Category: Energy

  • MIL-OSI: Equinor second quarter 2025 results

    Source: GlobeNewswire (MIL-OSI)

    Equinor (OSE:EQNR, NYSE:EQNR) delivered an adjusted operating income* of USD 6.53 billion and USD 1.74 billion after tax* in the second quarter of 2025. Equinor reported a net operating income of USD 5.72 billion and a net income of USD 1.32 billion. Adjusted net income* was USD 1.67 billion, leading to adjusted earnings per share* of USD 0.64.

    Solid financial results

    • Strong operational performance and production growth
    • Higher US onshore gas production capturing higher prices
    • Stable cost and capex in line with guidance
    • Balance sheet remains robust through lower price environment

    Strategic progress

    • Delivered key milestones on Johan Castberg, Johan Sverdrup phase 3 and Fram South/Troll
    • Announced divestment of the Peregrino field in Brazil for USD 3.5 billion
    • Financial close of Baltyk 2 & 3 offshore wind projects in Poland
    • Empire Wind 1 project development back in execution. Impairments driven by regulatory changes for future offshore wind projects leading to a loss of future synergies on South Brooklyn Marine Terminal, and increased exposure to tariffs

    Capital distribution

    • Ordinary cash dividend of USD 0.37 per share, third tranche of share buy-back of up to USD 1.265 billion
    • Expected total capital distribution of USD 9 billion in 2025

    Anders Opedal, President and CEO of Equinor ASA:

    “We are on track to deliver production growth in 2025 in line with our guidance. Strong operational performance and Johan Castberg reaching plateau are key contributors this quarter. In today’s volatile markets we stay committed to being a long-term energy provider to Europe.”

    “Last year, we strengthened our onshore gas portfolio in the US and this has created substantial value this quarter, with a fifty percent increase in gas production at prices almost eighty percent higher than the same time last year.“

    “We continue to progress our portfolio in renewables, and the Empire Wind 1 project development is back in execution. We have reached financial close for the Baltyk 2 & 3 offshore wind projects in Poland at favourable terms, contributing to strong returns.”

    Solid production

    Equinor delivered a total equity production of 2,096 mboe per day in the second quarter, up 2% from 2,048 mboe in the same quarter last year.

    On the Norwegian continental shelf the operational performance was strong. New production from the Johan Castberg field reaching plateau and Halten East contributed. Together, this offset natural decline, impact from the turnaround at Hammerfest LNG and maintenance at the Kollsnes processing plant.

    The acquisition of additional interests in US onshore assets in 2024, and higher production from these assets, contributed to a 28% increase in oil and gas production from US in the second quarter, compared to the same period last year.

    The production from the international upstream segment, excluding US, is down compared to the same quarter last year, due to exits from Nigeria and Azerbaijan in 2024. Higher production in Brazil, and new wells in Argentina and Angola, contributed positively.

    The total power generation from the renewable portfolio was 0.83 TWh. The increase compared to second quarter last year is due to ramp up of power production from Dogger Bank A and new production from the onshore wind farm Lyngsåsa in Sweden which was acquired in first quarter 2025.

    In the quarter, Equinor completed 5 offshore exploration wells on the NCS with 2 commercial discoveries.

    Strong financial results

    Equinor delivered an adjusted operating income* of USD 6.53 billion and USD 1.74 billion after tax* in the second quarter of 2025. The results are affected by lower liquids prices, which were partially offset by higher gas prices and higher production.

    The reported net operating income of USD 5.72 billion is down from USD 7.66 billion in the same quarter last year. This is impacted by an impairment of USD 955 million due to regulatory changes causing loss of synergies from future offshore wind projects and increased exposure to tariffs. Of this, USD 763 million is related to Empire Wind 1/South Brooklyn Marine Terminal project and the remainder is related to the Empire Wind 2 lease.

    Equinor realised a European gas price of USD 12.0 per mmbtu and realised liquids prices were USD 63.0 per bbl in the second quarter.

    Adjusted operating and administrative expenses* are stable from the same quarter last year.

    Strong operational performance generated cash flows provided by operating activities, before taxes paid and working capital items, of USD 9.17 billion for the second quarter.

    Equinor paid two NCS tax instalments totalling USD 6.85 billion in the quarter. From August, the payments of tax on the NCS will be changed to ten installments annually, and for third quarter Equinor expects to pay two installments of NOK 19.7 billion each.

    Cash flow from operations after taxes paid* ended at USD 1.94 billion.

    Organic capital expenditure* was USD 3.40 billion for the quarter, and total capital expenditures were USD 3.58 billion.

    The net debt to capital employed adjusted ratio* was 15.2% at the end of the second quarter, compared to 6.9% at the end of the first quarter of 2025. The calculation of net debt ratio includes the effect of the Norwegian state’s share of the share buy-back, at USD 4.26 billion paid in July.

    Strategic progress

    Since the end of the last quarter, Equinor progressed projects to facilitate long-term production and value creation on the Norwegian continental shelf. The plan for development and operation on Fram South was submitted and final investment decision was made on Johan Sverdrup phase 3 in the North Sea which are  expected to increase the recoverable volumes from the field by 40-50 million boe.

    After less than three months in production, the Johan Castberg field in the Barents Sea reached plateau on 17 June. The same month, an oil discovery estimated at approximately 9-15 million barrels was made in the area and can contribute with additional reserves for the field.

    Equinor and Centrica signed a long-term gas sales agreement of 55 TWh of natural gas per year for a period of 10 years, demonstrating the importance of long-term gas supplies from the NCS to support the UK’s energy security.

    Equinor continues to high-grade its international portfolio. In the quarter, the sale of the Peregrino field in Brazil for USD 3.5 billion was announced. Equinor will focus on the start-up of the Bacalhau field expected on stream later in 2025 and progressing the Raia gas project. New exploration acreage in the Santos basin was awarded.

    Financial close was announced on the Baltyk 2 and Baltyk 3 offshore wind projects with financing packages totalling EUR 6 billion. The wind projects are located offshore Poland with an expected total capacity of 1.4 GW.

    Competitive capital distribution

    The board of directors has decided a cash dividend of USD 0.37 per share for the second quarter of 2025, in line with communication at the Capital Markets Update in February.

    Expected total capital distribution for 2025 is USD 9 billion, including a share buy-back programme of up to USD 5 billion. The board has decided to initiate a third tranche of the share buy-back programme of up to USD 1.265 billion. The tranche will commence on 24 July and end no later than 27 October 2025.

    The second tranche of the share buy-back programme for 2025 was completed on 17 July 2025 with a total value of USD 1.265 billion.

    All share buy-back amounts include shares to be redeemed by the Norwegian state.

    – – –

    *For items marked with an asterisk throughout this report, see Use and reconciliation of non-GAAP financial measures in the Supplementary disclosures.

    – – –

    Further information from:

    Investor relations
    Bård Glad Pedersen, Senior vice president Investor relations,
    +47 918 01 791 (mobile)

    Press
    Sissel Rinde, Vice president Media relations,
    +47 412 60 584 (mobile)

    This information is subject to the disclosure requirements pursuant to Section 5-12 of the Norwegian Securities Trading Act

    Attachments

    The MIL Network

  • MIL-OSI: Equinor ASA: Key information relating to cash dividend for the second quarter 2025

    Source: GlobeNewswire (MIL-OSI)

    Key information relating to the cash dividend to be paid by Equinor (OSE: EQNR, NYSE: EQNR) for the second quarter 2025. 

    Cash dividend amount: 0.37

    Announced currency: USD

    Last day including rights: 12 November 2025

    Ex-date Oslo Børs: 13 November 2025

    Ex-date New York Stock Exchange: 14 November 2025

    Record date: 14 November 2025

    Payment date: 26 November 2025

    Date of approval: 22 July 2025

    Other information: The cash dividend per share in NOK will be communicated on 20 November 2025.

    This information is published in accordance with the requirements of the Euronext Oslo Børs Continuing Obligations and is subject to the disclosure requirements pursuant to Section 5-12 in the Norwegian Securities Trading Act. 

    The MIL Network

  • MIL-OSI: Equinor to commence third tranche of the 2025 share buy-back programme

    Source: GlobeNewswire (MIL-OSI)

    Equinor (OSE: EQNR, NYSE: EQNR) will on 24 July 2025 commence the third tranche of up to USD 1,265 million of the share buy-back programme for 2025, as announced in relation with the second quarter results 23 July 2025. 

    In this third tranche of the share buy-back programme for 2025, shares for up to USD 417.5 million will be purchased in the market, implying a total third tranche of up to USD 1,265 million including shares to be redeemed from the Norwegian State. The tranche will end no later than 27 October 2025. 

    Equinor announced at the Capital Market Update in February 2025 a share buy-back programme of up to USD 5 billion for 2025, including shares to be redeemed from the Norwegian State, in order to conclude the two-year programme for 2024 – 2025, announced in February 2024. The share buy-back programme will be subject to market outlook and balance sheet strength and be structured into tranches where Equinor will buy back shares for a certain value in USD over a defined period. For the third tranche in 2025, Equinor will be entering into a non-discretionary agreement with a third party who will execute repurchases of shares and make its trading decisions independently of the company.

    Commencement of new share buy-back tranches after the third tranche in 2025 will be decided by the board of directors on a quarterly basis in line with the company’s dividend policy and will be subject to board authorisation for share buy-back from the company’s annual general meeting and agreement with the Norwegian State regarding share buy-back (as further described below).

    The purpose of the share buy-back programme is to reduce the issued share capital of the company. All shares purchased as part of the third tranche for 2025 will thus be cancelled through a capital reduction at the annual general meeting of the company in May 2026. 

    Further information about the share buy-back programme and the third tranche:

    The third tranche of the share buy-back programme for 2025 is based on an authorisation granted to the board of directors at the annual general meeting of the company held on 14 May 2025. According to the authorisation, the maximum number of shares which can be purchased in the market is 84 million, of which 67,622,812 remain available per commencement of the third tranche in 2025 (buy-backs made under previous tranches in the authorisation period taken into account). The minimum price that can be paid per share is NOK 50, and the maximum price is NOK 1,000. The authorisation is valid until the annual general meeting of the company in May 2026, but no later than 30 June 2026.

    An agreement between Equinor and the Norwegian State regulates the State’s participation in the share buy-back: at the annual general meeting of the company in May 2026, the State will, as per proposal by the board of directors, vote for the cancellation of shares purchased in the market pursuant to the board authorisation, and the redemption and cancellation of a proportionate number of its shares in order to maintain its ownership share in the company at 67%. The price to be paid to the State for redemption of the State’s shares shall be the volume-weighted average of the price paid by Equinor for shares purchased in the market plus an interest rate compensation, adjusted for any dividends paid. 

    In the third tranche in 2025, shares will be purchased on the Oslo Stock Exchange and possibly other trading venues within the EEA. Transactions will be conducted in accordance with applicable safe harbour conditions, and as further set out in the Norwegian Securities Trading Act of 2007, EU Commission Regulation (EC) No 2016/1052 and the Norwegian Financial Supervisory Authority’s Guidelines for buy-back programmes from March 2025. 

    The board of directors will propose to the annual general meeting to be held in May 2026, to cancel shares purchased in the market in this third tranche in 2025 and to redeem and cancel a proportionate number of the State’s shares per the agreement with the State. Any shares purchased under subsequent tranches of the share buy-back programme for 2025, including a proportionate number of the State’s shares will follow a similar process at the annual general meeting of the company in 2026. 

    This is information that Equinor is obliged to make public pursuant to the EU Market Abuse Regulation and that is subject to the disclosure requirements pursuant to Section 5-12 the Norwegian Securities Trading Act.

    Further information from: 

    Investor relations 
    Bård Glad Pedersen, senior vice president Investor Relations, 
    +47 918 01 791 

    Media 
    Sissel Rinde, vice president Media Relations, 
    +47 412 60 584  

    The MIL Network

  • MIL-OSI Russia: China puts major oil field into operation in Bohai Sea

    Translation. Region: Russian Federal

    Source: People’s Republic of China in Russian – People’s Republic of China in Russian –

    An important disclaimer is at the bottom of this article.

    Source: People’s Republic of China – State Council News

    BEIJING, July 23 (Xinhua) — China National Offshore Oil Corp. (CNOOC) said Tuesday it has started production at an oil field in the Bohai Sea, marking a major step in the development of the country’s offshore energy resources.

    The Kenli 10-2 oil field is located in the southern waters of the Bohai Sea. It is the largest lithological field discovered to date in China’s offshore areas, with proven geological reserves of over 100 million tons.

    The first stage of the Kenli 10-2 development project plans to commission 79 production wells with an expected maximum daily flow rate of 3,000 tons of oil and gas equivalent. The second stage of field development will also be implemented here.

    To overcome the technical difficulties caused by the complex composition of heavy oil, CNOOC has established a sophisticated reservoir development technology system specifically designed for heavy oil production.

    “The successful launch of the first phase of the Kenli 10-2 oil field development project marks a new stage in the development of China’s complex offshore heavy oil reservoir,” said Yan Hongtao, deputy general manager of CNOOC, adding that “this is a key step toward achieving our annual production target of 40 million tons in the Bohai Sea within a year.” -0-

    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 USA: Appropriations Committee Approves Chairman Fleischmann’s FY26 Energy and Water Bill

    Source: United States House of Representatives – Congressman Chuck Fleischmann (R-TN)

    Washington, DC – The House Appropriations Committee met to consider the Fiscal Year 2026 Energy and Water Development and Related Agencies Appropriations Act, led by Energy and Water Appropriations Chairman Chuck Fleischmann (TN-03). The bill was approved by the Committee with a vote of 35 to 27. Approval of Rep. Fleischmann’s FY26 Energy and Water Appropriations bill by the Appropriations Committee is a key step before the bill can be brought to the House Floor for a vote.

    Energy and Water Chairman Chuck Fleischmann said, “To achieve America’s new Golden Age, we must safeguard our national security, unleash American energy dominance, and increase economic prosperity for all our citizens. I am proud that, in tight fiscal times where every dollar spent must be scrutinized, the Fiscal Year 2026 Energy and Water Development appropriations bill makes historic investments in our national security and nuclear deterrent, advances American leadership in deploying new nuclear technologies, provides robust funding for waterways infrastructure projects nationwide, reduces our reliance on foreign sources of critical minerals, unleashes American energy production, and stops wasteful, inflationary spending. This bill is the product of close collaboration with the Trump Administration and my colleagues on the Appropriations Committee, and I thank them for their strong support.”

    House Committee on Appropriations Chairman Tom Cole (OK-04) said, “This FY26 Energy and Water bill is focused on lowering energy costs and advancing affordable, reliable, and secure power for the nation. It recognizes that American energy dominance is essential to our economic strength, national security, and global leadership—fueling jobs, innovation, and resilience across every community. Further, we make clear to our adversaries that America will lead with strength built on domestic energy and critical mineral production. We also prioritize essential waterway, flood control, and ports and harbors projects. Chairman Fleischmann’s approach ensures a stronger future reinforced through cutting-edge technology, strategic use of abundant resources, and responsible stewardship of taxpayer dollars, and I commend its full committee approval.”

    Energy and Water Subcommittee Chairman Fleischmann’s opening remarks are available here.
    Chairman Cole’s opening remarks are available here.

    Fiscal Year 2026 Energy and Water Development and Related Agencies Appropriations Bill
    The Energy and Water Development and Related Agencies Appropriations Bill provides a total discretionary allocation of $57.300 billion, which is $766.4 million below the Fiscal Year 2025 enacted level. The defense portion of the allocation is $33.223 billion, and the non-defense portion of the allocation is $24.077 billion.

    The bill prioritizes funding for agencies and programs that safeguard U.S. national security, unleash American energy dominance, and advance economic competitiveness.

    Key Takeaways

    Champions America’s nuclear deterrent and strengthens national security by: 

    • Providing $20.662 billion for the continued modernization of the nuclear weapons stockpile and infrastructure.
    • Providing $2.171 billion to support the U.S. Navy’s nuclear fleet by investing in infrastructure and new technologies to maintain America’s advantage over our adversaries.
    • Providing $1.984 billion to reduce the danger of hostile nations or terrorist groups acquiring nuclear weapons.
    • Prohibiting the sale of crude oil from the Strategic Petroleum Reserve to the Chinese Communist Party.
    • Prohibiting access to U.S. nuclear weapons production facilities by citizens of China and Russia.
    • Prohibiting the Department of Energy from providing financial assistance to any foreign entity of concern.
    • Prohibiting the purchase of technology and telecommunications equipment from China and other adversaries.

    Supports the Trump Administration and mandate of the American people by: 

    • Codifying President Trump’s executive actions by prohibiting funding for Diversity, Equity, and Inclusion and Critical Race Theory programs and ending federal censorship of free speech.
    • Continuing the prohibition on funding for any discriminatory action against individuals advocating for traditional marriage.
    • Allowing for the lawful carry of firearms on Corps of Engineers land.

    Restores American energy dominance and bolsters the national economy by: 

    • Supporting one of the largest investments focused on mining production technologies for critical minerals extraction in decades, reducing reliance on foreign sources.
    • Robustly funding small modular reactor and advanced reactor demonstration projects, as well as increasing funding for the Nuclear Regulatory Commission to expand capacity for the review, licensing, and oversight of new nuclear reactors.
      • These investments are key to regaining international dominance in the nuclear market and achieving the Trump Administration’s goal to expand nuclear energy capacity to 400 gigawatts by 2050.
    • Facilitating the efficient transport of goods and commodities through improvements and maintenance of America’s ports and waterways.
    • Increasing investments to develop new baseload geothermal energy sources to capitalize on our vast domestic resources.
    • Maintaining funding for cybersecurity efforts that enable a resilient, reliable, and secure electric grid.

    Safeguards American taxpayer dollars and preserves core functions by: 

    • Eliminating the Biden-era Office of Clean Energy Demonstrations.
    • Including no funds for the Department of Energy Office of Energy Justice and Equity.
    • Refocusing applied energy technology program funding to ensure taxpayer resources are directed to the highest priority research and development efforts.
    • Reducing global dependency on the U.S. for foreign nuclear reactor conversions.

    During the markup, Committee Republicans also stood with the America First agenda and rejected Democrat amendments that would have: 

    • Restricted the implementation of the America First agenda.
    • Repealed reconciliation efforts that reformed green new scam climate initiatives.
    • Sought to hamper enforcement efforts at Alligator Alcatraz.
    • Promoted and advanced critical race theory.
    • Allowed unapproved flags to be flown over federal facilities.
    • Funded polarizing diversity, equity, and inclusion (DEI) initiatives.
    • Exposed Americans to religious discrimination.
    • Prohibited the implementation of certain President Trump executive orders.
    • Increased taxpayer spending to unnecessary levels for certain programs.

    Adopted Amendments 

    • Fleischmann #1 (Manager’s Amendment) Makes technical, bipartisan changes to the bill and report.
      • The amendment was adopted by voice vote.
    • Clyde #1 – Addresses the collection and utilization of recreation fees.
      • The amendment was adopted by voice vote.
    • Moore #2 – Increases funding for Regional Commissions.
      • The amendment was adopted by voice vote. 

    Bill text, before adoption of amendments, is available here.
    Bill report, before adoption of amendments, is available here.
    A table of included Community Project Funding requests is available here.

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    MIL OSI USA News

  • MIL-OSI USA: Schakowsky, Jayapal, Raskin, Senate Colleagues Fight for Children’s Fundamental Right to a Healthy, Livable Planet

    Source: United States House of Representatives – Congresswoman Jan Schakowsky (9th District of Illinois)

    Full Text of Resolution (PDF)

    WASHINGTON – Today, U.S. Representatives Jan Schakowsky (IL-09), Pramila Jayapal (WA-07), and Jamie Raskin (MD-08) led over 40 Representatives in the introduction of a new resolution to protect the fundamental rights of the nation’s children to a safe, habitable environment in the face of climate chaos’ increasingly destructive and deadly impacts.

    “There is no room for debate: climate change is real, and as this crisis grows, our kids are increasingly paying the price. The movement to protect our planet is more important than ever before because we have a president who continues to ignore the science and cozy up to the fossil fuel industry,” said Congresswoman Jan Schakowsky. “I am introducing the Children’s Fundamental Rights to Life and a Stable Climate System Resolution to emphasize that we as leaders have a duty to ensure that all people, especially our young people, are protected from the existential threat of climate change. Our children and grandchildren should not be forced to suffer the consequences of our lack of action. Together we can save our planet.”

    “Every single one of us — no matter our age, our background, our race, our income — has the right to life, liberty, and the pursuit of happiness. But those rights are in jeopardy, because the future of our planet is in jeopardy. I applaud the young people who are taking their futures into their own hands and standing up to the Trump administration’s efforts to sell out our clean air and water to the highest fossil fuel bidder. Inaction is not an option and we all must stand up for climate justice and a future where we can all thrive,” said Congresswoman Pramila Jayapal.

    “Children have a right to live and therefore a right to a livable planet,” said Congressman Jamie Raskin. “But the Trump Administration wants to carve out more giveaways to the Carbon Kings rather than protect the climate for children and future generations of Americans. Our Resolution with Representatives Jayapal and Schakowsky and Senator Merkley is about uplifting the voices of those who will be most affected by this climate irresponsibility and corruption—young people and children—and sounding the alarm on America’s accelerating climate disaster. The time to act for public accountability is right now. I salute everyone involved in this important campaign.”

    The resolution — led in the U.S. Senate by Sen. Jeff Merkley (D-OR) — responds to the Trump Administration’s ‘Polluters over People’ agenda that has enriched Big Oil, fueled climate chaos, and increased energy costs for working families. The resolution calls for leadership to put the United States on a trajectory to avoid the worst impacts of climate chaos.   

    “Every child in America deserves a healthy and prosperous future, but the Trump Administration is selling out our health, safety, planet, and future to make billionaire corporate polluters even richer,” said Senator Jeff Merkley. “We stand with these courageous young activists in Oregon and across the country who are taking matters into their own hands with immediate and decisive steps to fight for themselves and future generations, address climate chaos, and tackle environmental injustice.”

    The resolution highlights the principles underpinning Lighthiser v. Trump, a youth-led lawsuit that was filed by 22 young plaintiffs from five states, challenging the Trump Administration’s Executive Orders that “unleash fossil fuels” and endanger the lives of children and future generations.

    In addition to Reps. Schakowsky, Jayapal, and Raskin, cosponsors of the resolution include Reps. Rashida Tlaib, Summer L. Lee, Shri Thanedar, Delia C. Ramirez, Yassamin Ansari, Eleanor Holmes Norton, Andre Carson, Nydia M. Velázquez, Nanette Barragán, Alexandria Ocasio-Cortez, Dina Titus, Maxwell Frost, Bonnie Watson Coleman, Steve Cohen, Mary Gay Scanlon, Lateefah Simon, Jerrold Nadler, Kathy Castor, Kevin Mullin, Danny Davis, Julia Brownley, Dave Min, Sara Jacobs, Judy Chu, Maxine Dexter, David Scott, Mark Takano, Gabe Amo, Jared Huffman, Sydney Kamlager-Dove, Valerie Foushee, Becca Balint, Henry C. “Hank” Johnson, Jr., Ro Khanna, Alma S. Adams, Ritchie Torres, James P. McGovern, Jill Tokuda, Darren Soto, Stephen F. Lynch, LaMonica McIver, Val Hoyle, and Jahana Hayes.

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    MIL OSI USA News

  • MIL-OSI USA: Schakowsky, Fletcher, Matsui, Pressley Introduce Safer Beauty Bill Package

    Source: United States House of Representatives – Congresswoman Jan Schakowsky (9th District of Illinois)

    WASHINGTON – U.S. Representative Jan Schakowsky (IL-09), Ranking Member of the Commerce, Manufacturing, and Trade Subcommittee of the House Energy and Commerce Committee, on Wednesday reintroduced the Safer Beauty Bill Package with her colleagues, Reps. Lizzie Fletcher (TX-07), Doris Matsui (CA-07), and Ayanna Pressley (MA-07). The bill package includes four separate bills that offer progressive updates to an increasingly outdated set of federal cosmetics laws. This package builds upon the Modernization of Cosmetics Regulation Act (MoCRA), which passed under President Joe Biden and expanded FDA oversight to include the regulation of the cosmetics industry, including mandatory recall authority, adverse event reporting, and requiring facility registration, and more.

    “Safe, accessible beauty cannot wait. After more than 80 years of inaction, the United States finally updated its cosmetics laws in 2022. President Biden was able to sign into law the Modernization of Cosmetics Regulation Act, which now gives authority to the Food and Drug Administration to recall beauty and personal care products that are harming human health. While this was an important first step, our work is not done,” said Congresswoman Jan Schakowsky. “I am proud to reintroduce the Safer Beauty Bill Package with my colleagues, Reps. Lizzie Fletcher, Doris Matsui, and Ayanna Pressley, which would protect consumers from toxic chemicals linked to hormone disruption, cancer and other health problems; require full ingredient transparency for consumers and manufacturers; and protect the health of women of color and salon workers, who are among the most highly exposed to toxic chemicals because of the products marketed to them or commonly found in their workplaces. We must pass the Safer Beauty Bill Package now!”

    “Many people assume that the personal care and beauty items they use are safe, but with minimal oversight, many of the care, beauty, and salon products sold across the country actually contain toxic chemicals,” said Congresswoman Lizzie Fletcher.  “I am glad to partner with Congresswoman Schakowsky to reintroduce the Toxic-Free Beauty Act to protect the health and safety of people across the country by banning chemicals known to cause significant harm in beauty products.”

    “Americans deserve the comfort of knowing the products they use every day are safe and properly labeled,” said Congresswoman Doris Matsui. “That’s why I am proud to join Congresswoman Schakowsky in announcing the Cosmetic Hazardous Ingredient Right to Know Act, which will introduce much needed transparency and accountability to the cosmetics industry. This is a commonsense step toward protecting consumers and our public health. Whether it’s a parent buying shampoo for their child or a professional exposed to dozens of products daily, every person should have clear, honest information about what they’re putting on their bodies.” 

    “For decades, the beauty products marketed to Black women and girls and found in our salons have contained toxic, unregulated chemicals – leaving us to disproportionately suffer from increased incidences of cancer, respiratory issues, and adverse reproductive outcomes,” said Congresswoman Ayanna Pressley. “This isn’t a coincidence – this is exploitation. Black women, girls, and salon workers should be able to show up everyday as our beautiful, authentic selves, without fear for our health and safety. It’s past time that we regulate these hazardous products and affirm our right to safer alternatives, and I am proud to co-lead the Cosmetic Safety Protections for Communities of Color and Salon Workers Act and partner with my colleagues and dedicated advocates on the Safer Beauty Bill Package to do exactly that.”

    The four bills cover almost every aspect of personal care product safety. They are:  

    • H.R. 4433 – The Toxic-Free Beauty Act (Reps. Schakowsky and Fletcher): Bans 18 of the most toxic chemicals and two whole classes of chemicals (phthalates and formaldehyde releasing preservatives) that have been banned by the European Union and a number of states including California, Maryland, Oregon, Washington, and Vermont.
    • H.R. 4434 – Cosmetic Supply Chain Transparency Act (Rep. Schakowsky): Requires suppliers of raw materials, ingredients, and private label products to provide full ingredient disclosure and safety data to cosmetic companies so they can make safer products.
    • H.R. 4435 – Cosmetic Hazardous Ingredient Right to Know Act (Reps. Schakowsky and Matsui): Requires product label and website disclosure of secret, unlabeled, and often toxic chemicals in our personal care products. Last Congress, this bill only required transparency for fragrance and flavor ingredients and has been expanded to cover all ingredients that can pose a health risk to consumers.
    • H.R. 4436 – Cosmetic Safety Protections for Communities of Color and Salon Workers (Reps. Schakowsky and Pressley): Funds research, resource materials, education and outreach, and the development of safer chemicals to protect the health of women of color and salon workers, two vulnerable populations who are among the most highly exposed to toxic chemicals because of the cosmetic products marketed to them or commonly found in their workplaces. This bill also requires the FDA to regulate the safety of synthetic braids, which can contain toxic chemicals.

    The average American adult uses about 12 personal care products a day, resulting in exposure to an average of 168 unique chemicals. Children are also exposed to products containing risky chemicals during critical stages of childhood development. As these products range from toothpaste to makeup, it is easy for companies to conceal harmful chemicals that risk American livelihoods. Chemicals in beauty and personal care products have been linked to cancer, infertility, poor infant and maternal health outcomes, asthma, and many other serious health concerns. Women of color are disproportionately exposed to these harmful chemicals due to workplace conditions.

    Joining Reps. Schakowsky, Fletcher, Matsui, and Pressley as original cosponsors of the Safer Beauty Bill Package are Reps. Dingell, Khanna, Norton, and Tlaib. 

    The bill has been endorsed by a coalition of over 150 organizations and safe cosmetics companies. Find a full list of endorsements here.

    “Thank you, Rep. Schakowsky, for your steadfast advocacy on behalf of cosmetic safety and for introducing the 2025 Safer Beauty Bill Package which will protect everyone regardless of where they live, shop or work” said Janet Nudelman, Director of Breast Cancer Prevention Partner’s Campaign for Safe Cosmetics. “This important suite of bills will match the new high bar for ingredient safety set by laws recently enacted in CA, MD, OR, WA, VT, and NY; create long overdue protections for women of color and professional salon workers; and set a new industry standard for ingredient and supply chain transparency.”

    For over a decade, Congresswoman Schakowsky has fought tirelessly to pass a robust regulatory framework for cosmetics and personal care products. The efforts focus on closing major loopholes in federal law that allow companies to use nearly any ingredient in these products, even chemicals that are known to harm human health and the environment like coal tar dyes, formaldehyde, lead acetate, parabens, and phthalates.

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    MIL OSI USA News

  • MIL-OSI USA: MATSUI CONDEMNS REPUBLICAN CUTS TO PUBLIC MEDIA

    Source: United States House of Representatives – Congresswoman Doris Matsui (D-CA)

    WASHINGTON, D.C. – Today, Congresswoman Doris Matsui (CA-07), Ranking Member of the House Energy and Commerce Subcommittee on Communications and Technology, released the following statement in response toRepublicans passing the Trump administration’s $9 billion rescission package, including clawing back $1.1 billion in funding for public radio and television.

    “By ripping away funding for local radio and television stations, Republicans are jeopardizing Americans’ ability to access free, community-supported access to news, educational programming, and lifesaving emergency alerts,” said Congresswoman Matsui. “This is an attack on the over 1500 local stations nationwide—and the millions of Americans who rely on them—all to satisfy President Trump’s obsession with silencing dissenting voices and bullying our press into becoming his personal mouthpiece. Stations, especially those serving our most rural and remote communities, will be forced to cut back on programming, lay off staff, and even go off air.”

    “I will keep fighting against President Trump’s deliberate and dangerous assault on our free press,” Matsui continued. “Congress must fully restore funding to public media and protect it from political interference. We must stand up for Americans’ ability to access no-cost, trusted educational resources, nonpartisan journalism, and public safety content that connect the local communities they serve.”

    The Public Broadcasting Act of 1967 established the Corporation for Public Broadcasting (CPB) as a private, non-profit corporation to provide non-commercial educational programming to the public. For 50 years, Congress has provided advance appropriations for CPB to protect public media from political interference and provide the essential lead time to plan and develop high-quality programming. CPB provides grants to 1,216 public radio stations and 365 public television stations across the country, to provide nearly 99 percent of the U.S. population with free programming and services.

    Congresswoman Matsui has actively pushed back against the Trump administration’s attacks on a free and independent press. In March, Congresswoman Matsui introduced the Broadcast Freedom and Independence Act, legislation that would prohibit the Federal Communications Commission (FCC) from revoking broadcast licenses or taking action against broadcasters based on the viewpoints they disseminate. The legislation would reaffirm the importance of the independence of the FCC, including that the President should not mandate the FCC’s agenda.

    That same month, Congresswoman Matsui, along with Congressman Frank Pallone (NJ-06), Ranking Member of the House Energy and Commerce Committee, and Congresswoman Yvette Clarke (NY-09), Ranking Member of the Subcommittee on Oversight and Investigations Subcommittee, opened a probe into the Trump FCC’s sham investigations into media outlets. Congresswoman Matsui also led a bipartisan letter emphasizing the importance of federal funding for public radio and television.

    # # #

    MIL OSI USA News

  • MIL-OSI USA: MATSUI AND COLLEAGUES SLAM REVISED GUIDANCE FOR BROADBAND, EQUITY, ACCESS, AND DEPLOYMENT PROGRAM

    Source: United States House of Representatives – Congresswoman Doris Matsui (D-CA)

    WASHINGTON D.C. – Today, Congresswoman Doris Matsui (CA-07), Ranking Member of the House Energy and Commerce Subcommittee on Communications and Technology, led a group of 22 lawmakers in a letter to U.S. Department of Commerce (DOC) Secretary Howard Lutnick, expressing deep concerns regarding the recent restructuring of the Broadband Equity, Access, and Deployment (BEAD) Program. 

    The BEAD Program provides $42.45 billion to expand high-speed internet access by funding planning, infrastructure deployment, and adoption programs in all 50 states. Over 40 states and territories, including California, had partially or fully completed the process of selecting projects for deployment. But last month, DOC released new guidelines through their BEAD Restructuring Policy Notice (BPRN) that threatens to derail progress. The notice would force states to reopen the application process and rescind preliminary and provisional awards—substantially delaying efforts to get shovels in the ground and broadband to the communities that need it most.

      

    “Despite your stated goals of removing burdensome requirements from the BEAD Program and ensuring American taxpayers receive the ‘benefit of the bargain,’ the BRPN actually further complicates and delays the program for all stakeholders, violating congressional intent” wrote the lawmakers. “Worst of all, American families and businesses will be left with inferior connectivity.”

    The new guidelines impose burdensome scoring requirements that would hamstring states’ flexibility to choose the most effective mix of technologies to deliver reliable, scalable, and future-proof internet service.  On top of that, the Trump administration’s changes would gut key safeguards—slashing protections for affordability, good-paying jobs, climate-resilient infrastructure, and a free and open internet. These changes will drive up costs for consumers while driving down the quality of service.

    “The BEAD Program you inherited on January 20, 2025, was on track to get shovels in the ground months ago to deliver reliable, high-speed internet to communities on the wrong side of the digital divide. Nothing about the BRPN simplifies the BEAD Program for state broadband offices or providers, and the changes you insist upon will only lead to indefinite delays and worse internet service for Americans,” the lawmakers continued. 

    The full letter is available HERE

    # # #

    MIL OSI USA News

  • MIL-OSI USA: House Passes Four Amo Amendments to Strengthen Rhode Island’s Defense Workforce and Blue Economy

    Source: US Congressman Gabe Amo (Rhode Island 1st District)

    Amo amendments bolstering Rhode Island’s cutting-edge defense innovation and our nation’s readiness included in the Department of Defense Appropriations Act passed through the House.

    WASHINGTON, DC – TODAY, House Foreign Affairs Committee Vice Ranking Member Gabe Amo (D-RI) authored four amendments that passed the House as part of the Fiscal Year 2026 Department of Defense Appropriations Act. The amendments support and encourage Rhode Island’s premier defense manufacturers like VATN Systems in Portsmouth, Composite Energy Technologies in Bristol, Textron Inc. in Providence, and G-Form in North Smithfield — national leaders in developing underwater drones for the United States Navy.

    “Rhode Island is leading our nation in developing cutting-edge technology that should be utilized to strengthen and modernize the U.S. military,” said Congressman Gabe Amo (D-RI). “The amendments I pushed for that were included in this year’s Defense Department appropriations bill will support good paying jobs at home in Rhode Island while advancing our national security.”

     

    Background

    Ranking Member Amo’s first amendment provides $10 million in funding for testing and adoption across the U.S. Navy fleet of underwater drone battery technology developed in RI.

    Amo’s second amendment provides $8 million in funding to develop underwater drones utilizing cutting edge composite materials technology developed by companies like Composite Energy Technologies in Bristol, RI.   

    The third amendment authored by Amo provides $10 million to upgrade the fuel tanks of military helicopters to increase servicemember safety and maintenance affordability while providing good-paying jobs in Rhode Island. 

    Amo’s fourth amendment provides $5 million in improvements to the safety and functionality of servicemembers helmets in extremely cold conditions using state of the art materials like those developed by G-Form in North Smithfield, RI.

    ###

    MIL OSI USA News

  • MIL-OSI USA: Kennedy applauds USDOT lease agreement for National Center of Excellence for LNG Safety in Lake Charles

    US Senate News:

    Source: United States Senator John Kennedy (Louisiana)

    WASHINGTON – Senator John Kennedy (R-La.), a member of the Senate Appropriations Committee, issued the following statement applauding the U.S. Department of Transportation’s Pipeline and Hazardous Materials Safety Administration (PHMSA) for entering into a 20-year lease agreement with McNeese State University in Lake Charles, La., the location of the PHMSA National Center of Excellence for Liquefied Natural Gas (LNG) Safety (the Center). McNeese was chosen as the Center’s site earlier this year. The lease will start on August 1, 2025.

    “LNG production is one of the most critical ways our nation can unleash our energy dominance and protect our national security, and Louisiana is leading the way. I’m proud to see the U.S. Department of Transportation take this major step forward in building our National Center of Excellence for LNG Safety in Lake Charles. This Center will be a game changer for our region and be the tip of the spear for LNG innovation, operations, and safety in the U.S.,” said Kennedy. 

    “Louisiana is at the heart of America’s growing LNG revolution. There is no better place to locate our Center of Excellence to ensure we safely transport this critical energy source,” said U.S. Transportation Secretary Sean P. Duffy.

    The Protecting our Infrastructure of Pipelines and Enhancing Safety (PIPES) Act of 2020 required PHMSA to establish that the National Center of Excellence for LNG Safety improve the federal government’s LNG facility expertise, serve as an information repository on best practices for LNG facilities, and facilitate collaboration among LNG stakeholders. 

    “We are excited to reach another important milestone in the construction of the Center, which will be a hub for advancing U.S. LNG safety,” said PHMSA Acting Administrator Ben Kochman. 

    “We are thrilled to finalize the long-term lease with PHMSA for a location on our McNeese campus. This project has been in the works for over two years, and it would not have been possible without the tireless efforts of Senator Kennedy and his staff, our partners in Washington, D.C., and our colleagues at the University of Louisiana. We believe having PHMSA right here in Lake Charles—working alongside us—will serve as a powerful catalyst for securing the future of our region’s vital industries,” said Dr. Wade Rousse, President, McNeese State University.

    Kennedy has long fought for the National Center of Excellence for LNG Safety and its presence in southwest Louisiana.

    • In 2020, Kennedy inserted a provision into the PIPES Act requiring the Center to be located in Louisiana. The PIPES Act, including Kennedy’s addition, became law as part of the Consolidated Appropriations Act of 2021.
    • In May 2024, Kennedy questioned then-Secretary of Transportation Pete Buttigieg during the Senate Appropriations Subcommittee on Transportation, Housing and Urban Development and Related Agencies (THUD Appropriations). In response to Kennedy’s questions, Buttigieg confirmed that the Center would be located in Lake Charles, La.
    • During a May 2025 THUD Appropriations hearing, Kennedy questioned Secretary Duffy and confirmed that McNeese State University would be the site of the new Center. McNeese State University is the first undergraduate institution in the U.S. to offer a certificate program in the LNG Business and already hosts its own LNG Center of Excellence.

    PHMSA and other federal agencies, including the U.S. Coast Guard, Department of Energy, and Federal Energy Regulatory Commission, have worked together to ensure the Center is focused on its mission of making the U.S. the leader in LNG operations. 

    Additional information about the National Center of Excellence for LNG Safety is available on PHMSA’s website.

    MIL OSI USA News

  • MIL-OSI USA: Congressman Russell Fry (SC-07) Introduces Legislation to Codify President Trump’s Executive Order on Showerheads

    Source:

    Congressman Russell Fry (SC-07) Introduces Legislation to Codify President Trump’s Executive Order on Showerheads

    WASHINGTON, D.C. – Today, Congressman Russell Fry (SC-07) introduced the Saving Homeowners from Overregulation With Exceptional Rinsing (SHOWER) Act, a bill to codify President Trump’s clear and consistent definition of “showerhead” and put an end to the federal government’s overregulation of household water fixtures.

    Under the 2016 Trump Administration, the Department of Energy (DOE) rightly clarified that each nozzle in a multi-head shower system could be treated as a separate showerhead, each allowed to flow at up to 2.5 gallons per minute (GPM), consistent with the original intent of the 1992 Energy Policy Act.

    But in 2021, the Biden Administration reversed course, reinstating a burdensome interpretation that limited the combined flow of all nozzles in a system to 2.5 GPM—effectively reducing water pressure and restricting consumer choice. That rule was widely criticized as overreach and emblematic of a broader regulatory agenda targeting everyday household appliances.

    President Trump issued an Executive Order in April of 2025 directing DOE to eliminate the Biden-era rule, and DOE followed through in May by repealing the restrictive definition entirely. The SHOWER Act now ensures this rollback is enshrined in law and cannot be reversed by future administrations.

    Specifically, the bill:

    • Codifies the definition of “showerhead” using the ASME A112.18.1–2018 industry standard.

    • Clarifies that each individual nozzle in a multi-nozzle unit may operate independently at up to 2.5 GPM.

    • Excludes safety showerheads used for emergency purposes.

    • Directs the DOE to revise existing regulations within 180 days to reflect the updated statutory definition.

    • Prevents future reinterpretations that would restrict water flow and limit consumer options.

    Washington bureaucrats have gone too far in dictating what happens in Americans’ own homes,” said Congressman Fry. “The SHOWER Act is a smart fix that reaffirms each shower nozzle is just that—its own showerhead—and should be treated accordingly under the law. This is about defending consumer choice, pushing back on regulatory overreach, and standing up for commonsense policy.”

    For far too long federal regulations and red tape have limited consumer choice and forced Americans to live with limited water pressure,” said Chairman Guthrie. “Low pressure showers waste time and increase water usage. By codifying how different nozzles are categorized, the SHOWER Act offers a commonsense fix that will allow households to choose what meets their needs, not what Washington mandates.  Thank you to Representative Fry for leading this legislation and for your work to deliver results for consumers across the country.” 

    Full text of the bill can be found HERE.

    Congressman Fry serves on both the House Energy and Commerce Committee and the House Judiciary Committee. To stay up to date with Congressman Fry and his work for the Seventh District, follow his official Facebook, Instagram, and X pages and visit his website at fry.house.gov.

    MIL OSI USA News

  • MIL-OSI: Pulse Seismic Inc. Reports Strong Q2 2025 Financial Results and Declares Special and Regular Quarterly Dividends

    Source: GlobeNewswire (MIL-OSI)

    CALGARY, Alberta, July 22, 2025 (GLOBE NEWSWIRE) — Pulse Seismic Inc. (TSX:PSD) (OTCQX:PLSDF) (“Pulse” or the “Company”) is pleased to report its financial and operating results for the three and six months ended June 30, 2025. The unaudited condensed consolidated interim financial statements, accompanying notes and MD&A are being filed on SEDAR+ (www.sedarplus.ca) and will be available on Pulse’s website at www.pulseseismic.com.

    Today, Pulse’s Board of Directors declared a regular quarterly dividend of $0.0175 per common share and also declared a special dividend of $0.20 per common share. The total dividend declared will be approximately $11.0 million based on Pulse’s 50,755,057 common shares outstanding as of July 22, 2025, to be paid on August 20, 2025, to shareholders of record on August 13, 2025. This dividend is designated as an eligible dividend for Canadian income tax purposes. For non-resident shareholders, Pulse’s dividends are subject to Canadian withholding tax.

    “In the first half of 2025 the Company has benefited from increases in traditional data sales as well as energy sector M&A, generating revenue of $41.1 million, an EBITDA margin of 86% and $27.2 million of shareholder free cashflow,” stated Neal Coleman, Pulse’s President and CEO. “Pulse’s industry leading seismic data library contains vital subsurface information used by E&P companies for risk mitigation and maximization of drilling results,” he continued. “The Company continues to rely on shareholder free cashflow as the basis for its capital allocation strategy and remains focused on returns to shareholders, as evidenced by distributing 84% of 2025 free cash flow in the form of dividends. Pulse’s Board of Directors today declared the second special dividend of 2025,” Coleman continued. “In the last 24 months, special dividends of $0.80 have been declared, in addition to the regular dividend which has increased annually and is currently set at $0.07 per year,” he concluded.

    HIGHLIGHTS FOR THE THREE AND SIX MONTHS ENDED JUNE 30, 2025

    • The regular quarterly dividend of $0.0175 per common share declared and paid in the second quarter of 2025 was a 17% increase over the regular quarterly dividend of $0.015 per common share declared and paid in the first quarter of 2025. A special dividend of $0.20 per common share totaling $10.2 million was also declared and paid in the first quarter of 2025;
    • The Company renewed its Normal Course Issuer Bid (NCIB) on February 24, 2025. During the six months ended June 30, 2025, the Company purchased and cancelled 80,600 shares under the NCIB at an average price of $2.43 per share, for total cost of approximately $197,000;
    • Total revenue for the three months ended June 30, 2025, was $18.3 million, compared to $6.3 million for the same period in 2024. Total revenue for the six months ended June 30, 2025, was $41.1 million, compared to $15.1 million for the same period in 2024. Revenue generated in the first half of 2025 reflects an increase of 71% compared to the last three years average of annual revenue;
    • Shareholder free cash flow(a) was $11.7 million ($0.23 per share basic and diluted) for the three months ended June 30, 2025, compared to $3.9 million ($0.07 per share basic and diluted) for the same period in 2024. Shareholder free cash flow was $27.2 million ($0.53 per share basic and diluted) for the six months ended June 30, 2025, compared to $8.9 million ($0.17 per share basic and diluted) for the same period in 2024;
    • EBITDA(a) was $15.2 million ($0.30 per share basic and diluted) for the three months ended June 30, 2025, compared to $4.4 million ($0.0.09 per share basic and diluted) for the same period in 2024. For the six months ended June 30, 2025, EBITDA was $35.3 million ($0.69 per share basic and diluted) compared to $10.6 million ($0.21 per share basic and diluted) for the same period in 2024;
    • Net earnings for the three months ended June 30, 2025, was $9.6 million ($0.19 per share basic and diluted) compared to net earnings of $1.3 million ($0.03 per share basic and diluted) for the same period in 2024. Net earnings for the six months ended June 30, 2025, was $22.9 million ($0.45 per share basic and diluted) compared to net earnings of $4.0 million ($0.08 per share basic and diluted) for the same period in 2024; and
    • At June 30, 2025, the Company had a cash balance of $25.9 million as well as $5.0 million of available liquidity on its revolving demand credit facility.
    SELECTED FINANCIAL AND
    OPERATING INFORMATION
             
               
               
    (Thousands of dollars except per share data, Three months ended June 30, Six months ended June 30, Year ended,
    numbers of shares and kilometres of seismic data) 2025 2024   2025 2024 December 31,
      (Unaudited) (Unaudited) 2024
    Revenue 18,316 6,300   41,075 15,077 23,379
               
    Amortization of seismic data library 2,224 2,279   4,449 4,549 9,090
    Net earnings 9,565 1,341   22,940 4,022 3,391
    Per share basic and diluted 0.19 0.03   0.45 0.08 0.07
    Cash provided by (used in) operating activities 12,543 (1,269 ) 29,158 9,195 14,195
    Per share basic and diluted 0.25 (0.02 ) 0.57 0.18 0.28
    EBITDA (a) 15,238 4,418   35,286 10,647 15,496
    Per share basic and diluted (a) 0.30 0.09   0.69 0.21 0.30
    Shareholder free cash flow (a) 11,733 3,869   27,152 8,907 12,408
    Per share basic and diluted (a) 0.23 0.07   0.53 0.17 0.24
               
    Capital expenditures          
    Seismic data   225 225
    Property and equipment   45
    Total capital expenditures   225 270
               
    Dividends          
    Regular dividends declared 885 775   1,648 1,490 3,018
    Special dividends declared   10,167 2,548
    Total dividends declared 885 775   11,815 1,490 5,566
               
    Normal course issuer bid          
    Number of shares purchased and cancelled 37,300 539,500   80,600 1,166,800 1,784,000
    Cost of shares purchased and cancelled 91 1,222   197 2,407 3,880
               
    Weighted average shares outstanding          
    Basic and diluted 50,761,321 51,734,590   50,795,174 51,928,298 51,448,985
    Shares outstanding at period-end     50,755,057 51,455,063 50,837,863
               
    Seismic library          
    2D in kilometres     829,207 829,207 829,207
    3D in square kilometres     65,310 65,310 65,310
    FINANCIAL POSITION
    AND RATIO
             
          June 30, June 30, December 31,
    (Thousands of dollars except ratio)     2025 2024 2024
    Working capital     24,202 10,996 9,222
    Working capital ratio     4.8:1 4.0:1 5.1:1
    Cash and cash equivalents     25,876 9,392 8,722
    Total assets     36,479 29,184 21,516
    Trailing 12 -month (TTM) EBITDA(b)     40,135 27,528 15,496
    Shareholders’ equity     29,177 25,177 18,295
               

    (a)The Company’s continuous disclosure documents provide discussion and analysis of “EBITDA”, “EBITDA per share”, “shareholder free cash flow” and “shareholder free cash flow per share”. These financial measures do not have standard definitions prescribed by IFRS and, therefore, may not be comparable to similar measures disclosed by other companies. The Company has included these non-GAAP financial measures because management, investors, analysts and others use them as measures of the Company’s financial performance. The Company’s definition of EBITDA is cash available for interest payments, cash taxes, repayment of debt, purchase of its shares, discretionary capital expenditures and the payment of dividends, and is calculated as earnings (loss) from operations before interest, taxes, depreciation and amortization. The Company believes EBITDA assists investors in comparing Pulse’s results on a consistent basis without regard to non-cash items, such as depreciation and amortization, which can vary significantly depending on accounting methods or non-operating factors such as historical cost. EBITDA per share is defined as EBITDA divided by the weighted average number of shares outstanding for the period. Shareholder free cash flow further refines the calculation of capital available to invest in growing the Company’s 2D and 3D seismic data library, to repay debt, to purchase its common shares and to pay dividends by deducting non-discretionary expenditures from EBITDA. Non-discretionary expenditures are defined as non-cash expenses, debt financing costs (net of deferred financing expenses amortized in the current period), net restructuring costs and current tax provisions. Shareholder free cash flow per share is defined as shareholder free cash flow divided by the weighted average number of shares outstanding for the period.
    These non-GAAP financial measures are defined, calculated and reconciled to the nearest GAAP financial measures in the Management’s Discussion and Analysis.
    (b) TTM EBITDA is defined as the sum of EBITDA generated over the previous 12 months and is used to provide a comparable annualized measure.
    These non-GAAP financial measures are defined, calculated and reconciled to the nearest GAAP financial measures in the Management’s Discussion and Analysis.

    OUTLOOK
    Pulse had a very strong first half year, generating revenue of $41.1 million and ending the quarter with $24.2 million of working capital including $25.9 million in cash. These financial results have provided capital returns to shareholders, strengthened the balance sheet, and positioned the Company for solid financial performance in 2025.

    Pulse’s ability to forecast future revenue continues to be challenging, as significant annual fluctuations are the norm in the seismic data library business. Industry trends that we consider relevant as we look forward include land sales in Western Canada, drilling forecasts for the year, commodity price levels, M&A forecasts and the status of industry infrastructure improvements. It is difficult to predict in the midst of the current market dynamics how this will unfold through the remainder of 2025. M&A activity for the year so far, has surpassed many analysts’ earlier expectations and is expected to remain strong for the remainder of 2025. Lower oil prices have contributed to decreased corporate valuations which often lead to acquisition opportunities. Alberta land sales through 2024 were strong, but at midpoint in 2025 have generated just over half the amount for the same period in 2024. In British Columbia land sales were resumed in Q3 2024 after a pause of over three years. New infrastructure, such as the TMX pipeline expansion, a driver of increased drilling activity, which was completed in 2024 has provided increased export capacity. The Canadian Association of Energy Contractors, in November 2024 forecast an increase to 6,604 wells to be drilled in 2025, an approximate 7% increase over 2024. There has been no update published to this forecast, and drilling activity is reported to be relatively stable. LNG Canada’s liquified natural gas export facility is now operational and is expected to contribute to increased drilling and may lead to an improvement in Canadian natural gas prices.

    Of course, there continues to be a high level of uncertainty on political and economic fronts. Uncertainty around energy tariffs and trade policy between Canada and the United States, are contributing to the lack of clarity for the future. It is clear that Canada needs to continue to build pipelines and increase natural gas egress, to support the country’s energy security, as well as to secure new buyers of Canadian energy.

    Pulse, as previously stated, has low visibility regarding future seismic data library sales levels, regardless of industry conditions. The Company remains focused on business practices that have served throughout the full range of conditions. The Company maintains a strong balance sheet and carries no debt. Led by an experienced and capable management team, Pulse operates with a low-cost structure and focuses on maintaining excellent client relations and providing exceptional customer service. Pulse’s strong financial position, high leverage to increased revenue in its EBITDA margin and careful management of its cash resources continue to translate to the return of capital to shareholders through regular and special dividends.

    CORPORATE PROFILE

    Pulse is a market leader in the acquisition, marketing and licensing of 2D and 3D seismic data to the western Canadian energy sector. Pulse owns the largest licensable seismic data library in Canada, currently consisting of approximately 65,310 square kilometres of 3D seismic and 829,207 kilometres of 2D seismic. The library extensively covers the Western Canada Sedimentary Basin, where most of Canada’s oil and natural gas exploration and development occur.

    For further information, please contact:
    Neal Coleman, President and CEO
    Or
    Pamela Wicks, Vice President Finance and CFO
    Tel.: 403-237-5559
    Toll-free: 1-877-460-5559
    E-mail: info@pulseseismic.com.
    Please visit our website at www.pulseseismic.com

    This document contains information that constitutes “forward-looking information” or “forward-looking statements” (collectively, “forward-looking information”) within the meaning of applicable securities legislation. Forward-looking information is often, but not always, identified by the use of words such as “anticipate”, “believe”, “expect”, “plan”, “intend”, “forecast”, “target”, “project”, “guidance”, “may”, “will”, “should”, “could”, “estimate”, “predict” or similar words suggesting future outcomes or language suggesting an outlook.

    The Outlook section herein contain forward-looking information which includes, but is not limited to, statements regarding:

    > The outlook of the Company for the year ahead, including future operating costs and expected revenues;

    > Recent events on the political, economic, regulatory, and legal fronts affecting the industry’s medium- to longer-term prospects, including progression and completion of contemplated infrastructure projects;

    > The Company’s capital resources and sufficiency thereof to finance future operations, meet its obligations associated with financial liabilities and carry out the necessary capital expenditures through 2025;

    > Pulse’s capital allocation strategy;

    > Pulse’s dividend policy;

    > Oil and natural gas prices and forecast trends;

    > Oil and natural gas drilling activity and land sales activity;

    > Oil and natural gas company capital budgets;

    > Future demand for seismic data;

    > Future seismic data sales;

    > Pulse’s business and growth strategy; and

    > Other expectations, beliefs, plans, goals, objectives, assumptions, information and statements about possible future events, conditions, results and performance, as they relate to the Company or to the oil and natural gas industry as a whole.

    By its very nature, forward-looking information involves inherent risks and uncertainties, both general and specific, and risks that predictions, forecasts, projections and other forward-looking statements will not be achieved. Pulse does not publish specific financial goals or otherwise provide guidance, due to the inherently poor visibility of seismic revenue. The Company cautions readers not to place undue reliance on these statements as a number of important factors could cause the actual results to differ materially from the beliefs, plans, objectives, expectations and anticipations, estimates and intentions expressed in such forward-looking information.

    These factors include, but are not limited to:

    > Uncertainty of the timing and volume of data sales;

    > Volatility of oil and natural gas prices;

    > Risks associated with the oil and natural gas industry in general;

    > The Company’s ability to access external sources of debt and equity capital;

    > Credit, liquidity and commodity price risks;

    > The demand for seismic data;

    > The pricing of data library licence sales;

    > Cybersecurity;

    > Relicensing (change-of-control) fees and partner copy sales;

    > Environmental, health and safety risks;

    > Federal and provincial government laws and regulations, including those pertaining to taxation, royalty rates, environmental protection, public health and safety;

    > Competition;

    > Dependence on key management, operations and marketing personnel;

    > The loss of seismic data;

    > Protection of intellectual property rights;

    > The introduction of new products; and

    > Climate change.

    Pulse cautions that the foregoing list of factors that may affect future results is not exhaustive. Additional information on these risks and other factors which could affect the Company’s operations and financial results is included under “Risk Factors” in the Company’s most recent annual information form, and in the Company’s most recent audited annual financial statements, most recent MD&A, management information circular, quarterly reports, material change reports and news releases. Copies of the Company’s public filings are available on SEDAR+ at www.sedarplus.ca.

    When relying on forward-looking information to make decisions with respect to Pulse, investors and others should carefully consider the foregoing factors and other uncertainties and potential events. Furthermore, the forward-looking information contained in this document is provided as of the date of this document and the Company does not undertake any obligation to update publicly or to revise any of the included forward-looking information, except as required by law. The forward-looking information in this document is provided for the limited purpose of enabling current and potential investors to evaluate an investment in Pulse. Readers are cautioned that such forward-looking information may not be appropriate, and should not be used, for other purposes.

    PDF available: http://ml.globenewswire.com/Resource/Download/8df92694-2a01-45f3-b5b4-ecc0f5bd6edb

    The MIL Network

  • MIL-OSI: Timberland Bancorp Third Fiscal Quarter Net Income Increases to $7.10 Million

    Source: GlobeNewswire (MIL-OSI)

    • Quarterly EPS Increases 22% to $0.90 from $0.74 One Year Ago
    • Quarterly Net Interest Margin Increases to 3.80%
    • Quarterly Return on Average Assets Increases to 1.47%
    • Quarterly Return on Average Equity Increases to 11.23%
    • Announces New Stock Repurchase Program

    HOQUIAM, Wash., July 22, 2025 (GLOBE NEWSWIRE) — Timberland Bancorp, Inc. (NASDAQ: TSBK) (“Timberland” or “the Company”), the holding company for Timberland Bank (the “Bank”), today reported net income of $7.10 million, or $0.90 per diluted common share for the quarter ended June 30, 2025. This compares to net income of $6.76 million, or $0.85 per diluted common share for the preceding quarter and $5.92 million, or $0.74 per diluted common share, for the comparable quarter one year ago.

    For the first nine months of fiscal 2025, Timberland’s net income increased 16% to $20.72 million, or $2.60 per diluted common share, from $17.93 million, or $2.21 per diluted common share for the first nine months of fiscal 2024.

    “Timberland delivered solid third fiscal quarter results, driven by continued net interest margin expansion and steady balance sheet growth,” stated Dean Brydon, Chief Executive Officer. “Net income and earnings per share increased 20% and 22%, respectively, compared to the third fiscal quarter a year ago. Compared to the prior quarter, net income and earnings per share increased 5% and 6%, respectively, primarily due to higher net interest income and non-interest income. We also posted year-over-year improvements across all key profitability metrics, and our tangible book value per share (non-GAAP) continued its upward trend. Looking ahead we believe our strong capital position, solid earnings, and continued focus on disciplined growth position us well to navigate the current environment and drive long-term shareholder value.”

    “As a result of Timberland’s strong earnings and sound capital position, our Board of Directors announced a quarterly cash dividend to shareholders of $0.26 per share, payable on August 22, 2025, to shareholders of record on August 8, 2025,” stated Jonathan Fischer, President and Chief Operating Officer. “This represents the 51st consecutive quarter Timberland will have paid a cash dividend. In addition, the Company also announced the adoption of a new stock repurchase program. We believe Timberland stock presents a strong investment opportunity, and buying back shares is a strategy to enhance long-term value for shareholders. Under the new repurchase program, the Company may repurchase up to 5% of the outstanding shares, or 393,842 shares. The new stock repurchase program replaces our existing stock repurchase program, which had 31,762 shares available to be repurchased.”

    “Our net interest margin continued to show positive momentum in the third fiscal quarter, expanding to 3.80%,” said Marci Basich, Chief Financial Officer. “This represents a one basis point increase from the prior quarter and a 27 basis point improvement compared to the same period last year, reflecting our disciplined asset-liability management and favorable shift in earning asset yields. Total deposits grew by $19 million, or 1%, during the quarter, driven primarily by higher balances in certificates of deposit. This growth highlights the continued strength of our customer relationships and the effectiveness of our deposit-gathering strategies. We remain focused on maintaining a well-balanced funding mix while sustaining stable margin performance going forward.”

    “The loan portfolio continues to expand at a steady pace, with growth of 2% over the prior quarter and 3% year-over year,” Brydon continued. “Credit quality remains an area we are monitoring closely, as we are seeing a mix of stable-to-positive trends alongside a few metrics that have shown modest deterioration. Net charge-offs continue to be minimal, with net recoveries of $1,000 during the third quarter. Our non-performing assets (“NPA”) ratio increased to 0.21% at June 30, 2025, compared to 0.13% at the end of the prior quarter. However, it remains a slight improvement from the 0.22% reported a year ago. Although non-accrual loans increased this quarter primarily due to a single matured loan, total non-accrual balances remain modestly below year-ago levels.”

    Earnings and Balance Sheet Highlights (at or for the periods ended June 30, 2025, compared to June 30, 2024, or March 31, 2025):
      
        Earnings Highlights:

    • Earnings per diluted common share (“EPS”) increased 6% to $0.90 for the current quarter from $0.85 for the preceding quarter and increased 22% from $0.74 for the comparable quarter one year ago; EPS increased 18% to $2.60 for the first nine months of fiscal 2025 from $2.21 for the first nine months of fiscal 2024;
    • Net income increased 5% to $7.10 million for the current quarter from $6.76 million for the preceding quarter and increased 20% from $5.92 million for the comparable quarter one year ago; Net income increased 16% to $20.72 million for the first nine months of fiscal 2025 from $17.93 million for the first nine months of fiscal 2024;
    • Return on average equity (“ROE”) and return on average assets (“ROA”) for the current quarter were 11.23% and 1.47%, respectively;
    • Net interest margin (“NIM”) for the current quarter expanded to 3.80% from 3.79% for the preceding quarter and 3.53% for the comparable quarter one year ago; and
    • The efficiency ratio for the current quarter improved to 54.48% from 56.25% for the preceding quarter and 58.97% for the comparable quarter one year ago.

       Balance Sheet Highlights:

    • Total assets increased 1% from the prior quarter and increased 3% year-over-year;
    • Net loans receivable increased 2% from the prior quarter and increased 3% year-over-year;
    • Total deposits increased 1% from the prior quarter and increased 3% year-over-year;
    • Total shareholders’ equity increased 2% from the prior quarter and increased 6% year-over-year; 34,236 shares of common stock were repurchased during the current quarter for $1.02 million;
    • Non-performing assets to total assets ratio was 0.21% at June 30, 2025 compared to 0.13% at March 31, 2025 and 0.22% at June 30, 2024;
    • Book and tangible book (non-GAAP) values per common share increased to $32.58 and $30.62 respectively, at June 30, 2025; and
    • Liquidity (both on-balance sheet and off-balance sheet) remained strong at June 30, 2025 with only $20 million in borrowings and additional secured borrowing line capacity of $674 million available through the Federal Home Loan Bank (“FHLB”) and the Federal Reserve.

    Operating Results

    Operating revenue (net interest income before the provision for credit losses plus non-interest income) for the current quarter increased 3% to $20.50 million from $19.90 million for the preceding quarter and increased 9% from $18.77 million for the comparable quarter one year ago. The increase in operating revenue compared to the preceding quarter was primarily due to increases in total interest and dividend income and non-interest income, which were partially offset by an increase in total funding costs. Operating revenue increased 8% to $60.06 million for the first nine months of fiscal 2025 from $55.82 million for the first nine months of fiscal 2024, primarily due to an increase in total interest and dividend income, which was partially offset by an increase in funding costs.

    Net interest income increased $409,000, or 2%, to $17.62 million for the current quarter from $17.21 million for the preceding quarter and increased $1.64 million, or 10%, from $15.98 million for the comparable quarter one year ago. The increase in net interest income compared to the preceding quarter was primarily due to a $20.80 million increase in the average balance of total interest-earning assets and, to a lesser extent, a two-basis point increase in the weighted average yield on total interest-earning assets to 5.50% from 5.48%. These increases were partially offset by a $20.21 million increase in the average balance of interest-bearing liabilities and a two-basis point increase in the weighted average cost of interest-bearing liabilities. Timberland’s NIM for the current quarter expanded to 3.80% from 3.79% for the preceding quarter and 3.53% for the comparable quarter one year ago.   The NIM for the current quarter was increased by approximately four basis points due to the collection of $102,000 in pre-payment penalties, non-accrual interest, and late fees, and the accretion of $68,000 of the fair value discount on acquired loans.   The NIM for the preceding quarter was increased by approximately five basis points due to the collection of $201,000 in pre-payment penalties, non-accrual interest, and late fees, and the accretion of $17,000 of the fair value discount on acquired loans.   The NIM for the comparable quarter one year ago was increased by approximately three basis points due to the collection of $124,000 in pre-payment penalties, non-accrual interest, and late fees, and the accretion of $9,000 of the fair value discount on acquired loans. Net interest income for the first nine months of fiscal 2025 increased $4.19 million, or 9%, to $51.81 million from $47.62 million for the first nine months of fiscal 2024, primarily due to a 32 basis point increase in the weighted average yield of total interest-earning assets to 5.49% from 5.17% and a $49.96 million increase in the average balance of total interest-earning assets. These increases to net interest income were partially offset by a seven basis point increase in the weighted average cost of interest-bearing liabilities to 2.53% from 2.46% and a $58.86 million increase in the average balance of total interest-bearing liabilities. Timberland’s NIM expanded to 3.74% for the first nine months of fiscal 2025 from 3.53% for the first nine months of fiscal 2024.

    A $351,000 provision for credit losses on loans was recorded for the quarter ended June 30, 2025. The provision was primarily due to loan portfolio growth and changes in the composition of the loan portfolio. This compares to a $237,000 provision for credit losses on loans for the preceding quarter and a $264,000 provision for credit losses on loans for the comparable quarter one year ago. In addition, a $93,000 provision for credit losses on unfunded commitments and a $4,000 recapture of credit losses on investment securities were recorded for the current quarter.  

    Non-interest income increased $188,000, or 7%, to $2.88 million for the current quarter from $2.69 million for the preceding quarter and increased $84,000, or 3%, from $2.79 million for the comparable quarter one year ago. The increase in non-interest income compared to the preceding quarter was primarily due to an increase in ATM and debit card interchange transaction fees and smaller changes in several other categories. Fiscal year-to-date non-interest income increased by 1%, to $8.26 million from $8.20 million for the first nine months of fiscal 2024.

    Total operating (non-interest) expenses for the current quarter decreased $27,000 (less than 1%), to $11.17 million from $11.19 million for the preceding quarter and increased $98,000, or 1%, from $11.07 million for the comparable quarter one year ago.   The decrease in operating expenses compared to the preceding quarter was primarily due to decreases in salaries and employee benefits, premises and equipment, technology and communications, professional fees, and smaller decreases in several other expense categories. These decreases were partially offset by increases in state and local taxes and smaller increases in several other expense categories. The efficiency ratio for the current quarter improved to 54.48% from 56.25% for the preceding quarter and 58.97% for the comparable quarter one year ago. Fiscal year-to-date operating expenses increased 2% to $33.43 million from $32.68 million for the first nine months of fiscal 2024. The efficiency ratio for the first nine months of fiscal 2025 improved to 55.65% from 58.55% for the first nine months of fiscal 2024.

    The provision for income taxes for the current quarter increased $85,000, or 5%, to $1.79 million from $1.71 million for the preceding quarter, primarily due to higher taxable income. Timberland’s effective income tax rate was 20.1% for the quarter ended June 30, 2025, compared to 20.2% for the quarter ended March 31, 2025 and 20.6% for the quarter ended June 30, 2024. Timberland’s effective income tax rate was 20.1% for the first nine months of fiscal 2025 compared to 20.2% for the first nine months of fiscal 2024.  

    Balance Sheet Management

    Total assets increased $24.46 million, or 1%, during the quarter to $1.96 billion at June 30, 2025 from $1.93 billion at March 31, 2025 and increased $56.56 million, or 3%, from $1.90 billion one year ago. The increase during the current quarter was primarily due to a $21.42 million increase in net loans receivable and smaller increases in several other categories.

    Liquidity

    Timberland has continued to maintain a strong liquidity position, both on-balance sheet and off-balance sheet. Liquidity, as measured by the sum of cash and cash equivalents, CDs held for investment, and available for sale investment securities, was 17.0% of total liabilities at June 30, 2025, compared to 16.9% at March 31, 2025, and 14.7% one year ago. Timberland also had secured borrowing line capacity of $674 million available through the FHLB and the Federal Reserve at June 30, 2025. With a strong and diversified deposit base, only 17% of Timberland’s deposits were uninsured or uncollateralized at June 30, 2025. (Note: This calculation excludes public deposits that are fully collateralized.)

    Loans

    Net loans receivable increased $21.42 million, or 2%, during the quarter to $1.44 billion at June 30, 2025 from $1.42 billion at March 31, 2025. This increase was primarily due to a $21.83 million increase in multi-family loans, a $5.67 million increase in commercial real estate loans, a $3.89 million increase in land loans and smaller increases in several other loan categories. These increases were partially offset by a $5.50 million decrease in construction loans, a $4.80 million decrease in commercial business loans, and smaller decreases in several other loan categories. The increase in multi-family loans was, in large part, due to several multi-family construction projects being completed and converting to permanent financing during the quarter.

    Loan Portfolio
    ($ in thousands)
     
      June 30, 2025   March 31, 2025   June 30, 2024
      Amount   Percent   Amount   Percent   Amount   Percent
    Mortgage loans:                      
    One- to four-family (a) $317,574     21%     $315,421     21%     $288,611     19%  
    Multi-family   200,418     13       178,590     12       177,950     12  
    Commercial   607,924     40       602,248     40       597,865     40  
    Construction – custom and                      
    owner/builder   128,900     8       114,401     7       128,222     9
    Construction – speculative
    one-to four-family
      9,595     1       9,791     1       11,441     1  
    Construction – commercial   15,992     1       22,352     1       32,130     2  
    Construction – multi-family   32,731     2       46,602     3       35,631     2  
    Construction – land                      
    development   15,461     1       15,032     1       19,104     1  
    Land   36,193     2       32,301     2       32,384     2  
    Total mortgage loans   1,364,788     89       1,336,738     88       1,323,338     88  
                           
    Consumer loans:                      
    Home equity and second                      
    mortgage   47,511     3       47,458     3       43,679     3  
    Other   2,176           2,375           3,121      
    Total consumer loans   49,687     3       49,833     3       46,800     3  
                           
    Commercial loans:                      
    Commercial business loans   126,497     8       131,243     9       136,213     9  
    SBA PPP loans   101           156           314      
    Total commercial loans   126,598     8       131,399     9       136,527     9  
    Total loans   1,541,073     100%       1,517,970     100%       1,506,665     100%  
    Less:                      
    Undisbursed portion of                      
    construction loans in                      
    process   (76,272)           (75,042)           (87,196)      
    Deferred loan origination                      
    fees   (5,427)           (5,329)           (5,404)      
    Allowance for credit losses   (17,878)           (17,525)           (17,046)      
    Total loans receivable, net $1,441,496         $1,420,074         $1,397,019      

    _______________________
    (a)   Does not include one- to four-family loans held for sale totaling $1,763, $1,151, and $1,795 at June 30, 2025, March 31, 2025, and June 30, 2024, respectively.  

    The following table provides a breakdown of commercial real estate (“CRE”) mortgage loans by collateral type as of June 30, 2025:

    CRE Loan Portfolio Breakdown by Collateral
    ($ in thousands)
    Collateral Type   Balance   Percent of
    CRE
    Portfolio
      Percent of
    Total Loan
    Portfolio
      Average
    Balance Per
    Loan
      Non-
    Accrual
    Industrial warehouses   $128 822   21%     8%     $1 301   $161
    Medical/dental offices     81 238   13     5       1 269    
    Office buildings     68 916   11     5       801    
    Other retail buildings     54 472   9     3       567    
    Mini-storage     38 483   6     2       1 539    
    Hotel/motel     31 656   5     2       2 638    
    Restaurants     27 485   5     2       585    
    Gas stations/conv. stores     24 359   4     2       1 015    
    Churches     14 690   3     1       918    
    Nursing homes     13 532   2     1       2 255    
    Shopping centers     10 507   2     1       1 751    
    Mobile home parks     8 882   2     1       444    
    Additional CRE     104 882   17     7       760     —    
    Total CRE   $607 924   100%     40%     $951   $161

    Timberland originated $81.99 million in loans during the quarter ended June 30, 2025, compared to $56.76 million for the preceding quarter and $74.32 million for the comparable quarter one year ago. Timberland continues to originate fixed-rate one- to four-family mortgage loans, a portion of which are sold into the secondary market for asset-liability management purposes and to generate non-interest income.   During the current quarter, fixed-rate one- to four-family mortgage loans totaling $5.11 million were sold compared to $5.17 million for the preceding quarter and $3.05 million for the comparable quarter one year ago.

    Investment Securities
            
    Timberland’s investment securities and CDs held for investment increased $2.04 million, or 1%, to $237.36 million at June 30, 2025, from $235.33 million at March 31, 2025. The increase was primarily due to the purchase of additional U.S. government agency mortgage-backed investment securities and U.S. Treasury investment securities. Partially offsetting these increases was the sale of $13.49 million available for sale investment securities, which resulted in a net gain of $24,000.

    Deposits

    Total deposits increased $18.65 million, or 1%, during the quarter to $1.67 billion at June 30, 2025, from $1.65 billion at March 31, 2025. The quarter’s increase consisted of a $16.01 million increase in certificates of deposit account balances, a $4.66 million increase in money market account balances, and a $1.60 million increase in NOW checking account balances. These decreases were partially offset by a $2.03 million decrease in savings account balances and a $1.59 million decrease in non-interest-bearing checking account balances.

    Deposit Breakdown
    ($ in thousands)
     
          June 30, 2025   March 31, 2025   June 30, 2024  
          Amount    Percent   Amount   Percent   Amount   Percent  
    Non-interest-bearing demand     $406,222   24%   $407,811   25%   $407,125   25%  
    NOW checking     334,922   20   333,325   20   324,795   20  
    Savings     205,829   12   207,857   13   207,921   13  
    Money market     305,207   18   300,552   18   327,162   20  
    Certificates of deposit under $250     244,063   15   227,137   14   195,022   12  
    Certificates of deposit $250 and over     126,254   8   124,009   7   117,788   7  
    Certificates of deposit – brokered     46,980   3   50,139   3   48,731   3  
    Total deposits     $1,669,477   100%   $1,650,830   100%   $1,628,544   100%  

    Borrowings

    Total borrowings were $20.00 million at both June 30, 2025 and March 31, 2025. At June 30, 2025, the weighted average rate on the borrowings was 3.97%.

    Shareholders’ Equity and Capital Ratios

    Total shareholders’ equity increased $4.14 million, or 2%, to $256.66 million at June 30, 2025, from $252.52 million at March 31, 2025, and increased $15.44 million, or 6%, from $241.22 million at June 30, 2024.   The increase in shareholders’ equity during the quarter was primarily due to net income of $7.10 million, which was partially offset by the payment of $2.05 million in dividends to shareholders and the repurchase of 34,236 shares of common stock for $1.02 million (an average price of $29.74 per share).

    Timberland remains well capitalized with a total risk-based capital ratio of 20.54%, a Tier 1 leverage capital ratio of 12.63%, a tangible common equity to tangible assets ratio (non-GAAP) of 12.42%, and a shareholders’ equity to total assets ratio of 13.11% at June 30, 2025.   Timberland’s held to maturity investment securities were $141.57 million at June 30, 2025, with a net unrealized loss of $5.99 million (pre-tax). Although not permitted by U.S. Generally Accepted Accounting Principles (“GAAP”), including these unrealized losses in accumulated other comprehensive income (loss) (“AOCI”) would result in a ratio of shareholders’ equity to total assets of 12.90%, compared to 13.11%, as reported.

    New Stock Repurchase Program

    The Company announced a new stock repurchase program today. Under the repurchase program, the Company may repurchase up to 5% of the Company’s outstanding shares, or 393,842 shares. The new stock repurchase program replaces the existing stock repurchase program which had 31,762 shares available to be repurchased.

    The repurchase program permits shares to be repurchased in open market or private transactions, through block trades, and pursuant to any trading plan that may be adopted in accordance with Rule 10b5-1 of the Securities and Exchange Commission (“SEC”). Repurchases will be made at management’s discretion at prices management considers to be attractive and in the best interest of both the Company and its shareholders, subject to the availability of stock, general market conditions, the trading price of the stock, alternative uses for capital, and the Company’s financial performance. Open market purchases will be conducted in accordance with the limitations set forth in Rule 10b-18 of the SEC and other applicable legal requirements. The repurchase program may be suspended, terminated, or modified at any time for any reason, including market conditions, the cost of repurchasing the shares, the availability of alternative investment opportunities, liquidity, and other factors deemed appropriate. These factors may also affect the timing and amount of share repurchases. The repurchase program does not obligate the Company to purchase any particular number of shares.

    Asset Quality
    Timberland’s non-performing assets to total assets ratio was 0.21% at June 30, 2025, compared to 0.13% at March 31, 2025 and 0.22% at June 30, 2024.   Net recoveries totaled $1,000 for the current quarter compared to net charge-offs of less than $1,000 for the preceding quarter and net charge-offs of $36,000 for the comparable quarter one year ago. During the current quarter, provisions for credit losses of $351,000 on loans and $93,000 unfunded commitments were made, which was partially offset by a $4,000 recapture of credit losses on investment securities. The allowance for credit losses (“ACL”) for loans as a percentage of loans receivable was 1.23% at June 30, 2025, compared to 1.22% at March 31, 2025 and 1.21% one year ago.

    Total delinquent loans (past due 30 days or more) and non-accrual loans increased $2.86 million or 86%, to $6.18 million at June 30, 2025, from $3.32 million at March 31, 2025 and increased $1.95 million, or 46%, from $4.23 million at June 30, 2024. Non-accrual loans increased $1.52 million, or 65%, to $3.84 million at June 30, 2025 from $2.33 million at March 31, 2025 and decreased $277,000, or 7%, from $4.12 million at March 31, 2024.   The quarterly increase in non-accrual loans was primarily due to one loan (secured by several single family homes) being past maturity. The loan is well collateralized (based on recent appraisals) and the Bank is working with the borrower to renew the loan. Loans graded “Substandard” totaled $32.37 million (or 2% of total loans receivable) at June 30, 2025.

    Non-Accrual Loans
    ($ in thousands)
     
      June 30, 2025   March 31, 2025   June 30, 2024
      Amount   Quantity   Amount   Quantity   Amount   Quantity
    Mortgage loans:                      
    One- to four-family $1,781   1   $47   1   $135   2
    Commercial   161   2     324   3     1,310   4
    Construction – custom and                      
    owner/builder               152   1
    Total mortgage loans   1,942   3     371   4     1,597   7
                           
    Consumer loans:                      
    Home equity and second                      
    mortgage   575   3     575   3     615   3
    Other                
    Total consumer loans   575   3     575   3     615   3
                           
    Commercial business loans   1,326   9     1,381   11     1,908   8
    Total loans $3,843   15   $2,327   18   $4,120   18

            
    Timberland had two properties classified as other real estate owned (“OREO”) at June 30, 2025:

      June 30, 2025   March 31, 2025   June 30, 2024
      Amount   Quantity   Amount   Quantity   Amount   Quantity
    Other real estate owned:                      
    Commercial $221   1   $221   1   $  
    Land     1       1       1
    Total mortgage loans $221   2   $221   2   $   1

    About Timberland Bancorp, Inc.
    Timberland Bancorp, Inc., a Washington corporation, is the holding company for Timberland Bank. The Bank opened for business in 1915 and primarily serves consumers and businesses across Grays Harbor, Thurston, Pierce, King, Kitsap and Lewis counties, Washington with a full range of lending and deposit services through its 23 branches (including its main office in Hoquiam).    

    Disclaimer
    Certain matters discussed in this press release may contain forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. These statements relate to our financial condition, results of operations, plans, objectives, future performance or business. Forward-looking statements are not statements of historical fact, are based on certain assumptions and often include the words “believes,” “expects,” “anticipates,” “estimates,” “forecasts,” “intends,” “plans,” “targets,” “potentially,” “probably,” “projects,” “outlook” or similar expressions or future or conditional verbs such as “may,” “will,” “should,” “would” and “could.” Forward-looking statements include statements with respect to our beliefs, plans, objectives, goals, expectations, assumptions and statements about future economic performance. These forward-looking statements are subject to known and unknown risks, uncertainties and other factors that could cause our actual results to differ materially from the results anticipated or implied by our forward-looking statements, including, but not limited to: potential adverse impacts to economic conditions in our local market areas, other markets where the Company has lending relationships, or other aspects of the Company’s business operations or financial markets, including, without limitation, as a result of employment levels, labor shortages and the effects of inflation, a potential recession or slowed economic growth; continuing elevated levels of inflation and the impact of current and future monetary policies of the Board of Governors of the Federal Reserve System (“Federal Reserve”) in response thereto; the effects of any federal government shutdown; credit risks of lending activities, including any deterioration in the housing and commercial real estate markets which may lead to increased losses and non-performing loans in our loan portfolio resulting in our ACL not being adequate to cover actual losses and thus requiring us to materially increase our ACL through the provision for credit losses; changes in general economic conditions, either nationally or in our market areas; changes in the levels of general interest rates, and the relative differences between short and long-term interest rates, deposit interest rates, our net interest margin and funding sources; fluctuations in the demand for loans, the number of unsold homes, land and other properties and fluctuations in real estate values in our market areas; secondary market conditions for loans and our ability to sell loans in the secondary market; results of examinations of us by the Federal Reserve and of our bank subsidiary by the Federal Deposit Insurance Corporation (“FDIC”), the Washington State Department of Financial Institutions, Division of Banks or other regulatory authorities, including the possibility that any such regulatory authority may, among other things, institute a formal or informal enforcement action against us or our bank subsidiary which could require us to increase our ACL, write-down assets, change our regulatory capital position or affect our ability to borrow funds or maintain or increase deposits or impose additional requirements or restrictions on us, any of which could adversely affect our liquidity and earnings; the impact of bank failures or adverse developments at other banks and related negative press about the banking industry in general on investor and depositor sentiment; legislative or regulatory changes that adversely affect our business including changes in banking, securities and tax law, in regulatory policies and principles, or the interpretation of regulatory capital or other rules; our ability to attract and retain deposits; our ability to control operating costs and expenses; the use of estimates in determining fair value of certain of our assets, which estimates may prove to be incorrect and result in significant declines in valuation; difficulties in reducing risks associated with the loans in our consolidated balance sheet; staffing fluctuations in response to product demand or the implementation of corporate strategies that affect our work force and potential associated charges; disruptions, security breaches, or other adverse events, failures or interruptions in, or attacks on, our information technology systems or on the third-party vendors who perform several of our critical processing functions; our ability to retain key members of our senior management team; costs and effects of litigation, including settlements and judgments; our ability to implement our business strategies; our ability to manage loan delinquency rates; increased competitive pressures among financial services companies; changes in consumer spending, borrowing and savings habits; the availability of resources to address changes in laws, rules, or regulations or to respond to regulatory actions; our ability to pay dividends on our common stock; the quality and composition of our securities portfolio and the impact if any adverse changes in the securities markets, including on market liquidity; inability of key third-party providers to perform their obligations to us; changes in accounting policies and practices, as may be adopted by the financial institution regulatory agencies or the Financial Accounting Standards Board (“FASB”), including additional guidance and interpretation on accounting issues and details of the implementation of new accounting methods; the economic impact of climate change, severe weather events, natural disasters, pandemics, epidemics and other public health crises, acts of war or terrorism, civil unrest and other external events on our business; other economic, competitive, governmental, regulatory, and technological factors affecting our operations, pricing, products and services; and other risks described elsewhere in this press release and in the Company’s other reports filed with or furnished to the Securities and Exchange Commission.

    Any of the forward-looking statements that we make in this press release and in the other public statements we make are based upon management’s beliefs and assumptions at the time they are made. We do not undertake and specifically disclaim any obligation to publicly update or revise any forward-looking statements included in this press release to reflect the occurrence of anticipated or unanticipated events or circumstances after the date of such statements or to update the reasons why actual results could differ from those contained in such statements, whether as a result of new information, future events or otherwise. In light of these risks, uncertainties and assumptions, the forward-looking statements discussed in this document might not occur and we caution readers not to place undue reliance on any forward-looking statements. These risks could cause our actual results for fiscal 2025 and beyond to differ materially from those expressed in any forward-looking statements by, or on behalf of, us, and could negatively affect the Company’s consolidated financial condition and results of operations as well as its stock price performance.

    TIMBERLAND BANCORP INC. AND SUBSIDIARY
    CONSOLIDATED STATEMENTS OF INCOME
      Three Months Ended
    ($ in thousands, except per share amounts) (unaudited)   June 30,   March 31,   June 30,
          2025       2025       2024  
      Interest and dividend income            
      Loans receivable   $21,411     $20,896     $19,537  
      Investment securities     2,064       2,003       2,335  
      Dividends from mutual funds, FHLB stock and other investments     83       82       94  
      Interest bearing deposits in banks     1,986       1,884       2,173  
      Total interest and dividend income     25,544       24,865       24,139  
                   
      Interest expense            
      Deposits     7,721       7,454       7,938  
      Borrowings     201       198       220  
      Total interest expense     7,922       7,652       8,158  
      Net interest income     17,622       17,213       15,981  
      Provision for credit losses – loans     351       237       264  
      Recapture of credit losses – investment securities     (4)       (5)       (12)  
      Prov. for (recapture of ) credit losses – unfunded commitments     93       14       (8)  
      Net int. income after provision for (recapture of) credit losses     17,182       16,967       15,737  
                   
      Non-interest income            
      Service charges on deposits     966       959       1,014  
      ATM and debit card interchange transaction fees     1,262       1,176       1,297  
      Gain on sales of investment securities, net     24              
      Gain on sales of loans, net     138       122       68  
      Bank owned life insurance (“BOLI”) net earnings     171       165       158  
      Other     314       265       254  
      Total non-interest income, net     2,875       2,687       2,791  
                   
      Non-interest expense            
      Salaries and employee benefits     5,825       5,977       5,928  
      Premises and equipment     973       1,075       1,011  
      Gain on sale of premises and equipment, net                 (3)  
      Advertising     182       189       211  
      OREO and other repossessed assets, net     8       9        
      ATM and debit card processing     658       521       580  
      Postage and courier     137       142       130  
      State and local taxes     570       335       335  
      Professional fees     341       431       335  
      FDIC insurance     211       219       208  
      Loan administration and foreclosure     99       155       156  
      Technology and communications     993       1,121       1,086  
      Deposit operations     345       319       450  
      Amortization of core deposit intangible (“CDI”)     45       45       56  
      Other, net     780       656       586  
      Total non-interest expense, net     11,167       11,194       11,069  
                   
      Income before income taxes     8,890       8,460       7,459  
      Provision for income taxes     1,790       1,705       1,535  
      Net income   $7,100     $6,755     $5,924  
                   
      Net income per common share:            
      Basic   $0.90     $0.85     $0.74  
      Diluted     0.90       0.85       0.74  
                   
      Weighted average common shares outstanding:            
      Basic     7,893,308       7,937,063       8,004,552  
      Diluted     7,921,762       7,968,632       8,039,345  
    TIMBERLAND BANCORP INC. AND SUBSIDIARY
    CONSOLIDATED STATEMENTS OF INCOME
      Nine Months Ended
    ($ in thousands, except per share amounts) (unaudited)   June 30,   June 30,
          2025       2024  
      Interest and dividend income        
      Loans receivable   $63,339     $56,841  
      Investment securities     6,205       6,892  
      Dividends from mutual funds, FHLB stock and other investments     252       266  
      Interest bearing deposits in banks     5,870       5,791  
      Total interest and dividend income     75,666       69,790  
               
      Interest expense        
      Deposits     23,259       21,383  
      Borrowings     602       787  
      Total interest expense     23,861       22,170  
      Net interest income     51,805       47,620  
      Provision for credit losses – loans     640       810  
      Recapture of credit losses – investment securities     (14)       (20)  
      Prov. for (recapture of) credit losses – unfunded commitments     87       (130)  
      Net int. income after provision for (recapture of) credit losses     51,092       46,960  
               
      Non-interest income        
      Service charges on deposits     2,924       3,024  
      ATM and debit card interchange transaction fees     3,706       3,773  
      Gain on sales of investment securities, net     24        
      Gain on sales of loans, net     303       188  
      Bank owned life insurance (“BOLI”) net earnings     503       470  
      Other     799       749  
      Total non-interest income, net     8,259       8,204  
               
      Non-interest expense        
      Salaries and employee benefits     17,893       17,863  
      Premises and equipment     2,998       3,065  
      Gain on sale of premises and equipment, net           (3)  
      Advertising     552       556  
      OREO and other repossessed assets, net     17       1  
      ATM and debit card processing     1,700       1,796  
      Postage and courier     401       401  
      State and local taxes     1,251       979  
      Professional fees     1,118       908  
      FDIC insurance     640       624  
      Loan administration and foreclosure     383       395  
      Technology and communications     3,253       3,101  
      Deposit operations     997       1,094  
      Amortization of core deposit intangible (“CDI”)     135       169  
      Other, net     2,090       1,735  
      Total non-interest expense, net     33,428       32,684  
               
      Income before income taxes     25,923       22,480  
      Provision for income taxes     5,208       4,552  
      Net income   $20,715     $17,928  
               
      Net income per common share:        
      Basic   $2.61     $2.22  
      Diluted     2.60       2.21  
               
      Weighted average common shares outstanding:        
      Basic     7,929,626       8,067,068  
      Diluted     7,963,412       8,109,043  
    TIMBERLAND BANCORP INC. AND SUBSIDIARY
    CONSOLIDATED BALANCE SHEETS
     
    ($ in thousands, except per share amounts) (unaudited)   June 30,   March 31,   June 30,
          2025       2025       2024  
    Assets            
    Cash and due from financial institutions   $32,532     $26,010     $25,566  
    Interest-bearing deposits in banks     161,095       165,201       133,347  
      Total cash and cash equivalents     193,627       191,211       158,913  
                   
    Certificates of deposit (“CDs”) held for investment, at cost     8,462       8,711       10,458  
    Investment securities:            
      Held to maturity, at amortized cost (net of ACL – investment securities)     141,570       140,954       176,787  
      Available for sale, at fair value     86,475       84,807       74,515  
    Investments in equity securities, at fair value     855       853       836  
    FHLB stock     2,045       2,045       2,037  
    Other investments, at cost     3,000       3,000       3,000  
    Loans held for sale     1,763       1,151       1,795  
                 
    Loans receivable     1,459,374       1,437,599       1,414,065  
    Less: ACL – loans     (17,878)       (17,525)       (17,046)  
      Net loans receivable     1,441,496       1,420,074       1,397,019  
                   
    Premises and equipment, net     21,490       21,436       21,558  
    OREO and other repossessed assets, net     221       221        
    BOLI     24,113       23,942       23,436  
    Accrued interest receivable     7,174       7,127       7,045  
    Goodwill     15,131       15,131       15,131  
    CDI     316       361       508  
    Loan servicing rights, net     911       1,051       1,526  
    Operating lease right-of-use assets     1,248       1,324       1,550  
    Other assets     7,295       9,331       4,515  
      Total assets   $1,957,192     $1,932,730     $1,900,629  
                   
    Liabilities and shareholders’ equity            
    Deposits: Non-interest-bearing demand   $406,222     $407,811     $407,125  
    Deposits: Interest-bearing     1,263,255       1,243,019       1,221,419  
      Total deposits     1,669,477       1,650,830       1,628,544  
                   
    Operating lease liabilities     1,350       1,426       1,649  
    FHLB borrowings     20,000       20,000       20,000  
    Other liabilities and accrued expenses     9,701       7,950       9,213  
      Total liabilities     1,700,528       1,680,206       1,659,406  
                 
    Shareholders’ equity            
    Common stock, $.01 par value; 50,000,000 shares authorized;
            7,876,853 shares issued and outstanding – June 30, 2025
            7,903,489 shares issued and outstanding – March 31, 2025
            7,953,431 shares issued and outstanding – June 30, 2024
        27,226       28,028       30,681  
    Retained earnings     230,213       225,166       211,087  
    Accumulated other comprehensive loss     (775)       (670)       (545)  
      Total shareholders’ equity     256,664       252,524       241,223  
      Total liabilities and shareholders’ equity   $1,957,192     $1,932,730     $1,900,629  
      Three Months Ended
    PERFORMANCE RATIOS:   June 30, 2025   March 31, 2025   June 30, 2024
    Return on average assets (a)     1.47%       1.43%       1.25%  
    Return on average equity (a)     11.23%       10.95%       9.95%  
    Net interest margin (a)     3.80%       3.79%       3.53%  
    Efficiency ratio     54.48%       56.25%       58.97%  
                 
      Nine Months Ended
        June 30, 2025       June 30, 2024
    Return on average assets (a)     1.44%           1.27%  
    Return on average equity (a)     11.07%           10.10%  
    Net interest margin (a)     3.74%           3.53%  
    Efficiency ratio     55.65%           58.55%  
                 
      Three Months Ended
    ASSET QUALITY RATIOS AND DATA: ($ in thousands)   June 30, 2025   March 31, 2025   June 30, 2024
    Non-accrual loans   $3,843     $2,327     $4,120  
    Loans past due 90 days and still accruing                  
    Non-performing investment securities     38       41       72  
    OREO and other repossessed assets     221       221        
    Total non-performing assets (b)   $4,102     $2,589     $4,192  
                 
    Non-performing assets to total assets (b)     0.21%       0.13%       0.22%  
    Net charge-offs (recoveries) during quarter   $(1)     $     $36  
    Allowance for credit losses – loans to non-accrual loans     465%       753%       414%  
    Allowance for credit losses – loans to loans receivable (c)     1.23%       1.22%       1.21%  
                 
                 
    CAPITAL RATIOS:            
    Tier 1 leverage capital     12.63%       12.55%       12.04%  
    Tier 1 risk-based capital     19.29%       19.04%       17.97%  
    Common equity Tier 1 risk-based capital     19.29%       19.04%       17.97%  
    Total risk-based capital     20.54%       20.29%       19.22%  
    Tangible common equity to tangible assets (non-GAAP)     12.42%       12.36%       11.97%  
                 
    BOOK VALUES:            
    Book value per common share   $32.58     $31.95     $30.33  
    Tangible book value per common share (d)     30.62       29.99       28.36  

    ________________________________________________

    (a) Annualized
    (b) Non-performing assets include non-accrual loans, loans past due 90 days and still accruing, non-performing investment securities and OREO and other repossessed assets.
    (c) Does not include loans held for sale and is before the allowance for credit losses.
    (d) Tangible common equity divided by common shares outstanding (non-GAAP).                                

    AVERAGE BALANCES, YIELDS, AND RATES – QUARTERLY
    ($ in thousands)
    (unaudited)

      For the Three Months Ended 
      June 30, 2025    March 31, 2025    June 30, 2024 
      Amount   Rate   Amount   Rate   Amount   Rate
                           
    Assets                      
    Loans receivable and loans held for sale $ 1,450,350     5.92 %   $ 1,435,999     5.90 %   $ 1,391,582     5.65 %
    Investment securities and FHLB stock (1)   232,272     3.71       232,532     3.64             268,954     3.63  
    Interest-earning deposits in banks and CDs   178,887     4.45       172,175     4.44       161,421     5.41  
    Total interest-earning assets   1,861,509     5.50       1,840,706     5.48            1,821,957     5.33  
    Other assets         79,715           77,563           82,008      
    Total assets $ 1,941,224         $ 1,918,269         $ 1,903,965      
                           
    Liabilities and Shareholders’ Equity                      
    NOW checking accounts $ 333,074     1.39 %   $ 328,115     1.32 %   $ 329,344     1.29 %
    Money market accounts   304,526     3.16       306,137     3.18       326,023     3.56  
    Savings accounts   205,592     0.35       206,054     0.28       208,488     0.27  
    Certificates of deposit accounts   363,342     3.77       343,945     3.82       311,545     4.21  
    Brokered CDs   48,028     4.83       50,104     4.85       45,442     5.32  
    Total interest-bearing deposits   1,254,562     2.47       1,234,355     2.45       1,220,842     2.62  
    Borrowings   20,002     4.03       20,000     4.04       20,001     4.42  
    Total interest-bearing liabilities   1,274,564     2.49       1,254,355     2.47       1,240,843     2.64  
                           
    Non-interest-bearing demand deposits   402,717           403,738           413,494      
    Other liabilities   10,266           10,064           10,245      
    Shareholders’ equity   253,677           250,112           239,383      
    Total liabilities and shareholders’ equity $ 1,941,224         $ 1,918,269         $ 1,903,965      
                           
    Interest rate spread     3.01 %       3.01 %       2.69 %
    Net interest margin (2)     3.80 %       3.79 %       3.53 %
    Average interest-earning assets to                      
    average interest-bearing liabilities   146.05 %         146.75 %         146.83 %    

               _____________________________________
    (1) Includes other investments
    (2) Net interest margin = annualized net interest income /
          average interest-earning assets
            

    AVERAGE BALANCES, YIELDS, AND RATES
    ($ in thousands)
    (unaudited)

      For the Nine Months Ended 
      June 30, 2025    June 30, 2024 
      Amount   Rate   Amount   Rate
                   
    Assets              
    Loans receivable and loans held for sale $ 1,441,506     5.87 %   $ 1,363,213     5.57 %
    Investment securities and FHLB stock (1)   237,400     3.81             294,789     3.24  
    Interest-earning deposits in banks and CDs       172,591     4.55       143,537     5.39  
    Total interest-earning assets        1,851,497     5.49            1,801,539     5.17  
    Other assets   77,595           81,650      
    Total assets $ 1,929,092         $ 1,883,189      
                   
    Liabilities and Shareholders’ Equity              
    NOW checking accounts $ 329,883     1.36 %   $ 358,052     1.48 %
    Money market accounts   311,762     3.26       273,683     3.09  
    Savings accounts   205,764     0.30       214,275     0.24  
    Certificates of deposit accounts   346,313     3.89       291,707     4.12  
    Brokered CDs   48,169     4.71       42,856     5.37  
    Total interest-bearing deposits   1,241,891     2.50       1,180,573     2.42  
    Borrowings   20,001     4.02       22,457     4.68  
    Total interest-bearing liabilities   1,261,892     2.53       1,203,030     2.46  
                   
    Non-interest-bearing demand deposits   406,906           431,849      
    Other liabilities             10,159           11,273      
    Shareholders’ equity   250,135           237,037      
    Total liabilities and shareholders’ equity $ 1,929,092         $ 1,883,189      
                   
    Interest rate spread     2.96 %       2.71 %
    Net interest margin (2)     3.74 %       3.53 %
    Average interest-earning assets to              
    average interest-bearing liabilities   146.72 %         149.75 %    

    _____________________________________
    (1) Includes other investments
    (2) Net interest margin = annualized net interest income /
    average interest-earning assets

    Non-GAAP Financial Measures
    In addition to results presented in accordance with GAAP, this press release contains certain non-GAAP financial measures. Timberland believes that certain non-GAAP financial measures provide investors with information useful in understanding the Company’s financial performance; however, readers of this report are urged to review these non-GAAP financial measures in conjunction with GAAP results as reported.

    Financial measures that exclude intangible assets are non-GAAP measures. To provide investors with a broader understanding of capital adequacy, Timberland provides non-GAAP financial measures for tangible common equity, along with the GAAP measure. Tangible common equity is calculated as shareholders’ equity less goodwill and CDI. In addition, tangible assets equal total assets less goodwill and CDI.

    The following table provides a reconciliation of ending shareholders’ equity (GAAP) to ending tangible shareholders’ equity (non-GAAP) and ending total assets (GAAP) to ending tangible assets (non-GAAP).

    ($ in thousands)   June 30, 2025   March 31, 2025   June 30, 2024
                 
    Shareholders’ equity   $ 256,664     $ 252,524     $ 241,223  
    Less goodwill and CDI     (15,447)       (15,492)       (15,639)  
    Tangible common equity   $ 241,217     $ 237,032     $ 225,584  
                 
    Total assets   $ 1,957,192     $ 1,932,730     $ 1,900,629  
    Less goodwill and CDI     (15,447)       (15,492)       (15,639)  
    Tangible assets   $ 1,941,745     $ 1,917,238     $ 1,884,990  

    Contact: Dean J. Brydon, CEO 
    Jonathan A. Fischer, President & COO
    Marci A. Basich, CFO 
    (360) 533-4747 
    www.timberlandbank.com

    The MIL Network

  • MIL-OSI Russia: Foreign Ministers of Azerbaijan and Georgia Discuss Bilateral Cooperation and Regional Projects

    Translation. Region: Russian Federal

    Source: People’s Republic of China in Russian – People’s Republic of China in Russian –

    An important disclaimer is at the bottom of this article.

    Source: People’s Republic of China – State Council News

    Tbilisi, July 22 (Xinhua) — Georgian Foreign Minister Maka Bochorishvili and Azerbaijani Foreign Minister Jeyhun Bayramov held talks in Tbilisi to discuss key areas of bilateral and regional cooperation, the Georgian Foreign Ministry said on Tuesday.

    The parties exchanged views on strengthening political dialogue, cooperation in the areas of energy, transport and trade, and also touched upon current challenges in the area of regional security.

    Following the talks, a joint press conference was held. M. Bochorishvili emphasized the importance of ensuring sustainable peace and stability in the South Caucasus, expressing hope for the earliest possible achievement of a peace agreement between Azerbaijan and Armenia. The head of the Georgian Foreign Ministry placed special emphasis on the trilateral format of cooperation between Azerbaijan, Georgia and Armenia. “We believe that we have the potential to continue cooperation between the three countries in this format,” she said.

    J. Bayramov, for his part, confirmed the unwavering support for Georgia’s territorial integrity and highly appreciated the level of political relations between the two states. He noted that in the first five months of 2025, bilateral trade turnover exceeded USD 330 million, which is 20 percent more than in the same period last year. In addition, as the minister added, Azerbaijan continues to be one of the largest foreign investors in the Georgian economy with a total investment of over USD 3.6 billion.

    J. Bayramov emphasized the strategic importance of joint infrastructure projects, including the Baku-Tbilisi-Ceyhan oil pipeline, the Southern Gas Corridor and the Baku-Tbilisi-Kars railway. According to him, these projects contribute to the expansion of regional connectivity and have great international potential.

    During the talks, the parties also discussed the development of a cross-border project to deliver renewable energy from Azerbaijan through Georgia and the Black Sea to the European market and ways to improve the efficiency of cargo transportation along the Middle Corridor. –0–

    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: Talen Energy Reports PJM Auction Results for the 2026/2027 Planning Year

    Source: GlobeNewswire (MIL-OSI)

    HOUSTON, July 22, 2025 (GLOBE NEWSWIRE) — Talen Energy Corporation (“Talen,” “we,” or “our”) (NASDAQ: TLN), a leading independent power producer, today reported its results from the PJM Base Residual Auction for the 2026/2027 planning year. Talen cleared a total of 6,702 megawatts at a clearing price of $329.17 per megawatt-day across the MAAC, PPL and PSEG Locational Deliverability Areas, equating to approximately $805 million in capacity revenues for the 2026/2027 planning year. The planning year runs from June 1, 2026, through May 31, 2027.

    About Talen

    Talen Energy (NASDAQ: TLN) is a leading independent power producer and energy infrastructure company dedicated to powering the future. We own and operate approximately 10.7 gigawatts of power infrastructure in the United States, including 2.2 gigawatts of nuclear power and a significant dispatchable fossil fleet. We produce and sell electricity, capacity, and ancillary services into wholesale U.S. power markets, with our generation fleet principally located in the Mid-Atlantic and Montana. Our team is committed to generating power safely and reliably and delivering the most value per megawatt produced. Talen is also powering the digital infrastructure revolution. We are well-positioned to serve this growing industry, as artificial intelligence data centers increasingly demand more reliable, clean power. Talen is headquartered in Houston, Texas. For more information, visit https://www.talenenergy.com/.

    Investor Relations:
    Sergio Castro
    Vice President & Treasurer
    InvestorRelations@talenenergy.com

    Media:
    Taryne Williams
    Director, Corporate Communications
    Taryne.Williams@talenenergy.com

    Forward-Looking Statements

    This communication contains forward-looking statements within the meaning of the federal securities laws, which statements are subject to substantial risks and uncertainties. These forward-looking statements are intended to qualify for the safe harbor from liability established by the Private Securities Litigation Reform Act of 1995. All statements other than statements of historical fact included in this communication, or incorporated by reference into this communication, are forward-looking statements. Throughout this communication, we have attempted to identify forward-looking statements by using words such as “anticipate,” “believe,” “continue,” “could,” “estimate,” “expect,” “forecasts,” “goal,” “intend,” “may,” “plan,” “potential,” “predict,” “project,” “seek,” “should,” “will,” or other forms of these words or similar words or expressions or the negative thereof, although not all forward-looking statements contain these terms. Forward-looking statements address future events and conditions concerning, among other things, capital expenditures, earnings, litigation, regulatory matters, hedging, liquidity and capital resources and accounting matters. Forward-looking statements are subject to substantial risks and uncertainties that could cause our future business, financial condition, results of operations or performance to differ materially from our historical results or those expressed or implied in any forward-looking statement contained in this communication. All of our forward-looking statements include assumptions underlying or relating to such statements that may cause actual results to differ materially from expectations, and are subject to numerous factors that present considerable risks and uncertainties.

    The MIL Network

  • MIL-OSI: Baker Hughes Company Announces Second-Quarter 2025 Results

    Source: GlobeNewswire (MIL-OSI)

    Second-quarter highlights

    • Orders of $7.0 billion, including $3.5 billion of IET orders.
    • RPO of $34.0 billion, including record IET RPO of $31.3 billion.
    • Revenue of $6.9 billion, down 3% year-over-year.
    • Attributable net income of $701 million.
    • GAAP diluted EPS of $0.71 and adjusted diluted EPS* of $0.63.
    • Adjusted EBITDA* of $1,212 million, up 7% year-over-year.
    • Cash flows from operating activities of $510 million and free cash flow* of $239 million.
    • Returns to shareholders of $423 million, including $196 million of share repurchases.

    HOUSTON and LONDON, July 22, 2025 (GLOBE NEWSWIRE) — Baker Hughes Company (Nasdaq: BKR) (“Baker Hughes” or the “Company”) announced results today for the second quarter of 2025.

    “We delivered strong second-quarter results, with total adjusted EBITDA margins increasing 170 basis points year-over-year to 17.5% despite a modest decline in revenue. This performance reflects the benefits of structural cost improvements and continued deployment of our business system, which is driving higher productivity, stronger operating leverage and more durable earnings across the company,” said Lorenzo Simonelli, Baker Hughes Chairman and Chief Executive Officer.

    “IET orders totaled $3.5 billion in the quarter, resulting in another record backlog for the segment. Importantly, order momentum remained strong, supported by more than $550 million of data center related orders, despite the absence of large LNG awards. Following a strong first half and a positive outlook for second half awards, we are confident of achieving the full-year order guidance range for IET.”

    “We remain confident in our ability to deliver solid performance in 2025, with continued growth in IET helping to offset softness in more market-sensitive areas of OFSE – underscoring the strength of our portfolio and the benefits of our strategic diversification. Accordingly, we are raising our full-year revenue and EBITDA guidance for IET and reestablishing full-year guidance for OFSE.”

    “During the quarter, we also announced three strategic transactions to advance our portfolio optimization strategy, reinforcing efforts to enhance the durability of earnings and cash flow while creating long-term value for shareholders. These actions are designed to unlock value from non-core businesses in our portfolio and redeploy that capital into higher-margin opportunities that fit our financial and strategic frameworks.”

    “We are progressing with our strategy of positioning the company for sustainable, differentiated growth and commend the focus and dedication of our people in executing this strategy,” concluded Simonelli.

    * Non-GAAP measure. See reconciliations in the section titled “Reconciliation of GAAP to non-GAAP Financial Measures.”

        Three Months Ended   Variance
    (in millions except per share amounts)   June 30, 2025 March 31, 2025 June 30, 2024   Sequential Year-over-year
    Orders   $ 7,032   $ 6,459   $ 7,526     9 % (7 %)
    Revenue     6,910     6,427     7,139     8 % (3 %)
    Net income attributable to Baker Hughes     701     402     579     74 % 21 %
    Adjusted net income attributable to Baker Hughes*     623     509     568     22 % 10 %
    Adjusted EBITDA*     1,212     1,037     1,130     17 % 7 %
    Diluted earnings per share (EPS)     0.71     0.40     0.58     76 % 22 %
    Adjusted diluted EPS*     0.63     0.51     0.57     23 % 11 %
    Cash flow from operating activities     510     709     348     (28 %) 47 %
    Free cash flow*     239     454     106     (47 %) F


    * Non-GAAP measure. See reconciliations in the section titled “Reconciliation of GAAP to non-GAAP Financial Measures.”

    Certain columns and rows in our tables and financial statements may not sum up due to the use of rounded numbers.

    “F” is used in most instances when variance is above 100%. Additionally, “U” is used when variance is below (100)%.

    Quarter Highlights

    Executing our portfolio optimization strategy

    In the second quarter, Baker Hughes announced three strategic transactions, all of which reflect a disciplined capital allocation framework and a focus on core businesses with strong return potential.

    First, the Company signed an agreement to form a joint venture with a subsidiary of Cactus, Inc., contributing the Oilfield Services & Equipment’s (OFSE) Surface Pressure Control (SPC) product line in exchange for approximately $345 million while maintaining a minority ownership stake.

    Second, the Company announced an agreement to sell the Precision Sensors & Instrumentation (PSI) product line within Industrial & Energy Technology (IET) to Crane Company for approximately $1.15 billion. These proceeds will enhance the Company’s flexibility to reinvest in higher-growth, higher-return areas that support further margin expansion and improved returns.

    Finally, Baker Hughes agreed to acquire Continental Disc Corporation (CDC), a leading provider of pressure management solutions, for approximately $540 million. The CDC acquisition strengthens the IET Industrial Products portfolio with a highly complementary, margin-accretive business that expands the Company’s position in the flow and pressure control market and enhances recurring, lifecycle driven revenue.

    Key awards and technology achievements

    The Company continued to support the development of critical data center projects, with year-to-date data center awards of more than $650 million. IET received an award to supply 30 NovaLT™ turbines, representing our largest data center award to-date. The turbines, alongside other associated Baker Hughes equipment, will deliver up to 500 megawatts (MW) of reliable and efficient power for data center development across various U.S. locations.

    Frontier Infrastructure awarded a contract for NovaLT™ turbines, delivering up to 270 MW of power for its data center projects in Wyoming and Texas. This follows the March 2025 enterprise-wide agreement to accelerate large scale carbon capture and storage (CCS) and power solutions.

    Baker Hughes continues to grow the pipeline of future data center opportunities. At the Saudi-U.S. Investment Forum in May, the Company signed an MoU with DataVolt that plans to power data centers globally, including the NEOM project in the Kingdom that intends to utilize Baker Hughes’ multi-fuel NovaLT™ technology solution.

    In addition to growing demand from data center applications, IET experienced increased demand for NovaLT™ turbines in the gas infrastructure sector. During the second quarter, the segment secured an award for four gas turbines to support Aramco’s Master Gas System III pipeline project. Including this award, we have secured a total of $2.9 billion in gas infrastructure equipment orders over the past six quarters.

    Highlighting the durability of IET’s lifecycle model, the segment was awarded several aftermarket services contracts. In Gas Technology Services (GTS), the Company secured more than $350 million of Contractual Services Agreements (CSA) during the quarter. We signed a maintenance agreement with Belayim Petroleum Company (“Petrobel”) to improve uptime and reliability of critical turbomachinery equipment in Egypt. Also in GTS, we renewed a multi-year service agreement with Oman LNG, including resident engineering support along with digital remote monitoring and diagnostics services delivered through iCenter™.

    The Company gained further traction with New Energy globally, with year-to-date bookings now totaling $1.25 billion. In Climate Technology Solutions (CTS), we secured one of our largest CCS orders to-date, providing compression technology for a CCS hub in the Middle East. Also in CTS, we signed a framework agreement with Energinet in Denmark to supply 16 reciprocating compressor packages, supporting an increase in biogas production while driving methane and CO2 emissions reduction for gas infrastructure across the country.

    Industrial Technology continued to demonstrate strong momentum across multiple end markets. In Industrial Solutions, we secured a variety of awards for our Cordant™ suite of solutions. This includes an award from a large NOC to deploy Asset Performance Management across several compression stations in the Middle East, and an award from NOVA Chemicals to optimize maintenance spend and maximize production.

    OFSE maintained strong momentum in Mature Assets Solutions around the globe. In Angola, OFSE was awarded multi-year production solutions contracts for chemicals, artificial lift, and digital services to support a major operator’s offshore activities. In Kazakhstan, the TOPAN and Baker Hughes joint venture secured a critical production chemicals and services award. In Norway, Equinor awarded OFSE a contract to industrialize offshore plug and abandonment (P&A) operations in the Oseberg East field, which followed the announcement of a multi-year P&A framework agreement for integrated well services.

    OFSE saw continued adoption of Leucipa™ automated field production solution, securing an award from Repsol for next-generation AI capabilities following the MoU signed in October 2024. The Company also signed an agreement with ENI to deploy Leucipa for electric submersible pumps (ESP) optimization and AI-powered predictive failure analytics in the Middle East.

    Also in the Middle East, Baker Hughes signed a master services agreement with Aramco for installation and maintenance of ESPs across the Kingdom of Saudi Arabia.

    In North America, OFSE secured a multi-year contract to provide drag reducing chemicals to be deployed on Genesis Energy’s Cameron Highway Oil Pipeline and Poseidon systems, each of which is operated and 64% owned by Genesis Energy. To support this agreement, OFSE will expand its chemicals manufacturing footprint and deploy Leucipa. Additionally, bp awarded OFSE a multi-year chemicals management services contract to optimize throughput and asset reliability in the U.S. Gulf Coast.

    In Germany, OFSE successfully drilled Lower Saxony’s first productive deep geothermal exploration well, a project that leverages OFSE’s integrated well construction and production capabilities and the Company’s industry-leading subsurface-to-surface digital solutions to monitor and optimize operational performance.

    Consolidated Financial Results

    Revenue for the quarter was $6,910 million, an increase of 8% sequentially and down $229 million year-over-year. The decrease in revenue year-over-year was driven by a decrease in OFSE partially offset by an increase in IET.

    The Company’s total book-to-bill ratio in the second quarter of 2025 was 1.0; the IET book-to-bill ratio was 1.1.

    Net income as determined in accordance with accounting principles generally accepted in the United States of America (“GAAP”) for the second quarter of 2025 was $701 million. Net income increased $299 million sequentially and increased $122 million year-over-year.

    Adjusted net income (a non-GAAP financial measure) for the second quarter of 2025 was $623 million, which excludes adjustments totaling $78 million. A list of the adjusting items and associated reconciliation from GAAP has been provided in Table 1b in the section titled “Reconciliation of GAAP to non-GAAP Financial Measures.” Adjusted net income for the second quarter of 2025 was up 22% sequentially and up 10% year-over-year.

    Depreciation and amortization for the second quarter of 2025 was $293 million.

    Adjusted EBITDA (a non-GAAP financial measure) for the second quarter of 2025 was $1,212 million, which excludes adjustments totaling $102 million. See Table 1a in the section titled “Reconciliation of GAAP to non-GAAP Financial Measures.” Adjusted EBITDA for the second quarter was up 17% sequentially and up 7% year-over-year.

    The sequential increase in adjusted net income and adjusted EBITDA was primarily driven by an increase in volume, favorable FX, and overall productivity. The year-over-year increase in adjusted net income and adjusted EBITDA was driven by productivity and structural cost out initiatives, favorable FX, partially offset by lower volume in OFSE, and cost inflation in both segments.

    Other Financial Items

    Remaining Performance Obligations (“RPO”) in the second quarter of 2025 ended at $34 billion, an increase of $0.8 billion from the first quarter of 2025. OFSE RPO was $2.7 billion, down 3% sequentially, while IET RPO was $31.3 billion, up 3% sequentially. Within IET RPO, GTE RPO was $11.3 billion, and GTS RPO was $15.6 billion.

    Income tax expense in the second quarter of 2025 was $256 million.

    Other (income) expense, net in the second quarter of 2025 was $(134) million, primarily related to changes in fair value for equity securities of $(119) million.

    GAAP diluted earnings per share was $0.71. Adjusted diluted earnings per share (a non-GAAP financial measure) was $0.63. Excluded from adjusted diluted earnings per share were all items listed in Table 1b in the section titled “Reconciliation of GAAP to non-GAAP Financial Measures.”

    Cash flow from operating activities was $510 million for the second quarter of 2025. Free cash flow (a non-GAAP financial measure) for the quarter was $239 million. A reconciliation from GAAP has been provided in Table 1c in the section titled “Reconciliation of GAAP to non-GAAP Financial Measures.”

    Capital expenditures, net of proceeds from disposal of assets, were $271 million for the second quarter of 2025, of which $184 million was for OFSE and $68 million was for IET.

    Results by Reporting Segment

    The following segment discussions and variance explanations are intended to reflect management’s view of the relevant comparisons of financial results on a sequential or year-over-year basis, depending on the business dynamics of the reporting segments.

    Oilfield Services & Equipment

    (in millions)   Three Months Ended   Variance
    Segment results   June 30, 2025 March 31, 2025 June 30, 2024   Sequential Year-over-year
    Orders   $ 3,503   $ 3,281   $ 4,068     7 % (14 %)
    Revenue   $ 3,617   $ 3,499   $ 4,011     3 % (10 %)
    EBITDA   $ 677   $ 623   $ 716     9 % (5 %)
    EBITDA margin     18.7 %   17.8 %   17.8 %   0.9pts 0.9pts
    (in millions)   Three Months Ended   Variance
    Revenue by Product Line   June 30, 2025 March 31, 2025 June 30, 2024   Sequential Year-over-year
    Well Construction   $ 921   $ 892   $ 1,090     3 % (16 %)
    Completions, Intervention, and Measurements     935     925     1,118     1 % (16 %)
    Production Solutions     968     899     958     8 % 1 %
    Subsea & Surface Pressure Systems     793     782     845     1 % (6 %)
    Total Revenue   $ 3,617   $ 3,499   $ 4,011     3 % (10 %)
    (in millions)   Three Months Ended   Variance
    Revenue by Geographic Region   June 30, 2025 March 31, 2025 June 30, 2024   Sequential Year-over-year
    North America   $ 928   $ 922   $ 1,023     1 % (9 %)
    Latin America     639     568     663     12 % (4 %)
    Europe/CIS/Sub-Saharan Africa     653     580     827     13 % (21 %)
    Middle East/Asia     1,398     1,429     1,498     (2 %) (7 %)
    Total Revenue   $ 3,617   $ 3,499   $ 4,011     3 % (10 %)
                   
    North America   $ 928   $ 922   $ 1,023     1 % (9 %)
    International   $ 2,689   $ 2,577   $ 2,988     4 % (10 %)


    EBITDA excludes depreciation and amortization of
    $233 million, $226 million, and $223 million for the three months ended June 30, 2025, March 31, 2025, and June 30, 2024, respectively. EBITDA margin is defined as EBITDA divided by revenue.

    OFSE orders of $3,503 million for the second quarter of 2025 increased by 7% sequentially. Subsea and Surface Pressure Systems orders were $698 million, up 31% sequentially, and down 21% year-over-year.

    OFSE revenue of $3,617 million for the second quarter of 2025 was up 3% sequentially, and down 10% year-over-year.

    North America revenue was $928 million, up 1% sequentially. International revenue was $2,689 million, up 4% sequentially, with increase in all regions with the exception of Middle East and Asia.

    Segment EBITDA for the second quarter of 2025 was $677 million, an increase of $54 million, or 9% sequentially. The sequential increase in EBITDA was primarily driven by productivity, structural cost-out initiatives, volume increase, partially offset by inflation and revenue mix.

    Industrial & Energy Technology

    (in millions)   Three Months Ended   Variance
    Segment results   June 30, 2025 March 31, 2025 June 30, 2024   Sequential Year-over-year
    Orders   $ 3,530   $ 3,178   $ 3,458     11 % 2 %
    Revenue   $ 3,293   $ 2,928   $ 3,128     12 % 5 %
    EBITDA   $ 585   $ 501   $ 497     17 % 18 %
    EBITDA margin     17.8 %   17.1 %   15.9 %   0.7pts 1.9pts
    (in millions)   Three Months Ended   Variance
    Orders by Product Line   June 30, 2025 March 31, 2025 June 30, 2024   Sequential Year-over-year
    Gas Technology Equipment   $ 781   $ 1,335   $ 1,493     (42 %) (48 %)
    Gas Technology Services     986     913     769     8 % 28 %
    Total Gas Technology     1,767     2,248     2,261     (21 %) (22 %)
    Industrial Products     513     501     524     2 % (2 %)
    Industrial Solutions     327     281     281     16 % 16 %
    Total Industrial Technology     839     782     805     7 % 4 %
    Climate Technology Solutions     923     148     392     F F
    Total Orders   $ 3,530   $ 3,178   $ 3,458     11 % 2 %
    (in millions)   Three Months Ended   Variance
    Revenue by Product Line   June 30, 2025 March 31, 2025 June 30, 2024   Sequential Year-over-year
    Gas Technology Equipment   $ 1,624   $ 1,456   $ 1,539     12 % 6 %
    Gas Technology Services     752     592     691     27 % 9 %
    Total Gas Technology     2,377     2,047     2,230     16 % 7 %
    Industrial Products     488     445     509     10 % (4 %)
    Industrial Solutions     273     258     262     6 % 4 %
    Total Industrial Technology     761     703     770     8 % (1 %)
    Climate Technology Solutions     156     178     128     (12 %) 22 %
    Total Revenue   $ 3,293   $ 2,928   $ 3,128     12 % 5 %


    EBITDA excludes depreciation and amortization of
    $56 million, $53 million, and $55 million for the three months ended June 30, 2025, March 31, 2025, and June 30, 2024, respectively. EBITDA margin is defined as EBITDA divided by revenue.

    “F” is used in most instances when variance is above 100%. Additionally, “U” is used when variance is below (100)%.

    IET orders of $3,530 million for the second quarter of 2025 increased by $72 million, or 2% year-over-year. The increase was driven primarily by Climate Technology Solutions and partially offset by Gas Technology.

    IET revenue of $3,293 million for the second quarter of 2025 increased $165 million, or 5% year-over-year. The increase was driven by Gas Technology Equipment, up $85 million or 6% year-over-year, Gas Technology Services, up $61 million or 9% year-over-year, and Climate Technology Solutions, up $28 million or 22% year-over-year.

    Segment EBITDA for the quarter was $585 million, an increase of $88 million, or 18% year-over-year. The year-over-year increase in segment EBITDA was driven by positive pricing, favorable FX, and productivity, partially offset by cost inflation.

    Reconciliation of GAAP to non-GAAP Financial Measures

    Management provides non-GAAP financial measures because it believes such measures are widely accepted financial indicators used by investors and analysts to analyze and compare companies on the basis of operating performance (including adjusted EBITDA; adjusted net income attributable to Baker Hughes; and adjusted diluted earnings per share) and liquidity (free cash flow) and that these measures may be used by investors to make informed investment decisions. Management believes that the exclusion of certain identified items from several key operating performance measures enables us to evaluate our operations more effectively, to identify underlying trends in the business, and to establish operational goals for certain management compensation purposes. Management also believes that free cash flow is an important supplemental measure of our cash performance but should not be considered as a measure of residual cash flow available for discretionary purposes, or as an alternative to cash flow from operating activities presented in accordance with GAAP.

    Table 1a. Reconciliation of Net Income Attributable to Baker Hughes to Adjusted EBITDA and Segment EBITDA

        Three Months Ended
    (in millions)   June 30, 2025 March 31, 2025 June 30, 2024
    Net income attributable to Baker Hughes (GAAP)   $ 701   $ 402   $ 579  
    Net income attributable to noncontrolling interests     10     7     2  
    Provision for income taxes     256     152     243  
    Interest expense, net     54     51     47  
    Depreciation & amortization     293     285     283  
    Change in fair value of equity securities (1)     (119 )   140     (19 )
    Other charges and credits (1)     17         (6 )
    Adjusted EBITDA (non-GAAP)     1,212     1,037     1,130  
    Corporate costs     78     85     83  
    Other (income) / expense not allocated to segments     (28 )   1      
    Total Segment EBITDA (non-GAAP)   $ 1,262   $ 1,124   $ 1,213  
    OFSE     677     623     716  
    IET     585     501     497  


    (1) 
    Change in fair value of equity securities and other charges and credits are reported in “Other (income) expense, net” on the condensed consolidated statements of income (loss).

    Table 1a reconciles net income attributable to Baker Hughes, which is the directly comparable financial result determined in accordance with GAAP, to adjusted EBITDA and Segment EBITDA. Adjusted EBITDA and Segment EBITDA exclude the impact of certain identified items.

    Table 1b. Reconciliation of Net Income Attributable to Baker Hughes to Adjusted Net Income Attributable to Baker Hughes

        Three Months Ended
    (in millions, except per share amounts)   June 30, 2025 March 31, 2025 June 30, 2024
    Net income attributable to Baker Hughes (GAAP)   $ 701   $ 402   $ 579  
    Change in fair value of equity securities     (119 )   140     (19 )
    Other adjustments     17         14  
    Tax adjustments(1)     24     (32 )   (6 )
    Total adjustments, net of income tax     (78 )   108     (11 )
    Less: adjustments attributable to noncontrolling interests              
    Adjustments attributable to Baker Hughes     (78 )   108     (11 )
    Adjusted net income attributable to Baker Hughes (non-GAAP)   $ 623   $ 509   $ 568  
             
    Denominator:        
    Weighted-average shares of Class A common stock outstanding diluted     991     999     1,001  
    Adjusted earnings per share – diluted (non-GAAP)   $ 0.63   $ 0.51   $ 0.57  


    (1) 
    All periods reflect the tax associated with the other (income) loss adjustments.

    Table 1b reconciles net income attributable to Baker Hughes, which is the directly comparable financial result determined in accordance with GAAP, to adjusted net income attributable to Baker Hughes. Adjusted net income attributable to Baker Hughes excludes the impact of certain identified items.

    Table 1c. Reconciliation of Net Cash Flows from Operating Activities to Free Cash Flow

        Three Months Ended
    (in millions)   June 30, 2025 March 31, 2025 June 30, 2024
    Net cash flows from operating activities (GAAP)   $ 510   $ 709   $ 348  
    Add: cash used for capital expenditures, net of proceeds from disposal of assets     (271 )   (255 )   (242 )
    Free cash flow (non-GAAP)   $ 239   $ 454   $ 106  

    Table 1c reconciles net cash flows from operating activities, which is the directly comparable financial result determined in accordance with GAAP, to free cash flow. Free cash flow is defined as net cash flows from operating activities less expenditures for capital assets plus proceeds from disposal of assets.


    Financial Tables (GAAP)

    Condensed Consolidated Statements of Income (Loss)
    (Unaudited)
     
        Three Months Ended June 30, Six Months Ended June 30,
    (In millions, except per share amounts)     2025     2024     2025     2024  
    Revenue   $ 6,910   $ 7,139   $ 13,337   $ 13,557  
    Costs and expenses:          
    Cost of revenue     5,295     5,493     10,247     10,469  
    Selling, general and administrative     567     643     1,144     1,261  
    Research and development costs     161     158     307     322  
    Other (income) expense, net     (134 )   (26 )   6     (48 )
    Interest expense, net     54     47     105     88  
    Income before income taxes     967     824     1,528     1,465  
    Provision for income taxes     (256 )   (243 )   (408 )   (421 )
    Net income     711     581     1,120     1,044  
    Less: Net income attributable to noncontrolling interests     10     2     17     10  
    Net income attributable to Baker Hughes Company   $ 701   $ 579   $ 1,103   $ 1,034  
               
    Per share amounts:      
    Basic income per Class A common stock   $ 0.71   $ 0.58   $ 1.11   $ 1.04  
    Diluted income per Class A common stock   $ 0.71   $ 0.58   $ 1.11   $ 1.03  
               
    Weighted average shares:          
    Class A basic     988     996     990     997  
    Class A diluted     991     1,001     995     1,002  
               
    Cash dividend per Class A common stock   $ 0.23   $ 0.21   $ 0.46   $ 0.42  
    Condensed Consolidated Statements of Financial Position
    (Unaudited)
     
    (In millions)   June 30, 2025 December 31, 2024
    ASSETS
    Current Assets:      
    Cash and cash equivalents   $ 3,087   $ 3,364  
    Current receivables, net     6,511     7,122  
    Inventories, net     5,105     4,954  
    All other current assets     2,915     1,771  
    Total current assets     17,618     17,211  
    Property, plant and equipment, less accumulated depreciation     5,176     5,127  
    Goodwill     5,801     6,078  
    Other intangible assets, net     3,919     3,951  
    Contract and other deferred assets     1,841     1,730  
    All other assets     4,385     4,266  
    Total assets   $ 38,740   $ 38,363  
    LIABILITIES AND EQUITY
    Current Liabilities:      
    Accounts payable   $ 4,340   $ 4,542  
    Short-term debt     66     53  
    Progress collections and deferred income     5,680     5,672  
    All other current liabilities     2,429     2,724  
    Total current liabilities     12,515     12,991  
    Long-term debt     5,968     5,970  
    Liabilities for pensions and other postretirement benefits     997     988  
    All other liabilities     1,392     1,359  
    Equity     17,868     17,055  
    Total liabilities and equity   $ 38,740   $ 38,363  
           
    Outstanding Baker Hughes Company shares:      
    Class A common stock     985     990  
    Condensed Consolidated Statements of Cash Flows
    (Unaudited)
     
        Three Months Ended June 30, Six Months Ended June 30,
    (In millions)     2025     2025     2024  
    Cash flows from operating activities:        
    Net income   $ 711   $ 1,120   $ 1,044  
    Adjustments to reconcile net income to net cash flows from operating activities:        
    Depreciation and amortization     293     579     566  
    Stock-based compensation cost     52     102     101  
    Change in fair value of equity securities     (119 )   21     (71 )
    (Benefit) provision for deferred income taxes     36     (17 )   33  
    Working capital     (120 )   98     (36 )
    Other operating items, net     (343 )   (684 )   (505 )
    Net cash flows provided by operating activities     510     1,219     1,132  
    Cash flows from investing activities:        
    Expenditures for capital assets     (301 )   (601 )   (625 )
    Proceeds from disposal of assets     30     74     101  
    Other investing items, net     (15 )   (69 )   (6 )
    Net cash flows used in investing activities     (286 )   (596 )   (530 )
    Cash flows from financing activities:        
    Repayment of long-term debt             (125 )
    Dividends paid     (227 )   (456 )   (419 )
    Repurchase of Class A common stock     (196 )   (384 )   (324 )
    Other financing items, net     (20 )   (105 )   (61 )
    Net cash flows used in financing activities     (443 )   (945 )   (929 )
    Effect of currency exchange rate changes on cash and cash equivalents     29     45     (35 )
    Decrease in cash and cash equivalents     (190 )   (277 )   (362 )
    Cash and cash equivalents, beginning of period     3,277     3,364     2,646  
    Cash and cash equivalents, end of period   $ 3,087   $ 3,087   $ 2,284  
    Supplemental cash flows disclosures:        
    Income taxes paid, net of refunds   $ 211   $ 418   $ 336  
    Interest paid   $ 98   $ 148   $ 150  


    Supplemental Financial Information

    Supplemental financial information can be found on the Company’s website at: investors.bakerhughes.com in the Financial Information section under Quarterly Results.

    Conference Call and Webcast

    The Company has scheduled an investor conference call to discuss management’s outlook and the results reported in today’s earnings announcement. The call will begin at 9:30 a.m. Eastern time, 8:30 a.m. Central time on Wednesday, July 23, 2025, the content of which is not part of this earnings release. The conference call will be broadcast live via a webcast and can be accessed by visiting the Events and Presentations page on the Company’s website at: investors.bakerhughes.com. An archived version of the webcast will be available on the website for one month following the webcast.

    Forward-Looking Statements

    This news release (and oral statements made regarding the subjects of this release) may contain forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended, (each a “forward-looking statement”). Forward-looking statements concern future circumstances and results and other statements that are not historical facts and are sometimes identified by the words “may,” “will,” “should,” “potential,” “intend,” “expect,” “would,” “seek,” “anticipate,” “estimate,” “overestimate,” “underestimate,” “believe,” “could,” “project,” “predict,” “continue,” “target,” “goal” or other similar words or expressions. There are many risks and uncertainties that could cause actual results to differ materially from our forward-looking statements. These forward-looking statements are also affected by the risk factors described in the Company’s annual report on Form 10-K for the annual period ended December 31, 2024 and those set forth from time to time in other filings with the Securities and Exchange Commission (“SEC”). The documents are available through the Company’s website at: www.investors.bakerhughes.com or through the SEC’s Electronic Data Gathering and Analysis Retrieval system at: www.sec.gov. We undertake no obligation to publicly update or revise any forward-looking statement, except as required by law. Readers are cautioned not to place undue reliance on any of these forward-looking statements.

    Our expectations regarding our business outlook and business plans; the business plans of our customers; oil and natural gas market conditions; cost and availability of resources; economic, legal and regulatory conditions, and other matters are only our forecasts regarding these matters.

    These forward-looking statements, including forecasts, may be substantially different from actual results, which are affected by many risks, along with the following risk factors and the timing of any of these risk factors:

    • Economic and political conditions – the impact of worldwide economic conditions and rising inflation; the impact of tariffs and the potential for significant increases thereto; the impact of global trade policy and the potential for significant changes thereto; the effect that declines in credit availability may have on worldwide economic growth and demand for hydrocarbons; foreign currency exchange fluctuations and changes in the capital markets in locations where we operate; and the impact of government disruptions and sanctions.
    • Orders and RPO – our ability to execute on orders and RPO in accordance with agreed specifications, terms and conditions and convert those orders and RPO to revenue and cash.
    • Oil and gas market conditions – the level of petroleum industry exploration, development and production expenditures; the price of, volatility in pricing of, and the demand for crude oil and natural gas; drilling activity; drilling permits for and regulation of the shelf and the deepwater drilling; excess productive capacity; crude and product inventories; liquefied natural gas supply and demand; seasonal and other adverse weather conditions that affect the demand for energy; severe weather conditions, such as tornadoes and hurricanes, that affect exploration and production activities; Organization of Petroleum Exporting Countries (“OPEC”) policy and the adherence by OPEC nations to their OPEC production quotas.
    • Terrorism and geopolitical risks – war, military action, terrorist activities or extended periods of international conflict, particularly involving any petroleum-producing or consuming regions, including Russia and Ukraine; and the recent conflict in the Middle East; labor disruptions, civil unrest or security conditions where we operate; potentially burdensome taxation, expropriation of assets by governmental action; cybersecurity risks and cyber incidents or attacks; epidemic outbreaks.

    About Baker Hughes:

    Baker Hughes (Nasdaq: BKR) is an energy technology company that provides solutions to energy and industrial customers worldwide. Built on a century of experience and conducting business in over 120 countries, our innovative technologies and services are taking energy forward – making it safer, cleaner and more efficient for people and the planet. Visit us at bakerhughes.com.

    For more information, please contact:

    Investor Relations

    Chase Mulvehill
    +1 346-297-2561
    investor.relations@bakerhughes.com

    Media Relations

    Adrienne M. Lynch
    +1 713-906-8407
    adrienne.lynch@bakerhughes.com

    The MIL Network

  • MIL-OSI: Baker Hughes Company Announces Second-Quarter 2025 Results

    Source: GlobeNewswire (MIL-OSI)

    Second-quarter highlights

    • Orders of $7.0 billion, including $3.5 billion of IET orders.
    • RPO of $34.0 billion, including record IET RPO of $31.3 billion.
    • Revenue of $6.9 billion, down 3% year-over-year.
    • Attributable net income of $701 million.
    • GAAP diluted EPS of $0.71 and adjusted diluted EPS* of $0.63.
    • Adjusted EBITDA* of $1,212 million, up 7% year-over-year.
    • Cash flows from operating activities of $510 million and free cash flow* of $239 million.
    • Returns to shareholders of $423 million, including $196 million of share repurchases.

    HOUSTON and LONDON, July 22, 2025 (GLOBE NEWSWIRE) — Baker Hughes Company (Nasdaq: BKR) (“Baker Hughes” or the “Company”) announced results today for the second quarter of 2025.

    “We delivered strong second-quarter results, with total adjusted EBITDA margins increasing 170 basis points year-over-year to 17.5% despite a modest decline in revenue. This performance reflects the benefits of structural cost improvements and continued deployment of our business system, which is driving higher productivity, stronger operating leverage and more durable earnings across the company,” said Lorenzo Simonelli, Baker Hughes Chairman and Chief Executive Officer.

    “IET orders totaled $3.5 billion in the quarter, resulting in another record backlog for the segment. Importantly, order momentum remained strong, supported by more than $550 million of data center related orders, despite the absence of large LNG awards. Following a strong first half and a positive outlook for second half awards, we are confident of achieving the full-year order guidance range for IET.”

    “We remain confident in our ability to deliver solid performance in 2025, with continued growth in IET helping to offset softness in more market-sensitive areas of OFSE – underscoring the strength of our portfolio and the benefits of our strategic diversification. Accordingly, we are raising our full-year revenue and EBITDA guidance for IET and reestablishing full-year guidance for OFSE.”

    “During the quarter, we also announced three strategic transactions to advance our portfolio optimization strategy, reinforcing efforts to enhance the durability of earnings and cash flow while creating long-term value for shareholders. These actions are designed to unlock value from non-core businesses in our portfolio and redeploy that capital into higher-margin opportunities that fit our financial and strategic frameworks.”

    “We are progressing with our strategy of positioning the company for sustainable, differentiated growth and commend the focus and dedication of our people in executing this strategy,” concluded Simonelli.

    * Non-GAAP measure. See reconciliations in the section titled “Reconciliation of GAAP to non-GAAP Financial Measures.”

        Three Months Ended   Variance
    (in millions except per share amounts)   June 30, 2025 March 31, 2025 June 30, 2024   Sequential Year-over-year
    Orders   $ 7,032   $ 6,459   $ 7,526     9 % (7 %)
    Revenue     6,910     6,427     7,139     8 % (3 %)
    Net income attributable to Baker Hughes     701     402     579     74 % 21 %
    Adjusted net income attributable to Baker Hughes*     623     509     568     22 % 10 %
    Adjusted EBITDA*     1,212     1,037     1,130     17 % 7 %
    Diluted earnings per share (EPS)     0.71     0.40     0.58     76 % 22 %
    Adjusted diluted EPS*     0.63     0.51     0.57     23 % 11 %
    Cash flow from operating activities     510     709     348     (28 %) 47 %
    Free cash flow*     239     454     106     (47 %) F


    * Non-GAAP measure. See reconciliations in the section titled “Reconciliation of GAAP to non-GAAP Financial Measures.”

    Certain columns and rows in our tables and financial statements may not sum up due to the use of rounded numbers.

    “F” is used in most instances when variance is above 100%. Additionally, “U” is used when variance is below (100)%.

    Quarter Highlights

    Executing our portfolio optimization strategy

    In the second quarter, Baker Hughes announced three strategic transactions, all of which reflect a disciplined capital allocation framework and a focus on core businesses with strong return potential.

    First, the Company signed an agreement to form a joint venture with a subsidiary of Cactus, Inc., contributing the Oilfield Services & Equipment’s (OFSE) Surface Pressure Control (SPC) product line in exchange for approximately $345 million while maintaining a minority ownership stake.

    Second, the Company announced an agreement to sell the Precision Sensors & Instrumentation (PSI) product line within Industrial & Energy Technology (IET) to Crane Company for approximately $1.15 billion. These proceeds will enhance the Company’s flexibility to reinvest in higher-growth, higher-return areas that support further margin expansion and improved returns.

    Finally, Baker Hughes agreed to acquire Continental Disc Corporation (CDC), a leading provider of pressure management solutions, for approximately $540 million. The CDC acquisition strengthens the IET Industrial Products portfolio with a highly complementary, margin-accretive business that expands the Company’s position in the flow and pressure control market and enhances recurring, lifecycle driven revenue.

    Key awards and technology achievements

    The Company continued to support the development of critical data center projects, with year-to-date data center awards of more than $650 million. IET received an award to supply 30 NovaLT™ turbines, representing our largest data center award to-date. The turbines, alongside other associated Baker Hughes equipment, will deliver up to 500 megawatts (MW) of reliable and efficient power for data center development across various U.S. locations.

    Frontier Infrastructure awarded a contract for NovaLT™ turbines, delivering up to 270 MW of power for its data center projects in Wyoming and Texas. This follows the March 2025 enterprise-wide agreement to accelerate large scale carbon capture and storage (CCS) and power solutions.

    Baker Hughes continues to grow the pipeline of future data center opportunities. At the Saudi-U.S. Investment Forum in May, the Company signed an MoU with DataVolt that plans to power data centers globally, including the NEOM project in the Kingdom that intends to utilize Baker Hughes’ multi-fuel NovaLT™ technology solution.

    In addition to growing demand from data center applications, IET experienced increased demand for NovaLT™ turbines in the gas infrastructure sector. During the second quarter, the segment secured an award for four gas turbines to support Aramco’s Master Gas System III pipeline project. Including this award, we have secured a total of $2.9 billion in gas infrastructure equipment orders over the past six quarters.

    Highlighting the durability of IET’s lifecycle model, the segment was awarded several aftermarket services contracts. In Gas Technology Services (GTS), the Company secured more than $350 million of Contractual Services Agreements (CSA) during the quarter. We signed a maintenance agreement with Belayim Petroleum Company (“Petrobel”) to improve uptime and reliability of critical turbomachinery equipment in Egypt. Also in GTS, we renewed a multi-year service agreement with Oman LNG, including resident engineering support along with digital remote monitoring and diagnostics services delivered through iCenter™.

    The Company gained further traction with New Energy globally, with year-to-date bookings now totaling $1.25 billion. In Climate Technology Solutions (CTS), we secured one of our largest CCS orders to-date, providing compression technology for a CCS hub in the Middle East. Also in CTS, we signed a framework agreement with Energinet in Denmark to supply 16 reciprocating compressor packages, supporting an increase in biogas production while driving methane and CO2 emissions reduction for gas infrastructure across the country.

    Industrial Technology continued to demonstrate strong momentum across multiple end markets. In Industrial Solutions, we secured a variety of awards for our Cordant™ suite of solutions. This includes an award from a large NOC to deploy Asset Performance Management across several compression stations in the Middle East, and an award from NOVA Chemicals to optimize maintenance spend and maximize production.

    OFSE maintained strong momentum in Mature Assets Solutions around the globe. In Angola, OFSE was awarded multi-year production solutions contracts for chemicals, artificial lift, and digital services to support a major operator’s offshore activities. In Kazakhstan, the TOPAN and Baker Hughes joint venture secured a critical production chemicals and services award. In Norway, Equinor awarded OFSE a contract to industrialize offshore plug and abandonment (P&A) operations in the Oseberg East field, which followed the announcement of a multi-year P&A framework agreement for integrated well services.

    OFSE saw continued adoption of Leucipa™ automated field production solution, securing an award from Repsol for next-generation AI capabilities following the MoU signed in October 2024. The Company also signed an agreement with ENI to deploy Leucipa for electric submersible pumps (ESP) optimization and AI-powered predictive failure analytics in the Middle East.

    Also in the Middle East, Baker Hughes signed a master services agreement with Aramco for installation and maintenance of ESPs across the Kingdom of Saudi Arabia.

    In North America, OFSE secured a multi-year contract to provide drag reducing chemicals to be deployed on Genesis Energy’s Cameron Highway Oil Pipeline and Poseidon systems, each of which is operated and 64% owned by Genesis Energy. To support this agreement, OFSE will expand its chemicals manufacturing footprint and deploy Leucipa. Additionally, bp awarded OFSE a multi-year chemicals management services contract to optimize throughput and asset reliability in the U.S. Gulf Coast.

    In Germany, OFSE successfully drilled Lower Saxony’s first productive deep geothermal exploration well, a project that leverages OFSE’s integrated well construction and production capabilities and the Company’s industry-leading subsurface-to-surface digital solutions to monitor and optimize operational performance.

    Consolidated Financial Results

    Revenue for the quarter was $6,910 million, an increase of 8% sequentially and down $229 million year-over-year. The decrease in revenue year-over-year was driven by a decrease in OFSE partially offset by an increase in IET.

    The Company’s total book-to-bill ratio in the second quarter of 2025 was 1.0; the IET book-to-bill ratio was 1.1.

    Net income as determined in accordance with accounting principles generally accepted in the United States of America (“GAAP”) for the second quarter of 2025 was $701 million. Net income increased $299 million sequentially and increased $122 million year-over-year.

    Adjusted net income (a non-GAAP financial measure) for the second quarter of 2025 was $623 million, which excludes adjustments totaling $78 million. A list of the adjusting items and associated reconciliation from GAAP has been provided in Table 1b in the section titled “Reconciliation of GAAP to non-GAAP Financial Measures.” Adjusted net income for the second quarter of 2025 was up 22% sequentially and up 10% year-over-year.

    Depreciation and amortization for the second quarter of 2025 was $293 million.

    Adjusted EBITDA (a non-GAAP financial measure) for the second quarter of 2025 was $1,212 million, which excludes adjustments totaling $102 million. See Table 1a in the section titled “Reconciliation of GAAP to non-GAAP Financial Measures.” Adjusted EBITDA for the second quarter was up 17% sequentially and up 7% year-over-year.

    The sequential increase in adjusted net income and adjusted EBITDA was primarily driven by an increase in volume, favorable FX, and overall productivity. The year-over-year increase in adjusted net income and adjusted EBITDA was driven by productivity and structural cost out initiatives, favorable FX, partially offset by lower volume in OFSE, and cost inflation in both segments.

    Other Financial Items

    Remaining Performance Obligations (“RPO”) in the second quarter of 2025 ended at $34 billion, an increase of $0.8 billion from the first quarter of 2025. OFSE RPO was $2.7 billion, down 3% sequentially, while IET RPO was $31.3 billion, up 3% sequentially. Within IET RPO, GTE RPO was $11.3 billion, and GTS RPO was $15.6 billion.

    Income tax expense in the second quarter of 2025 was $256 million.

    Other (income) expense, net in the second quarter of 2025 was $(134) million, primarily related to changes in fair value for equity securities of $(119) million.

    GAAP diluted earnings per share was $0.71. Adjusted diluted earnings per share (a non-GAAP financial measure) was $0.63. Excluded from adjusted diluted earnings per share were all items listed in Table 1b in the section titled “Reconciliation of GAAP to non-GAAP Financial Measures.”

    Cash flow from operating activities was $510 million for the second quarter of 2025. Free cash flow (a non-GAAP financial measure) for the quarter was $239 million. A reconciliation from GAAP has been provided in Table 1c in the section titled “Reconciliation of GAAP to non-GAAP Financial Measures.”

    Capital expenditures, net of proceeds from disposal of assets, were $271 million for the second quarter of 2025, of which $184 million was for OFSE and $68 million was for IET.

    Results by Reporting Segment

    The following segment discussions and variance explanations are intended to reflect management’s view of the relevant comparisons of financial results on a sequential or year-over-year basis, depending on the business dynamics of the reporting segments.

    Oilfield Services & Equipment

    (in millions)   Three Months Ended   Variance
    Segment results   June 30, 2025 March 31, 2025 June 30, 2024   Sequential Year-over-year
    Orders   $ 3,503   $ 3,281   $ 4,068     7 % (14 %)
    Revenue   $ 3,617   $ 3,499   $ 4,011     3 % (10 %)
    EBITDA   $ 677   $ 623   $ 716     9 % (5 %)
    EBITDA margin     18.7 %   17.8 %   17.8 %   0.9pts 0.9pts
    (in millions)   Three Months Ended   Variance
    Revenue by Product Line   June 30, 2025 March 31, 2025 June 30, 2024   Sequential Year-over-year
    Well Construction   $ 921   $ 892   $ 1,090     3 % (16 %)
    Completions, Intervention, and Measurements     935     925     1,118     1 % (16 %)
    Production Solutions     968     899     958     8 % 1 %
    Subsea & Surface Pressure Systems     793     782     845     1 % (6 %)
    Total Revenue   $ 3,617   $ 3,499   $ 4,011     3 % (10 %)
    (in millions)   Three Months Ended   Variance
    Revenue by Geographic Region   June 30, 2025 March 31, 2025 June 30, 2024   Sequential Year-over-year
    North America   $ 928   $ 922   $ 1,023     1 % (9 %)
    Latin America     639     568     663     12 % (4 %)
    Europe/CIS/Sub-Saharan Africa     653     580     827     13 % (21 %)
    Middle East/Asia     1,398     1,429     1,498     (2 %) (7 %)
    Total Revenue   $ 3,617   $ 3,499   $ 4,011     3 % (10 %)
                   
    North America   $ 928   $ 922   $ 1,023     1 % (9 %)
    International   $ 2,689   $ 2,577   $ 2,988     4 % (10 %)


    EBITDA excludes depreciation and amortization of
    $233 million, $226 million, and $223 million for the three months ended June 30, 2025, March 31, 2025, and June 30, 2024, respectively. EBITDA margin is defined as EBITDA divided by revenue.

    OFSE orders of $3,503 million for the second quarter of 2025 increased by 7% sequentially. Subsea and Surface Pressure Systems orders were $698 million, up 31% sequentially, and down 21% year-over-year.

    OFSE revenue of $3,617 million for the second quarter of 2025 was up 3% sequentially, and down 10% year-over-year.

    North America revenue was $928 million, up 1% sequentially. International revenue was $2,689 million, up 4% sequentially, with increase in all regions with the exception of Middle East and Asia.

    Segment EBITDA for the second quarter of 2025 was $677 million, an increase of $54 million, or 9% sequentially. The sequential increase in EBITDA was primarily driven by productivity, structural cost-out initiatives, volume increase, partially offset by inflation and revenue mix.

    Industrial & Energy Technology

    (in millions)   Three Months Ended   Variance
    Segment results   June 30, 2025 March 31, 2025 June 30, 2024   Sequential Year-over-year
    Orders   $ 3,530   $ 3,178   $ 3,458     11 % 2 %
    Revenue   $ 3,293   $ 2,928   $ 3,128     12 % 5 %
    EBITDA   $ 585   $ 501   $ 497     17 % 18 %
    EBITDA margin     17.8 %   17.1 %   15.9 %   0.7pts 1.9pts
    (in millions)   Three Months Ended   Variance
    Orders by Product Line   June 30, 2025 March 31, 2025 June 30, 2024   Sequential Year-over-year
    Gas Technology Equipment   $ 781   $ 1,335   $ 1,493     (42 %) (48 %)
    Gas Technology Services     986     913     769     8 % 28 %
    Total Gas Technology     1,767     2,248     2,261     (21 %) (22 %)
    Industrial Products     513     501     524     2 % (2 %)
    Industrial Solutions     327     281     281     16 % 16 %
    Total Industrial Technology     839     782     805     7 % 4 %
    Climate Technology Solutions     923     148     392     F F
    Total Orders   $ 3,530   $ 3,178   $ 3,458     11 % 2 %
    (in millions)   Three Months Ended   Variance
    Revenue by Product Line   June 30, 2025 March 31, 2025 June 30, 2024   Sequential Year-over-year
    Gas Technology Equipment   $ 1,624   $ 1,456   $ 1,539     12 % 6 %
    Gas Technology Services     752     592     691     27 % 9 %
    Total Gas Technology     2,377     2,047     2,230     16 % 7 %
    Industrial Products     488     445     509     10 % (4 %)
    Industrial Solutions     273     258     262     6 % 4 %
    Total Industrial Technology     761     703     770     8 % (1 %)
    Climate Technology Solutions     156     178     128     (12 %) 22 %
    Total Revenue   $ 3,293   $ 2,928   $ 3,128     12 % 5 %


    EBITDA excludes depreciation and amortization of
    $56 million, $53 million, and $55 million for the three months ended June 30, 2025, March 31, 2025, and June 30, 2024, respectively. EBITDA margin is defined as EBITDA divided by revenue.

    “F” is used in most instances when variance is above 100%. Additionally, “U” is used when variance is below (100)%.

    IET orders of $3,530 million for the second quarter of 2025 increased by $72 million, or 2% year-over-year. The increase was driven primarily by Climate Technology Solutions and partially offset by Gas Technology.

    IET revenue of $3,293 million for the second quarter of 2025 increased $165 million, or 5% year-over-year. The increase was driven by Gas Technology Equipment, up $85 million or 6% year-over-year, Gas Technology Services, up $61 million or 9% year-over-year, and Climate Technology Solutions, up $28 million or 22% year-over-year.

    Segment EBITDA for the quarter was $585 million, an increase of $88 million, or 18% year-over-year. The year-over-year increase in segment EBITDA was driven by positive pricing, favorable FX, and productivity, partially offset by cost inflation.

    Reconciliation of GAAP to non-GAAP Financial Measures

    Management provides non-GAAP financial measures because it believes such measures are widely accepted financial indicators used by investors and analysts to analyze and compare companies on the basis of operating performance (including adjusted EBITDA; adjusted net income attributable to Baker Hughes; and adjusted diluted earnings per share) and liquidity (free cash flow) and that these measures may be used by investors to make informed investment decisions. Management believes that the exclusion of certain identified items from several key operating performance measures enables us to evaluate our operations more effectively, to identify underlying trends in the business, and to establish operational goals for certain management compensation purposes. Management also believes that free cash flow is an important supplemental measure of our cash performance but should not be considered as a measure of residual cash flow available for discretionary purposes, or as an alternative to cash flow from operating activities presented in accordance with GAAP.

    Table 1a. Reconciliation of Net Income Attributable to Baker Hughes to Adjusted EBITDA and Segment EBITDA

        Three Months Ended
    (in millions)   June 30, 2025 March 31, 2025 June 30, 2024
    Net income attributable to Baker Hughes (GAAP)   $ 701   $ 402   $ 579  
    Net income attributable to noncontrolling interests     10     7     2  
    Provision for income taxes     256     152     243  
    Interest expense, net     54     51     47  
    Depreciation & amortization     293     285     283  
    Change in fair value of equity securities (1)     (119 )   140     (19 )
    Other charges and credits (1)     17         (6 )
    Adjusted EBITDA (non-GAAP)     1,212     1,037     1,130  
    Corporate costs     78     85     83  
    Other (income) / expense not allocated to segments     (28 )   1      
    Total Segment EBITDA (non-GAAP)   $ 1,262   $ 1,124   $ 1,213  
    OFSE     677     623     716  
    IET     585     501     497  


    (1) 
    Change in fair value of equity securities and other charges and credits are reported in “Other (income) expense, net” on the condensed consolidated statements of income (loss).

    Table 1a reconciles net income attributable to Baker Hughes, which is the directly comparable financial result determined in accordance with GAAP, to adjusted EBITDA and Segment EBITDA. Adjusted EBITDA and Segment EBITDA exclude the impact of certain identified items.

    Table 1b. Reconciliation of Net Income Attributable to Baker Hughes to Adjusted Net Income Attributable to Baker Hughes

        Three Months Ended
    (in millions, except per share amounts)   June 30, 2025 March 31, 2025 June 30, 2024
    Net income attributable to Baker Hughes (GAAP)   $ 701   $ 402   $ 579  
    Change in fair value of equity securities     (119 )   140     (19 )
    Other adjustments     17         14  
    Tax adjustments(1)     24     (32 )   (6 )
    Total adjustments, net of income tax     (78 )   108     (11 )
    Less: adjustments attributable to noncontrolling interests              
    Adjustments attributable to Baker Hughes     (78 )   108     (11 )
    Adjusted net income attributable to Baker Hughes (non-GAAP)   $ 623   $ 509   $ 568  
             
    Denominator:        
    Weighted-average shares of Class A common stock outstanding diluted     991     999     1,001  
    Adjusted earnings per share – diluted (non-GAAP)   $ 0.63   $ 0.51   $ 0.57  


    (1) 
    All periods reflect the tax associated with the other (income) loss adjustments.

    Table 1b reconciles net income attributable to Baker Hughes, which is the directly comparable financial result determined in accordance with GAAP, to adjusted net income attributable to Baker Hughes. Adjusted net income attributable to Baker Hughes excludes the impact of certain identified items.

    Table 1c. Reconciliation of Net Cash Flows from Operating Activities to Free Cash Flow

        Three Months Ended
    (in millions)   June 30, 2025 March 31, 2025 June 30, 2024
    Net cash flows from operating activities (GAAP)   $ 510   $ 709   $ 348  
    Add: cash used for capital expenditures, net of proceeds from disposal of assets     (271 )   (255 )   (242 )
    Free cash flow (non-GAAP)   $ 239   $ 454   $ 106  

    Table 1c reconciles net cash flows from operating activities, which is the directly comparable financial result determined in accordance with GAAP, to free cash flow. Free cash flow is defined as net cash flows from operating activities less expenditures for capital assets plus proceeds from disposal of assets.


    Financial Tables (GAAP)

    Condensed Consolidated Statements of Income (Loss)
    (Unaudited)
     
        Three Months Ended June 30, Six Months Ended June 30,
    (In millions, except per share amounts)     2025     2024     2025     2024  
    Revenue   $ 6,910   $ 7,139   $ 13,337   $ 13,557  
    Costs and expenses:          
    Cost of revenue     5,295     5,493     10,247     10,469  
    Selling, general and administrative     567     643     1,144     1,261  
    Research and development costs     161     158     307     322  
    Other (income) expense, net     (134 )   (26 )   6     (48 )
    Interest expense, net     54     47     105     88  
    Income before income taxes     967     824     1,528     1,465  
    Provision for income taxes     (256 )   (243 )   (408 )   (421 )
    Net income     711     581     1,120     1,044  
    Less: Net income attributable to noncontrolling interests     10     2     17     10  
    Net income attributable to Baker Hughes Company   $ 701   $ 579   $ 1,103   $ 1,034  
               
    Per share amounts:      
    Basic income per Class A common stock   $ 0.71   $ 0.58   $ 1.11   $ 1.04  
    Diluted income per Class A common stock   $ 0.71   $ 0.58   $ 1.11   $ 1.03  
               
    Weighted average shares:          
    Class A basic     988     996     990     997  
    Class A diluted     991     1,001     995     1,002  
               
    Cash dividend per Class A common stock   $ 0.23   $ 0.21   $ 0.46   $ 0.42  
    Condensed Consolidated Statements of Financial Position
    (Unaudited)
     
    (In millions)   June 30, 2025 December 31, 2024
    ASSETS
    Current Assets:      
    Cash and cash equivalents   $ 3,087   $ 3,364  
    Current receivables, net     6,511     7,122  
    Inventories, net     5,105     4,954  
    All other current assets     2,915     1,771  
    Total current assets     17,618     17,211  
    Property, plant and equipment, less accumulated depreciation     5,176     5,127  
    Goodwill     5,801     6,078  
    Other intangible assets, net     3,919     3,951  
    Contract and other deferred assets     1,841     1,730  
    All other assets     4,385     4,266  
    Total assets   $ 38,740   $ 38,363  
    LIABILITIES AND EQUITY
    Current Liabilities:      
    Accounts payable   $ 4,340   $ 4,542  
    Short-term debt     66     53  
    Progress collections and deferred income     5,680     5,672  
    All other current liabilities     2,429     2,724  
    Total current liabilities     12,515     12,991  
    Long-term debt     5,968     5,970  
    Liabilities for pensions and other postretirement benefits     997     988  
    All other liabilities     1,392     1,359  
    Equity     17,868     17,055  
    Total liabilities and equity   $ 38,740   $ 38,363  
           
    Outstanding Baker Hughes Company shares:      
    Class A common stock     985     990  
    Condensed Consolidated Statements of Cash Flows
    (Unaudited)
     
        Three Months Ended June 30, Six Months Ended June 30,
    (In millions)     2025     2025     2024  
    Cash flows from operating activities:        
    Net income   $ 711   $ 1,120   $ 1,044  
    Adjustments to reconcile net income to net cash flows from operating activities:        
    Depreciation and amortization     293     579     566  
    Stock-based compensation cost     52     102     101  
    Change in fair value of equity securities     (119 )   21     (71 )
    (Benefit) provision for deferred income taxes     36     (17 )   33  
    Working capital     (120 )   98     (36 )
    Other operating items, net     (343 )   (684 )   (505 )
    Net cash flows provided by operating activities     510     1,219     1,132  
    Cash flows from investing activities:        
    Expenditures for capital assets     (301 )   (601 )   (625 )
    Proceeds from disposal of assets     30     74     101  
    Other investing items, net     (15 )   (69 )   (6 )
    Net cash flows used in investing activities     (286 )   (596 )   (530 )
    Cash flows from financing activities:        
    Repayment of long-term debt             (125 )
    Dividends paid     (227 )   (456 )   (419 )
    Repurchase of Class A common stock     (196 )   (384 )   (324 )
    Other financing items, net     (20 )   (105 )   (61 )
    Net cash flows used in financing activities     (443 )   (945 )   (929 )
    Effect of currency exchange rate changes on cash and cash equivalents     29     45     (35 )
    Decrease in cash and cash equivalents     (190 )   (277 )   (362 )
    Cash and cash equivalents, beginning of period     3,277     3,364     2,646  
    Cash and cash equivalents, end of period   $ 3,087   $ 3,087   $ 2,284  
    Supplemental cash flows disclosures:        
    Income taxes paid, net of refunds   $ 211   $ 418   $ 336  
    Interest paid   $ 98   $ 148   $ 150  


    Supplemental Financial Information

    Supplemental financial information can be found on the Company’s website at: investors.bakerhughes.com in the Financial Information section under Quarterly Results.

    Conference Call and Webcast

    The Company has scheduled an investor conference call to discuss management’s outlook and the results reported in today’s earnings announcement. The call will begin at 9:30 a.m. Eastern time, 8:30 a.m. Central time on Wednesday, July 23, 2025, the content of which is not part of this earnings release. The conference call will be broadcast live via a webcast and can be accessed by visiting the Events and Presentations page on the Company’s website at: investors.bakerhughes.com. An archived version of the webcast will be available on the website for one month following the webcast.

    Forward-Looking Statements

    This news release (and oral statements made regarding the subjects of this release) may contain forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended, (each a “forward-looking statement”). Forward-looking statements concern future circumstances and results and other statements that are not historical facts and are sometimes identified by the words “may,” “will,” “should,” “potential,” “intend,” “expect,” “would,” “seek,” “anticipate,” “estimate,” “overestimate,” “underestimate,” “believe,” “could,” “project,” “predict,” “continue,” “target,” “goal” or other similar words or expressions. There are many risks and uncertainties that could cause actual results to differ materially from our forward-looking statements. These forward-looking statements are also affected by the risk factors described in the Company’s annual report on Form 10-K for the annual period ended December 31, 2024 and those set forth from time to time in other filings with the Securities and Exchange Commission (“SEC”). The documents are available through the Company’s website at: www.investors.bakerhughes.com or through the SEC’s Electronic Data Gathering and Analysis Retrieval system at: www.sec.gov. We undertake no obligation to publicly update or revise any forward-looking statement, except as required by law. Readers are cautioned not to place undue reliance on any of these forward-looking statements.

    Our expectations regarding our business outlook and business plans; the business plans of our customers; oil and natural gas market conditions; cost and availability of resources; economic, legal and regulatory conditions, and other matters are only our forecasts regarding these matters.

    These forward-looking statements, including forecasts, may be substantially different from actual results, which are affected by many risks, along with the following risk factors and the timing of any of these risk factors:

    • Economic and political conditions – the impact of worldwide economic conditions and rising inflation; the impact of tariffs and the potential for significant increases thereto; the impact of global trade policy and the potential for significant changes thereto; the effect that declines in credit availability may have on worldwide economic growth and demand for hydrocarbons; foreign currency exchange fluctuations and changes in the capital markets in locations where we operate; and the impact of government disruptions and sanctions.
    • Orders and RPO – our ability to execute on orders and RPO in accordance with agreed specifications, terms and conditions and convert those orders and RPO to revenue and cash.
    • Oil and gas market conditions – the level of petroleum industry exploration, development and production expenditures; the price of, volatility in pricing of, and the demand for crude oil and natural gas; drilling activity; drilling permits for and regulation of the shelf and the deepwater drilling; excess productive capacity; crude and product inventories; liquefied natural gas supply and demand; seasonal and other adverse weather conditions that affect the demand for energy; severe weather conditions, such as tornadoes and hurricanes, that affect exploration and production activities; Organization of Petroleum Exporting Countries (“OPEC”) policy and the adherence by OPEC nations to their OPEC production quotas.
    • Terrorism and geopolitical risks – war, military action, terrorist activities or extended periods of international conflict, particularly involving any petroleum-producing or consuming regions, including Russia and Ukraine; and the recent conflict in the Middle East; labor disruptions, civil unrest or security conditions where we operate; potentially burdensome taxation, expropriation of assets by governmental action; cybersecurity risks and cyber incidents or attacks; epidemic outbreaks.

    About Baker Hughes:

    Baker Hughes (Nasdaq: BKR) is an energy technology company that provides solutions to energy and industrial customers worldwide. Built on a century of experience and conducting business in over 120 countries, our innovative technologies and services are taking energy forward – making it safer, cleaner and more efficient for people and the planet. Visit us at bakerhughes.com.

    For more information, please contact:

    Investor Relations

    Chase Mulvehill
    +1 346-297-2561
    investor.relations@bakerhughes.com

    Media Relations

    Adrienne M. Lynch
    +1 713-906-8407
    adrienne.lynch@bakerhughes.com

    The MIL Network

  • MIL-OSI: Weatherford Announces Second Quarter 2025 Results

    Source: GlobeNewswire (MIL-OSI)

    • Second quarter revenue of $1,204 million increased 1% sequentially
    • Second quarter operating income of $237 million increased 67% sequentially
    • Second quarter net income of $136 million increased 79% sequentially; net income margin of 11.3%
    • Second quarter adjusted EBITDA* of $254 million was flat sequentially; adjusted EBITDA margin* of 21.1% decreased 11 basis points sequentially
    • Second quarter cash provided by operating activities of $128 million and adjusted free cash flow* of $79 million
    • Repurchased $27 million of 8.625% Senior Notes due 2030 in the second quarter of 2025
    • Shareholder return of $52 million for the quarter, which included dividend payments of $18 million and share repurchases of $34 million
    • Board approved quarterly cash dividend of $0.25 per share, payable on September 4, 2025, to shareholders of record as of August 6, 2025
    • Signed an agreement with Amazon Web Services to migrate and modernize our digital platforms, including the Modern Edge Platform and Unified Data Model, enhancing operational efficiency and data-driven decision-making. The collaboration also boosts Weatherford’s Software Launchpad, offering scalable, cloud-based solutions while ensuring data control and integration flexibility

    *Non-GAAP – refer to the section titled Non-GAAP Financial Measures Defined and GAAP to Non-GAAP Financial Measures Reconciled

    HOUSTON, July 22, 2025 (GLOBE NEWSWIRE) — Weatherford International plc (NASDAQ: WFRD) (“Weatherford” or the “Company”) announced today its results for the second quarter of 2025.

    Revenues for the second quarter of 2025 were $1,204 million, an increase of 1% sequentially and a decrease of 14% year-over-year. Operating income in the second quarter of 2025 was $237 million, an increase of 67% sequentially and a decrease of 10% year-over-year. Net income in the second quarter of 2025 was $136 million, with a 11.3% margin, an increase of 79%, or 493 basis points, sequentially, and an increase of 9%, or 240 basis points, year-over-year. Adjusted EBITDA* was $254 million, with a 21.1% margin, flat, or a decrease of 11 basis points, sequentially, and a decrease of 30%, or 488 basis points, year-over-year. Basic income per share in the second quarter of 2025 was $1.87, an increase of 81% sequentially and an increase of 10% year-over-year. Diluted income per share in the second quarter of 2025 was $1.87, an increase of 81% sequentially and an increase of 13% year-over-year.

    Second quarter 2025 cash flows provided by operating activities were $128 million, a decrease of 10% sequentially and a decrease of 15% year-over-year. Adjusted free cash flow* was $79 million, an increase of 20% sequentially and a decrease of 18% year-over-year. Capital expenditures were $54 million in the second quarter of 2025, a decrease of 30% sequentially and a decrease of 13% year-over-year.

    Girish Saligram, President and Chief Executive Officer, commented, “Our core operating markets continued to exhibit activity slowdown during the quarter, driven by geopolitical events, supply-demand imbalance concerns, and trade uncertainties. Despite these structural headwinds, the One Weatherford team delivered second-quarter results in line with expectations, reflecting disciplined execution and operational efficiency in a distinctly softer market. The sequential performance demonstrates strong fundamentals and the resilience of our operating model. Revenues increased and adjusted EBITDA was flat despite the previously announced divestiture of certain businesses in Argentina. Adjusted Free Cash Flow also increased, even as receivables continued to build in Latin America due to lack of payments in Mexico. This performance underscores the strength of the new Weatherford operating paradigm and marks a positive departure from past responses to prior market cycle inflections.

    Looking ahead, activity levels in both North America and international markets continue to show signs of sluggishness, and expectations for a broader sector recovery have shifted further to the right. While we anticipate a relatively flat trajectory on revenues for the immediate future, we remain focused on driving adjusted free cash flow conversion through portfolio optimization, structural cost efficiencies, optimization of working capital, and CAPEX efficiency.”

    *Non-GAAP – refer to the section titled Non-GAAP Financial Measures Defined and GAAP to Non-GAAP Financial Measures Reconciled

    Operational & Commercial Highlights

    • An International Oil Company (IOC) awarded Weatherford a three-year contract to provide Managed Pressure Drilling (MPD) services for a deepwater development project in Mexico.
    • Aramco awarded Weatherford a one-year contract extension to provide MPD services for its onshore and offshore wells.
    • Weatherford, with Superior Energy Services, secured a three-year contract to supply conventional completions (Upper and Lower) equipment to Petrobras for pre-salt and post-salt fields offshore Brazil.
    • Cairn Oil & Gas granted Weatherford a Letter of Award to provide Completions, Liner Hanger, Whipstock systems and services, and MPD services for High Temperature – Ultra High Temperature (HT-UHT) drilling and rigless project in Barmer, India.
    • bp UK awarded Weatherford a one-year contract to provide Cementation Products, Completions, Drilling Services, Intervention Services & Drilling Tools (ISDT), and a one-year contract to provide Liner Hanger systems for the Northern Endurance Partnership CO2 Storage Project in offshore UK.
    • Beach Energy Limited awarded Weatherford contracts to provide Cementation Products, Cement Heads, Liner Hangers, and Tubular Running Services (TRS) for a campaign in offshore Australia.
    • Origin Energy awarded Weatherford a five-year contract to re-supply PCP systems in onshore Australia.
    • OMV awarded Weatherford a three-year contract to supply Completions and Reservoir Monitoring equipment in Tunisia.
    • Shell awarded Weatherford a three-year contract to provide ISDT offshore in the Gulf of America.
    • An IOC awarded Weatherford a three-year contract to provide thru-tubing Well Services in offshore Malaysia.
    • Kuwait Oil Company (KOC) awarded Weatherford a contract for the supply of XpressTM XT Liner Hanger systems for deep drilling operations in Kuwait.
    • A National Oil Company in the Middle East awarded a two-year contract to provide thru-tubing and safety valve systems in the United Arab Emirates.
    • A major operator in Canada awarded Weatherford a two-year contract to provide Artificial Lift services in onshore Canada.
    • Weatherford, in strategic partnership with Constellation, secured a three-year contract to deliver TRS, integrating the automated Vero™ technology into their rig for Petrobras in offshore Brazil.

    Technology Highlights

    • Drilling & Evaluation (“DRE”)
      • In Kuwait, Weatherford successfully deployed combined Magnus™ and Victus™ solutions for a pilot project for KOC. This approach enabled the use of a smaller wellhead, eliminated one casing string, and allowed effective drilling and cementing through stacked reservoirs, potentially unlocking new completion designs and enhancing recovery.
      • In Qatar, Weatherford successfully completed the first Modus™ job using MPD techniques that significantly improved operational efficiency and well safety. The Modus system enabled the operator to reach the targeted total depth while saving substantial rig time and costs compared to conventional methods.
      • In Norway, Weatherford successfully completed three open hole logging jobs for an international operator using coiled tubing for deployment. This approach enabled effective logging in a highly deviated well, overcoming the limitations of conventional wireline conveyance.
    • Well Construction and Completions (“WCC”)
      • In the Gulf of America, Weatherford successfully integrated multiple TRS technologies for bp. This integration enhanced operational speed, cost-effectiveness, and well integrity while improving quality, efficiency, and safety by reducing personnel requirements and eliminating manual intervention.
      • In the United Kingdom, Weatherford successfully implemented StringGuardTM for Shell. The solution is designed to provide protection against potential dropped string events, with the aim of maintaining operational focus and incident free delivery.
    • Production and Intervention (“PRI”)
      • Weatherford’s Rotaflex® Artificial Lift technology has witnessed continued global adoption, with recent installations in France, Australia, and Oman. These projects have addressed a variety of operational challenges, including the replacement of Electric Submersible Pumps and conventional pumping units, enhancement of production efficiency, support for Coal Bed Methane initiatives, and restoration of output in complex wells, underscoring the versatility and effectiveness of the Rotaflex technology.
      • In Norway, Weatherford completed a successful field trial of TITAN RS technology for Equinor, following the acquisition of Ardyne. The trial delivered a full casing cut and recovery solution for the plug and abandonment market, reinforcing Weatherford’s leadership in advanced well abandonment.
      • In Saudi Arabia, Weatherford installed the first Rod Lift system in the Jafurah field. The unit was successfully commissioned, validating Weatherford’s Rod Lift technology as a viable artificial lift solution for this unconventional gas field.

    Shareholder Return

    During the second quarter of 2025, Weatherford paid dividends of $18 million and repurchased shares for approximately $34 million, resulting in a total shareholder return of $52 million. In the first half of the year, Weatherford paid dividends of $36 million and repurchased shares for approximately $87 million, resulting in a total shareholder return of $123 million.

    On July 17, 2025, our Board declared a cash dividend of $0.25 per share of the Company’s ordinary shares, payable on September 4, 2025, to shareholders of record as of August 6, 2025.

    Results by Reportable Segment

    Drilling and Evaluation (“DRE”)
      

        Three Months Ended   Variance
    ($ in Millions)   June 30,
    2025
      March 31,
    2025
      June 30,
    2024
      Seq.   YoY
    Revenue   $          335     $              350     $          427     (4)   %   (22)    %
    Segment Adjusted EBITDA   $            69     $                 74     $          130     (7)   %   (47)    %
    Segment Adj EBITDA Margin     20.6 %     21.1 %     30.4 %            (55) bps         (985) bps

    Second quarter 2025 DRE revenue of $335 million decreased by $15 million, or 4% sequentially, primarily from lower Wireline activity in North America and Latin America partly offset by higher Drilling Services activity in Europe/Sub-Sahara Africa/Russia and Latin America. Year-over-year DRE revenue decreased by $92 million, or 22%, primarily from lower activity across all geographies, especially in Latin America, partly offset by higher Drilling Services activity in Europe/Sub-Sahara Africa/ Russia, North America and Middle East/North Africa/Asia.

    Second quarter 2025 DRE segment adjusted EBITDA of $69 million decreased by $5 million, or 7% sequentially, primarily from lower Wireline activity, partly offset by higher Drilling Services activity. Year-over-year DRE segment adjusted EBITDA decreased by $61 million, or 47%, primarily from lower activity across all geographies, especially in Latin America.

    Well Construction and Completions (“WCC”)  

        Three Months Ended   Variance
    ($ in Millions)   June 30,
    2025
      March 31,
    2025
      June 30,
    2024
      Seq.   YoY
    Revenue   $          456     $              441     $          504     3 %   (10)   %
    Segment Adjusted EBITDA   $          118     $              128     $          145     (8) %   (19)   %
    Segment Adj EBITDA Margin     25.9 %     29.0 %     28.8 %         (315) bps          (289) bps

    Second quarter 2025 WCC revenue of $456 million increased by $15 million, or 3% sequentially, primarily from higher Liner Hangers and Cementation Products activity partly offset by lower Completions activity especially in Latin America.  Year-over-year WCC revenues decreased by $48 million, or 10%, primarily from lower activity in Latin America, Europe/Sub-Sahara Africa/Russia and North America partly offset by higher Liner Hangers activity in Middle East/North Africa/Asia.

    Second quarter 2025 WCC segment adjusted EBITDA of $118 million decreased by $10 million, or 8% sequentially, primarily from lower Completions activity partly offset by higher Liner Hangers activity and Cementation Products activity and fall through. Year-over-year WCC segment adjusted EBITDA decreased by $27 million, or 19%, primarily from lower activity in Latin America, Europe/Sub-Sahara Africa/Russia and North America partly offset by higher Liner Hangers and TRS fall through in Middle East/North Africa/Asia.

    Production and Intervention (“PRI”)  

        Three Months Ended   Variance
    ($ in Millions)   June 30,
    2025
      March 31,
    2025
      June 30,
    2024
      Seq.   YoY
    Revenue   $          327         $              334     $          369     (2)  %   (11)   %
    Segment Adjusted EBITDA   $            63         $                 62     $            85     2 %   (26)   %
    Segment Adj EBITDA Margin     19.3 %     18.6 %     23.0 %             70  bps          (377) bps

    Second quarter 2025 PRI revenue of $327 million  decreased by $7 million, or 2% sequentially, primarily from lower Pressure Pumping activity in Latin America pursuant to the sale of the Argentina Pressure Pumping business partly offset by higher Artificial Lift and Sub-sea Intervention activity. Year-over-year PRI revenue decreased by $42 million, or 11%, as lower activity across all geographies was partly offset by higher Sub-sea intervention activity in Latin America.

    Second quarter 2025 PRI segment adjusted EBITDA of $63 million increased by $1 million, or 2% sequentially, primarily from  higher Sub-sea Intervention activity and fall through partly offset by lower Pressure Pumping activity in Latin America pursuant to the sale of the Argentina Pressure Pumping business. Year-over-year PRI segment adjusted EBITDA decreased by $22 million, or 26%, primarily from lower activity across all geographies, partly offset by higher Sub-sea intervention activity and fall through in Latin America.

    Revenue by Geography 

        Three Months Ended   Variance
    ($ in Millions)   June 30,
    2025
      March 31,
    2025
      June 30,
    2024
      Seq.   YoY
    North America   $             241   $                  250   $             252   (4) %   (4) %
                         
    International   $             963   $                  943   $          1,153   2 %   (16) %
       Latin America                     195                        241                    353   (19) %   (45) %
       Middle East/North Africa/Asia                    524                        503                    542   4 %   (3) %
       Europe/Sub-Sahara Africa/Russia                    244                        199                    258   23 %   (5) %
    Total Revenue   $          1,204   $               1,193   $          1,405   1 %   (14) %


    North America

    Second quarter 2025 North America revenue of $241 million decreased by $9 million, or 4% sequentially, primarily from lower Wireline activity in Canada Land, partly offset by higher Cementation Products and Liner Hangers activity. Year-over-year, North America decreased by $11 million, or 4% , primarily from lower activity across all the segments, partly offset by higher activity in US Offshore.

    International

    Second quarter 2025 international revenue of $963 million increased by $20 million, or 2% sequentially and decreased by $190 million, or 16% year-over-year.

    Second quarter 2025 Latin America revenue of $195 million decreased by $46 million, or 19% sequentially, primarily from lower activity in Argentina pursuant to the sale of the Argentina Pressure Pumping business, partly offset by higher Sub-sea intervention activity. Year-over-year, Latin America revenue decreased by $158 million, or 45%, primarily from lower activity in Mexico and Argentina, partly offset by higher Sub-sea intervention activity.

    Second quarter 2025 Middle East/North Africa/Asia revenue of $524 million increased by $21 million, or 4% sequentially, primarily from higher Liner Hangers and Cementation Products activity partly offset by lower Drilling Services. Year-over-year, the Middle East/North Africa/Asia revenue decreased by $18 million, or 3%, primarily from lower activity in the DRE and PRI segments partly offset by higher Liner Hangers activity.

    Second quarter 2025 Europe/Sub-Sahara Africa/Russia revenue of $244 million increased by $45 million, or 23% sequentially, primarily from higher activity across all the segments. Year-over-year, Europe/Sub-Sahara Africa/Russia revenue decreased by $14 million, or 5%, primarily from lower activity across all the segments especially WCC, partly offset by higher Drilling Services and Pressure Pumping.

    About Weatherford
    Weatherford delivers innovative energy services that integrate proven technologies with advanced digitalization to create sustainable offerings for maximized value and return on investment. Our world-class experts partner with customers to optimize their resources and realize the full potential of their assets. Operators choose us for strategic solutions that add efficiency, flexibility, and responsibility to any energy operation. The Company conducts business in approximately 75 countries and has approximately 17,300 team members representing more than 110 nationalities and 310 operating locations. Visit weatherford.com for more information and connect with us on social media.

    Conference Call Details

    Weatherford will host a conference call on Wednesday, July 23, 2025, to discuss the Company’s results for the second quarter ended June 30, 2025. The conference call will begin at 8:30 a.m. Eastern Time (7:30 a.m. Central Time).

    Listeners are encouraged to download the accompanying presentation slides which will be available in the investor relations section of the Company’s website.

    Listeners can participate in the conference call via a live webcast at https://www.weatherford.com/investor-relations/investor-news-and-events/events/ or by dialing +1 877-328-5344 (within the U.S.) or +1 412-902-6762 (outside of the U.S.) and asking for the Weatherford conference call. Participants should log in or dial in approximately 10 minutes prior to the start of the call.

    A telephonic replay of the conference call will be available until August 6, 2025, at 5:00 p.m. Eastern Time. To access the replay, please dial +1 877-344-7529 (within the U.S.) or +1 412-317-0088 (outside of the U.S.) and reference conference number 1312926. A replay and transcript of the earnings call will also be available in the investor relations section of the Company’s website.

    Contacts
    For Investors:
    Luke Lemoine
    Senior Vice President, Corporate Development & Investor Relations
    +1 713-836-7777
    investor.relations@weatherford.com

    For Media:
    Kelley Hughes
    Senior Director, Communications & Employee Engagement
    media@weatherford.com

    Forward-Looking Statements

    This news release contains projections and forward-looking statements concerning, among other things, the Company’s adjusted EBITDA*, adjusted EBITDA margin*, adjusted free cash flow*, shareholder return program, forecasts or expectations regarding business outlook, prospects for its operations, capital expenditures, expectations regarding future financial results, and are also generally identified by the words “believe,” “project,” “expect,” “anticipate,” “estimate,” “outlook,” “budget,” “intend,” “strategy,” “plan,” “guidance,” “may,” “should,” “could,” “will,” “would,” “will be,” “will continue,” “will likely result,” and similar expressions, although not all forward-looking statements contain these identifying words. Such statements are based upon the current beliefs of Weatherford’s management and are subject to significant risks, assumptions, and uncertainties. Should one or more of these risks or uncertainties materialize, or underlying assumptions prove incorrect, actual results may vary materially from those indicated in our forward-looking statements. Readers are cautioned that forward-looking statements are only estimates and may differ materially from actual future events or results, based on factors including but not limited to: global political, economic and market conditions, political disturbances, war or other global conflicts, terrorist attacks, changes in global trade policies, tariffs and sanctions, weak local economic conditions and international currency fluctuations; general global economic repercussions related to U.S. and global inflationary pressures and potential recessionary concerns; various effects from conflicts in the Middle East and the Russia Ukraine conflicts, including, but not limited to, nationalization of assets, extended business interruptions, sanctions, treaties and regulations (including changes in the regulatory environment) imposed by various countries, associated operational and logistical challenges, and impacts to the overall global energy supply; cybersecurity issues; our ability to comply with, and respond to, climate change, environmental, social and governance and other sustainability initiatives and future legislative and regulatory measures both globally and in specific geographic regions; the potential for a resurgence of a pandemic in a given geographic area and related disruptions; the price and price volatility of, and demand for, oil and natural gas; the macroeconomic outlook for the oil and gas industry; our ability to generate cash flow from operations to fund our operations; our ability to effectively and timely adapt our technology portfolio, products and services to remain competitive, and to address and participate in changes to the market demands, including for the transition to alternate sources of energy such as geothermal, carbon capture and responsible abandonment, including our digitalization efforts, increases in the prices and lead times, and the lack of availability of our procured products and services, including due to macroeconomic and geopolitical conditions such as tariffs and changes in trade policies, our ability to timely collect from customers; our ability to effectively execute our capital allocation framework; our ability to return capital to shareholders, including those related to the timing and amounts (including any plans or commitments in respect thereof) of any dividends and share repurchases; and the realization of additional cost savings and operational efficiencies.

    These risks and uncertainties are more fully described in Weatherford’s reports and registration statements filed with the Securities and Exchange Commission, including the risk factors described in the Company’s Annual Report on Form 10-K and Quarterly Reports on Form 10-Q. Accordingly, you should not place undue reliance on any of the Company’s forward-looking statements. Any forward-looking statement speaks only as of the date on which such statement is made, and the Company undertakes no obligation to correct or update any forward-looking statement, whether as a result of new information, future events or otherwise, except as required by applicable law, and we caution you not to rely on them unduly.

    *Non-GAAP – refer to the section titled Non-GAAP Financial Measures Defined and GAAP to Non-GAAP Financial Measures Reconciled

    Weatherford International plc
    Selected Statements of Operations (Unaudited)
                         
        Three Months Ended   Six Months Ended
    ($ in Millions, Except Per Share Amounts)   June 30,
    2025
      March 31,
    2025
      June 30,
    2024
      June 30,
    2025
      June 30,
    2024
    Revenues:                    
    DRE Revenues   $              335     $                 350     $              427     $            685     $            849  
    WCC Revenues                    456                          441                      504                     897                    962  
    PRI Revenues                    327                          334                      369                     661                    717  
    All Other                       86                            68                      105                     154                    235  
    Total Revenues                 1,204                      1,193                   1,405                 2,397                 2,763  
                         
    Operating Income:                    
    DRE Segment Adjusted EBITDA[1]   $                69     $                    74     $              130     $            143     $            260  
    WCC Segment Adjusted EBITDA[1]                    118                          128                      145                     246                    265  
    PRI Segment Adjusted EBITDA[1]                       63                            62                        85                     125                    158  
    All Other[2]                       19                              4                        23                       23                       50  
    Corporate[2]                     (15 )                        (15 )                    (18 )                   (30 )                   (32 )
    Depreciation and Amortization                     (64 )                        (62 )                    (86 )                 (126 )                (171 )
    Share-based Compensation                       (9 )                          (7 )                    (12 )                   (16 )                   (25 )
    Gain on Sale of Business                       70                            —                        —                       70                       —  
    Restructuring Charges                     (11 )                        (29 )                       (5 )                   (40 )                     (8 )
    Other (Charges) Credits                       (3 )                        (13 )                        2                     (16 )                     —  
    Operating Income                    237                          142                      264                     379                    497  
                         
    Other Expense:                    
    Interest Expense, Net of Interest Income of $14, $11,
    $17, $25 and $31
                        (21 )                        (26 )                    (24 )                   (47 )                   (53 )
    Loss on Blue Chip Swap Securities                       (1 )                          —                      (10 )                     (1 )                   (10 )
    Other Expense, Net                     (24 )                        (20 )                    (20 )                   (44 )                 (42 )
    Income Before Income Taxes                    191                            96                      210                     287                    392  
    Income Tax Provision                     (46 )                        (10 )                    (73 )                   (56 )                (132 )
    Net Income                    145                            86                      137                     231                    260  
    Net Income Attributable to Noncontrolling Interests                         9                            10                        12                       19                       23  
    Net Income Attributable to Weatherford   $              136     $                    76     $              125     $            212     $            237  
                         
    Basic Income Per Share   $             1.87     $                1.04     $             1.71     $           2.91     $           3.25  
    Basic Weighted Average Shares Outstanding                   72.2                         73.1                     73.2                    72.7                   73.1  
                         
    Diluted Income Per Share   $             1.87     $                1.03     $             1.66     $           2.90     $           3.16  
    Diluted Weighted Average Shares Outstanding                   72.4                         73.4                     75.3       72.9       75.0  
    [1] Segment adjusted EBITDA is our primary measure of segment profitability under U.S. GAAP ASC 280 “Segment Reporting” and represents segment earnings before interest, taxes, depreciation, amortization, share-based compensation, restructuring charges and other adjustments. Research and development expenses are included in segment adjusted EBITDA.
    [2] All Other includes results from non-core business activities (including integrated services and projects), and Corporate includes overhead support and centrally managed or shared facilities costs. All Other and Corporate do not individually meet the criteria for segment reporting.
    Weatherford International plc
    Selected Balance Sheet Data (Unaudited)
           
    ($ in Millions) June 30, 2025   December 31, 2024
    Assets:      
    Cash and Cash Equivalents $                              943   $                                 916
    Restricted Cash                                     60                                         59
    Accounts Receivable, Net                               1,177                                    1,261
    Inventories, Net                                  881                                       880
    Property, Plant and Equipment, Net                               1,136                                    1,061
    Intangibles, Net                                  305                                       325
           
    Liabilities:      
    Accounts Payable                                  685                                       792
    Accrued Salaries and Benefits                                  252                                       302
    Current Portion of Long-term Debt                                     26                                         17
    Long-term Debt                               1,565                                    1,617
           
    Shareholders’ Equity:      
    Total Shareholders’ Equity                               1,519                                    1,283
    Weatherford International plc
    Selected Cash Flows Information (Unaudited)
                         
        Three Months Ended   Six Months Ended
    ($ in Millions)   June 30,
    2025
      March 31,
    2025
      June 30,
    2024
      June 30,
    2025
      June 30,
    2024
    Cash Flows From Operating Activities:                    
    Net Income   $             145     $                    86     $             137     $             231     $             260  
    Adjustments to Reconcile Net Income to Net Cash
    Provided By Operating Activities:
                       
    Depreciation and Amortization                      64                             62                        86                      126                      171  
    Foreign Exchange Losses                      17                             13                          8                        30                        23  
    Loss on Blue Chip Swap Securities                        1                             —                        10                          1                        10  
    Gain on Disposition of Assets                      (3 )                           (1 )                    (25 )                      (4 )                    (32 )
    Gain on Sale of Business                    (70 )                           —                        —                      (70 )                      —   
    Deferred Income Tax Provision (Benefit)                      (5 )                             7                        13                          2                        27  
    Share-Based Compensation                        9                               7                        12                        16                        25  
    Changes in Accounts Receivable, Inventory, Accounts
    Payable and Accrued Salaries and Benefits
                       (22 )                         (17 )                    (22 )                    (39 )                  (174 )
    Other Changes, Net                      (8 )                         (15 )                    (69 )                    (23 )                    (29 )
    Net Cash Provided By Operating Activities                    128                          142                      150                      270                      281  
                         
    Cash Flows From Investing Activities:                    
    Capital Expenditures for Property, Plant and Equipment                    (54 )                         (77 )                    (62 )                  (131 )                  (121 )
    Proceeds from Disposition of Assets                        5                               1                          8                          6                        18  
    Proceeds from Sale of Businesses                      97                             —                        —                        97                        —   
    Purchases of Blue Chip Swap Securities                    (83 )                           —                      (50 )                    (83 )                    (50 )
    Proceeds from Sales of Blue Chip Swap Securities                      82                             —                        40                        82                        40  
    Business Acquisitions, Net of Cash Acquired                      —                             —                        —                        —                       (36 )
    Proceeds from Sale of Investments                      —                             —                        —                        —                         41  
    Other Investing Activities                      (4 )                           (3 )                        3                        (7 )                      (7 )
    Net Cash Provided by (Used In) Investing Activities                      43                           (79 )                    (61 )                    (36 )                  (115 )
                         
    Cash Flows From Financing Activities:                    
    Repayments of Long-term Debt                    (34 )                         (39 )                    (87 )                    (73 )                  (259 )
       Distributions to Noncontrolling Interests                      (8 )                           —                        (9 )                      (8 )                      (9 )
    Tax Remittance on Equity Awards                      —                           (20 )                      (1 )                    (20 )                      (9 )
    Share Repurchases                    (34 )                         (53 )                      —                      (87 )                      —   
    Dividends Paid                    (18 )                         (18 )                      —                      (36 )                      —   
    Other Financing Activities                      (3 )                           (3 )                      (5 )                      (6 )                    (12 )
    Net Cash Used In Financing Activities   $              (97 )   $                (133 )   $           (102 )   $           (230 )   $           (289 )
    Weatherford International plc
    Non-GAAP Financial Measures Defined (Unaudited)

    We report our financial results in accordance with U.S. generally accepted accounting principles (GAAP). However, Weatherford’s management believes that certain non-GAAP financial measures (as defined under the SEC’s Regulation G and Item 10(e) of Regulation S-K) may provide users of this financial information additional meaningful comparisons between current results and results of prior periods and comparisons with peer companies. The non-GAAP amounts shown in the following tables should not be considered as substitutes for results reported in accordance with GAAP but should be viewed in addition to the Company’s reported results prepared in accordance with GAAP.

    Adjusted EBITDA* – Adjusted EBITDA* is a non-GAAP measure and represents consolidated income before interest expense, net, income taxes, depreciation and amortization expense, and excludes, among other items, restructuring charges, share-based compensation expense, as well as other charges and credits. Management believes adjusted EBITDA* is useful to assess and understand normalized operating performance and trends. Adjusted EBITDA* should be considered in addition to, but not as a substitute for consolidated net income and should be viewed in addition to the Company’s reported results prepared in accordance with GAAP.

    Adjusted EBITDA margin* – Adjusted EBITDA margin* is a non-GAAP measure which is calculated by dividing consolidated adjusted EBITDA* by consolidated revenues. Management believes adjusted EBITDA margin* is useful to assess and understand normalized operating performance and trends. Adjusted EBITDA margin* should be considered in addition to, but not as a substitute for consolidated net income margin and should be viewed in addition to the Company’s reported results prepared in accordance with GAAP.

    Adjusted Free Cash Flow* – Adjusted Free Cash Flow* is a non-GAAP measure and represents cash flows provided by (used in) operating activities, less capital expenditures plus proceeds from the disposition of assets. Management believes adjusted free cash flow* is useful to understand our performance at generating cash and demonstrates our discipline around the use of cash. Adjusted free cash flow* should be considered in addition to, but not as a substitute for cash flows provided by operating activities and should be viewed in addition to the Company’s reported results prepared in accordance with GAAP.

    Net Debt* – Net Debt* is a non-GAAP measure that is calculated taking short and long-term debt less cash and cash equivalents and restricted cash. Management believes the net debt* is useful to assess the level of debt in excess of cash and cash and equivalents as we monitor our ability to repay and service our debt. Net debt* should be considered in addition to, but not as a substitute for overall debt and total cash and should be viewed in addition to the Company’s results prepared in accordance with GAAP.​

    Net Leverage* – Net Leverage* is a non-GAAP measure which is calculated by dividing by taking net debt* divided by adjusted EBITDA* for the trailing 12 months. Management believes the net leverage* is useful to understand our ability to repay and service our debt. Net leverage* should be considered in addition to, but not as a substitute for the individual components of above defined net debt* divided by consolidated net income attributable to Weatherford and should be viewed in addition to the Company’s reported results prepared in accordance with GAAP.

    *Non-GAAP – as defined above and reconciled to the GAAP measures in the section titled GAAP to Non-GAAP Financial Measures Reconciled

    Weatherford International plc
    GAAP to Non-GAAP Financial Measures Reconciled (Unaudited)
     
                         
        Three Months Ended   Six Months Ended
    ($ in Millions, Except Margin in Percentages)   June 30,
    2025
      March 31,
    2025
      June 30,
    2024
      June 30,
    2025
      June 30,
    2024
    Revenues   $         1,204     $          1,193     $         1,405     $      2,397     $      2,763  
    Net Income Attributable to Weatherford   $            136     $                76     $            125     $         212     $         237  
    Net Income Margin     11.3 %     6.4 %     8.9 %     8.8 %     8.6 %
    Adjusted EBITDA*   $            254     $              253     $            365     $         507     $         701  
    Adjusted EBITDA Margin*     21.1 %     21.2 %     26.0 %     21.2 %     25.4 %
                         
    Net Income Attributable to Weatherford   $            136     $                76     $            125     $         212     $         237  
    Net Income Attributable to Noncontrolling Interests                       9                        10                       12                    19                    23  
    Income Tax Provision                     46                        10                       73                    56                 132  
    Interest Expense, Net of Interest Income of $14, $11,
    $17, $25 and $31
                        21                        26                       24                    47                    53  
    Loss on Blue Chip Swap Securities                       1                        —                       10                      1                    10  
    Other Expense, Net                     24                        20                       20                    44                    42  
    Operating Income                  237                      142                    264                 379                 497  
    Depreciation and Amortization                     64                        62                       86                 126                 171  
    Other Charges (Credits)[1]                       3                        13                       (2 )                  16                    —  
    Gain on Sale of Business                   (70 )                      —                       —                  (70 )                  —  
    Restructuring Charges                     11                        29                         5                    40                      8  
    Share-Based Compensation                       9                          7                       12                    16                    25  
    Adjusted EBITDA*   $            254     $              253     $            365     $         507     $         701  
                         
    Net Cash Provided By Operating Activities   $            128     $              142     $            150     $         270     $         281  
    Capital Expenditures for Property, Plant and
    Equipment
                      (54 )                    (77 )                   (62 )             (131 )             (121 )
    Proceeds from Disposition of Assets                       5                          1                         8                      6                    18  
    Adjusted Free Cash Flow*   $              79     $                66     $              96     $         145     $         178  
    [1] Other Charges (Credits) in the three and six months ended June 30, 2025 primarily includes fees to third-party financial institutions related to collections of certain receivables from our largest customer in Mexico and other miscellaneous charges and credits.

    *Non-GAAP – as reconciled to the GAAP measures above and defined in the section titled Non-GAAP Financial Measures Defined

    Weatherford International plc
    GAAP to Non-GAAP Financial Measures Reconciled Continued (Unaudited)
     
                   
         
    ($ in Millions)   June 30,
    2025
      March 31,
    2025
      June 30,
    2024
     
    Current Portion of Long-term Debt   $                   26   $                    22   $                   20  
    Long-term Debt                    1,565                    1,583                    1,628  
    Total Debt   $              1,591   $              1,605   $              1,648  
                   
    Cash and Cash Equivalents   $                 943   $                 873   $                 862  
    Restricted Cash                          60                          57                          58  
    Total Cash   $              1,003   $                 930   $                 920  
                   
    Components of Net Debt              
    Current Portion of Long-term Debt   $                   26   $                    22   $                   20  
    Long-term Debt                    1,565                    1,583                    1,628  
    Less: Cash and Cash Equivalents                       943                        873                       862  
    Less: Restricted Cash                          60                          57                          58  
    Net Debt*   $                 588   $                 675   $                 728  
                   
    Net Income for trailing 12 months   $                 481   $                 470   $                 500  
    Adjusted EBITDA* for trailing 12 months   $              1,188   $              1,299   $              1,327  
                   
    Net Leverage* (Net Debt*/Adjusted EBITDA*)                      0.49 x                     0.52 x                    0.55 x


    *Non-GAAP – as reconciled to the GAAP measures above and defined in the section titled Non-GAAP Financial Measures Defined

    The MIL Network

  • MIL-OSI USA: Newhouse Votes for Responsible Land Management, Unleashing Natural Resources

    Source: United States House of Representatives – Congressman Dan Newhouse (4th District of Washington)

    Headline: Newhouse Votes for Responsible Land Management, Unleashing Natural Resources

    WASHINGTON, D.C. – Today, Rep. Dan Newhouse (WA-04) released the following statement upon committee passage of the Fiscal Year 2026 Interior, Environment, and Related Agencies Appropriations Act. 

    “In my four years as Chairman of the Congressional Western Caucus, I worked hard to counter the Biden administration’s top-down regulations that threatened our public lands and natural resources across the West. This legislation is a course correction from the previous administration to unleash the resources we have under our feet, protect public lands for all who enjoy their benefits, and prioritize conservation over preservation across the United States. I also secured critical funding for three water infrastructure projects in Othello, Winthrop, and Oroville to address the water supply and distribution challenges these communities face,” said Rep. Newhouse. 

    Newhouse added, “I thank Subcommittee Chairman Mike Simpson and Full Committee Chairman Tom Cole for their leadership and commitment to funding priorities that support our rural way of life.” 

    The Interior, Environment, and Related Agencies Appropriations Bill provides a total discretionary allocation of $37.971 billion, which is $2.54 billion (6%) below the Fiscal Year 2025 enacted level. 

    The bill fully funds the Payments in Lieu of Taxes (PILT) program, estimated at $550 million, and prioritizes funding for Tribes and Wildland Fire Management.  

    Champions American energy dominance and reduces regulatory burdens by: 

    • Providing the OMB requested increase of $13.6 million for offshore oil and gas development at the Bureau of Ocean Energy Management and the OMB requested increase of $15 million for onshore oil and gas development at the Bureau of Land Management.
    • Requiring the Secretary of the Interior to conduct onshore and offshore oil and gas lease sales.
    • Prohibiting the use of the social cost of carbon, which has stymied new development.
    • Prohibiting the EPA from imposing the methane fee on oil and gas producers created by the Democrats’ Inflation Reduction Act.
    • Prohibiting multiple U.S. Fish and Wildlife Service rulings used to weaponize the Endangered Species Act against land users and energy producers.

    Protects access to public lands by: 

    • Blocking restrictions on hunting, fishing, and recreational shooting on federal lands.
    • Preventing additional regulations on ammunition, ammunition components, or fishing tackle under the Toxic Substances Control Act or any other law.
    • Prohibiting restrictions on where standard lead ammunition and fishing tackle can be used on certain federal lands or waters unless conditions are met.
    • Stopping the Bureau of Land Management’s Conservation and Landscape Health rule to ensure continued access to public lands for grazing, recreation, and energy development.

    Bolsters U.S. national security and border protections by:  

    • Reducing our reliance on foreign countries for critical minerals by promoting access to resources here at home through blocking certain lease withdrawals in Minnesota and reinstating mineral leases in the Superior National Forest.
    • Promoting domestic mining by ensuring ancillary mining activities can be approved, which is a fix to the Rosemont decision that created additional red tape and regulatory uncertainty for mining operations.
    • Ensuring chemical and pesticide manufacturers are not overburdened with requirements that would drive businesses overseas and threaten American competitiveness.
    • Prohibiting funds for the National Park Service to provide housing to an alien without lawful status.
    • Providing $771.84 million for Tribal Public Safety and Justice programs, which is a 39% increase over the FY25 enacted level.

    Newhouse secured funding for the following projects in Washington’s Fourth District in this legislation:

    City of Othello 

    Amount Secured: $1,000,000  

    The City of Othello is 100 percent reliant on a rapidly depleting groundwater supply and after several years of data collection, study completions, and pilot test studies, the City of Othello has developed an Aquifer Storage and Recovery (ASR) strategy to mitigate declining water levels in the Wanapum Basalt aquifer. The ASR method has proven to be effective, and the City has progressed to the stage of predesign. The City is requesting funding assistance with the next phase of “design” to build a permanent solution that will result in a sustainable, reliable, environmentally responsible water supply plan for the Othello region.

    City of Winthrop 

    Amount Secured: $1,500,000 

    The proposed project will improve the reliability of the Town of Winthrop’s water source and distribution system. The town only has one functioning well (Well #1). If that well goes down, the town only has a day or two of water available in its three reservoirs. Well #2 has been approved as an emergency water source by Department of Health, but it needs to be rehabilitated to be in regular use. 

    Scope of work includes: 

    • Rehabilitation of Well #2, including new pump, motor, piping, electrical/controls, generator backup, and a new well house.
    • Repairs to the Town’s East Reservoir, including waterproofing, concrete repairs, and altitude valve replacement. 

    Community benefits include public health and safety, fire protection, and water conservation. Winthrop is ranked #6 on the Washington DNR’s burn probability list. Given the community’s vulnerability to wildfire, ensuring a resilient and redundant water supply system with reliable fire flow capacity is critical for public safety

    City of Oroville 

    Amount Secured: $1,400,000 

    The project will result in new, upgraded water pipes that ensure safe and reliable drinking water to Oroville’s north end area. The City of Oroville requests $1,750,000 for construction of the first phase of the project which consists of approximately 3,500 lineal feet of aging and undersized water transmission main piping serving the “North End” of the City’s water system. The existing water t-mains consist of 4-inch and 6-inch deteriorated PVC pipe, which cannot provide adequate fire flow or service pressure and are prone to leaking. The project will replace these existing, undersized transmission mains with 12-inch transmission mains along 20th from Main St to Juniper St, and along Juniper St and Main St from 20th St to 23rd St. The project will also replace existing, undersized water transmission mains with 8-inch transmission mains along Deerpath Dr from 21st St to 23rd St, and along 23rd St from Deerpath Dr to Westlake Ave. 

    Bill text before amendments can be found here. 

    ### 

    MIL OSI USA News

  • MIL-OSI: Orrstown Financial Services, Inc. Reports Second Quarter 2025 Results and Announces Dividend Increase

    Source: GlobeNewswire (MIL-OSI)

    • Net income of $19.4 million, or $1.01 per diluted share, for the three months ended June 30, 2025 compared to net income of $18.1 million, or $0.93 per diluted share, for the three months ended March 31, 2025; the second quarter of 2025 included $1.0 million in merger-related expenses compared to $1.6 million in merger-related expenses for the first quarter of 2025;
    • Excluding the impact of the merger-related expenses referenced above, net of taxes, net income and diluted earnings per share were $20.2 million(1) and $1.04(1), respectively, for the second quarter of 2025 compared to $19.3 million(1) and $1.00(1), respectively, for the first quarter of 2025;
    • Net interest margin, on a tax equivalent basis, was 4.07% in the second quarter of 2025 compared to 4.00% in the first quarter of 2025; the net accretion of purchase accounting marks positively impacted the margin by 50 basis points in the second quarter of 2025;
    • Return on average assets was 1.45% and return on average equity was 14.56% for the three months ended June 30, 2025, compared to 1.35% and 13.98% for the return on average assets and return on average equity, respectively, for the three months ended March 31, 2025;
    • Excluding the impact of the merger-related expenses referenced above, net of taxes, adjusted return on average assets was 1.51%(1) and adjusted return on average equity was 15.12%(1) for the three months ended June 30, 2025 compared to 1.45%(1) and 14.97%(1), respectively, for the three months ended March 31, 2025;
    • Loans increased by $55.4 million, or 6% annualized, from March 31, 2025 to June 30, 2025; classified loans decreased by $10.4 million from $76.2 million at March 31, 2025 to $65.8 million at June 30, 2025;
    • Noninterest income increased by $1.3 million from $11.6 million for the three months ended March 31, 2025 to $12.9 million for the three months ended June 30, 2025;
    • Noninterest expense decreased by $0.6 million from $38.2 million for the three months ended March 31, 2025 to $37.6 million for the three months ended June 30, 2025, reflecting a decline in merger-related expenses during the second quarter of 2025; merger-related costs are not expected to be meaningful going forward; the second quarter of 2025 also included $0.6 million of severance charges in salaries and employee benefits expense;
    • Efficiency ratio decreased from 63.2% for the three months ended March 31, 2025 to 60.3% for the three months ended June 30, 2025; excluding the impact of the merger-related expenses, the efficiency ratio was 58.7%(1) for the three months ended June 30, 2025 compared to 60.5%(1) for the three months ended March 31, 2025;
    • Tangible common equity increased to 8.3% at June 30, 2025 compared to 7.9% at March 31, 2025;
    • Tangible book value per common share(1) increased to $22.77 per share at June 30, 2025 compared to $21.99 per share at March 31, 2025;
    • The Board of Directors authorized a share repurchase program on June 20, 2025, through which the Company could repurchase up to 500,000 shares of its common stock;
    • The Board of Directors declared a cash dividend of $0.27 per common share, payable August 12, 2025, to shareholders of record as of August 5, 2025; this represents a $0.01 per share increase in the Company’s quarter cash dividend; the dividend has increased by 35% since the closing of the merger with Codorus Valley Bancorp.

    (1) Non-GAAP measure. See Appendix A for additional information.

    HARRISBURG, Pa., July 22, 2025 (GLOBE NEWSWIRE) — Orrstown Financial Services, Inc. (NASDAQ: ORRF), the parent company of Orrstown Bank (the “Bank”), announced earnings for the periods ended June 30, 2025. Net income totaled $19.4 million for the three months ended June 30, 2025, compared to net income of $18.1 million for the three months ended March 31, 2025 and net income of $7.7 million for the three months ended June 30, 2024. Diluted earnings per share was $1.01 for the three months ended June 30, 2025, compared to diluted earnings per share of $0.93 for the three months ended March 31, 2025 and diluted earnings per share of $0.73 for the three months ended June 30, 2024. For the second quarter of 2025, excluding the impact of merger-related expenses, net of taxes, net income and diluted earnings per share were $20.2 million(1) and $1.04(1), respectively. For the first quarter of 2025, excluding the impact of merger-related expenses, net of taxes, net income and diluted earnings per share were $19.3 million(1) and $1.00(1), respectively. For the second quarter of 2024, excluding the impact of the merger-related expenses, net of taxes, net income and diluted earnings per share were $8.7 million(1) and $0.83(1), respectively.

    “At the one-year mark after the merger with Codorus Valley Bancorp, we are very pleased to have achieved metrics near top of peers, with significant upside opportunities in front of us,” said Thomas R. Quinn, Jr., President and Chief Executive Officer. “In the second quarter, we experienced positive traction on loan production. While commercial loan growth was lower than expected, our pipeline remains strong as we head into the third quarter. We remain prudent with our lending decisions and will not compromise on credit quality. Net interest margin improved in the quarter with good momentum going into the remainder of the year. While expenses remain slightly elevated, we do not anticipate any further meaningful merger-related expenses and continue to implement process improvements that will enhance efficiency and facilitate future growth. We believe that our strong credit metrics and capital generation have positioned us well for the future.”

    (1) Non-GAAP measure. See Appendix A for additional information.


    DISCUSSION OF RESULTS

    Balance Sheet

    Loans

    Loans held for investment increased by $55.4 million and totaled $3.9 billion at both June 30, 2025 and March 31, 2025. Commercial loans increased by $16.1 million, or 2% annualized, and residential mortgages increased by $37.9 million from March 31, 2025 to June 30, 2025. The increase in loans included a purchase of property assessed clean energy (“PACE”) loans totaling $25.4 million.

    Investment Securities

    Investment securities, all of which are classified as available-for-sale, increased by $29.9 million to $885.4 million at June 30, 2025 from $855.5 million at March 31, 2025. During the second quarter of 2025, the Bank purchased $50.1 million of investment securities, which was partially offset by paydowns totaling $20.4 million. The overall duration of the Company’s investment securities portfolio was 4.5 years at June 30, 2025 compared to 4.3 years at March 31, 2025. See Appendix B for a summary of the Bank’s investment securities at June 30, 2025, highlighting their concentrations, credit ratings and credit enhancement levels.

    Deposits

    During the second quarter of 2025, deposits decreased by $117.1 million and totaled $4.5 billion at June 30, 2025 compared to $4.6 billion March 31, 2025. Time deposits, money market deposits, non-interest bearing demand deposits, saving deposits and interest-bearing demand deposits decreased by $58.0 million, $35.8 million, $13.9 million, $6.2 million and $3.2 million, respectively, from March 31, 2025 to June 30, 2025. The declines in time deposits and money market deposits are due to continued run-off in higher yielding promotional balances. The decreases in the other categories were consistent with normal cyclical activity. As a result of the decrease in total deposits, the Bank’s loan-to-deposit ratio increased to 87% at June 30, 2025 from 84% at March 31, 2025.

    Borrowings

    The Bank actively manages its liquidity position through its various sources of funding to meet the needs of its clients. FHLB advances and other borrowings were $136.3 million at June 30, 2025 compared to $100.3 million at March 31, 2025. The increase was due to higher utilization of overnight borrowings during the second quarter of 2025 as deposit balances declined and lending and investing activities increased. The Bank seeks to maintain sufficient liquidity to ensure client needs can be addressed in a timely basis. The Bank had available alternative funding sources, such as FHLB advances and other wholesale options, of approximately $1.7 billion at June 30, 2025.

    Income Statement

    Net Interest Income and Margin

    Net interest income was $49.5 million for the three months ended June 30, 2025 compared to $48.8 million for the three months ended March 31, 2025. The net interest margin, on a tax equivalent basis, increased to 4.07% in the second quarter of 2025 from 4.00% in the first quarter of 2025. This increase is primarily the result of the cost of funds declining by 12 basis points from the first quarter of 2025 to the second quarter of 2025. This was partially offset by a decrease of seven basis points in the yield on loans from the three months ended March 31, 2025 to the three months ended June 30, 2025. This decrease was due to a reduction in accelerated accretion on acquired loans over that period. The second quarter 2025 net interest margin reflects the full impact of deposit rate reductions implemented in the prior quarter as well as the runoff of higher rate time deposits and money market balances.

    The net interest margin was positively impacted by the net accretion impact of purchase accounting marks on loans, securities, deposits and borrowings of $5.2 million during the second quarter of 2025 compared to $6.9 million for the first quarter of 2025. This change was due primarily to lower accelerated accretion in the three months ended June 30, 2025.

    Interest income on loans, on a tax equivalent basis, decreased by $0.4 million to $63.2 million for the three months ended June 30, 2025 compared to $63.6 million for the three months ended March 31, 2025. Average loans decreased by $14.7 million during the three months ended June 30, 2025 compared to the three months ended March 31, 2025. The accretion of purchase accounting marks on loans totaled $4.9 million during the second quarter of 2025 compared to $6.6 million during the first quarter of 2025.

    Interest income on investment securities, on a tax equivalent basis, was $10.6 million for the second quarter of 2025 compared to $10.1 million in the first quarter of 2025, an increase of $0.5 million. Average investment securities increased by $39.0 million during the three months ended June 30, 2025 compared to the three months ended March 31, 2025 primarily due to the aforementioned purchases.

    Interest expense, on a tax equivalent basis, decreased by $1.5 million to $25.3 million for the three months ended June 30, 2025 compared to $26.8 million for the three months ended March 31, 2025. Average interest-bearing deposits decreased by $70.3 million during the three months ended June 30, 2025 compared to the three months ended March 31, 2025. The cost of interest-bearing deposits declined by 14 basis points from the first quarter of 2025 to the second quarter of 2025. In addition, interest expense includes $0.4 million and $0.6 million of amortization of purchase accounting marks on interest bearing liabilities for the three months ended June 30, 2025 and March 31, 2025, respectively.

    Provision for Credit Losses on Loans

    The allowance for credit losses (“ACL”) on loans increased to $47.9 million at June 30, 2025 from $47.8 million at March 31, 2025. The ACL to total loans was 1.22% at June 30, 2025 compared to 1.23% at March 31, 2025. The Company recorded provision expense of $0.2 million for the three months ended June 30, 2025 compared to a recovery in the provision for credit losses on loans of $0.6 million for the three months ended March 31, 2025 . Net charge-offs were $0.1 million for the three months ended June 30, 2025 compared to $0.3 million for the three months ended March 31, 2025.

    Classified loans decreased by $10.4 million to $65.8 million at June 30, 2025 from $76.2 million at March 31, 2025 due to net upgrades and loan repayments. Non-accrual loans totaled $22.4 million at June 30, 2025 compared to $22.7 million at March 31, 2025. Nonaccrual loans to total loans decreased to 0.57% at June 30, 2025 compared to 0.59% at March 31, 2025. Management believes the ACL to be adequate based on current asset quality metrics and economic forecasts.

    Noninterest Income

    Noninterest income increased by $1.3 million to $12.9 million for the three months ended June 30, 2025 from $11.6 million for the three months ended March 31, 2025.

    Swap fee income increased by $0.3 million to $0.7 million for the three months ended June 30, 2025 compared to $0.4 million for the three months ended March 31, 2025. Swap fee income will fluctuate based on market conditions and client demand.

    Income from service charges was $2.6 million for the three months ended June 30, 2025 compared to $2.4 million for the three months ended March 31, 2025 based on increased cash management services activity.

    Income from mortgage banking activities increased by $0.2 million from $0.3 million in the three months ended March 31, 2025 to $0.5 million in the three months ended June 30, 2025. The first quarter of 2025 included a decrease of $0.2 million in the fair value of mortgage servicing rights.

    Wealth management income decreased by $0.2 million to $5.2 million for the three months ended June 30, 2025 compared to $5.4 million for the three months ended March 31, 2025.

    Other income increased by $0.7 million to $2.4 million for the three months ended June 30, 2025 compared to $1.7 million for the three months ended March 31, 2025. During the second quarter of 2025, the Bank recorded $0.3 million in solar tax credits and a gain on the sale of other real estate owned of $0.1 million.

    Noninterest Expenses

    Noninterest expenses decreased by $0.6 million to $37.6 million in the three months ended June 30, 2025 from $38.2 million in the three months ended March 31, 2025.

    For the three months ended June 30, 2025, merger-related expenses totaled $1.0 million, a decrease of $0.6 million, compared to $1.6 million for the three months ended March 31, 2025. The merger-related costs incurred in the second quarter of 2025 primarily included software conversion costs. The Company does not expect to incur meaningful merger-related expenses going forward.

    Salaries and benefits expense increased by $1.0 million to $21.4 million for the three months ended June 30, 2025 compared to $20.4 million for the three months ended March 31, 2025. The increase during the second quarter of 2025 includes $0.6 million of severance costs, the impact of merit salary increases in May and the impact of one extra day in the quarter.

    Occupancy, furniture and equipment expenses decreased by $0.5 million to $4.2 million for the three months ended June 30, 2025 from $4.7 million for the three months ended March 31, 2025 primarily due to the seasonal expenses incurred during the first quarter of 2025.

    Professional services expense increased by $0.2 million from the three months ended March 31, 2025 to the three months ended June 30, 2025. During the quarter, the Company continued to utilize an elevated level of third-party assistance to enhance daily functions and operational processes throughout the organization. While the Company will remain reliant on these services into the second half of 2025, the Company expects expenses related to these services to decline beginning in the third quarter of 2025.

    Advertising and bank promotions expense increased by $0.6 million to $1.1 million in the three months ended June 30, 2025 from $0.5 million in the three months ended March 31, 2025 due to $0.7 million in contributions to tax credit programs during the second quarter of 2025. Taxes other than income decreased by $0.6 million in the three months ended June 30, 2025 compared to the three months ended March 31, 2025. This decrease reflects the tax impact of the contributions referenced above.

    Income Taxes

    The Company’s effective tax rate was 21.3% for the second quarter of 2025 compared to 20.7% for the first quarter of 2025. The Company’s effective tax rate for the three months ended June 30, 2025 is greater than the 21% federal statutory rate primarily due to the disallowed portion of interest expense against earnings in association with the Bank’s tax-exempt investments under the Tax Equity and Fiscal Responsibility Act of 1982 partially offset by the benefit of tax-exempt income, including interest earned on tax-exempt loans and securities and income from life insurance policies and tax credits. The Company regularly analyzes its projected taxable income and makes adjustments to the provision for income taxes accordingly.

    Capital

    Shareholders’ equity totaled $548.4 million at June 30, 2025 compared to $532.9 million at March 31, 2025. The increase is due to net income of $19.4 million and share-based compensation activity of $1.6 million, partially offset by dividend payments of $5.1 million and other comprehensive losses of $0.5 million.

    Tangible book value per common share(1) increased to $22.77 per share at June 30, 2025 from $21.99 per share at March 31, 2025. The Company’s tangible common equity ratio was 8.3% at June 30, 2025 compared to 7.9% at March 31, 2025. Average tangible common equity per common share(1) was $18.43 at June 30, 2025 compared to $17.91 at March 31, 2025.

    The Company’s capital ratios increased during the three months ended June 30, 2025 due primarily to earnings. The Company’s tier 1 common equity, tier 1 and total risk-based capital ratios were 10.9%, 11.1% and 13.3%, respectively, at June 30, 2025 compared to 10.6%, 10.8% and 13.1%, respectively, at March 31, 2025. The Company’s Tier 1 leverage ratio increased to 9.0% at June 30, 2025 compared to 8.6% at March 31, 2025.

    At June 30, 2025, all four capital ratios applicable to the Company were above regulatory minimum levels to be deemed “well capitalized” under current bank regulatory guidelines. The Company continues to believe that capital is adequate to support the risks inherent in the balance sheet, as well as growth requirements.

    The Board of Directors authorized a share repurchase program on June 20, 2025, through which the Company could repurchase up to 500,000 shares of its common stock. The Company repurchased 2,134 common shares during the second quarter of 2025.

    (1) Non-GAAP measure. See Appendix A for additional information.


    Investor Relations Contact:
    Neelesh Kalani
    Executive Vice President, Chief Financial Officer
    Phone (717) 510-7097

    FINANCIAL HIGHLIGHTS (Unaudited)
                 
                   
                   
      Three Months Ended   Six Months Ended
      June 30,   June 30,   June 30,   June 30,
    (In thousands)   2025       2024       2025       2024  
                   
    Profitability for the period:              
    Net interest income $ 49,512     $ 26,103     $ 98,273     $ 52,984  
    Provision for (Recovery of) credit losses – loans   209       812       (345 )     1,233  
    Recovery of credit losses – unfunded loan commitments   (100 )           (100 )     (123 )
    Noninterest income   12,915       7,172       24,539       13,802  
    Noninterest expenses   37,614       22,639       75,790       45,108  
    Income before income tax expense   24,704       9,824       47,467       20,568  
    Income tax expense   5,256       2,086       9,968       4,299  
    Net income available to common shareholders $ 19,448     $ 7,738     $ 37,499     $ 16,269  
                   
    Financial ratios:              
    Return on average assets (1)   1.45 %     0.97 %     1.40 %     1.04 %
    Return on average assets, adjusted (1) (2) (3)   1.51 %     1.09 %     1.48 %     1.14 %
    Return on average equity (1)   14.56 %     11.41 %     14.28 %     12.09 %
    Return on average equity, adjusted (1) (2) (3)   15.12 %     12.88 %     15.05 %     13.33 %
    Net interest margin (1)   4.07 %     3.54 %     4.04 %     3.65 %
    Efficiency ratio   60.3 %     68.0 %     61.7 %     67.5 %
    Efficiency ratio, adjusted (2) (3)   58.7 %     64.6 %     59.6 %     64.8 %
    Income per common share:              
    Basic $ 1.01     $ 0.74     $ 1.96     $ 1.57  
    Basic, adjusted (2) (3) $ 1.05     $ 0.84     $ 2.06     $ 1.73  
    Diluted $ 1.01     $ 0.73     $ 1.94     $ 1.55  
    Diluted, adjusted (2) (3) $ 1.04     $ 0.83     $ 2.04     $ 1.71  
                   
    Average equity to average assets   9.97 %     8.50 %     9.81 %     8.58 %
                   
    (1) Annualized for the three and six months ended June 30, 2025 and 2024.
    (2) Ratio has been adjusted for the non-recurring charges for all periods presented.
    (3) Non-GAAP based financial measure. Please refer to Appendix A – Supplemental Reporting of Non-GAAP Measures and GAAP to Non-GAAP Reconciliations for a discussion of our use of non-GAAP based financial measures, including tables reconciling GAAP and non-GAAP financial measures appearing herein.
    FINANCIAL HIGHLIGHTS (Unaudited)      
    (continued)      
      June 30,   December 31,
    (Dollars in thousands, except per share amounts)   2025       2024  
    At period-end:      
    Total assets $ 5,387,645     $ 5,441,589  
    Loans, net of allowance for credit losses   3,883,481       3,882,525  
    Loans held-for-sale, at fair value   5,206       6,614  
    Securities available for sale, at fair value   885,373       829,711  
    Total deposits   4,516,625       4,623,096  
    FHLB advances and other borrowings and Securities sold under agreements to repurchase   166,381       141,227  
    Subordinated notes and trust preferred debt   69,021       68,680  
    Shareholders’ equity   548,448       516,682  
           
    Credit quality and capital ratios (1):      
    Allowance for credit losses to total loans   1.22 %     1.24 %
    Total nonaccrual loans to total loans   0.57 %     0.61 %
    Nonperforming assets to total assets   0.42 %     0.45 %
    Allowance for credit losses to nonaccrual loans   214 %     202 %
    Total risk-based capital:      
    Orrstown Financial Services, Inc.   13.3 %     12.4 %
    Orrstown Bank   13.3 %     12.4 %
    Tier 1 risk-based capital:      
    Orrstown Financial Services, Inc.   11.1 %     10.2 %
    Orrstown Bank   12.1 %     11.2 %
    Tier 1 common equity risk-based capital:      
    Orrstown Financial Services, Inc.   10.9 %     10.0 %
    Orrstown Bank   12.1 %     11.2 %
    Tier 1 leverage capital:      
    Orrstown Financial Services, Inc.   9.0 %     8.3 %
    Orrstown Bank   9.8 %     9.1 %
           
    Book value per common share $ 28.07     $ 26.65  
           
    (1) Capital ratios are estimated for the current period, subject to regulatory filings. The Company elected the three-year phase in option for the day-one impact of ASU 2016-13 for current expected credit losses (“CECL”) to regulatory capital. Beginning in 2023, the Company adjusted retained earnings, allowance for credit losses includable in tier 2 capital and the deferred tax assets from temporary differences in risk weighted assets by the permitted percentage of the day-one impact from adopting the CECL standard.
    ORRSTOWN FINANCIAL SERVICES, INC.      
    CONSOLIDATED BALANCE SHEETS (Unaudited)      
           
    (Dollars in thousands, except per share amounts) June 30, 2025   December 31, 2024
    Assets      
    Cash and due from banks $ 54,335     $ 51,026  
    Interest-bearing deposits with banks   95,042       197,848  
    Cash and cash equivalents   149,377       248,874  
    Restricted investments in bank stocks   21,204       20,232  
    Securities available for sale (amortized cost of $916,830 and $864,920 at June 30, 2025 and December 31, 2024, respectively)   885,373       829,711  
    Loans held for sale, at fair value   5,206       6,614  
    Loans   3,931,379       3,931,214  
    Less: Allowance for credit losses   (47,898 )     (48,689 )
    Net loans   3,883,481       3,882,525  
    Premises and equipment, net   51,703       50,217  
    Cash surrender value of life insurance   145,760       143,854  
    Goodwill   69,751       68,106  
    Other intangible assets, net   42,748       47,765  
    Accrued interest receivable   19,958       21,058  
    Deferred tax assets, net   36,683       42,647  
    Other assets   76,401       79,986  
    Total assets $ 5,387,645     $ 5,441,589  
           
    Liabilities      
    Deposits:      
    Noninterest-bearing $ 918,263     $ 894,176  
    Interest-bearing   3,598,362       3,728,920  
    Total deposits   4,516,625       4,623,096  
    Securities sold under agreements to repurchase and federal funds purchased   30,047       25,863  
    FHLB advances and other borrowings   136,334       115,364  
    Subordinated notes and trust preferred debt   69,021       68,680  
    Other liabilities   87,170       91,904  
    Total liabilities   4,839,197       4,924,907  
           
    Shareholders’ Equity      
    Preferred stock, $1.25 par value per share; 500,000 shares authorized; no shares issued or outstanding          
    Common stock, no par value—$0.05205 stated value per share; 50,000,000 shares authorized; 19,713,126 shares issued and 19,535,835 outstanding at June 30, 2025; 19,722,640 shares issued and 19,389,967 outstanding at December 31, 2024   1,026       1,027  
    Additional paid—in capital   422,349       423,274  
    Retained earnings   153,923       126,540  
    Accumulated other comprehensive loss   (24,479 )     (26,316 )
    Treasury stock— 177,291 and 332,673 shares, at cost at June 30, 2025 and December 31, 2024, respectively   (4,371 )     (7,843 )
    Total shareholders’ equity   548,448       516,682  
    Total liabilities and shareholders’ equity $ 5,387,645     $ 5,441,589  

    ORRSTOWN FINANCIAL SERVICES, INC.
    CONDENSED CONSOLIDATED STATEMENTS OF INCOME (Unaudited)
                     
        Three Months Ended   Six Months Ended
        June 30,   June 30,   June 30,   June 30,
    (Dollars in thousands, except per share amounts)     2025       2024       2025       2024  
    Interest income                
    Loans   $ 63,036     $ 35,537     $ 126,468     $ 71,770  
    Investment securities – taxable     9,406       4,999       18,350       9,583  
    Investment securities – tax-exempt     878       881       1,753       1,758  
    Short-term investments     1,513       1,864       3,781       2,820  
    Total interest income     74,833       43,281       150,352       85,931  
    Interest expense                
    Deposits     22,855       15,265       47,115       28,781  
    Securities sold under agreements to repurchase and federal funds purchased     106       27       190       52  
    FHLB advances and other borrowings     1,030       1,152       2,148       2,626  
    Subordinated notes and trust preferred debt     1,330       734       2,626       1,488  
    Total interest expense     25,321       17,178       52,079       32,947  
    Net interest income     49,512       26,103       98,273       52,984  
    Provision for (Recovery of) credit losses – loans     209       812       (345 )     1,233  
    Recovery of credit losses – unfunded loan commitments     (100 )           (100 )     (123 )
    Net interest income after provision for (recovery of) credit losses     49,403       25,291       98,718       51,874  
    Noninterest income                
    Service charges     2,630       1,283       5,025       2,483  
    Interchange income     1,441       961       2,868       1,872  
    Swap fee income     669       375       1,063       574  
    Wealth management income     5,267       3,312       10,682       6,414  
    Mortgage banking activities     478       369       780       827  
    Investment securities gains (losses)     8       (12 )     21       (17 )
    Other income     2,422       884       4,100       1,649  
    Total noninterest income     12,915       7,172       24,539       13,802  
    Noninterest expenses                
    Salaries and employee benefits     21,364       13,195       41,752       26,947  
    Occupancy, furniture and equipment     4,211       2,705       8,886       5,344  
    Data processing     965       1,237       1,889       2,502  
    Advertising and bank promotions     1,077       774       1,576       1,172  
    FDIC insurance     674       419       1,498       860  
    Professional services     2,016       801       3,842       1,432  
    Taxes other than income     295       49       1,237       543  
    Intangible asset amortization     2,472       215       5,007       440  
    Merger-related expenses     968       1,135       2,617       1,807  
    Restructuring expenses                 91        
    Other operating expenses     3,572       2,109       7,395       4,061  
    Total noninterest expenses     37,614       22,639       75,790       45,108  
    Income before income tax expense     24,704       9,824       47,467       20,568  
    Income tax expense     5,256       2,086       9,968       4,299  
    Net income   $ 19,448     $ 7,738     $ 37,499     $ 16,269  
     
        Three Months Ended   Six Months Ended
        June 30,   June 30,   June 30,   June 30,
          2025       2024       2025       2024  
    Share information:                
    Basic earnings per share   $ 1.01     $ 0.74     $ 1.96     $ 1.57  
    Diluted earnings per share   $ 1.01     $ 0.73     $ 1.94     $ 1.55  
    Dividends paid per share   $ 0.26     $ 0.20     $ 0.52     $ 0.40  
    Weighted average shares – basic     19,173       10,393       19,165       10,371  
    Weighted average shares – diluted     19,342       10,553       19,335       10,517  

    ANALYSIS OF NET INTEREST INCOME
           
    Average Balances and Interest Rates, Taxable-Equivalent Basis (Unaudited)    
      Three Months Ended
      6/30/2025   3/31/2025   12/31/2024   9/30/2024   6/30/2024
    (In thousands)     Taxable-   Taxable-       Taxable-   Taxable-       Taxable-   Taxable-       Taxable-   Taxable-       Taxable-   Taxable-
    Average   Equivalent   Equivalent   Average   Equivalent   Equivalent   Average   Equivalent   Equivalent   Average   Equivalent   Equivalent   Average   Equivalent   Equivalent
    Balance   Interest   Rate   Balance   Interest   Rate   Balance   Interest   Rate   Balance   Interest   Rate   Balance   Interest   Rate
    Assets                                                          
    Federal funds sold & interest-bearing bank balances $ 136,106   $ 1,513     4.46%   $ 203,347   $ 2,268     4.52%   $ 199,236   $ 2,492     4.96%   $ 184,465   $ 2,452     5.29%   $ 142,868   $ 1,864     5.25%
    Investment securities (1)(2)   904,119     10,626     4.70     865,126     10,052     4.65     849,389     9,887     4.66     849,700     10,123     4.77     538,451     6,114     4.54
    Loans (1)(3)(4)(5)   3,894,979     63,246     6.52     3,909,694     63,641     6.59     3,961,269     68,073     6.82     3,989,259     70,849     7.07     2,324,942     35,690     6.17
    Total interest-earning assets   4,935,203     75,385     6.13     4,978,167     75,961     6.17     5,009,894     80,452     6.38     5,023,424     83,424     6.61     3,006,261     43,668     5.84
    Other assets   439,569             447,530             454,271             491,719             204,863        
    Total assets $ 5,374,772           $ 5,425,697           $ 5,464,165           $ 5,515,143           $ 3,211,124        
    Liabilities and Shareholders’ Equity                                                
    Interest-bearing demand deposits $ 2,463,687     13,880     2.26   $ 2,473,543     14,156     2.32   $ 2,522,885     15,575     2.45   $ 2,554,743     16,165     2.52   $ 1,649,753     10,118     2.47
    Savings deposits   269,309     165     0.25     273,313     165     0.25     272,718     166     0.24     283,337     148     0.21     165,467     140     0.34
    Time deposits   914,108     8,810     3.87     970,588     9,939     4.15     998,963     11,109     4.41     1,014,628     12,290     4.82     481,721     5,007     4.18
    Total interest-bearing deposits   3,647,104     22,855     2.51     3,717,444     24,260     2.65     3,794,566     26,850     2.81     3,852,708     28,603     2.95     2,296,941     15,265     2.67
    Securities sold under agreements to repurchase and federal funds purchased   25,917     106     1.64     26,163     84     1.30     21,572     67     1.23     23,075     96     1.66     13,412     27     0.81
    FHLB advances and other borrowings   104,068     1,030     3.97     112,859     1,118     4.02     115,373     1,165     4.01     115,388     1,154     3.98     115,000     1,152     4.03
    Subordinated notes and trust preferred debt   68,910     1,330     7.74     68,739     1,296     7.65     68,571     1,360     7.88     68,399     1,437     8.36     32,118     734     9.19
    Total interest-bearing liabilities   3,845,999     25,321     2.64     3,925,205     26,758     2.76     4,000,082     29,442     2.92     4,059,570     31,290     3.07     2,457,471     17,178     2.81
    Noninterest-bearing demand deposits   904,031             887,726             849,999             807,886             423,037        
    Other liabilities   89,058             89,077             97,685             110,017             57,828        
    Total liabilities   4,839,088             4,902,008             4,947,766             4,977,473             2,938,336        
    Shareholders’ equity   535,684             523,689             516,399             537,670             272,788        
    Total $ 5,374,772           $ 5,425,697           $ 5,464,165           $ 5,515,143           $ 3,211,124        
    Taxable-equivalent net interest income / net interest spread       50,064     3.49%         49,203     3.41%         51,010     3.46%         52,134     3.55%         26,490     3.02%
    Taxable-equivalent net interest margin         4.07%           4.00%           4.05%           4.14%           3.54%
    Taxable-equivalent adjustment       (552 )             (442 )             (437 )             (437 )             (387 )    
    Net interest income     $ 49,512             $ 48,761             $ 50,573             $ 51,697             $ 26,103      
    Ratio of average interest-earning assets to average interest-bearing liabilities         128%           127%           125%           124%           122%
                                                               
                                                               
    NOTES:                                                          
    (1) Yields and interest income on tax-exempt assets have been computed on a taxable-equivalent basis assuming a 21% tax rate.
    (2) Average balance of investment securities is computed at fair value.
    (3) Average balances include nonaccrual loans.
    (4) Interest income on loans includes prepayment and late fees, where applicable.
    (5) Interest income on loans includes accretion on purchase accounting marks of $4.9 million, $6.6 million, $7.6 million, $7.3 million and $0.2 million for the three months ended June 30, 2025, March 31, 2025, December 31, 2024, September 30, 2024 and June 30, 2024, respectively.
    ANALYSIS OF NET INTEREST INCOME        
    Average Balances and Interest Rates, Taxable-Equivalent Basis (Unaudited)    
    (continued)                      
      Six Months Ended
      June 30, 2025   June 30, 2024
          Taxable-   Taxable-       Taxable-   Taxable-
      Average   Equivalent   Equivalent   Average   Equivalent   Equivalent
    (In thousands) Balance   Interest   Rate   Balance   Interest   Rate
    Assets                      
    Federal funds sold & interest-bearing bank balances $ 169,541   $ 3,781     4.50 %   $ 108,695   $ 2,820     5.22 %
    Investment securities (1)(2)   884,730     20,787     4.70       529,151     11,808     4.47  
    Loans (1)(3)(4)(5)(6)   3,902,295     126,883     6.56       2,316,522     72,072     6.25  
    Total interest-earning assets   4,956,566     151,451     6.15       2,954,368     86,700     5.90  
    Other assets   443,528             200,580        
    Total assets $ 5,400,094           $ 3,154,948        
    Liabilities and Shareholders’ Equity                      
    Interest-bearing demand deposits $ 2,468,589     28,036     2.29     $ 1,610,188     19,310     2.41  
    Savings deposits   271,104     330     0.25       167,736     284     0.34  
    Time deposits   942,387     18,749     4.01       455,082     9,187     4.06  
    Total interest-bearing deposits   3,682,080     47,115     2.58       2,233,006     28,781     2.59  
    Securities sold under agreements to repurchase and federal funds purchased   26,039     190     1.47       12,711     52     0.83  
    FHLB advances and other borrowings   108,439     2,148     3.99       126,253     2,626     4.18  
    Subordinated notes and trust preferred debt   68,825     2,626     7.69       32,109     1,488     9.32  
    Total interest-bearing liabilities   3,885,383     52,079     2.70       2,404,079     32,947     2.76  
    Noninterest-bearing demand deposits   895,924             420,253        
    Other liabilities   89,067             60,078        
    Total liabilities   4,870,374             2,884,410        
    Shareholders’ equity   529,720             270,538        
    Total liabilities and shareholders’ equity $ 5,400,094           $ 3,154,948        
    Taxable-equivalent net interest income / net interest spread       99,372     3.45 %         53,753     3.14 %
    Taxable-equivalent net interest margin         4.04 %           3.65 %
    Taxable-equivalent adjustment       (1,099 )             (769 )    
    Net interest income     $ 98,273             $ 52,984      
    Ratio of average interest-earning assets to average interest-bearing liabilities         128 %           123 %
                           
    NOTES TO ANALYSIS OF NET INTEREST INCOME:                
    (1) Yields and interest income on tax-exempt assets have been computed on a taxable-equivalent basis assuming a 21% tax rate.
    (2) Average balance of investment securities is computed at fair value.
    (3) Average balances include nonaccrual loans.
    (4) Interest income on loans includes prepayment and late fees, where applicable.
    (5) Interest income on loans includes interest recovered of $1.6 million from the payoff of a commercial real estate loan on nonaccrual status for the six months ended June 30, 2024.
    (6) Interest income on loans includes accretion on purchase accounting marks of $11.5 million and $0.3 million for the six months ended June 30, 2025 and 2024, respectively.
    ORRSTOWN FINANCIAL SERVICES, INC.        
    HISTORICAL TRENDS IN QUARTERLY FINANCIAL DATA (Unaudited)        
                       
    (In thousands) June 30,
    2025
      March 31,
    2025
      December 31,
    2024
      September 30,
    2024
      June 30,
    2024
    Profitability for the quarter:                  
    Net interest income $ 49,512     $ 48,761     $ 50,573     $ 51,697     $ 26,103  
    Provision for (Recovery of) credit losses   109       (554 )     1,755       13,681       812  
    Noninterest income   12,915       11,624       11,247       12,386       7,172  
    Noninterest expenses   37,614       38,176       42,930       60,299       22,639  
    Income (loss) before income taxes   24,704       22,763       17,135       (9,897 )     9,824  
    Income tax expense (benefit)   5,256       4,712       3,451       (1,994 )     2,086  
    Net income (loss) $ 19,448     $ 18,051     $ 13,684     $ (7,903 )   $ 7,738  
                       
    Financial ratios:                  
    Return on average assets (1)   1.45 %     1.35 %     1.00 %   (0.57)%     0.97 %
    Return on average assets, adjusted (1)(2)(3)   1.51 %     1.45 %     1.22 %     1.55 %     1.09 %
    Return on average equity (1)   14.56 %     13.98 %     10.54 %   (5.85)%     11.41 %
    Return on average equity, adjusted (1)(2)(3)   15.12 %     14.97 %     12.86 %     15.85 %     12.88 %
    Net interest margin (1)   4.07 %     4.00 %     4.05 %     4.14 %     3.54 %
    Efficiency ratio   60.3 %     63.2 %     69.4 %     94.1 %     68.0 %
    Efficiency ratio, adjusted (2)(3)   58.7 %     60.5 %     62.3 %     60.2 %     64.6 %
                       
    Per share information:                  
    Income (loss) per common share:                  
    Basic $ 1.01     $ 0.94     $ 0.72     $ (0.41 )   $ 0.74  
    Basic, adjusted (2)(3)   1.05       1.01       0.87       1.12       0.84  
    Diluted   1.01       0.93       0.71       (0.41 )     0.73  
    Diluted, adjusted (2)(3)   1.04       1.00       0.87       1.11       0.83  
    Book value   28.07       27.32       26.65       26.65       25.97  
    Tangible book value(3)   22.77       21.99       21.19       21.12       24.08  
    Average tangible common equity(3)   18.43       17.91       13.62       (6.49 )     12.35  
    Cash dividends paid   0.26       0.26       0.23       0.23       0.20  
                       
    Average basic shares   19,172       19,157       19,118       19,088       10,393  
    Average diluted shares   19,342       19,328       19,300       19,226       10,553  

    (1)
    Annualized.
    (2) Ratio has been adjusted for non-recurring expenses for all periods presented.
    (3) Non-GAAP based financial measure. Please refer to Appendix A – Supplemental Reporting of Non-GAAP Measures and GAAP to Non-GAAP Reconciliations for a discussion of our use of non-GAAP based financial measures, including tables reconciling GAAP and non-GAAP financial measures appearing herein.
     
    ORRSTOWN FINANCIAL SERVICES, INC.                
    HISTORICAL TRENDS IN QUARTERLY FINANCIAL DATA (Unaudited)        
    (continued)                  
    (In thousands) June 30,
    2025
      March 31,
    2025
      December 31,
    2024
      September 30,
    2024
      June 30,
    2024
    Noninterest income:                  
    Service charges $ 2,630   $ 2,395   $ 2,050     $ 2,360   $ 1,283  
    Interchange income   1,441     1,427     1,608       1,779     961  
    Swap fee income   669     394     597       505     375  
    Wealth management income   5,267     5,415     4,902       5,037     3,312  
    Mortgage banking activities   478     302     517       491     369  
    Other income   2,422     1,678     1,578       1,943     884  
    Investment securities gains (losses)   8     13     (5 )     271     (12 )
    Total noninterest income $ 12,915   $ 11,624   $ 11,247     $ 12,386   $ 7,172  
                       
    Noninterest expenses:                  
    Salaries and employee benefits $ 21,364   $ 20,388   $ 22,444     $ 27,190   $ 13,195  
    Occupancy, furniture and equipment   4,211     4,675     4,893       4,333     2,705  
    Data processing   965     924     1,540       2,046     1,237  
    Advertising and bank promotions   1,077     499     878       537     774  
    FDIC insurance   674     824     955       862     419  
    Professional services   2,016     1,826     1,591       1,119     801  
    Taxes other than income   295     942     (312 )     503     49  
    Intangible asset amortization   2,472     2,535     2,838       2,464     215  
    Provision for legal settlement           478            
    Merger-related expenses   968     1,649     3,887       16,977     1,135  
    Restructuring expenses       91     39       257      
    Other operating expenses   3,572     3,823     3,699       4,011     2,109  
    Total noninterest expenses $ 37,614   $ 38,176   $ 42,930     $ 60,299   $ 22,639  
                       
    HISTORICAL TRENDS IN QUARTERLY FINANCIAL DATA (Unaudited)            
    (continued)                  
    (In thousands) June 30,
    2025
      March 31,
    2025
      December 31,
    2024
      September 30,
    2024
      June 30,
    2024
    Balance Sheet at quarter end:                  
    Cash and cash equivalents $ 149,377     $ 287,120     $ 248,874     $ 236,780     $ 132,509  
    Restricted investments in bank stocks   21,204       19,693       20,232       20,247       11,147  
    Securities available for sale   885,373       855,456       829,711       826,828       529,082  
    Loans held for sale, at fair value   5,206       5,261       6,614       3,561       1,562  
    Loans:                  
    Commercial real estate:                  
    Owner occupied   622,315       617,854       633,567       622,726       371,301  
    Non-owner occupied   1,203,038       1,157,383       1,160,238       1,164,501       710,477  
    Multi-family   239,388       257,724       274,135       276,296       151,542  
    Non-owner occupied residential   163,018       168,354       179,512       190,786       89,156  
    Agricultural   124,291       134,916       125,156       129,486       25,551  
    Commercial and industrial   487,063       455,494       451,384       471,983       349,425  
    Acquisition and development:                  
    1-4 family residential construction   38,490       40,621       47,432       56,383       32,439  
    Commercial and land development   198,889       227,434       241,424       262,317       129,883  
    Municipal   28,693       30,780       30,044       27,960       10,594  
    Total commercial loans   3,105,185       3,090,560       3,142,892       3,202,438       1,870,368  
    Residential mortgage:                  
    First lien   472,030       464,642       460,297       451,195       271,153  
    Home equity – term   5,784       9,224       5,988       6,508       4,633  
    Home equity – lines of credit   305,968       295,820       303,561       303,165       192,736  
    Other – term(1)   25,384                          
    Installment and other loans   17,028       15,739       18,476       18,131       8,713  
    Total loans   3,931,379       3,875,985       3,931,214       3,981,437       2,347,603  
    Allowance for credit losses   (47,898 )     (47,804 )     (48,689 )     (49,630 )     (29,864 )
    Net loans held for investment   3,883,481       3,828,181       3,882,525       3,931,807       2,317,739  
    Goodwill   69,751       68,106       68,106       70,655       18,724  
    Other intangible assets, net   42,748       45,230       47,765       46,144       1,974  
    Total assets   5,387,645       5,441,586       5,441,589       5,470,589       3,198,782  
    Total deposits   4,516,625       4,633,716       4,623,096       4,650,853       2,702,884  
    FHLB advances and other borrowings and Securities sold under agreements to repurchase   166,381       123,480       141,227       137,310       129,625  
    Subordinated notes and trust preferred debt   69,021       68,850       68,680       68,510       32,128  
    Total shareholders’ equity   548,448       532,936       516,682       516,206       278,376  
                       
    (1) Other – term includes property assessed clean energy (“PACE”) loans.
    HISTORICAL TRENDS IN QUARTERLY FINANCIAL DATA (Unaudited)            
    (continued)                  
      June 30,
    2025
      March 31,
    2025
      December 31,
    2024
      September 30,
    2024
      June 30,
    2024
    Capital and credit quality measures(1):                  
    Total risk-based capital:                  
    Orrstown Financial Services, Inc.   13.3 %     13.1 %     12.4 %     12.4 %     13.3 %
    Orrstown Bank   13.3 %     13.0 %     12.4 %     12.2 %     13.1 %
    Tier 1 risk-based capital:                  
    Orrstown Financial Services, Inc.   11.1 %     10.8 %     10.2 %     10.0 %     11.1 %
    Orrstown Bank   12.1 %     11.9 %     11.2 %     11.0 %     12.0 %
    Tier 1 common equity risk-based capital:                  
    Orrstown Financial Services, Inc.   10.9 %     10.6 %     10.0 %     9.8 %     11.1 %
    Orrstown Bank   12.1 %     11.9 %     11.2 %     11.0 %     12.0 %
    Tier 1 leverage capital:                  
    Orrstown Financial Services, Inc.   9.0 %     8.6 %     8.3 %     8.0 %     8.9 %
    Orrstown Bank   9.8 %     9.5 %     9.1 %     8.8 %     9.5 %
                       
    Average equity to average assets   9.97 %     9.65 %     9.45 %     9.75 %     8.50 %
    Allowance for credit losses to total loans   1.22 %     1.23 %     1.24 %     1.25 %     1.27 %
    Total nonaccrual loans to total loans   0.57 %     0.59 %     0.61 %     0.68 %     0.36 %
    Nonperforming assets to total assets   0.42 %     0.42 %     0.45 %     0.49 %     0.26 %
    Allowance for credit losses to nonaccrual loans   214 %     210 %     202 %     184 %     357 %
                       
    Other information:                  
    Net charge-offs $ 115     $ 331     $ 3,002     $ 269     $ 113  
    Classified loans   65,754       76,211       88,628       105,465       48,722  
    Nonperforming and other risk assets:                  
    Nonaccrual loans   22,423       22,727       24,111       26,927       8,363  
    Other real estate owned         138       138       138        
    Total nonperforming assets   22,423       22,865       24,249       27,065       8,363  
    Financial difficulty modifications still accruing   5,759       5,127       4,897       9,497        
    Loans past due 90 days or more and still accruing   1,312       400       641       337       187  
    Total nonperforming and other risk assets $ 29,494     $ 28,392     $ 29,787     $ 36,899     $ 8,550  
    (1) Capital ratios are estimated for the current period, subject to regulatory filings. The Company elected the three-year phase in option for the day-one impact of ASU 2016-13 for current expected credit losses (“CECL”) to regulatory capital. Beginning in 2023, the Company adjusted retained earnings, allowance for credit losses includable in tier 2 capital and the deferred tax assets from temporary differences in risk weighted assets by the permitted percentage of the day-one impact from adopting the new CECL standard.

    Appendix A- Supplemental Reporting of Non-GAAP Measures and GAAP to Non-GAAP Reconciliations

    Management believes providing certain other “non-GAAP” financial information will assist investors in their understanding of the effect on recent financial results from non-recurring charges.

    As a result of acquisitions, the Company has intangible assets consisting of goodwill, core deposit and other intangible assets, which totaled $112.5 million and $115.9 million at June 30, 2025 and December 31, 2024, respectively. In addition, during the three months ended June 30, 2025, March, 31, 2025, December 31, 2024, September 30, 2024 and June 30, 2024, the Company incurred $1.0 million, $1.6 million, $3.9 million, $17.0 million and $1.1 million in merger-related expenses, respectively. During the three months ended December 31, 2024 and September 30, 2024, the Company incurred other non-recurring charges totaling $0.5 million and $20.2 million, respectively.

    Tangible book value per common share, tangible common equity and the impact of the non-recurring expenses on net income and associated ratios, as used by the Company in this earnings release, are determined by methods other than in accordance with U.S. Generally Accepted Accounting Principles (“GAAP”). While we believe this information is a useful supplement to GAAP based measures presented in this earnings release, readers are cautioned that this non-GAAP disclosure has limitations as an analytical tool, should not be viewed as a substitute for financial measures determined in accordance with GAAP, and should not be considered in isolation or as a substitute for analysis of our results and financial condition as reported under GAAP, nor are such measures necessarily comparable to non-GAAP performance measures that may be presented by other companies. This supplemental presentation should not be construed as an inference that our future results will be unaffected by similar adjustments to be determined in accordance with GAAP.

    The following tables present the computation of each non-GAAP based measure:

    (In thousands)

    Tangible Book Value per Common Share   June 30,
    2025
      March 31,
    2025
      December 31,
    2024
      September 30,
    2024
      June 30,
    2024
    Shareholders’ equity (most directly comparable GAAP-based measure)   $ 548,448     $ 532,936     $ 516,682     $ 516,206     $ 278,376  
    Less: Goodwill     69,751       68,106       68,106       70,655       18,724  
    Other intangible assets     42,748       45,230       47,765       46,144       1,974  
    Related tax effect     (8,977 )     (9,498 )     (10,031 )     (9,690 )     (415 )
    Tangible common equity (non-GAAP)   $ 444,926     $ 429,098     $ 410,842     $ 409,097     $ 258,093  
                         
    Common shares outstanding     19,536       19,510       19,390       19,373       10,720  
                         
    Book value per share (most directly comparable GAAP-based measure)   $ 28.07     $ 27.32     $ 26.65     $ 26.65     $ 25.97  
    Intangible assets per share     5.30       5.33       5.46       5.53       1.89  
    Tangible book value per share (non-GAAP)   $ 22.77     $ 21.99     $ 21.19     $ 21.12     $ 24.08  
                         
    Return on Average Common Equity   June 30,
    2025
      March 31,
    2025
      December 31,
    2024
      September 30,
    2024
      June 30,
    2024
    Average shareholders’ equity   $ 535,684     $ 523,689     $ 516,399     $ 537,670   $ 272,788  
    Less: Average goodwill     68,126       68,106       71,477       36,034     18,724  
    Less: Average other intangible assets, gross     44,304       46,864       45,319       17,393     2,105  
    Average tangible equity   $ 423,254     $ 408,719     $ 399,603     $ 484,243   $ 251,959  
    Return on average tangible equity     18.43 %     17.91 %     13.62 %   (6.49)%     12.35 %
                         
    (In thousands) Three Months Ended   Six Months Ended
    Adjusted Ratios for Non-recurring Charges June 30,
    2025
      March 31, 2025   December 31,
    2024
      September 30,
    2024
      June 30,
    2024
      June 30,
    2025
        June 30,
    2024
    Net income (loss) (A) – most directly comparable GAAP-based measure $ 19,448     $ 18,051     $ 13,684     $ (7,903 )   $ 7,738     $ 37,499       $ 16,269  
    Plus: Merger-related expenses (B)   968       1,649       3,887       16,977       1,135       2,617         1,807  
    Plus: Executive retirement expenses (B)               35       4,758                      
    Plus: Provision for credit losses on non-PCD loans (B)                     15,504                      
    Plus: Provision for legal settlement (B)               478                            
    Less: Related tax effect (C)   (221 )     (368 )     (1,386 )     (7,915 )     (139 )     (590 )       (140 )
    Adjusted net income (D=A+B-C) – Non-GAAP $ 20,195     $ 19,332     $ 16,698     $ 21,421     $ 8,734     $ 39,526       $ 17,936  
                                 
    Average assets (E) $ 5,374,772     $ 5,425,697     $ 5,464,165     $ 5,515,143     $ 3,211,124     $ 5,400,094       $ 3,154,948  
    Return on average assets (= A / E) – most directly comparable GAAP-based measure (1)   1.45 %     1.35 %     1.00 %   (0.57)%     0.97 %     1.40 %       1.04 %
    Return on average assets, adjusted (= D / E) – Non-GAAP (1)   1.51 %     1.45 %     1.22 %     1.55 %     1.09 %     1.48 %       1.14 %
                                 
    Average equity (F) $ 535,684     $ 523,689     $ 516,399     $ 537,670     $ 272,788     $ 529,720       $ 270,538  
    Return on average equity (= A / F) – most directly comparable GAAP-based measure (1)   14.56 %     13.98 %     10.54 %   (5.85)%     11.41 %     14.28 %       12.09 %
    Return on average equity, adjusted (= D / F) – Non-GAAP (1)   15.12 %     14.97 %     12.86 %     15.85 %     12.88 %     15.05 %       13.33 %
                                 
    Weighted average shares – basic (G) – most directly comparable GAAP-based measure   19,173       19,157       19,118       19,088       10,393       19,165         10,371  
    Basic earnings (loss) per share (= A / G) – most directly comparable GAAP-based measure $ 1.01     $ 0.94     $ 0.72     $ (0.41 )   $ 0.74     $ 1.96       $ 1.57  
    Basic earnings per share, adjusted (= D / G) – Non-GAAP $ 1.05     $ 1.01     $ 0.87     $ 1.12     $ 0.84     $ 2.06       $ 1.73  
                                 
    Weighted average shares – diluted (H) – most directly comparable GAAP-based measure   19,342       19,328       19,300       19,226       10,553       19,335         10,517  
    Diluted earnings (loss) per share (= A / H) – most directly comparable GAAP-based measure $ 1.01     $ 0.93     $ 0.71     $ (0.41 )   $ 0.73     $ 1.94       $ 1.55  
    Diluted earnings per share, adjusted (= D / H) – Non-GAAP $ 1.04     $ 1.00     $ 0.87     $ 1.11     $ 0.83     $ 2.04       $ 1.71  
                                 
    (1) Annualized                            
      Three Months Ended   Six Months Ended
      June 30,
    2025
      March 31, 2025   December 31,
    2024
      September 30,
    2024
      June 30,
    2024
      June 30,
    2025
        June 30,
    2024
    Noninterest expense (I) – most directly comparable GAAP-based measure $ 37,614     $ 38,176     $ 42,930     $ 60,299     $ 22,639     $ 75,790       $ 45,108  
    Less: Merger-related expenses (B)   (968 )     (1,649 )     (3,887 )     (16,977 )     (1,135 )     (2,617 )       (1,807 )
    Less: Executive retirement expenses (B)               (35 )     (4,758 )                    
    Less: Provision for legal settlement (B)               (478 )                          
    Adjusted noninterest expense (J = I – B) – Non-GAAP $ 36,646     $ 36,527     $ 38,531     $ 38,564     $ 21,504     $ 73,173       $ 43,301  
                                 
    Net interest income (K) $ 49,512     $ 48,761     $ 50,573     $ 51,697     $ 26,103     $ 98,273       $ 52,984  
    Noninterest income (L)   12,915       11,624       11,247       12,386       7,172       24,539         13,802  
    Total operating income (M = K + L) $ 62,427     $ 60,385     $ 61,820     $ 64,083     $ 33,275     $ 122,812       $ 66,786  
                                 
    Efficiency ratio (= I / M) – most directly comparable GAAP-based measure   60.3 %     63.2 %     69.4 %     94.1 %     68.0 %     61.7 %       67.5 %
    Efficiency ratio, adjusted (= J / M) – Non-GAAP   58.7 %     60.5 %     62.3 %     60.2 %     64.6 %     59.6 %       64.8 %
                                 
    (1) Annualized                            

    Appendix B- Investment Portfolio Concentrations

    The following table summarizes the credit ratings and collateral associated with the Company’s investment security portfolio, excluding equity securities, at June 30, 2025:

    (In thousands)

    Sector Portfolio Mix   Amortized Book   Fair Value   Credit Enhancement   AAA   AA   A   BBB   BB   NR   Collateral / Guarantee Type
    Unsecured ABS %   $ 2,827   $ 2,673   28 %   %   %   %   %   %   100 %   Unsecured Consumer Debt
    Student Loan ABS       3,577     3,576   28                         100     Seasoned Student Loans
    Federal Family Education Loan ABS 8       75,724     74,828   11         47     33     7     13         Federal Family Education Loan (1)
    PACE Loan ABS       1,912     1,702   7     100                         PACE Loans (2)
    Non-Agency CMBS 3       24,012     24,027   24                         100      
    Non-Agency RMBS 2       15,936     14,596   16     100                         Reverse Mortgages (3)
    Municipal – General Obligation 11       100,035     90,241       16     77     7                  
    Municipal – Revenue 13       120,446     105,710           82     12             6      
    SBA ReRemic (5)       1,904     1,890           100                     SBA Guarantee (4)
    Small Business Administration 1       5,156     5,275           100                     SBA Guarantee (4)
    Agency MBS 22       198,876     197,965           100                     Residential Mortgages (4)
    Agency CMO 38       344,233     342,057           100                      
    U.S. Treasury securities 2       20,036     18,641           100                     U.S. Government Guarantee (4)
    Corporate bonds       1,941     1,977               52     48              
      100 %   $ 916,615   $ 885,158       4 %   85 %   5 %   1 %   1 %   4 %    
                                               
    (1) 97% guaranteed by U.S. government
    (2) PACE acronym represents Property Assessed Clean Energy loans
    (3) Non-agency reverse mortgages with current structural credit enhancements
    (4) Guaranteed by U.S. government or U.S. government agencies
    (5) SBA ReRemic acronym represents Re-Securitization of Real Estate Mortgage Investment Conduits
                                               
    Note: Ratings in table are the lowest of the six rating agencies (Standard & Poor’s, Moody’s, Fitch, Morningstar, DBRS and Kroll Bond Rating Agency). Standard & Poor’s rates U.S. government obligations at AA+.

    About the Company

    With $5.4 billion in assets, Orrstown Financial Services, Inc. and its wholly-owned subsidiary, Orrstown Bank, provide a wide range of consumer and business financial services in Berks, Cumberland, Dauphin, Franklin, Lancaster, Perry and York Counties, Pennsylvania and Anne Arundel, Baltimore, Harford, Howard, and Washington Counties, Maryland, as well as Baltimore City, Maryland. The Company’s lending area also includes counties in Pennsylvania, Maryland, Delaware, Virginia and West Virginia within a 75-mile radius of the Company’s executive and administrative offices as well as the District of Columbia. Orrstown Bank is an Equal Housing Lender and its deposits are insured up to the legal maximum by the FDIC. Orrstown Financial Services, Inc.’s common stock is traded on Nasdaq (ORRF). For more information about Orrstown Financial Services, Inc. and Orrstown Bank, visit www.orrstown.com.

    Cautionary Note Regarding Forward-Looking Statements

    This press release contains “forward-looking statements” within the meaning of Section 27A of the Securities Act and Section 21E of the Exchange Act. Forward-looking statements reflect the current views of the Company’s management with respect to, among other things, future events and the Company’s financial performance. These statements are often, but not always, made through the use of words or phrases such as “may,” “should,” “could,” “predict,” “potential,” “believe,” “will likely result,” “expect,” “continue,” “will,” “anticipate,” “seek,” “estimate,” “intend,” “plan,” “project,” “forecast,” “goal,” “target,” “would” and “outlook,” or the negative variations of those words or other comparable words of a future or forward-looking nature. These forward-looking statements are not historical facts, and are based on current expectations, estimates, predictions or projections about events or the Company’s industry, management’s beliefs and certain assumptions made by management, many of which, by their nature, are inherently uncertain and beyond the Company’s control. Accordingly, the Company cautions you that any such forward-looking statements are not guarantees of future performance and are subject to risks, assumptions and uncertainties that are difficult to predict. Although the Company believes that the expectations reflected in these forward-looking statements are reasonable as of the date made, actual results may prove to be materially different from the results expressed or implied by the forward-looking statements and there can be no assurances that the Company will achieve the desired level of new business development and new loans, growth in the balance sheet and fee-based revenue lines of business, cost savings initiatives and continued reductions in risk assets or mitigation of losses in the future. Factors which could cause the actual results to differ from those expressed or implied by the forward-looking statements include, but are not limited to, the following: interest rate changes or volatility; general economic conditions (including inflation and concerns about liquidity) on a national basis or in the local markets in which the Company operates; ineffectiveness of the Company’s strategic growth plan due to changes in current or future market conditions; the effects of competition and how it may impact our community banking model, including industry consolidation and development of competing financial products and services; changes in consumer behavior due to changing political, business and economic conditions, or legislative or regulatory initiatives; changes in, and evolving interpretations of, existing and future laws and regulations; changes in credit quality; inability to raise capital, if necessary, under favorable conditions; volatility in the securities markets; the demand for our products and services; deteriorating economic conditions; geopolitical tensions; operational risks including, but not limited to, cybersecurity incidents, fraud, natural disasters and future pandemics; expenses associated with litigation and legal proceedings; the possibility that the anticipated benefits of the merger with Codorus Valley Bancorp are not realized when expected or at all; and other risks and uncertainties, including those detailed in our Annual Report on Form 10-K for the year ended December 31, 2024 under the sections titled “Risk Factors” and “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and in subsequent filings made with the Securities and Exchange Commission.

    The foregoing list of factors is not exhaustive. If one or more events related to these or other risks or uncertainties materializes, or if the Company’s underlying assumptions prove to be incorrect, actual results may differ materially from what the Company anticipates. Accordingly, you should not place undue reliance on any such forward-looking statements. Any forward-looking statement speaks only as of the date on which it is made, and the Company disclaims any obligation to publicly update or review any forward-looking statement, whether as a result of new information, future developments or otherwise. New risks and uncertainties arise from time to time, and it is not possible for the Company to predict those events or how they may affect it. In addition, the Company cannot assess the impact of each factor on its business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained in any forward-looking statements. All forward-looking statements, expressed or implied, included in this press release are expressly qualified in their entirety by this cautionary statement. This cautionary statement should also be considered in connection with any subsequent written or oral forward-looking statements that the Company or persons acting on the Company’s behalf may issue.

    The review period for subsequent events extends up to and includes the filing date of a public company’s financial statements, when filed with the Securities and Exchange Commission. Accordingly, the consolidated financial information presented in this announcement is subject to change. Annualized, pro forma, projected and estimated numbers in this document are used for illustrative purposes only and are not forecasts and may not reflect actual results.

    The MIL Network

  • MIL-OSI: Ellomay Capital Announces the Acquisition of 15% of Dorad Energy’s Shares by Ellomay Luzon Energy, Increasing Ellomay Luzon Energy’s Holdings in Dorad to 33.75%

    Source: GlobeNewswire (MIL-OSI)

    Tel-Aviv, Israel, July 22, 2025 (GLOBE NEWSWIRE) — Ellomay Capital Ltd. (NYSE American; TASE: ELLO) (“Ellomay” or the “Company”), a renewable energy and power generator and developer of renewable energy and power projects in Europe, the USA and Israel, announced that on July 22, 2025, Ellomay Luzon Energy Infrastructures Ltd. (“Ellomay Luzon Energy”), an Israeli private company 50% held indirectly by the Company, completed the acquisition of 15% of the outstanding shares of Dorad Energy Ltd. (“Dorad”). As a result of the acquisition, Ellomay Luzon Energy holds 33.75% of Dorad’s outstanding shares.  

    Ellomay Luzon Energy acquired 15% of Dorad’s outstanding shares by exercising the right of first refusal granted to Ellomay Luzon Energy and other Dorad shareholders in connection with a sale of the shares by Zorlu Enerji Elektrik Üretim A.S (“Zorlu”), a former Dorad shareholder. In connection with the right of first refusal process, Ellomay Luzon Energy and Edelcom Ltd. (“Edelcom”), each executed an agreement to purchase 7.5% of Dorad’s shares. As not all the conditions to closing of the sale of 7.5% of Dorad’s shares to Edelcom were fulfilled, Edelcom’s agreement was terminated and Ellomay Luzon Energy, who did succeed in fulfilling all of the conditions to closing, acquired 15% of Dorad’s shares.

    The consideration for the shares was approximately NIS 424 million (approximately €108 million), and was funded by bank financing (the “Loan Agreement”) provided to Ellomay Luzon Energy consisting of three tranches as follows: (i) a loan in the amount of NIS 175 million (approximately €45 million), bearing annual interest in the range of +0.5% to -0.5% of the Israeli Prime Rate (the “First Loan”), (ii) a loan in the amount of NIS 175 million (approximately €45 million), bearing fixed annual interest rate between 5% and 6% (the “Second Loan”), and (iii) a loan in the amount of NIS 70 million (approximately €18 million), bearing annual interest rate in the range of +0.5% to -0.5% of the Israeli Prime Rate (the “Third Loan”).

    The First Loan is repayable in four semi-annual payments commencing December 31, 2031 and ending on June 30, 2033, and the interest on the First Loan is payable in semi-annual payments commencing December 31, 2025 and ending on the final repayment of the First Loan. The Second Loan is repayable in sixteen semi-annual payments commencing December 31, 2025 and ending on June 30, 2033, and the interest on the Second Loan is payable in semi-annual payment commencing December 31, 2025 and ending on the final repayment of the Second Loan. The Third Loan is repayable in one payment on December 31, 2025, unless the conditions set forth in the Loan Agreement will not be met, which will enable Ellomay Luzon Energy to ask for an extension until December 31, 2026. The interest on the Third Loan is payable on December 31, 2025 and, to the extent an extension is requested, in semi-annual payments thereafter until the final repayment of the Third Loan.

    In connection with the Loan Agreement, Ellomay Luzon Energy granted the lender a first ranking fixed pledge on its rights in connection with an account with the lender (the “Pledged Account”), in which all amounts due to Ellomay Luzon Energy from Dorad will be deposited. The Loan Agreement provides that when any dividend is received from Dorad: (i) Ellomay Luzon Energy will leave in the Pledged Account the amount required for the next payment to the lender, (ii) to the extent the amount received during a calendar year exceeds NIS 65 million, then Ellomay Luzon Energy will make an early repayment of the First Loan and thereafter the Third Loan in the amount of 50% of the difference between the amount of receipts in the calendar year and NIS 65 million by no later than June 30 of the following year (pro rata over all future payments), and (iii) with respect to any amount in excess of the amounts required as stated in paragraphs (i) and (ii) – Ellomay Luzon Energy is entitled to use the funds deposited in the Pledged Account for any need, subject to the provisions of the law and the agreements with the lender. The Loan Agreement provides that the First and Third Loans may be prepaid without an early repayment fee and the Second Loan may be prepaid subject to payment of fees as generally acceptable in the lender.

    The Loan Agreement includes customary immediate repayment provisions, including in the event of a breach of an undertaking by Ellomay Luzon Energy, a deterioration in Ellomay Luzon Energy’s financial situation and the initiation of legal proceedings in connection with the Dorad shares held by Ellomay Luzon Energy. The Loan Agreement includes additional undertakings by Ellomay Luzon Energy, including not to amend the Ellomay Luzon Energy shareholders’ agreement without the lender’s prior written consent and the execution of an undertaking not to operate outside its current field of operations; not to assume financial obligations and not to provide financing to a third party; not to sell and/or transfer and/or deliver and/or lease and/or rent any Asset and/or any right of its rights, as well as a negative pledge on any Asset (as this term is defined below) and/or part of the its Assets, without the lender’s prior written consent, other than a pledge on its shares of Dorad in favor of the lenders of Dorad. The undertaking defines an “Asset” as any asset and right of Ellomay Luzon Energy, including the shares of Dorad held by it and other rights of any kind, including its unissued share capital and goodwill.

    On July 20, 2025, Edelcom filed a request with the Tel Aviv-Jaffa District Court (the “Court”) for injunctions and temporary injunctions, ex parte, aimed at preventing the receipt of approval from the Dorad board of directors and Dorad’s shareholders for the sale of 7.5% of Dorad’s shares to any third party other than Edelcom and preventing such a sale. The Court, in its decision date July 20, 2025, rejected the request for ex parte relief and directed Edelcom to update the Court on the decisions of Dorad’s board of directors and shareholders by July 22, 2025, and, to the extent that the request for interim relief is still relevant, to file a main proceeding by July 27, 2025, further noting that the respondents (among them, inter alia: Dorad, Ellomay Luzon Energy and Zorlu), will prepare to respond to the request for interim relief by July 30, 2025. The Court’s decision further noted that if future actions will be approved by Dorad based on a transfer of shares if it occurs (and this, as stated, without the Court preventing it), whereby the increased power of the respondents as shareholders is used for the purpose of changes in Dorad’s board of directors, or the transfer of the shares to third parties, as Edelcom noted that it fears, and to the extent that the respondents will try to take such actions or other irrevocable action, Edelcom will be notified seven days in advance, in a manner that will allow it time to act and the Court to give appropriate instructions. A hearing is scheduled for August 6, 2025.

    About Ellomay Capital Ltd.

    Ellomay is an Israeli based company whose shares are registered with the NYSE American and with the Tel Aviv Stock Exchange under the trading symbol “ELLO”. Since 2009, Ellomay focuses its business in the renewable energy and power sectors in Europe, the USA and Israel.

    To date, Ellomay has evaluated numerous opportunities and invested significant funds in the renewable, clean energy and natural resources industries in Israel, Italy, Spain, the Netherlands and Texas, USA, including:

    • Approximately 335.9 MW of operating solar power plants in Spain (including a 300 MW solar plant in owned by Talasol, which is 51% owned by the Company) and 51% of approximately 38 MW of operating solar power plants in Italy;
    • 9.375% indirect interest in Dorad Energy Ltd., which owns and operates one of Israel’s largest private power plants with production capacity of approximately 850MW, representing about 6%-8% of Israel’s total current electricity consumption;
    • Groen Gas Goor B.V., Groen Gas Oude-Tonge B.V. and Groen Gas Gelderland B.V., project companies operating anaerobic digestion plants in the Netherlands, with a green gas production capacity of approximately 3 million, 3.8 million and 9.5 million Nm3 per year, respectively;
    • 83.333% of Ellomay Pumped Storage (2014) Ltd., which is involved in a project to construct a 156 MW pumped storage hydro power plant in the Manara Cliff, Israel;
    • 51% of solar projects in Italy with an aggregate capacity of 160 MW that commenced construction processes;
    • Solar projects in Italy with an aggregate capacity of 134 MW that have reached “ready to build” status; and
    • Solar projects in the Dallas Metropolitan area, Texas, USA with an aggregate capacity of approximately 27 MW that are connected to the grid and additional 22 MW that are awaiting connection to the grid.

    For more information about Ellomay, visit http://www.ellomay.com.

    Information Relating to Forward-Looking Statements

    This press release contains forward-looking statements that involve substantial risks and uncertainties, including statements that are based on the current expectations and assumptions of the Company’s management. All statements, other than statements of historical facts, included in this press release regarding the Company’s plans and objectives, expectations and assumptions of management are forward-looking statements. The use of certain words, including the words “estimate,” “project,” “intend,” “expect,” “believe” and similar expressions are intended to identify forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. The Company may not actually achieve the plans, intentions or expectations disclosed in the forward-looking statements and you should not place undue reliance on the Company’s forward-looking statements. Various important factors could cause actual results or events to differ materially from those that may be expressed or implied by the Company’s forward-looking statements, including potential outcome of current and future litigation in connection with Dorad’s shares held by Ellomay Luzon Energy, changes in electricity prices and demand, regulatory changes increases in interest rates and inflation, changes in the supply and prices of resources required for the operation of the Company’s facilities (such as waste and natural gas) and in the price of oil, the impact of the war and hostilities in Israel and Gaza and between Israel and Iran, the impact of the continued military conflict between Russia and Ukraine, technical and other disruptions in the operations or construction of the power plants owned by the Company, inability to obtain the financing required for the development and construction of projects, inability to advance the expansion of Dorad, increases in interest rates and inflation, changes in exchange rates, delays in development, construction, or commencement of operation of the projects under development, failure to obtain permits – whether within the set time frame or at all, climate change, and general market, political and economic conditions in the countries in which the Company operates, including Israel, Spain, Italy and the United States. and general market, political and economic conditions in the countries in which the Company operates, including Israel, Spain, Italy and the United States. These and other risks and uncertainties associated with the Company’s business are described in greater detail in the filings the Company makes from time to time with Securities and Exchange Commission, including its Annual Report on Form 20-F. The forward-looking statements are made as of this date and the Company does not undertake any obligation to update any forward-looking statements, whether as a result of new information, future events or otherwise.

    Contact:
    Kalia Rubenbach (Weintraub)
    CFO
    Tel: +972 (3) 797-1111
    Email: hilai@ellomay.com

    The MIL Network

  • MIL-OSI: Range Announces Second Quarter 2025 Results

    Source: GlobeNewswire (MIL-OSI)

    FORT WORTH, Texas, July 22, 2025 (GLOBE NEWSWIRE) — RANGE RESOURCES CORPORATION (NYSE: RRC) today announced its second quarter 2025 financial results.

    Second Quarter 2025 Highlights –

    • Cash flow from operating activities of $336 million
    • Cash flow from operations, before working capital changes, of $301 million
    • Repurchased $53 million of shares, paid $21 million in dividends, and reduced net debt to $1.2 billion
    • Capital spending was $154 million, approximately 23% of the annual 2025 budget
    • Realized price, including hedges, was $3.49 per mcfe
    • Natural gas differential, including basis hedging, of ($0.50) per mcf to NYMEX
    • Pre-hedge NGL realizations of $23.73 per barrel – a premium of $0.61 over Mont Belvieu equivalent
    • Production averaged 2.20 Bcfe per day, approximately 68% natural gas
    • Improved 2025 production guidance and increased expected lateral footage in year-end inventory, while lowering 2025 capital due to operational efficiencies.

    Commenting on the results, Dennis Degner, the Company’s CEO said, “This year is off to a great start with another quarter of efficiency gains and consistent well performance driving strong free cash flow and building operational momentum. Our strong financial results supported $74 million in share repurchases and dividends, while lowering net debt to $1.2 billion. We believe Range is well positioned to benefit as in-basin demand opportunities materialize alongside a global call on natural gas. Range is one of the few producers in Appalachia with sufficient high-quality inventory to support the required growth in baseload supply. Further, Range’s continued efficiencies are supported by our countercyclical investments in drilled inventory over the last 18 months and consistent well results. Importantly, we intend to help meet future demand increases while also returning significant capital to shareholders.”

    Financial Discussion

    Except for generally accepted accounting principles (“GAAP”) reported amounts, specific expense categories exclude non-cash impairments, unrealized mark-to-market adjustment on derivatives, non-cash stock compensation and other items shown separately on the attached tables. “Unit costs” as used in this release are composed of direct operating, transportation, gathering, processing and compression, taxes other than income, general and administrative, interest and depletion, depreciation and amortization costs divided by production. See “Non-GAAP Financial Measures” for a definition of non-GAAP financial measures and the accompanying tables that reconcile each non-GAAP measure to its most directly comparable GAAP financial measure.

    Second Quarter 2025 Results

    GAAP revenues and other income for second quarter 2025 totaled $856 million, GAAP net cash provided from operating activities (including changes in working capital) was $336 million, and GAAP net income was $238 million ($0.99 per diluted share).  Second quarter earnings results include a $155 million mark-to-market derivative gain due to decreases in commodity prices.

    Cash flow from operations before changes in working capital, a non-GAAP measure, was $301 million.  Adjusted net income comparable to analysts’ estimates, a non-GAAP measure, was $158 million ($0.66 per diluted share) in second quarter 2025.

    The following table details Range’s second quarter 2025 unit costs per mcfe(a):

    Expenses   2Q 2025
    (per mcfe)
      2Q 2024
    (per mcfe)
      Increase (Decrease)
                 
    Direct operating(a)   $ 0.11   $ 0.11   0 %
    Transportation, gathering, processing and compression(a)     1.52     1.44   6 %
    Taxes other than income     0.04     0.03   33 %
    General and administrative(a)     0.16     0.16   0 %
    Interest expense(a)     0.13     0.14   (7 %)
    Total cash unit costs(b)          1.97     1.88   5 %
    Depletion, depreciation and amortization (DD&A)     0.46     0.45            2 %
    Total unit costs plus DD&A(b)   $ 2.43   $ 2.33   4 %

    (a) Excludes stock-based compensation, one-time settlements, and amortization of deferred financing costs.
    (b) Totals may not be exact due to rounding.

    The following table details Range’s average production and realized pricing for second quarter 2025(a):

      2Q25 Production & Realized Pricing
        Natural Gas
    (mcf)
      Oil (bbl)   NGLs
    (bbl)
      Natural Gas
    Equivalent (mcfe)
           
                     
    Net production per day     1,497,771       6,382       110,209     2,197,321
                     
    Average NYMEX price   $ 3.44     $ 63.72     $ 23.12    
    Differential, including basis hedging     (0.50 )     (10.95 )        0.61    
    Realized prices before NYMEX hedges     2.94       52.77       23.73     3.35
    Settled NYMEX hedges     0.19       1.45       0.15     0.14
    Average realized prices after hedges   $ 3.13     $ 54.22     $ 23.88   $ 3.49

    (a) Totals may not be exact due to rounding

    Second quarter 2025 natural gas, NGLs and oil price realizations (including the impact of cash-settled hedges and derivative settlements) averaged $3.49 per mcfe.

    • The average natural gas price, including the impact of basis hedging, was $2.94 per mcf, or a ($0.50) per mcf differential to NYMEX. Range continues to expect its 2025 natural gas differential to average ($0.40) to ($0.48) relative to NYMEX.
    • Range’s pre-hedge NGL price during the quarter was $23.73 per barrel, approximately $0.61 above the Mont Belvieu weighted equivalent. Range is improving its expected 2025 NGL differential to average +$0.40 to +$1.25 relative to a Mont Belvieu equivalent barrel.
    • Crude oil and condensate price realizations, before realized hedges, averaged $52.77 per barrel, or $10.95 below WTI (West Texas Intermediate). Range continues to expect its 2025 condensate differential to average ($10.00) to ($15.00) relative to NYMEX.

    Repurchase Activity and Financial Position

    During the second quarter, Range repurchased 1,453,438 shares at an average price of approximately $36.35 per share. As of June 30, 2025, the Company had approximately $900 million of availability under the share repurchase program.

    In May 2025, Range paid off the remaining principal balance of its 4.875% senior notes due 2025 at par by utilizing cash on hand and by borrowing on the bank credit facility. As of June 30, 2025, Range had net debt outstanding of approximately $1.22 billion, consisting of $1.1 billion of senior notes, $125 million on the facility, and $0.1 million in cash.

    Capital Expenditures and Operational Activity

    Second quarter 2025 drilling and completion expenditures were $136 million. In addition, during the quarter, approximately $11 million was invested in acreage, and $7 million was invested in infrastructure, pneumatic devices, and other investments. Year-to-date capital investments of $301 million are approximately $10 million below plan as a result of operational efficiencies. As a result, Range is lowering the high-end of its 2025 capital guide to $680 million.

    During the quarter, Range drilled ~285,000 lateral feet across 20 wells, while turning to sales ~156,000 lateral feet across 12 wells. The added inventory of drilled but not completed laterals places Range on track to exit 2025 with greater than 400,000 lateral feet of growth inventory to support future development.

    The table below summarizes expected 2025 activity plans regarding the number of wells to sales in each area.

          Wells TIL
    1H 2025
      Remaining
    2025
      2025
    Planned TIL
    SW PA Super-Rich     5   3   8
    SW PA Wet     17   12   29
    SW PA Dry     0   5   5
    NE PA Dry     0   4   4
    Total Wells     22   24   46
                   

    Guidance – 2025

    Updated Capital & Production Guidance

    Range’s 2025 all-in capital budget is now $650 million – $680 million, improved from prior guidance of $650 million – $690 million. Annual production is now expected to be approximately 2.225 Bcfe per day in 2025, updated from prior guidance of ~2.2 Bcfe per day. Liquids are expected to be over 30% of production.

    Updated Full Year 2025 Expense Guidance

      Updated Guidance   Prior Guidance
    Direct operating expense: $0.12 – $0.13 per mcfe   $0.12 – $0.14 per mcfe
    Transportation, gathering, processing and compression expense: $1.50 – $1.55 per mcfe   $1.50 – $1.55 per mcfe
    Taxes other than income: $0.03 – $0.04 per mcfe   $0.03 – $0.04 per mcfe
    Exploration expense: $24 – $28 million   $24 – $28 million
    G&A expense: $0.17 – $0.18 per mcfe   $0.17 – $0.19 per mcfe
    Net Interest expense: $0.12 – $0.13 per mcfe   $0.12 – $0.13 per mcfe
    DD&A expense: $0.45 – $0.46 per mcfe   $0.45 – $0.46 per mcfe
    Net brokered gas marketing expense: $8 – $12 million   $8 – $12 million
           

    Updated Full Year 2025 Price Guidance

    Based on recent market indications, Range expects to average the following price differentials for its production in 2025.

      Updated Guidance   Prior Guidance
    FY 2025 Natural Gas:(1) NYMEX minus $0.40 to $0.48   NYMEX minus $0.40 to $0.48
    FY 2025 Natural Gas Liquids:(2) MB plus $0.40 to $1.25 per barrel   MB plus $0.25 to $1.25 per barrel
    FY 2025 Oil/Condensate: WTI minus $10.00 to $15.00   WTI minus $10.00 to $15.00

    (1) Including basis hedging
    (2) Mont Belvieu-equivalent pricing based on weighting of 53% ethane, 27% propane, 8% normal butane, 4% iso-butane and 8% natural gasoline.

    Hedging Status

    Range hedges portions of its expected future production volumes to increase the predictability of cash flow and maintain a strong, flexible financial position. Please see the detailed hedging schedule posted on the Range website under Investor Relations – Financial Information.

    Range has also hedged basis across the Company’s numerous natural gas sales points to limit volatility between benchmark and regional prices. The combined fair value of natural gas basis hedges as of June 30, 2025, was a net gain of $19.9 million.

    Conference Call Information

    A conference call to review the financial results is scheduled on Wednesday, July 23 at 8:00 AM Central Time (9:00 AM Eastern Time). Please click here to pre-register for the conference call and obtain a dial in number with passcode.

    A simultaneous webcast of the call may be accessed at www.rangeresources.com. The webcast will be archived for replay on the Company’s website until August 23rd.

    Non-GAAP Financial Measures

    To supplement the presentation of its financial results prepared in accordance with generally accepted accounting principles (GAAP), the Company’s earnings press release contains certain financial measures that are not presented in accordance with GAAP. Management believes certain non-GAAP measures may provide financial statement users with meaningful supplemental information for comparisons within the industry. These non-GAAP financial measures may include, but are not limited to Net Income, excluding certain items, Cash flow from operations before changes in working capital, realized prices, Net debt and Cash margin.

    Adjusted net income comparable to analysts’ estimates as set forth in this release represents income or loss from operations before income taxes adjusted for certain non-cash items (detailed in the accompanying table) less income taxes. We believe adjusted net income comparable to analysts’ estimates is calculated on the same basis as analysts’ estimates and that many investors use this published research in making investment decisions and evaluating operational trends of the Company and its performance relative to other oil and gas producing companies. Diluted earnings per share (adjusted) as set forth in this release represents adjusted net income comparable to analysts’ estimates on a diluted per share basis. A table is included which reconciles income or loss from operations to adjusted net income comparable to analysts’ estimates and diluted earnings per share (adjusted). On its website, the Company provides additional comparative information on prior periods.

    Cash flow from operations before changes in working capital represents net cash provided by operations before changes in working capital and exploration expense adjusted for certain non-cash compensation items. Cash flow from operations before changes in working capital (sometimes referred to as “adjusted cash flow”) is widely accepted by the investment community as a financial indicator of an oil and gas company’s ability to generate cash to internally fund exploration and development activities and to service debt. Cash flow from operations before changes in working capital is also useful because it is widely used by professional research analysts in valuing, comparing, rating and providing investment recommendations of companies in the oil and gas exploration and production industry. In turn, many investors use this published research in making investment decisions. Cash flow from operations before changes in working capital is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operations, investing, or financing activities as an indicator of cash flows, or as a measure of liquidity. A table is included which reconciles net cash provided by operations to cash flow from operations before changes in working capital as used in this release. On its website, the Company provides additional comparative information on prior periods for cash flow, cash margins and non-GAAP earnings as used in this release.

    The cash prices realized for oil and natural gas production, including the amounts realized on cash-settled derivatives and net of transportation, gathering, processing and compression expense, is a critical component in the Company’s performance tracked by investors and professional research analysts in valuing, comparing, rating and providing investment recommendations and forecasts of companies in the oil and gas exploration and production industry. In turn, many investors use this published research in making investment decisions. Due to the GAAP disclosures of various derivative transactions and third-party transportation, gathering, processing and compression expense, such information is now reported in various lines of the income statement. The Company believes that it is important to furnish a table reflecting the details of the various components of each income statement line to better inform the reader of the details of each amount and provide a summary of the realized cash-settled amounts and third-party transportation, gathering, processing and compression expense, which were historically reported as natural gas, NGLs and oil sales. This information is intended to bridge the gap between various readers’ understanding and fully disclose the information needed.

    Net debt is calculated as total debt less cash and cash equivalents. The Company believes this measure is helpful to investors and industry analysts who utilize Net debt for comparative purposes across the industry.

    The Company discloses in this release the detailed components of many of the single line items shown in the GAAP financial statements included in the Company’s Annual or Quarterly Reports on Form 10-K or 10-Q. The Company believes that it is important to furnish this detail of the various components comprising each line of the Statements of Operations to better inform the reader of the details of each amount, the changes between periods and the effect on its financial results.
      
    We believe that the presentation of PV10 value of our proved reserves is a relevant and useful metric for our investors as supplemental disclosure to the standardized measure, or after-tax amount, because it presents the discounted future net cash flows attributable to our proved reserves before taking into account future corporate income taxes and our current tax structure. While the standardized measure is dependent on the unique tax situation of each company, PV10 is based on prices and discount factors that are consistent for all companies. Because of this, PV10 can be used within the industry and by credit and security analysts to evaluate estimated net cash flows from proved reserves on a more comparable basis.

    RANGE RESOURCES CORPORATION (NYSE: RRC) is a leading U.S. independent natural gas and NGL producer with operations focused in the Appalachian Basin. The Company is headquartered in Fort Worth, Texas.  More information about Range can be found at www.rangeresources.com.

    Included within this release are certain “forward-looking statements” within the meaning of the federal securities laws, including the safe harbor provisions of the Private Securities Litigation Reform Act of 1995, that are not limited to historical facts, but reflect Range’s current beliefs, expectations or intentions regarding future events.  Words such as “may,” “will,” “could,” “should,” “expect,” “plan,” “project,” “intend,” “anticipate,” “believe,” “outlook”, “estimate,” “predict,” “potential,” “pursue,” “target,” “continue,” and similar expressions are intended to identify such forward-looking statements.

    All statements, except for statements of historical fact, made within regarding activities, events or developments the Company expects, believes or anticipates will or may occur in the future, such as those regarding future well costs, expected asset sales, well productivity, future liquidity and financial resilience, anticipated exports and related financial impact, NGL market supply and demand, future commodity fundamentals and pricing, future capital efficiencies, future shareholder value, emerging plays, capital spending, anticipated drilling and completion activity, acreage prospectivity, expected pipeline utilization and future guidance information, are forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. These statements are based on assumptions and estimates that management believes are reasonable based on currently available information; however, management’s assumptions and Range’s future performance are subject to a wide range of business risks and uncertainties and there is no assurance that these goals and projections can or will be met. Any number of factors could cause actual results to differ materially from those in the forward-looking statements. Further information on risks and uncertainties is available in Range’s filings with the Securities and Exchange Commission (SEC), including its most recent Annual Report on Form 10-K. Unless required by law, Range undertakes no obligation to publicly update or revise any forward-looking statements to reflect circumstances or events after the date they are made.

    The SEC permits oil and gas companies, in filings made with the SEC, to disclose proved reserves, which are estimates that geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions as well as the option to disclose probable and possible reserves. Range has elected not to disclose its probable and possible reserves in its filings with the SEC. Range uses certain broader terms such as “resource potential,” “unrisked resource potential,” “unproved resource potential” or “upside” or other descriptions of volumes of resources potentially recoverable through additional drilling or recovery techniques that may include probable and possible reserves as defined by the SEC’s guidelines. Range has not attempted to distinguish probable and possible reserves from these broader classifications. The SEC’s rules prohibit us from including in filings with the SEC these broader classifications of reserves. These estimates are by their nature more speculative than estimates of proved, probable and possible reserves and accordingly are subject to substantially greater risk of actually being realized. Unproved resource potential refers to Range’s internal estimates of hydrocarbon quantities that may be potentially discovered through exploratory drilling or recovered with additional drilling or recovery techniques and have not been reviewed by independent engineers. Unproved resource potential does not constitute reserves within the meaning of the Society of Petroleum Engineer’s Petroleum Resource Management System and does not include proved reserves. Area wide unproven resource potential has not been fully risked by Range’s management. “EUR”, or estimated ultimate recovery, refers to our management’s estimates of hydrocarbon quantities that may be recovered from a well completed as a producer in the area. These quantities may not necessarily constitute or represent reserves within the meaning of the Society of Petroleum Engineer’s Petroleum Resource Management System or the SEC’s oil and natural gas disclosure rules. Actual quantities that may be recovered from Range’s interests could differ substantially. Factors affecting ultimate recovery include the scope of Range’s drilling program, which will be directly affected by the availability of capital, drilling and production costs, commodity prices, availability of drilling services and equipment, drilling results, lease expirations, transportation constraints, regulatory approvals, field spacing rules, recoveries of gas in place, length of horizontal laterals, actual drilling results, including geological and mechanical factors affecting recovery rates and other factors. Estimates of resource potential may change significantly as development of our resource plays provides additional data.

    In addition, our production forecasts and expectations for future periods are dependent upon many assumptions, including estimates of production decline rates from existing wells and the undertaking and outcome of future drilling activity, which may be affected by significant commodity price or drilling cost changes. Investors are urged to consider closely the disclosure in our most recent Annual Report on Form 10-K, available from our website at www.rangeresources.com or by written request to 100 Throckmorton Street, Suite 1200, Fort Worth, Texas 76102. You can also obtain this Form 10-K on the SEC’s website at www.sec.gov or by calling the SEC at 1-800-SEC-0330.

    SOURCE: Range Resources Corporation

    Range Investor Contacts:

    Laith Sando
    817-869-4267

    Matt Schmid
    817-869-1538

    Range Media Contact:

    Mark Windle
    724-873-3223

    RANGE RESOURCES CORPORATION  
                                       
                                       
    STATEMENTS OF OPERATIONS                                  
    Based on GAAP reported earnings with additional                                  
    details of items included in each line in Form 10-Q                                  
    (Unaudited, In thousands, except per share data)                                  
      Three Months Ended June 30,     Six Months Ended June 30,  
      2025     2024     %     2025     2024     %  
    Revenues and other income:                                  
    Natural gas, NGLs and oil sales (a) $ 666,638     $ 478,450           $ 1,458,558     $ 1,045,451        
    Derivative fair value income (loss)   154,747       16,808             (4,210 )     63,406        
    Brokered natural gas and marketing   33,009       31,393             87,417       60,224        
    ARO settlement gain (loss) (b)   1                   1       (26 )      
    Interest income (b)   1,762       3,376             4,815       6,319        
    Gain on sale of assets (b)   102       66             164       153        
    Other (b)   16       16             84       38        
    Total revenues and other income   856,275       530,109       62 %     1,546,829       1,175,565       32 %
                                       
    Costs and expenses:                                  
    Direct operating   22,616       22,281             47,452       43,945        
    Direct operating – stock-based compensation (c)   504       471             1,041       968        
    Transportation, gathering, processing and compression   304,714       281,495             610,823       572,370        
    Taxes other than income   7,835       4,974             14,822       10,342        
    Brokered natural gas and marketing   34,183       33,513             91,544       64,408        
    Brokered natural gas and marketing – stock-based compensation (c)   802       583             1,642       1,291        
    Exploration   7,562       6,316             13,606       10,518        
    Exploration – stock-based compensation (c)   366       335             713       659        
    Abandonment and impairment of unproved properties   6,781       1,524             11,355       3,895        
    General and administrative   32,757       31,372             64,310       65,144        
    General and administrative – stock-based compensation (c)   9,326       8,482             19,437       18,460        
    General and administrative – lawsuit settlements   63       287             90       478        
    Exit costs   8,502       10,094             17,399       20,409        
    Deferred compensation plan (d)   (88 )     1,240             2,791       7,645        
    Interest expense   25,630       28,356             53,415       57,472        
    Interest expense – amortization of deferred financing costs (e)   1,166       1,357             2,542       2,717        
    Gain on early extinguishment of debt         (179 )           (3 )     (243 )      
    Depletion, depreciation and amortization   91,514       87,598             182,073       174,735        
    Total costs and expenses   554,233       520,099       7 %     1,135,052       1,055,213       8 %
                                       
    Income before income taxes   302,042       10,010       2917 %     411,777       120,352       242 %
                                       
    Income tax expense (benefit)                                  
    Current   4,645       2,399             6,645       3,981        
    Deferred   59,819       (21,093 )           70,502       (4,471 )      
        64,464       (18,694 )           77,147       (490 )      
                                       
    Net income $ 237,578     $ 28,704       728 %   $ 334,630     $ 120,842       177 %
                                       
                                       
    Net income Per Common Share                                  
    Basic $ 0.99     $ 0.12           $ 1.40     $ 0.50        
    Diluted $ 0.99     $ 0.12           $ 1.39     $ 0.49        
                                       
    Weighted average common shares outstanding, as reported                                  
    Basic   238,187       241,125       -1 %     239,106       240,815       -1 %
    Diluted   239,717       242,983       -1 %     240,772       242,766       -1 %
                                       
                                       
    (a) See separate natural gas, NGLs and oil sales information table.  
    (b) Included in Other income in the 10-Q.  
    (c) Costs associated with stock compensation and restricted stock amortization, which have been reflected  
        in the categories associated with the direct personnel costs, which are combined with the cash costs in the 10-Q.  
    (d) Reflects the change in market value of the vested Company stock held in the deferred compensation plan.  
    (e) Included in interest expense in the 10-Q.  
       
    RANGE RESOURCES CORPORATION  
               
               
    BALANCE SHEET          
    (In thousands) June 30,     December 31,  
      2025     2024  
      (Unaudited)     (Audited)  
    Assets          
    Current assets $ 272,616     $ 636,982  
    Derivative assets   51,115       87,098  
    Natural gas and oil properties, net (successful efforts method)   6,535,097       6,421,700  
    Other property and equipment, net   2,736       2,465  
    Operating lease right-of-use assets   170,159       119,838  
    Other   73,388       79,592  
      $ 7,105,111     $ 7,347,675  
               
    Liabilities and Stockholders’ Equity          
    Current liabilities $ 580,744     $ 1,263,247  
    Asset retirement obligations   1,189       1,189  
    Derivative liabilities   1,201       9,634  
               
    Bank debt   121,092        
    Senior notes, excluding current maturities   1,090,607       1,089,614  
    Deferred tax liabilities   611,873       541,378  
    Derivative liabilities   23,187       10,488  
    Deferred compensation liabilities   64,262       65,233  
    Operating lease liabilities   109,026       35,737  
    Asset retirement obligations and other liabilities   143,174       137,181  
    Divestiture contract obligation   232,062       257,317  
        2,978,417       3,411,018  
               
    Common stock and retained deficit   4,761,293       4,449,987  
    Other comprehensive income   582       611  
    Common stock held in treasury   (635,181 )     (513,941 )
    Total stockholders’ equity   4,126,694       3,936,657  
      $ 7,105,111     $ 7,347,675  
                   
    RECONCILIATION OF TOTAL DEBT AS REPORTED                
    TO NET DEBT, a non-GAAP measure                
    (Unaudited, in thousands)                
      June 30,     December 31,        
      2025     2024     %  
                     
    Total debt, net of deferred financing costs, as reported $ 1,211,699     $ 1,697,883       -29 %
    Unamortized debt issuance costs, as reported   13,301       10,819        
    Less cash and cash equivalents, as reported   (134 )     (304,490 )      
    Net debt, a non-GAAP measure $ 1,224,866     $ 1,404,212       -13 %
                           
    RANGE RESOURCES CORPORATION  
                           
                           
                           
    CASH FLOWS FROM OPERATING ACTIVITIES                      
    (Unaudited, in thousands)                      
                           
      Three Months Ended June 30,     Six Months Ended June 30,  
      2025     2024     2025     2024  
                           
    Net income $ 237,578     $ 28,704     $ 334,630     $ 120,842  
    Adjustments to reconcile net cash provided from continuing operations:                      
    Deferred income tax expense (benefit)   59,819       (21,093 )     70,502       (4,471 )
    Depletion, depreciation and amortization   91,514       87,598       182,073       174,735  
    Abandonment and impairment of unproved properties   6,781       1,524       11,355       3,895  
    Derivative fair value (income) loss   (154,747 )     (16,808 )     4,210       (63,406 )
    Cash settlements on derivative financial instruments   31,466       128,057       36,039       250,430  
    Divestiture contract obligation, including accretion   8,502       10,062       17,399       20,329  
    Amortization of deferred financing costs and other   962       1,193       2,144       2,425  
    Deferred and stock-based compensation   11,047       11,122       26,130       29,337  
    Gain on sale of assets   (102 )     (66 )     (164 )     (153 )
    Loss (gain) on early extinguishment of debt         (179 )     (3 )     (243 )
                           
    Changes in working capital:                      
    Accounts receivable   96,785       (30,541 )     68,064       76,913  
    Other current assets   518       (13,461 )     (8,510 )     (22,405 )
    Accounts payable   (27,023 )     (17,906 )     9,158       (5,718 )
    Accrued liabilities and other   (26,912 )     (19,431 )     (86,754 )     (101,805 )
    Net changes in working capital   43,368       (81,339 )     (18,042 )     (53,015 )
    Net cash provided from operating activities $ 336,188     $ 148,775     $ 666,273     $ 480,705  
                           
                           
                           
    RECONCILIATION OF NET CASH PROVIDED FROM OPERATING                      
    ACTIVITIES, AS REPORTED, TO CASH FLOW FROM OPERATIONS                      
    BEFORE CHANGES IN WORKING CAPITAL, a non-GAAP measure                      
    (Unaudited, in thousands)                      
      Three Months Ended June 30,     Six Months Ended June 30,  
      2025     2024     2025     2024  
    Net cash provided from operating activities, as reported $ 336,188     $ 148,775     $ 666,273     $ 480,705  
    Net changes in working capital   (43,368 )     81,339       18,042       53,015  
    Exploration expense   7,562       6,316       13,606       10,518  
    Lawsuit settlements   63       287       90       478  
    Non-cash compensation adjustment and other   66       185       (109 )     84  
    Cash flow from operations before changes in working capital – non-GAAP measure $ 300,511     $ 236,902     $ 697,902     $ 544,800  
                           
                           
                           
    ADJUSTED WEIGHTED AVERAGE SHARES OUTSTANDING                      
    (Unaudited, in thousands)                      
      Three Months Ended June 30,     Six Months Ended June 30,  
      2025     2024     2025     2024  
    Basic:                      
    Weighted average shares outstanding   238,804       242,647       239,785       242,365  
    Stock held by deferred compensation plan   (617 )     (1,522 )     (679 )     (1,550 )
    Adjusted basic   238,187       241,125       239,106       240,815  
                           
    Dilutive:                      
    Weighted average shares outstanding   238,804       242,647       239,785       242,365  
    Dilutive stock options under treasury method   913       336       987       401  
    Adjusted dilutive   239,717       242,983       240,772       242,766  
                                   
    RANGE RESOURCES CORPORATION  
                                       
                                       
    RECONCILIATION OF NATURAL GAS, NGLs AND OIL SALES                                  
    AND DERIVATIVE FAIR VALUE INCOME (LOSS) TO                                  
    CALCULATED CASH REALIZED NATURAL GAS, NGLs AND                                  
    OIL PRICES WITH AND WITHOUT THIRD-PARTY                                  
    TRANSPORTATION, GATHERING, PROCESSING AND                                  
    COMPRESSION COSTS, a non-GAAP measure                                  
    (Unaudited, In thousands, except per unit data)                      
      Three Months Ended June 30,     Six Months Ended June 30,  
      2025     2024     %     2025     2024     %  
    Natural gas, NGLs and Oil Sales components:                                  
    Natural gas sales $ 397,955     $ 209,652           $ 888,332     $ 481,127        
    NGLs sales   238,034       228,285             513,688       484,361        
    Oil sales   30,649       40,513             56,538       79,963        
    Total Natural Gas, NGLs and Oil Sales, as reported $ 666,638     $ 478,450       39 %   $ 1,458,558     $ 1,045,451       40 %
                                       
    Derivative Fair Value Income (Loss), as reported $ 154,747     $ 16,808           $ (4,210 )   $ 63,406        
    Cash settlements on derivative financial instruments – (gain) loss:                                  
    Natural gas   (29,114 )     (126,194 )           (33,843 )     (247,107 )      
    NGLs   (1,508 )     (1,978 )           (1,096 )     (1,901 )      
    Oil   (844 )     115             (1,100 )     (1,422 )      
    Total change in fair value related to commodity derivatives prior to                                  
    settlement, a non-GAAP measure $ 123,281     $ (111,249 )         $ (40,249 )   $ (187,024 )      
                                       
    Transportation, gathering, processing and compression components:                                  
    Natural Gas $ 154,704     $ 153,040           $ 312,223     $ 303,152        
    NGLs   149,209       128,077             297,047       268,351        
    Oil   801       378             1,553       867        
    Total transportation, gathering, processing and compression, as reported $ 304,714     $ 281,495           $ 610,823     $ 572,370        
                                       
    Natural gas, NGL and Oil sales, including cash-settled derivatives: (c)                                  
    Natural gas sales $ 427,069     $ 335,846           $ 922,175     $ 728,234        
    NGLs sales   239,542       230,263             514,784       486,262        
    Oil Sales   31,493       40,398             57,638       81,385        
    Total $ 698,104     $ 606,507       15 %   $ 1,494,597     $ 1,295,881       15 %
                                       
    Production of natural gas, NGLs and oil during the periods (a):                                  
    Natural Gas (mcf)   136,297,159       136,099,063       0 %     272,260,589       268,749,303       1 %
    NGLs (bbls)   10,029,051       9,376,810       7 %     19,949,040       19,137,533       4 %
    Oil (bbls)   580,791       593,020       -2 %     1,004,370       1,203,299       -17 %
    Gas equivalent (mcfe) (b)   199,956,211       195,918,043       2 %     397,981,049       390,794,295       2 %
                                       
    Production of natural gas, NGLs and oil – average per day (a):                                  
    Natural Gas (mcf)   1,497,771       1,495,594       0 %     1,504,202       1,476,645       2 %
    NGLs (bbls)   110,209       103,042       7 %     110,216       105,151       5 %
    Oil (bbls)   6,382       6,517       -2 %     5,549       6,612       -16 %
    Gas equivalent (mcfe) (b)   2,197,321       2,152,946       2 %     2,198,790       2,147,221       2 %
                                       
    Average prices, excluding derivative settlements and before third-party                                  
    transportation costs:                                  
    Natural Gas (per mcf) $ 2.92     $ 1.54       90 %   $ 3.26     $ 1.79       82 %
    NGLs (per bbl) $ 23.73     $ 24.35       -3 %   $ 25.75     $ 25.31       2 %
    Oil (per bbl) $ 52.77     $ 68.32       -23 %   $ 56.29     $ 66.45       -15 %
    Gas equivalent (per mcfe) (b) $ 3.33     $ 2.44       36 %   $ 3.66     $ 2.68       37 %
                                       
    Average prices, including derivative settlements before third-party                                  
    transportation costs: (c)                                  
    Natural Gas (per mcf) $ 3.13     $ 2.47       27 %   $ 3.39     $ 2.71       25 %
    NGLs (per bbl) $ 23.88     $ 24.56       -3 %   $ 25.80     $ 25.41       2 %
    Oil (per bbl) $ 54.22     $ 68.12       -20 %   $ 57.39     $ 67.63       -15 %
    Gas equivalent (per mcfe) (b) $ 3.49     $ 3.10       13 %   $ 3.75     $ 3.32       13 %
                                       
    Average prices, including derivative settlements and after third-party                                  
    transportation costs: (d)                                  
    Natural Gas (per mcf) $ 2.00     $ 1.34       49 %   $ 2.24     $ 1.58       42 %
    NGLs (per bbl) $ 9.01     $ 10.90       -17 %   $ 10.91     $ 11.39       -4 %
    Oil (per bbl) $ 52.84     $ 67.48       -22 %   $ 55.84     $ 66.91       -17 %
    Gas equivalent (per mcfe) (b) $ 1.97     $ 1.66       19 %   $ 2.22     $ 1.85       20 %
                                       
    Transportation, gathering and compression expense per mcfe $ 1.52     $ 1.44       6 %   $ 1.53     $ 1.47       4 %
                                       
    (a) Represents volumes sold regardless of when produced.  
    (b) Oil and NGLs are converted at the rate of one barrel equals six mcfe based upon the approximate relative energy content of oil to natural gas, which is not necessarily  
    indicative of the relationship of oil and natural gas prices.  
    (c) Excluding third-party transportation, gathering, processing and compression costs.  
    (d) Net of transportation, gathering, processing and compression costs.  
       
    RANGE RESOURCES CORPORATION  
                                       
                                       
                                       
    RECONCILIATION OF INCOME BEFORE INCOME                                  
    TAXES AS REPORTED TO INCOME BEFORE INCOME TAXES                                  
    EXCLUDING CERTAIN ITEMS, a non-GAAP measure                                  
    (Unaudited, In thousands, except per share data)                                  
      Three Months Ended June 30,     Six Months Ended June 30,  
      2025     2024     %     2025     2024     %  
                                       
    Income from operations before income taxes, as reported $ 302,042     $ 10,010       2917 %   $ 411,777     $ 120,352       242 %
    Adjustment for certain special items:                                  
    Gain on the sale of assets   (102 )     (66 )           (164 )     (153 )      
    ARO settlement (gain) loss   (1 )                 (1 )     26        
    Change in fair value related to derivatives prior to settlement   (123,281 )     111,249             40,249       187,024        
    Abandonment and impairment of unproved properties   6,781       1,524             11,355       3,895        
    Loss (gain) on early extinguishment of debt         (179 )           (3 )     (243 )      
    Lawsuit settlements   63       287             90       478        
    Exit costs   8,502       10,094             17,399       20,409        
    Brokered natural gas and marketing – stock-based compensation   802       583             1,642       1,291        
    Direct operating – stock-based compensation   504       471             1,041       968        
    Exploration expenses – stock-based compensation   366       335             713       659        
    General & administrative – stock-based compensation   9,326       8,482             19,437       18,460        
    Deferred compensation plan – non-cash adjustment   (88 )     1,240             2,791       7,645        
                                       
    Income before income taxes, as adjusted   204,914       144,030       42 %     506,326       360,811       40 %
                                       
    Income tax expense, as adjusted                                  
    Current   4,645       2,399             6,645       3,981        
    Deferred (a)   42,485       30,728             109,810       79,006        
                                       
    Net income, excluding certain items, a non-GAAP measure $ 157,784     $ 110,903       42 %   $ 389,871     $ 277,824       40 %
                                       
    Non-GAAP income per common share                                  
    Basic $ 0.66     $ 0.46       43 %   $ 1.63     $ 1.15       42 %
    Diluted $ 0.66     $ 0.46       43 %   $ 1.62     $ 1.14       42 %
                                       
    Non-GAAP diluted shares outstanding, if dilutive   239,717       242,983             240,772       242,766        
                                       
                                       
                                       
    (a) Taxes are estimated to be approximately 23% for 2024 and 2025  
       
    RANGE RESOURCES CORPORATION  
                           
                           
                           
    RECONCILIATION OF NET INCOME, EXCLUDING                      
    CERTAIN ITEMS AND ADJUSTED EARNINGS PER                      
    SHARE, non-GAAP measures                      
    (In thousands, except per share data)                      
      Three Months Ended June 30,     Six Months Ended June 30,  
      2025     2024     2025     2024  
                           
    Net income, as reported $ 237,578     $ 28,704     $ 334,630     $ 120,842  
    Adjustments for certain special items:                      
    Gain on the sale of assets   (102 )     (66 )     (164 )     (153 )
    ARO settlement (gain) loss   (1 )           (1 )     26  
    Gain on early extinguishment of debt         (179 )     (3 )     (243 )
    Change in fair value related to derivatives prior to settlement   (123,281 )     111,249       40,249       187,024  
    Abandonment and impairment of unproved properties   6,781       1,524       11,355       3,895  
    Lawsuit settlements   63       287       90       478  
    Exit costs   8,502       10,094       17,399       20,409  
    Stock-based compensation   10,998       9,871       22,833       21,378  
    Deferred compensation plan   (88 )     1,240       2,791       7,645  
    Tax impact   17,334       (51,821 )     (39,308 )     (83,477 )
                           
    Net income, excluding certain items, a non-GAAP measure $ 157,784     $ 110,903     $ 389,871     $ 277,824  
                           
    Net income per diluted share, as reported $ 0.99     $ 0.12     $ 1.39     $ 0.49  
    Adjustments for certain special items per diluted share:                      
    Gain on the sale of assets                      
    ARO settlement (gain) loss                      
    Gain on early extinguishment of debt                      
    Change in fair value related to derivatives prior to settlement   (0.51 )     0.46       0.17       0.77  
    Abandonment and impairment of unproved properties   0.03       0.01       0.05       0.02  
    Lawsuit settlements                      
    Exit costs   0.04       0.04       0.07       0.08  
    Stock-based compensation   0.05       0.04       0.09       0.09  
    Deferred compensation plan         0.01       0.01       0.03  
    Adjustment for rounding differences   (0.01 )     (0.01 )            
    Tax impact   0.07       (0.21 )     (0.16 )     (0.34 )
    Dilutive share impact (rabbi trust and other)                      
                           
    Net income per diluted share, excluding certain items, a non-GAAP measure $ 0.66     $ 0.46     $ 1.62     $ 1.14  
                           
    Adjusted earnings per share, a non-GAAP measure:                      
    Basic $ 0.66     $ 0.46     $ 1.63     $ 1.15  
    Diluted $ 0.66     $ 0.46     $ 1.62     $ 1.14  
                                   
    RANGE RESOURCES CORPORATION  
                           
                           
    RECONCILIATION OF CASH MARGIN PER MCFE, a non-                      
    GAAP measure                      
    (Unaudited, In thousands, except per unit data)                      
      Three Months Ended June 30,     Six Months Ended June 30,  
      2025     2024     2025     2024  
                           
    Revenues                      
    Natural gas, NGLs and oil sales, as reported $ 666,638     $ 478,450     $ 1,458,558     $ 1,045,451  
    Derivative fair value income (loss), as reported   154,747       16,808       (4,210 )     63,406  
    Less non-cash fair value (gain) loss   (123,281 )     111,249       40,249       187,024  
    Brokered natural gas and marketing, as reported   33,009       31,393       87,417       60,224  
    Other income, as reported   1,881       3,458       5,064       6,484  
    Less gain on sale of assets   (102 )     (66 )     (164 )     (153 )
    Less ARO settlement   (1 )           (1 )     26  
    Cash revenues   732,891       641,292       1,586,913       1,362,462  
                           
    Expenses                      
    Direct operating, as reported   23,120       22,752       48,493       44,913  
    Less direct operating stock-based compensation   (504 )     (471 )     (1,041 )     (968 )
    Transportation, gathering and compression, as reported   304,714       281,495       610,823       572,370  
    Taxes other than income, as reported   7,835       4,974       14,822       10,342  
    Brokered natural gas and marketing, as reported   34,985       34,096       93,186       65,699  
    Less brokered natural gas and marketing stock-based compensation   (802 )     (583 )     (1,642 )     (1,291 )
    General and administrative, as reported   42,146       40,141       83,837       84,082  
    Less G&A stock-based compensation   (9,326 )     (8,482 )     (19,437 )     (18,460 )
    Less lawsuit settlements   (63 )     (287 )     (90 )     (478 )
    Interest expense, as reported   26,796       29,713       55,957       60,189  
    Less amortization of deferred financing costs   (1,166 )     (1,357 )     (2,542 )     (2,717 )
    Cash expenses   427,735       401,991       882,366       813,681  
                           
    Cash margin, a non-GAAP measure $ 305,156     $ 239,301     $ 704,547     $ 548,781  
                           
    Mmcfe produced during period   199,956       195,918       397,981       390,794  
                           
    Cash margin per mcfe $ 1.53     $ 1.22     $ 1.77     $ 1.40  
                           
    RECONCILIATION OF INCOME BEFORE INCOME TAXES                      
    TO CASH MARGIN, a non-GAAP measure                      
    (Unaudited, in thousands, except per unit data)                      
      Three Months Ended June 30,     Six Months Ended June 30,  
      2025     2024     2025     2024  
                           
    Income before income taxes, as reported $ 302,042     $ 10,010     $ 411,777     $ 120,352  
    Adjustments to reconcile income before income taxes                      
    to cash margin:                      
    ARO settlements   (1 )           (1 )     26  
    Derivative fair value (income) loss   (154,747 )     (16,808 )     4,210       (63,406 )
    Net cash receipts on derivative settlements   31,466       128,057       36,039       250,430  
    Exploration expense   7,562       6,316       13,606       10,518  
    Lawsuit settlements   63       287       90       478  
    Exit costs   8,502       10,094       17,399       20,409  
    Deferred compensation plan   (88 )     1,240       2,791       7,645  
    Stock-based compensation (direct operating, brokered natural gas and   10,998       9,871       22,833       21,378  
    marketing and general and administrative)                      
    Bad debt expense                      
    Interest – amortization of deferred financing costs   1,166       1,357       2,542       2,717  
    Depletion, depreciation and amortization   91,514       87,598       182,073       174,735  
    Gain on sale of assets   (102 )     (66 )     (164 )     (153 )
    Gain on early extinguishment of debt         (179 )     (3 )     (243 )
    Abandonment and impairment of unproved properties   6,781       1,524       11,355       3,895  
    Cash margin, a non-GAAP measure $ 305,156     $ 239,301     $ 704,547     $ 548,781  

    The MIL Network

  • MIL-OSI: Enphase Energy Reports Financial Results for the Second Quarter of 2025

    Source: GlobeNewswire (MIL-OSI)

    FREMONT, Calif., July 22, 2025 (GLOBE NEWSWIRE) — Enphase Energy, Inc. (NASDAQ: ENPH), a global energy technology company and the world’s leading supplier of microinverter-based solar and battery systems, announced today financial results for the second quarter of 2025, which included the summary below from its President and CEO, Badri Kothandaraman.

    We reported quarterly revenue of $363.2 million in the second quarter of 2025, along with 48.6% for non-GAAP gross margin. We shipped approximately 1.53 million microinverters, or 675.4 megawatts DC, and 190.9 megawatt hours (MWh) of IQ® Batteries.

    Highlights for the second quarter of 2025 are listed below:

    • IQ® Meter Collar approved by 29 U.S. utilities to date
    • U.S. manufacturing: shipped approximately 1.41 million microinverters and record 46.9 MWh of IQ Batteries
    • Revenue of $363.2 million
    • GAAP gross margin of 46.9%; non-GAAP gross margin of 48.6% with net IRA benefit
    • Non-GAAP gross margin of 37.2%, excluding net IRA benefit of 11.4%
    • GAAP operating income of $37.0 million; non-GAAP operating income of $98.6 million
    • GAAP net income of $37.1 million; non-GAAP net income of $89.9 million
    • GAAP diluted earnings per share of $0.28; non-GAAP diluted earnings per share of $0.69
    • Free cash flow of $18.4 million; ending cash, cash equivalents and marketable securities of $1.53 billion

    Our revenue and earnings for the second quarter of 2025 are provided below, compared with the prior quarter:

    (In thousands, except per share and percentage data)

      GAAP   Non-GAAP
      Q2 2025   Q1 2025   Q2 2024   Q2 2025   Q1 2025   Q2 2024
    Revenue $ 363,153     $ 356,084     $ 303,458     $ 363,153     $ 356,084     $ 303,458  
    Gross margin   46.9 %     47.2 %     45.2 %     48.6 %     48.9 %     47.1 %
    Operating expenses $ 133,486     $ 136,319     $ 135,367     $ 77,781     $ 79,423     $ 81,706  
    Operating income $ 37,007     $ 31,922     $ 1,799     $ 98,613     $ 94,637     $ 61,080  
    Net income $ 37,052     $ 29,730     $ 10,833     $ 89,869     $ 89,243     $ 58,824  
    Basic EPS $ 0.28     $ 0.23     $ 0.08     $ 0.69     $ 0.68     $ 0.43  
    Diluted EPS $ 0.28     $ 0.22     $ 0.08     $ 0.69     $ 0.68     $ 0.43  
     

    Total revenue for the second quarter of 2025 was $363.2 million, compared to $356.1 million in the first quarter of 2025. Our revenue in the second quarter of 2025 included $40.4 million of safe harbor revenue, compared to $54.3 million of safe harbor revenue in the first quarter. Our revenue in the United States for the second quarter of 2025 increased approximately 3%, compared to the first quarter. The increase was the result of seasonality partially offset by lower safe harbor revenue. Our revenue in Europe increased approximately 11% for the second quarter of 2025, compared to the first quarter. The increase in revenue was primarily due to higher microinverter and battery sales as we continued to ramp shipments of our IQ® Battery 5P™ with FlexPhase during the second quarter.

    Our non-GAAP gross margin was 48.6% in the second quarter of 2025, compared to 48.9% in the first quarter. Our non-GAAP gross margin, excluding net benefit from the Inflation Reduction Act (IRA), was 37.2% in the second quarter of 2025, compared to 38.3% in the first quarter. The reciprocal tariffs had a negative impact of approximately two percentage points on margins.

    Our non-GAAP operating expenses were $77.8 million in the second quarter of 2025, compared to $79.4 million in the first quarter. Our non-GAAP operating income was $98.6 million in the second quarter of 2025, compared to $94.6 million in the first quarter.

    We exited the second quarter of 2025 with $1.53 billion in cash, cash equivalents and marketable securities and generated $26.6 million in cash flow from operations in the second quarter. Our capital expenditures were $8.2 million in the second quarter of 2025, compared to $14.6 million in the first quarter of 2025.

    In the second quarter of 2025, we repurchased 702,948 shares of our common stock at an average price of $42.67 per share for a total of approximately $30.0 million. We also spent approximately $3.0 million by withholding shares to cover taxes for employee stock vesting that reduced the diluted shares by 58,332 shares.

    During the second quarter of 2025, we shipped approximately 1.41 million microinverters from manufacturing facilities in the United States that we booked for 45X production tax credits. We continued to ship our IQ8HC™ Microinverters, IQ8P-3P™ Commercial Microinverters, and IQ® Battery 5Ps from these facilities, meeting domestic content requirements.

    We shipped a record 190.9 MWh of IQ Batteries in the second quarter of 2025, compared to 170.1 MWh in the first quarter. More than 11,700 installers worldwide are certified to install our IQ Batteries, compared to more than 10,900 installers worldwide in the first quarter of 2025. In addition, we have 210 MWh of batteries in our fleet currently enrolled in virtual power plant (VPP) programs globally.

    During the second quarter of 2025, we began shipping our fourth-generation Enphase Energy System, which includes the IQ® Battery 10C, IQ® Meter Collar, and IQ® Combiner 6C, to customers in the United States. The IQ Battery 10C is designed to be 30% more energy-dense, occupy 62% less wall space, and lower the cost of install compared to previous models. Together, these components simplify the entire backup installation process, enhance reliability, and provide greater value to homeowners. The IQ Meter Collar has now been approved by 29 U.S. utilities.

    We also ramped shipments of our IQ Battery with FlexPhase into more countries in Europe. This AC-coupled battery system supports both single-phase and three-phase homes, providing full backup capability and superior flexibility to meet diverse home energy needs.

    The IQ® EV Charger 2, our most advanced residential charger to date, is now shipping to 18 countries across Europe, Australia, and New Zealand. This smart charger is designed to work seamlessly with Enphase solar and battery systems or as a powerful standalone solution. We also started shipping our IQ® Balcony Solar Kit, a simple and efficient solution for harnessing solar energy from panels installed on apartment balconies, in Belgium and Germany during the second quarter of 2025.

    We continue to strengthen our digital platform and improve the customer experience. We are investing in several new enhancements for Solargraf, our all-in-one installer platform, including expanded third-party ownership (TPO) partner integrations, a custom tariff builder, enhanced dealership management features, and a simplified, AI-driven design experience – all aimed at making Solargraf even more powerful and intuitive.

    BUSINESS HIGHLIGHTS

    On July 17, 2025, Enphase Energy announced initial shipments of the IQ Battery 5P supplied from manufacturing facilities in the United States with higher domestic content than previous models.

    On July 10 and July 2, 2025, Enphase Energy announced that production shipments of its IQ EV Charger 2 have expanded Europe to now include Greece, Romania, Ireland, Poland, Australia, and New Zealand.

    On June 16, 2025, Enphase Energy announced the launch of the IQ Battery 5P with FlexPhase, for customers in more European countries, including Spain, Portugal, France, Sweden, Denmark, Belgium, and the Netherlands.

    On June 4, 2025, Enphase Energy announced that IQ8P-3P Commercial Microinverters made with domestic content were selected for significant commercial projects on a Florida school, an affordable housing complex in Rhode Island, and a community center in California.

    On May 19, 2025, Enphase Energy introduced IQ® Energy Management that integrates with Enphase solar and battery systems to enable smart management of variable electricity rates and select third-party electric vehicle (EV) chargers, heat pumps, and resistive electric water heaters in France.

    On May 12 and May 7, 2025, Enphase Energy announced the launch of the IQ Balcony Solar System in Belgium and Germany that empowers apartment dwellers and homeowners with limited roof space to generate their own clean energy from balconies, patios, and small outdoor areas.

    On May 8, 2025, Enphase Energy announced the availability of new software that allows homeowners with existing legacy IQ7™ Microinverter-based systems to seamlessly expand their solar capacity using IQ8™ Microinverters.

    On April 28, 2025, Enphase Energy announced production shipments of IQ8 Microinverters in Japan through a distribution agreement with ITOCHU Corporation, one of the largest trading companies in the country.

    THIRD QUARTER 2025 FINANCIAL OUTLOOK

    For the third quarter of 2025, Enphase Energy estimates both GAAP and non-GAAP financial results as follows:

    • Revenue to be within a range of $330.0 million to $370.0 million, which includes shipments of 190 to 210 MWh of IQ Batteries.
    • GAAP gross margin to be within a range of 41.0% to 44.0% with net IRA benefit, including approximately three to five percentage points of new tariff impact.
    • Non-GAAP gross margin to be within a range of 43.0% to 46.0% with net IRA benefit and 33.0% to 36.0% excluding net IRA benefit, including approximately three to five percentage points of new tariff impact. Non-GAAP gross margin excludes stock-based compensation expense and acquisition related amortization.
    • Net IRA benefit to be within a range of $34.0 million to $38.0 million based on estimated shipments of 1,200,000 units of U.S. manufactured microinverters.
    • GAAP operating expenses to be within a range of $130.0 million to $134.0 million.
    • Non-GAAP operating expenses to be within a range of $78.0 million to $82.0 million, excluding $52.0 million estimated for stock-based compensation expense, acquisition related amortization, restructuring and asset impairment charges.

    For 2025, Enphase expects a GAAP tax rate of 19-21% and a non-GAAP tax rate of 15-17%, including IRA benefits.

    Follow Enphase Online

    Use of non-GAAP Financial Measures

    Enphase Energy has presented certain non-GAAP financial measures in this press release. Generally, a non-GAAP financial measure is a numerical measure of a company’s performance, financial position, or cash flows that either exclude or include amounts that are not normally excluded or included in the most directly comparable measure calculated and presented in accordance with generally accepted accounting principles in the United States (GAAP). Reconciliation of each non-GAAP financial measure to the most directly comparable GAAP financial measure can be found in the accompanying tables to this press release. Non-GAAP financial measures presented by Enphase Energy include non-GAAP gross profit, gross margin, operating expenses, income from operations, net income, net income per share (basic and diluted), net IRA benefit, and free cash flow.

    These non-GAAP financial measures do not reflect a comprehensive system of accounting, differ from GAAP measures with the same captions and may differ from non-GAAP financial measures with the same or similar captions that are used by other companies. In addition, these non-GAAP measures have limitations in that they do not reflect all of the amounts associated with Enphase Energy’s results of operations as determined in accordance with GAAP. As such, these non-GAAP measures should be considered as a supplement to, and not as a substitute for, or superior to, financial measures calculated in accordance with GAAP. Enphase Energy uses these non-GAAP financial measures to analyze its operating performance and future prospects, develop internal budgets and financial goals, and to facilitate period-to-period comparisons. Enphase Energy believes that these non-GAAP financial measures reflect an additional way of viewing aspects of its operations that, when viewed with its GAAP results, provide a more complete understanding of factors and trends affecting its business.

    As presented in the “Reconciliation of Non-GAAP Financial Measures” tables below, each of the non-GAAP financial measures excludes one or more of the following items for purposes of calculating non-GAAP financial measures to facilitate an evaluation of Enphase Energy’s current operating performance and a comparison to its past operating performance:

    Stock-based compensation expense. Enphase Energy excludes stock-based compensation expense from its non-GAAP measures primarily because they are non-cash in nature. Moreover, the impact of this expense is significantly affected by Enphase Energy’s stock price at the time of an award over which management has limited to no control.

    Acquisition related amortization. This item represents amortization of acquired intangible assets, which is a non-cash expense. Acquisition related amortization of acquired intangible assets are not reflective of Enphase Energy’s ongoing financial performance.

    Restructuring and asset impairment charges. Enphase Energy excludes restructuring and asset impairment charges due to the nature of the expenses being unusual and arising outside the ordinary course of continuing operations. These costs primarily consist of fees paid for cash-based severance costs, accelerated stock-based compensation expense and asset write-downs of property and equipment and acquired intangible assets, and other contract termination costs resulting from restructuring initiatives.

    Non-cash interest expense. This item consists primarily of amortization of debt issuance costs and accretion of debt discount because these expenses do not represent a cash outflow for Enphase Energy except in the period the financing was secured and such amortization expense is not reflective of Enphase Energy’s ongoing financial performance.

    Non-GAAP income tax adjustment. This item represents the amount adjusted to Enphase Energy’s GAAP tax provision or benefit to exclude the income tax effects of GAAP adjustments such as stock-based compensation, amortization of purchased intangibles, and other non-recurring items that are not reflective of Enphase Energy ongoing financial performance.

    Non-GAAP net income per share, diluted. Enphase Energy excludes the dilutive effect of in-the-money portion of convertible senior notes as they are covered by convertible note hedge transactions that reduce potential dilution to our common stock upon conversion of the Notes due 2025, Notes due 2026, and Notes due 2028, and includes the dilutive effect of employee’s stock-based awards and the dilutive effect of warrants. Enphase Energy believes these adjustments provide useful supplemental information to the ongoing financial performance.

    Net IRA benefit. This item represents the advanced manufacturing production tax credit (AMPTC) from the IRA for manufacturing microinverters in the United States, partially offset by the incremental manufacturing cost incurred in the United States relative to manufacturing in India. The AMPTC is accounted for by Enphase Energy as an income-based government grants that reduces cost of revenues in the condensed consolidated statements of operations.

    Free cash flow. This item represents net cash flows from operating activities less purchases of property and equipment.

    Conference Call Information

    Enphase Energy will host a conference call for analysts and investors to discuss its second quarter 2025 results and third quarter 2025 business outlook today at 4:30 p.m. Eastern Time (1:30 p.m. Pacific Time). The call is open to the public by dialing (833) 634-5018. A live webcast of the conference call will also be accessible from the “Investor Relations” section of Enphase Energy’s website at https://investor.enphase.com.

    Following the webcast, an archived version will be available on the website for approximately one year. In addition, an audio replay of the conference call will be available by calling (877) 344-7529; replay access code 6021998, beginning approximately one hour after the call.

    Forward-Looking Statements

    This press release contains forward-looking statements, including statements related to Enphase Energy’s expectations as to its third quarter of 2025 financial outlook, including revenue, shipments of IQ Batteries by MWh, gross margin with net IRA benefit and excluding net IRA benefit, estimated shipments of U.S. manufactured microinverters, operating expenses, and annualized effective tax rate with IRA benefit; its expectations regarding the expected net IRA benefit; future enhancements for Solargraf; and the capabilities, advantages, features, and performance of its technology and products. These forward-looking statements are based on Enphase Energy’s current expectations and inherently involve significant risks and uncertainties. Enphase Energy’s actual results and the timing of events could differ materially from those anticipated in such forward-looking statements as a result of certain risks and uncertainties including those risks described in more detail in its most recently filed Annual Report on Form 10-K, Quarterly Report on Form 10-Q, and other documents on file with the SEC from time to time and available on the SEC’s website at www.sec.gov. Enphase Energy undertakes no duty or obligation to update any forward-looking statements contained in this release as a result of new information, future events or changes in its expectations, except as required by law.

    A copy of this press release can be found on the investor relations page of Enphase Energy’s website at https://investor.enphase.com.

    About Enphase Energy, Inc.

    Enphase Energy, a global energy technology company based in Fremont, CA, is the world’s leading supplier of microinverter-based solar and battery systems that enable people to harness the sun to make, use, save, and sell their own power – and control it all with a smart mobile app. The company revolutionized the solar industry with its microinverter-based technology and builds all-in-one solar, battery, and software solutions. Enphase has shipped approximately 83.1 million microinverters, and more than 4.9 million Enphase-based systems have been deployed in over 160 countries. For more information, visit https://enphase.com/.

    © 2025 Enphase Energy, Inc. All rights reserved. Enphase Energy, Enphase, the “e” logo, IQ, IQ8, and certain other marks listed at https://enphase.com/trademark-usage-guidelines are trademarks or service marks of Enphase Energy, Inc. Other names are for informational purposes and may be trademarks of their respective owners.

    Contact:

    Zach Freedman
    Enphase Energy, Inc.
    Investor Relations
    ir@enphaseenergy.com

    ENPHASE ENERGY, INC.
    CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
    (In thousands, except per share data)
    (Unaudited)
      Three Months Ended Six Months Ended
      June 30,
    2025
      March 31,
    2025
      June 30,
    2024
      June 30,
    2025
      June 30,
    2024
    Net revenues $ 363,153     $ 356,084     $ 303,458     $ 719,237     $ 566,797  
    Cost of revenues   192,660       187,843       166,292       380,503       314,123  
    Gross profit   170,493       168,241       137,166       338,734       252,674  
    Operating expenses:                  
    Research and development   45,421       50,174       48,871       95,595       103,082  
    Sales and marketing   50,708       48,948       51,775       99,656       105,082  
    General and administrative   34,035       34,035       33,550       68,070       68,732  
    Restructuring and asset impairment charges   3,322       3,162       1,171       6,484       3,078  
    Total operating expenses   133,486       136,319       135,367       269,805       279,974  
    Income (loss) from operations   37,007       31,922       1,799       68,929       (27,300 )
    Other income, net                  
    Interest income   14,911       17,032       19,203       31,943       38,912  
    Interest expense   (815 )     (2,047 )     (2,220 )     (2,862 )     (4,416 )
    Other expense, net   (8,898 )     (14 )     (7,566 )     (8,912 )     (7,479 )
    Total other income, net   5,198       14,971       9,417       20,169       27,017  
    Income (loss) before income taxes   42,205       46,893       11,216       89,098       (283 )
    Income tax provision   (5,153 )     (17,163 )     (383 )     (22,316 )     (4,981 )
    Net income (loss) $ 37,052     $ 29,730     $ 10,833     $ 66,782     $ (5,264 )
    Net income (loss) per share:                  
    Basic $ 0.28     $ 0.23     $ 0.08     $ 0.51     $ (0.04 )
    Diluted $ 0.28     $ 0.22     $ 0.08     $ 0.50     $ (0.04 )
    Shares used in per share calculation:                  
    Basic   131,031       131,869       135,646       131,447       135,768  
    Diluted   135,219       136,208       136,123       135,719       135,768  
     
    ENPHASE ENERGY, INC.
    CONDENSED CONSOLIDATED BALANCE SHEETS
    (In thousands)
    (Unaudited)
      June 30,
    2025
      December 31,
    2024
    ASSETS      
    Current assets:      
    Cash and cash equivalents $ 370,536   $ 369,110
    Restricted cash       95,006
    Marketable securities   1,159,648     1,253,480
    Accounts receivable, net   223,218     223,749
    Inventory   173,016     165,004
    Prepaid expenses and other assets   362,523     220,735
    Total current assets   2,288,941     2,327,084
    Property and equipment, net   136,902     147,514
    Intangible assets, net   32,380     42,398
    Goodwill   214,890     211,571
    Other assets   193,426     205,542
    Deferred tax assets, net   312,250     315,567
    Total assets $ 3,178,789   $ 3,249,676
    LIABILITIES AND STOCKHOLDERS’ EQUITY      
    Current liabilities:      
    Accounts payable $ 162,697   $ 90,032
    Accrued liabilities   206,537     196,887
    Deferred revenues, current   129,040     237,225
    Warranty obligations, current   33,136     34,656
    Debt, current   631,179     101,291
    Total current liabilities   1,162,589     660,091
    Long-term liabilities:      
    Deferred revenues, non-current   331,531     341,982
    Warranty obligations, non-current   172,950     158,233
    Other liabilities   59,542     55,265
    Debt, non-current   571,540     1,201,089
    Total liabilities   2,298,152     2,416,660
    Total stockholders’ equity   880,637     833,016
    Total liabilities and stockholders’ equity $ 3,178,789   $ 3,249,676
     
    ENPHASE ENERGY, INC.
    CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
    (In thousands)
    (Unaudited)
      Three Months Ended   Six Months Ended
      June 30,
    2025
      March 31,
    2025
      June 30,
    2024
      June 30,
    2025
      June 30,
    2024

    Cash flows from operating activities:
                     
    Net income (loss) $ 37,052     $ 29,730     $ 10,833     $ 66,782     $ (5,264 )
    Adjustments to reconcile net income (loss) to net cash provided by operating activities:                  
    Depreciation and amortization   20,085       19,915       20,484       40,000       40,621  
    Net accretion of premium (discount) on marketable securities   (1,234 )     3,512       (1,030 )     2,278       1,795  
    Provision for doubtful accounts   130       62       1,897       192       1,767  
    Asset impairment   1,538       27       6,241       1,565       6,573  
    Non-cash interest expense   828       1,679       2,157       2,507       4,289  
    Change in fair value of debt securities   9,464       (323 )     1,931       9,141       989  
    Stock-based compensation   53,896       55,633       52,757       109,529       113,590  
    Deferred income taxes   403       8,560       (14,076 )     8,963       (22,368 )
    Changes in operating assets and liabilities:                  
    Accounts receivable   8,681       1,760       82,183       10,441       159,542  
    Inventory   (28,991 )     20,979       31,825       (8,012 )     37,527  
    Prepaid expenses and other assets   (64,261 )     (75,553 )     (42,810 )     (139,814 )     (53,707 )
    Accounts payable, accrued and other liabilities   37,212       54,232       (23,944 )     91,444       (90,228 )
    Warranty obligations   2,639       10,558       15       13,197       (11,908 )
    Deferred revenues   (50,813 )     (82,357 )     (1,401 )     (133,170 )     (6,955 )
      Net cash provided by operating activities   26,629       48,414       127,062       75,043       176,263  
    Cash flows from investing activities:                  
    Purchases of property and equipment   (8,259 )     (14,608 )     (9,636 )     (22,867 )     (17,007 )
    Investment in tax equity fund   (1,440 )     (6,904 )           (8,344 )      
    Purchases of marketable securities   (284,306 )     (200,826 )     (300,053 )     (485,132 )     (772,321 )
    Maturities and sale of marketable securities   242,820       335,398       282,063       578,218       779,436  
      Net cash provided by (used in) investing activities   (51,185 )     113,060       (27,626 )     61,875       (9,892 )
    Cash flows from financing activities:                  
    Settlement of Notes due 2025         (102,168 )           (102,168 )     (2 )
    Repurchase of common stock   (29,993 )     (99,964 )     (99,908 )     (129,957 )     (141,904 )
    Proceeds from issuance of common stock under employee equity plans   5,302       67       6,769       5,369       7,955  
    Payment of withholding taxes related to net share settlement of equity awards   (2,864 )     (12,110 )     (7,473 )     (14,974 )     (67,515 )
      Net cash used in financing activities   (27,555 )     (214,175 )     (100,612 )     (241,730 )     (201,466 )
      Effect of exchange rate changes on cash, cash equivalents and restricted cash   7,557       3,675       (374 )     11,232       (1,551 )
    Net decrease in cash, cash equivalents and restricted cash   (44,554 )     (49,026 )     (1,550 )     (93,580 )     (36,646 )
    Cash, cash equivalents and restricted cash — Beginning of period   415,090       464,116       253,652       464,116       288,748  
    Cash, cash equivalents and restricted cash — End of period $ 370,536     $ 415,090     $ 252,102     $ 370,536     $ 252,102  
     
    ENPHASE ENERGY, INC.
    RECONCILIATION OF NON-GAAP FINANCIAL MEASURES
    (In thousands, except per share data and percentages)
    (Unaudited)
      Three Months Ended   Six Months Ended
      June 30,
    2025
      March 31,
    2025
      June 30,
    2024
      June 30,
    2025
      June 30,
    2024
    Gross profit (GAAP) $ 170,493     $ 168,241     $ 137,166     $ 338,734     $ 252,674  
      Stock-based compensation   4,311       4,239       3,730       8,550       7,912  
      Acquisition related amortization   1,590       1,580       1,890       3,170       3,781  
    Gross profit (Non-GAAP) $ 176,394     $ 174,060     $ 142,786     $ 350,454     $ 264,367  
                         
    Gross margin (GAAP)   46.9 %     47.2 %     45.2 %     47.1 %     44.6 %
      Stock-based compensation   1.3       1.2       1.3       1.2       1.3  
      Acquisition related amortization   0.4       0.5       0.6       0.4       0.7  
    Gross margin (Non-GAAP)   48.6 %     48.9 %     47.1 %     48.7 %     46.6 %
                         
    Operating expenses (GAAP) $ 133,486     $ 136,319     $ 135,367     $ 269,805     $ 279,974  
      Stock-based compensation(1)   (49,506 )     (50,885 )     (49,027 )     (100,391 )     (105,678 )
      Acquisition related amortization   (2,877 )     (2,849 )     (3,463 )     (5,726 )     (6,925 )
      Restructuring and asset impairment charges(1)   (3,322 )     (3,162 )     (1,171 )     (6,484 )     (3,078 )
    Operating expenses (Non-GAAP) $ 77,781     $ 79,423     $ 81,706     $ 157,204     $ 164,293  
                         
    (1)Includes stock-based compensation as follows:                  
      Research and development $ 20,481     $ 21,647     $ 20,210     $ 42,128     $ 44,760  
      Sales and marketing   16,657       16,396       16,784       33,053       34,962  
      General and administrative   12,368       12,842       12,033       25,210       25,956  
      Restructuring and asset impairment charges   79       509             588        
      Total $ 49,585     $ 51,394     $ 49,027     $ 100,979     $ 105,678  
                         
    Income (loss) from operations (GAAP) $ 37,007     $ 31,922     $ 1,799     $ 68,929     $ (27,300 )
      Stock-based compensation   53,817       55,124       52,757       108,941       113,590  
      Acquisition related amortization   4,467       4,429       5,353       8,896       10,706  
      Restructuring and asset impairment charges   3,322       3,162       1,171       6,484       3,078  
    Income from operations (Non-GAAP) $ 98,613     $ 94,637     $ 61,080     $ 193,250     $ 100,074  
                         
    Net income (loss) (GAAP) $ 37,052     $ 29,730     $ 10,833     $ 66,782     $ (5,264 )
      Stock-based compensation   53,817       55,124       52,757       108,941       113,590  
      Acquisition related amortization   4,467       4,429       5,353       8,896       10,706  
      Restructuring and asset impairment charges   3,322       3,162       1,171       6,484       3,078  
      Non-cash interest expense   829       1,678       2,157       2,507       4,289  
      Non-GAAP income tax adjustment   (9,618 )     (4,880 )     (13,447 )     (14,498 )     (19,619 )
    Net income (Non-GAAP) $ 89,869     $ 89,243     $ 58,824     $ 179,112     $ 106,780  
                         
    Net income (loss) per share, basic (GAAP) $ 0.28     $ 0.23     $ 0.08     $ 0.51     $ (0.04 )
      Stock-based compensation   0.41       0.42       0.39       0.80       0.84  
      Acquisition related amortization   0.03       0.04       0.04       0.08       0.08  
      Restructuring and asset impairment charges   0.03       0.02       0.01       0.06       0.02  
      Non-cash interest expense   0.01       0.01       0.02       0.02       0.03  
      Non-GAAP income tax adjustment   (0.07 )     (0.04 )     (0.11 )     (0.11 )     (0.14 )
    Net income per share, basic (Non-GAAP) $ 0.69     $ 0.68     $ 0.43     $ 1.36     $ 0.79  
                         
      Shares used in basic per share calculation GAAP and Non-GAAP   131,031       131,869       135,646       131,447       135,768  
                         
    Net income (loss) per share, diluted (GAAP) $ 0.28     $ 0.22     $ 0.08     $ 0.50     $ (0.04 )
      Stock-based compensation   0.41       0.42       0.38       0.83       0.84  
      Acquisition related amortization   0.03       0.04       0.04       0.07       0.08  
      Restructuring and asset impairment charges   0.03       0.03       0.01       0.05       0.02  
      Non-cash interest expense   0.01       0.01       0.02       0.02       0.03  
      Non-GAAP income tax adjustment   (0.07 )     (0.04 )     (0.10 )     (0.11 )     (0.15 )
    Net income per share, diluted (Non-GAAP) $ 0.69     $ 0.68     $ 0.43     $ 1.36     $ 0.78  
                         
      Shares used in diluted per share calculation GAAP   135,219       136,208       136,123       135,719       135,768  
      Shares used in diluted per share calculation Non-GAAP   131,144       132,133       136,123       131,644       136,439  
                         
    Income-based government grants (GAAP) $ 61,040     $ 53,631     $ 24,329     $ 114,671     $ 42,946  
      Incremental cost for manufacturing in U.S.   (19,528 )     (15,773 )     (5,950 )     (35,301 )     (10,832 )
    Net IRA benefit (Non-GAAP) $ 41,512     $ 37,858     $ 18,379     $ 79,370     $ 32,114  
                         
    Net cash provided by operating activities (GAAP) $ 26,629     $ 48,414     $ 127,062     $ 75,043     $ 176,263  
      Purchases of property and equipment   (8,259 )     (14,608 )     (9,636 )     (22,867 )     (17,007 )
    Free cash flow (Non-GAAP) $ 18,370     $ 33,806     $ 117,426     $ 52,176     $ 159,256  
     

    This press release was published by a CLEAR® Verified individual.

    The MIL Network

  • MIL-OSI USA: Burlison Opens Subcommittee Hearing on Advancing Nuclear Energy

    Source: United States House of Representatives – Representative Eric Burlison (R-Missouri 7th District)

    WASHINGTON—Subcommittee on Economic Growth, Energy Policy, and Regulatory Affairs Chairman Eric Burlison (R-Mo.) delivered opening remarks at today’s hearing on “The New Atomic Age: Advancing America’s Energy Future.” In his opening statement, Subcommittee Chairman Burlison highlighted President Trump’s actions to boost American energy production and Congressional action to reinvigorate the nuclear industry. Subcommittee Chairman Burlison also noted the efficiency and cost of nuclear energy emphasized the importance discovering new pathways to solving domestic energy challenges.

    VIDEO: Opening Remarks

    Below are Subcommittee Chairman Burlison’s prepared remarks:

    A new age for nuclear power has started—led by President Trump’s four recent executive orders on nuclear energy and Congressional action to reinvigorate the nuclear industry. 

    President Trump’s orders call for permitting reform and the reduction of overburdensome regulations from the Nuclear Regulatory Commission, which has become a slow-moving, bureaucratic mess, constraining and delaying expansion of U.S. nuclear power deployment for decades.  

    Under President Trump’s orders, the NRC must rule on reactor license applications within 18 months—a dramatic shift from the ambiguous, open-ended timelines of the past. 

    President Trump’s orders also promote expanding domestic mining, enrichment of uranium and other reactor fuels, and nuclear-fuel recycling.  

    These ground-breaking actions will power United States energy independence and provide a secure and reliable U.S. electrical grid—something we must obtain as the AI revolution places surging demands on our. electrical capacity.  

    At the heart of nuclear power’s resurgence are two key innovations: small and micro modular reactors.  

    These new reactors promise the U.S. will have a strong answer to future energy demands.  

    They will be more capital-effective, more efficient, and more scalable for both on and off-grid sites here in the United States.  

    Moreover, they offer enhanced safety features, eliminate the risk of meltdowns, and can use recycled fuel from other reactors.  

    The Department of Energy predicts that 12 percent of electricity consumption in the United States in 2028 will come from data centers, which require constant and consistent electricity.  

    And the Energy Information Agency recently projected that U.S. power consumption will reach all-time highs this year and next, in part due to AI and data-center demand.

    Nuclear power is the answer to data centers’ growing appetite for stable energy.

    I recently toured two prototype micro modular reactors being developed here in the United States.  

    I can confidently say the technology is ready—what is holding nuclear back is the onerous and capital-intensive regulatory permitting burden placed on nuclear energy expansion. 

    Under the Trump Administration, the federal government is waking up to the roadblock that nuclear power has faced for decades.

    The federal government, not technology, has been in the way.  

    Congress should and will be watching for the fruits of the Administration’s actions, eager to cooperate in achieving lasting change.  

    Nuclear power in the age of SMRs and MMRs isn’t just safe—it’s essential.  

    It is our best shot at securing clean, reliable, American energy independence.

    MIL OSI USA News

  • MIL-OSI USA: Welch Grills HHS Nominee on Trump Admin’s Plans to Zero Out Funding for LIHEAP 

    US Senate News:

    Source: United States Senator Peter Welch (D-Vermont)

    President Trump’s Fiscal Year 2026 budget would end LIHEAP program, which provides heating assistance for more than 26,000 Vermonters 
    WASHINGTON, D.C. — U.S. Senator Peter Welch (D-Vt.), a member of the Senate Judiciary Committee, today grilled Dr. Alex Adams, President Trump’s pick to serve as Assistant Secretary for Family Support at the Department of Health and Human Services (HHS), about the Trump Administration’s plans to eliminate funding for the Low-Income Energy Assistance Program (LIHEAP). LIHEAP helps more than 26,000 Vermonters and 6.2 million Americans afford heat and air conditioning.   

    “LIHEAP is an incredibly important program—it’s getting zeroed out in the budget. I know that you played a major role in Idaho in administering the LIHEAP program there. It’s really, really important in Vermont in those cold winters,” said Senator Welch. “I’m asking you—as a person who did really good work for the people of Idaho, administering the LIHEAP program—what do you think about zeroing out that program?” 
    Dr. Adams: “Senator, I’ll reiterate what the Secretary said. If Congress funds it, we’ll get the money out the door.” 
    Senator Welch: “But the President is zeroing it out. And you’re not in Congress…you’re working for President Trump, right? So, my question goes back to, what’s your view about zeroing out the LIHEAP program?” 
    Dr. Adams: “So, as a former state budget director, I would say no budget decision is ever made in a vacuum. It has to look at the total picture, and because this is an Administration that’s committed to energy policies, more permits—” 
    Senator Welch: “So you won’t answer, basically.” 

    Watch Senator Welch’s full remarks below: 

    Read a key excerpt from Senator Welch’s exchange with Alex Adams, President Trump’s nominee to serve as Assistant Secretary for Family Support at HHS:  

    Senator Welch: “The whole point of LIHEAP is it’s people who don’t have the resources to participate in the market. They have no control over a) the weather and b) the price of home heating fuel, right?” 
    Dr. Adams: “Senator, I think in states like mine we have policies that prohibit shutting off of utilities for certain critical months. I think you’re going to have to take into account the nuances and all the other factors in the market.”  
    Senator Welch: “I’ll just say candidly: I really admire the work you did in Idaho on the LIHEAP program, among other things, and I’m really disappointed in your—from my perspective—lack of candor about what your view is about zeroing out a program that you worked really hard on.” 

    In May, the Vermont Congressional Delegation pushed back against the Trump Administration’s plans to eliminate the LIHEAP and terminate employees at HHS who distribute the funding. The Delegation previously called on Secretary of HHS Robert F. Kennedy, Jr. to immediately reinstate the staff of the Division of Energy Assistance at HHS and disburse funding to states for LIHEAP. They have yet to receive a reply. 
    Learn more about Senator Welch’s work by visiting his website or by following him on social media. 

    MIL OSI USA News

  • MIL-OSI USA: Governor Stein Announces 515 New Jobs in Western NC as Manufacturer Selects Graham County

    Source: US State of North Carolina

    Headline: Governor Stein Announces 515 New Jobs in Western NC as Manufacturer Selects Graham County

    Governor Stein Announces 515 New Jobs in Western NC as Manufacturer Selects Graham County
    lsaito

    Raleigh, NC

    Governor Josh Stein announced today that Eco King Solutions, LLC, a new subsidiary of a major manufacturer, plans to create 515 jobs in Graham County. The company will invest $80.5 million in Robbinsville to establish its first North American production facility to produce disposable, biodegradable paper tableware.

    “North Carolina offers global companies a perfect location for expansion into North America,” said Governor Josh Stein. “We welcome Eco King to western North Carolina, where it will find a welcoming business climate, education and workforce programs tailored to its needs, and the full range of competitive advantages that make North Carolina the top state to do business in the country.”

    Eco King Solutions is the wholly owned U.S. subsidiary of Chinese manufacturer Zhejiang Kingsun Eco-pack Co., Ltd, which was founded in 2008 and operates three high-capacity factories in China employing approximately 1,200 people. The company specializes in the production of disposable dishware such as bowls, plates, clamshell containers, and trays used in supermarkets and a wide variety of other food service industries. The company serves a growing customer base in North America, and the project represents a strategic expansion to better serve this market. Establishing the facility in Robbinsville will allow the company to localize production, improve supply chain efficiency, and reduce international shipping costs and production lead times. 

    “We have been impressed by how welcoming Robbinsville, Graham County and North Carolina have been to our company and this important project,” said Ping Zhang, Chairman of Eco King Solutions. “We worked very hard to find the right location for our business to thrive. We know we found it right here due to the excellent workforce, quality of life and friendly business climate. We are excited to be a part of the community, and we are excited for our company to prosper here.”

    “This investment is a success story for manufacturing in western North Carolina, where folks work hard to make great products,” said Commerce Secretary Lee Lilley. “Whether it’s CNBC naming us the top state for business or investments from CEOs around the world, North Carolina continues to be a global destination for great job creation.”

    Although wages will vary depending on the position, the average salary for the new jobs will be $46,707, in line with the average wage in Graham County of $46,628. The new jobs will generate an annual payroll impact in the community of more than $14 million.

    The company’s project in North Carolina will be facilitated, in part, by a Job Development Investment Grant (JDIG) approved by the state’s Economic Investment Committee earlier today. Over the course of the 12-year term of this grant, the project is estimated to grow the state’s economy by more than $743.4 million. Using a formula that takes into account the new tax revenues generated by 300 of the new jobs and the capital investment, the JDIG agreement authorizes the potential reimbursement to the company of up to $2,894,000, spread over 12 years. State payments occur only following performance verification by the departments of Commerce and Revenue that the company has met its incremental job creation and investment targets.

    The project’s projected return on investment of public dollars is 106 percent, meaning for every dollar of potential cost, the state receives $2.06 in state revenue. JDIG projects result in positive net tax revenue to the state treasury, even after taking into consideration the grant’s reimbursement payments to a given company. 

    “A major economic development win like today’s announcement provides proof that Robbinsville and Graham County are great places to do business,” said Senator Kevin Corbin. “We’re proud that Eco King chose us for their first North American factory, and we will do everything we can to help them be successful in western North Carolina.

    “I am very excited for Robbinsville,” said Representative Karl E. Gillespie. “The company will be establishing its first manufacturing facility in North America in Graham County. It’s another strong example of why North Carolina was recently named the #1 State in the nation to do business. This project is expected to bring new jobs, boost our local economy, and improve the quality of life in our community. Thank you to our local, regional, and state economic development leaders for helping make this project a reality.”

    Partnering with the North Carolina Department of Commerce and the Economic Development Partnership of North Carolina on this project were the North Carolina General Assembly, the North Carolina Community College System, the Commerce Department’s Divisions of Workforce Solutions and Rural Economic Development, Duke Energy, the Town of Robbinsville, Graham County, the Southwestern Commission, and the Mountain West Partnership. 

    Jul 22, 2025

    MIL OSI USA News

  • MIL-OSI USA: Chairman Aguilar: Republicans spent the last six months putting more money in billionaires’ pockets and cutting health care

    Source: US House of Representatives – Democratic Caucus

    The following text contains opinion that is not, or not necessarily, that of MIL-OSI – July 22, 2025

    WASHINGTON, D.C. — Today, House Democratic Caucus Chair Pete Aguilar, Vice Chair Ted Lieu and DCCC Chair Suzan DelBene held a press conference on Trump and Republicans’ One Big Ugly Law raising health care costs while sinking Republican chances of holding on to the House. 

    CHAIRMAN AGUILAR: Good morning. Grateful to be joined today by DCCC Chair, Suzan DelBene and the Vice Chair, Ted Lieu. At the DCCC today, we had a productive Caucus meeting across the street. Donald Trump promised to lower costs on day one. We’re six months into this Trump Administration, and prices are rising because of reckless tariffs, inflation is still too high and now health care costs are going to skyrocket. For the 24 million Americans who rely on the Affordable Care Act, health insurance will go up by as much as 75 percent. And these price hikes don’t even include the tax credits that Republicans are going to let expire, so even more Americans are going to see higher costs and could lose their health care coverage. Democrats have been warning about the dangers of the Republican cuts to Medicaid leading to higher prices for everyone. The American people were told that Donald Trump and Republicans were going to turn the economy around and prioritize families. But that couldn’t be further from the truth: they’ve spent the last six months putting more money in billionaires’ pockets and cutting health care. But they did make private jets tax deductible, so there’s that. They’re even shielding Jeffrey Epstein and his associates—including the President of the United States—from accountability, despite promising for years to release the files that implicate those involved. At a time when family budgets are stretched thin, Republicans are only prioritizing the needs of billionaires. It’s not just bad policy that will make the economy worse, it’s a slap in the face to working people who voted to bring down costs. Now, I’ll introduce Vice Chair Ted Lieu.

    VICE CHAIR LIEU: Thank you, Chairman Aguilar. This morning, I went on this interesting website called HouseRepublicanPriceHike.com. And if you go on that website, you can see the increases in grocery prices starting from the beginning of this year. Beef prices, for example, are at an all-time high. Donald Trump promised that he was going to lower inflation on day one. He lied. Inflation has continuously increased. The most recent report has inflation increasing above expectations to 2.7 percent. Core CPI increased even more to 2.9 percent. And what are Congressional Republicans doing? Nothing. In fact, it’s even worse than that. They are actually ending this week early because they’re afraid to cast votes on the Jeffrey Epstein issue.

    The Rules Committee is not meeting because they’re afraid to cast votes to release the Epstein files. So you’ve got this Epstein issue affecting Congressional operations and making sure that the Congressional Republicans don’t work on trying to lower costs. So this is an epic cover-up, right? This is a cover-up of epic proportions, where you’ve got the majority party literally having us leave Congress early, and not having the Rules Committee meet, because they don’t want to deal with releasing the Epstein files. We should release the Epstein files. It is what Donald Trump campaigned on. It’s what Attorney General Pam Bondi talked about this February when she said that Epstein’s client list was, ‘sitting on my desk right now.’ Why don’t we have that client list? And these are the questions the American people keep asking, and the story is not going to go away. Because at its core, this is an issue about underage women who were sexually abused and assaulted. Attorney General Pam Bondi should not be protecting Jeffrey Epstein’s legacy, nor his clients, nor should Congressional Republicans be doing the same. With that, it is my honor to introduce our amazing field general for the DCCC, Congresswoman Suzan DelBene. She’s done a fantastic job, and she’s going to discuss what we talked about this morning. 

    DCCC CHAIR DELBENE: Thanks Vice Chair Lieu and Chairman Aguilar. Good morning, everyone. This morning, in Caucus, we presented how we’re holding House Republicans accountable for their disastrous agenda and our path to retake the majority. We hear over and over and over again from people back home that the top issue for them is affordability and lowering costs—lowering costs for everyday goods. By all accounts, Republicans have failed miserably in the time that they’ve had the trifecta. Prices are still rising, whether it’s housing, health insurance premiums or everyday things like food and groceries. Republicans broke their promise to lower costs. Their Big Ugly Law is just another broken promise. It rips coverage away from millions of people and will raise health care bills for everyone, regardless of what kind of insurance that they have, and it takes food off the table from hungry families and children. It guts funding for rural hospitals and increases ER wait times. Energy bills will go up for families across the country. Republicans did all of this to pay for tax breaks for the wealthiest few. Their agenda is cruel, it’s extreme and an absolute disaster, and the American people agree. 

    In poll after poll, we see that the Republicans’ bill is massively unpopular. The more people learn about it, the more they oppose it. The one lie Republicans keep telling themselves is that voters won’t punish them in the midterms because the American people won’t feel the pain of the cuts until after the election. Aside from the fact that this is exactly the kind of insincere political gamesmanship the public hates, it’s also not true. In a matter of months, millions of people will see their health insurance costs go up by an average of 75 percent—rural hospitals are already announcing they’ll close down and cut services. So no matter how many legislative games that Republicans try to play, there’s no hiding from the facts—the Big Ugly Law will have devastating consequences that will absolutely be felt by working families. 

    Republicans are poised to lose the majority next year, and they know it. You can tell by the way they’re behaving. They avoid in-person town halls because they’re afraid to face the public when they have to talk about their Big Ugly Bill. House Republicans are headed for the exits. We already have three vulnerable Republicans decide to retire or not run for re-election because they know they’re not going to take the majority. And we know there are more with one foot out the door, who may soon announce that they won’t seek re-election. So in these last six months, Republicans have broken promise after promise, feeding into a larger narrative that reminds everyone that they don’t work for the American people—they work for the elite, the powerful and the billionaires. It’s a theme we hear on the ground day after day, and if House Republicans would take the time to listen to their constituents back home, instead of only working and waiting for Donald Trump to tell them what to do, they would know. But instead, they blindly follow his orders that are hurting our economy and hitting the American families in their pocketbooks, and that’s why they’ll lose the majority.

    House Democrats will hold every single vulnerable Republican accountable for their betrayal against their communities when they supported the Big Ugly Bill. We have the better message, we have stronger candidates and public sentiment is on our side. And next year, we’ll have the gavels. Thank you and I’ll turn it back to the Chairman.

    Video of the full press conference and Q&A can be viewed here.


    ###

    MIL OSI USA News

  • MIL-OSI USA: NASA Tests New Heat Source Fuel for Deep Space Exploration

    Source: NASA

    To explore the unknown in deep space, millions of miles away from Earth, it’s crucial for spacecraft to have ample power. NASA’s radioisotope power systems (RPS) are a viable option for these missions and have been used for over 60 years, including for the agency’s Voyager spacecraft and Perseverance Mars rover. These nuclear batteries provide long-term electrical power for spacecraft and science instruments using heat produced by the natural radioactive decay of radioisotopes. Now, NASA is testing a new type of RPS heat source fuel that could become an additional option for future long-duration journeys to extreme environments.
    Historically, the radioisotope plutonium-238 (plutonium oxide) has been NASA’s RPS heat source fuel of choice, but americium-241 has been a source of interest for the past two decades in Europe. In January, the Thermal Energy Conversion Branch at NASA’s Glenn Research Center in Cleveland and the University of Leicester, based in the United Kingdom, partnered through an agreement to put this new option to the test.
    One method to generate electricity from radioisotope heat sources is the free-piston Stirling convertor. This is a heat engine that converts thermal energy into electrical energy. However, instead of a crankshaft to extract power, pistons float freely within the engine. It could operate for decades continuously without wear, as it does not have piston rings or rotating bearings that will eventually wear out. Thus, a Stirling convertor could generate more energy, allowing more time for exploration in deep space. Researchers from the University of Leicester — who have been leaders in the development of americium RPS and heater units for more than 15 years — and NASA worked to test the capabilities of a Stirling generator testbed powered by two electrically heated americium-241 heat source simulators.
    “The concept started as just a design, and we took it all the way to the prototype level: something close to a flight version of the generator,” said Salvatore Oriti, mechanical engineer at Glenn. “The more impressive part is how quickly and inexpensively we got it done, only made possible by a great synergy between the NASA and University of Leicester teams. We were on the same wavelength and shared the same mindset.”

    The university provided the heat source simulators and generator housing. The heat source simulator is the exact size and shape of their real americium-241 heat source, but it uses embedded electric heaters to create an equivalent amount of heat to simulate the decay of americium fuel and therefore drive generator operation. The Stirling Research Lab at Glenn provided the test station, Stirling convertor hardware, and support equipment.
    “A particular highlight of this (testbed) design is that it is capable of withstanding a failed Stirling convertor without a loss of electrical power,” said Hannah Sargeant, research fellow at the University of Leicester. “This feature was demonstrated successfully in the test campaign and highlights the robustness and reliability of an Americium-Radioisotope Stirling Generator for potential future spaceflight missions, including long-duration missions that could operate for many decades.”
    The test proved the viability of an americium-fueled Stirling RPS, and performance and efficiency targets were successfully met. As for what’s next, the Glenn team is pursuing the next version of the testbed that will be lower mass, higher fidelity, and undergo further environmental testing.
    “I was very pleased with how smoothly everything went,” Oriti said of the test results. “Usually in my experience, you don’t accomplish everything you set out to, but we did that and more. We plan to continue that level of success in the future.”
    For more information on NASA’s RPS programs, visit:https://science.nasa.gov/rps

    MIL OSI USA News

  • MIL-OSI USA: NASA Tests New Heat Source Fuel for Deep Space Exploration

    Source: NASA

    To explore the unknown in deep space, millions of miles away from Earth, it’s crucial for spacecraft to have ample power. NASA’s radioisotope power systems (RPS) are a viable option for these missions and have been used for over 60 years, including for the agency’s Voyager spacecraft and Perseverance Mars rover. These nuclear batteries provide long-term electrical power for spacecraft and science instruments using heat produced by the natural radioactive decay of radioisotopes. Now, NASA is testing a new type of RPS heat source fuel that could become an additional option for future long-duration journeys to extreme environments.
    Historically, the radioisotope plutonium-238 (plutonium oxide) has been NASA’s RPS heat source fuel of choice, but americium-241 has been a source of interest for the past two decades in Europe. In January, the Thermal Energy Conversion Branch at NASA’s Glenn Research Center in Cleveland and the University of Leicester, based in the United Kingdom, partnered through an agreement to put this new option to the test.
    One method to generate electricity from radioisotope heat sources is the free-piston Stirling convertor. This is a heat engine that converts thermal energy into electrical energy. However, instead of a crankshaft to extract power, pistons float freely within the engine. It could operate for decades continuously without wear, as it does not have piston rings or rotating bearings that will eventually wear out. Thus, a Stirling convertor could generate more energy, allowing more time for exploration in deep space. Researchers from the University of Leicester — who have been leaders in the development of americium RPS and heater units for more than 15 years — and NASA worked to test the capabilities of a Stirling generator testbed powered by two electrically heated americium-241 heat source simulators.
    “The concept started as just a design, and we took it all the way to the prototype level: something close to a flight version of the generator,” said Salvatore Oriti, mechanical engineer at Glenn. “The more impressive part is how quickly and inexpensively we got it done, only made possible by a great synergy between the NASA and University of Leicester teams. We were on the same wavelength and shared the same mindset.”

    The university provided the heat source simulators and generator housing. The heat source simulator is the exact size and shape of their real americium-241 heat source, but it uses embedded electric heaters to create an equivalent amount of heat to simulate the decay of americium fuel and therefore drive generator operation. The Stirling Research Lab at Glenn provided the test station, Stirling convertor hardware, and support equipment.
    “A particular highlight of this (testbed) design is that it is capable of withstanding a failed Stirling convertor without a loss of electrical power,” said Hannah Sargeant, research fellow at the University of Leicester. “This feature was demonstrated successfully in the test campaign and highlights the robustness and reliability of an Americium-Radioisotope Stirling Generator for potential future spaceflight missions, including long-duration missions that could operate for many decades.”
    The test proved the viability of an americium-fueled Stirling RPS, and performance and efficiency targets were successfully met. As for what’s next, the Glenn team is pursuing the next version of the testbed that will be lower mass, higher fidelity, and undergo further environmental testing.
    “I was very pleased with how smoothly everything went,” Oriti said of the test results. “Usually in my experience, you don’t accomplish everything you set out to, but we did that and more. We plan to continue that level of success in the future.”
    For more information on NASA’s RPS programs, visit:https://science.nasa.gov/rps

    MIL OSI USA News