrafine particle cocktails we generate outdoors, especially from traffic, and indoors, for example, in heating our homes using stoves.

    “What’s more, of course, the nanoparticle ‘mix’ varies from place to place and city to city, so the full scale of the dementia/air pollution pandemic will only become more obvious when epidemiological studies take particle composition, as well as ultrafine size, into account.”

    Dr Isolde Radford, Senior Policy Manager at Alzheimer’s Research UK, said:    
      
    “Air pollution is not just an environmental issue – it’s a serious and growing threat to our brain health. If no one were exposed to air pollution, there would be three fewer cases of dementia for every 100 people who develop it now. This rigorous review adds to mounting evidence that exposure to air pollution – from traffic fumes to wood burners – increases the risk of developing dementia.  
      
    “But poor air quality doesn’t affect all communities equally. As this analysis highlights, marginalised groups are often exposed to higher levels of pollution, yet remain underrepresented in research. Future studies must reflect the full diversity of society – because those most at risk could stand to benefit the most from action.  
     
    “What’s still unclear is exactly how air pollution affects the brain. There are several biological pathways that could explain the link, and to prevent dementia in the future, we need to deepen our understanding of these mechanisms.  
     
    “Air pollution is one of the major modifiable risk factors for dementia – but it’s not something individuals can solve alone. That’s where government leadership is vital. While the 10-Year Health Plan acknowledges the health harms of air pollution, far more needs to be done to tackle this invisible threat. Alzheimer’s Research UK is calling for a bold, cross-government approach to health prevention — one that brings together departments beyond health, including DEFRA, to take coordinated action on the drivers of dementia risk.  
     
    “The UK is still working to meet the World Health Organization’s air pollution limits by 2040 – but that timeline simply isn’t good enough. We have the evidence and the means to reach these targets by 2030. Doing so could help prevent thousands more people from developing dementia. The Government must act now to set stronger, health-based air quality targets – ones that protect our brains as well as our lungs.”

    Long-term air pollution exposure and incident dementia: a systematic review and meta-analysis’ by Clare B Best Rogowski et al. was published in The Lancet Planetary Health at 23:30 UK time on Thursday 24th July. 

    DOI: https://doi.org/10.1016/S2542-5196(25)00118-4

    Declared interests

    Dr Mark Dallas: Dr Dallas receives research funding from the Medical Research Council and Carbon Monoxide Research Trust.

    Dr Tom Russ: I don’t have any conflicts as such but am active in research in this area.

    Prof Roy Harrison: Roy Harrison is a member of the Defra Air Quality Expert Group and the DHSC Committee on the Medical Effects of Air Pollutants. He has research funding from UKRI, Defra and the European Union Horizon Programme.

    Dr Samuel Cai: I do not have any conflict of interest to declare.

    Prof Barbara Maher: None to declare

    For all other experts, no reply to our request for DOIs was received.

    MIL OSI United Kingdom

  • MIL-OSI Russia: Alexander Novak chaired a meeting of the subcommittee on increasing the sustainability of the agricultural engineering industry

    Translation. Region: Russian Federal

    Source: Ministry of Economic Development (Russia) – Ministry of Economic Development (Russia) –

    An important disclaimer is at the bottom of this article.

    Deputy Prime Minister Alexander Novak held a meeting of the subcommittee on increasing the stability of the financial sector and individual sectors of the economy. The situation in agricultural engineering and the work of individual systemically important organizations were discussed.

    The event was attended by the Minister of Economic Development Maxim Reshetnikov, the Minister of Agriculture Oksana Lut, the First Deputy Chairman of the State Duma Alexander Zhukov, the Deputy Chairman of the Federation Council Nikolai Zhuravlev, the President of the Russian Union of Industrialists and Entrepreneurs Alexander Shokhin, representatives of federal authorities, the Central Bank of Russia, heads and representatives of investment banks, development institutions, industry companies, and parliamentarians.

    The meeting participants reviewed the current situation in terms of production and sales of domestic agricultural machinery. It was noted that the measures to support the industry agreed upon at previous meetings of the subcommittee help maintain the sustainability of its work. These include preferential leasing, lending and subsidies, deferrals of payment of the recycling fee, and the possibility for farmers to purchase domestic machinery at discounts.

    In addition, the Russian Ministry of Agriculture is working on the issue of increasing the rate of subsidizing loans issued for the purchase of agricultural machinery. The participants of the meeting agreed that as demand for agricultural machinery stabilizes, and subsidizing loans are launched in the near future, there is currently no need to introduce additional measures to support the industry.

    Alexander Novak instructed the Ministry of Economic Development, the Ministry of Agriculture, and the Ministry of Industry and Trade to continue monitoring the situation in the agricultural engineering sector and to promptly propose solutions to ensure the development of the industry.

    The Deputy Prime Minister also instructed federal authorities to promptly monitor the situation at all systemically important enterprises to ensure their sustainable operation in the current economic conditions.

    “Previously adopted support measures are working successfully and have begun to produce a positive effect from implementation. We continue to monitor the situation, if necessary, we will fine-tune the current measures and return to the issue of developing new mechanisms,” emphasized Alexander Novak.

    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 Russia: Vitaly Savelyev held a meeting on the implementation of the Moscow-St. Petersburg high-speed railway construction project

    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.

    Previous news Next news

    Vitaly Savelyev held a meeting on the implementation of the Moscow-St. Petersburg high-speed railway construction project

    The meeting participants discussed issues related to the continuation of work on the design of the route, as well as the progress of production of the high-speed train, including options for the interior design of the cars and their technical equipment, the supply of parts and components for the first series of trains.

    Key factors in making decisions regarding the selection of parts and finishing elements are related to compliance with deadlines and technical requirements for the train. Delivery of 43 high-speed electric trains is planned until 2030. Until the end of 2028, 28 trains will be operated on the route with a gradual increase in their number in accordance with the supply agreement.

    The maximum speed of the train will reach 400 km/h, and the operating speed will be up to 360 km/h.

    The new highway will reduce travel time between the cities to 2 hours 15 minutes. It is expected that the passenger flow on the route will be at least 23 million people by the end of 2030.

    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 Russia: Dmitry Grigorenko: Executive discipline in drafting bills has reached 100% due to digitalization

    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.

    The government demonstrated a record level of executive discipline in preparing bills based on the results of the first half of 2025. This figure has been continuously increasing due to the introduction of digital tools in the process of developing legislative initiatives. This was reported by Deputy Prime Minister – Chief of the Government Staff Dmitry Grigorenko.

    He noted that 100% of bills were submitted for consideration to the State Duma on time based on the results of the first six months of 2025. Last year, this figure was 99%, in 2023 – 95%, and in 2022 – 84%.

    Over the past year, the number of draft laws for which the deadline for submission to deputies was postponed has been halved. To date, such postponements occur only for 5% of bills. In 2024, the deadline for submission to the State Duma was postponed for 11% of legislative initiatives, and in 2023 – for 38% of such documents.

    Moreover, according to the results of the first half of 2025, the number of government bills increased by 8%, and the number of amendments proposed by the Government increased by 76% compared to the same period last year.

    “Today, when preparing bills and regulations, we use a digital monitoring system. This is not just a control tool, but a new management standard: the system automatically tracks deadlines, records those responsible, and predicts the risks of non-fulfillment of certain tasks. Such transparency has significantly increased the executive discipline of government agencies and ensured 100% fulfillment of plans. This is a clear confirmation of the effectiveness of digital solutions in public administration, and we intend to develop their use,” said Dmitry Grigorenko.

    Since 2020, the Government Office has been operating an information system for monitoring key Government tasks, which includes a separate module for bills and regulatory legal acts. It allows tracking the number of documents that are being processed, their level of readiness, as well as the planned deadlines for submission and signing. At the same time, the data is updated in real time, which allows the Government to promptly respond to the risks of non-fulfillment of plans.

    The system is constantly evolving, taking into account current priorities. Since 2023, it has been recording changes in the deadlines for preparing bills and by-laws, which increases the accuracy of planning. Since last year, it has also been used to control the process of providing feedback and opinions from the Government on legislative initiatives of deputies. As a result, the deadlines for preparing such documents by federal ministries and departments have been reduced by more than half over the past year.

    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 Russia: Mikhail Mishustin held a meeting with the Prime Minister of the Republic of Armenia Nikol Pashinyan

    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.

    The meeting took place on the sidelines of the International Environmental Conference

    Previous news Next news

    Meeting of Mikhail Mishustin with Prime Minister of Armenia Nikol Pashinyan

    The heads of government discussed current issues of Russian-Armenian relations in the trade and economic, scientific and technological, and cultural and humanitarian spheres.

    Drive

    Mikhail Mishustin and Nikol Pashinyan noted the importance of creating favorable conditions for the implementation of joint projects in various fields.

    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 New Zealand: Strengthening primary care to better meet patient needs

    Source: New Zealand Government

    The Government is taking further action to ensure Kiwis can see a doctor, focusing on improved funding for rural practices, faster access to primary care, and a stronger pipeline of locally trained GPs, Health Minister Simeon Brown says.
     

    • Updating GP funding to better reflect patient needs
    • Setting a new health target for faster GP access
    • Backing GP training and retention

    “We want all New Zealanders to be able to see a GP when they need one, regardless of where they live,” Mr Brown says.

    “In rural areas especially, GP clinics with only one doctor or closed books makes it harder for patients to get timely appointments. We’re committed to changing that.

    “The health system should reflect the needs of patients, wherever they live in New Zealand. That’s why we’re making changes to the way GP clinics are funded to ensure money goes where it’s needed most.”

    The government’s funding method for GP clinics, known as capitation, will be updated for the first time in more than 20 years. This is proposed to take effect from 1 July 2026.

    “The current model is outdated and doesn’t reflect the needs of patients. The revised formula will go beyond just age and sex, to also include multimorbidity, rurality, and socioeconomic deprivation.

    “These changes will better distribute funding to where it’s needed most, so that GP clinics with a higher needs population of enrolled patients will receive more funding to care for them.”

    The Government is also introducing a new national health target to drive timely access to primary care.

    “People shouldn’t have to wait weeks to see a doctor. Delays can lead to poorer health outcomes, more pressure on hospitals, and growing frustration for patients. We’re focused on delivering timely, quality care that puts patients first.”

    “This new target will be developed in partnership with the primary care sector and is proposed to ensure that more than 80 per cent of people can see a primary care provider within one week, taking effect from 1 July 2026. It will take effect from 1 July 2026 and aligns with the target of ensuring 80 percent of people receive faster access to primary mental health and addiction services within one week.”

    The Government is also making targeted investments in general practice training to strengthen the GP workforce and support long-term retention.

    “The General Practice Education Programme (GPEP), delivered by the Royal New Zealand College of General Practitioners, is the only accredited training and education pathway in New Zealand for doctors wanting to specialise as GPs. Vocational training through GPEP takes a minimum of three years to complete, but currently only the first year of training is funded. 

    “We are increasing funding for this programme to ensure it is valued and supported in the same way as other medical specialist training programmes.”

    As part of this investment, the Government is funding:
     

    • Training fees in 2025 for doctors in their second, third, and post-third year of GPEP to encourage completion of their training
    • Exam and preparation costs for around 200 GPEP trainees who have completed, or nearly completed, training but not yet taken the fellowship exam
    • Full ongoing training and education costs for approximately 400 GPEP year 2 and 3 trainees each year

    “Our goal is to make general practice a more attractive and sustainable career path, especially in rural and high-needs communities, so we can bring more doctors into the areas that need them most.

    “By fully covering training and exam costs, we’ll enable hundreds of doctors to complete the pathway to becoming GPs, giving them the support they need to finish their training and enter the health workforce – building a stronger pipeline of experienced GPs who can train and mentor the next generation.

    “This Government knows that primary care is the cornerstone of the health system, which is why we’re committed to making it more accessible and responsive to the unique needs of communities.

    “Improving access, particularly in rural and underserved areas, will help ease pressure on hospitals and ensure New Zealanders get timely, quality care when and where they need it,” Mr Brown says.

    MIL OSI New Zealand News

  • MIL-OSI USA: AG Brown files a lawsuit against Fidelity Information Services to protect the personal data of people who apply for or receive food assistance benefits

    Source: Washington State News

    SEATTLE – Attorney General Nick Brown today filed a breach of contract lawsuit against Fidelity Information Services (FIS) to block the company from illegally disclosing the private, personal data of more than one million Washington residents who receive or applied for food assistance benefits to the federal government for its deportation efforts.

    Since 2015, FIS has served as the contractor for Washington’s Department of Social and Health Services (DSHS) to deliver benefit payments to recipients. DSHS administers food assistance programs including the federally funded Supplemental Nutrition Assistance Program (SNAP) and the state-funded Food Assistance Program (FAP). FAP provides food benefits to people who would be eligible for SNAP but are excluded from the federal program because of their immigration status.

    “People who need food assistance for themselves and their families should be able to trust that their data will be protected and kept private,” Brown said. “If a contractor fails to uphold the terms they’ve agreed to, we will hold them accountable under the law.”

    Washington law requires that the information of public benefits applicants and recipients be protected from unauthorized disclosure or improper use. Additionally, the contract with FIS requires the company to get DSHS’s express written consent before disclosing this information and to follow DSHS policies and rules protecting recipients’ information.

    Nevertheless, FIS informed DSHS on May 9 that it intended to turn over the personal data of SNAP cardholders and data about transactions to the U.S. Department of Agriculture (USDA). That came in the wake of guidance from USDA incorrectly claiming it could use federal food benefits law to obtain SNAP data directly from contractors, rather than state agencies, to use for the Trump administration’s immigration enforcement efforts.

    DSHS told FIS on May 14 that the agency does not consent to the disclosure of confidential information to USDA, and FIS initially pledged that it would refrain from sharing the data until authorized. But since then, as USDA has continued its efforts to collect personal data of SNAP recipients, FIS failed to respond to repeated requests from DSHS asking for confirmation that it would not turn over any data without DSHS’s express consent.

    In the complaint, filed in Thurston County Superior Court, Brown argues that DSHS is entitled to a court order blocking FIS from disclosing confidential information to USDA and a declaration that unauthorized disclosure would constitute a breach of contract. The complaint also asks the court to determine that any unauthorized disclosure of confidential and personally identifiable information would violate the Washington Consumer Protection Act and the Washington Law Against Discrimination.

    Brown is asking the court to order FIS not to disclose any confidential information to any third party without the express written consent of DSHS.

    A copy of the complaint is available here.

    -30-

    Washington’s Attorney General serves the people and the state of Washington. As the state’s largest law firm, the Attorney General’s Office provides legal representation to every state agency, board, and commission in Washington. Additionally, the Office serves the people directly by enforcing consumer protection, civil rights, and environmental protection laws. The Office also prosecutes elder abuse, Medicaid fraud, and handles sexually violent predator cases in 38 of Washington’s 39 counties. Visit www.atg.wa.gov to learn more.

    Media Contact:

    Email: press@atg.wa.gov

    Phone: (360) 753-2727

    General contacts: Click here

    Media Resource Guide & Attorney General’s Office FAQ

    MIL OSI USA News

  • MIL-OSI: Athabasca Oil Announces 2025 Second Quarter Results Highlighted by Strong Operational Results, Continued Share Buybacks and a Pristine Financial Position

    Source: GlobeNewswire (MIL-OSI)

    CALGARY, Alberta, July 24, 2025 (GLOBE NEWSWIRE) — Athabasca Oil Corporation (TSX: ATH) (“Athabasca” or the “Company”) is pleased to report its second quarter results marked by strong operational performance, consistent financial results and execution on return of capital commitments. With low corporate break-evens, differentiated long-life assets and a pristine balance sheet, the Company is well positioned to advance its strategic priorities.

    Q2 2025 Consolidated Corporate Results

    • Production: Average production of 39,088 boe/d (98% Liquids), representing 4% (15% per share) growth year-over-year.
    • Cash Flow: Adjusted Funds Flow of $128 million ($0.25 per share). Cash Flow from Operating Activities of $101 million. Free Cash Flow of $66 million from Athabasca (Thermal Oil).
    • Capital Program: $73 million total capital expenditures including $54 million at Leismer to support the 40,000 bbl/d phased growth project.
    • Shareholder Returns: Purchased 24 million shares through its buy-back program year-to-date. The Company is committed to returning 100% of Free Cash Flow (Thermal Oil) to shareholders in 2025 and has completed ~$600 million in share buybacks since March 31, 2023, reducing its fully diluted share count by 21%.

    Operations Highlights

    • Leismer: Production currently ~28,000 bbl/d (June 2025) with four sustaining well pairs expected to be placed on production through the balance of the year. The progressive growth project remains on time and on budget. The Company expects production to stay flat until the next growth plateau of 32,000 bbl/d in H2 2026.
    • Hangingstone: Production currently ~8,900 bbl/d (June 2025) following the start-up of two extended reach well pairs which are outperforming management’s expectations. The asset continues to deliver meaningful free cash flow generation.
    • Duvernay Energy (“DEC”): A four well pad (30% working interest) with ~5,000 meter laterals was completed in mid July and will be placed on production in August. Completion operations are expected to commence on a three well pad (100% working interest) in September. DEC is positioned for strong operational momentum into year end with an exit target of ~6,000 boe/d.

    Resilient Producer

    • Pristine Financial Position: The Company has a Net Cash position of $119 million, Liquidity of $437 million (including $304 million cash) and a long-dated maturity of 2029 on its term debt. The Company also has $2.2 billion of tax pools (~80% high-value and immediately deductible).
    • Low Break-evens: Long-life, low decline assets afford Athabasca with a sustaining capital advantage. The Company’s 2025 Thermal Oil capital program which includes growth initiatives is fully funded within cash flow below US$50/bbl WTI. Long term sustaining capital investment is estimated at ~C$8/bbl (five‐year annual average) to hold production flat.

    2025 Corporate Guidance

    • Consolidated Production Outlook: The Company anticipates production at the upper end of guidance of 37,500 – 39,500 boe/d with an exit rate of ~41,000 boe/d. Thermal Oil production is trending at the upper end of its prior guidance of 33,500 – 35,500 bbl/d. Duvernay Energy is expected to average ~4,000 boe/d with an exit target of ~6,000 boe/d following the tie-in of two multi-well pads.
    • Thermal Capital: The forecast capital budget for Thermal oil is unchanged at ~$250 million, including sustaining capital and the Leismer expansion project. This $300 million expansion project (over three years) is highly economic (~$25,000/bbl/d capital efficiency) and provides flexibility with interim growth targets to ~32,000 bbl/d in H2 2026 and ~35,000 bbl/d in H1 2027 before achieving the regulatory approved 40,000 bbl/d capacity at the end of 2027. Athabasca’s Thermal Oil capital projects are flexible, highly economic and have phased optionality on timing based on the macroeconomic environment. By year-end 2025, the Company anticipates being ~50% complete of total capital exposure for the expansion project.
    • Duvernay Energy Corporation Capital: The 2025 capital program of ~$75 million will drive production momentum in H2 2025. The capital program in DEC is flexible and designed to be self-funded. The Company has a deep inventory of ~444 gross future drilling locations with no near-term land expiries.
    • Free Cash Flow Focus: The Company forecasts consolidated Adjusted Funds Flow between $525 – $550 million1, including $475 – $500 million from its Thermal Oil assets. 2025 Thermal Oil Free Cash Flow is forecasted at ~$250 million and is planned to be returned to shareholders through share buybacks. Every +US$1/bbl move in West Texas Intermediate (“WTI”) and Western Canadian Select (“WCS”) heavy oil impacts annual Adjusted Funds Flow by ~$10 million and ~$17 million, respectively.

    Corporate Consolidated Strategy

    • Value Creation: The Company’s Thermal Oil division provides a differentiated liquids weighted growth platform supported by financial resiliency to execute on return of capital initiatives. Athabasca’s subsidiary company, Duvernay Energy Corporation, is designed to enhance value for Athabasca’s shareholders by providing a clear path for self-funded production and cash flow growth in the Kaybob Duvernay resource play. Athabasca (Thermal Oil) and DEC have independent strategies and capital allocation frameworks.
    • Steadfast Focus on Cash Flow Per Share Growth: Athabasca’s disciplined capital allocation framework is designed to unlock shareholder value by prioritizing multi-year cash flow per share growth. The Company forecasts ~20% compounded annual cash flow per share growth between 2025-2029 driven by investing in attractive capital projects and prioritizing share buybacks with 100% of Free Cash Flow. The Company sees significant intrinsic value not reflected in the current share price and intends to remain active with its share buyback strategy.

    Athabasca (Thermal Oil) Strategy

    • Large Resource Base: Athabasca’s top-tier assets underpin a strong Free Cash Flow outlook with low sustaining capital requirements. The long life, low decline asset base includes ~1.2 billion barrels of Proved plus Probable reserves and ~1 billion barrels of Contingent Resource.
    • Strong Financial Position: Prudent balance sheet management is a core tenet of Athabasca’s strategy. The Company has a Net Cash position of $119 million, Liquidity of $437 million (including $304 million cash) and a long-dated maturity of 2029 on its term debt.
    • Leismer Progressive Growth: This $300 million expansion project (over three years) is highly economic (~$25,000/bbl/d capital efficiency) and provides flexibility with interim growth targets to ~32,000 bbl/d in H2 2026 and ~35,000 bbl/d in H1 2027 before achieving the regulatory approved 40,000 bbl/d capacity at the end of 2027. On completion of the expansion project, the Company can maintain Leismer at 40,000 bbl/d for approximately fifty years (Proved plus Probable Reserves).
    • Sustaining Hangingstone: The Hangingstone asset is very competitive and continues to deliver meaningful cash flow contributions to the Company. The objective is to sustain production and maintain competitive netbacks ($36.51/bbl H1 2025 Operating Netback).
    • Corner – Future Optionality: The Company’s Corner asset is a large de-risked oil sands asset adjacent to Leismer with 351 million barrels of Proved plus Probable reserves and 520 million barrels Contingent Resource (Best Estimate Unrisked). There are over 300 delineation wells and ~80% seismic coverage, with reservoir qualities similar to or better than Leismer. The asset has a 40,000 bbl/d regulatory approval for development with the existing pipeline corridor passing through the Corner lease. The Company has updated its development plans and is finalizing facility cost estimates, with a focus on capital efficient modular design.
    • Significant Multi-Year Free Cash Flow: Inclusive of the progressive growth at Leismer, Athabasca (Thermal Oil) expects to generate in excess of $1.8 billion of Free Cash Flow1 during the five-year time frame of 2025-29. Free Cash Flow will continue to support the Company’s return of capital initiatives.
    • Sound Heavy Oil Fundamentals: Canadian heavy oil markets remain strong supported by the Trans Mountain Expansion pipeline and sustained global refining demand. This has resulted in tighter and less volatile WCS heavy differentials with August index pricing at ~US$10/bbl. Athabasca is a direct beneficiary of structurally tighter differentials that are forecasted to hold in the coming years.
    • Thermal Oil Royalty Advantage: Athabasca has significant unrecovered capital balances on its Thermal Oil Assets that ensure a low Crown royalty framework (~6%1). Leismer is forecasted to remain pre-payout until late 20271 and Hangingstone is forecasted to remain pre-payout beyond 20301.
    • Tax Free Horizon Advantage: Athabasca (Thermal Oil) has $2.2 billion of valuable tax pools and does not forecast paying cash taxes this decade.

    Duvernay Energy Strategy

    • Accelerating Value: DEC is an operated, private subsidiary of Athabasca (owned 70% by Athabasca and 30% by Cenovus Energy). DEC accelerates value realization for Athabasca’s shareholders by providing a clear path for self-funded production and cash flow growth without compromising Athabasca’s capacity to fund its Thermal Oil assets or its return of capital strategy.
    • Kaybob Duvernay Focused: Exposure to ~200,000 gross acres in the liquids rich and oil windows with ~444 gross future well locations, including ~46,000 gross acres with 100% working interest.
    • Self-Funded Growth: Near-term activity will be funded within Adjusted Funds Flow, initial seed capital and the DEC credit facility. The Company has growth potential to in excess of ~20,000 boe/d (75% Liquids) by the late 2020s1.

    Footnote: Refer to the “Reader Advisory” section within this news release for additional information on Non‐GAAP Financial Measures (e.g. Adjusted Funds Flow, Free Cash Flow, Net Cash, Liquidity) and production disclosure.
    1 Pricing assumptions: H1 2025 actualized and US$65 WTI, US$12.50 WCS heavy differential, C$2 AECO, and 0.725 C$/US$ FX for H2 2025. 2026+ US$70 WTI, US$12.50 WCS heavy differential, C$3 AECO, and 0.725 C$/US$ FX

    Financial and Operational Highlights

      Three months ended
    June 30,
      Six months ended
    June 30,
     
    ($ Thousands, unless otherwise noted) 2025     2024     2025     2024    
    CORPORATE CONSOLIDATED(1)                
    Petroleum and natural gas production (boe/d)(2)   39,088       37,621       38,404       35,546    
    Petroleum, natural gas and midstream sales $ 360,070     $ 401,738     $ 727,914     $ 712,854    
    Operating Income(2) $ 141,707     $ 179,751     $ 287,297     $ 284,886    
    Operating Income Net of Realized Hedging(2)(3) $ 142,101     $ 178,176     $ 286,048     $ 284,756    
    Operating Netback ($/boe)(2) $ 38.81     $ 52.46     $ 41.30     $ 44.77    
    Operating Netback Net of Realized Hedging ($/boe)(2)(3) $ 38.92     $ 52.00     $ 41.12     $ 44.75    
    Capital expenditures $ 73,066     $ 48,453     $ 136,399     $ 124,464    
    Cash flow from operating activities $ 101,432     $ 135,083     $ 224,785     $ 211,721    
    per share – basic $ 0.20     $ 0.24     $ 0.44     $ 0.38    
    Adjusted Funds Flow(2) $ 127,591     $ 165,746     $ 257,266     $ 253,518    
    per share – basic $ 0.25     $ 0.30     $ 0.51     $ 0.45    
    ATHABASCA (THERMAL OIL)                
    Bitumen production (bbl/d)(2)   36,476       33,765       35,613       32,651    
    Petroleum, natural gas and midstream sales $ 355,160     $ 395,279     $ 717,535     $ 700,320    
    Operating Income(2) $ 135,803     $ 161,694     $ 271,119     $ 262,143    
    Operating Netback ($/bbl)(2) $ 39.79     $ 52.59     $ 42.02     $ 44.91    
    Capital expenditures $ 56,110     $ 34,084     $ 106,486     $ 76,203    
    Adjusted Funds Flow(2) $ 122,097     $ 149,413     $ 243,450     $ 233,126    
    Free Cash Flow(2) $ 65,987     $ 115,329     $ 136,964     $ 156,923    
    DUVERNAY ENERGY(1)                
    Petroleum and natural gas production (boe/d)(2)   2,612       3,856       2,791       2,895    
    Percentage Liquids (%)(2) 72 %   80 %   73 %   77 %  
    Petroleum, natural gas and midstream sales $ 13,526     $ 26,749     $ 31,145     $ 38,287    
    Operating Income(2) $ 5,904     $ 18,057     $ 16,178     $ 22,743    
    Operating Netback ($/boe)(2) $ 24.84     $ 51.46     $ 32.03     $ 43.17    
    Capital expenditures $ 16,956     $ 14,369     $ 29,913     $ 48,261    
    Adjusted Funds Flow(2) $ 5,494     $ 16,333     $ 13,816     $ 20,392    
    Free Cash Flow(2) $ (11,462 )   $ 1,964     $ (16,097 )   $ (27,869 )  
    NET INCOME AND COMPREHENSIVE INCOME                
    Net income and comprehensive income(4) $ 56,870     $ 96,076     $ 128,874     $ 134,685    
    per share – basic(4) $ 0.11     $ 0.17     $ 0.25     $ 0.24    
    per share – diluted(4) $ 0.11     $ 0.17     $ 0.25     $ 0.24    
    COMMON SHARES OUTSTANDING                
    Weighted average shares outstanding – basic   502,593,860       557,299,962       508,393,229       562,188,451    
    Weighted average shares outstanding – diluted   510,591,132       566,559,671       512,076,328       569,058,329    
      June 30,   December 31,  
    As at ($ Thousands) 2025   2024  
    LIQUIDITY AND BALANCE SHEET (CONSOLIDATED)        
    Cash and cash equivalents $ 304,048   $ 344,836  
    Available credit facilities(5) $ 133,074   $ 136,324  
    Face value of term debt $ 200,000   $ 200,000  
     
    (1) Corporate Consolidated and Duvernay Energy reflect gross production and financial metrics before taking into consideration Athabasca’s 70% equity interest in Duvernay Energy.
    (2) Refer to the “Reader Advisory” section within this News Release for additional information on Non-GAAP Financial Measures and production disclosure.
    (3) Includes realized commodity risk management gain of $0.4 million and loss of $1.2 million for the three and six months ended June 30, 2025 (three and six months ended June 30, 2024 – loss of $1.6 million and $0.1 million).
    (4) Net income and comprehensive income per share amounts are based on net income and comprehensive income attributable to shareholders of the Parent Company. In the calculation of diluted net income per share for the three months ended June 30, 2025 net income was increased by $0.4 million, to account for the impact to net income had the outstanding warrants been converted to equity. In the calculation of diluted net income per share for the three months ended June 30, 2024 net income was reduced by $0.4 million, to account for the impact to net income had the outstanding warrants been converted to equity.
    (5) Includes available credit under Athabasca’s and Duvernay Energy’s Credit Facilities and Athabasca’s Unsecured Letter of Credit Facility.
     

    Athabasca (Thermal Oil) Q2 2025 Highlights and Operations Update

    • Production: Production of 36,476 bbl/d (27,818 bbl/d at Leismer and 8,658 bbl/d at Hangingstone).
    • Cash Flow: Adjusted Funds Flow of $122.1 million; Operating Income of $135.8 million with an Operating Netback of $39.79/bbl ($42.02/bbl H1 2025).
    • Capital: $56.1 million of capital expenditures in Q2, with $53.9 million at Leismer as the Company advances the 40,000 bbl/d progressive growth project.
    • Free Cash Flow: $66.0 million of Free Cash Flow supporting return of capital commitment.

    Leismer

    Earlier this year, the Company brought six extended reach redrills on Pad L1 (1,000 – 1,700 meter laterals) on production supporting current production of ~28,000 bbl/d (June 2025). Four well pairs on Pad L10 are expected to maintain production rates at facility capacity for the balance of 2025. The first two wells started steaming in April with production expected in Q3, and the final two will begin steaming this summer with first production expected in Q4. Another six well pairs will be drilled on Pad 11 in H2 2025.

    Activity at Leismer remains focused on advancing progressive growth to 40,000 bbl/d by the end of 2027. The project cost is estimated at $300 million generating a capital efficiency of approximately $25,000/bbl/d. The $300 million will be spent between 2025 and 2027 and includes an estimated $190 million for facility capital and an estimated $110 million for growth wells. By year-end 2025, the Company anticipates being ~50% complete of total capital exposure for the expansion project. The project remains on budget and on schedule with the original sanction plans announced in July 2024. The progressive build provides flexibility with interim growth targets to ~32,000 bbl/d in H2 2026 following the next planned turnaround, and ~35,000 bbl/d in H1 2027 before achieving the regulatory approved 40,000 bbl/d capacity at the end of 2027.

    Hangingstone

    At Hangingstone, two extended reach sustaining well pairs (~1,400 meter average laterals) were placed on production in March with production of ~8,900 bbl/d (June 2025). The well pairs ramped up faster than anticipated, benefiting from favorable reservoir temperatures and pressure supported by offsetting wells. Current well pair performance between 800 – 1,000 bbl/d per well has exceeded management’s expectations. Hangingstone continues to deliver meaningful cash flow contributions to the Company.

    Duvernay Energy Corporation Q2 2025 Highlights and Operations Update

    • Production: Production of 2,612 boe/d (72% Liquids).
    • Cash Flow: Adjusted Funds Flow of $5.5 million with an Operating Netback of $24.84/boe ($32.03/boe H1 2025).
    • Capital: $17.0 million of capital expenditures including completions on a 30% working interest four-well pad.  

    During the quarter completions operations commenced on a four well pad (30% working interest) with average laterals of ~5,000 meters. Completion operations on this pad were completed in mid July and the wells are expected to be on production in early August. A three well pad (100% working interest) is scheduled to be completed in early Fall and on production shortly thereafter. Earlier in 2025, a strategic gathering system was completed connecting the operated wells to existing operated infrastructure.

    Production from new wells drilled in 2024 continue to validate DEC’s type curve expectations. The five wells placed on production have averaged IP30’s of ~1,200 boe/d per well (86% Liquids) and IP90s of ~940 boe/d (86% Liquids) per well.

    DEC retains significant operational flexibility with no near-term land expiries and the ability to adjust spending in response to commodity price movements.

    About Athabasca Oil Corporation

    Athabasca Oil Corporation is a Canadian energy company with a focused strategy on the development of thermal and light oil assets. Situated in Alberta’s Western Canadian Sedimentary Basin, the Company has amassed a significant land base of extensive, high quality resources. Athabasca’s light oil assets are held in a private subsidiary (Duvernay Energy Corporation) in which Athabasca owns a 70% equity interest. Athabasca’s common shares trade on the TSX under the symbol “ATH”. For more information, visit www.atha.com.

    For more information, please contact:

    Reader Advisory:

    This News Release contains forward-looking information that involves various risks, uncertainties and other factors. All information other than statements of historical fact is forward-looking information. The use of any of the words “anticipate”, “plan”, “project”, “continue”, “maintain”, “may”, “estimate”, “expect”, “will”, “target”, “forecast”, “could”, “intend”, “potential”, “guidance”, “outlook” and similar expressions suggesting future outcome are intended to identify forward-looking information. The forward-looking information is not historical fact, but rather is based on the Company’s current plans, objectives, goals, strategies, estimates, assumptions and projections about the Company’s industry, business and future operating and financial results. This 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. No assurance can be given that these expectations will prove to be correct and such forward-looking information included in this News Release should not be unduly relied upon. This information speaks only as of the date of this News Release. In particular, this News Release contains forward-looking information pertaining to, but not limited to, the following: our strategic plans; the allocation of future capital; timing and quantum for shareholder returns including share buybacks; the terms of our NCIB program; our drilling plans and capital efficiencies; production growth to expected production rates and estimated sustaining capital amounts; timing of Leismer’s and Hangingstone’s pre-payout royalty status; applicability of tax pools; Adjusted Funds Flow and Free Cash Flow over various periods; type well economic metrics; number of drilling locations; forecasted daily production and the composition of production; break-even metrics, our outlook in respect of the Company’s business environment, including in respect of commodity pricing; and other matters.

    In addition, information and statements in this News Release relating to “Reserves” and “Resources” are deemed to be forward-looking information, as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated, and that the reserves and resources described can be profitably produced in the future. With respect to forward-looking information contained in this News Release, assumptions have been made regarding, among other things: commodity prices; the regulatory framework governing royalties, taxes and environmental matters in the jurisdictions in which the Company conducts and will conduct business and the effects that such regulatory framework will have on the Company, including on the Company’s financial condition and results of operations; the Company’s financial and operational flexibility; the Company’s financial sustainability; Athabasca’s cash flow break-even commodity price; the Company’s ability to obtain qualified staff and equipment in a timely and cost-efficient manner; the applicability of technologies for the recovery and production of the Company’s reserves and resources; future capital expenditures to be made by the Company; future sources of funding for the Company’s capital programs; the Company’s future debt levels; future production levels; the Company’s ability to obtain financing and/or enter into joint venture arrangements, on acceptable terms; operating costs; compliance of counterparties with the terms of contractual arrangements; impact of increasing competition globally; collection risk of outstanding accounts receivable from third parties; geological and engineering estimates in respect of the Company’s reserves and resources; recoverability of reserves and resources; the geography of the areas in which the Company is conducting exploration and development activities and the quality of its assets. Certain other assumptions related to the Company’s Reserves and Resources are contained in the report of McDaniel & Associates Consultants Ltd. (“McDaniel”) evaluating Athabasca’s Proved Reserves, Probable Reserves and Contingent Resources as at December 31, 2024 (which is respectively referred to herein as the “McDaniel Report”).

    Actual results could differ materially from those anticipated in this forward-looking information as a result of the risk factors set forth in the Company’s Annual Information Form (“AIF”) dated March 5, 2025 available on SEDAR at www.sedarplus.ca, including, but not limited to: weakness in the oil and gas industry; exploration, development and production risks; prices, markets and marketing; market conditions; trade relations and tariffs; climate change and carbon pricing risk; statutes and regulations regarding the environment including deceptive marketing provisions; regulatory environment and changes in applicable law; gathering and processing facilities, pipeline systems and rail; reputation and public perception of the oil and gas sector; environment, social and governance goals; political uncertainty; state of capital markets; ability to finance capital requirements; access to capital and insurance; abandonment and reclamation costs; changing demand for oil and natural gas products; anticipated benefits of acquisitions and dispositions; royalty regimes; foreign exchange rates and interest rates; reserves; hedging; operational dependence; operating costs; project risks; supply chain disruption; financial assurances; diluent supply; third party credit risk; indigenous claims; reliance on key personnel and operators; income tax; cybersecurity; advanced technologies; hydraulic fracturing; liability management; seasonality and weather conditions; unexpected events; internal controls; limitations and insurance; litigation; natural gas overlying bitumen resources; competition; chain of title and expiration of licenses and leases; breaches of confidentiality; new industry related activities or new geographical areas; water use restrictions and/or limited access to water; relationship with Duvernay Energy Corporation; management estimates and assumptions; third-party claims; conflicts of interest; inflation and cost management; credit ratings; growth management; impact of pandemics; ability of investors resident in the United States to enforce civil remedies in Canada; and risks related to our debt and securities. All subsequent forward-looking information, whether written or oral, attributable to the Company or persons acting on its behalf are expressly qualified in their entirety by these cautionary statements.

    Also included in this News Release are estimates of Athabasca’s 2025 outlook which are based on the various assumptions as to production levels, commodity prices, currency exchange rates and other assumptions disclosed in this News Release. To the extent any such estimate constitutes a financial outlook, it was approved by management and the Board of Directors of Athabasca and is included to provide readers with an understanding of the Company’s outlook. Management does not have firm commitments for all of the costs, expenditures, prices or other financial assumptions used to prepare the financial outlook or assurance that such operating results will be achieved and, accordingly, the complete financial effects of all of those costs, expenditures, prices and operating results are not objectively determinable. The actual results of operations of the Company and the resulting financial results may vary from the amounts set forth herein, and such variations may be material. The outlook and forward-looking information contained in this New Release was made as of the date of this News release and the Company disclaims any intention or obligations to update or revise such outlook and/or forward-looking information, whether as a result of new information, future events or otherwise, unless required pursuant to applicable law.

    Oil and Gas Information

    “BOEs” may be misleading, particularly if used in isolation. A BOE conversion ratio of six thousand cubic feet of natural gas to one barrel of oil equivalent (6 Mcf: 1 bbl) is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. As the value ratio between natural gas and crude oil based on the current prices of natural gas and crude oil is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.

    Initial Production Rates 

    Test Results and Initial Production Rates: The well test results and initial production rates provided herein should be considered to be preliminary, except as otherwise indicated. Test results and initial production rates disclosed herein may not necessarily be indicative of long-term performance or of ultimate recovery.

    Reserves Information

    The McDaniel Report was prepared using the assumptions and methodology guidelines outlined in the COGE Handbook and in accordance with National Instrument 51-101 Standards of Disclosure for Oil and Gas Activities, effective December 31, 2024. There are numerous uncertainties inherent in estimating quantities of bitumen, light crude oil and medium crude oil, tight oil, conventional natural gas, shale gas and natural gas liquids reserves and the future cash flows attributed to such reserves. The reserve and associated cash flow information set forth above are estimates only. In general, estimates of economically recoverable reserves and the future net cash flows therefrom are based upon a number of variable factors and assumptions, such as historical production from the properties, production rates, ultimate reserve recovery, timing and amount of capital expenditures, marketability of oil and natural gas, royalty rates, the assumed effects of regulation by governmental agencies and future operating costs, all of which may vary materially. For those reasons, estimates of the economically recoverable reserves attributable to any particular group of properties, classification of such reserves based on risk of recovery and estimates of future net revenues associated with reserves prepared by different engineers, or by the same engineers at different times, may vary. The Company’s actual production, revenues, taxes and development and operating expenditures with respect to its reserves will vary from estimates thereof and such variations could be material. Reserves figures described herein have been rounded to the nearest MMbbl or MMboe. For additional information regarding the consolidated reserves and information concerning the resources of the Company as evaluated by McDaniel in the McDaniel Report, please refer to the Company’s AIF.

    Reserve Values (i.e. Net Asset Value) is calculated using the estimated net present value of all future net revenue from our reserves, before income taxes discounted at 10%, as estimated by McDaniel effective December 31, 2024 and based on average pricing of McDaniel, Sproule and GLJ as of January 1, 2025.

    The 444 gross Duvernay drilling locations referenced include: 87 proved undeveloped locations and 85 probable undeveloped locations for a total of 172 booked locations with the balance being unbooked locations. Proved undeveloped locations and probable undeveloped locations are booked and derived from the Company’s most recent independent reserves evaluation as prepared by McDaniel as of December 31, 2024 and account for drilling locations that have associated proved and/or probable reserves, as applicable. Unbooked locations are internal management estimates. Unbooked locations do not have attributed reserves or resources (including contingent or prospective). Unbooked locations have been identified by management as an estimation of Athabasca’s multi-year drilling activities expected to occur over the next two decades based on evaluation of applicable geologic, seismic, engineering, production and reserves information. There is no certainty that the Company will drill all unbooked drilling locations and if drilled there is no certainty that such locations will result in additional oil and gas reserves, resources or production. The drilling locations on which the Company will actually drill wells, including the number and timing thereof is ultimately dependent upon the availability of funding, commodity prices, provincial fiscal and royalty policies, costs, actual drilling results, additional reservoir information that is obtained and other factors.

    Non-GAAP and Other Financial Measures, and Production Disclosure

    The “Corporate Consolidated Adjusted Funds Flow”, “Corporate Consolidated Adjusted Funds Flow per Share”, “Athabasca (Thermal Oil) Adjusted Funds Flow”, “Duvernay Energy Adjusted Funds Flow”, “Corporate Consolidated Free Cash Flow”, “Athabasca (Thermal Oil) Free Cash Flow”, “Duvernay Energy Free Cash Flow”, “Corporate Consolidated Operating Income”, “Corporate Consolidated Operating Income Net of Realized Hedging”, “Athabasca (Thermal Oil) Operating Income”, “Duvernay Energy Operating Income”, “Corporate Consolidated Operating Netback”, “Corporate Consolidated Operating Netback Net of Realized Hedging”, “Athabasca (Thermal Oil) Operating Netback”, “Duvernay Energy Operating Netback” and “Cash Transportation and Marketing Expense” financial measures contained in this News Release do not have standardized meanings which are prescribed by IFRS and they are considered to be non-GAAP financial measures or ratios. These measures may not be comparable to similar measures presented by other issuers and should not be considered in isolation with measures that are prepared in accordance with IFRS. Net Cash and Liquidity are supplementary financial measures. The Leismer and Hangingstone operating results are supplementary financial measures that when aggregated, combine to the Athabasca (Thermal Oil) segment results.

    Adjusted Funds Flow, Adjusted Funds Flow Per Share and Free Cash Flow

    Adjusted Funds Flow and Free Cash Flow are non-GAAP financial measures and are not intended to represent cash flow from operating activities, net earnings or other measures of financial performance calculated in accordance with IFRS. The Adjusted Funds Flow and Free Cash Flow measures allow management and others to evaluate the Company’s ability to fund its capital programs and meet its ongoing financial obligations using cash flow internally generated from ongoing operating related activities. Adjusted Funds Flow per share is a non-GAAP financial ratio calculated as Adjusted Funds Flow divided by the applicable number of weighted average shares outstanding. Adjusted Funds Flow and Free Cash Flow are calculated as follows:

      Three months ended
    June 30, 2025
     
     ($ Thousands) Athabasca
    (Thermal Oil)
      Duvernay Energy(1)   Corporate
    Consolidated(1)
     
    Cash flow from operating activities $ 101,142   $ 290   $ 101,432  
    Changes in non-cash working capital   20,922     5,207     26,129  
    Settlement of provisions   33     (3 )   30  
    ADJUSTED FUNDS FLOW   122,097     5,494     127,591  
    Capital expenditures   (56,110 )   (16,956 )   (73,066 )
    FREE CASH FLOW $ 65,987   $ (11,462 ) $ 54,525  
    (1) Duvernay Energy and Corporate Consolidated reflect gross financial metrics before taking into consideration Athabasca’s 70% equity interest in Duvernay Energy.
      Six months ended
    June 30, 2025
     
     ($ Thousands) Athabasca
    (Thermal Oil)
      Duvernay Energy(1)   Corporate
    Consolidated(1)
     
    Cash flow from operating activities $ 214,569   $ 10,216   $ 224,785  
    Changes in non-cash working capital   28,152     3,595     31,747  
    Settlement of provisions   729     5     734  
     ADJUSTED FUNDS FLOW   243,450     13,816     257,266  
    Capital expenditures   (106,486 )   (29,913 )   (136,399 )
     FREE CASH FLOW $ 136,964   $ (16,097 ) $ 120,867  
    (1) Duvernay Energy and Corporate Consolidated reflect gross financial metrics before taking into consideration Athabasca’s 70% equity interest in Duvernay Energy.
      Three months ended
    June 30, 2024
     
     ($ Thousands) Athabasca
    (Thermal Oil)
      Duvernay Energy(1)   Corporate
    Consolidated(1)
     
    Cash flow from operating activities $ 124,027   $ 11,056   $ 135,083  
    Changes in non-cash working capital   25,375     5,390     30,765  
    Settlement of provisions   11     (113 )   (102 )
    ADJUSTED FUNDS FLOW   149,413     16,333     165,746  
    Capital expenditures   (34,084 )   (14,369 )   (48,453 )
    FREE CASH FLOW $ 115,329   $ 1,964   $ 117,293  
    (1) Duvernay Energy and Corporate Consolidated reflect gross financial metrics before taking into consideration Athabasca’s 70% equity interest in Duvernay Energy.
      Six months ended
    June 30, 2024
     
     ($ Thousands) Athabasca
    (Thermal Oil)
      Duvernay Energy(1)   Corporate
    Consolidated(1)
     
    Cash flow from operating activities $ 197,068   $ 14,653   $ 211,721  
    Changes in non-cash working capital   34,761     5,535     40,296  
    Settlement of provisions   1,297     204     1,501  
     ADJUSTED FUNDS FLOW   233,126     20,392     253,518  
    Capital expenditures   (76,203 )   (48,261 )   (124,464 )
     FREE CASH FLOW $ 156,923   $ (27,869 ) $ 129,054  
    (1) Duvernay Energy and Corporate Consolidated reflect gross financial metrics before taking into consideration Athabasca’s 70% equity interest in Duvernay Energy.
     

    Duvernay Energy Operating Income and Operating Netback

    The non-GAAP measure Duvernay Energy Operating Income in this News Release is calculated by subtracting the Duvernay Energy royalties, operating expenses and transportation & marketing expenses from petroleum and natural gas sales which is the most directly comparable GAAP measure. The Duvernay Energy Operating Netback per boe is a non-GAAP financial ratio calculated by dividing the Duvernay Energy Operating Income by the Duvernay Energy production. The Duvernay Energy Operating Income and the Duvernay Energy Operating Netback measures allow management and others to evaluate the production results from the Company’s Duvernay Energy assets.

    The Duvernay Energy Operating Income is calculated using the Duvernay Energy Segments GAAP results, as follows:

      Three months ended
    June 30,
      Six months ended
    June 30,
     
    ($ Thousands, unless otherwise noted) 2025   2024   2025   2024  
    Petroleum and natural gas sales $ 13,526   $ 26,749   $ 31,145   $ 38,287  
    Royalties   (1,792 )   (3,498 )   (4,553 )   (5,812 )
    Operating expenses   (4,870 )   (4,063 )   (8,656 )   (7,703 )
    Transportation and marketing   (960 )   (1,131 )   (1,758 )   (2,029 )
    DUVERNAY ENERGY OPERATING INCOME $ 5,904   $ 18,057   $ 16,178   $ 22,743  
                             

    Athabasca (Thermal Oil) Operating Income and Operating Netback

    The non-GAAP measure Athabasca (Thermal Oil) Operating Income in this News Release is calculated by subtracting the Athabasca (Thermal Oil) segments cost of diluent blending, royalties, operating expenses and cash transportation & marketing expenses from heavy oil (blended bitumen) and midstream sales which is the most directly comparable GAAP measure. The Athabasca (Thermal Oil) Operating Netback per bbl is a non-GAAP financial ratio calculated by dividing the respective projects Operating Income by its respective bitumen sales volumes. The Athabasca (Thermal Oil) Operating Income and the Athabasca (Thermal Oil) Operating Netback measures allow management and others to evaluate the production results from the Athabasca (Thermal Oil) assets.

    The Athabasca (Thermal Oil) Operating Income is calculated using the Athabasca (Thermal Oil) Segments GAAP results, as follows:

      Three months ended
    June 30,
      Six months ended
    June 30,
     
    ($ Thousands, unless otherwise noted) 2025   2024   2025   2024  
    Heavy oil (blended bitumen) and midstream sales $ 355,160   $ 395,279   $ 717,535   $ 700,320  
    Cost of diluent   (147,065 )   (148,166 )   (299,197 )   (282,026 )
    Total bitumen and midstream sales   208,095     247,113     418,338     418,294  
    Royalties   (9,431 )   (28,823 )   (25,395 )   (40,360 )
    Operating expenses – non-energy   (26,810 )   (24,417 )   (51,697 )   (47,542 )
    Operating expenses – energy   (13,621 )   (11,635 )   (27,128 )   (28,193 )
    Transportation and marketing(1)   (22,430 )   (20,544 )   (42,999 )   (40,056 )
    ATHABASCA (THERMAL OIL) OPERATING INCOME $ 135,803   $ 161,694   $ 271,119   $ 262,143  
    (1) Transportation and marketing excludes non-cash costs of $0.6 million and $1.1 million for the three and six months ended June 30, 2025 (three and six months ended June 30, 2024 – $0.6 million and $1.1 million).
     

    Corporate Consolidated Operating Income and Corporate Consolidated Operating Income Net of Realized Hedging and Operating Netbacks

    The non-GAAP measures of Corporate Consolidated Operating Income including or excluding realized hedging in this News Release are calculated by adding or subtracting realized gains (losses) on commodity risk management contracts (as applicable), royalties, the cost of diluent blending, operating expenses and cash transportation & marketing expenses from petroleum, natural gas and midstream sales which is the most directly comparable GAAP measure. The Corporate Consolidated Operating Netbacks including or excluding realized hedging per boe are non-GAAP ratios calculated by dividing Corporate Consolidated Operating Income including or excluding hedging by the total sales volumes and are presented on a per boe basis. The Corporate Consolidated Operating Income and Corporate Consolidated Operating Netbacks including or excluding realized hedging measures allow management and others to evaluate the production results from the Company’s Duvernay Energy and Athabasca (Thermal Oil) assets combined together including the impact of realized commodity risk management gains or losses (as applicable).

      Three months ended
    June 30,
      Six months ended
    June 30,
     
    ($ Thousands, unless otherwise noted) 2025   2024   2025   2024  
    Petroleum, natural gas and midstream sales(1) $ 368,686   $ 422,028   $ 748,680   $ 738,607  
    Royalties   (11,223 )   (32,321 )   (29,948 )   (46,172 )
    Cost of diluent(1)   (147,065 )   (148,166 )   (299,197 )   (282,026 )
    Operating expenses   (45,301 )   (40,115 )   (87,481 )   (83,438 )
    Transportation and marketing(2)   (23,390 )   (21,675 )   (44,757 )   (42,085 )
    Operating Income   141,707     179,751     287,297     284,886  
    Realized gain (loss) on commodity risk mgmt. contracts   394     (1,575 )   (1,249 )   (130 )
    OPERATING INCOME NET OF REALIZED HEDGING $ 142,101   $ 178,176   $ 286,048   $ 284,756  
    (1) Non-GAAP measure includes intercompany NGLs (i.e. condensate) sold by the Duvernay Energy segment to the Athabasca (Thermal Oil) segment for use as diluent that is eliminated on consolidation.
    (2) Transportation and marketing excludes non-cash costs of $0.6 million and $1.1 million for the three and six months ended June 30, 2025 (three and six months ended June 30, 2024 – $0.6 million and $1.1 million).
     

    Cash Transportation and Marketing Expense

    The Cash Transportation and Marketing Expense financial measures contained in this News Release are calculated by subtracting the non-cash transportation and marketing expense as reported in the Consolidated Statement of Cash Flows from the transportation and marketing expense as reported in the Consolidated Statement of Income (Loss) and are considered to be non-GAAP financial measures.

    Net Cash

    Net Cash is defined as the face value of term debt, plus accounts payable and accrued liabilities, plus current portion of provisions and other liabilities plus income tax payable less current assets, excluding risk management contracts.

    Liquidity

    Liquidity is defined as cash and cash equivalents plus available credit capacity.

    Production volumes details

        Three months ended
    June 30,
      Six months ended
    June 30,
     
    Production   2025   2024   2025   2024  
    Duvernay Energy:                  
    Oil and condensate NGLs(1) bbl/d   1,608     2,806     1,723     2,006  
    Other NGLs bbl/d   282     266     304     223  
    Natural gas(2) mcf/d   4,329     4,706     4,585     3,998  
    Total Duvernay Energy boe/d   2,612     3,856     2,791     2,895  
    Total Thermal Oil bitumen bbl/d   36,476     33,765     35,613     32,651  
    Total Company production boe/d   39,088     37,621     38,404     35,546  
    (1) Comprised of 99% or greater of tight oil, with the remaining being light and medium crude oil.
    (2) Comprised of 99% or greater of shale gas, with the remaining being conventional natural gas.
     

    This News Release also makes reference to Athabasca’s forecasted average daily Thermal Oil production of 33,500 ‐ 35,500 bbl/d for 2025. Athabasca expects that 100% of that production will be comprised of bitumen. Duvernay Energy’s forecasted total average daily production of ~4,000 boe/d for 2025 is expected to be comprised of approximately 65% tight oil, 25% shale gas and 10% NGLs.

    Liquids is defined as bitumen, light crude oil, medium crude oil and natural gas liquids.

    Break Even is an operating metric that calculates the US$WTI oil price required to fund operating costs (Operating Break-even), sustaining capital (Sustaining Break-even), or growth capital (Total Capital) within Adjusted Funds Flow.

    The MIL Network

  • MIL-OSI: Athabasca Oil Announces 2025 Second Quarter Results Highlighted by Strong Operational Results, Continued Share Buybacks and a Pristine Financial Position

    Source: GlobeNewswire (MIL-OSI)

    CALGARY, Alberta, July 24, 2025 (GLOBE NEWSWIRE) — Athabasca Oil Corporation (TSX: ATH) (“Athabasca” or the “Company”) is pleased to report its second quarter results marked by strong operational performance, consistent financial results and execution on return of capital commitments. With low corporate break-evens, differentiated long-life assets and a pristine balance sheet, the Company is well positioned to advance its strategic priorities.

    Q2 2025 Consolidated Corporate Results

    • Production: Average production of 39,088 boe/d (98% Liquids), representing 4% (15% per share) growth year-over-year.
    • Cash Flow: Adjusted Funds Flow of $128 million ($0.25 per share). Cash Flow from Operating Activities of $101 million. Free Cash Flow of $66 million from Athabasca (Thermal Oil).
    • Capital Program: $73 million total capital expenditures including $54 million at Leismer to support the 40,000 bbl/d phased growth project.
    • Shareholder Returns: Purchased 24 million shares through its buy-back program year-to-date. The Company is committed to returning 100% of Free Cash Flow (Thermal Oil) to shareholders in 2025 and has completed ~$600 million in share buybacks since March 31, 2023, reducing its fully diluted share count by 21%.

    Operations Highlights

    • Leismer: Production currently ~28,000 bbl/d (June 2025) with four sustaining well pairs expected to be placed on production through the balance of the year. The progressive growth project remains on time and on budget. The Company expects production to stay flat until the next growth plateau of 32,000 bbl/d in H2 2026.
    • Hangingstone: Production currently ~8,900 bbl/d (June 2025) following the start-up of two extended reach well pairs which are outperforming management’s expectations. The asset continues to deliver meaningful free cash flow generation.
    • Duvernay Energy (“DEC”): A four well pad (30% working interest) with ~5,000 meter laterals was completed in mid July and will be placed on production in August. Completion operations are expected to commence on a three well pad (100% working interest) in September. DEC is positioned for strong operational momentum into year end with an exit target of ~6,000 boe/d.

    Resilient Producer

    • Pristine Financial Position: The Company has a Net Cash position of $119 million, Liquidity of $437 million (including $304 million cash) and a long-dated maturity of 2029 on its term debt. The Company also has $2.2 billion of tax pools (~80% high-value and immediately deductible).
    • Low Break-evens: Long-life, low decline assets afford Athabasca with a sustaining capital advantage. The Company’s 2025 Thermal Oil capital program which includes growth initiatives is fully funded within cash flow below US$50/bbl WTI. Long term sustaining capital investment is estimated at ~C$8/bbl (five‐year annual average) to hold production flat.

    2025 Corporate Guidance

    • Consolidated Production Outlook: The Company anticipates production at the upper end of guidance of 37,500 – 39,500 boe/d with an exit rate of ~41,000 boe/d. Thermal Oil production is trending at the upper end of its prior guidance of 33,500 – 35,500 bbl/d. Duvernay Energy is expected to average ~4,000 boe/d with an exit target of ~6,000 boe/d following the tie-in of two multi-well pads.
    • Thermal Capital: The forecast capital budget for Thermal oil is unchanged at ~$250 million, including sustaining capital and the Leismer expansion project. This $300 million expansion project (over three years) is highly economic (~$25,000/bbl/d capital efficiency) and provides flexibility with interim growth targets to ~32,000 bbl/d in H2 2026 and ~35,000 bbl/d in H1 2027 before achieving the regulatory approved 40,000 bbl/d capacity at the end of 2027. Athabasca’s Thermal Oil capital projects are flexible, highly economic and have phased optionality on timing based on the macroeconomic environment. By year-end 2025, the Company anticipates being ~50% complete of total capital exposure for the expansion project.
    • Duvernay Energy Corporation Capital: The 2025 capital program of ~$75 million will drive production momentum in H2 2025. The capital program in DEC is flexible and designed to be self-funded. The Company has a deep inventory of ~444 gross future drilling locations with no near-term land expiries.
    • Free Cash Flow Focus: The Company forecasts consolidated Adjusted Funds Flow between $525 – $550 million1, including $475 – $500 million from its Thermal Oil assets. 2025 Thermal Oil Free Cash Flow is forecasted at ~$250 million and is planned to be returned to shareholders through share buybacks. Every +US$1/bbl move in West Texas Intermediate (“WTI”) and Western Canadian Select (“WCS”) heavy oil impacts annual Adjusted Funds Flow by ~$10 million and ~$17 million, respectively.

    Corporate Consolidated Strategy

    • Value Creation: The Company’s Thermal Oil division provides a differentiated liquids weighted growth platform supported by financial resiliency to execute on return of capital initiatives. Athabasca’s subsidiary company, Duvernay Energy Corporation, is designed to enhance value for Athabasca’s shareholders by providing a clear path for self-funded production and cash flow growth in the Kaybob Duvernay resource play. Athabasca (Thermal Oil) and DEC have independent strategies and capital allocation frameworks.
    • Steadfast Focus on Cash Flow Per Share Growth: Athabasca’s disciplined capital allocation framework is designed to unlock shareholder value by prioritizing multi-year cash flow per share growth. The Company forecasts ~20% compounded annual cash flow per share growth between 2025-2029 driven by investing in attractive capital projects and prioritizing share buybacks with 100% of Free Cash Flow. The Company sees significant intrinsic value not reflected in the current share price and intends to remain active with its share buyback strategy.

    Athabasca (Thermal Oil) Strategy

    • Large Resource Base: Athabasca’s top-tier assets underpin a strong Free Cash Flow outlook with low sustaining capital requirements. The long life, low decline asset base includes ~1.2 billion barrels of Proved plus Probable reserves and ~1 billion barrels of Contingent Resource.
    • Strong Financial Position: Prudent balance sheet management is a core tenet of Athabasca’s strategy. The Company has a Net Cash position of $119 million, Liquidity of $437 million (including $304 million cash) and a long-dated maturity of 2029 on its term debt.
    • Leismer Progressive Growth: This $300 million expansion project (over three years) is highly economic (~$25,000/bbl/d capital efficiency) and provides flexibility with interim growth targets to ~32,000 bbl/d in H2 2026 and ~35,000 bbl/d in H1 2027 before achieving the regulatory approved 40,000 bbl/d capacity at the end of 2027. On completion of the expansion project, the Company can maintain Leismer at 40,000 bbl/d for approximately fifty years (Proved plus Probable Reserves).
    • Sustaining Hangingstone: The Hangingstone asset is very competitive and continues to deliver meaningful cash flow contributions to the Company. The objective is to sustain production and maintain competitive netbacks ($36.51/bbl H1 2025 Operating Netback).
    • Corner – Future Optionality: The Company’s Corner asset is a large de-risked oil sands asset adjacent to Leismer with 351 million barrels of Proved plus Probable reserves and 520 million barrels Contingent Resource (Best Estimate Unrisked). There are over 300 delineation wells and ~80% seismic coverage, with reservoir qualities similar to or better than Leismer. The asset has a 40,000 bbl/d regulatory approval for development with the existing pipeline corridor passing through the Corner lease. The Company has updated its development plans and is finalizing facility cost estimates, with a focus on capital efficient modular design.
    • Significant Multi-Year Free Cash Flow: Inclusive of the progressive growth at Leismer, Athabasca (Thermal Oil) expects to generate in excess of $1.8 billion of Free Cash Flow1 during the five-year time frame of 2025-29. Free Cash Flow will continue to support the Company’s return of capital initiatives.
    • Sound Heavy Oil Fundamentals: Canadian heavy oil markets remain strong supported by the Trans Mountain Expansion pipeline and sustained global refining demand. This has resulted in tighter and less volatile WCS heavy differentials with August index pricing at ~US$10/bbl. Athabasca is a direct beneficiary of structurally tighter differentials that are forecasted to hold in the coming years.
    • Thermal Oil Royalty Advantage: Athabasca has significant unrecovered capital balances on its Thermal Oil Assets that ensure a low Crown royalty framework (~6%1). Leismer is forecasted to remain pre-payout until late 20271 and Hangingstone is forecasted to remain pre-payout beyond 20301.
    • Tax Free Horizon Advantage: Athabasca (Thermal Oil) has $2.2 billion of valuable tax pools and does not forecast paying cash taxes this decade.

    Duvernay Energy Strategy

    • Accelerating Value: DEC is an operated, private subsidiary of Athabasca (owned 70% by Athabasca and 30% by Cenovus Energy). DEC accelerates value realization for Athabasca’s shareholders by providing a clear path for self-funded production and cash flow growth without compromising Athabasca’s capacity to fund its Thermal Oil assets or its return of capital strategy.
    • Kaybob Duvernay Focused: Exposure to ~200,000 gross acres in the liquids rich and oil windows with ~444 gross future well locations, including ~46,000 gross acres with 100% working interest.
    • Self-Funded Growth: Near-term activity will be funded within Adjusted Funds Flow, initial seed capital and the DEC credit facility. The Company has growth potential to in excess of ~20,000 boe/d (75% Liquids) by the late 2020s1.

    Footnote: Refer to the “Reader Advisory” section within this news release for additional information on Non‐GAAP Financial Measures (e.g. Adjusted Funds Flow, Free Cash Flow, Net Cash, Liquidity) and production disclosure.
    1 Pricing assumptions: H1 2025 actualized and US$65 WTI, US$12.50 WCS heavy differential, C$2 AECO, and 0.725 C$/US$ FX for H2 2025. 2026+ US$70 WTI, US$12.50 WCS heavy differential, C$3 AECO, and 0.725 C$/US$ FX

    Financial and Operational Highlights

      Three months ended
    June 30,
      Six months ended
    June 30,
     
    ($ Thousands, unless otherwise noted) 2025     2024     2025     2024    
    CORPORATE CONSOLIDATED(1)                
    Petroleum and natural gas production (boe/d)(2)   39,088       37,621       38,404       35,546    
    Petroleum, natural gas and midstream sales $ 360,070     $ 401,738     $ 727,914     $ 712,854    
    Operating Income(2) $ 141,707     $ 179,751     $ 287,297     $ 284,886    
    Operating Income Net of Realized Hedging(2)(3) $ 142,101     $ 178,176     $ 286,048     $ 284,756    
    Operating Netback ($/boe)(2) $ 38.81     $ 52.46     $ 41.30     $ 44.77    
    Operating Netback Net of Realized Hedging ($/boe)(2)(3) $ 38.92     $ 52.00     $ 41.12     $ 44.75    
    Capital expenditures $ 73,066     $ 48,453     $ 136,399     $ 124,464    
    Cash flow from operating activities $ 101,432     $ 135,083     $ 224,785     $ 211,721    
    per share – basic $ 0.20     $ 0.24     $ 0.44     $ 0.38    
    Adjusted Funds Flow(2) $ 127,591     $ 165,746     $ 257,266     $ 253,518    
    per share – basic $ 0.25     $ 0.30     $ 0.51     $ 0.45    
    ATHABASCA (THERMAL OIL)                
    Bitumen production (bbl/d)(2)   36,476       33,765       35,613       32,651    
    Petroleum, natural gas and midstream sales $ 355,160     $ 395,279     $ 717,535     $ 700,320    
    Operating Income(2) $ 135,803     $ 161,694     $ 271,119     $ 262,143    
    Operating Netback ($/bbl)(2) $ 39.79     $ 52.59     $ 42.02     $ 44.91    
    Capital expenditures $ 56,110     $ 34,084     $ 106,486     $ 76,203    
    Adjusted Funds Flow(2) $ 122,097     $ 149,413     $ 243,450     $ 233,126    
    Free Cash Flow(2) $ 65,987     $ 115,329     $ 136,964     $ 156,923    
    DUVERNAY ENERGY(1)                
    Petroleum and natural gas production (boe/d)(2)   2,612       3,856       2,791       2,895    
    Percentage Liquids (%)(2) 72 %   80 %   73 %   77 %  
    Petroleum, natural gas and midstream sales $ 13,526     $ 26,749     $ 31,145     $ 38,287    
    Operating Income(2) $ 5,904     $ 18,057     $ 16,178     $ 22,743    
    Operating Netback ($/boe)(2) $ 24.84     $ 51.46     $ 32.03     $ 43.17    
    Capital expenditures $ 16,956     $ 14,369     $ 29,913     $ 48,261    
    Adjusted Funds Flow(2) $ 5,494     $ 16,333     $ 13,816     $ 20,392    
    Free Cash Flow(2) $ (11,462 )   $ 1,964     $ (16,097 )   $ (27,869 )  
    NET INCOME AND COMPREHENSIVE INCOME                
    Net income and comprehensive income(4) $ 56,870     $ 96,076     $ 128,874     $ 134,685    
    per share – basic(4) $ 0.11     $ 0.17     $ 0.25     $ 0.24    
    per share – diluted(4) $ 0.11     $ 0.17     $ 0.25     $ 0.24    
    COMMON SHARES OUTSTANDING                
    Weighted average shares outstanding – basic   502,593,860       557,299,962       508,393,229       562,188,451    
    Weighted average shares outstanding – diluted   510,591,132       566,559,671       512,076,328       569,058,329    
      June 30,   December 31,  
    As at ($ Thousands) 2025   2024  
    LIQUIDITY AND BALANCE SHEET (CONSOLIDATED)        
    Cash and cash equivalents $ 304,048   $ 344,836  
    Available credit facilities(5) $ 133,074   $ 136,324  
    Face value of term debt $ 200,000   $ 200,000  
     
    (1) Corporate Consolidated and Duvernay Energy reflect gross production and financial metrics before taking into consideration Athabasca’s 70% equity interest in Duvernay Energy.
    (2) Refer to the “Reader Advisory” section within this News Release for additional information on Non-GAAP Financial Measures and production disclosure.
    (3) Includes realized commodity risk management gain of $0.4 million and loss of $1.2 million for the three and six months ended June 30, 2025 (three and six months ended June 30, 2024 – loss of $1.6 million and $0.1 million).
    (4) Net income and comprehensive income per share amounts are based on net income and comprehensive income attributable to shareholders of the Parent Company. In the calculation of diluted net income per share for the three months ended June 30, 2025 net income was increased by $0.4 million, to account for the impact to net income had the outstanding warrants been converted to equity. In the calculation of diluted net income per share for the three months ended June 30, 2024 net income was reduced by $0.4 million, to account for the impact to net income had the outstanding warrants been converted to equity.
    (5) Includes available credit under Athabasca’s and Duvernay Energy’s Credit Facilities and Athabasca’s Unsecured Letter of Credit Facility.
     

    Athabasca (Thermal Oil) Q2 2025 Highlights and Operations Update

    • Production: Production of 36,476 bbl/d (27,818 bbl/d at Leismer and 8,658 bbl/d at Hangingstone).
    • Cash Flow: Adjusted Funds Flow of $122.1 million; Operating Income of $135.8 million with an Operating Netback of $39.79/bbl ($42.02/bbl H1 2025).
    • Capital: $56.1 million of capital expenditures in Q2, with $53.9 million at Leismer as the Company advances the 40,000 bbl/d progressive growth project.
    • Free Cash Flow: $66.0 million of Free Cash Flow supporting return of capital commitment.

    Leismer

    Earlier this year, the Company brought six extended reach redrills on Pad L1 (1,000 – 1,700 meter laterals) on production supporting current production of ~28,000 bbl/d (June 2025). Four well pairs on Pad L10 are expected to maintain production rates at facility capacity for the balance of 2025. The first two wells started steaming in April with production expected in Q3, and the final two will begin steaming this summer with first production expected in Q4. Another six well pairs will be drilled on Pad 11 in H2 2025.

    Activity at Leismer remains focused on advancing progressive growth to 40,000 bbl/d by the end of 2027. The project cost is estimated at $300 million generating a capital efficiency of approximately $25,000/bbl/d. The $300 million will be spent between 2025 and 2027 and includes an estimated $190 million for facility capital and an estimated $110 million for growth wells. By year-end 2025, the Company anticipates being ~50% complete of total capital exposure for the expansion project. The project remains on budget and on schedule with the original sanction plans announced in July 2024. The progressive build provides flexibility with interim growth targets to ~32,000 bbl/d in H2 2026 following the next planned turnaround, and ~35,000 bbl/d in H1 2027 before achieving the regulatory approved 40,000 bbl/d capacity at the end of 2027.

    Hangingstone

    At Hangingstone, two extended reach sustaining well pairs (~1,400 meter average laterals) were placed on production in March with production of ~8,900 bbl/d (June 2025). The well pairs ramped up faster than anticipated, benefiting from favorable reservoir temperatures and pressure supported by offsetting wells. Current well pair performance between 800 – 1,000 bbl/d per well has exceeded management’s expectations. Hangingstone continues to deliver meaningful cash flow contributions to the Company.

    Duvernay Energy Corporation Q2 2025 Highlights and Operations Update

    • Production: Production of 2,612 boe/d (72% Liquids).
    • Cash Flow: Adjusted Funds Flow of $5.5 million with an Operating Netback of $24.84/boe ($32.03/boe H1 2025).
    • Capital: $17.0 million of capital expenditures including completions on a 30% working interest four-well pad.  

    During the quarter completions operations commenced on a four well pad (30% working interest) with average laterals of ~5,000 meters. Completion operations on this pad were completed in mid July and the wells are expected to be on production in early August. A three well pad (100% working interest) is scheduled to be completed in early Fall and on production shortly thereafter. Earlier in 2025, a strategic gathering system was completed connecting the operated wells to existing operated infrastructure.

    Production from new wells drilled in 2024 continue to validate DEC’s type curve expectations. The five wells placed on production have averaged IP30’s of ~1,200 boe/d per well (86% Liquids) and IP90s of ~940 boe/d (86% Liquids) per well.

    DEC retains significant operational flexibility with no near-term land expiries and the ability to adjust spending in response to commodity price movements.

    About Athabasca Oil Corporation

    Athabasca Oil Corporation is a Canadian energy company with a focused strategy on the development of thermal and light oil assets. Situated in Alberta’s Western Canadian Sedimentary Basin, the Company has amassed a significant land base of extensive, high quality resources. Athabasca’s light oil assets are held in a private subsidiary (Duvernay Energy Corporation) in which Athabasca owns a 70% equity interest. Athabasca’s common shares trade on the TSX under the symbol “ATH”. For more information, visit www.atha.com.

    For more information, please contact:

    Reader Advisory:

    This News Release contains forward-looking information that involves various risks, uncertainties and other factors. All information other than statements of historical fact is forward-looking information. The use of any of the words “anticipate”, “plan”, “project”, “continue”, “maintain”, “may”, “estimate”, “expect”, “will”, “target”, “forecast”, “could”, “intend”, “potential”, “guidance”, “outlook” and similar expressions suggesting future outcome are intended to identify forward-looking information. The forward-looking information is not historical fact, but rather is based on the Company’s current plans, objectives, goals, strategies, estimates, assumptions and projections about the Company’s industry, business and future operating and financial results. This 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. No assurance can be given that these expectations will prove to be correct and such forward-looking information included in this News Release should not be unduly relied upon. This information speaks only as of the date of this News Release. In particular, this News Release contains forward-looking information pertaining to, but not limited to, the following: our strategic plans; the allocation of future capital; timing and quantum for shareholder returns including share buybacks; the terms of our NCIB program; our drilling plans and capital efficiencies; production growth to expected production rates and estimated sustaining capital amounts; timing of Leismer’s and Hangingstone’s pre-payout royalty status; applicability of tax pools; Adjusted Funds Flow and Free Cash Flow over various periods; type well economic metrics; number of drilling locations; forecasted daily production and the composition of production; break-even metrics, our outlook in respect of the Company’s business environment, including in respect of commodity pricing; and other matters.

    In addition, information and statements in this News Release relating to “Reserves” and “Resources” are deemed to be forward-looking information, as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated, and that the reserves and resources described can be profitably produced in the future. With respect to forward-looking information contained in this News Release, assumptions have been made regarding, among other things: commodity prices; the regulatory framework governing royalties, taxes and environmental matters in the jurisdictions in which the Company conducts and will conduct business and the effects that such regulatory framework will have on the Company, including on the Company’s financial condition and results of operations; the Company’s financial and operational flexibility; the Company’s financial sustainability; Athabasca’s cash flow break-even commodity price; the Company’s ability to obtain qualified staff and equipment in a timely and cost-efficient manner; the applicability of technologies for the recovery and production of the Company’s reserves and resources; future capital expenditures to be made by the Company; future sources of funding for the Company’s capital programs; the Company’s future debt levels; future production levels; the Company’s ability to obtain financing and/or enter into joint venture arrangements, on acceptable terms; operating costs; compliance of counterparties with the terms of contractual arrangements; impact of increasing competition globally; collection risk of outstanding accounts receivable from third parties; geological and engineering estimates in respect of the Company’s reserves and resources; recoverability of reserves and resources; the geography of the areas in which the Company is conducting exploration and development activities and the quality of its assets. Certain other assumptions related to the Company’s Reserves and Resources are contained in the report of McDaniel & Associates Consultants Ltd. (“McDaniel”) evaluating Athabasca’s Proved Reserves, Probable Reserves and Contingent Resources as at December 31, 2024 (which is respectively referred to herein as the “McDaniel Report”).

    Actual results could differ materially from those anticipated in this forward-looking information as a result of the risk factors set forth in the Company’s Annual Information Form (“AIF”) dated March 5, 2025 available on SEDAR at www.sedarplus.ca, including, but not limited to: weakness in the oil and gas industry; exploration, development and production risks; prices, markets and marketing; market conditions; trade relations and tariffs; climate change and carbon pricing risk; statutes and regulations regarding the environment including deceptive marketing provisions; regulatory environment and changes in applicable law; gathering and processing facilities, pipeline systems and rail; reputation and public perception of the oil and gas sector; environment, social and governance goals; political uncertainty; state of capital markets; ability to finance capital requirements; access to capital and insurance; abandonment and reclamation costs; changing demand for oil and natural gas products; anticipated benefits of acquisitions and dispositions; royalty regimes; foreign exchange rates and interest rates; reserves; hedging; operational dependence; operating costs; project risks; supply chain disruption; financial assurances; diluent supply; third party credit risk; indigenous claims; reliance on key personnel and operators; income tax; cybersecurity; advanced technologies; hydraulic fracturing; liability management; seasonality and weather conditions; unexpected events; internal controls; limitations and insurance; litigation; natural gas overlying bitumen resources; competition; chain of title and expiration of licenses and leases; breaches of confidentiality; new industry related activities or new geographical areas; water use restrictions and/or limited access to water; relationship with Duvernay Energy Corporation; management estimates and assumptions; third-party claims; conflicts of interest; inflation and cost management; credit ratings; growth management; impact of pandemics; ability of investors resident in the United States to enforce civil remedies in Canada; and risks related to our debt and securities. All subsequent forward-looking information, whether written or oral, attributable to the Company or persons acting on its behalf are expressly qualified in their entirety by these cautionary statements.

    Also included in this News Release are estimates of Athabasca’s 2025 outlook which are based on the various assumptions as to production levels, commodity prices, currency exchange rates and other assumptions disclosed in this News Release. To the extent any such estimate constitutes a financial outlook, it was approved by management and the Board of Directors of Athabasca and is included to provide readers with an understanding of the Company’s outlook. Management does not have firm commitments for all of the costs, expenditures, prices or other financial assumptions used to prepare the financial outlook or assurance that such operating results will be achieved and, accordingly, the complete financial effects of all of those costs, expenditures, prices and operating results are not objectively determinable. The actual results of operations of the Company and the resulting financial results may vary from the amounts set forth herein, and such variations may be material. The outlook and forward-looking information contained in this New Release was made as of the date of this News release and the Company disclaims any intention or obligations to update or revise such outlook and/or forward-looking information, whether as a result of new information, future events or otherwise, unless required pursuant to applicable law.

    Oil and Gas Information

    “BOEs” may be misleading, particularly if used in isolation. A BOE conversion ratio of six thousand cubic feet of natural gas to one barrel of oil equivalent (6 Mcf: 1 bbl) is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. As the value ratio between natural gas and crude oil based on the current prices of natural gas and crude oil is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.

    Initial Production Rates 

    Test Results and Initial Production Rates: The well test results and initial production rates provided herein should be considered to be preliminary, except as otherwise indicated. Test results and initial production rates disclosed herein may not necessarily be indicative of long-term performance or of ultimate recovery.

    Reserves Information

    The McDaniel Report was prepared using the assumptions and methodology guidelines outlined in the COGE Handbook and in accordance with National Instrument 51-101 Standards of Disclosure for Oil and Gas Activities, effective December 31, 2024. There are numerous uncertainties inherent in estimating quantities of bitumen, light crude oil and medium crude oil, tight oil, conventional natural gas, shale gas and natural gas liquids reserves and the future cash flows attributed to such reserves. The reserve and associated cash flow information set forth above are estimates only. In general, estimates of economically recoverable reserves and the future net cash flows therefrom are based upon a number of variable factors and assumptions, such as historical production from the properties, production rates, ultimate reserve recovery, timing and amount of capital expenditures, marketability of oil and natural gas, royalty rates, the assumed effects of regulation by governmental agencies and future operating costs, all of which may vary materially. For those reasons, estimates of the economically recoverable reserves attributable to any particular group of properties, classification of such reserves based on risk of recovery and estimates of future net revenues associated with reserves prepared by different engineers, or by the same engineers at different times, may vary. The Company’s actual production, revenues, taxes and development and operating expenditures with respect to its reserves will vary from estimates thereof and such variations could be material. Reserves figures described herein have been rounded to the nearest MMbbl or MMboe. For additional information regarding the consolidated reserves and information concerning the resources of the Company as evaluated by McDaniel in the McDaniel Report, please refer to the Company’s AIF.

    Reserve Values (i.e. Net Asset Value) is calculated using the estimated net present value of all future net revenue from our reserves, before income taxes discounted at 10%, as estimated by McDaniel effective December 31, 2024 and based on average pricing of McDaniel, Sproule and GLJ as of January 1, 2025.

    The 444 gross Duvernay drilling locations referenced include: 87 proved undeveloped locations and 85 probable undeveloped locations for a total of 172 booked locations with the balance being unbooked locations. Proved undeveloped locations and probable undeveloped locations are booked and derived from the Company’s most recent independent reserves evaluation as prepared by McDaniel as of December 31, 2024 and account for drilling locations that have associated proved and/or probable reserves, as applicable. Unbooked locations are internal management estimates. Unbooked locations do not have attributed reserves or resources (including contingent or prospective). Unbooked locations have been identified by management as an estimation of Athabasca’s multi-year drilling activities expected to occur over the next two decades based on evaluation of applicable geologic, seismic, engineering, production and reserves information. There is no certainty that the Company will drill all unbooked drilling locations and if drilled there is no certainty that such locations will result in additional oil and gas reserves, resources or production. The drilling locations on which the Company will actually drill wells, including the number and timing thereof is ultimately dependent upon the availability of funding, commodity prices, provincial fiscal and royalty policies, costs, actual drilling results, additional reservoir information that is obtained and other factors.

    Non-GAAP and Other Financial Measures, and Production Disclosure

    The “Corporate Consolidated Adjusted Funds Flow”, “Corporate Consolidated Adjusted Funds Flow per Share”, “Athabasca (Thermal Oil) Adjusted Funds Flow”, “Duvernay Energy Adjusted Funds Flow”, “Corporate Consolidated Free Cash Flow”, “Athabasca (Thermal Oil) Free Cash Flow”, “Duvernay Energy Free Cash Flow”, “Corporate Consolidated Operating Income”, “Corporate Consolidated Operating Income Net of Realized Hedging”, “Athabasca (Thermal Oil) Operating Income”, “Duvernay Energy Operating Income”, “Corporate Consolidated Operating Netback”, “Corporate Consolidated Operating Netback Net of Realized Hedging”, “Athabasca (Thermal Oil) Operating Netback”, “Duvernay Energy Operating Netback” and “Cash Transportation and Marketing Expense” financial measures contained in this News Release do not have standardized meanings which are prescribed by IFRS and they are considered to be non-GAAP financial measures or ratios. These measures may not be comparable to similar measures presented by other issuers and should not be considered in isolation with measures that are prepared in accordance with IFRS. Net Cash and Liquidity are supplementary financial measures. The Leismer and Hangingstone operating results are supplementary financial measures that when aggregated, combine to the Athabasca (Thermal Oil) segment results.

    Adjusted Funds Flow, Adjusted Funds Flow Per Share and Free Cash Flow

    Adjusted Funds Flow and Free Cash Flow are non-GAAP financial measures and are not intended to represent cash flow from operating activities, net earnings or other measures of financial performance calculated in accordance with IFRS. The Adjusted Funds Flow and Free Cash Flow measures allow management and others to evaluate the Company’s ability to fund its capital programs and meet its ongoing financial obligations using cash flow internally generated from ongoing operating related activities. Adjusted Funds Flow per share is a non-GAAP financial ratio calculated as Adjusted Funds Flow divided by the applicable number of weighted average shares outstanding. Adjusted Funds Flow and Free Cash Flow are calculated as follows:

      Three months ended
    June 30, 2025
     
     ($ Thousands) Athabasca
    (Thermal Oil)
      Duvernay Energy(1)   Corporate
    Consolidated(1)
     
    Cash flow from operating activities $ 101,142   $ 290   $ 101,432  
    Changes in non-cash working capital   20,922     5,207     26,129  
    Settlement of provisions   33     (3 )   30  
    ADJUSTED FUNDS FLOW   122,097     5,494     127,591  
    Capital expenditures   (56,110 )   (16,956 )   (73,066 )
    FREE CASH FLOW $ 65,987   $ (11,462 ) $ 54,525  
    (1) Duvernay Energy and Corporate Consolidated reflect gross financial metrics before taking into consideration Athabasca’s 70% equity interest in Duvernay Energy.
      Six months ended
    June 30, 2025
     
     ($ Thousands) Athabasca
    (Thermal Oil)
      Duvernay Energy(1)   Corporate
    Consolidated(1)
     
    Cash flow from operating activities $ 214,569   $ 10,216   $ 224,785  
    Changes in non-cash working capital   28,152     3,595     31,747  
    Settlement of provisions   729     5     734  
     ADJUSTED FUNDS FLOW   243,450     13,816     257,266  
    Capital expenditures   (106,486 )   (29,913 )   (136,399 )
     FREE CASH FLOW $ 136,964   $ (16,097 ) $ 120,867  
    (1) Duvernay Energy and Corporate Consolidated reflect gross financial metrics before taking into consideration Athabasca’s 70% equity interest in Duvernay Energy.
      Three months ended
    June 30, 2024
     
     ($ Thousands) Athabasca
    (Thermal Oil)
      Duvernay Energy(1)   Corporate
    Consolidated(1)
     
    Cash flow from operating activities $ 124,027   $ 11,056   $ 135,083  
    Changes in non-cash working capital   25,375     5,390     30,765  
    Settlement of provisions   11     (113 )   (102 )
    ADJUSTED FUNDS FLOW   149,413     16,333     165,746  
    Capital expenditures   (34,084 )   (14,369 )   (48,453 )
    FREE CASH FLOW $ 115,329   $ 1,964   $ 117,293  
    (1) Duvernay Energy and Corporate Consolidated reflect gross financial metrics before taking into consideration Athabasca’s 70% equity interest in Duvernay Energy.
      Six months ended
    June 30, 2024
     
     ($ Thousands) Athabasca
    (Thermal Oil)
      Duvernay Energy(1)   Corporate
    Consolidated(1)
     
    Cash flow from operating activities $ 197,068   $ 14,653   $ 211,721  
    Changes in non-cash working capital   34,761     5,535     40,296  
    Settlement of provisions   1,297     204     1,501  
     ADJUSTED FUNDS FLOW   233,126     20,392     253,518  
    Capital expenditures   (76,203 )   (48,261 )   (124,464 )
     FREE CASH FLOW $ 156,923   $ (27,869 ) $ 129,054  
    (1) Duvernay Energy and Corporate Consolidated reflect gross financial metrics before taking into consideration Athabasca’s 70% equity interest in Duvernay Energy.
     

    Duvernay Energy Operating Income and Operating Netback

    The non-GAAP measure Duvernay Energy Operating Income in this News Release is calculated by subtracting the Duvernay Energy royalties, operating expenses and transportation & marketing expenses from petroleum and natural gas sales which is the most directly comparable GAAP measure. The Duvernay Energy Operating Netback per boe is a non-GAAP financial ratio calculated by dividing the Duvernay Energy Operating Income by the Duvernay Energy production. The Duvernay Energy Operating Income and the Duvernay Energy Operating Netback measures allow management and others to evaluate the production results from the Company’s Duvernay Energy assets.

    The Duvernay Energy Operating Income is calculated using the Duvernay Energy Segments GAAP results, as follows:

      Three months ended
    June 30,
      Six months ended
    June 30,
     
    ($ Thousands, unless otherwise noted) 2025   2024   2025   2024  
    Petroleum and natural gas sales $ 13,526   $ 26,749   $ 31,145   $ 38,287  
    Royalties   (1,792 )   (3,498 )   (4,553 )   (5,812 )
    Operating expenses   (4,870 )   (4,063 )   (8,656 )   (7,703 )
    Transportation and marketing   (960 )   (1,131 )   (1,758 )   (2,029 )
    DUVERNAY ENERGY OPERATING INCOME $ 5,904   $ 18,057   $ 16,178   $ 22,743  
                             

    Athabasca (Thermal Oil) Operating Income and Operating Netback

    The non-GAAP measure Athabasca (Thermal Oil) Operating Income in this News Release is calculated by subtracting the Athabasca (Thermal Oil) segments cost of diluent blending, royalties, operating expenses and cash transportation & marketing expenses from heavy oil (blended bitumen) and midstream sales which is the most directly comparable GAAP measure. The Athabasca (Thermal Oil) Operating Netback per bbl is a non-GAAP financial ratio calculated by dividing the respective projects Operating Income by its respective bitumen sales volumes. The Athabasca (Thermal Oil) Operating Income and the Athabasca (Thermal Oil) Operating Netback measures allow management and others to evaluate the production results from the Athabasca (Thermal Oil) assets.

    The Athabasca (Thermal Oil) Operating Income is calculated using the Athabasca (Thermal Oil) Segments GAAP results, as follows:

      Three months ended
    June 30,
      Six months ended
    June 30,
     
    ($ Thousands, unless otherwise noted) 2025   2024   2025   2024  
    Heavy oil (blended bitumen) and midstream sales $ 355,160   $ 395,279   $ 717,535   $ 700,320  
    Cost of diluent   (147,065 )   (148,166 )   (299,197 )   (282,026 )
    Total bitumen and midstream sales   208,095     247,113     418,338     418,294  
    Royalties   (9,431 )   (28,823 )   (25,395 )   (40,360 )
    Operating expenses – non-energy   (26,810 )   (24,417 )   (51,697 )   (47,542 )
    Operating expenses – energy   (13,621 )   (11,635 )   (27,128 )   (28,193 )
    Transportation and marketing(1)   (22,430 )   (20,544 )   (42,999 )   (40,056 )
    ATHABASCA (THERMAL OIL) OPERATING INCOME $ 135,803   $ 161,694   $ 271,119   $ 262,143  
    (1) Transportation and marketing excludes non-cash costs of $0.6 million and $1.1 million for the three and six months ended June 30, 2025 (three and six months ended June 30, 2024 – $0.6 million and $1.1 million).
     

    Corporate Consolidated Operating Income and Corporate Consolidated Operating Income Net of Realized Hedging and Operating Netbacks

    The non-GAAP measures of Corporate Consolidated Operating Income including or excluding realized hedging in this News Release are calculated by adding or subtracting realized gains (losses) on commodity risk management contracts (as applicable), royalties, the cost of diluent blending, operating expenses and cash transportation & marketing expenses from petroleum, natural gas and midstream sales which is the most directly comparable GAAP measure. The Corporate Consolidated Operating Netbacks including or excluding realized hedging per boe are non-GAAP ratios calculated by dividing Corporate Consolidated Operating Income including or excluding hedging by the total sales volumes and are presented on a per boe basis. The Corporate Consolidated Operating Income and Corporate Consolidated Operating Netbacks including or excluding realized hedging measures allow management and others to evaluate the production results from the Company’s Duvernay Energy and Athabasca (Thermal Oil) assets combined together including the impact of realized commodity risk management gains or losses (as applicable).

      Three months ended
    June 30,
      Six months ended
    June 30,
     
    ($ Thousands, unless otherwise noted) 2025   2024   2025   2024  
    Petroleum, natural gas and midstream sales(1) $ 368,686   $ 422,028   $ 748,680   $ 738,607  
    Royalties   (11,223 )   (32,321 )   (29,948 )   (46,172 )
    Cost of diluent(1)   (147,065 )   (148,166 )   (299,197 )   (282,026 )
    Operating expenses   (45,301 )   (40,115 )   (87,481 )   (83,438 )
    Transportation and marketing(2)   (23,390 )   (21,675 )   (44,757 )   (42,085 )
    Operating Income   141,707     179,751     287,297     284,886  
    Realized gain (loss) on commodity risk mgmt. contracts   394     (1,575 )   (1,249 )   (130 )
    OPERATING INCOME NET OF REALIZED HEDGING $ 142,101   $ 178,176   $ 286,048   $ 284,756  
    (1) Non-GAAP measure includes intercompany NGLs (i.e. condensate) sold by the Duvernay Energy segment to the Athabasca (Thermal Oil) segment for use as diluent that is eliminated on consolidation.
    (2) Transportation and marketing excludes non-cash costs of $0.6 million and $1.1 million for the three and six months ended June 30, 2025 (three and six months ended June 30, 2024 – $0.6 million and $1.1 million).
     

    Cash Transportation and Marketing Expense

    The Cash Transportation and Marketing Expense financial measures contained in this News Release are calculated by subtracting the non-cash transportation and marketing expense as reported in the Consolidated Statement of Cash Flows from the transportation and marketing expense as reported in the Consolidated Statement of Income (Loss) and are considered to be non-GAAP financial measures.

    Net Cash

    Net Cash is defined as the face value of term debt, plus accounts payable and accrued liabilities, plus current portion of provisions and other liabilities plus income tax payable less current assets, excluding risk management contracts.

    Liquidity

    Liquidity is defined as cash and cash equivalents plus available credit capacity.

    Production volumes details

        Three months ended
    June 30,
      Six months ended
    June 30,
     
    Production   2025   2024   2025   2024  
    Duvernay Energy:                  
    Oil and condensate NGLs(1) bbl/d   1,608     2,806     1,723     2,006  
    Other NGLs bbl/d   282     266     304     223  
    Natural gas(2) mcf/d   4,329     4,706     4,585     3,998  
    Total Duvernay Energy boe/d   2,612     3,856     2,791     2,895  
    Total Thermal Oil bitumen bbl/d   36,476     33,765     35,613     32,651  
    Total Company production boe/d   39,088     37,621     38,404     35,546  
    (1) Comprised of 99% or greater of tight oil, with the remaining being light and medium crude oil.
    (2) Comprised of 99% or greater of shale gas, with the remaining being conventional natural gas.
     

    This News Release also makes reference to Athabasca’s forecasted average daily Thermal Oil production of 33,500 ‐ 35,500 bbl/d for 2025. Athabasca expects that 100% of that production will be comprised of bitumen. Duvernay Energy’s forecasted total average daily production of ~4,000 boe/d for 2025 is expected to be comprised of approximately 65% tight oil, 25% shale gas and 10% NGLs.

    Liquids is defined as bitumen, light crude oil, medium crude oil and natural gas liquids.

    Break Even is an operating metric that calculates the US$WTI oil price required to fund operating costs (Operating Break-even), sustaining capital (Sustaining Break-even), or growth capital (Total Capital) within Adjusted Funds Flow.

    The MIL Network

  • MIL-OSI Banking: Newfoundland and Labrador issue RFEI for 150 MW capacity and 500 GWh energy

    Source: – Press Release/Statement:

    Headline: Newfoundland and Labrador issue RFEI for 150 MW capacity and 500 GWh energy

    CanREA members are eager to propose new, affordable, wind and solar energy projects in Newfoundland & Labrador.

    Toronto, July 24, 2025—The Canadian Renewable Energy Association (CanREA) welcomes Newfoundland and Labrador Hydro’s new Request for Expressions of Interest (RFEI), as announced July 9.

    An information session held by Newfoundland and Labrador Hydro on July 23 confirmed that this RFEI is for the supply of energy and/or capacity that, in combination, can provide up to 150 megawatts (MW) of firm capacity and up to 500 gigawatt hours (GWh) of firm energy, to meet the increasing demands of the province’s Island Interconnected System.

    “With this announcement, CanREA is now tracking wind energy, solar energy and energy storage activity coast-to-coast in Canada, with a clear focus on building clean energy projects at scale and pace,” said Vittoria Bellissimo, CanREA’s President and CEO.

    The RFEI will help the utility gather market information to support the development of a Request for Proposals (RFP) and a Request for Information (RFI) later this year.

    “Newfoundland and Labrador needs more power, and our members are ready to compete for the opportunity to develop wind, solar and battery storage projects to help meet these needs, provide affordable, reliable and clean electricity to Newfoundlanders and support economic growth across the province,” said Jean Habel, CanREA’s Senior Director for Québec and Atlantic Canada.  

    Wind and solar energy, coupled with energy storage capacity, can contribute to a decarbonized energy grid, create local economic benefits and improve the resilience of the electricity system.

    CanREA will continue to engage with Newfoundland and Labrador Hydro and the government of Newfoundland and Labrador to ensure this RFEI process will result in the lowest-cost, highest-benefit outcomes for consumers.  

    “This RFEI is a high-priority item for CanREA’s members in Atlantic Canada, and we are confident that it will build momentum in Newfoundland and Labrador over the coming years,” said Eddie Oldfield, CanREA’s Manager for Atlantic Canada. 

    The deadline for questions is Friday, August 1, 2025, at 11:59 p.m. (NDT, and the RFEI bid closing date is Tuesday, September 2, 2025, at 3 p.m. (NDT).

    Quotes

    “With this announcement, CanREA is now tracking wind energy, solar energy and energy storage activity coast-to-coast in Canada, with a clear focus on building clean energy projects at scale and pace.”
    —Vittoria Bellissimo, President and CEO, Canadian Renewable Energy Association (CanREA)

    “Newfoundland and Labrador needs more power, and our members are ready to compete for the opportunity to develop wind, solar and battery storage projects to help meet these needs, provide affordable, reliable and clean electricity to Newfoundlanders and support economic growth across the province.”
    —Jean Habel, Senior Director for Québec and Atlantic Canada, Canadian Renewable Energy Association (CanREA) 

    “This RFEI is a high-priority item for CanREA’s members in Atlantic Canada, and we are confident that it will build momentum in Newfoundland and Labrador over the coming years.”
    —Eddie Oldfield, Atlantic Canada Manager, Canadian Renewable Energy Association (CanREA)

    Canadian Renewable Energy Association 

    Communications Canadian Renewable Energy Association communications@renewablesassociation.ca 

    About CanREA 

    The Canadian Renewable Energy Association (CanREA) is the voice for wind energy, solar energy and energy storage solutions that will power Canada’s energy future. We work to create the conditions for a modern energy system through stakeholder advocacy and public engagement. Our diverse members are uniquely positioned to deliver clean, low-cost, reliable, flexible and scalable solutions for Canada’s energy needs. For more information on how Canada can use wind energy, solar energy and energy storage to help achieve its net-zero commitments, consult “Powering Canada’s Journey to Net-Zero: CanREA’s 2050 Vision.” Follow us on Bluesky and LinkedIn here. Learn more at renewablesassociation.ca. 

    The post Newfoundland and Labrador issue RFEI for 150 MW capacity and 500 GWh energy appeared first on Canadian Renewable Energy Association.

    MIL OSI Global Banks

  • MIL-OSI: Meridian Corporation Reports Second Quarter 2025 Results and Announces a Quarterly Dividend of $0.125 per Common Share

    Source: GlobeNewswire (MIL-OSI)

    MALVERN, Pa., July 24, 2025 (GLOBE NEWSWIRE) — Meridian Corporation (Nasdaq: MRBK) today reported:

      Three Months Ended
    (Dollars in thousands, except per share data) (Unaudited) June 30, 
    2025
      March 31, 
    2025
      June 30, 
    2024
    Income:          
    Net income $ 5,592   $ 2,399   $ 3,326
    Diluted earnings per common share   0.49     0.21     0.30
    Pre-provision net revenue (PPNR) (1)   11,090     8,357     7,072
    (1) See Non-GAAP reconciliation in the Appendix          
               
    • Net income for the quarter ended June 30, 2025 was $5.6 million, or $0.49 per diluted share, up $3.2 million, or 133%, from prior quarter.
    • Pre-provision net revenue1 for the quarter was $11.1 million, an improvement of $4.0 million, or 57%. from Q2’2024.
    • Net interest margin was 3.54% for the second quarter of 2025, while loan yield improved to 7.24%, from prior quarter.
    • Return on average assets and return on average equity for the second quarter of 2025 were 0.90% and 12.68%, respectively.
    • Total assets at June 30, 2025 were $2.5 billion, compared to $2.5 billion at March 31, 2025 and $2.4 billion at June 30, 2024.
    • Commercial loans, excluding leases, increased $33.2 million, or 2% from prior quarter.
    • On July 24, 2025, the Board of Directors declared a quarterly cash dividend of $0.125 per common share, payable August 18, 2025 to shareholders of record as of August 11, 2025.

    Christopher J. Annas, Chairman and CEO commented:

    “Meridian’s second quarter 2025 earnings of $5.6 million were substantially above first quarter 2025, benefiting from improving margin, SBA loan sales and mortgage seasonality. PPNR was up 33% over the same period, reflecting overall healthy growth in our business units and good expense control. Loan growth was 2.5% for the quarter but was negatively impacted by a large SBA loan sale and the planned paydowns in our lease group. We continue to forecast loan growth in the 8-10% range for the year. Management is intensely focused on reducing the nonperforming loans, historically high for us, but negotiations and lengthy court schedules will slow the process.

    Meridian Wealth Partners continued its solid performance with pre-tax income of $604 thousand for the quarter. We have hired senior managers in this unit to further our growth, and capture a greater percentage of opportunities from our loan groups. The mortgage team is performing nicely but still facing a lack of homes for sale in our Philadelphia metro and Baltimore markets. It had a big turnaround from the first quarter, but volume might have been significantly higher if the inventory was sufficient.

    Our principal Philadelphia metro market is healthy and vibrant, and we have not yet seen the impact of economic uncertainties. We are excited about our market penetration in all segments, and believe this will propel us to greater performance.”

    Select Condensed Financial Information

      As of or for the three months ended (Unaudited)
      June 30, 
    2025
      March 31, 
    2025
      December 31, 
    2024
      September 30, 
    2024
      June 30, 
    2024
      (Dollars in thousands, except per share data)
    Income:                  
    Net income $ 5,592     $ 2,399     $ 5,600     $ 4,743     $ 3,326  
    Basic earnings per common share   0.50       0.21       0.50       0.43       0.30  
    Diluted earnings per common share   0.49       0.21       0.49       0.42       0.30  
    Net interest income   21,159       19,776       19,299       18,242       16,846  
                       
    Balance Sheet:                  
    Total assets $ 2,510,938     $ 2,528,888     $ 2,385,867     $ 2,387,721     $ 2,351,584  
    Loans, net of fees and costs   2,108,250       2,071,675       2,030,437       2,008,396       1,988,535  
    Total deposits   2,110,374       2,128,742       2,005,368       1,978,927       1,915,436  
    Non-interest bearing deposits   237,042       323,485       240,858       237,207       224,040  
    Stockholders’ equity   178,020       173,568       171,522       167,450       162,382  
                       
    Balance Sheet Average Balances:                  
    Total assets $ 2,491,627     $ 2,420,571     $ 2,434,270     $ 2,373,261     $ 2,319,295  
    Total interest earning assets   2,404,952       2,330,224       2,342,651       2,277,523       2,222,177  
    Loans, net of fees and costs   2,113,411       2,039,676       2,029,739       1,997,574       1,972,740  
    Total deposits   2,095,028       2,036,208       2,043,505       1,960,145       1,919,954  
    Non-interest bearing deposits   249,745       244,161       259,118       246,310       229,040  
    Stockholders’ equity   176,946       174,734       171,214       165,309       162,119  
                       
    Performance Ratios (Annualized):                  
    Return on average assets   0.90 %     0.40 %     0.92 %     0.80 %     0.58 %
    Return on average equity   12.68 %     5.57 %     13.01 %     11.41 %     8.25 %
                                           

    Income Statement – Second Quarter 2025 Compared to First Quarter 2025

    Second quarter net income increased $3.2 million, or 133.1%, to $5.6 million as net interest income increased $1.4 million, the provision for credit losses decreased $1.4 million, and non-interest income increased $4.0 million. These improvements to net income were partially offset by a $2.6 million increase to non-interest expense over the prior quarter. Detailed explanations of the major categories of income and expense follow below.

    Net Interest income

    The rate/volume analysis table below analyzes dollar changes in the components of interest income and interest expense as they relate to the change in balances (volume) and the change in interest rates (rate) of tax-equivalent net interest income for the periods indicated and allocated by rate and volume. Changes in interest income and/or expense related to changes attributable to both volume and rate have been allocated proportionately based on the relationship of the absolute dollar amount of the change in each category.

      Three Months Ended                
    (dollars in thousands) June 30,
    2025
      March 31,
    2025
      $ Change   % Change   Change due
    to rate
      Change due
    to volume
    Interest income:                      
    Cash and cash equivalents $ 427   $ 613   $ (186 )   (30.3 )%   $ 15     $ (201 )
    Investment securities – taxable   1,792     1,693     99     5.8 %     (10 )     109  
    Investment securities – tax exempt (1)   364     387     (23 )   (5.9 )%     (21 )     (2 )
    Loans held for sale   495     333     162     48.6 %     (15 )     177  
    Loans held for investment (1)   38,204     36,218     1,986     5.5 %     320       1,666  
    Total loans   38,699     36,551     2,148     5.9 %     305       1,843  
    Total interest income $ 41,282   $ 39,244   $ 2,038     5.2 %   $ 289     $ 1,749  
    Interest expense:                      
    Interest-bearing demand deposits $ 1,354   $ 1,229   $ 125     10.2 %   $ (51 )   $ 176  
    Money market and savings deposits   8,097     7,808     289     3.7 %     65       224  
    Time deposits   7,850     7,831     19     0.2 %     (170 )     189  
    Total interest – bearing deposits   17,301     16,868     433     2.6 %     (156 )     589  
    Borrowings   1,672     1,469     203     13.8 %     10       193  
    Subordinated debentures   1,079     1,055     24     2.3 %     22       2  
    Total interest expense   20,052     19,392     660     3.4 %     (124 )     784  
    Net interest income differential $ 21,230   $ 19,852   $ 1,378     6.94 %   $ 413     $ 965  
    (1) Reflected on a tax-equivalent basis.                    
                         

    Interest income increased $2.0 million quarter-over-quarter on a tax equivalent basis, driven by increased average balances of interest earning assets and to a lesser degree by higher yields on those assets. Average interest earning assets increased by $74.7 million, and contributed $1.7 million to interest income, while the yield on earnings assets increased 6 basis points and contributed $289 thousand to interest income.

    Average total loans, excluding residential loans for sale, increased $73.6 million. The largest drivers of this increase were commercial, commercial real estate, construction, and small business loans which on a combined basis increased $72.4 million on average, partially offset by a decrease in average leases of $9.4 million. Home equity, residential real estate, consumer and other loans held in portfolio increased on a combined basis $10.7 million on average.

    Interest expense increased $660 thousand, quarter-over-quarter, due to higher volume of interest-bearing deposits and borrowings. Interest expense on total deposits increased $433 thousand and interest expense on borrowings increased $227 thousand. During the period, interest-bearing checking accounts and money market accounts increased $20.7 million and $18.3 million on average, respectively, while time deposits increased $14.2 million on average. Borrowings increased $14.5 million on average. On a rate basis, interest-bearing checking accounts and time deposits experienced a decrease in the cost, with the overall cost of deposits dropping 5 basis points.

    Overall the net interest margin increased 8 basis points to 3.54% as the cost of funds declined and the yield on earning assets increased.

    Provision for Credit Losses

    The overall provision for credit losses for the second quarter decreased $1.4 million to $3.8 million, from $5.2 million in the first quarter. The lower provisioning reflects the drop in non-performing loans, a decrease in specific reserves required, as well as a lower level of loan growth quarter over quarter. Loan growth was impacted by the sale of SBA loans for the quarter, which exceeded the amount sold in the first quarter by $27.4 million.

    Non-interest income

    The following table presents the components of non-interest income for the periods indicated:

      Three Months Ended        
    (Dollars in thousands) June 30,
    2025
      March 31,
    2025
      $ Change   % Change
    Mortgage banking income $ 5,762     $ 3,393     $ 2,369     69.8 %
    Wealth management income   1,492       1,535       (43 )   (2.8 )%
    SBA loan income   1,988       748       1,240     165.8 %
    Earnings on investment in life insurance   240       222       18     8.1 %
    Net gain (loss) on sale of MSRs   467       (52 )     519     (998.1 )%
    Net change in the fair value of derivative instruments   (102 )     149       (251 )   (168.5 )%
    Net change in the fair value of loans held-for-sale   171       102       69     67.6 %
    Net change in the fair value of loans held-for-investment   190       170       20     11.8 %
    Net gain (loss) on hedging activity   16       21       (5 )   (23.8 )%
    Other   1,064       1,036       28     2.7 %
    Total non-interest income $ 11,288     $ 7,324     $ 3,964     54.1 %
                                 

    Total non-interest income increased $4.0 million, or 54.1%, quarter-over-quarter largely due to a $2.4 million positive improvement in mortgage banking income, combined with a $1.2 million increase in SBA loan income from the sale of SBA loans, and a $467 thousand gain recognized on the sale of MSRs. Mortgage loan sales increased $63.5 million or 42.9% quarter-over-quarter driving higher gain on sale income in addition to an improvement in the overall margin, leading to the higher level of mortgage banking income.  

    SBA loan income increased $1.2 million as the volume of SBA loans sold was up $27.4 million to $39.5 million, for the quarter-ended June 30, 2025 compared to the quarter-ended March 31, 2025. The gross margin on SBA sales was 6.2% for the quarter, down from 8.7% for the previous quarter. The sale included seasoned loans from 2021 & 2022 for which the market premium was much lower.

    Non-interest expense

    The following table presents the components of non-interest expense for the periods indicated:

      Three Months Ended        
    (Dollars in thousands) June 30,
    2025
      March 31,
    2025
      $ Change   % Change
    Salaries and employee benefits $ 13,179   $ 11,385   $ 1,794     15.8 %
    Occupancy and equipment   1,037     1,338     (301 )   (22.5 )%
    Professional fees   1,164     763     401     52.6 %
    Data processing and software   1,706     1,479     227     15.3 %
    Advertising and promotion   1,277     779     498     63.9 %
    Pennsylvania bank shares tax   269     269         %
    Other   2,725     2,730     (5 )   (0.2 )%
    Total non-interest expense $ 21,357   $ 18,743   $ 2,614     13.9 %
                             

    Overall salaries and benefits increased $1.8 million. Bank and wealth segments combined increased $1.4 million, while the mortgage segment increased $407 thousand. Bank and wealth segment salaries and employee benefits increased due to an increase of 12 full-time equivalent employees, as well as an increase in incentives and other benefits. Mortgage segment salaries, commissions, and employee benefits expense are impacted by volume and increased commensurate with the higher level of originations. Occupancy and equipment expense decreased $301 thousand due to a full quarter of savings realized from office lease terminations that occurred in the last few quarters. Professional fees increased $401 thousand over the prior period due to increases in legal, accounting, and other professional fees, while advertising and promotion expenses increased $498 thousand due to the timing of business development activities that typically increase this time of year, including special events.

    Balance Sheet – June 30, 2025 Compared to March 31, 2025

    Total assets decreased $18.0 million, or 0.7%, to $2.5 billion as of June 30, 2025 from $2.5 billion at March 31, 2025. Interest-earning cash and fed funds decreased $84.7 million, or 74.1%, to $29.6 million as of June 30, 2025 from March 31, 2025, as a temporary deposit at the end of the prior quarter of $103 million from a long standing customer, was eventually withdrawn after being on hand for several weeks.

    Portfolio loans grew $36.2 million, or 1.7% quarter-over-quarter. This growth was generated from commercial & industrial loans which increased $32.0 million, or 8.6%, commercial mortgage loans which increased $10.3 million, or 1.2%, and construction loans which increased $7.3 million, or 2.6%. SBA loan balances decreased $16.4 million, or 10.2%, from March 31, 2025, due to the increase in sales of such loans in the second quarter as discussed above in the non-interest income section. Lease financings also decreased $9.0 million, or 13.5% from March 31, 2025, partially offsetting the above noted loan growth, but this decline was expected.

    Total deposits decreased $18.4 million, or 0.9% quarter-over-quarter, led by a decline in non-interest bearing deposit of $86.4 million due to the impact of the $103 million temporary deposit discussed above, but this decline was largely offset by an increase of $68.1 million in interest-bearing deposits. Money market accounts and savings accounts increased a combined $8.7 million, while interest bearing demand deposits increased $12.8 million, and time deposits increased $46.6 million from largely wholesale efforts. Overall borrowings decreased $625 thousand, or 0.4% quarter-over-quarter.

    Total stockholders’ equity increased by $4.5 million from March 31, 2025, to $178.0 million as of June 30, 2025. Changes to equity for the current quarter included net income of $5.6 million, less dividends paid of $1.4 million, offset by a decrease of $102 thousand in other comprehensive income. The Community Bank Leverage Ratio for the Bank was 9.32% at June 30, 2025.

    Asset Quality Summary

    There was a positive improvement in the level of non-performing loans in the second quarter as they decreased $1.7 million to $50.5 million at June 30, 2025 compared to $52.2 million at March 31, 2025. This decline in non-performing loans was largely the result of the repossession of a billboard asset from a commercial loan relationship and a commercial real estate property from a separate commercial loan relationship. These assets were reclassified into OREO and other repossessed assets on the balance sheet at June 30, 2025. The decline in non-performing loans was partially offset by additional SBA loans that became non-performing during the quarter. Included in non-performing loans are $19.4 million of SBA loans of which $10.0 million, or 52%, are guaranteed by the SBA. The SBA portfolio was subject to the Fed’s rapid rate increase and $13.8 million, or 71% of these non-performing loans originated in 2020-2021 when rates were lower by over 500 basis points. As a result of these changes in non-performing loans, the ratio of non-performing loans to total loans decreased 14 bps to 2.35% as of June 30, 2025, from 2.49% as of March 31, 2025.

    Net charge-offs increased to $3.6 million, or 0.17% of total average loans for the quarter ended June 30, 2025, compared to net charge-offs of $2.8 million, or 0.14%, for the quarter ended March 31, 2025. Second quarter charge-offs consisted of $2.2 million in SBA loans, $972 thousand of small ticket equipment leases, and $583 thousand in commercial loans partly related to the repossession of loan collateral discussed above. Overall there were recoveries of $380 thousand, mainly related to leases.

    The ratio of allowance for credit losses to total loans held for investment was 1.00% as of June 30, 2025, relatively flat from 1.01% as of March 31, 2025. The baseline quantitative and qualitative reserve factors increased in the second quarter ACL calculation, offset by the impact of a lower reserve need as specific reserves declined. As of June 30, 2025 there were specific reserves of $3.3 million against individually evaluated loans, a decrease of $1.7 million from $5.0 million in specific reserves as of March 31, 2025.

    About Meridian Corporation

    Meridian Bank, the wholly owned subsidiary of Meridian Corporation, is an innovative community bank serving Pennsylvania, New Jersey, Delaware and Maryland. Through its 17 offices, including banking branches and mortgage locations, Meridian offers a full suite of financial products and services. Meridian specializes in business and industrial lending, retail and commercial real estate lending, electronic payments, and wealth management solutions through Meridian Wealth Partners. Meridian also offers a broad menu of high-yield depository products supported by robust online and mobile access. For additional information, visit our website at www.meridianbanker.com. Member FDIC.

    “Safe Harbor” Statement

    In addition to historical information, this press release may contain “forward-looking statements” within the meaning of the “safe harbor” provisions of the Private Securities Litigation Reform Act of 1995. These forward-looking statements include statements with respect to Meridian Corporation’s strategies, goals, beliefs, expectations, estimates, intentions, capital raising efforts, financial condition and results of operations, future performance and business. Statements preceded by, followed by, or that include the words “may,” “could,” “should,” “pro forma,” “looking forward,” “would,” “believe,” “expect,” “anticipate,” “estimate,” “intend,” “plan,” or similar expressions generally indicate a forward-looking statement. These forward-looking statements involve risks and uncertainties that are subject to change based on various important factors (some of which, in whole or in part, are beyond Meridian Corporation’s control). Numerous competitive, economic, regulatory, legal and technological factors, risks and uncertainties that could cause actual results to differ materially include, without limitation, credit losses and the credit risk of our commercial and consumer loan products; changes in the level of charge-offs and changes in estimates of the adequacy of the allowance for credit losses, or ACL; cyber-security concerns; rapid technological developments and changes; increased competitive pressures; changes in spreads on interest-earning assets and interest-bearing liabilities; changes in general economic conditions and conditions within the securities markets; escalating tariff and other trade policies and the resulting impacts on market volatility and global trade; unanticipated changes in our liquidity position; unanticipated changes in regulatory and governmental policies impacting interest rates and financial markets; legislation affecting the financial services industry as a whole, and Meridian Corporation, in particular; changes in accounting policies, practices or guidance; developments affecting the industry and the soundness of financial institutions and further disruption to the economy and U.S. banking system; among others, could cause Meridian Corporation’s financial performance to differ materially from the goals, plans, objectives, intentions and expectations expressed in such forward-looking statements. Meridian Corporation cautions that the foregoing factors are not exclusive, and neither such factors nor any such forward-looking statement takes into account the impact of any future events. All forward-looking statements and information set forth herein are based on management’s current beliefs and assumptions as of the date hereof and speak only as of the date they are made. For a more complete discussion of the assumptions, risks and uncertainties related to our business, you are encouraged to review Meridian Corporation’s filings with the Securities and Exchange Commission, including our Annual Report on Form 10-K for the year ended December 31, 2024 and subsequently filed quarterly reports on Form 10-Q and current reports on Form 8-K that update or provide information in addition to the information included in the Form 10-K and Form 10-Q filings, if any. Meridian Corporation does not undertake to update any forward-looking statement whether written or oral, that may be made from time to time by Meridian Corporation or by or on behalf of Meridian Bank.

    MERIDIAN CORPORATION AND SUBSIDIARIES
    FINANCIAL RATIOS (Unaudited)
    (Dollar amounts and shares in thousands, except per share amounts)
     
      Three Months Ended
      June 30,
    2025
      March 31,
    2025
      December 31,
    2024
      September 30,
    2024
      June 30,
    2024
    Earnings and Per Share Data:                  
    Net income $ 5,592     $ 2,399     $ 5,600     $ 4,743     $ 3,326  
    Basic earnings per common share $ 0.50     $ 0.21     $ 0.50     $ 0.43     $ 0.30  
    Diluted earnings per common share $ 0.49     $ 0.21     $ 0.49     $ 0.42     $ 0.30  
    Common shares outstanding   11,297       11,285       11,240       11,229       11,191  
                       
    Performance Ratios:                  
    Return on average assets (2)   0.90 %     0.40 %     0.92 %     0.80 %     0.58 %
    Return on average equity (2)   12.68       5.57       13.01       11.41       8.25  
    Net interest margin (tax-equivalent) (2)   3.54       3.46       3.29       3.20       3.06  
    Yield on earning assets (tax-equivalent) (2)   6.89       6.83       6.81       7.06       6.98  
    Cost of funds (2)   3.52       3.56       3.71       4.05       4.10  
    Efficiency ratio   65.82 %     69.16 %     65.72 %     70.67 %     72.89 %
                       
    Asset Quality Ratios:                  
    Net charge-offs (recoveries) to average loans   0.17 %     0.14 %     0.34 %     0.11 %     0.20 %
    Non-performing loans to total loans   2.35       2.49       2.19       2.20       1.84  
    Non-performing assets to total assets   2.14       2.07       1.90       1.97       1.68  
    Allowance for credit losses to:                  
    Total loans and other finance receivables   0.99       1.01       0.91       1.09       1.09  
    Total loans and other finance receivables (excluding loans at fair value) (1)   1.00       1.01       0.91       1.10       1.10  
    Non-performing loans   41.26 %     39.90 %     40.86 %     48.66 %     57.66 %
                       
    Capital Ratios:                  
    Book value per common share $ 15.76     $ 15.38     $ 15.26     $ 14.91     $ 14.51  
    Tangible book value per common share $ 15.44     $ 15.06     $ 14.93     $ 14.58     $ 14.17  
    Total equity/Total assets   7.09 %     6.86 %     7.19 %     7.01 %     6.91 %
    Tangible common equity/Tangible assets – Corporation (1)   6.96       6.73       7.05       6.87       6.76  
    Tangible common equity/Tangible assets – Bank (1)   8.96       8.61       9.06       8.95       8.85  
    Tier 1 leverage ratio – Bank   9.32       9.30       9.21       9.32       9.33  
    Common tier 1 risk-based capital ratio – Bank   10.53       10.15       10.33       10.17       9.84  
    Tier 1 risk-based capital ratio – Bank   10.53       10.15       10.33       10.17       9.84  
    Total risk-based capital ratio – Bank   11.54 %     11.14 %     11.20 %     11.22 %     10.84 %
    (1) See Non-GAAP reconciliation in the Appendix                
    (2) Annualized                  
                       
    MERIDIAN CORPORATION AND SUBSIDIARIES
    CONDENSED CONSOLIDATED STATEMENTS OF INCOME (Unaudited)
    (Dollar amounts and shares in thousands, except per share amounts)
     
      Three Months Ended   Six Months Ended
      June 30,
    2025
      March 31,
    2025
      June 30,
    2024
      June 30,
    2025
      June 30,
    2024
    Interest income:                  
    Loans and other finance receivables, including fees $ 38,697     $ 36,549     $ 36,486     $ 75,246   $ 71,825  
    Securities – taxable   1,792       1,693       1,324       3,485     2,575  
    Securities – tax-exempt   295       313       324       608     649  
    Cash and cash equivalents   427       613       331       1,040     631  
    Total interest income   41,211       39,168       38,465       80,379     75,680  
    Interest expense:                  
    Deposits   17,301       16,868       18,991       34,169     36,383  
    Borrowings and subordinated debentures   2,751       2,524       2,628       5,275     5,842  
    Total interest expense   20,052       19,392       21,619       39,444     42,225  
    Net interest income   21,159       19,776       16,846       40,935     33,455  
    Provision for credit losses   3,803       5,212       2,680       9,015     5,546  
    Net interest income after provision for credit losses   17,356       14,564       14,166       31,920     27,909  
    Non-interest income:                  
    Mortgage banking income   5,762       3,393       5,420       9,155     9,054  
    Wealth management income   1,492       1,535       1,444       3,027     2,761  
    SBA loan income   1,988       748       785       2,736     1,771  
    Earnings on investment in life insurance   240       222       215       462     422  
    Net gain (loss) on sale of MSRs   467       (52 )           415      
    Net change in the fair value of derivative instruments   (102 )     149       203       47     278  
    Net change in the fair value of loans held-for-sale   171       102       (29 )     273     (31 )
    Net change in the fair value of loans held-for-investment   190       170       (24 )     360     (199 )
    Net gain (loss) on hedging activity   16       21       (63 )     37     (82 )
    Other   1,064       1,036       1,293       2,100     3,254  
    Total non-interest income   11,288       7,324       9,244       18,612     17,228  
    Non-interest expense:                  
    Salaries and employee benefits   13,179       11,385       11,437       24,564     22,010  
    Occupancy and equipment   1,037       1,338       1,230       2,375     2,463  
    Professional fees   1,164       763       1,029       1,927     2,527  
    Data processing and software   1,706       1,479       1,506       3,185     3,038  
    Advertising and promotion   1,277       779       989       2,056     1,737  
    Pennsylvania bank shares tax   269       269       274       538     548  
    Other   2,725       2,730       2,553       5,455     4,869  
    Total non-interest expense   21,357       18,743       19,018       40,100     37,192  
    Income before income taxes   7,287       3,145       4,392       10,432     7,945  
    Income tax expense   1,695       746       1,066       2,441     1,943  
    Net income $ 5,592     $ 2,399     $ 3,326     $ 7,991   $ 6,002  
                       
    Basic earnings per common share $ 0.50     $ 0.21     $ 0.30     $ 0.71   $ 0.54  
    Diluted earnings per common share $ 0.49     $ 0.21     $ 0.30     $ 0.70   $ 0.54  
                       
    Basic weighted average shares outstanding   11,228       11,205       11,096       11,215     11,092  
    Diluted weighted average shares outstanding   11,392       11,446       11,150       11,415     11,178  
                                         
    MERIDIAN CORPORATION AND SUBSIDIARIES
    CONDENSED CONSOLIDATED STATEMENTS OF CONDITION (Unaudited)
    (Dollar amounts and shares in thousands, except per share amounts)
     
                       
      June 30,
    2025
      March 31,
    2025
      December 31,
    2024
      September 30,
    2024
      June 30,
    2024
    Assets:                  
    Cash and due from banks $ 20,604     $ 16,976     $ 5,598     $ 12,542     $ 8,457  
    Interest-bearing deposits at other banks   29,570       113,620       21,864       19,805       15,601  
    Federal funds sold         629                    
    Cash and cash equivalents   50,174       131,225       27,462       32,347       24,058  
    Securities available-for-sale, at fair value   187,902       185,221       174,304       171,568       159,141  
    Securities held-to-maturity, at amortized cost   32,642       32,720       33,771       33,833       35,089  
    Equity investments   2,130       2,126       2,086       2,166       2,088  
    Mortgage loans held for sale, at fair value   44,078       28,047       32,413       46,602       54,278  
    Loans and other finance receivables, net of fees and costs   2,108,250       2,071,675       2,030,437       2,008,396       1,988,535  
    Allowance for credit losses   (20,851 )     (20,827 )     (18,438 )     (21,965 )     (21,703 )
    Loans and other finance receivables, net of the allowance for credit losses   2,087,399       2,050,848       2,011,999       1,986,431       1,966,832  
    Restricted investment in bank stock   9,162       8,369       7,753       8,542       10,044  
    Bank premises and equipment, net   12,320       12,028       12,151       12,807       13,114  
    Bank owned life insurance   30,175       29,935       29,712       29,489       29,267  
    Accrued interest receivable   10,334       10,345       9,958       10,012       9,973  
    OREO and other repossessed assets   3,148       249       276       1,967       1,967  
    Deferred income taxes   5,314       5,136       4,669       3,537       3,950  
    Servicing assets   3,658       4,284       4,382       4,364       11,341  
    Servicing assets held for sale                     6,609        
    Goodwill   899       899       899       899       899  
    Intangible assets   2,665       2,716       2,767       2,818       2,869  
    Other assets   28,938       24,740       31,265       33,730       26,674  
    Total assets $ 2,510,938     $ 2,528,888     $ 2,385,867     $ 2,387,721     $ 2,351,584  
                       
    Liabilities:                  
    Deposits:                  
    Non-interest bearing $ 237,042     $ 323,485     $ 240,858     $ 237,207     $ 224,040  
    Interest bearing:                  
    Interest checking   173,865       161,055       141,439       133,429       130,062  
    Money market and savings deposits   956,448       947,795       913,536       822,837       787,479  
    Time deposits   743,019       696,407       709,535       785,454       773,855  
    Total interest-bearing deposits   1,873,332       1,805,257       1,764,510       1,741,720       1,691,396  
    Total deposits   2,110,374       2,128,742       2,005,368       1,978,927       1,915,436  
    Borrowings   138,965       139,590       124,471       144,880       187,260  
    Subordinated debentures   49,792       49,761       49,743       49,928       49,897  
    Accrued interest payable   7,059       7,404       6,860       7,017       7,709  
    Other liabilities   26,728       29,823       27,903       39,519       28,900  
    Total liabilities   2,332,918       2,355,320       2,214,345       2,220,271       2,189,202  
                       
    Stockholders’ equity:                  
    Common stock   13,300       13,288       13,243       13,232       13,194  
    Surplus   82,184       82,026       81,545       81,002       80,639  
    Treasury stock   (26,079 )     (26,079 )     (26,079 )     (26,079 )     (26,079 )
    Unearned common stock held by ESOP   (1,006 )     (1,006 )     (1,006 )     (1,204 )     (1,204 )
    Retained earnings   117,132       112,952       111,961       107,765       104,420  
    Accumulated other comprehensive loss   (7,511 )     (7,613 )     (8,142 )     (7,266 )     (8,588 )
    Total stockholders’ equity   178,020       173,568       171,522       167,450       162,382  
    Total liabilities and stockholders’ equity $ 2,510,938     $ 2,528,888     $ 2,385,867     $ 2,387,721     $ 2,351,584  
                                           
    MERIDIAN CORPORATION AND SUBSIDIARIES
    CONDENSED CONSOLIDATED STATEMENTS OF INCOME AND SEGMENT INFORMATION (Unaudited)
    (Dollar amounts and shares in thousands, except per share amounts)
     
      Three Months Ended
      June 30,
    2025
      March 31,
    2025
      December 31,
    2024
      September 30,
    2024
      June 30,
    2024
    Interest income $ 41,211   $ 39,168   $ 40,028   $ 40,319   $ 38,465
    Interest expense   20,052     19,392     20,729     22,077     21,619
    Net interest income   21,159     19,776     19,299     18,242     16,846
    Provision for credit losses   3,803     5,212     3,572     2,282     2,680
    Non-interest income   11,288     7,324     13,279     10,831     9,244
    Non-interest expense   21,357     18,743     21,411     20,546     19,018
    Income before income tax expense   7,287     3,145     7,595     6,245     4,392
    Income tax expense   1,695     746     1,995     1,502     1,066
    Net Income $ 5,592   $ 2,399   $ 5,600   $ 4,743   $ 3,326
                       
    Basic weighted average shares outstanding   11,228     11,205     11,158     11,110     11,096
    Basic earnings per common share $ 0.50   $ 0.21   $ 0.50   $ 0.43   $ 0.30
                       
    Diluted weighted average shares outstanding   11,392     11,446     11,375     11,234     11,150
    Diluted earnings per common share $ 0.49   $ 0.21   $ 0.49   $ 0.42   $ 0.30
                                 
      Segment Information
      Three Months Ended June 30, 2025   Three Months Ended June 30, 2024
    (dollars in thousands) Bank   Wealth   Mortgage   Total   Bank   Wealth   Mortgage   Total
    Net interest income $ 21,025     $ 63     $ 71     $ 21,159     $ 16,784     $ 36     $ 26     $ 16,846  
    Provision for credit losses   3,803                   3,803       2,680                   2,680  
    Net interest income after provision   17,222       63       71       17,356       14,104       36       26       14,166  
    Non-interest income   3,029       1,492       6,767       11,288       1,673       1,444       6,127       9,244  
    Non-interest expense   15,049       951       5,357       21,357       12,606       804       5,608       19,018  
    Income before income taxes $ 5,202     $ 604     $ 1,481     $ 7,287     $ 3,171     $ 676     $ 545     $ 4,392  
    Efficiency ratio   63 %     61 %     78 %     66 %     68 %     54 %     91 %     73 %
                                   
      Six Months Ended June 30, 2025   Six Months Ended June 30, 2024
    (dollars in thousands) Bank   Wealth   Mortgage   Total   Bank   Wealth   Mortgage   Total
    Net interest income $ 40,730     $ 73     $ 132     $ 40,935     $ 33,376     $ 30     $ 49     $ 33,455  
    Provision for credit losses   9,015                   9,015       5,546                   5,546  
    Net interest income after provision   31,715       73       132       31,920       27,830       30       49       27,909  
    Non-interest income   4,942       3,027       10,643       18,612       3,550       2,760       10,918       17,228  
    Non-interest expense   27,809       1,768       10,523       40,100       24,669       1,636       10,887       37,192  
    Income before income taxes $ 8,848     $ 1,332     $ 252     $ 10,432     $ 6,711     $ 1,154     $ 80     $ 7,945  
    Efficiency ratio   61 %     57 %     98 %     67 %     67 %     59 %     99 %     73 %
                                   

    MERIDIAN CORPORATION AND SUBSIDIARIES
    APPENDIX: NON-GAAP MEASURES (Unaudited)
    (Dollar amounts and shares in thousands, except per share amounts)

    Meridian believes that non-GAAP measures are meaningful because they reflect adjustments commonly made by management, investors, regulators and analysts. The non-GAAP disclosure have limitations as an analytical tool, should not be viewed as a substitute for performance and financial condition measures determined in accordance with GAAP, and should not be considered in isolation or as a substitute for analysis of Meridian’s results as reported under GAAP, nor is it necessarily comparable to non-GAAP performance measures that may be presented by other companies.

      Pre-Provision Net Revenue Reconciliation
      Three Months Ended   Six Months Ended
    (Dollars in thousands, except per share data, Unaudited) June 30,
    2025
      March 31,
    2025
      June 30,
    2024
      June 30,
    2025
      June 30,
    2024
    Income before income tax expense $ 7,287   $ 3,145   $ 4,392   $ 10,432   $ 7,945
    Provision for credit losses   3,803     5,212     2,680     9,015     5,546
    Pre-provision net revenue $ 11,090   $ 8,357   $ 7,072   $ 19,447   $ 13,491
                                 
      Pre-Provision Net Revenue Reconciliation
      Three Months Ended   Six Months Ended
    (Dollars in thousands, except per share data, Unaudited) June 30,
    2025
      March 31,
    2025
      June 30,
    2024
      June 30,
    2025
      June 30,
    2024
    Bank $ 9,005   $ 8,860     $ 5,851   $ 17,863   $ 12,257
    Wealth   604     726       676     1,332     1,154
    Mortgage   1,481     (1,229 )     545     252     80
    Pre-provision net revenue $ 11,090   $ 8,357     $ 7,072   $ 19,447   $ 13,491
                                   
      Allowance For Credit Losses (ACL) to Loans and Other Finance Receivables, Excluding and Loans at Fair Value
      June 30,
    2025
      March 31,
    2025
      December 31,
    2024
      September 30,
    2024
      June 30,
    2024
    Allowance for credit losses (GAAP) $ 20,851     $ 20,827     $ 18,438     $ 21,965     $ 21,703  
                       
    Loans and other finance receivables (GAAP)   2,108,250       2,071,675       2,030,437       2,008,396       1,988,535  
    Less: Loans at fair value   (14,541 )     (14,182 )     (14,501 )     (13,965 )     (12,900 )
    Loans and other finance receivables, excluding loans at fair value (non-GAAP) $ 2,093,709     $ 2,057,493     $ 2,015,936     $ 1,994,431     $ 1,975,635  
                       
    ACL to loans and other finance receivables (GAAP)   0.99 %     1.01 %     0.91 %     1.09 %     1.09 %
    ACL to loans and other finance receivables, excluding loans at fair value (non-GAAP)   1.00 %     1.01 %     0.91 %     1.10 %     1.10 %
                                           
      Tangible Common Equity Ratio Reconciliation – Corporation
      June 30,
    2025
      March 31,
    2025
      December 31,
    2024
      September 30,
    2024
      June 30,
    2024
    Total stockholders’ equity (GAAP) $ 178,020     $ 173,568     $ 171,522     $ 167,450     $ 162,382  
    Less: Goodwill and intangible assets   (3,564 )     (3,615 )     (3,666 )     (3,717 )     (3,768 )
    Tangible common equity (non-GAAP)   174,456       169,953       167,856       163,733       158,614  
                       
    Total assets (GAAP)   2,510,938       2,528,888       2,385,867       2,387,721       2,351,584  
    Less: Goodwill and intangible assets   (3,564 )     (3,615 )     (3,666 )     (3,717 )     (3,768 )
    Tangible assets (non-GAAP) $ 2,507,374     $ 2,525,273     $ 2,382,201     $ 2,384,004     $ 2,347,816  
    Tangible common equity to tangible assets ratio – Corporation (non-GAAP)   6.96 %     6.73 %     7.05 %     6.87 %     6.76 %
                                           
      Tangible Common Equity Ratio Reconciliation – Bank
      June 30,
    2025
      March 31,
    2025
      December 31,
    2024
      September 30,
    2024
      June 30,
    2024
    Total stockholders’ equity (GAAP) $ 228,127     $ 220,768     $ 219,119     $ 217,028     $ 211,308  
    Less: Goodwill and intangible assets   (3,564 )     (3,615 )     (3,666 )     (3,717 )     (3,768 )
    Tangible common equity (non-GAAP)   224,563       217,153       215,453       213,311       207,540  
                       
    Total assets (GAAP)   2,510,684       2,525,029       2,382,014       2,385,994       2,349,600  
    Less: Goodwill and intangible assets   (3,564 )     (3,615 )     (3,666 )     (3,717 )     (3,768 )
    Tangible assets (non-GAAP) $ 2,507,120     $ 2,521,414     $ 2,378,348     $ 2,382,277     $ 2,345,832  
    Tangible common equity to tangible assets ratio – Bank (non-GAAP)   8.96 %     8.61 %     9.06 %     8.95 %     8.85 %
                       
      Tangible Book Value Reconciliation
      June 30,
    2025
      March 31,
    2025
      December 31,
    2024
      September 30,
    2024
      June 30,
    2024
    Book value per common share $ 15.76     $ 15.38     $ 15.26     $ 14.91     $ 14.51  
    Less: Impact of goodwill /intangible assets   0.32       0.32       0.33       0.33       0.34  
    Tangible book value per common share $ 15.44     $ 15.06     $ 14.93     $ 14.58     $ 14.17  
                                           

    Contact:
    Christopher J. Annas
    484.568.5001
    CAnnas@meridianbanker.com

    The MIL Network

  • MIL-OSI Economics: Press Briefing Transcript: Julie Kozack, Director, Communications Department, July 24, 2025

    Source: International Monetary Fund

    July 24, 2025

    SPEAKER:  Ms. Julie Kozack, Director of the Communications Department, IMF

    MS. KOZACK: Good morning, and welcome to the IMF Press Briefing. It is wonderful to see all of you, both those of you here in person and colleagues online as well. I’m Julie Kozack, Director of the Communications Department at the IMF. As usual, this briefing is embargoed until 11 A.M. Eastern Time in the United States. I’ll start with a few announcements and then I’ll take your questions in person on Webex and via the Press Center.
    First, we will be releasing our flagship publication, the World Economic Outlook Update, next Tuesday, July 29th. The report will offer fresh insights into the current global economic trends and external imbalances.
    For your planning purposes, our Executive Board will be in recess from August 4th through the 15th, and we will notify you in due course on the date of our next press briefing.
    And with that, I will now open the floor for your questions. For those connecting virtually, please turn on both your camera and microphone when speaking, and the floor is opened.

    QUESTIONER: Just wanted to ask you about the tariff situation that’s unfolding at the moment, given the recent trade deals that the U.S. has struck with its key trading partners, including Japan, Indonesia, Philippines, just recently. The European Union is under negotiations that’s coming to fruition soon. It looks like the consensus is kind of around a 15 to 20% tariff rate in that range, that the US is, sort of agreeing with its partners for. And I just wanted to know if the IMF views that as an acceptable rate? Whether this would be detrimental to the global economy. I know we have the WEO coming out in a few days. Just wanted to get your take on what’s unfolding right now.

    MS. KOZACK: Let us see if there’s any other questions on this topic before I answer. If anyone online wants to come in on this topic, please let us know.
    So let me start with where we are. Since April, when we think about the global economy, we see activity indicators that reflect a complex backdrop shaped by trade tensions. We also saw that in the first quarter of the year, the data showed some front-loading of exports and imports ahead of, at that time, what was expected tariff increases. The more recent data points to trade diversion and to some unwinding of the front-loading. And at the same time, we are seeing some trade deals. Some have lowered tariffs. And at the same time, there’s also been some deals or some, not deals, but we have seen increases in tariffs, for example, on steel, aluminum, and copper. So, our team is assessing all of this information as it is coming in. And they will put together a comprehensive picture, which we will talk about in the WEO next week.

    I would also just remind that when we released our WEO in April, we talked about a period of very high uncertainty. And at that time, we had in our WEO a reference forecast, right? And that reflected the fact that we were in an uncertain environment where there were many different paths forward. For example, we had an effective tariff rate of the U.S. of about 25 percent based on April 2nd announcements. That effective tariff rate for the U.S. declined to 14 percent based on the pause of April 9th. And of course, one of the important factors for assessing the impact of the deals on the U.S. economy and the global economy will be what is the new effective tariff rate that will prevail.
    So, all of that work is ongoing, and we will have a full assessment next week in the WEO.

    QUESTIONER: So, would the 15 to 20 percent rate be higher than what we saw in the April WEO?

    MS. KOZACK: I think the way I would answer that is to simply say that we are looking at all the deals in April, and we had an effective rate around 14 percent. There, of course, has been movement since April. There have been deals. There have been some reductions in some tariff rates. There have been increases in other tariff rates. So, the team is going to have to put together that comprehensive assessment to determine what would be the new effective tariff rate that would prevail. And then, we would be in a position to compare it to what we had based on the April 2 announcement, what we had based on the April 9 pause, and then where we are today.
    And another very important factor will be what is the overall impact on uncertainty, right? We have talked about being in a very highly uncertain environment. So, of course, we will be looking at that closely as well.

    QUESTIONER: The president of Ukraine recently signed a law that regulates the anti-corruption bodies in the country. How does the IMF view this law, and how can this impact IMF Ukraine cooperation moving forward? And secondly, Ukrainian Prime Minister Yulia Svyrydenko said Ukraine is facing a significant budget shortfall and is likely seeking a new IMF loan. What is the IMF’s assessment of the possibility of launching a new program?

    MS. KOZACK: Any other questions on Ukraine?

    QUESTIONER: I just wanted to follow up on whether, despite the moves by the Ukrainian government, can the IMF land to Ukraine?

    MS. KOZACK: Are there questions online on Ukraine? On Ukraine, let me just step back and remind kind of where we are with Ukraine.
    On June 30th, the IMF Board completed the Eighth Review of the EFF program and that enabled a disbursement of half a billion U.S. dollars. And that brought total disbursements under the program to U.S. $10.6 billion. Ukraine’s economy remains resilient. The authorities met, and this was reported as part of the Eighth Review, all of the end-March and continuous quantitative performance criteria; they met the prior action that was required for that review, and they also met two structural benchmarks.
    With respect to the specific questions, on the first question that you had, the enacted law, as we see it, neutralizes the effectiveness of Ukraine’s anti-corruption institutions. And from our perspective, that would be very problematic for macroeconomic stability and growth in Ukraine. Stepping back a bit, you know, the establishment and the development of independent institutions to detect and prosecute corruption cases has been central to the IMF’s engagement with Ukraine over the past 10 years. And these institutions have contributed to an improvement in governance in Ukraine over that period.
    Why is this important for Ukraine? From our perspective, Ukraine needs a robust anti-corruption architecture. And that will help level the playing field, improve the business climate, and attract private investment into Ukraine. And it’s a central piece of Ukraine’s reform agenda. So, from our perspective, safeguarding the independence of anti-corruption institutions remains a critical policy priority.
    We do take note of the government’s intention to introduce a new bill to restore the independence of the anti-corruption institutions.
    So, what I can say now is that in the coming weeks, the IMF Staff and the authorities are expected to intensify discussions about the 2026 budget and s to do an assessment of Ukraine’s financing needs, both for 2026 and over the medium term. They will be intensifying discussions to put together that comprehensive picture. That work is essential for the current program and any future potential engagement that we would have with Ukraine.

    QUESTIONER: If it finishes, what was the Staff assessment of the First Review of the agreement with Argentina and when would the Board’s definition be? And following the report on external reserves published this week, I think it was on Monday, does the IMF’s concerns continue?

    QUESTIONER: Has the Board already met to evaluate the First Review? And do you know if Argentina has requested a waiver? And how does the IMF assess the recent rate in this area, action rate and interest rates? And what are the causes of this change in monetary and exchange rate policy? Thank you.

    QUESTIONER: Yes, to add up to what was asked if there are any concerns regarding the impact of the exchange rates on inflation as well? And also, if the concerns remain regarding the weak external position for Argentina.

    QUESTIONER: President Milei has already confirmed that, for fiscal reasons, he will veto the laws recently passed by the Congress to increase pensions, extend the pension moratorium and declare an emergency disability. So, then has this intention being talked with the IMF previously or what is the IMF position on this matter?

    MS. KOZACK: On Argentina, here is what I can share today. So first, I want to mention that discussions on the First Review, which many of you have mentioned, are very advanced at this stage. And the next step in these discussions will be to reach a Staff-Level Agreement between the authorities and Staff. And we believe that that can happen very shortly. After the Staff-Level Agreement is reached, then Staff will present the documents to the Executive Board for their approval and consideration.
    What I can also add, and we have talked about that before here, is that the program has been off to a strong start. It has been underpinned by the continued implementation of tight macroeconomic policies, including a strong fiscal anchor and a tight monetary policy stance. The transition to a more flexible exchange rate regime has been smooth. Disinflation has resumed. And Argentina has reassessed international capital markets earlier than had been initially anticipated under the program.
    Given that our Staff and the authorities are very engaged in these discussions, which again are at an advanced stage, I’m not going to provide any further details now. We will give space for them to bring those discussions to a conclusion, and then we will, of course, communicate once those discussions have come to a conclusion. And again, we do think that a Staff-Level agreement could happen very, very shortly.

    QUESTIONER: Will the Board meeting be before, and start the holiday recess, or after? Because we are talking about 15 days, if not.

    MS. KOZACK: So right now, I don’t have any further details to share with you, but certainly once a Staff-Level Agreement is reached, we will be communicating, including the potential timing for formal Board discussion.

    QUESTIONER: Can you please kindly update us on the current status of the discussion between the IMF and the Republic of Senegal regarding the temporarily suspended disbursements? Especially with the Annual Meetings approaching in October in Washington, is there a realistic prospect of finalizing the matter before then? This is the first question.
    The second one, following the recent meeting between His Excellency, the President of the Republic of Senegal, Bassirou Diomaye Faye, and Mrs. Gita Gopinath, First Deputy Managing Director of the IMF, could you kindly also share some insight into the key topics discussed? What were the main points of their exchange, particularly in regard to economic and financial cooperation?

    MS. KOZACK: Any other questions on Senegal Online? Does anyone want to come in on Senegal?

    QUESTIONER: I have a follow-up because investors have been expecting the Board to consider the waiver by September. Is that timeline realistic? And the government also said it shared everything in its findings for reconciliation with the IMF. Does the Fund feel it has everything it needs in order to make the decision on the waiver?

    QUESTIONER: Have you received the report done by Mazars? And, is it enough to conclude the misreporting, and can we have maybe a time for the Board? And then, when can we expect also a new program?

    MS. KOZACK: So, let me turn to these questions.
    I’ll start by saying that the IMF remains closely engaged with Senegal. And as part of this process, as was noted, First Deputy Managing Director Gita Gopinath met with President Bassirou Faye during his visit to Washington, D.C. on July 9th. Our First Deputy Managing Director (FDMD), Gopinath, emphasized the IMF’s continued support, as Senegal works to resolve the misreporting matter. And the President reaffirmed his government’s strong commitment to transparency and reform.

    What I can also share is that an IMF Staff team will visit Dakar. The mission is tentatively planned for later in August. The purpose of the mission is going to be to discuss the steps needed to bring the misreporting case to our Executive Board. And the team will also use the opportunity to initiate discussions on the contours of a new IMF-supported program for Senegal. We are also working closely with the authorities to design the corrective actions aimed at addressing the root causes of the misreporting and, of course, to strengthen capacity development in Senegal.

    With respect to the questions on the report by Mazars, what I can share there is that we have received a preliminary debt inventory that has been prepared by Forvis Mazars. Our IMF Staff are currently reviewing that report and all the information in detail. The preliminary assessment in the report is broadly aligned with expectations, and the final validation is ongoing. And I will leave it at that on Senegal. That is what I can share for now.

    QUESTIONER: My question is on Japan. Last week, the upper house election in Japan was over, but still unclear on the composition of a new government. And what is it you are recommending? But almost all parties pledged fiscal — expansionary fiscal policies, from providing cash to reduction of consumption tax. And what is your recommendation to the new government, especially on fiscal policy, given the power of debt in Japan? And my second question is on monetary policy of Federal Reserve next week. And should the Federal Reserve cut interest rates preemptively under the circumstance of huge pressure from President Donald Trump.

    MS. KOZACK: Let us start with Japan. So maybe let me just step back a little bit to give an overview of how we assessed the Japanese economy in our April WEO.
    So, at that time, we expected growth to strengthen in Japan, and we expected inflation to converge to the Bank of Japan’s 2 percent target by 2027. Growth was projected to accelerate from 0.2 percent in 2024 to 0.6 percent this year. At the same time, and as has been the case for quite some time, Japan continues to have high levels of public debt. And because of that, our advice for Japan is for a clear fiscal consolidation plan to offset pressures from rising interest payments and also from aging-related spending. And because of this advice, we assess that Japan has limited fiscal space, again because of high public debt and these future spending needs.

    In the near term, our advice to Japan is that given this limited fiscal space, it is essential that any response to shocks, any fiscal response to shocks, is both temporary and also targeted. And by targeted, I mean targeted toward vulnerable households and firms that may be most affected by shocks. Generalized subsidies and tax cuts, in our view, should be avoided. And that is because they are not targeted to the most vulnerable, and they are not an efficient use of Japan’s limited fiscal space.

    And then, on your second question, what I can say about the U.S. economy is that the U.S. economy has proven to be resilient in the past few years. It is something that we have been talking about for quite some time. But we do see high-frequency data that indicate moderating domestic demand and low consumer and business sentiment in the U.S. In addition, and as we mentioned before, there was a strong front-loading of imports into the U.S. in the first quarter. And that, in anticipation of tariffs, and that led to an important drag on growth in the first quarter. At the same time, in the U.S., labor markets remain resilient, and the unemployment rate remains relatively low.

    With respect to inflation, we do see inflation on a path towards the Fed’s 2 percent target, but it is subject to upside risks. And that means that the Fed’s task is complex given the very highly uncertain economic environment. So the Fed will need to take into account both policies undertaken by the U.S. administration, as well as incoming data in, and of course, data on potential wage pressures as it comes to thinking about, you know, the extent of rate decisions and the timing of any rate decisions going forward.

    QUESTIONER: On Argentina, can the IMF confirm that there was a meeting on Tuesday between the Board and Staff regarding the first program review? And I know you said you wouldn’t be able to divulge much details, but I’m going to ask it anyway. When should you expect Argentina’s $2 billion disbursement?

    MS. KOZACK: So, on the first question, all I can say on this is that it’s not unusual for IMF Staff to informally brief the Executive Board on a broad range of issues. And on the timing of the disbursement, as I already indicated, we will provide more information on the timing for a formal Board meeting only once a Staff-Level Agreement has been reached. And that formal Board meeting would indicate the time when any disbursement would be made available to the Argentine authorities.

    QUESTIONER: First, let me say on behalf of my colleague from the U.S., around the world, as well as in Africa, to say thank you to Gita for everything that she has done. Our engagements with African journalists, especially. So that’s part of what I wanted to say, thank you to her. I know she’s leaving.
    And my question now goes to if you can provide updates on African nations. And I have two specific questions, one on Malawi and one on South Africa. The recent reports on Malawi said the country is facing macroeconomic challenges. I know in 2020 they received the completed HIPC program. Could you provide any updates on whether the country has reached out for any assistance regarding HIPC? Whether they qualify for another Heavily Indebted Poor Countries Initiative (HIPC) program to help them? We know in the past year, they’ve experienced floods, droughts, and natural issues that have affected the economy. I was wondering if the IMF is providing any assistance to them.
    The other question is on South Africa. We see growing tension between South Africa and the U.S. So, can you talk about if there’s any economic implication? South Africa is the largest economic in. Africa is also seen as a gateway to the continent. What are the macroeconomic issues, implications for the South African Development Community region (SADC), and also for the continent as a whole?

    MS. KOZACK: With respect to Malawi, what I can say is we completed the Article IV Consultation with Malawi just yesterday, July 22nd, 2025, or two days ago. So that was the 2025 Article IV Consultation that has been completed. And of course, there will be a lot of rich discussion of the state of the Malawian economy in that report. With respect to your more specific question on HIPC, what I can say is that Malawi completed the HIPC process in 2006. And at that time, Malawi secured U.S. $3.1 billion of debt relief through the HIPC Initiative and the Multilateral Debt Relief Initiative or otherwise known as MDRI. Since 2006, our assessment is that public debt in Malawi has returned to unsustainable levels. Total public debt is reached 88 percent of GDP at the end of 2024. And the interest bill on public debt is estimated to approach about 7 percent of GDP, which is quite high.

    We continue to urge the authorities to take decisive steps to restore public debt sustainability. Completing an external debt Restructuring and addressing the high cost of domestic borrowing are both essential to do this. And of course, strengthening public debt management and securing concessional financing will also be critical. So again, Malawi already completed the HIPC process in 2006.

    And then, on South Africa. What I can say about South Africa, I can talk a bit about how we see the outlook for South Africa, the economic outlook. So right now, based on the April WEO, we see the current economic outlook for South Africa as subdued. We projected growth in April at 1 percent for this year and 1.3 percent for next year. Uncertainty, including related to global trade policies, is weighing on activity in South Africa. And that it’s causing firms and households to delay their investment decisions and also consumption decisions.

    And I would also refer you to the April REO, Regional Economic Outlook, for Africa, and that includes some estimates on the impact of uncertainty and financial conditions on the Sub-Saharan Africa region.
    And finally, we of course continue to assess developments in South Africa, and we’ll be providing an update in the July WEO.

    QUESTIONER: I just had two follow-up questions. One was on your comments about the Fed. As you know, the tension between the Trump administration and the Fed, particularly Chair Powell, has been increasing lately. The President is going to go tour the Fed building that’s being renovated. It is a subject of controversy. Given that the IMF has been a stalwart defender of Central Bank independence, should any of this lead to Chair Powell’s replacement or his resignation? Just wondering, what kind of signal that would send to financial markets, to other countries, what kind of precedent would that set? And secondly, regarding First Deputy Managing Director Gopinath’s departure, can you walk us through the process for choosing a replacement for her?
    Traditionally, this has been a position that the U.S. has had a very strong hand in choosing. It has typically been an American. Do you expect the U.S. Treasury Department, for example, to basically recommend a candidate to the Managing Director?

    MS. KOZACK: On your first question for quite some time, the IMF has consistently advocated for Central Bank independence. And we’ve said it’s critical to ensuring that Central Banks are able to achieve their mandated objectives, such as low and stable inflation. And as we have seen through the disinflation process that has been taking place over the last few years, the credibility of Central Banks around the world has been instrumental in anchoring inflation expectations and in bringing down inflation across, you know, across the world. And across many countries in the world. And it is also important that independence, of course, it must coexist with clear accountability to the public.
    And on the question about the process, on Gita Gopinath’s decision to return to Harvard, maybe just to step back to say that on July 21st, you know, the Managing Director announced that Gita Gopinath, our First Deputy Managing Director, would be leaving the Fund at the end of August to return to Harvard University. She will be the inaugural Gregory and Ania Coffey Professor of Economics in the Department of Economics.

    And for your background, Ms. Gopinath joined the Fund in January 2019 as the first female Chief Economist of the Fund. And she was promoted to First Deputy Managing Director in January of 2022. I can add that this was a personal decision for Ms. Gopinath. She will return to her roots in academia, where she will continue to push the research frontier in international finance and macroeconomics. And she will also be training the next generation of economists.
    With respect to the selection of process and how the process works, the Managing Director selects and appoints the First Managing Director and the three Deputy Managing Directors of the Fund. The appointment is subject to approval by the Fund’s Executive Board. And in making the selection, the Managing Director consults with the Executive Board regarding the type of qualifications that, in the view of the Executive Board, a First Deputy Managing Director or a Deputy Managing Director should possess.

    QUESTIONER: My first question is regarding Sri Lanka. When can we expect the next review for the IMF-supported program? And secondly, given the uncertainties and risks that are currently opposing the economy for Sri Lanka, is there any decision or any exploration by the IMF to revisit some of the targets that have been implemented in the program that was given to Sri Lanka?

    QUESTIONER: I would like to know that now Sri Lanka has already finished four reviews, and now we are heading for the fifth one. What is the overall view of the IMF? That Sri Lanka’s performance, how we perform during these four reviews? And what are the expectations for the next review in brief? Thank you very much.

    MS. KOZACK: I have a question here that came in through the Press center on Sri Lanka. The question is what is the status of the IMF review of Sri Lanka’s program, an assessment of the macroeconomic outlook as well as the status of the review of the current mission that is visiting Sri Lanka. So, let me go ahead and take these. So, stepping back, on July 1st, the IMF’s Executive Board completed the Fourth Review under the EFF arrangement with Sri Lanka. This provided the country with U.S. $350 million to support its economic policies and reforms, and it brought total IMF financial support to U.S. $1.74 billion.

    What I can add is that Sri Lanka’s ambitious reform agenda continues to deliver commendable outcomes. Inflation remains low, revenue collection is improving and reserves, international reserves, continue to accumulate for the country. The post-crisis growth rebound to 5 percent in 2024 is quite remarkable. The revenue-to-GDP ratio improved from 8.2 percent in 2022 to 13.5 percent in 2024. The debt restructuring is nearly complete. And program performance has been generally strong overall, and the government remains committed to program objectives.

    What I can also add is that although the economic outlook remains positive for Sri Lanka, global trade policy and uncertainties do pose risks. And so, as the team moves forward to the Fifth Review, which we expect will be held in the fall, they will, of course, be looking at the overall and making an overall assessment of Sri Lanka’s economy. You know, including any implications from trade tensions or uncertainty. And of course, that will be — they will take that into account in discussions with the authorities on policies, and all of the program matters as part of the Fifth Review.

    QUESTIONER: Hi Julie. Thank you for taking my question. I have two questions, one on Syria and one on Egypt. So today there was the Saudi Syrian Investment Forum in Damascus, and it was said that in addition to the Saudi investments in support that there will be some global support on this. And the IFC was mentioned as well. So, what’s the IMF’s call on this, given that we have one of the G20 countries pledging this huge amount of investments in support? And how will the IMF contribute in this? That’s on Syria.

    And on Egypt, a few weeks ago in our press briefing here, it was mentioned that the two reviews, the Fifth and the Sixth, will be done together in the fall. Can we say that this is going to be in fall after the Annual Meeting, after the WEO report is published for the — for the region and for the global? And what, what is the main factor that we’re looking at here that would ultimately change the way it’s viewed, how Egypt’s economy is viewed in light of all the recent developments?

    MS. KOZACK: On Syria, what I can say is, and as we discussed here before, an IMF staff team did visit Syria from June 1st through 5th, and that was the first visit since 2009. The team was there to assess economic and financial conditions in Syria and to discuss with the authorities their economic policy and capacity building priorities, ultimately to support the recovery of the Syrian economy. With your specific question, what I can say there is that we have mentioned that Syria will need substantial international assistance to support the authorities’ efforts to rehabilitate the economy, meet urgent humanitarian needs, and rebuild essential institutions and infrastructure. And this not only includes concessional financial support, but it also extends to capacity development. And here, the IMF is committed to supporting Syria in its recovery efforts. The IMF Staff is working in coordination with other partners to develop a detailed roadmap for policy and capacity building priorities for some of the key economic institutions. So that’s kind of within our mandate, and that includes the Finance Ministry, the Central Bank, and the Statistics Agency.

    With respect to Egypt, what I can say on Egypt is that the IMF Staff conducted a mission to Cairo in May 2025. The mission noted continued progress under Egypt’s macroeconomic reform program, including improvements in inflation and foreign exchange reserves. However, additional time was needed to finalize key policy measures, particularly those related to reducing the state’s footprint in the economy by advancing the implementation of the state ownership policy and leveling the playing field for businesses. To allow for this continued work, the Fifth and Sixth Reviews under the EFF will be combined, and they are expected to be completed in the fall. Our team remains committed to supporting Egypt in advancing reforms to strengthen resilience and foster inclusive and private sector led growth.

    MS. KOZACK: Coming back to the Press Center, I have a question that has come in on Ghana. It says Ghana’s Finance Minister is presenting the mid-year budget today, following a first half marked by notable improvements in key economic indicators. However, concerns are rising about potential new fiscal slippages, and that could undermine gains in inflation control, currency stability, and overall recovery. Does the IMF share these concerns? And second question, what is your view on the role of monetary policy at this point, especially as the Bank of Ghana prepares to review its policy stance?

    Again, stepping back, on July 7th, the IMF’s Executive Board completed the Fourth Review of Ghana’s ECF arrangement. And after Board approval, Ghana received about U.S. $367 million, bringing total support to around U.S. $2.3 billion since May 2023.
    With respect to the budget here, I can say that the IMF has welcomed the government’s corrective actions, including a strong 2025 budget and an audit of payables to quantify and address the pre-election fiscal slippages. The authorities have recently implemented changes to their public financial management and public procurement acts, and this helps improve the overall fiscal responsibility framework in Ghana. And the authorities have also adopted a strategy to address issues in the energy sector. I can add that the mid-year budget review is fully in line with the parameters and objectives of the IMF-supported program.

    And with respect to the question on monetary policy, what I can say is that Ghana has made good progress since the beginning of the program in reducing inflation. Inflation was extremely high at the end of 2022 at 54 percent. It has now come down substantially to 14 percent at end June 2025. Going forward, it will be important for monetary policy to remain sufficiently tight, consistent with bringing inflation down to the Bank of Ghana’s target range, which is 8 percent plus or minus 2 percentage points.

    QUESTIONER: I’m going to ask about digital assets. One very specifically. There’s this controversy with El Salvador that is going around and around, but the government says they’re still buying Bitcoin, and it seems that the IMF is saying they are just moving things around between wallets. And I wanted you to address that. Also, with the passage here in the U.S. of the GENIUS Act, I guess, what does the IMF, what do they think the impacts of this sort of increasing legitimization of digital assets in the U.S. is going to be in terms of other economies, in terms of the ability to implement monetary policy? I just wonder if you have any comment on that. Thank you very much for taking the question.

    QUESTIONER: I have a question, specifically on El Salvador. How does the IMF assess the country’s continued Bitcoin accumulation in the context of the fiscal and transparency standards embedded in the Extended Fund Facility, the $1.4 billion program that was agreed last December? To what extent could this strategy complicate monitoring or risk management of this program?

    MS. KOZACK: So, on El Salvador, I’ll start with El Salvador and then Matthew, I’ll get to your question on the GENIUS Act. So again, stepping back. So, on June 27th, the IMF Executive Board completed El Salvador’s annual Article IV Consultation and concluded the First Review of the EFF that enabled El Salvador to have access to U.S. $118 million. And so far, $231 million has been disbursed under the EFF program that was approved in February.
    Program performance has been solid in El Salvador. The economy has continued to expand as macroeconomic imbalances are being addressed. The key fiscal and reserve targets were met at the time of the review with margins. And substantial progress continues with the ambitious reform agenda in the areas of governance, transparency, and financial resilience.
    And risks from Bitcoin continue to be mitigated. Regarding the questions on Bitcoin, I don’t have much new to say other than as we have stated in the past, the total amount of Bitcoin held across government-owned wallets remains unchanged, and that is consistent with El Salvador’s program commitments. The accumulation of Bitcoin by the Strategic Bitcoin Reserve Fund is consistent with program conditionality. And the increases in the Bitcoin Reserve Fund relate to movements across various government-owned wallets.
    And on your second question on the GENIUS Act, let me get to this one. Let me just step back for a moment, and then I’ll kind of come directly to the GENIUS Act.

    So, first, the GENIUS Act covers stablecoins, and stablecoins are a key type of privately issued crypto asset that aims to maintain a stable value. They do bring potential benefits, including cheaper and faster cross-border payments, increased financial inclusion, and greater portfolio diversification. So those are some of the potential benefits. There are operational risks, of course, associated with stablecoins if they are not properly regulated under an appropriate policy framework.

    Now, turning to the GENIUS Act. The GENIUS Act provides a comprehensive foundation for financial innovation and deepening. And that is balanced with consideration of consumer protection and market integrity goals and a clear identification of the institutional framework for oversight.
    Now, with respect to the kind of implications of the GENIUS Act, we, of course, are continuing to very actively monitor developments of stablecoins. We are assessing the potential implications of the GENIUS Act. And for us at the IMF, what is going to be especially important are going to be the implications for the international monetary system and the potential for spillovers to other jurisdictions. So that’s work that is ongoing, and our teams are making those assessments at this time.

    QUESTIONER: Any update on UAE economy outlook for GCC region and oil economy in general?

    MS. KOZACK: What I can share on UAE and the GCC in general, and I’ll be — and, of course, next week as part of the WEO update, we will, of course, be providing an update for the GCC region.
    So, starting with the UAE. Near-term growth in the UAE has been strong, and it is expected to remain healthy at over 4 percent in 2025. That was the assessment at the time of the April WEO. What we are seeing is robust growth in the non-hydrocarbon activity, and it is boosted by tourism, construction, public expenditure, and financial services. So those are the drivers of growth. Oil production is also increasing faster than expected, given the reversal of oil production cuts. And the UAE economy has demonstrated resilience to lower oil prices and increased oil price volatility this year.

    Now, turning to the GCC, what I can say for the GCC is that despite oil production cuts, GCC growth is estimated to have rebounded to 1.4 percent in 2024. And our projection at the time of the April WEO was that it will increase further to 3.3 percent in 2025. Non-hydrocarbon output growth is expected to remain strong, supported by rapid investment, construction, and accelerated reforms to diversify the GCC economies.
    Inflation remains low in the GCC, and our policy advice is for fiscal policy to remain prudent while strengthening fiscal reform implementation. And of course, we encourage policymakers in the region to continue reforms to support economic diversification. And as I noted, we will be providing an update of this assessment as part of the WEO update.
    And with that, I’m going to bring this Press Briefing to a close. Thank you all for your participation today.

    As a reminder, this briefing is embargoed until 11:00 A.M. Eastern Time in the United States. A transcript will be made available later on our website, IMF.org. Should you have any clarifications or additional queries, please do reach out to my colleagues via media@imf.org.

    This concludes our Press Briefing. I wish everyone a wonderful day, and I look forward to seeing you all next time.

    IMF Communications Department
    MEDIA RELATIONS

    PRESS OFFICER: Meera Louis

    Phone: +1 202 623-7100Email: MEDIA@IMF.org

    MIL OSI Economics

  • MIL-OSI USA: Magic Valley Times-News: The One Big Beautiful Bill Will Help Idaho’s Rural Hospitals

    US Senate News:

    Source: United States Senator for Idaho Mike Crapo

    The One Big Beautiful Bill Act (OBBBA) has been signed into law, providing significant benefits to Idahoans, including cutting taxes for working families, promoting American manufacturing and energy dominance, and strengthening health care programs to support our most vulnerable populations.

    Nevertheless, the “politics of fear” have continued and disinformation misleads Idahoans about the law’s impact on Idaho’s health care system. In reality, this law represents the largest investment in rural health care in decades.

    The OBBBA ensures a more responsible use of taxpayer dollars by ending loopholes certain states use to get higher Medicaid payments from the federal government. There are two main tools states use to draw down more funds: state-directed payments and provider taxes.

    However, it is important to know that Idaho is not one of the states playing games with federal funding. Idaho does not use state-directed payments and does not have non-nursing home provider taxes above 3.5 percent.

    A responsible steward of taxpayer dollars, Idaho will not be affected by these reforms. Instead, Idaho’s rural hospitals will benefit from a new Rural Health Transformation Program that allocates money to all states, not just those using gimmicks to draw down more federal money.

    This $50 billion rural hospital fund is available to all states and 50 percent will be divided equally among states. This means Idaho stands to gain at least $100 million per year for five years.

    This is arguably the single largest investment in rural health care in more than 20 years. While it provides a way for states that do rely disproportionately on federal funding to make a financial plan, states like Idaho can provide immediate relief to rural hospitals and establish the tools necessary to be successful in the future.

    To understand how the bill’s reforms will save taxpayer dollars, it is important to understand how state-directed payments and provider taxes work.

    State-directed payments are used with Medicaid managed care and allow states to increase rates to providers over the base reimbursement rate. The Biden Administration expanded these payments to reach as high as the average commercial rate, much higher than those routinely paid by federal health programs. The OBBBA prohibits new state-directed payments over Medicare rates immediately and gradually phases down existing payments beginning in 2028. Again, Idaho does not currently use state-directed payments, but there is nothing in the law to prevent it from using these payments in the future.

    For provider taxes, states levy these fees on hospitals and other entities, then use that revenue to collect more federal dollars. For every dollar states spend on Medicaid, the federal government matches at a higher rate. The match is nine-to-one for the Obamacare expansion population, which gives states an incentive to spend more on healthy, able-bodied individuals than on vulnerable patients.

    The OBBBA stops provider tax gaming immediately and incrementally lowers states’ maximum rate beginning in 2028 until it reaches 3.5 percent. Because Idaho does not currently have a non-nursing home provider tax above 3.5 percent, it is ahead of the curve. Recognizing nursing homes overwhelmingly serve vulnerable patients, Congress exempts those provider taxes from the phase down.

    Curbing waste, fraud and abuse in the Medicaid program provides past-due and desperately needed improvement to the program and does not jeopardize rural hospitals. The states that have relied on financing gimmicks have necessary budgetary decisions to make in the years ahead. However, the reality is for states like Idaho, this bill represents a reward for the wise stewardship of taxpayer dollars and a historic investment in rural health care.

     

    MIL OSI USA News

  • MIL-OSI USA: Congresswoman Torres FY26 Community Projects $21 Million to California’s 35th Congressional District

    Source: United States House of Representatives – Congresswoman Norma Torres (35th District of California)

    July 24, 2025

    Washington, D.C. – Today, U.S. Representative Norma J. Torres (CA-35) announced the inclusion of 15 Community Project Funding requests in the House Appropriations Committee funding bills for Fiscal Year 2026. The bills including these projects have all been considered at the subcommittee level, and most have passed through the full Appropriations Committee and now advance to the House floor for consideration.  If fully funded, these locally driven proposals would bring more than $21,772,000 in federal resources directly to communities across California’s 35th Congressional District.

    “As a senior Member of the House Appropriations Committee, I am proud to advocate for strategic federal investments that reflect the real needs of our region—from clean water and safer streets to affordable housing and economic development,” said Congresswoman Torres. “Every one of these projects was developed in close partnership with our local governments, schools, and nonprofits. They will improve public safety, support small businesses, enhance critical infrastructure, and uplift the people of the Inland Empire.”

    Project Include: 

    Autism Society Inland Empire’s Law Enforcement Training Initiative – $1,031,000

    Provides training and resources for law enforcement to foster safer interactions with community members with a condition or disability that may impact communication or require additional accommodations or awareness during an interaction in several cities in the 35th District.

    Chino Basin Advanced Water Purification Demonstration Facility – $1,092,000

    First-of-its-kind water purification facility to increase water quality and long-term resilience.

    Chino Benson Emergency Power Generator Project – $1,092,000

    Backup power to ensure continued water delivery in Chino during outages.

    Chino Valley Innovation Center – $2,000,000

    Establishes a local entrepreneurship hub to support business growth and job creation.

    City of Montclair Fire Department Tractor Tiller Truck – $850,000

    Funds a high-maneuverability fire truck to enhance emergency response.

    City of Upland Campus Avenue Storm Drain Improvement – $1,092,000

    Upgrades storm drain system to prevent flooding and protect homes, schools, and businesses.

    Cypress Grove Supportive Housing – $2,000,000

    Supports the construction of permanent housing to address local homelessness in Fontana.

    Eastvale Library and Innovation Center – $3,100,000

    Expands access to information, education, and community programming.

    Los Serranos Flood Protection Project – $1,092,000

    Installs storm drain system to mitigate flood risk in Chino Hills.

    Merrill Center Crisis Stabilization Unit Rehabilitation – $1,100,000

    Rehabilitates critical behavioral health facilities to support those in crisis in Ontario.

    Monte Vista Water District Pipeline Replacement Project –$1,092,000

    Replaces aging pipeline infrastructure in Montclair to prevent leaks and improve water flow.

    Ontario-Montclair School District’s Safer Schools Initiative – $1,031,000

    Improves school safety infrastructure in collaboration with local law enforcement.

    Ontario Section 219 Recycled Water Expansion Project – $3,200,000

    Constructs 13 miles of new infrastructure to deliver recycled water to public landscapes.

    The Hub on Holt: Space for Entrepreneurship, Creation, and Innovation – $1,000,000

    Revitalizes a blighted corridor to support small businesses and community engagement in Ontario.

    Vista Verde II Affordable Housing Development – $1,000,000

    Adds affordable housing and promotes economic growth through construction jobs in Ontario.

    ###

    MIL OSI USA News

  • MIL-OSI Asia-Pac: Foreign Minister Lin and Paraguayan President Peña hold meeting, reaffirming rock-solid diplomatic ties

    Source: Republic of China Taiwan

    July 15, 2025  No. 245
    Minister of Foreign Affairs Lin Chia-lung met with President Santiago Peña on July 14 while leading a delegation to the Republic of Paraguay. During their meeting, Minister Lin delivered greetings and best wishes from President Lai Ching-te and conveyed sincere friendship to the government and people of Paraguay on behalf of the government and people of Taiwan.
     
    Welcoming Minister Lin’s delegation, President Peña communicated his highest regards to President Lai and reaffirmed the rock-solid diplomatic relations between Taiwan and Paraguay. Acknowledging the fraternal bond between the two countries, the president said that many years of cooperation had yielded diverse and fruitful results in a host of areas. He said that looking ahead, Paraguay would remain undaunted by foreign pressure and threats and continue to work hand in hand with Taiwan so as to move forward together.
     
    In his remarks, Minister Lin thanked President Peña for mentioning Taiwan first among Paraguay’s diplomatic allies during his inauguration speech in August 2023, which he said reflected the significance of Taiwan-Paraguay ties. He said that his visit to Paraguay was being undertaken to celebrate the 68th anniversary of diplomatic relations between the two nations and to lead a delegation of representatives from the semiconductor, ICT, technology, construction, smart agriculture, high-performance textile, green energy, furniture, and food processing industries—sectors with high potential for collaboration with their Paraguayan counterparts. He noted that a number of representatives had already decided to invest in factories in the Taiwan-Paraguay Smart Technology Park so as to develop business opportunities and create win-win outcomes. 
     
    Minister Lin also pointed out that Taiwan’s active promotion of the Diplomatic Allies Prosperity Project in Paraguay included such flagship initiatives as the Taiwan-Paraguay Polytechnic University, the Taiwan-Paraguay Smart Technology Park, an electric bus pilot program, and the development of a health information system (HIS) through the Health Information Management Efficiency Enhancement Project, as well as the planning and implementation of sovereign AI, 5G clean network, and HIS 2.0 programs. He said that these initiatives aimed to help Paraguay develop the technology sector and implement digital transformation, and exemplified the results of bilateral cooperation guided by the mindset that “Taiwan can help, Paraguay can lead.”
     
    President Peña and Minister Lin also attended the Paraguay-Taiwan Investment Opportunities Forum together. Speaking at the event, President Peña underlined the long-standing and solid diplomatic relations between Taiwan and Paraguay. He stated that Paraguay’s firm support for Taiwan over the past 68 years had been based on such shared values as freedom, democracy, and people’s right to self-determination, adding that this would not change for any economic interests or pressure. He said that helping Taiwan maintain its international presence was an important extension of Paraguay’s own legacy and sense of national dignity.
     
    President Peña went on to say that Paraguay’s economy was advancing steadily and that his country boasted an exceptional investment environment. He said he hoped that Taiwanese businesses would gain an in-depth understanding of Paraguay’s development potential and seize investment opportunities.
     
    Taiwan and Paraguay enjoy cordial and strong diplomatic relations. The two countries will continue to deepen their collaboration in education, technology, energy, agriculture, public health, infrastructure, and other fields so as to jointly expand progress and mutual prosperity. (E)

    MIL OSI Asia Pacific News

  • MIL-OSI Asia-Pac: MOFA strongly protests South African government’s announcement unilaterally renaming and downgrading status of Taiwan’s liaison offices

    Source: Republic of China Taiwan

    MOFA strongly protests South African government’s announcement unilaterally renaming and downgrading status of Taiwan’s liaison offices

    Date:2025-07-22
    Data Source:Department of West Asian and African Affairs

    July 22, 2025  
    No. 253  

    Without consulting Taiwan, South Africa’s Department of International Relations and Cooperation (DIRCO) issued a notice in the Government Gazette on July 21 indicating that, from April 1, Taiwan’s liaison offices in South Africa had been renamed the Taipei Commercial Office in Johannesburg and the Taipei Commercial Office in Cape Town. The notice even erroneously cited United Nations General Assembly Resolution 2758 and South Africa’s “one China policy.” The Ministry of Foreign Affairs (MOFA) strongly protests this announcement.
     
    Minister of Foreign Affairs Lin Chia-lung promptly instructed MOFA’s Department of West Asian and African Affairs and the Taipei Liaison Office in the Republic of South Africa (TLO) to lodge solemn protests with the Liaison Office of South Africa in Taipei and DIRCO, respectively. He also directed the TLO to continue to negotiate with DIRCO on the principles of parity and dignity.
     
    South African Deputy President Paul Mashatile led a delegation to China from July 14 to 18. Following his visit, the South African government published its unreasonable announcement in the Government Gazette. This demonstrates that China has ramped up suppression of Taiwan in South Africa and that South Africa is willing to bow to China and exert pressure on Taiwan. MOFA expresses regret and dissatisfaction over these developments.
     
    MOFA reiterates that the position of the Taiwan government remains unchanged and that it will not accept the South African government’s unilateral violation of its 1997 agreement with Taiwan. The Taiwan government will continue to communicate with the South African government on the principles of parity and dignity. And in the face of South Africa’s repeated unilateral changes to the names and status of Taiwan’s liaison offices, Taiwan will take appropriate action in accordance with the circumstances.
     
    MOFA solemnly calls on South Africa, as the host country of this year’s Group of 20 summit, to abide by the 1997 legal framework concerning bilateral relations and not employ coercive tactics against Taiwan’s liaison offices or take any other actions that might interfere with their operations or services before both sides have reached a consensus through consultations. (E)

    MIL OSI Asia Pacific News

  • MIL-OSI: Hold Me Ltd. Signs Binding LOI to Acquire Synthetic Darwin LLC, Creator of Darwinslab Ecosystem – Self-Evolving AI Agents Platform — Eyes Strategic Web3 Expansion

    Source: GlobeNewswire (MIL-OSI)

    Tel Aviv, Israel, July 24, 2025 (GLOBE NEWSWIRE) — Hold Me Ltd. (OTCID: HMELF), an Israeli tech company, today announced the signing of a binding Letter of Intent (LOI) to acquire Synthetic Darwin LLC, a U.S.-based AI research and development studio pioneering the next generation of self-evolving, autonomous AI agents – the DrwinsLab.

    Once fully operational, DarwinsLab’s platform would aim to enable AI agents to independently design, test, and refine themselves through recursive self-improvement and genetic algorithms modeled on natural selection, according to Gabriel Fridman of Synthetic Darwin. These agents operate in complex, open-ended simulation environments where they iteratively optimize architectures, objectives, and performance – with no human-in-the-loop. The system represents a powerful step toward fully autonomous, generalizable AI with wide applicability in R&D, algorithmic trading, decentralized coordination, robotics, and AI governance.

    Under the LOI, Hold Me will acquire 100% of Synthetic Darwin in a share-based transaction, subject to definitive agreements and customary regulatory approvals. As part of the transaction strategy, Hold Me will raise growth capital, positioning the combined company at the intersection of AI, blockchain, and capital markets innovation – effectively making it the first publicly traded company operating an ecosystem powered by a Solana-based utility token.

    “Synthetic Darwin will not just build models – they’re aiming to build meta-models: agents that architect and evolve better agents,” said CEO of Hold Me Ltd. “This is an inflection point in AI, and through this acquisition with a public company, we aim to bring this capability to scale – across sectors ranging from decentralized finance to defense autonomy.”

    The post-transaction vision includes deploying evolved AI agents in industrial and defense applications, financial services, healthcare , and on-chain governance environments, as well as integrating blockchain-based compute and reward layers for AI training economies.

    Menny Shalom, CEO of Hold Me, expects that this acquisition, would not only increase global visibility to the company but also provide access to institutional investors, enabling significant investment into compute, reinforcement environments, and cross-chain integrations.

    About Hold Me Ltd.

    Hold Me Ltd. (OTC: HMELF) is an Israeli-listed technology venture company focused on the convergence of artificial intelligence, decentralized systems, and digital infrastructure.

    About Synthetic Darwin LLC

    Synthetic Darwin LLC is a U.S.-based artificial intelligence company developing self-evolving AI systems through recursive improvement and genetic algorithms. Its autonomous agents are designed to autonomously explore, learn, and improve — unlocking new frontiers in self-directed machine intelligence.

    Forward-Looking Statements

    This press release contains “forward-looking statements” within the meaning of the federal securities laws, including Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. These forward-looking statements are based on Hold Me’s current expectations, estimates and projections about the expected date of closing of the proposed transaction and the potential benefits thereof, its business and industry, management’s beliefs and certain assumptions made by the parties, all of which are subject to change. In this context, forward-looking statements often address expected future business and financial performance and financial condition, and often contain words such as “expect,” “anticipate,” “intend,” “plan,” “believe,” “could,” “seek,” “see,” “will,” “may,” “would,” “might,” “potentially,” “estimate,” “continue,” “expect,” “target,” similar expressions or the negatives of these words or other comparable terminology that convey uncertainty of future events or outcomes. All forward-looking statements by their nature address matters that involve risks and uncertainties, many of which are beyond our control, and are not guarantees of future results, such as statements about the consummation of the proposed transaction and the anticipated benefits thereof. These and other forward-looking statements are not guarantees of future results and are subject to risks, uncertainties and assumptions that could cause actual results to differ materially from those expressed in any forward-looking statements. Accordingly, there are or will be important factors that could cause actual results to differ materially from those indicated in such statements and, therefore, you should not place undue reliance on any such statements and caution must be exercised in relying on forward-looking statements. Important risk factors that may cause such a difference include but are not limited to: the completion of the proposed transaction on anticipated terms and timing; the occurrence of any event, change or other circumstances that could give rise to the termination of the agreement; and the failure to realize the anticipated benefits of the proposed transaction. While the list of factors presented here is, will be, considered representative, no such list should be considered to be a complete statement of all potential risks and uncertainties. Unlisted factors may present significant additional obstacles to the realization of forward-looking statements. Hold Me does not assume any obligation to publicly provide revisions or updates to any forward-looking statements, whether as a result of new information, future developments or otherwise, should circumstances change, except as otherwise required by securities and other applicable laws.

    Contact:
    info@holdme.co.il

    The MIL Network

  • MIL-OSI USA: Rosen Helps Introduce Bill to Protect Access to Birth Control

    US Senate News:

    Source: United States Senator Jacky Rosen (D-NV)
    WASHINGTON, DC – Today, U.S. Senator Jacky Rosen (D-NV) joined Senate colleagues in introducing the Access to Birth Control Act. This legislation would guarantee women timely access to birth control at pharmacies nationwide—including by requiring pharmacies to provide patients with their preferred form of birth control medication.“When the Supreme Court overturned Roe v. Wade, it opened the floodgates to extreme attacks on reproductive freedoms across our nation. Anti-choice extremists have now made it clear that they will target women’s access to birth control and the ability to make their own family planning decisions,” said Senator Rosen. “Women, not anti-choice politicians, should decide what happens with their own bodies. I’m proud to have helped introduce this bill to protect women’s right to access birth control, and I’ll continue standing up to protect women’s ability to make decisions over their own bodies.”
    Senator Rosen continues fighting back against efforts to restrict women’s reproductive freedoms. She helped introduce the Right to Contraception Act, which was blocked by anti-choice Republicans last Congress. She also helped introduce the Let Doctors Provide Reproductive Health Care Act to protect doctors and other health care professionals from being prosecuted for providing reproductive care to their patients, as well as the Women’s Health Protection Act to protect reproductive freedoms in federal law.

    MIL OSI USA News

  • MIL-OSI USA: Malliotakis Applauds DOJ Lawsuit to Hold NYC Accountable for Dangerous Sanctuary Policies

    Source: United States House of Representatives – Congresswoman Nicole Malliotakis (NY-11)

    July 24, 2025

    (NEW YORK, NY) – Congresswoman Nicole Malliotakis issued the following statement regarding the Department of Justice’s lawsuit against New York City over its sanctuary city policies.

     

    “I thank Attorney General Pam Bondi and the Department of Justice for taking action to hold New York City accountable for its dangerous sanctuary policies, which have enabled violent crime in our streets, cost innocent lives, and resulted in billions of taxpayer dollars coming out of New Yorkers’ pockets. 

     

    Restoring public safety in our communities starts with New York City cooperating with ICE’s detainer requests. Failing to do so keeps dangerous criminals on our streets. I filed a Freedom of Information Law request that revealed just how far-reaching the consequences of these failed policies have become. The data showed that over 16,000 crimes were committed by thousands of perpetrators who were residing at hotels and shelters at taxpayer expense. The facts speak for themselves: sanctuary policies aren’t just misguided they are costly and dangerous.

     

    I look forward to continuing to work with the Department of Justice and the Trump Administration to enforce immigration laws, protect our communities, and hold city officials accountable for putting politics before public safety.”

    MIL OSI USA News

  • MIL-OSI United Kingdom: AUKUS treaty deepens UK-Australia defence partnership to generate £20 billion in trade and create 7,000 new jobs

    Source: United Kingdom – Executive Government & Departments

    Press release

    AUKUS treaty deepens UK-Australia defence partnership to generate £20 billion in trade and create 7,000 new jobs

    Foreign Secretary and Defence Secretary in Australia alongside UK’s Carrier Strike Group – demonstrating government’s commitment to a free and open Indo-Pacific.

    • Signing of new UK-Australia AUKUS treaty protects our seas, supports over 21,000 UK jobs and underpins up to £20 billion exports potential.  
    • Foreign Secretary and Defence Secretary in Australia alongside UK’s Carrier Strike Group – demonstrating government’s commitment to a free and open Indo-Pacific. 
    • New treaty unlocks greater economic cooperation and delivers on the Government’s Plan for Change.  

    A new 50 year AUKUS treaty will underpin the UK and Australian submarine programmes, support tens of thousands of jobs in the UK and Australia, enhance both nations’ industrial capacity, and deliver the submarines that keep the UK and our allies safe.   

    The deal demonstrates the Government’s commitment to deliver both security and prosperity, safeguarding jobs across the UK and boosting our defence industry, with new submarine exports amounting to hundreds of millions of pounds a year.  

    Expected to be worth up to £20 billion to the UK in exports over the next 25 years, this decades-long programme will create over 7,000 new jobs in UK shipyards and across the supply chain, building on the billions of pounds already invested in Barrow, Derby and beyond.  

    There will be over 21,000 people working on the conventionally-armed, nuclear-powered AUKUS submarine programme (known as SSN-AUKUS) in the UK at its peak, contributing to opportunities and economic growth in local communities across the UK.  

    Defence Secretary, John Healey, said:   

    AUKUS is one of Britain’s most important defence partnerships, strengthening global security while driving growth at home.

    This historic Treaty confirms our AUKUS commitment for the next half century. Through the Treaty, we are supporting high-skilled, well-paid jobs for tens of thousands of people in both the UK and Australia, delivering on our Plan for Change today and for the generations to come. There are people not yet born who will benefit from the jobs secured through this defence deal.

    Our deep defence relationship with Australia – from our work together to support Ukraine, share vital intelligence, and develop innovative technology – makes us secure at home and strong abroad.

    Foreign Secretary, David Lammy, said:

    The UK-Australia relationship is like no other, and in our increasingly volatile and dangerous world, our anchoring friendship has real impact in the protection of global peace and prosperity. 

    Our new bilateral AUKUS treaty is an embodiment of that – safeguarding a free and open Indo Pacific whilst catalysing growth for both our countries. 

    This is how our government delivers the Plan for Change – protecting our national security and stability whilst generating jobs for Brits.

    This is the latest milestone reached under the AUKUS partnership – our most strategically significant new defence partnership in a generation.  

    The Foreign Secretary and Defence Secretary will travel to Australia as the Carrier Strike Group and more than 3,000 British military personnel take part in the largest military exercise Australia has ever hosted. Their visit follows the exercise’s success where the AUKUS nations worked with Japan on advancing how we use robotics and autonomous systems in our defence systems.   

    Both ministers will meet their counterparts at the annual “Australia-UK Ministerial”, known as AUKMIN, to drive forward collaboration across the board – generating further trade and investment to our £23 billion per year annual trade relationship with Australia.  

    Travelling onto Melbourne, the Foreign Secretary and Defence Secretary will meet with businesses at the forefront of AUKUS – delivering the defence industrial strength needed to protect British, Australian and American interests.   

    The Foreign Secretary and Defence Secretary will visit Darwin to see our commitment to the Indo-Pacific first hand as the Carrier Strike Group docks in the Northern Territory.   

    This deployment – one of the UK’s largest this century – sends a clear message that the UK alongside our partners stands ready to protect the Indo-Pacific’s vital trade routes and will deter those who undermine global security.  

    On HMS Prince of Wales, the flagship of the group, the Foreign Secretary and Defence Secretary will meet the service personnel who have participated in Exercise Talisman Sabre, one of the largest military exercises in the world this year. Bringing together over 35,000 military personnel from 19 nations, this exercise strengthens and tests how key partners can work together to safeguard global trade routes and maintain regional stability.  

    The Carrier Strike Group deployment this year reinforces the Government’s Plan for Change by strengthening the international partnerships that underpin economic growth and national security, keeping Britain secure at home and strong abroad. It takes place against the backdrop of the Government’s landmark commitment to increase defence spending to 2.6% of GDP by 2027.   

    This historic investment underpins the Government’s mission-led approach to securing Britain’s future, providing the economic stability necessary for growth whilst ensuring the UK maintains cutting-edge capabilities such as to meet emerging global threats.

    Media enquiries

    Email newsdesk@fcdo.gov.uk

    Telephone 020 7008 3100

    Email the FCDO Newsdesk (monitored 24 hours a day) in the first instance, and we will respond as soon as possible.

    Updates to this page

    Published 24 July 2025

    MIL OSI United Kingdom

  • MIL-OSI: Landmark Bancorp, Inc. Announces Second Quarter 2025 Earnings per Share of $0.75 Declares Cash Dividend of $0.21 per Share

    Source: GlobeNewswire (MIL-OSI)

    Manhattan, KS, July 24, 2025 (GLOBE NEWSWIRE) — Landmark Bancorp, Inc. (“Landmark”; Nasdaq: LARK) reported diluted earnings per share of $0.75 for the second quarter of 2025, compared to $0.81 per share in the first quarter of 2025 and $0.52 per share in the same quarter of the prior year. Net earnings for the second quarter totaled $4.4 million, compared to $4.7 million in the prior quarter and $3.0 million in the second quarter of 2024. For the three months ended June 30, 2025, the return on average assets was 1.11%, the return on average equity was 12.25% and the efficiency ratio(1) was 62.8%.

    For the first six months of 2025, diluted earnings per share totaled $1.56 compared to $1.01 during the same period in 2024. Net earnings for the first six months of 2025 totaled $9.1 million, compared to $5.8 million in the first six months of 2024. For the six months ended June 30, 2025, the return on average assets was 1.16%, the return on average equity was 12.96%, and the efficiency ratio(1) was 63.4%.

    Second Quarter 2025 Performance Highlights

      Total gross loans increased in the second quarter 2025 by $42.9 million, an annualized increase of 16.0% over the prior quarter.
      The net interest margin improved 7 basis points to 3.83% compared to 3.76% in prior quarter and 3.25% in the second quarter of the prior year.
      Net interest income increased $564,000, or 4.3%, in the second quarter of 2025, and increased $2.7 million, or 24.7%, from the same quarter of the prior year.
      Deposits increased $23.4 million, or 1.9%, from the same quarter of the prior year, and declined $61.9 million from the prior quarter.
      Total assets increased $46.7 million, or 11.9% annualized, compared to the prior quarter.
      Credit quality remained stable with net charge-offs totaling $40,000 in the second quarter.
      Stockholders’ equity increased $5.7 million, and the ratio of equity to assets increased to 9.13% in the second quarter.
         

    In making this announcement, Abby Wendel, President and Chief Executive Officer of Landmark, commented, “I am pleased to report continued strong net earnings this quarter driven by growth in loans and net interest income. Loan demand remained strong in the second quarter of 2025, especially for commercial, commercial real estate and residential mortgage loans as total gross loans increased by $42.9 million or 16.0% annualized. Despite a decrease in total deposits in the second quarter, we have sustained year-over-year growth of $23.4 million, or 1.9%. The strong growth in our loan portfolio led to net interest income growth of 24.7% over the previous year and continued expansion in our net interest margin, which increased to 3.83%. Non-interest income increased by 8.0% this quarter compared to the prior quarter and expenses were well controlled. Credit quality remained solid overall with minimal net charge-offs. A provision for credit losses of $1.0 million was recorded this quarter to reflect the growth in loans and higher reserves against individually evaluated loans on non-accrual. Our strong performance is a direct result of the daily commitment and effort our associates put into making Landmark the top choice for both customers and investors.”

    Landmark’s Board of Directors declared a cash dividend of $0.21 per share, to be paid August 27, 2025, to common stockholders of record as of the close of business on August 13, 2025.

    Management will host a conference call to discuss the Company’s financial results at 10:00 a.m. (Central time) on Friday, July 25, 2025. Investors may participate via telephone by dialing (833) 470-1428 and using access code 703723. A replay of the call will be available through August 1, 2025, by dialing (855) 762-8306 and using access code 160217.

    (1) Non-GAAP financial measure. See the “Non-GAAP Financial Measures” section of this press release for a reconciliation. 

    Net Interest Income

    Net interest income in the second quarter of 2025 totaled $13.7 million representing an increase of $564,000, or 4.3%, compared to the previous quarter and an increase of $2.7 million, or 24.7%, in the same quarter of the prior year. The increase in net interest income this quarter was driven by higher interest income on loans and lower interest expense on deposits. The net interest margin increased to 3.83% during the second quarter from 3.76% during the prior quarter and 3.25% in the second quarter of the prior year. Compared to the previous quarter, interest income on loans increased $791,000 to $17.2 million, due to higher average balances combined with higher yields on loans. Average loan balances increased $33.3 million, while the average tax-equivalent yield on the loan portfolio increased 3 basis points to 6.37%. Interest on investment securities declined slightly due to lower balances, partially offset by higher earning rates. Compared to the first quarter of 2025, interest on deposits decreased $92,000, or 1.8%, due to lower rates and balances. Interest on other borrowed funds increased by $284,000, due to higher average balances. The average rate on interest-bearing deposits decreased 3 basis points to 2.14% while the average rate on other borrowed funds decreased 11 basis points to 4.98% in the second quarter of 2025.

    Non-Interest Income

    Non-interest income totaled $3.6 million for the second quarter of 2025, an increase of $268,000 from the previous quarter. The increase in non-interest income during the second quarter of 2025 was primarily due to increases of $178,000 in gains on sales of loans and $88,000 in fees and service charges.

    Non-Interest Expense

    During the second quarter of 2025, non-interest expense totaled $11.0 million, an increase of $200,000, or 1.9%, compared to the prior quarter. The increase in non-interest expense was primarily due to increases of $233,000 in data processing expense and $101,000 in other non-interest expense. The increase in data processing expense resulted from the implementation of additional services added and account growth, while the increase in other non-interest expense was primarily due to higher losses at our captive insurance subsidiary. Partially offsetting those increases was a decline in professional fees related to lower consulting and legal expenses during the quarter.

    Income Tax Expense

    Landmark recorded income tax expense of $944,000 in the second quarter of 2025 compared to $1.0 million in the first quarter of 2025. The effective tax rate was 17.7% in the second quarter of 2025 compared to 17.8% in the first quarter of 2025.

    Balance Sheet Highlights

    As of June 30, 2025, gross loans totaled $1.1 billion, an increase of $42.9 million, or 16.0% annualized since March 31, 2025. During the quarter, loan growth was primarily comprised of one-to-four family residential real estate (growth of $21.5 million), commercial (growth of $13.4 million) and commercial real estate (growth of $10.9 million). Investment securities available-for-sale decreased $3.6 million during the second quarter of 2025 mainly due to maturities. Pre-tax unrealized net losses on the investment securities portfolio decreased from $17.1 million at March 31, 2025, to $13.9 million at June 30, 2025, mainly due to lower market rates for these securities at June 30, 2025.

    Period end deposit balances decreased $61.9 million to $1.3 billion at June 30, 2025. The decline in deposits was driven by decreases in money market and checking accounts (decrease of $50.5 million), non-interest-bearing demand deposits (decrease of $16.5 million) and savings (decrease of $1.1 million), partially offset by an increase in certificates of deposit (increase of $6.2 million). The decrease in deposits was primarily driven by a decline in brokered deposits as well as lower core deposit balances at June 30, 2025. Total borrowings increased $105.9 million during the second quarter 2025 to fund asset growth and to offset lower deposit balances. At June 30, 2025, the loan to deposits ratio was 86.6% compared to 79.5% in the prior quarter.

    Stockholders’ equity increased to $148.4 million (book value of $25.66 per share) as of June 30, 2025, from $142.7 million (book value of $24.69 per share) as of March 31, 2025. The increase in stockholders’ equity was due mainly to a decrease in accumulated other comprehensive losses (lower unrealized net losses on investment securities) along with net earnings during the quarter. The ratio of equity to total assets increased to 9.13% on June 30, 2025, from 9.04% on March 31, 2025.

    The allowance for credit losses totaled $13.8 million, or 1.23% of total gross loans on June 30, 2025, compared to $12.8 million, or 1.19% of total gross loans on March 31, 2025. Net loan charge-offs totaled $40,000 in the second quarter of 2025, compared to $23,000 during the first quarter of 2025 and net recoveries of $52,000 in the second quarter of the prior year. A provision for credit losses on loans of $1.0 million was recorded in the second quarter of 2025 compared to no provision in the first quarter of 2025.

    Non-performing loans totaled $17.0 million, or 1.52% of gross loans, at June 30, 2025, compared to $13.3 million, or 1.24% of gross loans, at March 31, 2025. Loans 30-89 days delinquent totaled $4.3 million, or 0.39% of gross loans, as of June 30, 2025, compared to $10.0 million, or 0.93% of gross loans, as of March 31, 2025.

    About Landmark

    Landmark Bancorp, Inc., the holding company for Landmark National Bank, is listed on the Nasdaq Global Market under the symbol “LARK.” Headquartered in Manhattan, Kansas, Landmark National Bank is a community banking organization dedicated to providing quality financial and banking services. Landmark National Bank has 29 locations in 23 communities across Kansas: Manhattan (2), Auburn, Dodge City (2), Fort Scott (2), Garden City, Great Bend (2), Hoisington, Iola, Junction City, La Crosse, Lawrence (2), Lenexa, Louisburg, Mound City, Osage City, Osawatomie, Overland Park, Paola, Pittsburg, Prairie Village, Topeka (2), Wamego and Wellsville, Kansas. Visit www.banklandmark.com for more information.

    Contact:
    Mark A. Herpich
    Chief Financial Officer
    (785) 565-2000

    Special Note Concerning Forward-Looking Statements

    This press release may contain forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995 with respect to the financial condition, results of operations, plans, objectives, future performance and business of Landmark. Forward-looking statements, which may be based upon beliefs, expectations and assumptions of our management and on information currently available to management, are generally identifiable by the use of words such as “believe,” “expect,” “anticipate,” “plan,” “intend,” “estimate,” “may,” “will,” “would,” “could,” “should” or other similar expressions. Additionally, all statements in this press release, including forward-looking statements, speak only as of the date they are made, and Landmark undertakes no obligation to update any statement in light of new information or future events. A number of factors, many of which are beyond our ability to control or predict, could cause actual results to differ materially from those in our forward-looking statements. These factors include, among others, the following: (i) the strength of the local, state, national and international economies and financial markets, including the effects of inflationary pressures and future monetary policies of the Federal Reserve in response thereto; (ii) effects on the U.S. economy resulting from the threat or implementation of new, or changes to, existing policies, regulations, regulatory and other governmental agencies and executive orders, including tariffs, immigration policy, regulatory and other governmental agencies, DEI and ESG initiatives, consumer protection, foreign policy and tax regulations; ; (iii) changes in interest rates and prepayment rates of our assets; (iv) increased competition in the financial services sector and the inability to attract new customers, including from non-bank competitors such as credit unions and “fintech” companies; (v) timely development and acceptance of new products and services; (vi) rapid and expensive technological changes implemented by us and other parties in the financial services industry, including third-party vendors, which may be more difficult to implement or more expensive than anticipated or which may have unforeseen consequence to us and our customers, including the development and implementation of tools incorporating artificial intelligence; (vii) our risk management framework; (viii) interruptions in information technology and telecommunications systems and third-party services; (ix) the economic effects of severe weather, natural disasters, widespread disease or pandemics, or other external events; (x) the loss of key executives or employees; (xi) changes in consumer spending; (xii) integration of acquired businesses; (xiii) the commencement, cost and outcome of litigation and other legal proceedings and regulatory actions against us or to which the Company may become subject; (xiv) changes in accounting policies and practices, such as the implementation of the current expected credit losses accounting standard; (xv) the economic impact of past and any future terrorist attacks, acts of war, including ongoing conflicts in the Middle East and the Russian invasion of Ukraine, or threats thereof, and the response of the United States to any such threats and attacks; (xvi) the ability to manage credit risk, forecast loan losses and maintain an adequate allowance for loan losses; (xvii) fluctuations in the value of securities held in our securities portfolio; (xviii) concentrations within our loan portfolio and large loans to certain borrowers (including commercial real estate loans); (xix) the concentration of large deposits from certain clients who have balances above current FDIC insurance limits and may withdraw deposits to diversify their exposure; (xx) the level of non-performing assets on our balance sheets; (xxi) the ability to raise additional capital; (xxii) the occurrence of fraudulent activity, breaches or failures of our or our third-party vendors’ information security controls or cybersecurity-related incidents, including as a result of sophisticated attacks using artificial intelligence and similar tools or as a result of insider fraud; (xxiii) declines in real estate values; (xxiv) the effects of fraud on the part of our employees, customers, vendors or counterparties; (xxv) the Company’s success at managing and responding to the risks involved in the foregoing items; and (xxvi) any other risks described in the “Risk Factors” sections of reports filed by Landmark with the Securities and Exchange Commission. These risks and uncertainties should be considered in evaluating forward-looking statements, and undue reliance should not be placed on such statements. Additional information concerning Landmark and its business, including additional risk factors that could materially affect Landmark’s financial results, is included in our filings with the Securities and Exchange Commission.

    LANDMARK BANCORP, INC. AND SUBSIDIARIES
    Consolidated Balance Sheets (unaudited)

        June 30,     March 31,     December 31,     September 30,     June 30,  
    (Dollars in thousands)   2025     2025     2024     2024     2024  
    Assets                              
    Cash and cash equivalents   $ 25,038     $ 21,881     $ 20,275     $ 21,211     $ 23,889  
    Interest-bearing deposits at other banks     3,463       3,973       4,110       4,363       4,881  
    Investment securities available-for-sale, at fair value:                                        
    U.S. treasury securities     51,624       58,424       64,458       83,753       89,325  
    Municipal obligations, tax exempt     100,802       101,812       107,128       112,126       114,047  
    Municipal obligations, taxable     75,037       70,614       71,715       75,129       74,588  
    Agency mortgage-backed securities     124,979       125,142       129,211       140,004       142,499  
    Total investment securities available-for-sale     352,442       355,992       372,512       411,012       420,459  
    Investment securities held-to-maturity     3,730       3,701       3,672       3,643       3,613  
    Bank stocks, at cost     10,946       6,225       6,618       7,894       9,647  
    Loans:                                        
    One-to-four family residential real estate     377,133       355,632       352,209       344,380       332,090  
    Construction and land     26,373       28,645       25,328       23,454       30,480  
    Commercial real estate     370,455       359,579       345,159       324,016       318,850  
    Commercial     204,303       190,881       192,325       181,652       178,876  
    Agriculture     100,348       101,808       100,562       91,986       84,523  
    Municipal     6,938       7,082       7,091       7,098       6,556  
    Consumer     32,234       31,297       29,679       29,263       29,200  
    Total gross loans     1,117,784       1,074,924       1,052,353       1,001,849       980,575  
    Net deferred loan (fees) costs and loans in process     (615 )     (426 )     (307 )     (63 )     (583 )
    Allowance for credit losses     (13,762 )     (12,802 )     (12,825 )     (11,544 )     (10,903 )
    Loans, net     1,103,407       1,061,696       1,039,221       990,242       969,089  
    Loans held for sale, at fair value     4,773       2,997       3,420       3,250       2,513  
    Bank owned life insurance     39,607       39,329       39,056       39,176       38,826  
    Premises and equipment, net     19,654       19,886       20,220       20,976       20,986  
    Goodwill     32,377       32,377       32,377       32,377       32,377  
    Other intangible assets, net     2,275       2,426       2,578       2,729       2,900  
    Mortgage servicing rights     3,082       3,045       3,061       3,041       2,997  
    Real estate owned, net     167       167       167       428       428  
    Other assets     23,904       24,894       26,855       23,309       28,149  
    Total assets   $ 1,624,865     $ 1,578,589     $ 1,574,142     $ 1,563,651     $ 1,560,754  
                                             
    Liabilities and Stockholders’ Equity                                        
    Liabilities:                                        
    Deposits:                                        
    Non-interest-bearing demand     351,993       368,480       351,595       360,188       360,631  
    Money market and checking     562,919       613,459       636,963       565,629       546,385  
    Savings     148,092       149,223       145,514       145,825       150,996  
    Certificates of deposit     210,897       204,660       194,694       203,860       192,470  
    Total deposits     1,273,901       1,335,822       1,328,766       1,275,502       1,250,482  
    FHLB and other borrowings     155,110       48,767       53,046       92,050       131,330  
    Subordinated debentures     21,651       21,651       21,651       21,651       21,651  
    Repurchase agreements     5,825       6,256       13,808       9,528       8,745  
    Accrued interest and other liabilities     20,002       23,442       20,656       25,229       20,292  
    Total liabilities     1,476,489       1,435,938       1,437,927       1,423,960       1,432,500  
    Stockholders’ equity:                                        
    Common stock     58       58       58       55       55  
    Additional paid-in capital     95,266       95,148       95,051       89,532       89,469  
    Retained earnings     63,612       60,422       56,934       60,549       57,774  
    Treasury stock, at cost                       (396 )     (330 )
    Accumulated other comprehensive loss     (10,560 )     (12,977 )     (15,828 )     (10,049 )     (18,714 )
    Total stockholders’ equity     148,376       142,651       136,215       139,691       128,254  
    Total liabilities and stockholders’ equity   $ 1,624,865     $ 1,578,589     $ 1,574,142     $ 1,563,651     $ 1,560,754  


    LANDMARK BANCORP, INC. AND SUBSIDIARIES

    Consolidated Statements of Earnings (unaudited)

        Three months ended,     Six months ended,  
        June 30,     March 31,     June 30,     June 30,     June 30,  
    (Dollars in thousands, except per share amounts)   2025     2025     2024     2025     2024  
    Interest income:                                        
    Loans   $ 17,186     $ 16,395     $ 15,022     $ 33,581     $ 29,512  
    Investment securities:                                        
    Taxable     2,163       2,180       2,359       4,343       4,787  
    Tax-exempt     701       719       759       1,420       1,523  
    Interest-bearing deposits at banks     48       48       40       96       103  
    Total interest income     20,098       19,342       18,180       39,440       35,925  
    Interest expense:                                        
    Deposits     5,144       5,236       5,673       10,380       11,130  
    FHLB and other borrowings     861       565       1,027       1,426       2,049  
    Subordinated debentures     358       357       418       715       830  
    Repurchase agreements     52       65       88       117       195  
    Total interest expense     6,415       6,223       7,206       12,638       14,204  
    Net interest income     13,683       13,119       10,974       26,802       21,721  
    Provision for credit losses     1,000                   1,000       300  
    Net interest income after provision for credit losses     12,683       13,119       10,974       25,802       21,421  
    Non-interest income:                                        
    Fees and service charges     2,476       2,388       2,691       4,864       5,152  
    Gains on sales of loans, net     740       562       648       1,302       1,160  
    Bank owned life insurance     278       272       248       550       493  
    Losses on sales of investment securities, net           (2 )           (2 )      
    Other     132       138       133       270       315  
    Total non-interest income     3,626       3,358       3,720       6,984       7,120  
    Non-interest expense:                                        
    Compensation and benefits     6,234       6,154       5,504       12,388       11,036  
    Occupancy and equipment     1,244       1,252       1,294       2,496       2,684  
    Data processing     629       396       492       1,025       973  
    Amortization of mortgage servicing rights and other intangibles     238       239       256       477       668  
    Professional fees     540       745       649       1,285       1,296  
    Valuation allowance on real estate held for sale                 979             1,108  
    Other     2,076       1,975       1,921       4,051       3,881  
    Total non-interest expense     10,961       10,761       11,095       21,722       21,646  
    Earnings before income taxes     5,348       5,716       3,599       11,064       6,895  
    Income tax expense     944       1,015       587       1,959       1,105  
    Net earnings   $ 4,404     $ 4,701     $ 3,012     $ 9,105     $ 5,790  
                                             
    Net earnings per share (1)                                        
    Basic   $ 0.76     $ 0.81     $ 0.52     $ 1.58     $ 1.01  
    Diluted     0.75       0.81       0.52       1.56       1.01  
    Dividends per share (1)     0.21       0.21       0.20       0.42       0.40  
    Shares outstanding at end of period (1)     5,783,312       5,778,610       5,743,044       5,783,312       5,743,044  
    Weighted average common shares outstanding – basic (1)     5,782,555       5,777,593       5,745,310       5,780,930       5,744,381  
    Weighted average common shares outstanding – diluted (1)     5,840,923       5,814,650       5,748,053       5,827,844       5,748,332  
                                             
    Tax equivalent net interest income   $ 13,851     $ 13,291     $ 11,167     $ 27,142     $ 22,075  
                                             

    (1) Share and per share values at or for the periods ended June 30, 2024 have been adjusted to give effect to the 5% stock dividend paid during December 2024.


    LANDMARK BANCORP, INC. AND SUBSIDIARIES

    Select Ratios and Other Data (unaudited)

        As of or for the     As of or for the  
        three months ended,     six months ended,  
        June 30,     March 31,     June 30,     June 30,     June 30,  
    (Dollars in thousands, except per share amounts)   2025     2025     2024     2025     2024  
    Performance ratios:                                        
    Return on average assets (1)     1.11 %     1.21 %     0.78 %     1.16 %     0.75 %
    Return on average equity (1)     12.25 %     13.71 %     9.72 %     12.96 %     9.30 %
    Net interest margin (1)(2)     3.83 %     3.76 %     3.21 %     3.80 %     3.16 %
    Effective tax rate     17.7 %     17.8 %     16.3 %     17.7 %     16.0 %
    Efficiency ratio (3)     62.8 %     64.1 %     67.9 %     63.4 %     70.0 %
    Non-interest income to total income (3)     20.9 %     20.4 %     25.3 %     20.7 %     24.7 %
                                             
    Average balances:                                        
    Investment securities   $ 363,878     $ 377,845     $ 437,136     $ 370,823     $ 447,034  
    Loans     1,081,865       1,048,585       955,104       1,065,317       950,420  
    Assets     1,592,939       1,574,295       1,545,816       1,583,669       1,550,739  
    Interest-bearing deposits     965,214       979,787       936,237       972,460       935,827  
    FHLB and other borrowings     74,007       48,428       72,875       61,288       72,747  
    Subordinated debentures     21,651       21,651       21,651       21,651       21,651  
    Repurchase agreements     6,683       8,634       11,524       7,653       12,947  
    Stockholders’ equity   $ 144,151     $ 139,068     $ 124,624     $ 141,623     $ 125,235  
                                             
    Average tax equivalent yield/cost (1):                                        
    Investment securities     3.34 %     3.29 %     3.04 %     3.32 %     2.99 %
    Loans     6.37 %     6.34 %     6.33 %     6.36 %     6.25 %
    Total interest-bearing assets     5.60 %     5.53 %     5.29 %     5.56 %     5.20 %
    Interest-bearing deposits     2.14 %     2.17 %     2.44 %     2.15 %     2.39 %
    FHLB and other borrowings     4.67 %     4.73 %     5.67 %     4.69 %     5.66 %
    Subordinated debentures     6.63 %     6.69 %     7.76 %     6.66 %     7.71 %
    Repurchase agreements     3.12 %     3.05 %     3.07 %     3.08 %     3.03 %
    Total interest-bearing liabilities     2.41 %     2.38 %     2.78 %     2.40 %     2.74 %
                                             
    Capital ratios:                                        
    Equity to total assets     9.13 %     9.04 %     8.22 %                
    Tangible equity to tangible assets (3)     7.15 %     6.99 %     6.09 %                
    Book value per share   $ 25.66     $ 24.69     $ 22.33                  
    Tangible book value per share (3)   $ 19.66     $ 18.66     $ 16.19                  
                                             
    Rollforward of allowance for credit losses (loans):                                        
    Beginning balance   $ 12,802     $ 12,825     $ 10,851     $ 12,825     $ 10,608  
    Charge-offs     (103 )     (108 )     (119 )     (211 )     (260 )
    Recoveries     63       85       171       148       305  
    Provision for credit losses for loans     1,000                   1,000       250  
    Ending balance   $ 13,762     $ 12,802     $ 10,903     $ 13,762     $ 10,903  
                                             
    Allowance for unfunded loan commitments   $ 150     $ 150     $ 300                  
                                             
    Non-performing assets:                                        
    Non-accrual loans   $ 16,984     $ 13,280     $ 5,007                  
    Accruing loans over 90 days past due                                  
    Real estate owned     167       167       428                  
    Total non-performing assets   $ 17,151     $ 13,447     $ 5,435                  
                                             
    Loans 30-89 days delinquent   $ 4,321     $ 9,977     $ 1,872                  
                                             
    Other ratios:                                        
    Loans to deposits     86.62 %     79.48 %     77.50 %                
    Loans 30-89 days delinquent and still accruing to gross loans outstanding     0.39 %     0.93 %     0.19 %                
    Total non-performing loans to gross loans outstanding     1.52 %     1.24 %     0.51 %                
    Total non-performing assets to total assets     1.06 %     0.85 %     0.35 %                
    Allowance for credit losses to gross loans outstanding     1.23 %     1.19 %     1.11 %                
    Allowance for credit losses to total non-performing loans     81.03 %     96.40 %     217.76 %                
    Net loan charge-offs to average loans (1)     0.01 %     0.01 %     -0.02 %     0.01 %     -0.01 %
    (1 ) Information is annualized.
    (2 ) Net interest margin is presented on a fully tax equivalent basis, using a 21% federal tax rate.
    (3 ) Non-GAAP financial measures. See the “Non-GAAP Financial Measures” section of this press release for a reconciliation to the most comparable GAAP equivalent.
         

    LANDMARK BANCORP, INC. AND SUBSIDIARIES
    Non-GAAP Finacials Measures (unaudited)

        As of or for the     As of or for the  
        three months ended,     six months ended,  
        June 30,     March 31,     June 30,     June 30,     June 30,  
    (Dollars in thousands, except per share amounts)   2025     2025     2024     2025     2024  
                                   
    Non-GAAP financial ratio reconciliation:                                        
    Total non-interest expense   $ 10,961     $ 10,761     $ 11,095     $ 21,722     $ 21,646  
    Less: foreclosure and real estate owned expense     49       (50 )     39       (1 )     (11 )
    Less: amortization of other intangibles     (151 )     (152 )     (171 )     (303 )     (341 )
    Less: valuation allowance on real estate held for sale                 (979 )           (1,108 )
    Adjusted non-interest expense (A)     10,859       10,559       9,984       21,418       20,186  
                                             
    Net interest income (B)     13,683       13,119       10,974       26,802       21,721  
                                             
    Non-interest income     3,626       3,358       3,720       6,984       7,120  
    Less: losses on sales of investment securities, net           2             2        
    Less: gains on sales of premises and equipment and foreclosed assets     (9 )                 (9 )     9  
    Adjusted non-interest income (C)   $ 3,617     $ 3,360     $ 3,720     $ 6,977     $ 7,129  
                                             
    Efficiency ratio (A/(B+C))     62.8 %     64.1 %     67.9 %     63.4 %     70.0 %
    Non-interest income to total income (C/(B+C))     20.9 %     20.4 %     25.3 %     20.7 %     24.7 %
                                             
    Total stockholders’ equity   $ 148,376     $ 142,651     $ 128,254                  
    Less: goodwill and other intangible assets     (34,652 )     (34,803 )     (35,277 )                
    Tangible equity (D)   $ 113,724     $ 107,848     $ 92,977                  
                                             
    Total assets   $ 1,624,865     $ 1,578,589     $ 1,560,754                  
    Less: goodwill and other intangible assets     (34,652 )     (34,803 )     (35,277 )                
    Tangible assets (E)   $ 1,590,213     $ 1,543,786     $ 1,525,477                  
                                             
    Tangible equity to tangible assets (D/E)     7.15 %     6.99 %     6.09 %                
                                             
    Shares outstanding at end of period (F)     5,783,312       5,778,610       5,743,044                  
                                             
    Tangible book value per share (D/F)   $ 19.66     $ 18.66     $ 16.19                  

    The MIL Network