MIL-OSI: National Fuel Reports Third Quarter Fiscal 2025 Earnings and Announces Preliminary Guidance for Fiscal 2026

Source: GlobeNewswire (MIL-OSI)

WILLIAMSVILLE, N.Y., July 30, 2025 (GLOBE NEWSWIRE) — National Fuel Gas Company (“National Fuel” or the “Company”) (NYSE:NFG) today announced consolidated results for the third quarter of its 2025 fiscal year.

FISCAL 2025 THIRD QUARTER SUMMARY

GAAP earnings per share of $1.64 compared to a net loss $0.59 per share in the prior year.
Adjusted earnings per share of $1.64 increased 66% compared to $0.99 per share in the prior year. See non-GAAP reconciliation on page 2.
Exploration and Production adjusted operating results of $0.95 per share increased 157% versus the prior year, driven by lower per unit operating costs, higher realized natural gas prices, and strong well performance in the Eastern Development Area (“EDA”), which contributed to 112 Bcf of natural gas production, up 16% versus the prior year’s third quarter.
The Pipeline and Storage segment achieved several development milestones for expansion projects during the quarter with the announcement of the Shippingport Lateral Project and the receipt of FERC approval for the Tioga Pathway Project, which remains on track for a late calendar 2026 in-service date.
The Company generated $196 million in net cash provided by operating activities less net cash used in investing activities during the third quarter.
The Company is revising the midpoint of its fiscal 2025 adjusted earnings per share guidance to a range of $6.80 to $6.95 per share and is initiating its fiscal 2026 preliminary earnings guidance which, based upon a NYMEX price of $4.00, is expected to increase 20% from fiscal 2025 (see Guidance Summary on page 7).

MANAGEMENT COMMENTARY

David P. Bauer, President and Chief Executive Officer of National Fuel Gas Company, stated: “National Fuel’s excellent third quarter reflects ongoing success across the Company. Our integrated upstream and gathering operations saw record production and throughput during the quarter and a continued improvement in capital efficiency, while our regulated Utility and Pipeline & Storage segments continue to see an uplift in earnings from recent ratemaking activities and organic investment opportunities.

“As we look forward to fiscal 2026, we expect to see significant earnings growth versus the prior year. This highlights the momentum in each of our businesses and the overall positive long-term outlook for natural gas. Strong well results in the EDA continue to confirm the depth of our best-in-class inventory and operational excellence in Northeast Pennsylvania, and underpin our mid-single-digit production growth expectations in the coming years. In addition, we have line of sight to further growth in our regulated businesses, supporting our 5% to 7% average annual rate base growth projections. Taken together, along with the broader tailwinds from growing demand for natural gas, National Fuel is well positioned to create meaningful value for shareholders in the years to come.”

RETURN OF CAPITAL UPDATE

During the quarter, National Fuel announced that its Board of Directors approved a 4% increase in the Company’s dividend for an annual rate of $2.14 per share. This is our 55^th consecutive year of dividend increases and the 123^rd year of consecutive dividend payments, demonstrating the Company’s commitment to returning cash to shareholders.

With respect to the Company’s share repurchase program, since March 2024, the Company repurchased approximately 2 million shares at an average weighted price of $59.70 per share. Consistent with our disciplined approach to capital allocation, which balances growth with return of capital to shareholders, during the quarter the Company paused repurchases as it evaluated various growth opportunities, preserving balance sheet flexibility.

RECONCILIATION OF GAAP EARNINGS TO ADJUSTED OPERATING RESULTS

	Three Months Ended June 30,
	(Thousands)						(Per Share)
		2025			2024			2025		2024
Reported GAAP Earnings	$	149,818		$	(54,158	)	$	1.64	$	(0.59	)
Items impacting comparability:
Impairment of assets (E&P)		—			200,696			0.00		2.18
Tax impact of impairment of assets		—			(55,686	)		0.00		(0.60	)
Other (refer to Segment results for details)		(615	)		873			—		—
Adjusted Operating Results	$	149,203		$	91,725		$	1.64	$	0.99

FISCAL 2025 GUIDANCE UPDATE

National Fuel is revising its adjusted earnings per share guidance for fiscal 2025 to a range of $6.80 to $6.95. This updated range incorporates our third quarter results as well as lower expected realized natural gas prices for the remaining three months, which is largely offset by expected higher production and lower unit costs in the Exploration and Production segment. The Company is assuming an average NYMEX natural gas price of $3.25 per MMBtu for the remaining three months of fiscal 2025, which approximates the current NYMEX forward curve at this time.

The Company’s other fiscal 2025 guidance assumptions are detailed in the table on page 7.

INITIATION OF FISCAL 2026 PRELIMINARY GUIDANCE

The Company is initiating preliminary earnings guidance for fiscal 2026 which it is providing at various NYMEX prices:

NYMEX Assumption ($/MMBtu)	Fiscal 2026 Adjusted Earnings Per Share Sensitivities
$3.00	$6.35 – $6.85
$4.00	$8.00 – $8.50
$5.00	$9.75 – $10.25

2026 OUTLOOK

Seneca’s ongoing trend of improving capital efficiency is projected to continue in fiscal 2026 with capital expenditures expected to decrease by $20 million, or 4% at the midpoint, while production is expected to increase to a range of 440 to 455 Bcf, an increase of 6% at the midpoint.
Regulated segment earnings are expected to increase as a result of ongoing modernization investments which are supported by recent ratemaking efforts, driven by Distribution’s three-year New York rate settlement that continues through fiscal 2027 and additional margin related to the Pennsylvania modernization tracker, or DSIC (Distribution System Improvement Charge).
Combined Utility and Pipeline & Storage segment capital expenditures are expected to range between $395 and $455 million, an increase of $110 million from fiscal 2025 at midpoint of guidance, with continued investment in our longstanding modernization programs, as well as significant expansion-related spending on the Tioga Pathway and Shippingport Lateral projects driving meaningful rate base growth.

Additional details on the Company’s updated forecast assumptions and business segment guidance for fiscal 2026 are outlined in the table on page 7.

DISCUSSION OF THIRD QUARTER RESULTS BY SEGMENT

The following earnings discussion of each operating segment for the quarter ended June 30, 2025 is summarized in a tabular form on pages 8 and 9 of this report (earnings drivers for the nine months ended June 30, 2025 are summarized on pages 10 and 11). It may be helpful to refer to those tables while reviewing this discussion.

Note that management defines adjusted operating results as reported GAAP earnings adjusted for items impacting comparability, and adjusted EBITDA as reported GAAP earnings before the following items: interest expense, income taxes, depreciation, depletion and amortization, other income and deductions, impairments, and other items reflected in operating income that impact comparability.

Upstream Business

Exploration and Production Segment

The Exploration and Production segment operations are carried out by Seneca Resources Company, LLC (“Seneca”). Seneca explores for, develops and produces primarily natural gas reserves in Pennsylvania.

	Three Months Ended
	June 30,
(in thousands)		2025			2024		Variance
GAAP Earnings	$	86,671		$	(112,028	)	$	198,699
Impairment of assets		—			200,696			(200,696	)
Tax impact of impairment of assets		—			(55,686	)		55,686
Unrealized (gain) loss on derivative asset (2022 CA asset sale)		45			1,186			(1,141	)
Tax impact of unrealized (gain) loss on derivative asset		(12	)		(325	)		313
Adjusted Operating Results	$	86,704		$	33,843		$	52,861

Adjusted EBITDA	$	202,488		$	128,535		$	73,953

Seneca’s third quarter GAAP earnings increased $198.7 million versus the prior year. GAAP earnings in the prior year included a non-cash, pre-tax ceiling test impairment of $200.7 million ($145.0 million after-tax) to write-down the carrying value of Seneca’s reserves under the full cost method of accounting. GAAP earnings also included the impact of unrealized losses related to reductions in the fair value of contingent consideration received in connection with the June 2022 divestiture of Seneca’s California assets.

Excluding items impacting comparability, Seneca’s adjusted operating results in the third quarter increased $52.9 million primarily due to higher realized natural gas prices and production, as well as lower per unit operating expenses.

During the third quarter, Seneca produced a Company record 112 Bcf of natural gas, an increase of 15 Bcf, or 16%, from the prior year. Two highly prolific Utica pads turned in line this year in the EDA’s Tioga County were the main drivers behind this increase in production.

Seneca’s weighted average realized natural gas price, after the impact of hedging and transportation costs, was $2.71 per Mcf, an increase of $0.43 per Mcf from the prior year. This increase was primarily due to higher NYMEX prices and higher spot prices at local sales points in Pennsylvania.

	Three Months Ended
	June 30,
(Cost per Mcf)		2025		2024	Variance
Lease Operating and Transportation Expense (“LOE”)	$	0.66	$	0.69	$	(0.03	)
General and Administrative Expense (“G&A”)	$	0.17	$	0.19	$	(0.02	)
Taxes and Other	$	0.08	$	0.08	$	—
Total Cash Operating Costs	$	0.91	$	0.96	$	(0.05	)
Depreciation, Depletion and Amortization Expense (“DD&A”)	$	0.62	$	0.71	$	(0.09	)
Total Operating Costs	$	1.53	$	1.67	$	(0.14	)

On a per unit basis, third quarter total cash operating costs were lower compared to the prior year, primarily due to higher production. LOE included $61 million ($0.55 per Mcf), or 83% of total LOE, for gathering and compression service fees paid to the Company’s Gathering segment to connect Seneca’s production to sales points along interstate pipelines. DD&A for the quarter was $0.62 per Mcf, a decrease of $0.09 per Mcf from the prior year, largely due to ceiling test impairments recorded in prior quarters that lowered Seneca’s full cost pool depletable base.

Midstream Businesses

Pipeline and Storage Segment

The Pipeline and Storage segment’s operations are carried out by National Fuel Gas Supply Corporation (“Supply Corporation”) and Empire Pipeline, Inc. (“Empire”). The Pipeline and Storage segment provides natural gas transportation and storage services to affiliated and non-affiliated companies through an integrated system of pipelines and underground natural gas storage fields in western New York and Pennsylvania.

	Three Months Ended
	June 30,
(in thousands)		2025		2024	Variance
GAAP Earnings	$	28,857	$	30,690	$	(1,833	)

Adjusted EBITDA	$	67,019	$	68,221	$	(1,202	)

The Pipeline and Storage segment’s third quarter GAAP earnings decreased $1.8 million versus the prior year primarily due to higher Operations and Maintenance (“O&M”) expense. The increase in O&M expense was due largely to typical inflationary increases related to higher personnel costs and third-party contractors.

Gathering Segment

The Gathering segment’s operations are carried out by National Fuel Gas Midstream Company, LLC’s limited liability companies. The Gathering segment constructs, owns and operates natural gas gathering pipelines and compression facilities in the Appalachian region, which delivers Seneca and other non-affiliated Appalachian production to the interstate pipeline system.

	Three Months Ended
	June 30,
(in thousands)		2025		2024	Variance
GAAP Earnings	$	29,996	$	24,979	$	5,017

Adjusted EBITDA	$	55,923	$	47,631	$	8,292

The Gathering segment’s third quarter GAAP earnings increased $5.0 million versus the prior year primarily due to higher operating revenues, which increased $7.8 million, or 13%, primarily due to an increase in throughput from Seneca’s new wells located in Tioga County.

Downstream Business

Utility Segment

The Utility segment operations are carried out by National Fuel Gas Distribution Corporation (“Distribution Corporation”), which sells or transports natural gas to customers located in western New York and northwestern Pennsylvania.

	Three Months Ended
	June 30,
(in thousands)		2025		2024	Variance
GAAP Earnings	$	4,997	$	2,559	$	2,438

Adjusted EBITDA	$	25,743	$	21,047	$	4,696

The Utility segment’s third quarter GAAP earnings increased $2.4 million, or 95%, primarily as a result of new rates approved in the Utility’s New York rate case settlement, which became effective October 1, 2024, partially offset by higher operating costs and interest expense.

For the quarter, customer margin (operating revenues less purchased gas sold) increased $8.4 million, primarily due to an increase in customer usage, due in part to colder weather, as well as an increase in rates as part of the New York rate case settlement. Other income increased $4.0 million, largely due to the New York rate settlement, which required the recognition of non-service pension and post-retirement benefit income and a corresponding reduction in new base rates, resulting in no effect on net income.

O&M expense increased $2.7 million primarily driven by higher personnel costs, partially offset by a reduction in uncollectible expenses as a result of a tracker implemented as part of the New York rate case settlement. DD&A expense increased by $1.6 million primarily due to higher average depreciable plant in service compared to the prior year. Further, interest expense increased $2.5 million primarily due to a higher average amount of net borrowings.

Corporate and All Other

The Company’s operations that are included in Corporate and All Other generated a combined net loss of $0.7 million, which was largely consistent with the prior year.

EARNINGS TELECONFERENCE

A conference call to discuss the results will be held on Thursday, July 31, 2025, at 9 a.m. ET. All participants must pre-register to join this conference using the Participant Registration link. A webcast link to the conference call will be provided under the Events Calendar on the NFG Investor Relations website at investor.nationalfuelgas.com. A replay will be available following the call through the end of the day, Thursday, August 7, 2025. To access the replay, dial 1-866-813-9403 and provide Access Code 592578.

National Fuel is an integrated energy company reporting financial results for four operating segments: Exploration and Production, Pipeline and Storage, Gathering, and Utility. Additional information about National Fuel is available at www.nationalfuel.com.

Certain statements contained herein, including statements identified by the use of the words “anticipates,” “estimates,” “expects,” “forecasts,” “intends,” “plans,” “predicts,” “projects,” “believes,” “seeks,” “will,” “may” and similar expressions, and statements which are other than statements of historical facts, are “forward-looking statements” as defined by the Private Securities Litigation Reform Act of 1995. Forward-looking statements involve risks and uncertainties, which could cause actual results or outcomes to differ materially from those expressed in the forward-looking statements. The Company’s expectations, beliefs and projections contained herein are expressed in good faith and are believed to have a reasonable basis, but there can be no assurance that such expectations, beliefs or projections will result or be achieved or accomplished. In addition to other factors, the following are important factors that could cause actual results to differ materially from those discussed in the forward-looking statements: changes in laws, regulations or judicial interpretations to which the Company is subject, including those involving derivatives, taxes, safety, employment, climate change, other environmental matters, real property, and exploration and production activities such as hydraulic fracturing; governmental/regulatory actions, initiatives and proceedings, including those involving rate cases (which address, among other things, target rates of return, rate design, retained natural gas and system modernization), environmental/safety requirements, affiliate relationships, industry structure, and franchise renewal; changes in economic conditions, including the imposition of additional tariffs on U.S. imports and related retaliatory tariffs, inflationary pressures, supply chain issues, liquidity challenges, and global, national or regional recessions, and their effect on the demand for, and customers’ ability to pay for, the Company’s products and services; the Company’s ability to estimate accurately the time and resources necessary to meet emissions targets; governmental/regulatory actions and/or market pressures to reduce or eliminate reliance on natural gas; impairments under the SEC’s full cost ceiling test for natural gas reserves; changes in the price of natural gas; the creditworthiness or performance of the Company’s key suppliers, customers and counterparties; financial and economic conditions, including the availability of credit, and occurrences affecting the Company’s ability to obtain financing on acceptable terms for working capital, capital expenditures and other investments, including any downgrades in the Company’s credit ratings and changes in interest rates and other capital market conditions; the Company’s ability to complete strategic transactions; changes in price differentials between similar quantities of natural gas sold at different geographic locations, and the effect of such changes on commodity production, revenues and demand for pipeline transportation capacity to or from such locations; the impact of information technology disruptions, cybersecurity or data security breaches, including the impact of issues that may arise from the use of artificial intelligence technologies; factors affecting the Company’s ability to successfully identify, drill for and produce economically viable natural gas reserves, including among others geology, lease availability and costs, title disputes, weather conditions, water availability and disposal or recycling opportunities of used water, shortages, delays or unavailability of equipment and services required in drilling operations, insufficient gathering, processing and transportation capacity, the need to obtain governmental approvals and permits, and compliance with environmental laws and regulations; increased costs or delays or changes in plans with respect to Company projects or related projects of other companies, as well as difficulties or delays in obtaining necessary governmental approvals, permits or orders or in obtaining the cooperation of interconnecting facility operators; increasing health care costs and the resulting effect on health insurance premiums and on the obligation to provide other post-retirement benefits; other changes in price differentials between similar quantities of natural gas having different quality, heating value, hydrocarbon mix or delivery date; the cost and effects of legal and administrative claims against the Company or activist shareholder campaigns to effect changes at the Company; negotiations with the collective bargaining units representing the Company’s workforce, including potential work stoppages during negotiations; uncertainty of natural gas reserve estimates; significant differences between the Company’s projected and actual production levels for natural gas; changes in demographic patterns and weather conditions (including those related to climate change); changes in the availability, price or accounting treatment of derivative financial instruments; changes in laws, actuarial assumptions, the interest rate environment and the return on plan/trust assets related to the Company’s pension and other post-retirement benefits, which can affect future funding obligations and costs and plan liabilities; economic disruptions or uninsured losses resulting from major accidents, fires, severe weather, natural disasters, terrorist activities or acts of war, as well as economic and operational disruptions due to third-party outages; significant differences between the Company’s projected and actual capital expenditures and operating expenses; or increasing costs of insurance, changes in coverage and the ability to obtain insurance. The Company disclaims any obligation to update any forward-looking statements to reflect events or circumstances after the date thereof.

NATIONAL FUEL GAS COMPANY
AND SUBSIDIARIES

GUIDANCE SUMMARY

As discussed on page 2, the Company is revising its adjusted earnings per share guidance for fiscal 2025. Additional details on the Company’s forecast assumptions and business segment guidance are outlined in the table below.

The revised adjusted earnings per share guidance range excludes certain items that impacted the comparability of adjusted operating results during the nine months ended June 30, 2025, including: (1) the after tax impairment of assets, which reduced earnings by $1.14 per share; (2) after-tax premiums paid on early redemptions of debt, which reduced earnings by $0.02 per share; (3) after-tax unrealized losses on a derivative asset, which reduced earnings by $0.01 per share; and (4) after-tax unrealized losses on other investments, which reduced earnings by $0.02 per share. While the Company expects to record certain adjustments to unrealized gain or loss on investments during the remaining three months ending September 30, 2025, the amounts of these and other potential adjustments are not reasonably determinable at this time. As such, the Company is unable to provide earnings guidance other than on a non-GAAP basis.

	Updated FY 2025 Guidance	Preliminary FY 2026 Guidance

Consolidated Adjusted Earnings per Share	$6.80 to $6.95	See sensitivity table on p.2
Consolidated Effective Tax Rate	~ 25.5%	~ 25.5%

Capital Expenditures (Millions)
Exploration and Production	$500 – $510	$470 – $500
Pipeline and Storage	$120 – $140	$210 – $250
Gathering	$95 – $110	$90 – $110
Utility	$175 – $195	$185 – $205
Consolidated Capital Expenditures	$890 – $955	$955 – $1,065

Exploration and Production Segment Guidance

Commodity Price Assumptions	(remaining three months)
NYMEX natural gas price (per MMBtu)	$3.25	$3.00 / $4.00 / $5.00
Appalachian basin spot price (per MMBtu)	$2.50	$2.30 / $3.10 / $3.90

Production (Bcf)	420 to 425	440 to 455

E&P Operating Costs ($/Mcf)
LOE	$0.67 – $0.68	$0.67 – $0.68
G&A	~$0.18	~$0.18
DD&A	$0.63 – $0.65	$0.65 – $0.69

Other Business Segment Guidance (Millions)
Gathering Segment Revenues	$255 – $260	$245 – $255
Pipeline and Storage Segment Revenues	$420 – $430	$415 – $430

Utility Segment Guidance (Millions)
Customer Margin*	$450 – $460	$470 – $490
O&M Expense	$240 – $245	$250 – $260
Non-Service Pension & OPEB Income	$23 – $27	$23 – $27
^{* Customer Margin is defined as Operating Revenues less Purchased Gas Expense.}

NATIONAL FUEL GAS COMPANY
RECONCILIATION OF CURRENT AND PRIOR YEAR GAAP EARNINGS
QUARTER ENDED JUNE 30, 2025
(Unaudited)

	Upstream			Midstream						Downstream

	Exploration &			Pipeline &									Corporate /
(Thousands of Dollars)	Production			Storage			Gathering			Utility			All Other			Consolidated*

Third quarter 2024 GAAP earnings	$	(112,028	)	$	30,690		$	24,979		$	2,559		$	(358	)	$	(54,158	)
Items impacting comparability:
Impairment of assets		200,696															200,696
Tax impact of impairment of assets		(55,686	)														(55,686	)
Unrealized (gain) loss on derivative asset		1,186															1,186
Tax impact of unrealized (gain) loss on derivative asset		(325	)														(325	)
Unrealized (gain) loss on other investments														15			15
Tax impact of unrealized (gain) loss on other investments														(3	)		(3	)
Third quarter 2024 adjusted operating results		33,843			30,690			24,979			2,559			(346	)		91,725
Drivers of adjusted operating results**
Upstream Revenues
Higher (lower) natural gas production		27,144															27,144
Higher (lower) realized natural gas prices, after hedging		38,281															38,281
Midstream Revenues
Higher (lower) operating revenues								6,125									6,125
Downstream Margins***
Impact of usage and weather											2,738						2,738
Impact of new rates in New York											2,788						2,788
Regulatory revenue adjustments											670						670
Operating Expenses
Lower (higher) lease operating and transportation expenses		(5,747	)														(5,747	)
Lower (higher) operating expenses					(1,687	)					(2,126	)		(1,463	)		(5,276	)
Lower (higher) property, franchise and other taxes		(1,636	)														(1,636	)
Lower (higher) depreciation / depletion								(882	)		(1,242	)					(2,124	)
Other Income (Expense)
Higher (lower) other income		(531	)		(1,238	)					3,169			1,352			2,752
(Higher) lower interest expense		589			510						(2,007	)		(1,616	)		(2,524	)
Income Taxes
Lower (higher) income tax expense / effective tax rate		(5,564	)		(39	)		(178	)		(1,190	)		710			(6,261	)

All other / rounding		325			621			(48	)		(362	)		12			548
Third quarter 2025 adjusted operating results		86,704			28,857			29,996			4,997			(1,351	)		149,203
Items impacting comparability:
Unrealized gain (loss) on derivative asset		(45	)														(45	)
Tax impact of unrealized gain (loss) on derivative asset		12															12
Unrealized gain (loss) on other investments														820			820
Tax impact of unrealized gain (loss) on other investments														(172	)		(172	)
Third quarter 2025 GAAP earnings	$	86,671		$	28,857		$	29,996		$	4,997		$	(703	)	$	149,818

^{* Amounts do not reflect intercompany eliminations.}
^{** Drivers of adjusted operating results have been calculated using the 21% federal statutory rate.}
^{*** Downstream margin defined as operating revenues less purchased gas expense.}

NATIONAL FUEL GAS COMPANY
RECONCILIATION OF CURRENT AND PRIOR YEAR GAAP EARNINGS PER SHARE
QUARTER ENDED JUNE 30, 2025
(Unaudited)

	Upstream			Midstream						Downstream

	Exploration &			Pipeline &									Corporate /
	Production			Storage			Gathering			Utility			All Other			Consolidated*

Third quarter 2024 GAAP earnings per share	$	(1.22	)	$	0.33		$	0.27		$	0.03		$	—		$	(0.59	)
Items impacting comparability:
Impairment of assets, net of tax		1.58															1.58
Unrealized (gain) loss on derivative asset, net of tax		0.01															0.01
Unrealized (gain) loss on other investments, net of tax														—			—
Rounding														(0.01	)		(0.01	)
Third quarter 2024 adjusted operating results per share		0.37			0.33			0.27			0.03			(0.01	)		0.99
Drivers of adjusted operating results**
Upstream Revenues
Higher (lower) natural gas production		0.30															0.30
Higher (lower) realized natural gas prices, after hedging		0.42															0.42
Midstream Revenues
Higher (lower) operating revenues								0.07									0.07
Downstream Margins***
Impact of usage and weather											0.03						0.03
Impact of new rates in New York											0.03						0.03
Regulatory revenue adjustments											0.01						0.01
Operating Expenses
Lower (higher) lease operating and transportation expenses		(0.06	)														(0.06	)
Lower (higher) operating expenses					(0.02	)					(0.02	)		(0.02	)		(0.06	)
Lower (higher) property, franchise and other taxes		(0.02	)														(0.02	)
Lower (higher) depreciation / depletion								(0.01	)		(0.01	)					(0.02	)
Other Income (Expense)
Higher (lower) other income		(0.01	)		(0.01	)					0.03			0.01			0.02
(Higher) lower interest expense		0.01			0.01						(0.02	)		(0.02	)		(0.02	)
Income Taxes
Lower (higher) income tax expense / effective tax rate		(0.06	)		—			—			(0.01	)		0.01			(0.06	)

All other / rounding		—			0.01			—			(0.02	)		0.02			0.01
Third quarter 2025 adjusted operating results per share		0.95			0.32			0.33			0.05			(0.01	)		1.64
Items impacting comparability:
Unrealized gain (loss) on derivative asset, net of tax		—															—
Unrealized gain (loss) on other investments, net of tax														0.01			0.01
Rounding														(0.01	)		(0.01	)
Third quarter 2025 GAAP earnings per share	$	0.95		$	0.32		$	0.33		$	0.05		$	(0.01	)	$	1.64

^{* Amounts do not reflect intercompany eliminations.}
^{** Drivers of adjusted operating results have been calculated using the 21% federal statutory rate.}
^{*** Downstream margin defined as operating revenues less purchased gas expense.}

NATIONAL FUEL GAS COMPANY
RECONCILIATION OF CURRENT AND PRIOR YEAR GAAP EARNINGS
NINE MONTHS ENDED JUNE 30, 2025
(Unaudited)

	Upstream			Midstream						Downstream

	Exploration &			Pipeline &									Corporate /
(Thousands of Dollars)	Production			Storage			Gathering			Utility			All Other			Consolidated*
Nine months ended June 30, 2024 GAAP earnings	$	2,521		$	85,482		$	82,510		$	73,848		$	773		$	245,134
Items impacting comparability:
Impairment of assets		200,696															200,696
Tax impact of impairment of assets		(55,686	)														(55,686	)
Unrealized (gain) loss on derivative asset		4,848															4,848
Tax impact of unrealized (gain) loss on derivative asset		(1,330	)														(1,330	)
Unrealized (gain) loss on other investments														(1,803	)		(1,803	)
Tax impact of unrealized (gain) loss on other investments														379			379
Nine months ended June 30, 2024 adjusted operating results		151,049			85,482			82,510			73,848			(651	)		392,238
Drivers of adjusted operating results**
Upstream Revenues
Higher (lower) natural gas production		28,414															28,414
Higher (lower) realized natural gas prices, after hedging		70,158															70,158
Midstream Revenues
Higher (lower) operating revenues					12,241			5,793									18,034
Downstream Margins***
Impact of usage and weather											5,423						5,423
Impact of new rates in New York											25,230						25,230
Higher (lower) other operating revenues											(1,400	)					(1,400	)
Operating Expenses
Lower (higher) lease operating and transportation expenses		(5,810	)														(5,810	)
Lower (higher) operating expenses		(1,490	)		(3,790	)		(751	)		(6,700	)		(1,740	)		(14,471	)
Lower (higher) property, franchise and other taxes		(2,381	)														(2,381	)
Lower (higher) depreciation / depletion		13,760						(2,684	)		(2,551	)					8,525
Other Income (Expense)
Higher (lower) other income		(2,420	)		(1,840	)					14,888			3,653			14,281
(Higher) lower interest expense					838			(1,648	)		(5,686	)		(4,780	)		(11,276	)
Income Taxes
Lower (higher) income tax expense / effective tax rate		(7,902	)		(286	)		727			(2,318	)		755			(9,024	)

All other / rounding		555			374			234			306			67			1,536
Nine months ended June 30, 2025 adjusted operating results		243,933			93,019			84,181			101,040			(2,696	)		519,477
Items impacting comparability:
Impairment of assets		(141,802	)														(141,802	)
Tax impact of impairment of assets		37,169															37,169
Premiums paid on early redemption of debt		(1,430	)					(955	)								(2,385	)
Tax impact of premiums paid on early redemption of debt		385						257									642
Unrealized gain (loss) on derivative asset		(729	)														(729	)
Tax impact of unrealized gain (loss) on derivative asset		196															196
Unrealized gain (loss) on other investments														(1,780	)		(1,780	)
Tax impact of unrealized gain (loss) on other investments														374			374
Nine months ended June 30, 2025 GAAP earnings	$	137,722		$	93,019		$	83,483		$	101,040		$	(4,102	)	$	411,162

^{* Amounts do not reflect intercompany eliminations.}
^{** Drivers of adjusted operating results have been calculated using the 21% federal statutory rate.}
^{*** Downstream margin defined as operating revenues less purchased gas expense.}

NATIONAL FUEL GAS COMPANY
RECONCILIATION OF CURRENT AND PRIOR YEAR GAAP EARNINGS PER SHARE
NINE MONTHS ENDED JUNE 30, 2025
(Unaudited)

	Upstream			Midstream						Downstream

	Exploration &			Pipeline &									Corporate /
	Production			Storage			Gathering			Utility			All Other			Consolidated*
Nine months ended June 30, 2024 GAAP earnings per share	$	0.03		$	0.92		$	0.89		$	0.80		$	0.01		$	2.65
Items impacting comparability:
Impairment of assets, net of tax		1.57															1.57
Unrealized (gain) loss on derivative asset, net of tax		0.04															0.04
Unrealized (gain) loss on other investments, net of tax														(0.02	)		(0.02	)
Rounding		(0.01	)											0.01			—
Nine months ended June 30, 2024 adjusted operating results per share		1.63			0.92			0.89			0.80			—			4.24
Drivers of adjusted operating results**
Upstream Revenues
Higher (lower) natural gas production		0.31															0.31
Higher (lower) realized natural gas prices, after hedging		0.77															0.77
Midstream Revenues
Higher (lower) operating revenues					0.13			0.06									0.19
Downstream Margins***
Impact of usage and weather											0.06						0.06
Impact of new rates in New York											0.28						0.28
Higher (lower) other operating revenues											0.01						0.01
Operating Expenses
Lower (higher) lease operating and transportation expenses		(0.06	)														(0.06	)
Lower (higher) operating expenses		(0.02	)		(0.04	)		(0.01	)		(0.07	)		(0.02	)		(0.16	)
Lower (higher) property, franchise and other taxes		(0.03	)														(0.03	)
Lower (higher) depreciation / depletion		0.15						(0.03	)		(0.03	)					0.09
Other Income (Expense)
Higher (lower) other income		(0.03	)		(0.02	)					0.16			0.04			0.15
(Higher) lower interest expense					0.01			(0.02	)		(0.06	)		(0.05	)		(0.12	)
Income Taxes
Lower (higher) income tax expense / effective tax rate		(0.09	)		—			0.01			(0.03	)		0.01			(0.10	)

Impact of reduction in shares		0.03			0.01			0.01			0.01			—			0.06
All other / rounding		0.01			0.01			0.01			(0.02	)		(0.01	)		—
Nine months ended June 30, 2025 adjusted operating results per share		2.67			1.02			0.92			1.11			(0.03	)		5.69
Items impacting comparability:
Impairment of assets, net of tax		(1.14	)														(1.14	)
Premiums paid on early redemption of debt, net of tax		(0.01	)					(0.01	)								(0.02	)
Unrealized gain (loss) on derivative asset, net of tax		(0.01	)														(0.01	)
Unrealized gain (loss) on other investments, net of tax														(0.02	)		(0.02	)
Rounding														0.01			0.01
Nine months ended June 30, 2025 GAAP earnings per share	$	1.51		$	1.02		$	0.91		$	1.11		$	(0.04	)	$	4.51

^{* Amounts do not reflect intercompany eliminations.}
^{** Drivers of adjusted operating results have been calculated using the 21% federal statutory rate.}
^{*** Downstream margin defined as operating revenues less purchased gas expense.}

NATIONAL FUEL GAS COMPANY
AND SUBSIDIARIES

(Thousands of Dollars, except per share amounts)
	Three Months Ended						Nine Months Ended
	June 30,						June 30,
	(Unaudited)						(Unaudited)
SUMMARY OF OPERATIONS		2025			2024			2025			2024
Operating Revenues:
Utility Revenues	$	157,446		$	124,858		$	729,445		$	616,977
Exploration and Production and Other Revenues		303,883			220,905			864,701			739,537
Pipeline and Storage and Gathering Revenues		70,501			71,679			217,116			216,228
		531,830			417,442			1,811,262			1,572,742
Operating Expenses:
Purchased Gas		27,986			4,952			228,661			167,444
Operation and Maintenance:
Utility		56,053			53,412			174,744			166,405
Exploration and Production and Other		35,272			35,148			103,874			102,768
Pipeline and Storage and Gathering		41,679			40,019			119,982			114,321
Property, Franchise and Other Taxes		24,180			21,201			71,450			66,635
Depreciation, Depletion and Amortization		116,408			113,454			337,055			348,179
Impairment of Assets		—			200,696			141,802			200,696
		301,578			468,882			1,177,568			1,166,448

Operating Income (Loss)		230,252			(51,440	)		633,694			406,294

Other Income (Expense):
Other Income (Deductions)		8,534			3,188			31,486			12,989
Interest Expense on Long-Term Debt		(34,333	)		(32,876	)		(107,356	)		(89,791	)
Other Interest Expense		(3,556	)		(1,341	)		(13,033	)		(14,250	)

Income (Loss) Before Income Taxes		200,897			(82,469	)		544,791			315,242

Income Tax Expense (Benefit)		51,079			(28,311	)		133,629			70,108

Net Income (Loss) Available for Common Stock	$	149,818		$	(54,158	)	$	411,162		$	245,134

Earnings (Loss) Per Common Share
Basic	$	1.66		$	(0.59	)	$	4.54		$	2.67
Diluted	$	1.64		$	(0.59	)	$	4.51		$	2.65

Weighted Average Common Shares:
Used in Basic Calculation		90,358,018			91,874,049			90,546,228			91,966,034
Used in Diluted Calculation		91,139,556			91,874,049			91,247,547			92,467,787

NATIONAL FUEL GAS COMPANY
AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(Unaudited)

	June 30,			September 30,
(Thousands of Dollars)		2025			2024
ASSETS
Property, Plant and Equipment	$	15,044,963		$	14,524,798
Less – Accumulated Depreciation, Depletion and Amortization		7,588,956			7,185,593
Net Property, Plant and Equipment		7,456,007			7,339,205
Current Assets:
Cash and Temporary Cash Investments		39,317			38,222
Receivables – Net		222,515			127,222
Unbilled Revenue		15,347			15,521
Gas Stored Underground		12,810			35,055
Materials and Supplies – at average cost		51,022			47,670
Unrecovered Purchased Gas Costs		2,903			—
Other Current Assets		64,241			92,229
Total Current Assets		408,155			355,919
Other Assets:
Recoverable Future Taxes		90,493			80,084
Unamortized Debt Expense		6,701			5,604
Other Regulatory Assets		124,300			108,022
Deferred Charges		71,426			69,662
Other Investments		73,764			81,705
Goodwill		5,476			5,476
Prepaid Pension and Post-Retirement Benefit Costs		199,286			180,230
Fair Value of Derivative Financial Instruments		2,394			87,905
Other		8,158			5,958
Total Other Assets		581,998			624,646
Total Assets	$	8,446,160		$	8,319,770
CAPITALIZATION AND LIABILITIES
Capitalization:
Comprehensive Shareholders’ Equity
Common Stock, $1 Par Value Authorized – 200,000,000 Shares; Issued and
Outstanding – 90,355,956 Shares and 91,005,993 Shares, Respectively	$	90,356		$	91,006
Paid in Capital		1,047,406			1,045,487
Earnings Reinvested in the Business		1,953,533			1,727,326
Accumulated Other Comprehensive Loss		(115,807	)		(15,476	)
Total Comprehensive Shareholders’ Equity		2,975,488			2,848,343
Long-Term Debt, Net of Current Portion and Unamortized Discount and Debt Issuance Costs		2,381,852			2,188,243
Total Capitalization		5,357,340			5,036,586
Current and Accrued Liabilities:
Notes Payable to Banks and Commercial Paper		61,500			90,700
Current Portion of Long-Term Debt		300,000			500,000
Accounts Payable		123,131			165,068
Amounts Payable to Customers		24,275			42,720
Dividends Payable		48,340			46,872
Interest Payable on Long-Term Debt		39,060			27,247
Customer Advances		—			19,373
Customer Security Deposits		28,739			36,265
Other Accruals and Current Liabilities		207,179			162,903
Fair Value of Derivative Financial Instruments		57,673			4,744
Total Current and Accrued Liabilities		889,897			1,095,892
Other Liabilities:
Deferred Income Taxes		1,153,427			1,111,165
Taxes Refundable to Customers		297,602			305,645
Cost of Removal Regulatory Liability		302,932			292,477
Other Regulatory Liabilities		137,025			151,452
Other Post-Retirement Liabilities		3,393			3,511
Asset Retirement Obligations		188,305			203,006
Other Liabilities		116,239			120,036
Total Other Liabilities		2,198,923			2,187,292
Commitments and Contingencies		—			—
Total Capitalization and Liabilities	$	8,446,160		$	8,319,770

NATIONAL FUEL GAS COMPANY
AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)

	Nine Months Ended
	June 30,
(Thousands of Dollars)		2025			2024

Operating Activities:
Net Income Available for Common Stock	$	411,162		$	245,134
Adjustments to Reconcile Net Income to Net Cash
Provided by Operating Activities:
Impairment of Assets		141,802			200,696
Depreciation, Depletion and Amortization		337,055			348,179
Deferred Income Taxes		60,754			47,212
Premiums Paid on Early Redemption of Debt		2,385			—
Stock-Based Compensation		15,721			15,984
Other		19,296			18,542
Change in:
Receivables and Unbilled Revenue		(95,254	)		5,253
Gas Stored Underground and Materials and Supplies		18,803			18,981
Unrecovered Purchased Gas Costs		(2,903	)		—
Other Current Assets		28,038			17,431
Accounts Payable		1,744			(13,705	)
Amounts Payable to Customers		(18,445	)		3,550
Customer Advances		(19,373	)		(21,003	)
Customer Security Deposits		(7,526	)		7,910
Other Accruals and Current Liabilities		44,283			23,846
Other Assets		(35,348	)		(35,346	)
Other Liabilities		(39,918	)		(14,649	)
Net Cash Provided by Operating Activities	$	862,276		$	868,015

Investing Activities:
Capital Expenditures	$	(627,316	)	$	(684,200	)
Other		9,352			(1,371	)
Net Cash Used in Investing Activities	$	(617,964	)	$	(685,571	)

Financing Activities:
Changes in Notes Payable to Banks and Commercial Paper		(29,200	)		(287,500	)
Shares Repurchased Under Repurchase Plan		(54,430	)		(27,847	)
Reduction of Long-Term Debt		(1,004,086	)		—
Net Proceeds From Issuance of Long-Term Debt		988,731			299,396
Dividends Paid on Common Stock		(140,098	)		(136,610	)
Net Repurchases of Common Stock Under Stock and Benefit Plans		(4,134	)		(3,916	)
Net Cash Used in Financing Activities	$	(243,217	)	$	(156,477	)

Net Increase in Cash and Cash Equivalents		1,095			25,967
Cash and Cash Equivalents at Beginning of Period		38,222			55,447
Cash and Cash Equivalents at June 30	$	39,317		$	81,414

NATIONAL FUEL GAS COMPANY
AND SUBSIDIARIES

SEGMENT OPERATING RESULTS AND STATISTICS
(UNAUDITED)

UPSTREAM BUSINESS

	Three Months Ended									Nine Months Ended
(Thousands of Dollars, except per share amounts)	June 30,									June 30,
EXPLORATION AND PRODUCTION SEGMENT		2025			2024		Variance				2025			2024		Variance
Total Operating Revenues	$	303,883		$	220,905		$	82,978		$	864,701		$	739,537		$	125,164
Operating Expenses:
Operation and Maintenance:
General and Administrative Expense		18,602			18,213			389			56,776			53,170			3,606
Lease Operating and Transportation Expense		73,856			66,581			7,275			210,671			203,317			7,354
All Other Operation and Maintenance Expense		3,816			4,526			(710	)		10,994			12,714			(1,720	)
Property, Franchise and Other Taxes		5,121			3,050			2,071			12,778			9,764			3,014
Depreciation, Depletion and Amortization		68,848			68,778			70			196,773			214,191			(17,418	)
Impairment of Assets		—			200,696			(200,696	)		141,802			200,696			(58,894	)
		170,243			361,844			(191,601	)		629,794			693,852			(64,058	)

Operating Income (Loss)		133,640			(140,939	)		274,579			234,907			45,685			189,222

Other Income (Expense):
Non-Service Pension and Post-Retirement Benefit Credit		37			100			(63	)		111			301			(190	)
Interest and Other Income (Deductions)		44			(488	)		532			416			(830	)		1,246
Interest Expense on Long-Term Debt		—			—			—			(1,949	)		—			(1,949	)
Other Interest Expense		(13,925	)		(14,670	)		745			(44,215	)		(45,046	)		831
Income (Loss) Before Income Taxes		119,796			(155,997	)		275,793			189,270			110			189,160
Income Tax Expense (Benefit)		33,125			(43,969	)		77,094			51,548			(2,411	)		53,959
Net Income (Loss)	$	86,671		$	(112,028	)	$	198,699		$	137,722		$	2,521		$	135,201
Net Income (Loss) Per Share (Diluted)	$	0.95		$	(1.22	)	$	2.17		$	1.51		$	0.03		$	1.48

NATIONAL FUEL GAS COMPANY
AND SUBSIDIARIES

SEGMENT OPERATING RESULTS AND STATISTICS
(UNAUDITED)

MIDSTREAM BUSINESSES

	Three Months Ended									Nine Months Ended
(Thousands of Dollars, except per share amounts)	June 30,									June 30,
PIPELINE AND STORAGE SEGMENT		2025			2024		Variance				2025			2024		Variance
Revenues from External Customers	$	67,982		$	68,035		$	(53	)	$	207,916		$	204,071		$	3,845
Intersegment Revenues		37,597			37,384			213			113,849			103,781			10,068
Total Operating Revenues		105,579			105,419			160			321,765			307,852			13,913
Operating Expenses:
Purchased Gas		(164	)		614			(778	)		(42	)		1,540			(1,582	)
Operation and Maintenance		30,264			28,128			2,136			87,940			83,142			4,798
Property, Franchise and Other Taxes		8,460			8,456			4			25,727			25,776			(49	)
Depreciation, Depletion and Amortization		18,601			18,453			148			55,733			56,157			(424	)
		57,161			55,651			1,510			169,358			166,615			2,743

Operating Income		48,418			49,768			(1,350	)		152,407			141,237			11,170

Other Income (Expense):
Non-Service Pension and Post-Retirement Benefit Credit		952			1,257			(305	)		2,857			3,772			(915	)
Interest and Other Income		1,111			2,362			(1,251	)		4,945			6,340			(1,395	)
Interest Expense		(11,209	)		(11,855	)		646			(34,637	)		(35,698	)		1,061
Income Before Income Taxes		39,272			41,532			(2,260	)		125,572			115,651			9,921
Income Tax Expense		10,415			10,842			(427	)		32,553			30,169			2,384
Net Income	$	28,857		$	30,690		$	(1,833	)	$	93,019		$	85,482		$	7,537
Net Income Per Share (Diluted)	$	0.32		$	0.33		$	(0.01	)	$	1.02		$	0.92		$	0.10

	Three Months Ended									Nine Months Ended
	June 30,									June 30,
GATHERING SEGMENT		2025			2024		Variance				2025			2024		Variance
Revenues from External Customers	$	2,519		$	3,644		$	(1,125	)	$	9,200		$	12,157		$	(2,957	)
Intersegment Revenues		65,354			56,476			8,878			184,834			174,544			10,290
Total Operating Revenues		67,873			60,120			7,753			194,034			186,701			7,333
Operating Expenses:
Operation and Maintenance		11,929			12,382			(453	)		33,633			32,682			951
Property, Franchise and Other Taxes		21			107			(86	)		(206	)		224			(430	)
Depreciation, Depletion and Amortization		10,848			9,732			1,116			32,197			28,800			3,397
		22,798			22,221			577			65,624			61,706			3,918

Operating Income		45,075			37,899			7,176			128,410			124,995			3,415

Other Income (Expense):
Non-Service Pension and Post-Retirement Benefit Credit (Costs)		(1	)		9			(10	)		(1	)		28			(29	)
Interest and Other Income		—			113			(113	)		152			257			(105	)
Interest Expense on Long-Term Debt		—			—			—			(1,334	)		—			(1,334	)
Other Interest Expense		(3,870	)		(3,393	)		(477	)		(12,531	)		(10,824	)		(1,707	)
Income Before Income Taxes		41,204			34,628			6,576			114,696			114,456			240
Income Tax Expense		11,208			9,649			1,559			31,213			31,946			(733	)
Net Income	$	29,996		$	24,979		$	5,017		$	83,483		$	82,510		$	973
Net Income Per Share (Diluted)	$	0.33		$	0.27		$	0.06		$	0.91		$	0.89		$	0.02

NATIONAL FUEL GAS COMPANY
AND SUBSIDIARIES

SEGMENT OPERATING RESULTS AND STATISTICS
(UNAUDITED)

DOWNSTREAM BUSINESS

	Three Months Ended									Nine Months Ended
(Thousands of Dollars, except per share amounts)	June 30,									June 30,
UTILITY SEGMENT		2025			2024		Variance				2025			2024		Variance
Revenues from External Customers	$	157,446		$	124,858		$	32,588		$	729,445		$	616,977		$	112,468
Intersegment Revenues		77			86			(9	)		279			479			(200	)
Total Operating Revenues		157,523			124,944			32,579			729,724			617,456			112,268
Operating Expenses:
Purchased Gas		64,292			40,096			24,196			337,541			264,983			72,558
Operation and Maintenance		57,039			54,349			2,690			177,742			169,261			8,481
Property, Franchise and Other Taxes		10,449			9,452			997			32,761			30,471			2,290
Depreciation, Depletion and Amortization		17,945			16,373			1,572			51,908			48,678			3,230
		149,725			120,270			29,455			599,952			513,393			86,559

Operating Income		7,798			4,674			3,124			129,772			104,063			25,709

Other Income (Expense):
Non-Service Pension and Post-Retirement Benefit Credit		5,328			462			4,866			23,498			1,788			21,710
Interest and Other Income		628			1,485			(857	)		1,869			4,735			(2,866	)
Interest Expense		(10,958	)		(8,417	)		(2,541	)		(32,601	)		(25,402	)		(7,199	)
Income (Loss) Before Income Taxes		2,796			(1,796	)		4,592			122,538			85,184			37,354
Income Tax Expense (Benefit)		(2,201	)		(4,355	)		2,154			21,498			11,336			10,162
Net Income	$	4,997		$	2,559		$	2,438		$	101,040		$	73,848		$	27,192
Net Income Per Share (Diluted)	$	0.05		$	0.03		$	0.02		$	1.11		$	0.80		$	0.31

NATIONAL FUEL GAS COMPANY
AND SUBSIDIARIES

SEGMENT OPERATING RESULTS AND STATISTICS
(UNAUDITED)

	Three Months Ended									Nine Months Ended
(Thousands of Dollars, except per share amounts)	June 30,									June 30,
ALL OTHER		2025			2024		Variance				2025			2024		Variance
Total Operating Revenues	$	—		$	—		$	—		$	—		$	—		$	—
Operating Expenses:
Operation and Maintenance		—			—			—			—			—			—
		—			—			—			—			—			—

Operating Income		—			—			—			—			—			—
Other Income (Expense):
Interest and Other Income (Deductions)		(131	)		(65	)		(66	)		(489	)		(184	)		(305	)
Interest Expense		(141	)		(97	)		(44	)		(389	)		(262	)		(127	)
Loss before Income Taxes		(272	)		(162	)		(110	)		(878	)		(446	)		(432	)
Income Tax Benefit		(63	)		(38	)		(25	)		(204	)		(105	)		(99	)
Net Loss	$	(209	)	$	(124	)	$	(85	)	$	(674	)	$	(341	)	$	(333	)
Net Loss Per Share (Diluted)	$	—		$	—		$	—		$	(0.01	)	$	—		$	(0.01	)

	Three Months Ended									Nine Months Ended
	June 30,									June 30,
CORPORATE		2025			2024		Variance				2025			2024		Variance
Revenues from External Customers	$	—		$	—		$	—		$	—		$	—		$	—
Intersegment Revenues		1,341			1,285			56			4,024			3,856			168
Total Operating Revenues		1,341			1,285			56			4,024			3,856			168
Operating Expenses:
Operation and Maintenance		5,725			3,873			1,852			14,992			12,789			2,203
Property, Franchise and Other Taxes		129			136			(7	)		390			400			(10	)
Depreciation, Depletion and Amortization		166			118			48			444			353			91
		6,020			4,127			1,893			15,826			13,542			2,284

Operating Loss		(4,679	)		(2,842	)		(1,837	)		(11,802	)		(9,686	)		(2,116	)
Other Income (Expense):
Non-Service Pension and Post-Retirement Benefit Costs		(212	)		(386	)		174			(635	)		(1,161	)		526
Interest and Other Income		41,073			39,025			2,048			123,918			120,288			3,630
Interest Expense on Long-Term Debt		(34,333	)		(32,876	)		(1,457	)		(104,073	)		(89,791	)		(14,282	)
Other Interest Expense		(3,748	)		(3,595	)		(153	)		(13,815	)		(19,363	)		5,548
Income (Loss) before Income Taxes		(1,899	)		(674	)		(1,225	)		(6,407	)		287			(6,694	)
Income Tax Benefit		(1,405	)		(440	)		(965	)		(2,979	)		(827	)		(2,152	)
Net Income (Loss)	$	(494	)	$	(234	)	$	(260	)	$	(3,428	)	$	1,114		$	(4,542	)
Net Income (Loss) Per Share (Diluted)	$	(0.01	)	$	—		$	(0.01	)	$	(0.03	)	$	0.01		$	(0.04	)

	Three Months Ended									Nine Months Ended
	June 30,									June 30,
INTERSEGMENT ELIMINATIONS		2025			2024		Variance				2025			2024		Variance
Intersegment Revenues	$	(104,369	)	$	(95,231	)	$	(9,138	)	$	(302,986	)	$	(282,660	)	$	(20,326	)
Operating Expenses:
Purchased Gas		(36,142	)		(35,758	)		(384	)		(108,838	)		(99,079	)		(9,759	)
Operation and Maintenance		(68,227	)		(59,473	)		(8,754	)		(194,148	)		(183,581	)		(10,567	)
		(104,369	)		(95,231	)		(9,138	)		(302,986	)		(282,660	)		(20,326	)
Operating Income		—			—			—			—			—			—
Other Income (Expense):
Interest and Other Deductions		(40,295	)		(40,686	)		391			(125,155	)		(122,345	)		(2,810	)
Interest Expense		40,295			40,686			(391	)		125,155			122,345			2,810
Net Income	$	—		$	—		$	—		$	—		$	—		$	—
Net Income Per Share (Diluted)	$	—		$	—		$	—		$	—		$	—		$	—

NATIONAL FUEL GAS COMPANY
AND SUBSIDIARIES

SEGMENT INFORMATION (Continued)
(Thousands of Dollars)

	Three Months Ended									Nine Months Ended
	June 30,									June 30,
	(Unaudited)									(Unaudited)
							Increase										Increase
		2025			2024		(Decrease)				2025				2024		(Decrease)

Capital Expenditures:
Exploration and Production	$	123,369	_⁽¹⁾	$	114,679	_⁽³⁾	$	8,690		$	354,355		_{⁽¹⁾⁽²⁾}	$	399,820	_{⁽³⁾⁽⁴⁾}	$	(45,465	)
Pipeline and Storage		22,700	_⁽¹⁾		26,212	_⁽³⁾		(3,512	)		58,117		_{⁽¹⁾⁽²⁾}		68,791	_{⁽³⁾⁽⁴⁾}		(10,674	)
Gathering		26,638	_⁽¹⁾		29,570	_⁽³⁾		(2,932	)		58,164		_{⁽¹⁾⁽²⁾}		69,088	_{⁽³⁾⁽⁴⁾}		(10,924	)
Utility		50,025	_⁽¹⁾		49,257	_⁽³⁾		768			128,322		_{⁽¹⁾⁽²⁾}		117,508	_{⁽³⁾⁽⁴⁾}		10,814
Total Reportable Segments		222,732			219,718			3,014			598,958				655,207			(56,249	)
All Other		—			—			—			—				—			—
Corporate		138			71			67			518				253			265
Eliminations		—			—			—			(3,520	)			—			(3,520	)
Total Capital Expenditures	$	222,870		$	219,789		$	3,081		$	595,956			$	655,460		$	(59,504	)
_{⁽¹⁾ Capital expenditures for the quarter and nine months ended June 30, 2025, include accounts payable and accrued liabilities related to capital expenditures of $61.5 million, $5.7 million, $11.6 million, and $9.8 million in the Exploration and Production segment, Pipeline and Storage segment, Gathering segment and Utility segment, respectively. These amounts have been excluded from the Consolidated Statement of Cash Flows at June 30, 2025, since they represent non-cash investing activities at that date.}
_{⁽²⁾ Capital expenditures for the nine months ended June 30, 2025, exclude capital expenditures of $63.3 million, $14.4 million, $21.7 million and $20.6 million in the Exploration and Production segment, Pipeline and Storage segment, Gathering segment and Utility segment, respectively. These amounts were in accounts payable and accrued liabilities at September 30, 2024 and paid during the nine months ended June 30, 2025. These amounts were excluded from the Consolidated Statement of Cash Flows at September 30, 2024, since they represented non-cash investing activities at that date. These amounts have been included in the Consolidated Statement of Cash Flows at June 30, 2025.}
_{⁽³⁾ Capital expenditures for the quarter and nine months ended June 30, 2024, include accounts payable and accrued liabilities related to capital expenditures of $50.9 million, $7.0 million, $14.6 million, and $8.0 million in the Exploration and Production segment, Pipeline and Storage segment, Gathering segment and Utility segment, respectively. These amounts were excluded from the Consolidated Statement of Cash Flows at June 30, 2024, since they represented non-cash investing activities at that date.}
_{⁽⁴⁾ Capital expenditures for the nine months ended June 30, 2024, exclude capital expenditures of $43.2 million, $31.8 million, $20.6 million and $13.6 million in the Exploration and Production segment, Pipeline and Storage segment, Gathering segment and Utility segment, respectively. These amounts were in accounts payable and accrued liabilities at September 30, 2023 and paid during the nine months ended June 30, 2024. These amounts were excluded from the Consolidated Statement of Cash Flows at September 30, 2023, since they represented non-cash investing activities at that date. These amounts have been included in the Consolidated Statement of Cash Flows at June 30, 2024.}

DEGREE DAYS
				Percent Colder
				(Warmer) Than:
Three Months Ended June 30,	Normal	2025	2024	Normal ⁽¹⁾		Last Year ⁽¹⁾
Buffalo, NY ⁽²⁾	843	825	565	(2.1	)	46.0
Erie, PA	776	813	519	4.8		56.6

Nine Months Ended June 30,
Buffalo, NY ⁽²⁾	6,195	5,825	5,128	(6.0	)	13.6
Erie, PA	5,693	5,527	4,759	(2.9	)	16.1
_{⁽¹⁾Percents compare actual 2025 degree days to normal degree days and actual 2025 degree days to actual 2024 degree days.}
_{⁽²⁾Normal degree days changed from NOAA 30-year degree days to NOAA 15-year degree days with the implementation of new base rates in New York effective October 2024.}

NATIONAL FUEL GAS COMPANY
AND SUBSIDIARIES

EXPLORATION AND PRODUCTION INFORMATION

	Three Months Ended							Nine Months Ended
	June 30,							June 30,
					Increase							Increase
		2025		2024	(Decrease)				2025		2024	(Decrease)

Gas Production/Prices:
Production (MMcf)
Appalachia		111,588		96,504		15,084			314,819		300,144		14,675

Average Prices (Per Mcf)
Weighted Average	$	2.69	$	1.50	$	1.19		$	2.66	$	1.93	$	0.73
Weighted Average after Hedging	$	2.71	$	2.28	$	0.43		$	2.73	$	2.45	$	0.28

Selected Operating Performance Statistics:
General and Administrative Expense per Mcf ⁽¹⁾	$	0.17	$	0.19	$	(0.02	)	$	0.18	$	0.18	$	—
Lease Operating and Transportation Expense per Mcf ⁽¹⁾⁽²⁾	$	0.66	$	0.69	$	(0.03	)	$	0.67	$	0.68	$	(0.01	)
Depreciation, Depletion and Amortization per Mcf ⁽¹⁾	$	0.62	$	0.71	$	(0.09	)	$	0.63	$	0.71	$	(0.08	)
_{⁽¹⁾Refer to page 15 for the General and Administrative Expense, Lease Operating and Transportation Expense and Depreciation, Depletion, and Amortization Expense for the Exploration and Production segment.}
_{⁽²⁾Amounts include transportation expense of $0.56 and $0.59 per Mcf for the three months ended June 30, 2025 and June 30, 2024, respectively. Amounts include transportation expense of $0.57 per Mcf for the nine months ended June 30, 2025 and June 30, 2024.}

NATIONAL FUEL GAS COMPANY
AND SUBSIDIARIES

Pipeline and Storage Throughput – (millions of cubic feet – MMcf)

	Three Months Ended			Nine Months Ended
	June 30,			June 30,
			Increase			Increase
	2025	2024	(Decrease)	2025	2024	(Decrease)
Firm Transportation – Affiliated	20,123	18,377	1,746	101,233	92,433	8,800
Firm Transportation – Non-Affiliated	158,910	150,133	8,777	515,411	498,435	16,976
Interruptible Transportation	149	118	31	665	1,508	(843	)
	179,182	168,628	10,554	617,309	592,376	24,933

Gathering Volume – (MMcf)
	Three Months Ended			Nine Months Ended
	June 30,			June 30,
			Increase			Increase
	2025	2024	(Decrease)	2025	2024	(Decrease)
Gathered Volume	133,271	118,445	14,826	384,003	367,832	16,171

Utility Throughput – (MMcf)
	Three Months Ended			Nine Months Ended
	June 30,			June 30,
			Increase			Increase
	2025	2024	(Decrease)	2025	2024	(Decrease)
Retail Sales:
Residential Sales	10,151	8,123	2,028	60,738	53,168	7,570
Commercial Sales	1,658	1,308	350	9,997	8,401	1,596
Industrial Sales	93	62	31	594	389	205
	11,902	9,493	2,409	71,329	61,958	9,371
Transportation	13,853	12,819	1,034	55,881	52,984	2,897
	25,755	22,312	3,443	127,210	114,942	12,268

NATIONAL FUEL GAS COMPANY
AND SUBSIDIARIES
NON-GAAP FINANCIAL MEASURES

In addition to financial measures calculated in accordance with generally accepted accounting principles (GAAP), this press release contains information regarding adjusted operating results, adjusted EBITDA and free cash flow, which are non-GAAP financial measures. The Company believes that these non-GAAP financial measures are useful to investors because they provide an alternative method for assessing the Company’s ongoing operating results or liquidity and for comparing the Company’s financial performance to other companies. The Company’s management uses these non-GAAP financial measures for the same purpose, and for planning and forecasting purposes. The presentation of non-GAAP financial measures is not meant to be a substitute for financial measures in accordance with GAAP.

Management defines adjusted operating results as reported GAAP earnings before items impacting comparability. The following table reconciles National Fuel’s reported GAAP earnings to adjusted operating results for the three and nine months ended June 30, 2025 and 2024:

	Three Months Ended						Nine Months Ended
	June 30,						June 30,
(in thousands except per share amounts)		2025			2024			2025			2024
Reported GAAP Earnings	$	149,818		$	(54,158	)	$	411,162		$	245,134
Items impacting comparability:
Impairment of assets (E&P)		—			200,696			141,802			200,696
Tax impact of impairment of assets		—			(55,686	)		(37,169	)		(55,686	)
Premiums paid on early redemption of debt (E&P / Midstream)		—			—			2,385			—
Tax impact of premiums paid on early redemption of debt		—			—			(642	)		—
Unrealized (gain) loss on derivative asset (E&P)		45			1,186			729			4,848
Tax impact of unrealized (gain) loss on derivative asset		(12	)		(325	)		(196	)		(1,330	)
Unrealized (gain) loss on other investments (Corporate / All Other)		(820	)		15			1,780			(1,803	)
Tax impact of unrealized (gain) loss on other investments		172			(3	)		(374	)		379
Adjusted Operating Results	$	149,203		$	91,725		$	519,477		$	392,238

Reported GAAP Earnings Per Share	$	1.64		$	(0.59	)	$	4.51		$	2.65
Items impacting comparability:
Impairment of assets, net of tax (E&P)		—			1.58			1.14			1.57
Premiums paid on early redemption of debt, net of tax (E&P / Midstream)		—			—			0.02			—
Unrealized (gain) loss on derivative asset, net of tax (E&P)		—			0.01			0.01			0.04
Unrealized (gain) loss on other investments, net of tax (Corporate / All Other)		(0.01	)		—			0.02			(0.02	)
Rounding		0.01			(0.01	)		(0.01	)		—
Adjusted Operating Results Per Share	$	1.64		$	0.99		$	5.69		$	4.24

Management defines adjusted EBITDA as reported GAAP earnings before the following items: interest expense, income taxes, depreciation, depletion and amortization, other income and deductions, impairments, and other items reflected in operating income that impact comparability. The following tables reconcile National Fuel’s reported GAAP earnings to adjusted EBITDA for the three and nine months ended June 30, 2025 and 2024:

	Three Months Ended						Nine Months Ended
	June 30,						June 30,
(in thousands)		2025			2024			2025			2024
Reported GAAP Earnings	$	149,818		$	(54,158	)	$	411,162		$	245,134
Depreciation, Depletion and Amortization		116,408			113,454			337,055			348,179
Other (Income) Deductions		(8,534	)		(3,188	)		(31,486	)		(12,989	)
Interest Expense		37,889			34,217			120,389			104,041
Income Taxes		51,079			(28,311	)		133,629			70,108
Impairment of Assets		—			200,696			141,802			200,696
Adjusted EBITDA	$	346,660		$	262,710		$	1,112,551		$	955,169

Adjusted EBITDA by Segment
Pipeline and Storage Adjusted EBITDA	$	67,019		$	68,221		$	208,140		$	197,394
Gathering Adjusted EBITDA		55,923			47,631			160,607			153,795
Total Midstream Businesses Adjusted EBITDA		122,942			115,852			368,747			351,189
Exploration and Production Adjusted EBITDA		202,488			128,535			573,482			460,572
Utility Adjusted EBITDA		25,743			21,047			181,680			152,741
Corporate and All Other Adjusted EBITDA		(4,513	)		(2,724	)		(11,358	)		(9,333	)
Total Adjusted EBITDA	$	346,660		$	262,710		$	1,112,551		$	955,169

NATIONAL FUEL GAS COMPANY AND SUBSIDIARIES NON-GAAP FINANCIAL MEASURES SEGMENT ADJUSTED EBITDA
	Three Months Ended						Nine Months Ended
	June 30,						June 30,
(in thousands)		2025			2024			2025			2024
Exploration and Production Segment
Reported GAAP Earnings	$	86,671		$	(112,028	)	$	137,722		$	2,521
Depreciation, Depletion and Amortization		68,848			68,778			196,773			214,191
Other (Income) Deductions		(81	)		388			(527	)		529
Interest Expense		13,925			14,670			46,164			45,046
Income Taxes		33,125			(43,969	)		51,548			(2,411	)
Impairment of Assets		—			200,696			141,802			200,696
Adjusted EBITDA	$	202,488		$	128,535		$	573,482		$	460,572

Pipeline and Storage Segment
Reported GAAP Earnings	$	28,857		$	30,690		$	93,019		$	85,482
Depreciation, Depletion and Amortization		18,601			18,453			55,733			56,157
Other (Income) Deductions		(2,063	)		(3,619	)		(7,802	)		(10,112	)
Interest Expense		11,209			11,855			34,637			35,698
Income Taxes		10,415			10,842			32,553			30,169
Adjusted EBITDA	$	67,019		$	68,221		$	208,140		$	197,394

Gathering Segment
Reported GAAP Earnings	$	29,996		$	24,979		$	83,483		$	82,510
Depreciation, Depletion and Amortization		10,848			9,732			32,197			28,800
Other (Income) Deductions		1			(122	)		(151	)		(285	)
Interest Expense		3,870			3,393			13,865			10,824
Income Taxes		11,208			9,649			31,213			31,946
Adjusted EBITDA	$	55,923		$	47,631		$	160,607		$	153,795

Utility Segment
Reported GAAP Earnings	$	4,997		$	2,559		$	101,040		$	73,848
Depreciation, Depletion and Amortization		17,945			16,373			51,908			48,678
Other (Income) Deductions		(5,956	)		(1,947	)		(25,367	)		(6,523	)
Interest Expense		10,958			8,417			32,601			25,402
Income Taxes		(2,201	)		(4,355	)		21,498			11,336
Adjusted EBITDA	$	25,743		$	21,047		$	181,680		$	152,741

Corporate and All Other
Reported GAAP Earnings	$	(703	)	$	(358	)	$	(4,102	)	$	773
Depreciation, Depletion and Amortization		166			118			444			353
Other (Income) Deductions		(435	)		2,112			2,361			3,402
Interest Expense		(2,073	)		(4,118	)		(6,878	)		(12,929	)
Income Taxes		(1,468	)		(478	)		(3,183	)		(932	)
Adjusted EBITDA	$	(4,513	)	$	(2,724	)	$	(11,358	)	$	(9,333	)

Management defines free cash flow as net cash provided by operating activities, less net cash used in investing activities, adjusted for acquisitions and divestitures. The Company is unable to provide a reconciliation of any projected free cash flow measure to its comparable GAAP financial measure without unreasonable efforts. This is due to an inability to calculate the comparable GAAP projected metrics, including operating income and total production costs, given the unknown effect, timing, and potential significance of certain income statement items.

The MIL Network –

July 31, 2025

MIL-OSI Economics: Microsoft Cloud and AI strength fuels fourth quarter results

Source: Microsoft

Headline: Microsoft Cloud and AI strength fuels fourth quarter results

REDMOND, Wash. — July 30, 2025 — Microsoft Corp. today announced the following results for the quarter ended June 30, 2025, as compared to the corresponding period of last fiscal year:

Revenue was $76.4 billion and increased 18% (up 17% in constant currency)
Operating income was $34.3 billion and increased 23% (up 22% in constant currency)
Net income was $27.2 billion and increased 24% (up 22% in constant currency)
Diluted earnings per share was $3.65 and increased 24% (up 22% in constant currency)

“Cloud and AI is the driving force of business transformation across every industry and sector,” said Satya Nadella, chairman and chief executive officer of Microsoft. “We’re innovating across the tech stack to help customers adapt and grow in this new era, and this year, Azure surpassed $75 billion in revenue, up 34 percent, driven by growth across all workloads.”

“We closed out the fiscal year with a strong quarter, highlighted by Microsoft Cloud revenue reaching $46.7 billion, up 27% (up 25% in constant currency) year-over-year,” said Amy Hood, executive vice president and chief financial officer of Microsoft.

Business Highlights

Revenue in Productivity and Business Processes was $33.1 billion and increased 16% (up 14% in constant currency), with the following business highlights:

Microsoft 365 Commercial products and cloud services revenue increased 16% (up 15% in constant currency) driven by Microsoft 365 Commercial cloud revenue growth of 18% (up 16% in constant currency)
Microsoft 365 Consumer products and cloud services revenue increased 21% driven by Microsoft 365 Consumer cloud revenue growth of 20%
LinkedIn revenue increased 9% (up 8% in constant currency)
Dynamics products and cloud services revenue increased 18% (up 17% in constant currency) driven by Dynamics 365 revenue growth of 23% (up 21% in constant currency)

Revenue in Intelligent Cloud was $29.9 billion and increased 26% (up 25% in constant currency), with the following business highlights:

Server products and cloud services revenue increased 27% driven by Azure and other cloud services revenue growth of 39%

Revenue in More Personal Computing was $13.5 billion and increased 9%, with the following business highlights:

Windows OEM and Devices revenue increased 3%
Xbox content and services revenue increased 13% (up 12% in constant currency)
Search and news advertising revenue excluding traffic acquisition costs increased 21% (up 20% in constant currency)

Microsoft returned $9.4 billion to shareholders in the form of dividends and share repurchases in the fourth quarter of fiscal year 2025.

Fiscal Year 2025 Results

Microsoft Corp. today announced the following results for the fiscal year ended June 30, 2025, as compared to the corresponding period of last fiscal year:

Revenue was $281.7 billion and increased 15%
Operating income was $128.5 billion and increased 17% (up 18% in constant currency)
Net income was $101.8 billion and increased 16% (up 15% in constant currency)
Diluted earnings per share was $13.64 and increased 16%

Business Outlook

Microsoft will provide forward-looking guidance in connection with this quarterly earnings announcement on its earnings conference call and webcast.

Quarterly Highlights, Product Releases, and Enhancements

Every quarter Microsoft delivers hundreds of products, either as new releases, services, or enhancements to current products and services. These releases are a result of significant research and development investments, made over multiple years, designed to help customers be more productive and secure and to deliver differentiated value across the cloud and the edge.

Here are the major product releases and other highlights for the quarter, organized by product categories, to help illustrate how we are accelerating innovation across our businesses while expanding our market opportunities.

Webcast Details

Satya Nadella, chairman and chief executive officer, Amy Hood, executive vice president and chief financial officer, Alice Jolla, chief accounting officer, Keith Dolliver, corporate secretary and deputy general counsel, and Jonathan Neilson, vice president of investor relations, will host a conference call and webcast at 2:30 p.m. Pacific time (5:30 p.m. Eastern time) today to discuss details of the company’s performance for the quarter and certain forward-looking information. The session may be accessed at http://www.microsoft.com/en-us/investor. The webcast will be available for replay through the close of business on July 30, 2026.

Constant Currency

Microsoft presents constant currency information to provide a framework for assessing how our underlying businesses performed excluding the effect of foreign currency rate fluctuations. To present this information, current and comparative prior period results for entities reporting in currencies other than United States dollars are converted into United States dollars using the average exchange rates from the comparative period rather than the actual exchange rates in effect during the respective periods. All growth comparisons relate to the corresponding period in the last fiscal year. Microsoft has provided this non-GAAP financial information to aid investors in better understanding our performance. The non-GAAP financial measures presented in this release should not be considered as a substitute for, or superior to, the measures of financial performance prepared in accordance with GAAP.

Financial Performance Constant Currency Reconciliation

	Three Months Ended June 30,
($ in millions, except per share amounts)	Revenue	Operating Income	Net Income	Diluted Earnings per Share
2024 As Reported (GAAP)	$64,727	$27,925	$22,036	$2.95
2025 As Reported (GAAP)	$76,441	$34,323	$27,233	$3.65
Percentage Change Y/Y (GAAP)	18%	23%	24%	24%
Constant Currency Impact	$619	$326	$356	$0.05
Percentage Change Y/Y Constant Currency	17%	22%	22%	22%

	Twelve Months Ended June 30,
($ in millions, except per share amounts)	Revenue	Operating Income	Net Income	Diluted Earnings per Share
2024 As Reported (GAAP)	$245,122	$109,433	$88,136	$11.80
2025 As Reported (GAAP)	$281,724	$128,528	$101,832	$13.64
Percentage Change Y/Y (GAAP)	15%	17%	16%	16%
Constant Currency Impact	$(485)	$(351)	$56	$0.01
Percentage Change Y/Y Constant Currency	15%	18%	15%	16%

Segment Revenue Constant Currency Reconciliation

	Three Months Ended June 30,
($ in millions)	Productivity and Business Processes	Intelligent Cloud	More Personal Computing
2024 As Reported (GAAP)	$28,627	$23,785	$12,315
2025 As Reported (GAAP)	$33,112	$29,878	$13,451
Percentage Change Y/Y (GAAP)	16%	26%	9%
Constant Currency Impact	$368	$184	$67
Percentage Change Y/Y Constant Currency	14%	25%	9%

We have recast certain prior period amounts to conform to the way we internally manage and monitor our business.

Selected Product and Service Revenue Constant Currency Reconciliation

	Three Months Ended June 30, 2025
	Percentage Change Y/Y (GAAP)	Constant Currency Impact	Percentage Change Y/Y Constant Currency
Microsoft Cloud	27%	(2)%	25%
Microsoft 365 Commercial products and cloud services	16%	(1)%	15%
Microsoft 365 Commercial cloud	18%	(2)%	16%
Microsoft 365 Consumer products and cloud services	21%	0%	21%
Microsoft 365 Consumer cloud	20%	0%	20%
LinkedIn	9%	(1)%	8%
Dynamics products and cloud services	18%	(1)%	17%
Dynamics 365	23%	(2)%	21%
Server products and cloud services	27%	0%	27%
Azure and other cloud services	39%	0%	39%
Windows OEM and Devices	3%	0%	3%
Xbox content and services	13%	(1)%	12%
Search and news advertising excluding traffic acquisition costs	21%	(1)%	20%

About Microsoft

Microsoft (Nasdaq “MSFT” @microsoft) creates platforms and tools powered by AI to deliver innovative solutions that meet the evolving needs of our customers. The technology company is committed to making AI available broadly and doing so responsibly, with a mission to empower every person and every organization on the planet to achieve more.

Forward-Looking Statements

Statements in this release that are “forward-looking statements” are based on current expectations and assumptions that are subject to risks and uncertainties. Actual results could differ materially because of factors such as:

intense competition in all of our markets that could adversely affect our results of operations;
focus on cloud-based and AI services presenting execution and competitive risks;
significant investments in products and services that may not achieve expected returns;
acquisitions, joint ventures, and strategic alliances that could have an adverse effect on our business;
cyberattacks and security vulnerabilities that could lead to reduced revenue, increased costs, liability claims, or harm to our reputation or competitive position;
disclosure and misuse of personal data that could cause liability and harm to our reputation;
the possibility that we may not be able to protect information in our products and services from use by others;
abuse of our advertising, professional, marketplace, or gaming platforms that may harm our reputation or user engagement;
products and services, how they are used by customers, and how third-party products and services interact with them, presenting security, privacy, and execution risks;
issues about the use of AI in our offerings that may result in reputational or competitive harm, or liability;
excessive outages, data losses, and disruptions of our online services if we fail to maintain an adequate operations infrastructure;
supply or quality problems;
potential consequences of new, existing, and evolving legal and regulatory requirements;
claims against us that could result in adverse outcomes in legal disputes;
uncertainties relating to our business with government customers;
additional tax liabilities;
an inability to protect and utilize our intellectual property may harm our business and operating results;
claims that Microsoft has infringed the intellectual property rights of others;
damage to our reputation or our brands that may harm our business and results of operations;
adverse economic or market conditions that could harm our business;
catastrophic events or geopolitical conditions, such as the COVID-19 pandemic, that could disrupt our business;
exposure to increased economic and operational uncertainties from operating a global business, including the effects of foreign currency exchange; and
the dependence of our business on our ability to attract and retain talented employees.

For more information about risks and uncertainties associated with Microsoft’s business, please refer to the “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and “Risk Factors” sections of Microsoft’s SEC filings, including, but not limited to, its annual report on Form 10-K and quarterly reports on Form 10-Q, copies of which may be obtained by contacting Microsoft’s Investor Relations department at (800) 285-7772 or at Microsoft’s Investor Relations website at http://www.microsoft.com/en-us/investor.

All information in this release is as of June 30, 2025. The company undertakes no duty to update any forward-looking statement to conform the statement to actual results or changes in the company’s expectations.

For more information, press only:

Microsoft Media Relations, WE Communications for Microsoft, (425) 638-7777, [email protected]

For more information, financial analysts and investors only:

Jonathan Neilson, Vice President, Investor Relations, (425) 706-4400

Note to editors: For more information, news and perspectives from Microsoft, please visit the Microsoft News Center at http://www.microsoft.com/news. Web links, telephone numbers, and titles were correct at time of publication, but may since have changed. Shareholder and financial information, as well as today’s 2:30 p.m. Pacific time conference call with investors and analysts, is available at http://www.microsoft.com/en-us/investor.

MIL OSI Economics –

July 31, 2025

MIL-OSI Banking: Microsoft Cloud and AI strength fuels fourth quarter results

Source: Microsoft

Headline: Microsoft Cloud and AI strength fuels fourth quarter results

Microsoft Cloud and AI Strength Fuels Fourth Quarter Results

REDMOND, Wash. — July 30, 2025 — Microsoft Corp. today announced the following results for the quarter ended June 30, 2025, as compared to the corresponding period of last fiscal year:

· Revenue was $76.4 billion and increased 18% (up 17% in constant currency)

· Operating income was $34.3 billion and increased 23% (up 22% in constant currency)

· Net income was $27.2 billion and increased 24% (up 22% in constant currency)

· Diluted earnings per share was $3.65 and increased 24% (up 22% in constant currency)

“Cloud and AI is the driving force of business transformation across every industry and sector,” said Satya Nadella, chairman and chief executive officer of Microsoft. “We’re innovating across the tech stack to help customers adapt and grow in this new era, and this year, Azure surpassed $75 billion in revenue, up 34 percent, driven by growth across all workloads.”

“We closed out the fiscal year with a strong quarter, highlighted by Microsoft Cloud revenue reaching $46.7 billion, up 27% (up 25% in constant currency) year-over-year,” said Amy Hood, executive vice president and chief financial officer of Microsoft.

Business Highlights

Revenue in Productivity and Business Processes was $33.1 billion and increased 16% (up 14% in constant currency), with the following business highlights:

· Microsoft 365 Commercial products and cloud services revenue increased 16% (up 15% in constant currency) driven by Microsoft 365 Commercial cloud revenue growth of 18% (up 16% in constant currency)

· Microsoft 365 Consumer products and cloud services revenue increased 21% driven by Microsoft 365 Consumer cloud revenue growth of 20%

· LinkedIn revenue increased 9% (up 8% in constant currency)

· Dynamics products and cloud services revenue increased 18% (up 17% in constant currency) driven by Dynamics 365 revenue growth of 23% (up 21% in constant currency)

Revenue in Intelligent Cloud was $29.9 billion and increased 26% (up 25% in constant currency), with the following business highlights:

· Server products and cloud services revenue increased 27% driven by Azure and other cloud services revenue growth of 39%

Revenue in More Personal Computing was $13.5 billion and increased 9%, with the following business highlights:

· Windows OEM and Devices revenue increased 3%

· Xbox content and services revenue increased 13% (up 12% in constant currency)

· Search and news advertising revenue excluding traffic acquisition costs increased 21% (up 20% in constant currency)

Microsoft returned $9.4 billion to shareholders in the form of dividends and share repurchases in the fourth quarter of fiscal year 2025.

Fiscal Year 2025 Results

Microsoft Corp. today announced the following results for the fiscal year ended June 30, 2025, as compared to the corresponding period of last fiscal year:

· Revenue was $281.7 billion and increased 15%

· Operating income was $128.5 billion and increased 17% (up 18% in constant currency)

· Net income was $101.8 billion and increased 16% (up 15% in constant currency)

· Diluted earnings per share was $13.64 and increased 16%

Business Outlook

Microsoft will provide forward-looking guidance in connection with this quarterly earnings announcement on its earnings conference call and webcast.

Quarterly Highlights, Product Releases, and Enhancements

Every quarter Microsoft delivers hundreds of products, either as new releases, services, or enhancements to current products and services. These releases are a result of significant research and development investments, made over multiple years, designed to help customers be more productive and secure and to deliver differentiated value across the cloud and the edge.

Here are the major product releases and other highlights for the quarter, organized by product categories, to help illustrate how we are accelerating innovation across our businesses while expanding our market opportunities.

Webcast Details

Satya Nadella, chairman and chief executive officer, Amy Hood, executive vice president and chief financial officer, Alice Jolla, chief accounting officer, Keith Dolliver, corporate secretary and deputy general counsel, and Jonathan Neilson, vice president of investor relations, will host a conference call and webcast at 2:30 p.m. Pacific time (5:30 p.m. Eastern time) today to discuss details of the company’s performance for the quarter and certain forward-looking information. The session may be accessed at http://www.microsoft.com/en-us/investor. The webcast will be available for replay through the close of business on July 30, 2026.

Constant Currency

Microsoft presents constant currency information to provide a framework for assessing how our underlying businesses performed excluding the effect of foreign currency rate fluctuations. To present this information, current and comparative prior period results for entities reporting in currencies other than United States dollars are converted into United States dollars using the average exchange rates from the comparative period rather than the actual exchange rates in effect during the respective periods. All growth comparisons relate to the corresponding period in the last fiscal year. Microsoft has provided this non-GAAP financial information to aid investors in better understanding our performance. The non-GAAP financial measures presented in this release should not be considered as a substitute for, or superior to, the measures of financial performance prepared in accordance with GAAP.

Financial Performance Constant Currency Reconciliation

($ in millions, except per share amounts)	Revenue	Operating Income	Net Income	Diluted Earnings per Share
	Three Months Ended June 30,
2024 As Reported (GAAP)	$64,727	$27,925	$22,036	$2.95
2025 As Reported (GAAP)	$76,441	$34,323	$27,233	$3.65
Percentage Change Y/Y (GAAP)	18%	23%	24%	24%
Constant Currency Impact	$619	$326	$356	$0.05
Percentage Change Y/Y Constant Currency	17%	22%	22%	22%

($ in millions, except per share amounts)	Revenue	Operating Income	Net Income	Diluted Earnings per Share
	Twelve Months Ended June 30,
2024 As Reported (GAAP)	$245,122	$109,433	$88,136	$11.80
2025 As Reported (GAAP)	$281,724	$128,528	$101,832	$13.64
Percentage Change Y/Y (GAAP)	15%	17%	16%	16%
Constant Currency Impact	$(485)	$(351)	$56	$0.01
Percentage Change Y/Y Constant Currency	15%	18%	15%	16%

Segment Revenue Constant Currency Reconciliation

	Three Months Ended June 30,
($ in millions)	Productivity and Business Processes	Intelligent Cloud	More Personal Computing
2024 As Reported (GAAP)	$28,627	$23,785	$12,315
2025 As Reported (GAAP)	$33,112	$29,878	$13,451
Percentage Change Y/Y (GAAP)	16%	26%	9%
Constant Currency Impact	$368	$184	$67
Percentage Change Y/Y Constant Currency	14%	25%	9%

We have recast certain prior period amounts to conform to the way we internally manage and monitor our business.

Selected Product and Service Revenue Constant Currency Reconciliation

	Three Months Ended June 30, 2025
	Percentage Change Y/Y (GAAP)	Constant Currency Impact	Percentage Change Y/Y Constant Currency
Microsoft Cloud	27%	(2)%	25%
Microsoft 365 Commercial products and cloud services	16%	(1)%	15%
Microsoft 365 Commercial cloud	18%	(2)%	16%
Microsoft 365 Consumer products and cloud services	21%	0%	21%
Microsoft 365 Consumer cloud	20%	0%	20%
LinkedIn	9%	(1)%	8%
Dynamics products and cloud services	18%	(1)%	17%
Dynamics 365	23%	(2)%	21%
Server products and cloud services	27%	0%	27%
Azure and other cloud services	39%	0%	39%
Windows OEM and Devices	3%	0%	3%
Xbox content and services	13%	(1)%	12%
Search and news advertising excluding traffic acquisition costs	21%	(1)%	20%

About Microsoft

Microsoft (Nasdaq “MSFT” @microsoft) creates platforms and tools powered by AI to deliver innovative solutions that meet the evolving needs of our customers. The technology company is committed to making AI available broadly and doing so responsibly, with a mission to empower every person and every organization on the planet to achieve more.

Forward-Looking Statements

Statements in this release that are “forward-looking statements” are based on current expectations and assumptions that are subject to risks and uncertainties. Actual results could differ materially because of factors such as:

· intense competition in all of our markets that could adversely affect our results of operations;

· focus on cloud-based and AI services presenting execution and competitive risks;

· significant investments in products and services that may not achieve expected returns;

· acquisitions, joint ventures, and strategic alliances that could have an adverse effect on our business;

· cyberattacks and security vulnerabilities that could lead to reduced revenue, increased costs, liability claims, or harm to our reputation or competitive position;

· disclosure and misuse of personal data that could cause liability and harm to our reputation;

· the possibility that we may not be able to protect information in our products and services from use by others;

· abuse of our advertising, professional, marketplace, or gaming platforms that may harm our reputation or user engagement;

· products and services, how they are used by customers, and how third-party products and services interact with them, presenting security, privacy, and execution risks;

· issues about the use of AI in our offerings that may result in reputational or competitive harm, or liability;

· excessive outages, data losses, and disruptions of our online services if we fail to maintain an adequate operations infrastructure;

· supply or quality problems;

· potential consequences of new, existing, and evolving legal and regulatory requirements;

· claims against us that could result in adverse outcomes in legal disputes;

· uncertainties relating to our business with government customers;

· additional tax liabilities;

· an inability to protect and utilize our intellectual property may harm our business and operating results;

· claims that Microsoft has infringed the intellectual property rights of others;

· damage to our reputation or our brands that may harm our business and results of operations;

· adverse economic or market conditions that could harm our business;

· catastrophic events or geopolitical conditions, such as the COVID-19 pandemic, that could disrupt our business;

· exposure to increased economic and operational uncertainties from operating a global business, including the effects of foreign currency exchange; and

· the dependence of our business on our ability to attract and retain talented employees.

For more information about risks and uncertainties associated with Microsoft’s business, please refer to the “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and “Risk Factors” sections of Microsoft’s SEC filings, including, but not limited to, its annual report on Form 10-K and quarterly reports on Form 10-Q, copies of which may be obtained by contacting Microsoft’s Investor Relations department at (800) 285-7772 or at Microsoft’s Investor Relations website at http://www.microsoft.com/en-us/investor.

All information in this release is as of June 30, 2025. The company undertakes no duty to update any forward-looking statement to conform the statement to actual results or changes in the company’s expectations.

For more information, press only:

Microsoft Media Relations, WE Communications for Microsoft, (425) 638-7777, rrt@we-worldwide.com

For more information, financial analysts and investors only:

Jonathan Neilson, Vice President, Investor Relations, (425) 706-4400

Note to editors: For more information, news and perspectives from Microsoft, please visit the Microsoft News Center at http://www.microsoft.com/news. Web links, telephone numbers, and titles were correct at time of publication, but may since have changed. Shareholder and financial information, as well as today’s 2:30 p.m. Pacific time conference call with investors and analysts, is available at http://www.microsoft.com/en-us/investor.

**MICROSOFT CORPORATION**

INCOME STATEMENTS

(In millions, except per share amounts) (Unaudited)
	Three Months Ended June 30,		Twelve Months Ended June 30,
	Three Months Ended June 30,		Twelve Months Ended June 30,
	2025	2024	2025	2024
Revenue:
Product	$17,136	$13,217	$63,946	$64,773
Service and other	59,305	51,510	217,778	180,349
Total revenue	76,441	64,727	281,724	245,122
Cost of revenue:
Product	3,314	1,438	13,501	15,272
Service and other	20,700	18,246	74,330	58,842
Total cost of revenue	24,014	19,684	87,831	74,114
Gross margin	52,427	45,043	193,893	171,008
Research and development	8,829	8,056	32,488	29,510
Sales and marketing	7,285	6,816	25,654	24,456
General and administrative	1,990	2,246	7,223	7,609
Operating income	34,323	27,925	128,528	109,433
Other expense, net	(1,707)	(675)	(4,901)	(1,646)
Income before income taxes	32,616	27,250	123,627	107,787
Provision for income taxes	5,383	5,214	21,795	19,651
Net income	$27,233	$22,036	$101,832	$88,136
Earnings per share:
Basic	$3.66	$2.96	$13.70	$11.86
Diluted	$3.65	$2.95	$13.64	$11.80
Weighted average shares outstanding:
Basic	7,432	7,433	7,433	7,431
Diluted	7,461	7,472	7,465	7,469

COMPREHENSIVE INCOME STATEMENTS

(In millions) (Unaudited)
	Three Months Ended June 30,		Twelve Months Ended June 30,
	Three Months Ended June 30,		Twelve Months Ended June 30,
	2025	2024	2025	2024
Net income	$27,233	$22,036	$101,832	$88,136
Other comprehensive income (loss), net of tax:
Net change related to derivatives	(9)	(4)	(5)	24
Net change related to investments	444	88	1,574	957
Translation adjustments and other	1,051	(239)	674	(228)
Other comprehensive income (loss)	1,486	(155)	2,243	753
Comprehensive income	$28,719	$21,881	$104,075	$88,889

BALANCE SHEETS

(In millions) (Unaudited)
	June 30, 2025	June 30, 2024
Assets
Current assets:
Cash and cash equivalents	$30,242	$18,315
Short-term investments	64,323	57,228
Total cash, cash equivalents, and short-term investments	94,565	75,543
Accounts receivable, net of allowance for doubtful accounts of $944 and $830	69,905	56,924
Inventories	938	1,246
Other current assets	25,723	26,021
Total current assets	191,131	159,734
Property and equipment, net of accumulated depreciation of $93,653 and $76,421	204,966	135,591
Operating lease right-of-use assets	24,823	18,961
Equity and other investments	15,405	14,600
Goodwill	119,509	119,220
Intangible assets, net	22,604	27,597
Other long-term assets	40,565	36,460
Total assets	$619,003	$512,163
Liabilities and stockholders’ equity
Current liabilities:
Accounts payable	$27,724	$21,996
Short-term debt	0	6,693
Current portion of long-term debt	2,999	2,249
Accrued compensation	13,709	12,564
Short-term income taxes	7,211	5,017
Short-term unearned revenue	64,555	57,582
Other current liabilities	25,020	19,185
Total current liabilities	141,218	125,286
Long-term debt	40,152	42,688
Long-term income taxes	25,986	27,931
Long-term unearned revenue	2,710	2,602
Deferred income taxes	2,835	2,618
Operating lease liabilities	17,437	15,497
Other long-term liabilities	45,186	27,064
Total liabilities	275,524	243,686
Commitments and contingencies
Stockholders’ equity:
Common stock and paid-in capital – shares authorized 24,000; outstanding 7,434 and 7,434	109,095	100,923
Retained earnings	237,731	173,144
Accumulated other comprehensive loss	(3,347)	(5,590)
Total stockholders’ equity	343,479	268,477
Total liabilities and stockholders’ equity	$619,003	$512,163

CASH FLOWS STATEMENTS

(In millions) (Unaudited)
	Three Months Ended June 30,		Twelve Months Ended June 30,
	Three Months Ended June 30,		Twelve Months Ended June 30,
	2025	2024	2025	2024
Operations
Net income	$27,233	$22,036	$101,832	$88,136
Adjustments to reconcile net income to net cash from operations:
Depreciation, amortization, and other	11,203	6,380	34,153	22,287
Stock-based compensation expense	3,073	2,696	11,974	10,734
Net recognized losses on investments and derivatives	56	44	609	305
Deferred income taxes	(2,221)	(1,145)	(7,056)	(4,738)
Changes in operating assets and liabilities:
Accounts receivable	(16,179)	(13,246)	(10,581)	(7,191)
Inventories	(81)	55	309	1,284
Other current assets	(3,686)	(2,528)	(3,044)	(1,648)
Other long-term assets	418	(1,240)	(2,950)	(6,817)
Accounts payable	(652)	4,204	569	3,545
Unearned revenue	18,361	15,657	5,438	5,348
Income taxes	1,043	(806)	(38)	1,687
Other current liabilities	5,346	4,652	5,922	4,867
Other long-term liabilities	(1,267)	436	(975)	749
Net cash from operations	42,647	37,195	136,162	118,548
Financing
Proceeds from issuance (repayments) of debt, maturities of 90 days or less, net	0	(1,142)	(5,746)	5,250
Proceeds from issuance of debt	0	197	0	24,395
Repayments of debt	0	(13,065)	(3,216)	(29,070)
Common stock issued	548	534	2,056	2,002
Common stock repurchased	(4,546)	(4,210)	(18,420)	(17,254)
Common stock cash dividends paid	(6,169)	(5,574)	(24,082)	(21,771)
Other, net	(677)	(303)	(2,291)	(1,309)
Net cash used in financing	(10,844)	(23,563)	(51,699)	(37,757)
Investing
Additions to property and equipment	(17,079)	(13,873)	(64,551)	(44,477)
Acquisition of companies, net of cash acquired and divestitures, and purchases of intangible and other assets	(1,743)	(1,342)	(5,978)	(69,132)
Purchases of investments	(21,631)	(2,831)	(29,775)	(17,732)
Maturities of investments	4,618	1,557	16,079	24,775
Sales of investments	2,621	2,023	9,309	10,894
Other, net	2,642	(382)	2,317	(1,298)
Net cash used in investing	(30,572)	(14,848)	(72,599)	(96,970)
Effect of foreign exchange rates on cash and cash equivalents	183	(103)	63	(210)
Net change in cash and cash equivalents	1,414	(1,319)	11,927	(16,389)
Cash and cash equivalents, beginning of period	28,828	19,634	18,315	34,704
Cash and cash equivalents, end of period	$30,242	$18,315	$30,242	$18,315

SEGMENT REVENUE AND OPERATING INCOME

(In millions) (Unaudited)
	Three Months Ended June 30,		Twelve Months Ended June 30,
	Three Months Ended June 30,		Twelve Months Ended June 30,
	2025	2024	2025	2024
Revenue
Productivity and Business Processes	$33,112	$28,627	$120,810	$106,820
Intelligent Cloud	29,878	23,785	106,265	87,464
More Personal Computing	13,451	12,315	54,649	50,838
Total	$76,441	$64,727	$281,724	$245,122
Operating Income
Productivity and Business Processes	$18,993	$15,706	$69,773	$59,661
Intelligent Cloud	12,140	9,835	44,589	37,813
More Personal Computing	3,190	2,384	14,166	11,959
Total	$34,323	$27,925	$128,528	$109,433

We have recast certain prior period amounts to conform to the way we internally manage and monitor our business.

MIL OSI Global Banks –

July 31, 2025

MIL-OSI: CVR Energy Reports Second Quarter 2025 Results, Announces Leadership Transition Plans

Source: GlobeNewswire (MIL-OSI)

Second quarter net loss attributable to CVR Energy stockholders of $114 million; EBITDA loss of $24 million; adjusted EBITDA of $99 million
Second quarter loss per diluted share of $1.14 and adjusted loss per diluted share of 23 cents
Prepaid $70 million and $20 million in principal of the Term Loan in June and July 2025, respectively
Mark Pytosh to assume role of President, Chief Executive Officer and Director on January 1, 2026, following Dave Lamp retirement; Brett Icahn appointed to the Board of Directors effective August 1, 2025
CVR Partners announced a cash distribution of $3.89 per common unit

SUGAR LAND, Texas, July 30, 2025 (GLOBE NEWSWIRE) — CVR Energy, Inc. (NYSE: CVI, “CVR Energy” or the “Company”) today announced second quarter 2025 net loss attributable to CVR Energy stockholders of $114 million, or $1.14 per diluted share, compared to second quarter 2024 net income attributable to CVR Energy stockholders of $21 million, or 21 cents per diluted share. Adjusted loss for the second quarter of 2025 was 23 cents per diluted share, compared to adjusted earnings per diluted share of 9 cents in the second quarter of 2024. Net loss for the second quarter of 2025 was $90 million, compared to net income of $38 million in the second quarter of 2024. Second quarter 2025 EBITDA loss was $24 million, compared to second quarter 2024 EBITDA of $103 million. Adjusted EBITDA for the second quarter of 2025 was $99 million, compared to adjusted EBITDA of $87 million in the second quarter of 2024.

“CVR Energy’s 2025 second quarter earnings results for its refining business were impacted by an $89 million unfavorable mark-to-market impact on its outstanding Renewable Fuel Standard obligation as well as reduced throughput volumes while we ran off intermediate inventory following the completion of the planned turnaround at the Coffeyville refinery,” said Dave Lamp, CVR Energy’s President and Chief Executive Officer.

“CVR Partners achieved solid operating results for the second quarter of 2025, with a combined ammonia production rate of 91 percent,” Mr. Lamp said. “CVR Partners also was pleased to declare a second quarter 2025 cash distribution of $3.89 per common unit.”

The Company also announced leadership transition plans following Mr. Lamp’s notice of his intent to retire as President and Chief Executive Officer effective December 31, 2025. Mark A. Pytosh, the Company’s Executive Vice President – Corporate Services who also serves as President, Chief Executive Officer and Director of the general partner of CVR Partners, LP (“CVR Partners”), is expected to assume the role of President, Chief Executive Officer and Director of CVR Energy while continuing to serve in those same roles for CVR Partners’ general partner. Mr. Lamp is expected to remain on the Company’s Board of Directors and the board of directors of CVR Partners’ general partner.

“I would like to thank our employees, communities and stockholders for their support over the past several years. It has been a privilege to have worked closely with our strong management team to drive value throughout the organization, and I look forward to continuing to serve our companies as a member of the Board,” said Mr. Lamp. “Mark has been a strong leader for CVR Partners and for our midstream operations. We have worked closely together for many years, and I am confident he is the right person to build upon the foundations we have laid while driving CVR Energy and CVR Partners into the future.”

Mr. Pytosh joined the general partner of CVR Partners as a Director in 2011 and became President and Chief Executive Officer in May 2014. In January 2018, Mr. Pytosh was appointed Executive Vice President – Corporate Services of the Company with executive responsibility over the Company’s midstream operations. Prior to joining CVR Partners, Mr. Pytosh held senior financial roles in energy, power, solid waste and investment banking. Mr. Pytosh is expected to remain President, Chief Executive Officer and Director of CVR Partners’ general partner.

Mr. Pytosh commented, “Dave’s leadership, operating discipline and strong corporate values have inspired the Company. I look forward to building upon Dave’s incredible legacy while leveraging our operating platform and strong management team to position the Company for positive growth and maximizing value for all of our stockholders.”

On July 28, 2025, the Board appointed Brett Icahn as a director effective August 1, 2025, increasing the Board size to nine members.

Petroleum Segment

The Petroleum Segment reported a second quarter 2025 net loss of $137 million and EBITDA loss of $84 million, compared to net income of $18 million and EBITDA of $56 million for the second quarter of 2024. Adjusted EBITDA for the Petroleum Segment was $38 million for the second quarter of 2025, compared to adjusted EBITDA of $37 million for the second quarter of 2024.

Combined total throughput for the second quarter of 2025 was approximately 172,000 barrels per day (“bpd”) compared to approximately 186,000 bpd of combined total throughput for the second quarter of 2024. Throughput during the current quarter was lower primarily to allow processing of intermediate inventories built during the turnaround at the Coffeyville, Kansas, refinery which began in the first quarter of 2025 and was completed in April 2025.

Refining margin for the second quarter of 2025 was $35 million, or $2.21 per total throughput barrel, compared to $185 million, or $10.94 per total throughput barrel, during the same period in 2024. Included in our second quarter 2025 refining margin were unfavorable mark-to-market impacts on our outstanding Renewable Fuel Standard (“RFS”) obligation of $89 million, unfavorable inventory valuation impacts of $31 million, and unfavorable unrealized derivative impacts of $2 million primarily related to Canadian crude oil positions. Excluding these items, adjusted refining margin for the second quarter of 2025 was $9.95 per barrel, compared to an adjusted refining margin per barrel of $9.81 for the second quarter of 2024. The increase in adjusted refining margin per barrel was primarily due to an increase in the Group 3 2-1-1 crack spread.

Renewables Segment

Effective beginning with the Company’s Annual Report on Form 10-K for the year ended December 31, 2024, and due to the prominence of the renewables business relative to the Company’s overall 2024 performance, we revised our reportable segments to reflect a new reportable segment: Renewables. The Renewables Segment includes the operations of the renewable diesel unit and renewable feedstock pretreater at the refinery in Wynnewood, Oklahoma.

The Renewables Segment reported second quarter 2025 net loss of $11 million and EBITDA loss of $5 million, compared to net loss of $11 million and EBITDA loss of $5 million for the second quarter of 2024. Adjusted EBITDA loss for the Renewables Segment was $4 million for the second quarter of 2025, compared to adjusted EBITDA loss of $2 million for the second quarter of 2024.

Total vegetable oil throughput for the second quarter of 2025 was approximately 155,000 gallons per day (“gpd”), compared to approximately 127,000 gpd for the second quarter of 2024.

Renewables margin was $5 million, or $0.38 per vegetable oil throughput gallon, for the second quarter of 2025 compared to $5 million, or 43 cents per vegetable oil throughput gallon, for the second quarter of 2024. Factors contributing to our second quarter 2025 renewables margin were higher net sales of $13 million resulting from increased production and sales volumes, increased renewable diesel yield due to improved catalyst performance, and increased biomass-based diesel RIN and LCFS credit prices in the current period, partially offset by the loss of the BTC in the current period and a decrease in average CARB ULSD prices of 24 cents per gallon. Higher net sales were partially offset by higher cost of sales of $12 million due to an increase in throughput and production volumes.

Nitrogen Fertilizer Segment

The Nitrogen Fertilizer Segment reported net income of $39 million and EBITDA of $67 million on net sales of $169 million for the second quarter of 2025, compared to net income of $26 million and EBITDA of $54 million on net sales of $133 million for the second quarter of 2024.

Production at CVR Partners, LP’s (“CVR Partners”) fertilizer facilities decreased compared to the second quarter of 2024, producing a combined 197,000 tons of ammonia during the second quarter of 2025, of which 54,000 net tons were available for sale while the rest was upgraded to other fertilizer products, including 321,000 tons of urea ammonia nitrate (“UAN”). During the second quarter of 2024, the fertilizer facilities produced a combined 221,000 tons of ammonia, of which 69,000 net tons were available for sale while the remainder was upgraded to other fertilizer products, including 337,000 tons of UAN.

For the second quarter 2025, average realized gate prices for ammonia and UAN were up 14 percent and 18 percent, respectively, over the prior year to $593 and $317 per ton, respectively. Average realized gate prices for ammonia and UAN were $520 and $268 per ton, respectively, for the second quarter of 2024.

Corporate and Other

The Company reported an income tax benefit of $42 million, or 31.7 percent of loss before income taxes, for the three months ended June 30, 2025, compared to an income tax benefit of $26 million, or (219.7) percent of income before income taxes, for the three months ended June 30, 2024. The increase in income tax benefit was primarily due to a decrease in overall pretax earnings while the change in the effective tax rate was primarily due to changes in pretax earnings attributable to noncontrolling interest and the impact of federal and state tax credits and incentives in relation to overall pretax earnings.

Cash, Debt and Dividend

Consolidated cash and cash equivalents were $596 million at June 30, 2025, a decrease of $391 million from December 31, 2024. Consolidated total debt and finance lease obligations were $1.9 billion at June 30, 2025, including $570 million held by the Nitrogen Fertilizer Segment.

On June 30, 2025, certain of the Company’s subsidiaries (the “Term Loan Borrowers”) prepaid $70 million in principal of the senior secured term loan facility (the “Term Loan”), in addition to required principal and interest payments as set forth in the Term Loan. As a result of this transaction, the Company recognized a $1 million loss on extinguishment of debt in the second quarter of 2025, related to the write-off of unamortized discount and deferred financing costs. Further, on July 25, 2025, the Term Loan Borrowers prepaid an additional $20 million in principal of the Term Loan, plus any accrued and unpaid interest to the redemption date.

CVR Energy will not pay a cash dividend for the second quarter of 2025.

Today, CVR Partners announced that the Board of Directors of its general partner declared a second quarter 2025 cash distribution of $3.89 per common unit, which will be paid on August 18, 2025, to common unitholders of record as of August 11, 2025.

Second Quarter 2025 Earnings Conference Call

CVR Energy previously announced that it will host its second quarter 2025 Earnings Conference Call on Thursday, July 31, at 1 p.m. Eastern. The Earnings Conference Call may also include discussion of Company developments, forward-looking information and other material information about business and financial matters.

The second quarter 2025 Earnings Conference Call will be webcast live and can be accessed on the Investor Relations section of CVR Energy’s website at www.CVREnergy.com. For investors or analysts who want to participate during the call, the dial-in number is (877) 407-8291. The webcast will be archived and available for 14 days at https://edge.media-server.com/mmc/p/939p6amw. A repeat of the call also can be accessed for 14 days by dialing (877) 660-6853, conference ID 13754877.

Forward-Looking Statements
This news 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. Statements concerning current estimates, expectations and projections about future results, performance, prospects, opportunities, plans, actions and events and other statements, concerns, or matters that are not historical facts are “forward-looking statements,” as that term is defined under the federal securities laws. These forward-looking statements include, but are not limited to, statements regarding future: continued safe and reliable operations; drivers of our results; EBITDA and Adjusted EBITDA; management changes; impacts of planned and unplanned downtime; timing of turnarounds and impacts thereof on our results; asset utilization, capture, production volume, throughput, product yield and crude oil gathering rates, including the factors impacting same; cash flow generation; operating income and net sales, including the factors impacting same; refining margin; crack spreads, including the drivers thereof; impact of costs to comply with the RFS and revaluation of our RFS liability; inventory levels and valuation impacts; derivative gains and losses and the drivers thereof; renewable feedstocks; production rates and operations capabilities of our renewable diesel unit, including the ability to return to hydrocarbon service; demand trends; RIN generation levels; benefits of our corporate transformation to segregate our renewables business; access to capital and new partnerships; RIN pricing, including its impact on performance and the Company’s ability to offset the impact thereof; LCFS credit and CARB ULSD pricing; carbon capture and decarbonization initiatives; demand for refined products; ammonia and UAN pricing; global fertilizer industry conditions; grain prices; crop inventory levels; crop and planting levels; production levels and utilization at our nitrogen fertilizer facilities; nitrogen fertilizer sales volumes; ability to and levels to which we upgrade ammonia to other fertilizer products, including UAN; income tax expense and benefits, including the drivers thereof; pretax earnings and our effective tax rate; the availability and impact of tax credits and incentives; use of proceeds under our debt instruments; debt levels; ability to paydown debt, make debt prepayments and terms associated therewith; cash and cash equivalent levels; dividends and distributions, including the timing, payment and amount (if any) thereof; direct operating expenses, capital expenditures, depreciation and amortization; turnaround expense; cash reserves; labor supply shortages, difficulties, disputes or strikes, including the impact thereof; and other matters. You can generally identify forward-looking statements by our use of forward-looking terminology such as “anticipate,” “believe,” “continue,” “could,” “estimate,” “expect,” “explore,” “evaluate,” “intend,” “may,” “might,” “plan,” “potential,” “predict,” “seek,” “should,” or “will,” or the negative thereof or other variations thereon or comparable terminology. These forward-looking statements are only predictions and involve known and unknown risks and uncertainties, many of which are beyond our control. Investors are cautioned that various factors may affect these forward-looking statements, including (among others) the health and economic effects of any pandemic, demand for fossil fuels and price volatility of crude oil, other feedstocks and refined products; the ability of Company to pay cash dividends and of CVR Partners to make cash distributions; potential operating hazards; costs of compliance with existing or new laws and regulations and potential liabilities arising therefrom; impacts of the planting season on CVR Partners; our controlling shareholder’s intention regarding ownership of our common stock or CVR Partners’ common units; general economic and business conditions; political disturbances, geopolitical instability and tensions; existing and future laws, rulings, policies and regulations, including the reinterpretation or amplification thereof by regulators, and including but not limited to those relating to the environment, climate change, and/or the production, transportation, or storage of hazardous chemicals, materials, or substances, like ammonia; political uncertainty and impacts to the oil and gas industry and the United States economy generally as a result of actions taken by a new administration, including the imposition of tariffs or changes in climate or other energy laws, rules, regulations, or policies; impacts of plant outages; potential operating hazards from accidents, fires, severe weather, tornadoes, floods, wildfires, or other natural disasters; and other risks. For additional discussion of risk factors which may affect our results, please see the risk factors and other disclosures included in our most recent Annual Report on Form 10-K, any subsequently filed Quarterly Reports on Form 10-Q and our other Securities and Exchange Commission (“SEC”) filings. These and other risks may cause our actual results, performance or achievements to differ materially from any future results, performance or achievements expressed or implied by these forward-looking statements. Given these risks and uncertainties, you are cautioned not to place undue reliance on such forward-looking statements. The forward-looking statements included in this news release are made only as of the date hereof. CVR Energy disclaims any intention or obligation to update publicly or revise any forward-looking statements, whether as a result of new information, future events or otherwise, except to the extent required by law. The terms of the employment agreement referenced herein are qualified in their entirety by the text of the agreement which will be duly disclosed in the Company’s upcoming filings with the Securities and Exchange Commission.

About CVR Energy, Inc.
Headquartered in Sugar Land, Texas, CVR Energy is a diversified holding company primarily engaged in the renewable fuels and petroleum refining and marketing business, as well as in the nitrogen fertilizer manufacturing business through its interest in CVR Partners. CVR Energy subsidiaries serve as the general partner and own approximately 37 percent of the common units of CVR Partners.

Investors and others should note that CVR Energy may announce material information using SEC filings, press releases, public conference calls, webcasts and the Investor Relations page of its website. CVR Energy may use these channels to distribute material information about the Company and to communicate important information about the Company, corporate initiatives and other matters. Information that CVR Energy posts on its website could be deemed material; therefore, CVR Energy encourages investors, the media, its customers, business partners and others interested in the Company to review the information posted on its website.

Contact Information:

Investor Relations

Richard Roberts
(281) 207-3205
InvestorRelations@CVREnergy.com

Media Relations

Brandee Stephens
(281) 207-3516
MediaRelations@CVREnergy.com

Non-GAAP Measures

Our management uses certain non-GAAP performance measures, and reconciliations to those measures, to evaluate current and past performance and prospects for the future to supplement our financial information presented in accordance with accounting principles generally accepted in the United States (“GAAP”). These non-GAAP financial measures are important factors in assessing our operating results and profitability and include the performance and liquidity measures defined below.

As a result of continuing volatile market conditions and the impacts certain non-cash items may have on the evaluation of our operations and results, the Company began disclosing the Adjusted Refining Margin non-GAAP measure, as defined below, in the second quarter of 2024. We believe the presentation of this non-GAAP measure is meaningful to compare our operating results between periods and better aligns with our peer companies. All prior periods presented have been conformed to the definition below.

The following are non-GAAP measures we present for the periods ended June 30, 2025 and 2024:

EBITDA – Consolidated net income (loss) before (i) interest expense, net, (ii) income tax expense (benefit) and (iii) depreciation and amortization expense.

Petroleum EBITDA, Renewables EBITDA, and Nitrogen Fertilizer EBITDA – Segment net income (loss) before segment (i) interest expense, net, (ii) income tax expense (benefit), and (iii) depreciation and amortization.

Refining Margin – The difference between our Petroleum Segment net sales and cost of materials and other.

Adjusted Refining Margin – Refining Margin adjusted for certain significant noncash items and items that management believes are not attributable to or indicative of our underlying operational results of the period or that may obscure results and trends we deem useful.

Refining Margin and Adjusted Refining Margin, per Throughput Barrel – Refining Margin and Adjusted Refining Margin divided by the total throughput barrels during the period, which is calculated as total throughput barrels per day times the number of days in the period.

Direct Operating Expenses per Throughput Barrel – Direct operating expenses for our Petroleum Segment divided by total throughput barrels for the period, which is calculated as total throughput barrels per day times the number of days in the period.

Renewables Margin – The difference between our Renewables Segment net sales and cost of materials and other.

Adjusted Renewables Margin – Renewables Margin adjusted for certain significant noncash items and items that management believes are not attributable to or indicative of our underlying operational results of the period or that may obscure results and trends we deem useful.

Renewables Margin and Adjusted Renewables Margin, per Vegetable Oil Throughput Gallon – Renewables Margin and Adjusted Renewables Margin divided by the total vegetable oil throughput gallons for the period, which is calculated as total vegetable oil throughput gallons per day times the number of days in the period.

Direct Operating Expenses per Vegetable Oil Throughput Gallon – Direct operating expenses for our Renewables Segment divided by total vegetable oil throughput gallons for the period, which is calculated as total vegetable oil throughput gallons per day times the number of days in the period.

Adjusted EBITDA, Petroleum Adjusted EBITDA, Renewables Adjusted EBITDA, and Nitrogen Fertilizer Adjusted EBITDA – EBITDA, Petroleum EBITDA, Renewables EBITDA, and Nitrogen Fertilizer EBITDA adjusted for certain significant non-cash items and items that management believes are not attributable to or indicative of our underlying operational results of the period or that may obscure results and trends we deem useful.

Adjusted Earnings (Loss) per Share – Earnings (loss) per share adjusted for certain significant non-cash items and items that management believes are not attributable to or indicative of our on-going operations or that may obscure our underlying results and trends.

Free Cash Flow – Net cash provided by (used in) operating activities less capital expenditures and capitalized turnaround expenditures.

We present these measures because we believe they may help investors, analysts, lenders and ratings agencies analyze our results of operations and liquidity in conjunction with our U.S. GAAP results, including but not limited to our operating performance as compared to other publicly traded companies in the refining and fertilizer industries, without regard to historical cost basis or financing methods and our ability to incur and service debt and fund capital expenditures. Non-GAAP measures have important limitations as analytical tools, because they exclude some, but not all, items that affect net earnings and operating income. These measures should not be considered substitutes for their most directly comparable U.S. GAAP financial measures. See “Non-GAAP Reconciliations” included herein for reconciliation of these amounts. Due to rounding, numbers presented within this section may not add or equal to numbers or totals presented elsewhere within this document.

Factors Affecting Comparability of Our Financial Results

Petroleum Segment

Our results of operations for the periods presented may not be comparable with prior periods or to our results of operations in the future due to capitalized expenditures as part of planned turnarounds. Total capitalized expenditures were $24 million and $3 million during the three months ended June 30, 2025 and 2024, respectively, and $190 million and $42 million during the six months ended June 30, 2025 and 2024, respectively.

CVR Energy, Inc.
(all information in this release is unaudited)

Consolidated Statement of Operations Data


	Three Months Ended June 30,						Six Months Ended June 30,
(in millions, except per share data)		2025			2024			2025			2024
Net sales	$	1,761		$	1,967		$	3,407		$	3,829
Operating costs and expenses:
Cost of materials and other		1,582			1,667			3,099			3,130
Direct operating expenses (exclusive of depreciation and amortization)		169			173			324			337
Depreciation and amortization		76			70			142			145
Cost of sales		1,827			1,910			3,565			3,612
Selling, general and administrative expenses (exclusive of depreciation and amortization)		36			28			73			63
Depreciation and amortization		2			2			4			4
(Gain) loss on asset disposal		(1	)		—			—			1
Operating (loss) income		(103	)		27			(235	)		149
Other (expense) income:
Interest expense, net		(30	)		(19	)		(55	)		(39	)
Other income, net		1			4			4			8
(Loss) income before income tax benefit		(132	)		12			(286	)		118
Income tax benefit		(42	)		(26	)		(91	)		(10	)
Net (loss) income		(90	)		38			(195	)		128
Less: Net income attributable to noncontrolling interest		24			17			42			25
Net (loss) income attributable to CVR Energy stockholders	$	(114	)	$	21		$	(237	)	$	103

Basic and diluted (loss) earnings per share	$	(1.14	)	$	0.21		$	(2.36	)	$	1.02
Dividends declared per share	$	—		$	0.50		$	—		$	1.00

Adjusted (loss) earnings per share *	$	(0.23	)	$	0.09		$	(0.81	)	$	0.12
EBITDA *	$	(24	)	$	103		$	(85	)	$	306
Adjusted EBITDA *	$	99		$	87		$	122		$	186

Weighted-average common shares outstanding – basic and diluted		100.5			100.5			100.5			100.5

See “Non-GAAP Reconciliations” section below.

Selected Consolidated Balance Sheet Data

(in millions)	June 30, 2025		December 31, 2024
Cash and cash equivalents	$	596	$	987
Working capital (inclusive of cash and cash equivalents)		201		726
Total assets		3,984		4,263
Total debt and finance lease obligations, including current portion		1,861		1,919
Total liabilities		3,318		3,375
Total CVR stockholders’ equity		466		703

Selected Consolidated Cash Flow Data

	Three Months Ended June 30,						Six Months Ended June 30,
(in millions)		2025			2024			2025			2024
Net cash used in:
Operating activities	$	176		$	81		$	(19	)	$	258
Investing activities		(185	)		(74	)		(267	)		(129	)
Financing activities		(90	)		(65	)		(105	)		(729	)
Net decrease in cash, cash equivalents, and restricted cash	$	(99	)	$	(58	)	$	(391	)	$	(600	)

Free cash flow *	$	(12	)	$	7		$	(297	)	$	128

* See “Non-GAAP Reconciliations” section below.

Selected Segment Data

	Three Months Ended June 30,
		2025											2024
(in millions)	Petroleum			Renewables			Nitrogen Fertilizer		Consolidated			Petroleum		Renewables			Nitrogen Fertilizer		Consolidated
Net sales	$	1,561		$	76		$	169	$	1,761		$	1,795	$	63		$	133	$	1,967
Operating (loss) income		(133	)		(11	)		46		(103	)		10		(11	)		34		27
Net (loss) income		(137	)		(11	)		39		(90	)		18		(11	)		26		38
EBITDA *		(84	)		(5	)		67		(24	)		56		(5	)		54		103

Capital expenditures ⁽¹⁾
Maintenance	$	14		$	1		$	6	$	21		$	22	$	—		$	4	$	27
Growth		9			1			4		15			11		2			1		14
Total capital expenditures	$	23		$	2		$	10	$	36		$	33	$	2		$	5	$	41

	Six Months Ended June 30,
		2025											2024
(in millions)	Petroleum			Renewables			Nitrogen Fertilizer		Consolidated			Petroleum		Renewables			Nitrogen Fertilizer		Consolidated
Net sales	$	3,038		$	142		$	311	$	3,407		$	3,517	$	97		$	261	$	3,829
Operating (Loss) Income		(295	)		(11	)		81		(235	)		128		(21	)		54		149
Net (loss) income		(297	)		(11	)		66		(195	)		145		(20	)		39		128
EBITDA *		(202	)		1			120		(85	)		227		(9	)		93		306

Capital expenditures ⁽¹⁾
Maintenance	$	55		$	1		$	10	$	66		$	44	$	1		$	9	$	57
Growth		17			1			6		26			25		9			1		35
Total capital expenditures	$	72		$	2		$	16	$	92		$	69	$	10		$	10	$	92

* See “Non-GAAP Reconciliations” section below.
(1) Capital expenditures are shown exclusive of capitalized turnaround expenditures.

Selected Balance Sheet Data

	June 30, 2025								December 31, 2024
(in millions)	Petroleum		Renewables		Nitrogen Fertilizer		Consolidated		Petroleum		Renewables		Nitrogen Fertilizer		Consolidated
Cash and cash equivalents ⁽¹⁾	$	325	$	22	$	114	$	596	$	735	$	13	$	91	$	987
Total assets		3,011		414		998		3,984		3,288		420		1,019		4,263
Total debt and finance lease obligations, including current portion ⁽²⁾		293		—		570		1,861		354		—		569		1,919

(1) Corporate cash and cash equivalents consisted of $135 million and $148 million at June 30, 2025 and December 31, 2024, respectively.
(2) Corporate total debt and finance lease obligations, including current portion consisted of $998 million and $996 million at June 30, 2025 and December 31, 2024, respectively.

Petroleum Segment

Key Operating Metrics per Total Throughput Barrel

	Three Months Ended June 30,				Six Months Ended June 30,
(in millions)		2025		2024		2025		2024
Refining margin *	$	2.21	$	10.94	$	1.14	$	13.68
Adjusted refining margin *		9.95		9.81		9.04		10.15
Direct operating expenses *		6.45		6.94		7.32		6.34

See “Non-GAAP Reconciliations” section below.

Refining Throughput and Production Data by Refinery

Throughput Data	Three Months Ended June 30,		Six Months Ended June 30,
(in bpd)	2025	2024	2025	2024
Coffeyville
Gathered crude	61,505	87,402	44,213	74,903
Other domestic	30,718	28,625	21,584	37,275
Canadian	581	9,518	610	9,525
Condensate	—	5,079	—	6,390
Other feedstocks and blendstocks	7,883	10,773	7,111	11,671
Wynnewood
Gathered crude	55,470	34,190	56,936	38,624
Other domestic	1,595	2,421	1,087	1,210
Condensate	8,965	5,965	9,556	8,114
Other feedstocks and blendstocks	5,432	2,235	5,309	3,287
Total throughput	172,149	186,208	146,406	190,999

Production Data	Three Months Ended June 30,				Six Months Ended June 30,
(in bpd)	2025		2024		2025		2024
Coffeyville
Gasoline	50,323		71,515		34,718		72,119
Distillate	46,911		57,710		33,645		56,858
Other liquid products	(428	)	7,015		2,930		5,784
Solids	3,711		4,990		2,523		4,985
Wynnewood
Gasoline	36,657		25,672		38,190		28,828
Distillate	23,645		16,053		24,293		17,610
Other liquid products	8,267		2,349		6,671		3,956
Solids	12		6		11		6
Total production	169,098		185,310		142,981		190,146

Crude utilization ⁽¹⁾	76.9	%	83.9	%	64.9	%	85.2	%
Light product yield (as % of crude throughput) ⁽²⁾	99.2	%	98.7	%	97.7	%	99.6	%
Liquid volume yield (as % of total throughput) ⁽³⁾	96.1	%	96.8	%	95.9	%	96.9	%
Distillate yield (as % of crude throughput) ⁽⁴⁾	44.4	%	42.6	%	43.2	%	42.3	%

(1) Total Gathered crude, Other domestic, Canadian, and Condensate throughput (collectively, “Total Crude Throughput”) divided by consolidated crude oil throughput capacity of 206,500 bpd.
(2) Total Gasoline and Distillate divided by Total Crude Throughput.
(3) Total Gasoline, Distillate, and Other liquid products divided by total throughput.
(4) Total Distillate divided by Total Crude Throughput.

Key Market Indicators

	Three Months Ended June 30,						Six Months Ended June 30,
(dollars per barrel)		2025			2024			2025			2024
West Texas Intermediate (WTI) NYMEX	$	63.74		$	80.63		$	67.52		$	78.81
Crude Oil Differentials to WTI:
Brent		2.97			4.40			3.29			4.60
WCS (heavy sour)		(9.43	)		(12.53	)		(10.92	)		(14.66	)
Condensate		(0.71	)		(0.66	)		(0.68	)		(0.76	)
Midland Cushing		0.74			1.08			0.92			1.31
NYMEX Crack Spreads:
Gasoline		24.76			27.48			20.86			25.07
Heating Oil		26.99			24.67			27.71			30.62
NYMEX 2-1-1 Crack Spread		25.87			26.07			24.29			27.85
PADD II Group 3 Product Basis:
Gasoline		(3.58	)		(10.61	)		(3.20	)		(10.33	)
Ultra-Low Sulfur Diesel		(0.12	)		(3.89	)		(3.60	)		(7.04	)
PADD II Group 3 Product Crack Spread:
Gasoline		21.18			16.87			17.66			14.74
Ultra-Low Sulfur Diesel		26.87			20.78			24.11			23.59
PADD II Group 3 2-1-1		24.02			18.83			20.89			19.17

Renewables Segment

Key Operating Metrics per Vegetable Oil Throughput Gallon

	Three Months Ended June 30,				Six Months Ended June 30,
		2025		2024		2025		2024
Renewables margin *	$	0.38	$	0.43	$	0.76	$	0.51
Adjusted renewables margin *		0.44		0.67		0.68		0.64
Direct operating expenses *		0.54		0.72		0.51		0.76

See “Non-GAAP Reconciliations” section below.

Renewables Throughput and Production Data

	Three Months Ended June 30,				Six Months Ended June 30,
(in gallons per day)	2025		2024		2025		2024
Throughput Data
Corn Oil	1,107		33,253		10,488		34,947
Soybean Oil	153,609		93,303		144,837		66,128

Production Data
Renewable diesel	148,373		117,277		146,292		89,936

Renewable utilization ⁽¹⁾	61.4	%	50.2	%	61.6	%	40.1	%
Renewable diesel yield (as % of corn and soybean oil throughput)	95.9	%	92.7	%	94.2	%	89.0	%

(1) Total corn and soybean oil throughput divided by total renewable throughput capacity of 252,000 gallons per day.

Key Market Indicators

	Three Months Ended June 30,				Six Months Ended June 30,
		2025		2024		2025		2024
Chicago Board of Trade (CBOT) soybean oil (dollars per pound)	$	0.49	$	0.45	$	0.47	$	0.46
Midwest crude corn oil (dollars per pound)		0.50		0.51		0.48		0.53
CARB ULSD (dollars per gallon)		2.36		2.60		2.38		2.63
NYMEX ULSD (dollars per gallon)		2.16		2.51		2.27		2.61
California LCFS (dollars per metric ton)		52.36		51.51		59.13		57.37
Biodiesel RINs (dollars per RIN)		1.08		0.51		0.94		0.55

Nitrogen Fertilizer Segment

	Three Months Ended June 30,				Six Months Ended June 30,
(percent of capacity utilization)	2025		2024		2025		2024
Ammonia utilization rate ⁽¹⁾	91	%	102	%	96	%	96	%

(1) Reflects our ammonia utilization rate on a consolidated basis. Utilization is an important measure used by management to assess operational output at each of CVR Partners’ facilities. Utilization is calculated as actual tons produced divided by capacity. We present our utilization for the three and six months ended June 30, 2025 and 2024 and take into account the impact of our current turnaround cycles on any specific period. Additionally, we present utilization solely on ammonia production rather than each nitrogen product as it provides a comparative baseline against industry peers and eliminates the disparity of plant configurations for upgrade of ammonia into other nitrogen products. With our efforts being primarily focused on ammonia upgrade capabilities, this measure provides a meaningful view of how well we operate.

Sales and Production Data

	Three Months Ended June 30,				Six Months Ended June 30,
		2025		2024		2025		2024
Consolidated sales volumes (thousands of tons):
Ammonia		57		43		117		113
UAN		345		330		681		614

Consolidated product pricing at gate (dollars per ton): ⁽¹⁾
Ammonia	$	593	$	520	$	573	$	525
UAN		317		268		287		268

Consolidated production volume (thousands of tons):
Ammonia (gross produced) ⁽²⁾		197		221		413		414
Ammonia (net available for sale) ⁽²⁾		54		69		117		130
UAN		321		337		668		643

Feedstock:
Petroleum coke used in production (thousands of tons)		130		133		261		261
Petroleum coke used in production (dollars per ton)	$	56.68	$	62.96	$	49.54	$	69.21
Natural gas used in production (thousands of MMBtus) ⁽³⁾		1,897		2,213		4,057		4,361
Natural gas used in production (dollars per MMBtu) ⁽³⁾	$	3.29	$	1.93	$	4.00	$	2.51
Natural gas in cost of materials and other (thousands of MMBtus) ⁽³⁾		2,201		1,855		3,807		3,620
Natural gas in cost of materials and other (dollars per MMBtu) ⁽³⁾	$	3.63	$	1.85	$	4.05	$	2.65

(1) Product pricing at gate represents sales less freight revenue divided by product sales volume in tons and is shown in order to provide a pricing measure that is comparable across the fertilizer industry.
(2) Gross tons produced for ammonia represent total ammonia produced, including ammonia produced that was upgraded into other fertilizer products. Net tons available for sale represent ammonia available for sale that was not upgraded into other fertilizer products.
(3) The feedstock natural gas shown above does not include natural gas used for fuel. The cost of fuel natural gas is included in direct operating expense.

Key Market Indicators

	Three Months Ended June 30,				Six Months Ended June 30,
		2025		2024		2025		2024
Ammonia — Southern plains (dollars per ton)	$	576	$	523	$	569	$	545
Ammonia — Corn belt (dollars per ton)		630		565		624		581
UAN — Corn belt (dollars per ton)		403		288		364		290

Natural gas NYMEX (dollars per MMBtu)	$	3.51	$	2.32	$	3.69	$	2.21

Q3 2025 Outlook

The table below summarizes our outlook for certain operational statistics and financial information for the third quarter of 2025. See “Forward-Looking Statements” above.

	Q3 2025
	Low			High
Petroleum
Total throughput (bpd)		200,000			215,000
Crude utilization ⁽¹⁾		92	%		97	%
Direct operating expenses (in millions) ⁽²⁾	$	105		$	115

Renewables
Total throughput (in millions of gallons)		16			20
Renewable utilization ⁽⁴⁾		70	%		85	%
Direct operating expenses (in millions) ⁽²⁾	$	8		$	10

Nitrogen Fertilizer
Ammonia utilization rate		93	%		98	%
Direct operating expenses (in millions) ⁽²⁾	$	60		$	65

Capital Expenditures (in millions) ⁽³⁾
Petroleum	$	25		$	30
Renewables		1			3
Nitrogen Fertilizer		20			25
Other		1			2
Total capital expenditures	$	47		$	60

(1) Represents crude oil throughput divided by consolidated crude oil throughput capacity of 206,500 bpd.
(2) Direct operating expenses are shown exclusive of depreciation and amortization, turnaround expenses, and inventory valuation impacts.
(3) Turnaround and capital expenditures are disclosed on an accrual basis.
(4) Represents renewable feedstock throughput divided by total renewable throughput capacity of 252,000 gallons per day.

Non-GAAP Reconciliations

Reconciliation of Net (Loss) Income to EBITDA and Adjusted EBITDA

	Three Months Ended June 30,						Six Months Ended June 30,
(in millions)		2025			2024			2025			2024
Net (loss) income	$	(90	)	$	38		$	(195	)	$	128
Interest expense, net		30			19			55			39
Income tax benefit		(42	)		(26	)		(91	)		(10	)
Depreciation and amortization		78			72			146			149
EBITDA		(24	)		103			(85	)		306
Adjustments:
Revaluation of RFS liability, unfavorable (favorable)		89			—			200			(91	)
Unrealized loss (gain) on derivatives, net		2			(17	)		(1	)		7
Inventory valuation impacts, unfavorable (favorable)		32			1			8			(36	)
Adjusted EBITDA	$	99		$	87		$	122		$	186

Reconciliation of Basic and Diluted (Loss) Earnings per Share to Adjusted (Loss) Earnings per Share

	Three Months Ended June 30,						Six Months Ended June 30,
		2025			2024			2025			2024
Basic and diluted (loss) earnings per share	$	(1.14	)	$	0.21		$	(2.36	)	$	1.02
Adjustments: ⁽¹⁾
Revaluation of RFS liability, unfavorable (favorable)		0.65			—			1.50			(0.68	)
Unrealized loss (gain) on derivatives, net		0.02			(0.13	)		(0.01	)		0.05
Inventory valuation impacts, unfavorable (favorable)		0.24			0.01			0.06			(0.27	)
Adjusted (loss) earnings per share	$	(0.23	)	$	0.09		$	(0.81	)	$	0.12

(1) Amounts are shown after-tax, using the Company’s marginal tax rate, and are presented on a per share basis using the weighted average shares outstanding for each period.

Reconciliation of Net Cash (Used In) Provided By Operating Activities to Free Cash Flow

	Three Months Ended June 30,						Six Months Ended June 30,
(in millions)		2025			2024			2025			2024
Net cash (used in) provided by operating activities	$	176		$	81		$	(19	)	$	258
Less:
Capital expenditures		(41	)		(43	)		(92	)		(90	)
Capitalized turnaround expenditures		(148	)		(32	)		(191	)		(44	)
Return of equity method investment		1			1			5			4
Free cash flow	$	(12	)	$	7		$	(297	)	$	128

Reconciliation of Petroleum Segment Net (Loss) Income to EBITDA and Adjusted EBITDA

	Three Months Ended June 30,						Six Months Ended June 30,
(in millions)		2025			2024			2025			2024
Petroleum net (loss) income	$	(137	)	$	18		$	(297	)	$	145
Interest (income) expense, net		5			(5	)		5			(10	)
Depreciation and amortization		48			43			90			92
Petroleum EBITDA		(84	)		56			(202	)		227
Adjustments:
Revaluation of RFS liability, unfavorable (favorable)		89			—			200			(91	)
Unrealized loss (gain) on derivatives, net		2			(17	)		(1	)		7
Inventory valuation impacts, unfavorable (favorable) ⁽¹⁾		31			(2	)		10			(39	)
Petroleum Adjusted EBITDA	$	38		$	37		$	7		$	104

Reconciliation of Petroleum Segment Gross (Loss) Profit to Refining Margin and Adjusted Refining Margin

	Three Months Ended June 30,						Six Months Ended June 30,
(in millions)		2025			2024			2025			2024
Net sales	$	1,561		$	1,795		$	3,038		$	3,517
Less:
Cost of materials and other		(1,526	)		(1,610	)		(3,008	)		(3,041	)
Direct operating expenses (exclusive of depreciation and amortization)		(102	)		(118	)		(193	)		(221	)
Depreciation and amortization		(48	)		(43	)		(90	)		(92	)
Gross (loss) profit		(115	)		24			(253	)		163
Add:
Direct operating expenses (exclusive of depreciation and amortization)		102			118			193			221
Depreciation and amortization		48			43			90			92
Refining margin		35			185			30			476
Adjustments:
Revaluation of RFS liability, unfavorable (favorable)		89			—			200			(91	)
Unrealized loss (gain) on derivatives, net		2			(17	)		(1	)		7
Inventory valuation impacts, unfavorable (favorable) ⁽¹⁾		31			(2	)		10			(39	)
Adjusted refining margin	$	157		$	166		$	239		$	353

Total throughput barrels per day		172,149			186,208			146,406			190,999
Days in the period		91			91			181			182
Total throughput barrels		15,665,597			16,944,862			26,499,565			34,761,961

Refining margin per total throughput barrel	$	2.21		$	10.94		$	1.14		$	13.68
Adjusted refining margin per total throughput barrel		9.95			9.81			9.04			10.15
Direct operating expenses per total throughput barrel		6.45			6.94			7.32			6.34

(1) The Petroleum Segment’s basis for determining inventory value under GAAP is First-In, First-Out (“FIFO”). Changes in crude oil prices can cause fluctuations in the inventory valuation of crude oil, work in process and finished goods, thereby resulting in a favorable inventory valuation impact when crude oil prices increase and an unfavorable inventory valuation impact when crude oil prices decrease. The inventory valuation impact is calculated based upon inventory values at the beginning of the accounting period and at the end of the accounting period.

Reconciliation of Renewables Segment Net Loss to EBITDA and Adjusted EBITDA

	Three Months Ended June 30,						Six Months Ended June 30,
(in millions)		2025			2024			2025			2024
Renewables net loss	$	(11	)	$	(11	)	$	(11	)	$	(20	)
Interest income, net		—			—			—			(1	)
Depreciation and amortization		6			6			12			12
Renewables EBITDA		(5	)		(5	)		1			(9	)
Adjustments:
Inventory valuation impacts, (favorable) unfavorable ⁽¹⁾		1			3			(2	)		2
Renewables Adjusted EBITDA	$	(4	)	$	(2	)	$	(1	)	$	(7	)

Reconciliation of Renewables Segment Gross Loss to Renewables Margin and Adjusted Renewables Margin

	Three Months Ended June 30,						Six Months Ended June 30,
(in millions, except throughput data)		2025			2024			2025			2024
Net sales	$	76		$	63		$	142		$	97
Less:
Cost of materials and other		(71	)		(58	)		(121	)		(88	)
Direct operating expenses (exclusive of depreciation and amortization)		(7	)		(8	)		(14	)		(13	)
Depreciation and amortization		(6	)		(6	)		(12	)		(12	)
Gross loss		(8	)		(9	)		(5	)		(16	)
Add:
Direct operating expenses (exclusive of depreciation and amortization)		7			8			14			13
Depreciation and amortization		6			6			12			12
Renewables margin		5			5			21			9
Inventory valuation impacts, (favorable) unfavorable ⁽¹⁾		1			3			(2	)		2
Adjusted renewables margin	$	6		$	8		$	19		$	11

Total vegetable oil throughput gallons per day		154,716			126,556			155,325			101,075
Days in the period		91			91			181			182
Total vegetable oil throughput gallons		14,079,118			11,516,572			28,113,944			18,395,649

Renewables margin per vegetable oil throughput gallon	$	0.38		$	0.43		$	0.76		$	0.51
Adjusted renewables margin per vegetable oil throughput gallon		0.44			0.67			0.68			0.64
Direct operating expenses per vegetable oil throughput gallon		0.54			0.72			0.51			0.76

(1) The Renewables Segment’s basis for determining inventory value under GAAP is FIFO. Changes in renewable diesel and renewable feedstock prices can cause fluctuations in the inventory valuation of renewable diesel, work in process and finished goods, thereby resulting in a favorable inventory valuation impact when renewable diesel prices increase and an unfavorable inventory valuation impact when renewable diesel prices decrease. The inventory valuation impact is calculated based upon inventory values at the beginning of the accounting period and at the end of the accounting period.

Reconciliation of Nitrogen Fertilizer Segment Net Income to EBITDA and Adjusted EBITDA

	Three Months Ended June 30,				Six Months Ended June 30,
(in millions)		2025		2024		2025		2024
Nitrogen Fertilizer net income	$	39	$	26	$	66	$	39
Interest expense, net		7		8		15		15
Depreciation and amortization		21		20		39		39
Nitrogen Fertilizer EBITDA and Adjusted EBITDA	$	67	$	54	$	120	$	93

The MIL Network –

July 31, 2025

MIL-OSI: JD.com Announces Decision to Make a Voluntary Public Takeover Offer and Strategic Investment Partnership with CECONOMY

Source: GlobeNewswire (MIL-OSI)

BEIJING, July 30, 2025 (GLOBE NEWSWIRE) — JD.com, Inc. (“JD.com” or the “Company”) (NASDAQ: JD and HKEX: 9618 (HKD counter) and 89618 (RMB counter)), a leading supply chain-based technology and service provider, today announced that it decided to make a voluntary public takeover offer, through a wholly-owned indirect subsidiary JINGDONG Holding Germany GmbH (the “Bidder”), to all shareholders of CECONOMY AG (“CECONOMY”) (XETRA: CEC), the parent company of leading European consumer electronics retailers MediaMarkt and Saturn, to acquire all issued and outstanding bearer shares in CECONOMY (the “CECONOMY Shares”) for a cash consideration of EUR 4.60 per share (the “Takeover Offer”).

The Bidder and CECONOMY have also signed an investment agreement regarding the Takeover Offer and their intended cooperation after completion of the Takeover Offer. Furthermore, regarding their future cooperation, the Bidder and CECONOMY’s largest shareholder group comprising Convergenta Invest GmbH and related shareholders (together, “Convergenta”) entered into a shareholders’ agreement, effectiveness of which is subject to the completion of the Takeover Offer. As a result, post the completion of the Takeover Offer, Convergenta will hold 25.35% of the CECONOMY Shares, reducing its current shareholding in CECONOMY from 29.16% by an irrevocable undertaking to accept the Takeover Offer with respect to 3.81% of the CECONOMY Shares. The Bidder has also entered into agreements with several shareholders of CECONOMY, under which those shareholders have irrevocably undertaken to accept the Takeover Offer with respect to 31.7% of the CECONOMY Shares in total (including 3.81% from Convergenta), securing a total shareholding of 57.1% in combination with the retained stake of JD.com’s future partner Convergenta ahead of the launch of the Takeover Offer.

CECONOMY is a European retail leader in the field of consumer electronics. Its main brands MediaMarkt and Saturn operate omni-channel retail businesses, combining strong e-commerce presence with more than 1,000 retail stores in 11 countries. Under the strategic investment agreement, the Company and CECONOMY aim to drive CECONOMY’s growth as a stand-alone business and accelerate CECONOMY’s transformation into Europe’s leading omni-channel consumer electronics platform. JD.com, renowned for its superior customer experience and industry-leading e-commerce logistics service standards, will contribute its advanced technology, leading omni-channel retail expertise, and logistics and warehouse capabilities to the partnership. This will strengthen CECONOMY’s capabilities and further develop its core business and capitalize on its market position. As part of the strategic roadmap, CECONOMY will remain a stand-alone business in Europe with a local independent technology stack, and no changes are planned to the workforce, employee agreements and sites. CECONOMY’s Supervisory Board and Management Board fully support the public Takeover Offer.

“This partnership with CECONOMY will build Europe’s leading next-generation consumer electronics platform,” said JD.com CEO Sandy Xu. “CECONOMY’s market-leading position, strong customer relationships and growth are impressive, and we are firmly committed to investing in its people and distinct culture to build on this success. We will work with the team to strengthen the capabilities, while applying our advanced technology capabilities to accelerate CECONOMY’s ongoing transformation. Our goal is to further grow CECONOMY’s platform across Europe and create long-term value for customers, employees, investors and local communities. We have full confidence in the management team of CECONOMY and look forward to working together to initiate the next phase of growth.”

CECONOMY CEO Dr. Kai-Ulrich Deissner said, “With JD.com’s outstanding retail, logistics, and technology capabilities, we can further accelerate our successful growth trajectory and go beyond our current strategic goals. Thanks to the tremendous dedication and commitment of our entire team, CECONOMY operates from a position of strength. Given the constantly evolving customer expectations and market dynamics, standing still is not an option. In the coming years, we don’t just want to keep pace with the transformation in European retail – we want to continue leading it. JD.com is the right partner for this. We share a passion for our customers and a firm belief that our employees, trusted partnerships with international brand manufacturers, and the combination of digital and brick-and-mortar business are the keys to success. We partner with JD.com to strengthen European retail, based on complementary strengths and shared values.”

“We fully support the strategic investment agreement and takeover offer and are confident that it represents the best opportunity to further drive the successful transformation of CECONOMY,” said Jürgen Kellerhals of anchor shareholder Convergenta. “The management team of CECONOMY has a clear strategic vision, and JD.com brings the resources and expertise required to accelerate the company’s (CECONOMY’s) next phase of growth. The technological expertise of JD.com is world-leading, as demonstrated by its success in other markets. As the long-term anchor investor, we believe this is the right step at the right time for the business, our employees, and our customers.”

The Takeover Offer will be subject to customary conditions, including, among others, merger control, foreign direct investment and foreign subsidies clearances. The Takeover Offer will not be subject to a minimum acceptance rate. The transaction will be financed through a combination of acquisition loan and the Company’s cash on balance sheet. The closing of the Takeover Offer is expected to take place in the first half of 2026.

The Offer Document (in German and a non-binding English translation) which will set forth the detailed terms and conditions of the Takeover Offer, as well as further information relating thereto, will be published by the Bidder following approval by the German Federal Financial Supervisory Authority (Bundesanstalt für Finanzdienstleistungsaufsicht) on the internet at the website www.green-offer.com.

This announcement and the information within it are not intended to, and do not, constitute or form part of any offer to purchase or a solicitation of an offer to sell the CECONOMY Shares. Investors and holders of CECONOMY Shares are strongly advised to read the Offer Document and all other documents relating to the Takeover Offer as soon as they have been made public, as they will contain important information.

About JD.com, Inc.

JD.com is a leading supply chain-based technology and service provider. The Company’s cutting-edge retail infrastructure seeks to enable consumers to buy whatever they want, whenever and wherever they want it. The Company has opened its technology and infrastructure to partners, brands and other sectors, as part of its Retail as a Service offering to help drive productivity and innovation across a range of industries.

Safe Harbor Statement

This announcement contains forward-looking statements. These statements are made under the “safe harbor” provisions of the U.S. Private Securities Litigation Reform Act of 1995. These forward-looking statements can be identified by terminology such as “will,” “expects,” “anticipates,” “future,” “intends,” “plans,” “believes,” “estimates,” “confident” and similar statements. JD.com may also make written or oral forward-looking statements in its periodic reports to the U.S. Securities and Exchange Commission (the “SEC”), in announcements made on the website of the Hong Kong Stock Exchange, in its annual report to shareholders, in press releases and other written materials and in oral statements made by its officers, directors or employees to third parties. Statements that are not historical facts, including statements about JD.com’s beliefs and expectations, are forward-looking statements. Forward-looking statements involve inherent risks and uncertainties. A number of factors could cause actual results to differ materially from those contained in any forward-looking statement, including but not limited to the following: JD.com’s growth strategies; its future business development, results of operations and financial condition; its ability to attract and retain new customers and to increase revenues generated from repeat customers; its expectations regarding demand for and market acceptance of its products and services; trends and competition in China’s e-commerce market; changes in its revenues and certain cost or expense items; the expected growth of the Chinese e-commerce market; laws, regulations and governmental policies relating to the industries in which JD.com or its business partners operate; potential changes in laws, regulations and governmental policies or changes in the interpretation and implementation of laws, regulations and governmental policies that could adversely affect the industries in which JD.com or its business partners operate, including, among others, initiatives to enhance supervision of companies listed on an overseas exchange and tighten scrutiny over data privacy and data security; risks associated with JD.com’s acquisitions, investments and alliances, including fluctuation in the market value of JD.com’s investment portfolio; natural disasters and geopolitical events; change in tax rates and financial risks; intensity of competition; and general market and economic conditions in China and globally. Further information regarding these and other risks is included in JD.com’s filings with the SEC and the announcements on the website of the Hong Kong Stock Exchange. All information provided herein is as of the date of this announcement, and JD.com undertakes no obligation to update any forward-looking statement, except as required under applicable law.

For investor and media inquiries, please contact:

Investor Relations
Sean Zhang
+86 (10) 8912-6804
IR@JD.com

Media Relations
+86 (10) 8911-6155
Press@JD.com

The MIL Network –

July 31, 2025

MIL-Evening Report: How migrant business owners turn their identity into an asset, despite some bumps along the way

Source: The Conversation (Au and NZ) – By Shea X. Fan, Associate Professor, Human Resource Management, Deakin University

Odua Images/Shutterstock

Too often, it’s anti-immigration sentiment dominating headlines in Australia. But a quieter story is going untold. Migrants are not just fitting into Australian society, they’re actively reshaping it through entrepreneurship.

Starting a business is difficult for anyone. But migrant entrepreneurs often do so without the networks, credit history, or local knowledge many Australian-born business owners take for granted.

Our new research drew on interviews with 38 migrant business owners from 25 different countries, who had all lived in Australia for at least five years.

We found many are able to turn everyday exclusion into entrepreneurial fuel.
Many have been able to survive – even thrive – by turning their identity into an asset.

Yet there is still more we can do to take migrant entrepreneurship seriously and make it a core part of our economic and social planning.

Key challenges

Our research reveals migrant business owners face many forms of marginalisation. Some of these are well-understood among the public, others less so.

One of the biggest is social. Arriving in a new country without established relationships in the community or financial sector, many struggle to gain customer trust or secure loans. It can also mean having less of a safety net.

As one interviewee put it:

I don’t have networks built up over the generations to sustain me and give me time to jump back out [of financial difficulties] […] For migrant entrepreneurs, we often do not have such a structure to absorb risks.

Cultural stereotypes also hinder migrant entrepreneurs, and negative media portrayals can reinforce these biases. Even with local qualifications, they are often perceived as less professional or competent due to race, religion, accent or appearance.

Many interviewees spoke of constantly having to prove their legitimacy – being overlooked, second-guessed or treated as representatives of their ethnic group rather than as individual business people.

Establishing social networks in a new country can be difficult.
Peterfz30/Shutterstock

Structural barriers

While the lack of networks and cultural acceptance undermines confidence and connection, structural barriers directly constrain access to the resources needed to survive and expand.

Without a local credit history or collateral, many are ineligible for loans, yet need those very funds to build their credit standing. Even long-settled migrants found Australia’s legal, bureaucratic and financial systems difficult to navigate.

Language barriers and unfamiliar regulations can add layers of complexity to this problem. While government support programs exist, they are often inaccessible, or the availability of those programs are poorly communicated to culturally diverse communities.

These social and systemic disadvantages can push migrant business owners into informal markets or ethnic enclaves, where opportunities are fewer and risks higher.

Turning identity into an asset

Despite these barriers, migrant entrepreneurs often find ways to survive. One key strategy is to turn marginalised identities into business strengths.

Our research found some migrants begin by serving customers from their own ethnic communities, leveraging shared language, culture and trust. Once established, they expand to other migrant groups or the broader public.

In sectors such as food, fashion and wellness, cultural authenticity can be a competitive advantage.

One hairdresser from Korea, for example, drew clients by offering Korean styling techniques popularised by the global rise of the Korean popular music style K-pop. She said this gave her work appeal among other migrant groups:

Korean hairdressers are actually attractive to other Asian countries because Korean hairstyles are considered fashionable and detailed. It’s getting popular here too. This is like free marketing for me.

One interviewee said her connection to Korea had turned into a business asset.
kikujungboy CC/Shutterstock

And rather than simply competing on price, many migrant businesses offer something different: handmade, ethical, sustainable or culturally-rooted products. An Indian small business owner started her business by selling curry pastes made from her own family recipes, telling us:

I use my family’s traditional Indian recipes to create small spice packs, making it easy for Australians, mostly non-Indian customers, to cook authentic dishes at home.

Such ventures create not only economic value, but also spaces of cultural exchange and community belonging.

There’s more we can do

The most recent figures show migrant entrepreneurs make up one in three small business owners in Australia. Research conducted in 2017 found the vast majority of migrant entrepreneurs had not owned a business before migration.

With fewer systemic barriers and better support, their potential to contribute would be even greater. There are a range of actions policymakers, local councils, support organisations and local businesses could take.

First, access could be expanded to small business grants by removing overly complex eligibility and documentation barriers.

We should also support migrants to navigate collectively “gatekeeping” practices that lock them out of lending, investment and business certification.

That could include developing alternative credit assessment tools for migrants without a local credit history. There are already some microloan schemes tailored to new migrants or visa holders, including Thrive Refugee Enterprise.

At the same time, we need to ensure such schemes are being effectively communicated to the communities they’re intended to serve.

And we need media narratives and public campaigns that highlight successful migrant businesses. Crucially, both policy and practice must be informed by the voices and experiences of migrant entrepreneurs themselves, not just as case studies, but as co-designers of better systems.

The authors do not work for, consult, own shares in or receive funding from any company or organisation that would benefit from this article, and have disclosed no relevant affiliations beyond their academic appointment.

– ref. How migrant business owners turn their identity into an asset, despite some bumps along the way – https://theconversation.com/how-migrant-business-owners-turn-their-identity-into-an-asset-despite-some-bumps-along-the-way-261948

MIL OSI Analysis – EveningReport.nz –

July 31, 2025

MIL-OSI Banking: Oil and Natural Gas Trades Support Bipartisan SPEED Act for Permitting Reform

Source: Independent Petroleum Association of America

Headline: Oil and Natural Gas Trades Support Bipartisan SPEED Act for Permitting Reform

Jul 30, 2025 Oil and Natural Gas Trades Support Bipartisan SPEED Act for Permitting Reform

WASHINGTON — A group of eight oil and natural gas trade associations today highlighted their strong support for the bipartisan “Standardized Permitting and Expediting Development Act” (SPEED Act). In a letter, the group wrote that the bill introduced by House Natural Resources Committee Chairman Bruce Westerman (R-Ark.) and Rep. Jared Golden (D-Maine) “makes many significant changes that would positively impact our members’ ability to produce energy in America.”

The coalition is comprised of the Independent Petroleum Association of America, Energy Workforce & Technology Council, Gulf Energy Alliance, International Association of Drilling Contractors, National Ocean Industries Association, Texas Alliance of Energy Producers, U.S. Oil & Gas Association, and Western Energy Alliance. Combined, these groups represent over 80 percent of domestic oil and natural gas production in the United States.

The group’s letter details how the scope of the National Environmental Policy Act (NEPA) requirements and applications have grown since its enactment 50 years ago and the courts, Presidential directives, and agencies’ implementation of NEPA regulations have made NEPA unworkable and far more complicated than its original intent. The federal government’s “paper chase” hinders efforts to find innovative solutions to protect the environment, unlock investment and create jobs. The SPEED Act addresses many of the most pressing issues surrounding NEPA delays and will provide durable solutions to help expedite much needed infrastructure projects across the country.

Earlier in July the coalition called on lawmakers in the U.S. House of Representatives to “take swift action on permitting reform.” In a letter to Chairman Westerman ahead of an oversight hearing held by the Natural Resources Committee.

The following are statements from members of the coalition on support for the SPEED Act:

Dan Naatz, COO and EVP of the Independent Petroleum Association of America: “American energy producers appreciate Chairman Westerman and Congressman Golden’s efforts to address delays the NEPA process has brought to building out much-needed energy infrastructure. The Independent Petroleum Association of America supports the SPEED Act – the legislation’s reforms to our nation’s permitting system provide a balanced effort of environmental stewardship and the timely decision making needed for economic investment.”
Tim Tarpley, president of Energy Workforce & Technology Council: “The SPEED Act is a win for American energy and infrastructure. By cutting red tape, reducing frivolous lawsuits, and restoring common sense to NEPA, this bill ensures projects get built on time and on budget. Steps taken by the SPEED Act are especially critical for the energy services sector, where permitting delays stall job creation, investment, and innovation. Energy Workforce & Technology Council supports this legislation because it delivers the certainty needed to power our economy and keep America competitive.”
Erik Milito, president of the National Ocean Industries Association: “We commend Representatives Westerman and Golden for their bipartisan leadership on the SPEED Act, a timely and serious step toward modernizing America’s permitting system. Offshore energy companies are ready to invest and innovate across oil and gas, wind, carbon capture, deep sea mining, and emerging technologies. But outdated, unpredictable permitting continues to delay progress and deter investment, especially in one of the most complex regulatory environments in the world. The SPEED Act lays a strong foundation for reform, recognizing that energy development and environmental stewardship go hand in hand. We look forward to working with Congress to strengthen the bill and deliver the reliable, durable permitting system our energy future requires.”
Karr Ingham, Economist, president, Texas Alliance of Energy Producers: “The Alliance applauds Chairman Westerman’s leadership in this bipartisan effort to reduce barriers to energy production. The need is especially acute in Texas, where access to markets for Texas and U.S.-produced crude oil and natural gas is critical and has long been hampered by abuses in the permitting process. Additional pipeline and export capacity, including new LNG export facilities, is required to support the extraordinary growth in production accomplished by the U.S. domestic oil and gas industry. Furthermore, moving products to domestic and global markets more quickly meets growing energy needs at home and abroad, meets those needs in much cleaner fashion compared to non-U.S. production, and reduces the need to flare natural gas. Enactment of the SPEED Act will go a very long way toward enhancing development of cost effective projects that will expand delivery of high quality energy in Texas, the US, and around the world.”
Tim Stewart, president of the U.S. Oil & Gas Association: “It’s not a lack of interest or capital, knowhow or need holding American industry back, it is an artificial legal and regulatory morass which has been built up over decades. Federal agencies now prioritize process over outcome. The SPEED Act cuts through all that. If America wants to start building things again, we need to do this.”
Melissa Simpson, president of Western Energy Alliance: “The Alliance has been in court for a decade now defending oil and natural gas producers targeted by activist groups who use perceived NEPA deficiencies to halt federal leasing. It shouldn’t take that long to work through what the U.S. Supreme Court unanimously agreed is a procedural requirement, not a roadblock, to inform federal agencies and the public. We appreciate Chairman Westerman for prioritizing reasonable limits to judicial reviews on NEPA and courtroom obstructionism in the SPEED Act.”

The full letter to Chairman Westerman supporting the SPEED Act is available here.

# # #

MIL OSI Global Banks –

July 31, 2025

MIL-OSI USA: Acting Chairman Pham Lauds Presidential Working Group Recommendations to Usher in Golden Age of Crypto in the U.S.

Source: US Commodity Futures Trading Commission

WASHINGTON, D.C. — The President’s Working Group on Digital Asset Markets today released a multi-agency report on recommendations to strengthen American leadership in digital financial technology. The report included input from multiple federal agencies, including the Commodity Futures Trading Commission.
“Under President Trump’s leadership, the federal government is outlining a long-overdue roadmap to embrace cutting-edge technology that will revolutionize financial services, empower entrepreneurs, and once again cement American dominance as the cradle of innovation.
“I want to thank President Trump for taking decisive action to prioritize digital assets and write a new chapter in American ingenuity and global competitiveness. I also want to thank Special Advisor on AI and Crypto David Sacks, Treasury Secretary Scott Bessent, Attorney General Pam Bondi, Securities and Exchange Commission Chairman Paul Atkins, Working Group Executive Director Bo Hines, all the members of the President’s working group, their staffs and all who worked so diligently to make this possible. I particularly want to thank Meghan Tente, Brigitte Weyls and Harry Jung from the CFTC.
“This report represents a unified approach under the Trump Administration to usher in a golden age of crypto, and the CFTC stands ready to fulfill our mission to promote responsible innovation, safeguard our markets and ensure they remain the envy of the world.”

MIL OSI USA News –

July 31, 2025

MIL-Evening Report: Progress on Closing the Gap is stagnant or going backwards. Here are 3 things to help fix it

Source: The Conversation (Au and NZ) – By Madeleine Pugin, Research Fellow, School of Government and International Relations, Griffith University

The Productivity Commission’s latest data on Closing the Gap progress represents an unsurprisingly grim overview of the socioeconomic inequalities experienced by Aboriginal and Torres Strait Islander peoples.

Closing the Gap is the plan federal and state governments have to address Indigenous socioeconomic disadvantage. It sets specific targets across a range of areas.

This edition annual data report paints a concerning picture of Indigenous peoples’ quality of life across the states and territories. Despite 17 years of Closing the Gap policy, First Nations communities continue to face significant disadvantage. Of the 19 targets, 16 have been assessed, with four targets worsening. They are:

adult imprisonment
children in out-of-home care
suicide
children developmentally on track.

There have been some successes. Four targets are on track to be met: preschool enrolment, employment, and land and water rights. Although the latter targets are likely to be achieved, the Queensland and Northern Territory governments are walking away from plans for Treaty. This could undercut efforts for increased Indigenous rights recognition.

There is also improvement in six other target areas, but they are still not on track to be met by 2031:

life expectancy
healthy birthweights
year 12 or equivalent qualifications
youth engagement
appropriately sized housing.

Time for change

Year after year, Closing the Gap reporting offers little hope for meaningful change. It also falls short of providing crucial insights into what is working, what isn’t, and where resources and expertise should be directed to address unmet targets.

We must ask ourselves: when is it time to pursue a different approach?

These are complex issues with no simple solutions, but that must not deter us from pursuing every possible avenue for change. As the worsening suicide target shows, lives depend on it.

Nonetheless, there is little evidence to suggest governments are being impelled to act on the transformational changes required to implement the four priority reforms.

Since the failed Voice referendum, there has been little will from all levels of government to radically transform their way of working with First Nations communities. The gaps in outcomes are unlikely to close with this business-as-usual approach.

So what could be changed to help improve the lives of Indigenous people? Here are three ideas.

1. A national action plan, driven by human rights

Australia has no comprehensive Indigenous rights framework. Currently, recognition of Indigenous rights in existing Australian laws is “piecemeal” and inconsistent across jurisdictions.

Adopting a rights-based approach to the Closing the Gap framework could provide one way forward. The realisation of rights is central to genuine self-determination for Indigenous peoples.

The United Nations Declaration on the Rights of Indigenous Peoples (UNDRIP), which Australia endorsed in 2009, outlines the minimum standards of human rights relating to Indigenous peoples.

A 2023 report looking at how UNDRIP works in Australia contains a list of recommendations, with the first being:

that the Commonwealth Government ensure its approach to developing legislation and policy on matters relating to Aboriginal and Torres Strait Islander people (including, but not limited to, Closing the Gap initiatives) be consistent with the Articles outlined in the United Nations Declaration on the Rights of Indigenous Peoples.

UNDRIP’s core principals of self-determination and participation in decision-making directly align with what communities and experts have been calling for on Closing the Gap reform. At a minimum, the federal government should meaningfully negotiate a national action plan to implement the declaration.

Such a plan would help drive community-led solutions, empowering Indigenous peoples at local and regional levels. Bottom-up grassroots approaches are vital to Closing the Gap.

2. An independent oversight body

Despite the failure of the Voice referendum, an independent representative body is still needed at the national level. It would provide strategic oversight and accountability for implementation of the Closing the Gap policy at the local and regional levels.

This body could also provide much-needed political and policy advocacy to hold governments to their commitments.

There is the National Agreement on Closing the Gap, which Commonwealth, state, territory governments are a party to, as well as the Coalition of Peak Indigenous bodies and the Australian Local Government Association.

Yet some governments are enacting policies and laws which are inconsistent with the agreement. Queensland and the Northern Territory, for instance, have ceased involvement in Treaty processes and turned toward stricter penalties in response to youth offending – moves criticised by human rights commissions.

An independent representative body would help shed light on these inconsistencies and better hold governments accountable.

3. A bigger role for local government

What is often missing from the conversation is the crucial role local governments play in implementing policies that shape outcomes on the ground.

As frontline service providers, local governments are positioned to engage with communities on a direct, day-to-day basis, which can be responsive to the everyday needs of Aboriginal and Torres Strait Islander peoples.

In a first for local implementation of Closing the Gap, Tamworth Aboriginal Community Controlled Organisations and Tamworth Regional Council entered an agreement to work together towards addressing key aspects of initiative.

There are strong reasons for local governments to take a more central leadership role in trying to meet the Closing the Gap targets. To do so effectively, however, they require adequate resourcing and sustained funding to support community-driven programs.

Additionally, embedding Indigenous rights and interests in local government planning and policy would significantly enhance their capacity to contribute meaningfully.

Bartholomew Stanford receives funding from the Australian Research Council (ARC).

Madeleine Pugin does not work for, consult, own shares in or receive funding from any company or organisation that would benefit from this article, and has disclosed no relevant affiliations beyond their academic appointment.

– ref. Progress on Closing the Gap is stagnant or going backwards. Here are 3 things to help fix it – https://theconversation.com/progress-on-closing-the-gap-is-stagnant-or-going-backwards-here-are-3-things-to-help-fix-it-262042

MIL OSI Analysis – EveningReport.nz –

July 31, 2025

MIL-Evening Report: Big tech says AI could boost Australia’s economy by $115 billion a year. Does the evidence stack up?

Source: The Conversation (Au and NZ) – By Uri Gal, Professor in Business Information Systems, University of Sydney

Imaginima / Getty Images

AI is on the agenda in Canberra. In August, the Productivity Commission will release an interim report on harnessing data and digital technology such as AI “to boost productivity growth, accelerate innovation and improve government services”. Shortly afterward, the government will host an Economic Reform Roundtable where AI policy will be up for discussion.

AI developers are aggressively pursuing influence over the new rules. The Chinese government wants to include AI in trade deals. Meanwhile, as the US government seeks to “win the AI race”, US-based tech companies are making their own overtures.

The most ambitious intervention has come from ChatGPT developer OpenAI, which recently hired former Tech Council chief executive Kate Pounder as its local policy liaison. Pounder is also a former business partner of Assistant Minister for the Digital Economy Andrew Charlton.

OpenAI’s AI Economic Blueprint for Australia makes bold projections about the new technology’s impact on the country’s economy, accompanied by a host of policy proposals. However, these claims warrant careful scrutiny, particularly given the company’s clear commercial interests in shaping Australian regulation.

The gap between promise and evidence

OpenAI claims AI could boost Australia’s economy by A$115 billion annually by 2030. It attributes most of this to productivity gains in business, education and government. However, the supporting evidence is thin.

For instance, the report notes Australian workers have lower productivity than their US counterparts and then claims (without evidence) this is because Australia has invested less in digital technologies such as AI. However, it ignores numerous other factors affecting productivity, from industrial structure to regulatory environments.

The report also describes supposed AI-driven productivity gains in companies such as Moderna and Canva. However, these narratives lack any data about improved organisational or individual performance.

Perhaps more concerning is the report’s uniformly optimistic tone, which overlooks significant risks. These include organisations struggling with costly AI projects, massive job displacements, worsening labour conditions, and concentrating wealth.

Most problematically, OpenAI’s blueprint assumes AI adoption and its economic benefits will materialise rapidly across the economy. However, evidence suggests a different reality.

Economic impact from AI will unfold gradually

Recent evidence suggests AI’s economic impact may take decades to fully materialise. Studies report some 40% of US adults use generative AI yet this translates to less than 5% of work hours and an increase of less than 1% in labour productivity.

AI may not spread much faster than past technologies. The limiting factor will be how quickly individuals, organisations and institutions can adapt.

Even when AI tools are available, meaningful adoption requires time. People must develop new skills, change the way they work, and integrate the new technologies into complex organisations. The economic impacts of earlier general-purpose technologies such as computers and the internet took decades to fully materialise, and there’s little reason to believe AI will be fundamentally different.

The educational risk

Like Google, OpenAI is also aggressively pushing for AI adoption in education. It has teamed up with edtech companies and launched a new “study mode” in ChatGPT.

The push for AI tutoring and automated educational tools raises profound concerns about human development and learning.

Early evidence suggests over-reliance on AI tools may condition people to depend on them. When students routinely turn to AI, they risk avoiding the mental effort required to build critical thinking skills, creativity and independent inquiry. These capacities form the foundation of a thriving democracy and innovative economy.

Students who become accustomed to AI-assisted thinking may struggle to develop intellectual independence. This is needed for innovation, ethical reasoning and creative problem-solving.

AI applications that help teachers personalise instruction or identify learning gaps may be useful. But systems that substitute for students’ own cognitive effort and development should be avoided.

A multi-partner infrastructure strategy

Australia’s digital strategy will undoubtedly include significant investment in AI infrastructure such as data centres. One challenge for Australia is to avoid concentrating our investment around a single technology provider. Doing so would be a mistake that could compromise both economic competitiveness and national sovereignty.

Amazon plans to spend $20 billion on local data centres. Microsoft Azure already has significant local capacity, as does Australian company NextDC. This diversity provides a foundation, but maintaining and expanding it requires deliberate policy choices.

Maintaining multiple data centre suppliers helps keep computing power that is independent of foreign governments or single companies. This approach will give Australia more bargaining power to ensure lower prices, greener power and local skills quotas.

Diversification provides regulatory leverage as well. Australia can enforce common security standards knowing no single supplier can threaten an investment strike.

Australia’s AI future

AI technology is developing rapidly, driven by large corporations wielding vast amounts of capital and political influence. It presents real opportunities for economic growth and social benefit that Australia can’t afford to squander.

However, if the government uncritically accepts corporate advocacy, these opportunities may be captured by foreign interests.

Australia’s approach to AI policy should maintain human-centred values alongside technological advancement. This balance requires resisting the siren call of corporate promises.

The decisions made today will shape Australia’s future for decades. These choices should be guided by independent analysis, empirical evidence, and a commitment to outcomes for all Australians.

The Australian government must resist the temptation to let Silicon Valley write our digital future, no matter how persuasive their lobbyists or how impressive their promises. The stakes are simply too high to get this wrong.

Uri Gal does not work for, consult, own shares in or receive funding from any company or organisation that would benefit from this article, and has disclosed no relevant affiliations beyond their academic appointment.

– ref. Big tech says AI could boost Australia’s economy by $115 billion a year. Does the evidence stack up? – https://theconversation.com/big-tech-says-ai-could-boost-australias-economy-by-115-billion-a-year-does-the-evidence-stack-up-260705

MIL OSI Analysis – EveningReport.nz –

July 31, 2025

MIL-OSI United Kingdom: Time to pay up: Toughest crackdown on late payments in a generation unveiled in plan to back small businesses

Source: United Kingdom – Government Statements

Press release

Time to pay up: Toughest crackdown on late payments in a generation unveiled in plan to back small businesses

UK Government unveils its Small Business Plan to support SMEs across the country

Government to tackle late payments with the most significant legislative reforms in 25 years – an issue that costs the UK economy £11bn a year and shuts down 38 businesses every day
UK set to have the toughest late payments laws in the G7 as part of reforms to back small businesses and unlock growth as part of the Plan for Change
New £4bn finance boost including 69,000 Start-Up Loans to inspire the next generation of entrepreneurs and small business owners

Small businesses across the UK will benefit from the most comprehensive support package in a generation, as the government launches a bold new plan to give small businesses the tools to thrive and drive economic growth as part of its Plan for Change.

Small and medium sized firms employ 60% of the country’s workforce and generate £2.8 trillion in turnover. However, for too long, the odds have been stacked against small businesses.

From tradespeople and shopkeepers to start-up founders and family-run firms, too many work hard but don’t get the backing they deserve – held back by late payments and not getting the financial backing they need within a wider system that hasn’t worked in their favour.

That’s why the Government is taking serious action to back small businesses and give them the tools they need to grow. This builds on the solid foundation of certainty and stability this government has already delivered—through the trade deals we’ve secured, four interest rate cuts, and a long-term industrial and trade strategy that’s helping businesses plan ahead with confidence.

At the heart of the plan is a the most significant package of reforms in a generation to tackle late payments, with plans to introduce the toughest laws on late payments in the G7.

Late payments are one of the biggest barriers to small business growth —causing cashflow problems that stop firms from scaling up and investing in their future. Every day, hardworking businesses close their doors because they aren’t paid on time.

The new laws are set to give stronger powers to the Small Business Commissioner to empower them to wield fines, worth potentially millions of pounds, against the biggest firms who persistently choose to pay their suppliers late.

The Small Business Commissioner will be given new powers to carry out spot checks and enforce a 30-day invoice verification period to speed up resolutions to disputes. The upcoming legislation will also introduce maximum payment terms of 60 days, reducing to 45 days, giving firms certainty they’ll be paid on time.

Audit committees, under the proposals, will also be legally required to scrutinise payment practices at board level, placing greater pressure on large firms to show they’re treating small suppliers fairly backed by mandatory interest charges for those who pay late.

These changes will also save small businesses valuable time, freeing up hours currently spent chasing overdue invoices so they can focus on growing their business instead. Taken together, this will help ensure businesses are paid on time and end the scourge of late payments which costs the UK economy £11bn per year and closes down 38 UK businesses every day.

Prime Minister Keir Starmer said:

“From builders and electricians to freelance designers and manufacturers—too many hardworking people are being forced to spend precious hours chasing payments instead of doing what they do best – growing their businesses.

“It’s unfair, it’s exhausting, and it’s holding Britain back. So, our message is clear: it’s time to pay up.

“Through our Small Business Plan, we’re not only tackling the scourge of late payments once and for all, but we’re giving small business owners the backing and stability they need for their business to thrive, driving growth across the country through our Plan for Change.”

Business and Trade Secretary Jonathan Reynolds said:  

“This country is home to some of the brightest entrepreneurs and innovative businesses in the world, and we want to unleash their full potential by giving them back time and money to do what they do best – growing our local economies.

“Our Small Business plan – the first in over a decade – is slashing unnecessary admin costs, making it easier for businesses to set up shop and giving SMEs the financial backing they need.

“This is our Plan for Change in action, putting more money in people’s pockets, boosting local communities and ensuring Britain is a great place to do business and thrive.”

Small Business Minister Gareth Thomas said:

“I want the UK to be the best place in the world to start a business, grow and succeed – and that’s why we’ve taken bold steps today. 

“Too many small firms go under each year because they aren’t paid on time – that is completely unacceptable.

“I hear all too often about businesses who just don’t have the cash needed to start up or grow. Today, we’ve announced measures as part of our Plan for Change to tackle all of those issues and beyond. This is the government listening to businesses, working with them, and delivering real change.”

Policy Chair of the Federation of Small Businesses (FSB), Tina McKenzie, said:

“Making sure businesses are paid on time, that our high streets thrive, and creating conditions in which everyone can start and succeed in business are crucial priorities for small businesses, communities and the economy. It’s very welcome that the Prime Minister has today made them his Government’s priorities.

“I’m pleased that FSB and the Government have been able to work in lockstep on the bold and ambitious measures needed to tackle the scourge of late payment through legislation, and other pro-growth, pro-small business measures.

“Today’s plan is an encouraging commitment from the Government to take the side of small businesses in the great growth challenge ahead.”

Charlie Shaw, owner of Flock and Herd butchers in Peckham said:

“We’re proud to pay every supplier on time and once we receive an invoice, so it’s fantastic to see the government put the Small Business Plan into place tackling the big issue of late payments.

“We believe this is a fair and honest way to conduct business. It gives us a clear and current understanding of how our business is performing. Our relationships with our suppliers have been amazing and truly beneficial to all parties.”

As part of the plan, the government is also tackling another major barrier for small businesses – access to finance. Despite the UK’s world-leading financial services sector, many small firms struggle to secure the funding they need to invest, expand, or even survive.

To address this, the Government is launching a new £4 billion wave of financial support aimed at boosting growth and supporting more small businesses to start up and grow. This includes a £1bn boost for new businesses, with 69,000 Start-Up Loans and mentoring support to inspire the next generation of entrepreneurs and small business owners.

The Government is also going further by delivering a new £3 billion boost to the British Business Bank – raising the total guarantee to £5 billion – to help lenders offer more small business loans through the ‘ENABLE programme’. Under the scheme, the BBB provides a government-backed guarantee to help lenders feel safer when lending to smaller or newer businesses, enabling them to offer better loan terms including with lower interest.

These measures aim to break down long-standing barriers that have made it harder for small businesses to access the funding they need to get off the ground by making finance and loans more accessible, affordable, and fair.

Accelerating SME growth by just 1 percentage point per year, could deliver £320bn to the UK economy by 2030. All of these measures announced today back small businesses to the hilt and build on action already taken by this government to create the conditions for businesses to thrive:

Slashing of red tape to boost the hospitality and arts sector through hospitality zones and licensing reforms following the Licensing Taskforce co-chaired with Nick Mackenzie, Greene King CEO
High Street Rental Auctions to fill vacant high street premises
A revamped Board of Trade to get more small firms exporting around the world
The new Business Growth Service to ensure SMEs have access to key support
We’ve set out that we intend to introduce permanently lower business rates multipliers for the hard-hit retail, hospitality and leisure sector.

Notes to editors

Michelle Ovens CBE, Founder, Small Business Britain, said:

“I am thrilled to see the Small Business Plan launched today, putting the nation’s smallest businesses at the heart of Government strategy where it should be. These job creators and economy builders will benefit from a huge boost to funding through the British Business Bank, a boost to skills, support for high streets and a long hoped for legislative backing for getting paid on time. We will not see economic growth without small business growth, so I am eager to get on and help the Government deliver on this agenda – and help small businesses regardless of their background start, grow and thrive.”

Simon Groom, CEO of MagnifyB, said:

“MagnifyB welcomes the UK Government’s action to tackle late payments, which will give small businesses the cash flow stability they need to thrive. Alongside this, there is a clear need to provide micro and small businesses with far more than just a repository of information, including a practical digital toolset to strengthen their operations and improve their chances of long-term success. We hope that the new Small Business Commissioner can be instrumental in bringing together ideas and championing the initiatives needed to make this support a reality.”

Julianne Ponan MBE, Founder of Creative Nature, a small business that exports top 14 Allergen Free Baking Mixes and Snacks to 16 countries, said:

“I’m delighted to see the government’s new SME Strategy recognising the critical role small businesses play both at home and globally. From tackling late payments to simplifying access to growth advice and support, these measures are a lifeline for SMEs like mine who often face disproportionate challenges with limited resources. I’m especially encouraged by the commitment to reduce administrative burdens by 25% and improve access to finance both are major barriers to growth for underrepresented founders, including women and ethnic minority entrepreneurs. The focus on revitalising the high street, digital skills, and exporting support shows that the government is listening to the needs of small businesses.”

The full plan will be published later this morning on Gov.uk We have launched a public consultation to seek views on our proposed legislative measures to ensure companies pay their suppliers quickly and on time. Please go to GOV.UK for details of the proposed measures.
Today’s announcement builds on the foundation of the government putting the public finances on a sustainable path – providing long-term direction, stability, and confidence for small businesses to thrive. This has paid off – interest rates have been cut four times in the last 12 months and in the first three months of 2025, Britain was the fastest growing economy in the G7.
The Government has also extended 40% business rates relief for 250,000 firms until April 2026 protected bills from inflation, and ensured over 700,000 properties pay no rates at all. This is creating a fairer business rates system to protect the high street, support investment, and level the playing field as we intend to introduce permanently lower tax rates for retail, hospitality, and leisure properties from next year.
This has included 865,000 small businesses being protected from the NICs rise because of the Employment Allowance increase to £10500, whilst 700,000 small business properties do not pay business rates at all because of Small Business Rates Relief. Corporation tax has been capped at 25% – the lowest headline rate of Corporate Tax in the G7 – for the duration of parliament.

Published 30 July 2025

MIL OSI United Kingdom –

July 31, 2025

MIL-OSI Canada: Statement by Prime Minister Carney on Canada’s recognition of a Palestinian state

Source: Government of Canada – Prime Minister

“Canada has long been committed to a two-state solution – an independent, viable, and sovereign Palestinian state living side by side with the State of Israel in peace and security.

For decades, it was hoped that this outcome would be achieved as part of a peace process built around a negotiated settlement between the Israeli government and the Palestinian Authority.

Regrettably, this approach is no longer tenable. Prospects for a two-state solution have been steadily and gravely eroded, including by:

The pervasive threat of Hamas terrorism to Israel and its people, culminating in the heinous terrorist attack of October 7, 2023, and Hamas’ longstanding violent rejection of Israel’s right to exist and a two-state solution.
The accelerated settlement building across the West Bank and East Jerusalem, while settler violence against Palestinians has soared.
Actions such as the E1 Settlement Plan and this month’s vote by the Knesset calling for the annexation of the West Bank.
The ongoing failure by the Israeli government to prevent the rapidly deteriorating humanitarian disaster in Gaza, with impeded access to food and other essential humanitarian supplies.

The deepening suffering of civilians leaves no room for delay in co-ordinated international action to support peace, security, and the dignity of all human life. Preserving a two-state solution means standing with all people who choose peace over violence or terrorism, and honouring their innate desire for the peaceful co-existence of Israeli and Palestinian states as the only roadmap for a secure and prosperous future.

For these reasons, Canada intends to recognize the State of Palestine at the 80th Session of the United Nations General Assembly in September 2025.

This intention is predicated on the Palestinian Authority’s commitment to much-needed reforms, including the commitments by Palestinian Authority President Abbas to fundamentally reform its governance, to hold general elections in 2026 in which Hamas can play no part, and to demilitarize the Palestinian state. Canada will increase its efforts in supporting strong, democratic governance in Palestine and the contributions of its people to a more peaceful and hopeful future.

We reiterate that Hamas must immediately release all hostages taken in the horrific terrorist attack of October 7; that Hamas must disarm; and that Hamas must play no role in the future governance of Palestine. Canada will always steadfastly support Israel’s existence as an independent state in the Middle East living in peace and security. Any path to lasting peace for Israel also requires a viable and stable Palestinian state, and one that recognizes Israel’s inalienable right to security and peace.

Canada has already committed over $340 million in humanitarian aid to address the dire humanitarian situation in Gaza. We are further committing $30 million in new funding to help address the needs of Palestinian civilians, and providing an additional $10 million to support the Palestinian Authority’s role in stabilizing and governing the West Bank. We are working with our allies to deliver immediate assistance to those in dire need.

We will intensify our efforts with our international partners to develop a credible peace plan that establishes governance and security arrangements for Palestine and ensures the delivery of humanitarian aid at the necessary scale to Gaza. Canada will be a constructive partner in building a just, meaningful, and lasting peace in the region, and a future that respects the dignity, security, and aspirations of all Palestinians and Israelis.”

MIL OSI Canada News –

July 31, 2025

MIL-OSI USA: Tonko Demands DHS Restore Funding for UAlbany Mesonet Weather Detection Program

Source: United States House of Representatives – Representative Paul Tonko (Capital Region New York)

ALBANY, NY — Congressman Paul D. Tonko (NY-20), along with Representatives John Mannion (NY-22) and Joe Morelle (NY-25) today sent a letter to Department of Homeland Security (DHS) Secretary Kristi Noem urging the Trump Administration reverse its decision to terminate funding for the Exploiting Mesonet for Emergency Preparedness and Response to Weather Extremes (EMPOWER) project.

In 2023, the DHS awarded the University at Albany $3 million for this grant project to improve emergency management and deliver accurate, real-time forecasting for severe weather. But, earlier this month, that funding was abruptly terminated.

“Developed in partnership between DHS’s Science and Technology Directorate and the University at Albany, EMPOWER is exactly the kind of forward-looking, science-based emergency management program our nation needs as extreme weather, and natural disasters grow more frequent, intense, and deadly,” the lawmakers write.

The letter continues, “At the core of EMPOWER’s success is the New York State Mesonet, a state-of-the-art network of 127 weather stations that supplements National Weather Service observations. This is a moment that demands leadership and bold investment in resilience. In just the past few weeks, catastrophic flooding in Texas and record-setting heat across the country have underscored the urgency of strengthening our preparedness. Cutting off funding for a proven emergency response program amid an escalating climate crisis is not just short-sighted, it is dangerous.

“The stakes are simply too high to abandon tools and technologies that can help save lives.”

For years, Tonko has worked to strengthen and support the nation’s weather preparedness. Last Congress, he introduced the bipartisan National Mesonet Authorization Act alongside Representative Stephanie Bice (R-OK), legislation that would increase the overall coverage and accuracy of our current National Mesonet program.

Earlier this month, UAlbany sent a letter inviting DHS Secretary Noem to visit the campus and tour their facilities to lean more about how the university’s essential research supports DHS’s work and mission. UAlbany also sent a letter to the New York congressional delegation requesting support from members in helping to reinstate a $3 million DHS research grant.

The full letter to DHS Secretary Noem can be found HERE or below:

Dear Secretary Noem,

We write to express our strong objection to the Department of Homeland Security’s decision to terminate funding for the Exploiting Mesonets for Emergency Preparedness and Response to Weather Extremes (EMPOWER) project. This action not only undermines years of progress in public safety and emergency preparedness, but it also puts lives at risk. We ask you to reverse this decision and reinstate the $3 million grant supporting this initiative without delay.

Developed in partnership between DHS’s Science and Technology Directorate and the University at Albany, EMPOWER is exactly the kind of forward-looking, science-based emergency management program our nation needs as extreme weather, and natural disasters grow more frequent, intense, and deadly. It provides emergency managers and first responders with real[1]time, localized data to improve decision-making and response times, giving communities a better chance to prepare for and withstand extreme weather events.

At the core of EMPOWER’s success is the New York State Mesonet, a state-of-the-art network of 127 weather stations that supplements National Weather Service observations. The Mesonet fills gaps in our national monitoring infrastructure and provides the high-resolution, real-time data that emergency response systems increasingly depend on.

This is a moment that demands leadership and bold investment in resilience. In just the past few weeks, catastrophic flooding in Texas and record-setting heat across the country have underscored the urgency of strengthening our preparedness. Cutting off funding for a proven emergency response program amid an escalating climate crisis is not just short-sighted, it is dangerous.

For a modest federal investment, EMPOWER is delivering high-impact results. This administration has emphasized the importance of supporting state and local partners in disaster preparedness EMPOWER embodies that collaboration, demonstrating how strategic partnerships between federal science agencies, academia, and state governments can produce innovative, life-saving solutions.

We urge you to reinstate full funding for the EMPOWER initiative and ensure that the University at Albany and its partners can continue advancing this critical work. The stakes are simply too high to abandon tools and technologies that can help save lives.

MIL OSI USA News –

July 31, 2025

MIL-OSI New Zealand: Stronger accountability for your rates

Source: New Zealand Government

Key metrics published today show how much councils are spending and what they are spending it on, which has a direct impact on your rates, Local Government Minister Simon Watts says.

“We know it is really tough out there and the cost of living is the biggest worry for households. Councils need to show they are wisely spending ratepayers’ hard-earned money.

“Ratepayers place immense trust in their local councils who make key decisions on local infrastructure, fiscal management, and how their community operates on a day-to-day basis on their behalf.

“Some ratepayers are getting more and more fed up with rising rates hitting pockets harder than ever. This isn’t fair during a cost-of-living crisis where many Kiwis are doing it tough. It is important that ratepayers can see how their council is performing and what it is delivering for their community.

“That’s why the Government is putting clear facts and figures directly into the hands of ratepayers. When ratepayers know more about how their council is performing and where their money is going, they can engage more effectively and ask the tough questions.

“For instance, communities can now compare how much their council spends on core essentials like infrastructure and see whether their rates are going up more than average.

“We have been clear that we want to see councils get back to basics, focusing on delivering essential services and infrastructure, improving local decision-making, and supporting their communities through the cost of living – not adding to it.

“Releasing these performance metrics aligns with our commitment to lifting the performance of local government. It is an opportunity for councils that are focused on their core functions to highlight their efficiency and value to their communities.”

The Government is also actively exploring a rates capping system.

“Given the current pressures on households, the degree of rates increases is a massive worry. We’re actively exploring a rates capping system to ensure councils are spending ratepayers’ money responsibly,” Mr Watts says.

The metrics include information on council demographics, rates revenue, debt, staffing and expenditure, with benchmarking based on groupings of similar councils.

As an annual publication, the information will be developed over time to paint a fuller picture of council performance across New Zealand.

This year’s council profiles and group comparison tables are available on https://www.dia.govt.nz/local-government-performance-metrics.

MIL OSI New Zealand News –

July 31, 2025

MIL-OSI: Euronet and CoreCard Announce Merger Agreement to Unlock Global Opportunities in Credit Card Issuing and Processing

Source: GlobeNewswire (MIL-OSI)

LEAWOOD, Kan. and NORCROSS, Ga., July 30, 2025 (GLOBE NEWSWIRE) — Euronet (NASDAQ: EEFT), a global leader in payments processing and cross-border transactions, and CoreCard Corporation (NYSE: CCRD), a leading provider of innovative credit technology solutions and processing services to the financial technology and services market, today announced they have entered into a definitive agreement for Euronet to acquire CoreCard in a stock-for-stock merger transaction that values CoreCard at approximately $248 million, or $30 per share of CoreCard common stock. The exchange ratio and other terms of the transaction are described below.

The proposed transaction marks a pivotal step in accelerating Euronet’s strategic goal of a more diversified, future-ready revenue mix, that is anchored in scalable, modern platforms designed for the next generation of digital financial services across the globe.

Acquisition to Add a Proven Credit Card Platform and Marquee Clients to Fuel Euronet’s Growth Strategy

CoreCard’s platform is proven and trusted by some of the most respected names in finance and technology, and has been instrumental in launching one of the most successful co-branded credit card offerings in U.S. history in partnership with Goldman Sachs. This credibility, combined with CoreCard’s deep expertise in credit products, positions Euronet to compete in a sizeable market traditionally dominated by a few legacy providers.

The CoreCard modern architecture enables faster deployment, easier integrations, and the flexibility to support rapid innovation, which are key advantages in today’s world of payments, where banks and fintechs are looking to embed financial experiences in their customer journeys. This has enabled CoreCard to support diverse, bespoke use cases for fintech innovators such as Cardless, who has recently been chosen as the partner for the Coinbase credit card.

“More than a product expansion, this acquisition will be a catalyst for long-term growth, and we expect it to be accretive in the first full year post close,” said Michael J. Brown, Euronet’s Chairman and Chief Executive Officer. “By integrating CoreCard’s platform with our own Ren architecture and global distribution network, we will be positioned to become a leading modern card issuer and innovation partner for the next generation of digital finance. This acquisition is a natural extension of our strategy to invest in scalable, high-margin businesses that align with long-term market trends. We also value and respect the work of CoreCard’s employees, who we are eager to welcome to Euronet, and we look forward to their contributions to our company in the future.”

“Joining Euronet marks an exciting new chapter for CoreCard,” said Leland Strange, CEO of CoreCard. “Our team has built a modern, resilient credit card processing platform that serves some of the largest companies and financial institutions in the world. We’re excited to bring our capabilities to a global stage. We have spent a lot of time and diligence over the last year exploring the right ‘fit’ for what our team has built over many years, and we believe this is a great outcome for the team and our shareholders. We are joining with a company that has also been built on a strong foundation over many years that has kept a strong team and customer-focused culture with a focus on innovation.”

Time and Approvals

The transaction has been approved by the boards of directors of both Euronet and CoreCard, and is expected to close in late 2025, subject to approval by CoreCard shareholders and the satisfaction of certain other customary closing conditions, including the expiration or termination of the applicable waiting period under the Hart-Scott-Rodino Antitrust Improvements Act of 1976.

Transaction Details

Under the terms of the merger agreement, each share of CoreCard common stock will be exchanged for a number of shares of Euronet common stock equal to an exchange ratio between 0.2783 and 0.3142, calculated as $30 divided by the volume weighted average share price of Euronet common stock over the 15-trading day period ending on and including the second to last trading day prior to the closing date (the “Final Euronet Stock Price”), subject to a floor of $95.48 per share and a ceiling of $107.80 per share. CoreCard shareholders will receive 0.3142 Euronet shares for each of their CoreCard shares if the Final Euronet Stock Price is at or below $95.48, and 0.2783 Euronet shares for each of their CoreCard shares if the Final Euronet Stock Price is at or above $107.80.

Advisors

Stinson LLP is acting as outside counsel to Euronet. Kilpatrick Townsend & Stockton LLP is acting as outside counsel to CoreCard. Keefe, Bruyette & Woods, a Stifel Company, provided certain financial advice to the board of directors of CoreCard.

About CoreCard

CoreCard Corporation (NYSE: CCRD) provides a modern card issuing platform built for the future of global transactions in an embedded digital world. Dedicated to continual technological innovation in the ever-evolving payments industry backed by decades of deep expertise in credit card offerings, CoreCard helps customers conceptualize, implement, and manage all aspects of their issuing card programs. Keenly focused on steady, sustainable growth, CoreCard has earned the trust of some of the largest companies and financial institutions in the world, providing truly real-time transactions via their proven, reliable platform operating on private on-premise and leading cloud technology infrastructure.

About Euronet

A global leader in payments processing and cross-border transactions, Euronet moves money in all the ways consumers and businesses depend upon. This includes money transfers, credit/debit processing, ATMs, point-of-sale services, branded payments, currency exchange and more. With products and services in more than 200 countries and territories provided through its own brand and branded business segments, Euronet and its financial technologies and networks make participation in the global economy easier, faster and more secure for everyone. Visit the company’s website at www.euronetworldwide.com.

Cautionary Statement Regarding Forward-Looking Statements

This communication contains “forward-looking statements” within the United States Private Securities Litigation Reform Act of 1995. You can identify these statements and other forward-looking statements in this document by words such as “may,” “will,” “should,” “can,” “could,” “anticipate,” “estimate,” “expect,” “predict,” “project,” “future,” “potential,” “intend,” “plan,” “assume,” “believe,” “forecast,” “look,” “build,” “focus,” “create,” “work,” “continue,” “target,” “poised,” “advance,” “drive,” “aim,” “forecast,” “approach,” “seek,” “schedule,” “position,” “pursue,” “progress,” “budget,” “outlook,” “trend,” “guidance,” “commit,” “on track,” “objective,” “goal,” “strategy,” “opportunity,” “ambitions,” “aspire” and similar expressions, and variations or negative of such terms or other variations thereof. Words and terms of similar substance used in connection with any discussion of future plans, actions, or events identify forward-looking statements.

Forward-looking statements by their nature address matters that are, to different degrees, uncertain, such statements regarding the transactions contemplated by the Agreement and Plan of Merger (the “Merger Agreement’), dated as of July 30, 2025, by and among CoreCard, Euronet and Genesis Merger Sub Inc. (the “Transaction”), including the expected timing of the closing of the Transaction; future financial and operating results; benefits and synergies of the Transaction; future opportunities for the combined company; the conversion of equity interests contemplated by the Merger Agreement; the issuance of common stock of Euronet contemplated by the Merger Agreement; the expected filing by Euronet with the SEC of the Registration Statement and the proxy statement/prospectus; the ability of the parties to complete the proposed Transaction considering the various closing conditions and any other statements about future expectations that constitute forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995, Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. All such forward-looking statements are based upon current plans, estimates, expectations and ambitions that are subject to risks, uncertainties and assumptions, many of which are beyond the control of Euronet and CoreCard, that could cause actual results to differ materially from those expressed in such forward-looking statements. Key factors that could cause actual results to differ materially include, but are not limited to, the expected timing and likelihood of completion of the Transaction, including the timing, receipt and terms and conditions of any required governmental and regulatory approvals of the Transaction; the occurrence of any event, change or other circumstances that could give rise to the termination of the definitive agreement; the possibility that CoreCard’s shareholders may not approve the Transaction; the risk that the parties may not be able to satisfy the conditions to the Transaction in a timely manner or at all; risks related to disruption of management time from ongoing business operations due to the Transaction; the risk that any announcements relating to the Transaction could have adverse effects on the market price of Euronet’s common stock; the risk that the Transaction and its announcement could have an adverse effect on the parties’ business relationships and business generally, including the ability of CoreCard or Euronet to retain customers and retain and hire key personnel and maintain relationships with their suppliers and customers, and on their operating results and businesses generally; the risk of unforeseen or unknown liabilities; customer, shareholder, regulatory and other stakeholder approvals and support; the risk of potential litigation relating to the Transaction that could be instituted against CoreCard or its directors and/or officers; the risk associated with third party contracts containing material consent, anti-assignment, transfer or other provisions that may be related to the Transaction which are not waived or otherwise satisfactorily resolved; the risk of rating agency actions and Euronet’s ability to access short- and long-term debt markets on a timely and affordable basis; the risk of various events that could disrupt operations, including: conditions in world financial markets and general economic conditions; inflation; the war in Ukraine and the related economic sanctions; and military conflicts in the Middle East.

These risks, as well as other risks related to the proposed Transaction, will be described in the Registration Statement that will be filed with the SEC in connection with the proposed Transaction. While the list of factors presented here and the list of factors to be presented in the Registration Statement are considered representative, no such list should be considered to be a complete statement of all potential risks and uncertainties. Additional factors that may affect future results are contained in each company’s filings with the SEC, including each company’s most recent Annual Report on Form 10-K, as it may be updated from time to time by quarterly reports on Form 10-Q and current reports on Form 8-K, all of which are available at the SEC’s website http://www.sec.gov. Euronet regularly posts important information to the investor relations section of its website. Any forward-looking statements made in this release speak only as of the date of this release. Except as may be required by law, neither Euronet nor CoreCard intends to update these forward-looking statements and undertakes no duty to any person to provide any such update under any circumstances.

Important Information for Investors and Stockholders

In connection with the proposed transaction, Euronet plans to file with the SEC a registration statement on Form S-4 (the “Registration Statement”), which will include a proxy statement of CoreCard that also constitutes a prospectus of Euronet, and any other documents in connection with the transaction. After the Registration Statement has been declared effective by the SEC, the definitive proxy statement/prospectus will be sent to the holders of common stock of CoreCard. INVESTORS AND SHAREHOLDERS OF CORECARD AND EURONET ARE URGED TO READ THE PROXY STATEMENT/PROSPECTUS AND ANY OTHER DOCUMENTS FILED OR TO BE FILED WITH THE SEC IN CONNECTION WITH THE TRANSACTION WHEN THEY BECOME AVAILABLE, AS THEY WILL CONTAIN IMPORTANT INFORMATION ABOUT EURONET, CORECARD, THE TRANSACTION AND RELATED MATTERS. The registration statement and proxy statement/prospectus and other documents filed by Euronet or CoreCard with the SEC, when filed, will be available free of charge at the SEC’s website at www.sec.gov. Alternatively, investors and stockholders may obtain free copies of documents that are filed or will be filed with the SEC by Euronet, including the registration statement and the proxy statement/prospectus, on Euronet’s website at https://ir.euronetworldwide.com/for-investors, and may obtain free copies of documents that are filed or will be filed with the SEC by CoreCard, including the proxy statement/prospectus, on CoreCard’s website at https://investors.CoreCard.com/. The information included on, or accessible through, Euronet’s or CoreCard’s website is not incorporated by reference into this press release.

No Offer or Solicitation

This press release is not intended to and shall not constitute an offer to sell or the solicitation of an offer to buy any securities, nor shall there be any sale of securities in any jurisdiction in which such offer, solicitation or sale would be unlawful prior to appropriate registration or qualification under the securities laws of such jurisdiction. No offering of securities shall be made except by means of a prospectus meeting the requirements of Section 10 of the Securities Act of 1933, as amended.

Participants in the Solicitation

Euronet and CoreCard and their respective directors, executive officers and other employees may be deemed to be participants in the solicitation of proxies from CoreCard’s shareholders in connection with the proposed Transaction. A description of participants’ direct or indirect interests, by security holdings or otherwise, will be included in the proxy statement/prospectus relating to the proposed Transaction when it is filed with the SEC. Information regarding Euronet’s directors and executive officers is contained in the definitive proxy statement, dated April 4, 2025, for its 2025 annual meeting of stockholders, and in Euronet’s Annual Report on Form 10-K for the fiscal year ended December 31, 2024. Information regarding CoreCard’s directors and executive officers is contained in CoreCard’s definitive proxy statement, dated April 14, 2025, for its 2025 annual meeting of shareholders, and CoreCard’s Annual Report on Form 10-K for the fiscal year ended December 31, 2024. Additional information regarding ownership of Euronet’s securities by its directors and executive officers, and of ownership of CoreCard’s securities by its directors and executive officers, is included in each such person’s SEC filings on Forms 3 and 4. These documents and the other SEC filings described in this paragraph may be obtained free of charge as described above under the heading “Important Information for Investors and Stockholders.”

The MIL Network –

July 31, 2025

MIL-OSI Australia: Fast food, screens, and no greens: A recipe for teen health trouble

Source:

31 July 2025

When a cheeseburger costs less than a punnet of strawberries, it’s clear the odds are stacked against healthy choices – especially for teenagers.

Now, new research from the University of South Australia shows that it’s not just unhealthy eating habits affecting teens, but an alarming clustering of poor lifestyle choices that’s putting the majority of teenagers at serious risk of preventable diseases later in life.

In a study of more than 293,770 teenagers aged 12-17 – from 73 countries, across five world Health Organization (WHO) regions – researchers assessed habit clustering, including exercise, healthy food consumption and screen time, finding that:

85% did not get enough exercise
80% did not eat enough fruit and vegetables
50% regularly consumed fast food
39% had too many soft drinks
32% spent excessive time on screens.

Overall, more than 92.5% of teenagers reported two or more unhealthy behaviours, which puts them at increased risk of developing chronic diseases like obesity, heart disease and diabetes.

Specifically, 7% of teenagers reported one unhealthy behaviour; 30% of teenagers had two; 36.5% had three; 21.5% had four; and 4.5% had five unhealthy behaviours. Across all WHO regions, less than 1% of teenagers exhibited no unhealthy behaviours.

It’s timely research in light of the South Australian government’s new ’LiveLighter’ campaign to tackle obesity.

Lead researcher, UniSA’s Dr Ming Li, says behaviours that are set up in teenage years lay the groundwork for behaviours in adulthood.

“The teenage years are a critical window for growth and development – physically, mentally, and emotionally – and they set the foundation for long-term health,” Dr Li says.

“But with junk food so readily available, and physical activity often replaced by screen time, more teens are picking up multiple unhealthy habits that could lead to serious health issues down the track.”

The study found distinct differences between regions. Teenagers in higher-income countries – including the Americas and Eastern Mediterranean – were more likely to report a higher number of unhealthy behaviours, with 13% of teenagers in these regions recording all five risk factors.

While Australian data was not specifically assessed, Dr Ling says that Australian teenagers would likely report multiple unhealthy lifestyle behaviours, skin to those seen in other high-income countries.

Dr Li says these trends are driven by broader societal shifts.

“Some of what we see comes down to rapid urbanisation, sedentary school environments, and limited access to safe recreational spaces, particularly in low- and middle-income countries,” Dr Li says.

“On top of this, taste preferences, household income, and limited availability of fresh produce – especially in disadvantaged areas – make healthy choices harder to access and maintain.”

While the study reports multiple unhealthy lifestyle behaviours for most teenagers, it also finds some protective factors that can help.

“When teenagers have supportive families and a supportive peer group, their risk of having four or more unhealthy behaviours reduces by 16% and 4% respectively,” Dr Li says “Similarly, food-secure households also reduce risk by 9%.”

Dr Li says the findings point to the urgent need for tailored, multilevel strategies that go beyond individual choices to address social and environmental conditions.

“It’s clear we need systemic action – better school-based physical activity programs, urban design that gives teens access to green spaces, policies that make healthy food affordable, and limits on junk food marketing to children,” Dr Li says.

“Ultimately, good health needs to be an easier, more accessible choice – not one that requires privilege, planning, and willpower.”

…………………………………………………………………………………………………………………………

Contact for interview: Dr Ming Li E: Ming.Li@unisa.edu.au
Media contact: Annabel Mansfield M: +61 479 182 489 E: Annabel.Mansfield@unisa.edu.au

MIL OSI News –

July 31, 2025

MIL-OSI USA: Senator Collins Introduces Circuit Court Nominee Joshua Dunlap of Scarborough at Judiciary Committee Hearing

US Senate News:

Source: United States Senator for Maine Susan Collins

Click HERE for a full-resolution image

Click HERE to watch and HERE to download video of Senator Collins introducing Mr. Dunlap

Washington, D.C. – Today, at a hearing of the Senate Judiciary Committee, U.S. Senator Susan Collins introduced Joshua Dunlap of Scarborough, Maine, who has been nominated to the U.S. Court of Appeals for the First Circuit.

Mr. Dunlap grew up in Vassalboro, Maine, and is currently a partner in the litigation group of Pierce Atwood LLP, in Portland, where he co-chairs the firm’s Appellate & Amici division. He has practiced at Pierce Atwood for over fifteen years, handling substantial civil litigation matters in both appellate and trial courts. He also chairs the Maine Appellate Rules Committee, to which he was appointed by the Maine Supreme Judicial Court. Prior to his work at Pierce Atwood, Mr. Dunlap clerked for the Honorable Paul J. Kelly, Jr., of the United States Court of Appeals for the Tenth Circuit. Mr. Dunlap graduated first in his class from Notre Dame Law School. He came to Washington for his hearing with several members of his family, including his parents, wife, and children.

Senator Collins:

“Chairman Grassley, Ranking Member Durbin, members of this committee, I’m pleased to appear before this distinguished committee today to wholeheartedly support Joshua Dunlap’s nomination to serve on the U.S. Court of Appeals for the First Circuit.

“Josh grew up in Vassalboro, Maine and now lives in Scarborough with his wife, Sydney, and their three children. If you look in back of me, you will see his three children, his wife, his parents, and numerous other members of his family. In fact, 20 of them, who are so proud of his nomination that they’ve made the trip to Washington. Josh graduated first in his class from Notre Dame Law School, where he received the law school’s highest honor, awarded to the student with the most distinguished academic record. He then clerked for Judge Paul Kelly of the U.S. Court of Appeals for the Tenth Circuit.

“In 2009, Josh joined the very well-respected law firm Pierce Atwood in Portland, Maine. During his 16 years at the firm, he has specialized in complex civil litigation matters and currently serves as co-chair of the firm’s Appellate & Amicus division. Josh is admitted to practice in multiple U.S. Courts of Appeal and before the U.S. Supreme Court. He has also assisted special masters in three original jurisdiction proceedings before the U.S. Supreme Court. Finally, Josh also chairs the Maine Appellate Rules Committee to which he was appointed by the Maine Supreme Judicial Court. This impressive experience, coupled with his extraordinary intelligence and integrity, makes Josh exceptionally well-qualified for a seat on the First Circuit. His substantial appellate litigation experience will bring a practitioner’s perspective to the court.

“The committee has already received many compelling letters of support for this nominee, and I would like to highlight a couple of them. A diverse group of faculty and alumni of Notre Dame Law School who taught Josh or studied alongside him have praised his, “respect for differing views” and “deep appreciation for the rule of law.” A letter signed by 19 leading Maine attorneys, who described themselves as having a broad spectrum of political views and legal philosophies, wrote that Josh has all the qualities the finest judge’s exhibit; he is hardworking, courteous and judicial in temperament, very smart, and of sterling character with a commitment to fairness and the rule of law.

“Mr. Chairman, before I conclude, I would like to thank Judge William Kayatta, whom Josh has been nominated to replace, for his outstanding service to the First Circuit. I joined in recommending him to President Obama, and had the honor of introducing Judge Kayatta to this committee. Now, it is my honor to recommend Josh, who actually worked with Judge Kayatta early in his tenure at Pierce Atwood, to this committee. I am confident that, if confirmed, Josh will serve Maine and the nation extraordinarily well in this critical role.

“For these reasons, I urge the committee to support his nomination, and I appreciate this opportunity to introduce him to the committee.”

MIL OSI USA News –

July 31, 2025

MIL-OSI USA: Baldwin, Capito, Hassan Lead Bipartisan Bill to Deliver First Responders with Training and Tools to Prevent Overdose Deaths

US Senate News:

Source: United States Senator for Wisconsin Tammy Baldwin

WASHINGTON, D.C. – Today, U.S. Senators Tammy Baldwin (D-WI), Shelley Moore Capito (R-WV), and Maggie Hassan (D-NH) introduced the Safe Response Act, bipartisan legislation to reauthorize a grant program that allows states, local government entities, and Tribes to train and provide resources to first responders to respond to drug overdoses.

“The opioid crisis has left thousands of families across Wisconsin with an empty seat at the dinner table. As we start to turn the tide on this epidemic, we need to double down on what is working and ensure communities have the tools they need to reverse overdoses and poisonings,” said Senator Baldwin. “I’m proud to back this bipartisan bill to ensure first responders have the training they need to use lifesaving tools like Narcan and protect Wisconsin families from the heartbreak of losing a loved one too soon.”

“West Virginians know all too well the devastation and heartbreak drug overdoses cause in our communities. That’s why it is essential Congress provides the resources and training our first responders need to administer life-saving overdose reversal drugs and keep themselves safe in the process. I’m proud to join my colleagues in reintroducing this legislation that will equip our first responders with the necessary tools to save more lives,” said Senator Capito.

“Fire fighters, paramedics, police officers, and other first responders are on the frontlines fighting the opioid epidemic and we must keep working to ensure that they have the resources and support that they need,” said Senator Hassan. “This bipartisan legislation will help to ensure that more first responders in New Hampshire and across the country have access to training on how to use overdose reversal drugs like naloxone to save more lives.”

According to the Centers for Disease Control (CDC), there were 80,391 drug overdose deaths in the United States in 2024. Of those, over 50,000 overdose deaths were due to opioids, including fentanyl. This marked a sharp decline from the previous year — a decrease of 26.9% from the 110,037 deaths estimated in 2023 – in part due to the availability of opioid reversal drugs like naloxone.

The 2018 SUPPORT Act included a grant program to provide funding for states, local government entities, Indian Tribes, and tribal organizations to train and provide resources to first responders to respond to an overdose. The Safe Response Act would reauthorize this grant program, included as part of the bipartisan SUPPORT Act, providing $57 million per year for fiscal years 2026 through 2030 for grants to first responders and those in key community sectors to respond to overdoses. Grants may be used to:

Ensure that first responders and other members of key community sectors have the knowledge and training to utilize overdose reversal devices or administer overdose reversal medications, such as naloxone;
Provide technical assistance and training about how first responders and other members of key community sectors, such as first SUD treatment providers and emergency medical service agencies, can better protect themselves in the event of exposure to such drugs;
Establish processes, protocols, and mechanisms for referral to appropriate treatment, which may include an outreach coordinator or team to connect individuals receiving opioid overdose reversal drugs to follow-up services; and
Educate first responders and members of key community sectors about the need to follow standard safe operating procedures in instances of exposure to fentanyl, carfentanil, and other dangerous and illicit drugs.

Senator Baldwin’s Safe Response Act has garnered strong support from local, state, and national public safety leaders and organizations, including the Wisconsin Professional Police Association, Wisconsin State Fire Chiefs Association, Racine Police Chief Alexander Ramirez, Milwaukee Fire Chief Aaron Lipski, Kenosha Fire Chief Daniel Tilton, Green Bay Metro Fire Chief Matthew Knott, Rock County Sheriff Curt Fell, Kenosha City Administrator and former Kenosha Chief of Police John Morrissey, Waukesha Mayor Shawn Reilly, Waukesha Fire Chief Robert Goplin, Waukesha Police Chief Dan Thompson, Madison Mayor Satya Rhodes-Conway, Mothers Against Prescription Drug Abuse (MAPDA), Big Cities Health Coalition, National Association of Police Organizations, National Council of Urban Indian Health, and Association of State and Territorial Health Officials (ASTHO).

“As Chief of the Milwaukee Fire Department, I know firsthand the importance of supporting our first responders with critical training and resources to prevent overdose deaths. We recognize the importance of the Safe Response Act as substance misuse and overdose continue to significantly impact our local communities,” said Aaron Lipski, Chief of the Milwaukee Fire Department and Chair of RISE – Drug-Free MKE. “Thank you, Senator Baldwin, for your dedication to the ongoing efforts of helping those in the community with substance use issues to receive the best possible immediate and follow-up care through training and valuable resources to present a positive outcome for all involved.”

“The reauthorization of the Safe Response Act is a smart and necessary allocation of funds. As someone who spent decades in law enforcement and now serves in city leadership, I’ve seen firsthand how critical it is for our first responders to have the right tools, training, and resources,” said John W. Morrissey, Kenosha City Administrator and former Kenosha Police Chief. “The increased funding—from $36 to $57 million annually—will make a real difference for communities like Kenosha. I fully support this legislation and urge Congress to move it forward.”

“The opioid epidemic is not an abstract concept for local communities in Wisconsin. We are on the frontlines and need the resources to respond to this public health crisis. Senator Baldwin’s leadership on the Safe Response Act is deeply appreciated. This is an important tool to support first responders and our residents,” said Madison Mayor Satya Rhodes-Conway.

“As Fire Chief of the Green Bay Metro Fire Department, I’m proud to support Senator Baldwin’s Safe Response Act. Every day, our firefighters and paramedics witness the impact that the opioid and fentanyl crisis has on our community. This legislation will give first responders the training and resources they need to save lives and stay safe while doing it,” said Matthew Knott, Chief of the Green Bay Metro Fire Department.

A one-pager on this legislation is available here. Full text of this legislation is available here.

MIL OSI USA News –

July 31, 2025

MIL-OSI: Indicio and Black Mountain Investment Group Partner to Modernize KYC and Digital Identity Verification for Exchanges, Banks, and Law Firms

Source: GlobeNewswire (MIL-OSI)

Salt Lake City, Utah, July 30, 2025 (GLOBE NEWSWIRE) — Today, Indicio and Black Mountain Investment Group (“BMIG”) announced a strategic partnership to revolutionize KYC and identity verification processes for the financial and legal industries.
This partnership combines Indicio’s market-leading decentralized identity and authenticated biometric technology with Black Mountain’s expertise in business solutions to create a much-needed bridge between traditional and decentralized finance that delivers scalable, fraud-resistant technologies for institutions operating in increasingly global and regulated markets.
Global regulatory changes are accelerating growth in the cross-border asset ecosystem and fueling the evolution of decentralized finance (DeFi). Indicio and Black Mountain have developed proprietary technology that allows for a new, decentralized approach to verify investor, institution, and asset identities. This KYC is critical to scaling transactions in secure, fraud-resistant, and compliant ways.
Indicio developed the most powerful decentralized digital identity solution in the marketplace by incorporating authenticated biometrics in Verifiable Credentials trust-anchored to a blockchain with real encryption. This significantly increases the level of identity assurance for remote onboarding, KYC, and digital transactions- which can now be performed more rapidly and reliably than ever before by investors and institutions through the use of this technology.
“Indicio has developed an architectural approach to digital identity that meets the rapidly evolving needs of conventional and decentralized finance around KYC, account access, and digital asset management,” said Heather Dahl, CEO of Indicio. “We’re really excited to work with Black Mountain Investment Group to advance secure, seamless, decentralized trust for global financial transactions.”
“Trusted digital identity verification is a serious catalyst for advancing the digital transformation of and unlocking liquidity in global finance,” remarks Elijah Levine, CEO of BMIG. “It’s all too often that you work with the biggest and best banks and exchanges and they still operate on outdated and cumbersome KYC verification standards that are also often restricted to US-based financial transactions. When we saw the work that Indicio has been doing with biometric authentication and tamper-proof digital credentials in travel, not only did we want to invest immediately in their main business, but we also recognized that their tech is shockingly translatable to the finance industry.”
“We see a path towards rapid scale and believe that this technology should be implemented immediately across the biggest and best institutions in global finance for their own internal protection and liability purposes, outside of the efficiencies and liquidity that will be immediately unlocked. This partnership is centered around delivering innovative solutions that integrate the very latest technology into the rapidly expanding market of secure, privacy-preserving global asset transfers.”
About Indicio
Indicio is a global leader in Verifiable Credentials, decentralized identity, and digital trust infrastructure. From powering national identity pilots to enabling seamless international travel, Indicio helps governments and businesses build data and identity systems that are secure, privacy-preserving, and interoperable across borders and industries.
About Black Mountain Investment Group

Black Mountain Investment Group (“BMIG”) is a technology-driven back-office platform and entrepreneurial ecosystem designed to power the next generation of funds and businesses. BMIG provides operational support, strategic insight, and scalable infrastructure, empowering organizations to navigate growth and innovation at the intersection of traditional and decentralized finance.

Elijah Levine
hello@blackmountainig.com
blackmountainig.com
Indicio.tech

The MIL Network –

July 31, 2025

MIL-OSI: Gran Tierra Energy Inc. Reports Second Quarter 2025 Results & Another Quarter of Record Production

Source: GlobeNewswire (MIL-OSI)

Achieved Record Total Company Average Quarterly Production of 47,196 boepd
Funds Flow From Operations⁽¹⁾of $54 million, Adjusted EBITDA⁽¹⁾of $77 million and Return to Free Cash Flow
Signed Mandate Letter for Funding of Up to $200 Million
Entered into Binding Agreement to Exit the UK North Sea
Achieved Company Record Total of 32 Million Hours Without a Lost Time Injury
Recorded Operating Costs per boe of $13.42 for the Quarter – the Lowest Since The First Quarter of 2022

CALGARY, Alberta, July 30, 2025 (GLOBE NEWSWIRE) — Gran Tierra Energy Inc. (“Gran Tierra” or the “Company”) (NYSE American:GTE) (TSX:GTE) (LSE: GTE) announced the Company’s financial and operating results for the quarter ended June 30, 2025 (the “Quarter”) and provided an operational update. All dollar amounts are in United States (“U.S.”) dollars and all production volumes are on an average working interest before royalties (“WI”) basis unless otherwise indicated. Production is expressed in barrels (“bbl”) of oil equivalent (“boe”) per day (“boepd” or “boe/d”) and are based on WI sales before royalties. For per boe amounts based on net after royalty (“NAR”) production, see Gran Tierra’s Quarterly Report on Form 10-Q filed July 30, 2025.

Message to Shareholders

Gary Guidry, President and Chief Executive Officer of Gran Tierra, commented: “Gran Tierra delivered record-setting production this quarter, reflecting the strength of our diversified portfolio and consistent operational execution across Colombia, Ecuador, and Canada.

In Ecuador, we are building on the momentum of our Iguana Block discoveries with the planned drilling of two high-impact exploration wells in the Charapa Block later this year. In Colombia, the successful development drilling at Costayaco and Cohembi, along with the strong early waterflood response in Cohembi’s north area, underscores the ongoing potential of our core assets and validates our disciplined approach to reservoir management. In Acordionero, our proactive waterflood management, surface facility upgrades, pump upsizes and ongoing improvement in electrical submersible pump run lives continue to mitigate base decline.

In Canada, our Montney and Clearwater assets are delivering encouraging results, with three gross-wells (1.2 net) brought on stream in the Quarter, outperforming expectations. These outcomes further reinforce our strategy of disciplined capital allocation and balanced growth as we focus on generating long-term value for our stakeholders.

We continue to optimize our portfolio with the signed disposition of the UK North Sea assets, which is expected to close in the third quarter of 2025.”

Operational Update:

Safety: Since 2022, Gran Tierra has achieved a record of 32 million person-hours equating to more than 3 years without a lost time injury.
Ecuador
- Building on the successful discoveries in the Iguana Block during the first quarter of 2025, civil works are currently underway to support the drilling of the final two wells under Gran Tierra’s exploration commitments in the country. These wells are planned for the Charapa Block in the Conejo prospect, with drilling expected to commence toward the end of the third quarter of 2025.
Colombia
- Gran Tierra successfully drilled the first of three development wells planned for 2025 in the northern area of the Costayaco field. The Costayaco-63 well was perforated in four productive sands, stimulated, and placed on immediate production. The well is currently producing ~800 bbls of oil per day (“bopd”) with a 48% watercut compared to an average field watercut of 92%. In July, the second well—Costayaco-64—was drilled, stimulated and completed. The well is currently producing ~1,300 bopd with a 13% watercut. The final well, Costayaco-65, was spud on July 20, 2025 and is scheduled to be brought on production in August 2025.
- During the Quarter the remaining two wells of the 2025 five well Cohembi program were brought onto production. The average drilling cost of the five wells was ~$3.0 million per well, representing a 47% reduction from the prior operator’s average last five wells drilled in 2017/18. As part of the program and to support pressure, water injection began on May 30, 2025. A strong waterflood response and increase of greater than 2,600 bopd gross across the northern part of the field has been observed and continues to improve.
- The Cristobal well in LLA-85 was drilled below budget to total depth (“TD”) and abandoned, fulfilling all the commitments on the block.
- In Acordionero, production in the Quarter averaged ~14,200 bopd compared to ~13,800 bopd in the first quarter of 2025 (the “Prior Quarter”). Increases in base production were achieved by increasing total fluid production through planned electrical submersible pump upsizes, additional surface injection capacity allowing for continued growth of total fluid production and water injection. Record highs were achieved in both total fluid production (~89,400 bbls/day) and water injection (~85,000 bbls/day) during the Quarter.
Canada
- In the Simonette, the first two (1.0 net) Lower Montney wells were completed successfully and brought on stream on April 5, 2025. Results from both wells are currently out-performing management’s current type curves. The third Montney well was spud on June 29, 2025 and reached TD on July 18, 2025. The fourth Montney well was spud on July 22, 2025 and is expected to reach total depth in the first half of August.

Enhanced Liquidity:

Gran Tierra is pleased to announce it has signed a mandate letter with a syndicate of banks for a $200 million prepayment facility backed by crude oil deliveries. The Company is progressing toward full documentation, with closing expected in the third quarter of 2025 and funding anticipated shortly thereafter. The facility is structured to enhance financial flexibility, support long-term capital planning, and optimize the Company’s debt maturity profile. Further details of the prepayment will be announced in due course once final terms are agreed upon.
Separately, Gran Tierra recently completed the semi-annual redetermination of its Canadian credit facility, with lenders confirming an unchanged borrowing base of C$100 million. This outcome reflects the continued strength and stability of the Company’s Canadian asset base. The facility provides C$50 million in available commitments, comprised of a C$35 million syndicated facility and a C$15 million operating facility with a maturity date of October 31, 2026. The next redetermination is scheduled on or before November 30, 2025.
Gran Tierra also employs a disciplined, risk-managed hedging strategy designed to protect cash flow, support capital planning, and enhance financial stability across commodity cycles. The Company utilizes a diversified mix of oil and gas hedges that provide downside protection while preserving upside exposure. This proactive approach contributed to a $14 million derivative hedging gain booked during the Quarter. The Company also maintains a rolling 12-month hedging program to further mitigate volatility:
- South American Oil Hedges (Brent): For the second half of 2025, Gran Tierra has hedged approximately 50% of its South American oil production with a weighted average floor of $63.16 per barrel and a ceiling of $76.50 per barrel. For the first half of 2026 the Company has hedged approximately 33% of its South American oil production with a weighted average floor of $61.67 per barrel and a ceiling of $75.58.
- Canadian Oil Hedges (West Texas Intermediate): For the second half of 2025, Gran Tierra has hedged approximately 60% of its Canadian oil production with a weighted average floor of $61.67 per barrel and a ceiling of $72.37 per barrel. For the first half of 2026 the Company has hedged approximately 50% of its Canadian oil production with a weighted average floor of $56.82 per barrel and a ceiling of $72.01.
- Canadian Gas Hedges (AECO): For the second half of 2025, Gran Tierra has hedged approximately 40% of its Canadian gas production with a weighted average floor of $2.82 per GJ and a ceiling of $2.96 per GJ.
- FX Hedges (COP to USD): Starting in April 2025, Gran Tierra entered into a 12-month, $10 million per month hedging program for the COP to USD exchange rate. The hedges have a floor of 4,430 and a ceiling of 4,705.

Key Highlights of the Quarter:

Production: Gran Tierra’s total average WI production was 47,196 boepd, which was 44% higher than the second quarter of 2024 due to the production from the Canadian operations acquired on October 31, 2024 and positive exploration well drilling results in Ecuador. Total average WI production was 1% higher than the Prior Quarter as a result of successful drilling in Simonette, Cohembi infill drilling and waterflood management, strong Acordionero performance and continued exploration success in Ecuador from the Iguana wells. Working interest sales in the Quarter decreased to 45,727 boepd primarily due to the deferral of 143,730 barrels of Ecuador oil production, which were held in inventory at the end of June and subsequently sold in July.
Net Income (Loss): Gran Tierra incurred a net loss of $13 million, compared to a net loss of $19 million in the Prior Quarter and net income of $36 million in the second quarter of 2024.
Adjusted EBITDA⁽¹⁾: Adjusted EBITDA⁽¹⁾ was $77 million compared to $85 million in the Prior Quarter and $103 million in the second quarter of 2024. Twelve-month trailing net debt⁽¹⁾ to adjusted EBITDA⁽¹⁾ was 2.3 times (only accounts for eight months of Canadian operations adjusted EBITDA) and the Company continues to have a long-term target ratio of 1.0 times.
Funds Flow from Operations⁽¹⁾: Funds flow from operations⁽¹⁾ was $54 million ($1.53 per share), up 17% from the second quarter of 2024 and down 3% from the Prior Quarter. Brent price decreased by 11% per bbl compared to the Prior Quarter and our cash netback⁽¹⁾ decreased by 1% illustrating the resiliency of the portfolio.
Net Cash Provided by Operating Activities: Net cash provided by operating activities was $35 million ($0.98 per share), down 53% from the Prior Quarter and down 53% from the second quarter of 2024.
Cash and Debt: As of June 30, 2025, the Company had a cash balance of $61 million, total debt of $807 million and net debt⁽¹⁾ of $746 million. During the Quarter, the Company drew a total of $45 million on its credit facilities to fund capital expenditures. There were significant capital expenditures in the first quarter, amounting to approximately 40% of budgeted capital expenditures for the year, which were paid in the Quarter resulting in the Company drawing on its credit facilities. We currently forecast the facilities to have a zero balance by the end of the year. In addition to the $61 million cash on hand as of June 30, 2025, the Company currently has approximately $112 million in credit and lending facilities with $47 million drawn as of June 30, 2025.
Share Buybacks: Gran Tierra repurchased 239,754 shares of common stock during the Quarter. From January 1, 2023, to July 28, 2025, the Company repurchased approximately 5.2 million shares, or 15% of shares issued and outstanding on January 1, 2023.

Additional Key Financial Metrics:

Capital Expenditures: Capital expenditures were $51 million during the Quarter which were lower than the $95 million in the Prior Quarter and lower than $61 million in the second quarter of 2024. During the Quarter the majority of capital expenditures were incurred in Colombia on Cohembi drilling and infrastructure.
Oil, Natural Gas and Natural Gas Liquids (“NGL”) Sales: Gran Tierra generated sales of $152 million, down 8% from the second quarter of 2024 primarily as a result of a 22% decrease in Brent pricing, partially offset by 43% higher sales volumes due to higher production and lower Castilla, Oriente, and Vasconia oil differentials. Oil sales decreased 11% from the Prior Quarter primarily due to an 11% decrease in Brent price, partially offset by lower Castilla, Oriente, and Vasconia oil differentials.
South American Quality and Transportation Discounts: The Company’s quality and transportation discounts in South America per bbl were lower during the Quarter at $10.30, compared to $11.58 in the Prior Quarter and $12.79 in the second quarter of 2024. The Castilla oil differential per bbl tightened to $4.73, down from $5.34 in the Prior Quarter and $8.21 in the second quarter of 2024 (Castilla is the benchmark for the Company’s Middle Magdalena Valley Basin oil production). The Vasconia differential per bbl tightened to $1.71, down from $2.27 in the Prior Quarter, and $4.00 in the second quarter of 2024. The Ecuadorian benchmark, Oriente, per bbl was $7.26, down from $7.65 in the Prior Quarter and $8.38 in the second quarter of 2024. The current⁽²⁾ differentials are approximately $4.38 per bbl for Castilla, $1.38 per bbl for Vasconia, and $7.64 per bbl for Oriente.
Operating Expenses: On a per boe basis, operating expenses decreased by 17% when compared to the second quarter of 2024 and 16% when compared to the Prior Quarter, primarily due to lower workover activities and lower lifting costs associated with inventory build-up in Ecuador, power generation, and equipment rentals. This was the lowest operating expense per boe achieved since the first quarter of 2022. Total operating expenses decreased by 17% to $56 million, compared to the Prior Quarter, largely driven by lower workover activities and reduced lifting costs related to power generation, equipment rental, and inventory fluctuation in Ecuador. Compared to the second quarter of 2024, total operating expenses increased by 19% from $47 million, primarily due to the addition of Canadian operations and the ramp-up of activity in Ecuador. The increase in total operating costs is commensurate with the 44% increase in production.
Transportation Expenses: The Company’s transportation expenses increased by 10% to $8 million, compared to the Prior Quarter’s transportation expenses of $7 million as a result of incremental sales volumes transported by Canadian operations resulting in higher tolls. When compared to the second quarter of 2024 transportation expenses increased from $6 million due to new Canadian operations, higher sales volumes transported in Ecuador, partially offset by lower sales volumes transported in Colombia.
Operating Netback⁽¹⁾⁽³⁾: The Company’s operating netback(1)(3) was $21.39 per boe, down 6% from the Prior Quarter and down 45% from the second quarter of 2024, primarily as a result of a decrease in oil pricing. The decrease from the second quarter of 2024 is a result in the change in the Company’s production mix with the addition of the Canadian assets.
General and Administrative (“G&A”) Expenses: G&A expenses before stock-based compensation were $3.48 per boe, up from $2.86 per boe in the Prior Quarter, due to the timing of certain annual corporate expenses. G&A expenses before stock-based compensation were down from $3.77 per boe, compared to the second quarter of 2024 as a result of higher sales volumes from the inclusion of Canadian operations in the Quarter.
Cash Netback⁽¹⁾: Cash netback⁽¹⁾ per boe decreased to $12.95, compared to $13.04 in the Prior Quarter, primarily as a result of lower operating netback⁽¹⁾ and were offset by lower current income tax expense and positive cash settlement on derivative instruments. Compared to one year ago, cash netback⁽¹⁾ per boe decreased by $2.90 from $15.85 per boe as a result of lower operating netback⁽¹⁾ while being offset by lower current tax expense.

Financial and Operational Highlights (all amounts in $000s, except per share and boe amounts)

Consolidated Financial Data	Three Months Ended June 30,		Three Months Ended March 31,	Six Months Ended June 30,
	2025	2024	2025	2025	2024

Net (Loss) Income	$(12,741)	$36,371	$(19,280)	$(32,021)	$36,293
Per Share – Basic and Diluted	$(0.36)	$1.16	$(0.54)	$(0.90)	$1.15

Oil, Natural Gas and NGL Sales	$152,481	$165,609	$170,533	$323,014	$323,186
Operating Expenses	(55,855)	(47,035)	(67,354)	(123,209)	(95,501)
Transportation Expenses	(7,618)	(5,690)	(6,911)	(14,529)	(10,274)
Operating Netback ⁽¹⁾⁽³⁾	$89,008	$112,884	$96,268	$185,276	$217,411

G&A Expenses Before Stock-Based Compensation	$14,460	$10,967	$12,143	$26,603	$21,749
G&A Stock-Based Compensation Expense (Recovery)	546	6,160	(517)	29	9,521
G&A Expenses, Including Stock Based Compensation	$15,006	$17,127	$11,626	$26,632	$31,270

Adjusted EBITDA ⁽¹⁾	$76,987	$103,004	$85,162	$162,149	$197,796

EBITDA ⁽¹⁾	$84,908	$101,187	$79,710	$164,618	$193,078

Net Cash Provided by Operating Activities	$34,677	$73,233	$73,230	$107,907	$134,060

Funds Flow from Operations ⁽¹⁾	$53,906	$46,167	$55,344	$109,250	$120,474

Capital Expenditures (Before Changes in Working Capital)	$51,170	$61,273	$94,727	$145,897	$116,604

Free Cash Flow ⁽¹⁾	$2,736	$(15,106)	$(39,383)	$(36,647)	$3,870

Average Daily Production (boe/d)
WI Production Before Royalties	47,196	32,776	46,647	46,923	32,509
Royalties	(7,396)	(6,774)	(8,084)	(7,738)	(6,586)
Production NAR	39,800	26,002	38,563	39,185	25,923
Decrease (Increase) in Inventory	(1,469)	(811)	461	(509)	(288)
Sales	38,331	25,191	39,024	38,676	25,635
Royalties, % of WI Production Before Royalties	16%	21%	17%	16%	20%

Cash Netback ($/boe )⁽¹⁾
Average Realized Price before Royalties	43.71	72.24	48.55	46.14	69.27
Royalties	(7.07)	(15.31)	(8.33)	(7.69)	(14.16)
Average Realized Price	36.64	56.93	40.22	38.45	55.11
Transportation Expenses	(1.83)	(1.96)	(1.63)	(1.73)	(1.75)
Average Realized Price Net of Transportation Expenses	34.81	54.97	38.59	36.72	53.36
Operating Expenses	(13.42)	(16.17)	(15.89)	(14.67)	(16.29)
Operating Netback ⁽¹⁾⁽³⁾	21.39	38.80	22.70	22.05	37.07
G&A Expenses Before Stock-Based Compensation	(3.48)	(3.77)	(2.86)	(3.17)	(3.71)
Realized Foreign Exchange (Loss) Gain	(0.14)	0.37	(0.51)	(0.33)	(0.06)
Cash Settlement on Derivative Instruments	0.39	—	0.10	0.25	—
Interest Expense, Excluding Amortization of Debt Issuance Costs	(4.87)	(5.38)	(4.58)	(4.72)	(5.24)
Interest Income	0.06	0.35	0.10	0.08	0.29
Other Gain	0.09	—	—	0.04	—
Net Lease Payments	0.04	0.02	0.04	0.04	0.07
Current Income Tax Expense	(0.53)	(14.54)	(1.95)	(1.25)	(7.88)
Cash Netback ⁽¹⁾	$12.95	$15.85	$13.04	$12.99	$20.54

Share Information (000s)
Common Stock Outstanding, End of Period	35,289	31,022	35,524	35,289	31,022
Weighted Average Number of Shares of Common Stock Outstanding – Basic and Diluted	35,335	31,282	35,777	35,555	31,547

South American Operational Information	Three Months Ended June 30,		Three Months Ended March 31,	Six Months Ended June 30,
	2025	2024	2025	2025	2024
Operating Netback ⁽¹⁾⁽³⁾
Oil Sales	$118,187	$165,609	$138,671	$256,858	$323,186
Operating Expenses	(42,554)	(47,035)	(50,827)	(93,381)	(95,501)
Transportation Expenses	(4,176)	(5,690)	(4,304)	(8,480)	(10,274)
Operating Netback ⁽¹⁾⁽³⁾	$71,457	$112,884	$83,540	$154,997	$217,411

Capital Expenditures (Before Changes in Working Capital)	$49,327	$60,806	$64,984	$114,311	$116,137

Average Daily Production (boe/d)
WI Production Before Royalties	29,700	32,776	29,686	29,693	32,509
Royalties	(5,209)	(6,774)	(5,844)	(5,525)	(6,586)
Production NAR	24,491	26,002	23,842	24,168	25,923
Decrease (Increase) in Inventory	(1,469)	(811)	461	(509)	(288)
Sales	23,022	25,191	24,303	23,659	25,635
Royalties, % of WI Production Before Royalties	18%	21%	20%	19%	20%

Operating Netback ($/boe) ⁽¹⁾⁽³⁾
Brent	$66.71	$85.03	$74.98	$70.81	$83.42
Quality and Transportation Discount	(10.30)	(12.79)	(11.58)	(10.82)	(14.15)
Royalties	(10.41)	(15.31)	(12.29)	(11.36)	(14.16)
Average Realized Price	46.00	56.93	51.11	48.63	55.11
Transportation Expenses	(1.63)	(1.96)	(1.59)	(1.61)	(1.75)
Average Realized Price Net of Transportation Expenses	44.37	54.97	49.52	47.02	53.36
Operating Expenses	(16.56)	(16.17)	(18.73)	(17.68)	(16.29)
Operating Netback ⁽¹⁾⁽³⁾	$27.81	$38.80	$30.79	$29.34	$37.07

Canadian Operational Information ⁽⁴⁾	Three Months Ended June 30,		Three Months Ended March 31,	Six Months Ended June 30,
	2025	2024	2025	2025	2024
Operating Netback ⁽¹⁾⁽³⁾
Oil Sales	$23,196	$—	$21,269	$44,465	$—
Natural Gas Sales	6,894	—	7,561	14,455	—
NGL Sales	6,364	—	7,997	14,361	—
Royalties	(2,158)	—	(4,966)	(7,124)	—
Oil, Natural Gas and NGL Sales After Royalties	$34,296	$—	$31,861	$66,157	$—
Operating Expenses	(13,301)	—	(16,527)	(29,828)	—
Transportation Expenses	(3,442)	—	(2,607)	(6,049)	—
Operating Netback ⁽¹⁾⁽³⁾	$17,553	$—	$12,727	$30,280	$—

Capital Expenditures (Before Changes in Working Capital)	$1,796	$—	$29,360	$31,156	$—

Average Daily Production
Crude Oil (bbl/d)	4,335	—	3,623	3,981	—
Natural Gas (mcf/d)	50,124	—	49,860	49,992	—
NGLs (bbl/d)	4,807	—	5,029	4,917	—
WI Production Before Royalties (boe/d)	17,496	—	16,961	17,230	—
Royalties (boe/d)	(2,187)	—	(2,240)	(2,213)	—
Production NAR (boe/d)	15,309	—	14,721	15,017	—
Sales (boe/d)	15,309	—	14,721	15,017	—
Royalties, % of WI Production Before Royalties	13%	—%	13%	13%	—%

Benchmark Prices
West Texas Intermediate ($/bbl)	63.81	80.82	71.47	67.60	78.95
AECO Natural Gas Price (C$/GJ)	1.60	1.12	2.05	1.82	1.74

Average Realized Price
Crude Oil ($/bbl)	58.80	—	65.23	61.71	—
Natural Gas ($/mcf)	1.51	—	1.69	1.60	—
NGLs ($/bbl)	14.55	—	17.67	16.14	—

Operating Netback ($/boe) ⁽¹⁾⁽³⁾
Average Realized Price	$22.90	$—	$24.12	$23.50	$—
Royalties	(1.36)	—	(3.25)	(2.28)	—
Transportation Expenses	(2.16)	—	(1.71)	(1.94)	—
Operating Expenses	(8.35)	—	(10.83)	(9.56)	—
Operating Netback ⁽¹⁾⁽³⁾	$11.03	$—	$8.33	$9.72	$—

_{⁽¹⁾ Funds flow from operations, operating netback, net debt, cash netback, earnings before interest, taxes and depletion, depreciation and accretion (“DD&A”) (“EBITDA”) and EBITDA adjusted for non-cash lease expense, lease payments, foreign exchange gains or losses, stock-based compensation expense, other gains or losses, transaction costs and financial instruments gains or losses (“Adjusted EBITDA”), cash flow and free cash flow are non-GAAP measures and do not have standardized meanings under generally accepted accounting principles in the United States of America (“GAAP”). Cash flow refers to funds flow from operations. Free cash flow refers to funds flow from operations less capital expenditures. Refer to “Non-GAAP Measures” in this press release for descriptions of these non-GAAP measures and, where applicable, reconciliations to the most directly comparable measures calculated and presented in accordance with GAAP.}
_{⁽²⁾ Gran Tierra’s third quarter-to-date 2025 total average differentials and average production are for the period from July 1 to July 30, 2025.}
_{⁽³⁾ Operating netback as presented is defined as oil sales less operating and transportation expenses. See the table titled Financial and Operational Highlights above for the components of consolidated operating netback and corresponding reconciliation.}
_{⁽⁴⁾ Gran Tierra entered Canada with the acquisition of i3 Energy which closed October 31, 2024, therefore no comparative data is provided for the corresponding periods of 2024.}

Conference Call Information:

Gran Tierra will host its second quarter 2025 results conference call on Thursday, July 31, 2025, at 9:00 a.m. Mountain Time, 11:00 a.m. Eastern Time. Interested parties may access the conference call by registering at the following link: https://register-conf.media-server.com/register/BId33e377f2b494c3c95a7fbd1df59627e. The call will also be available via webcast at www.grantierra.com.

Corporate Presentation:

Gran Tierra’s Corporate Presentation has been updated and is available on the Company website at www.grantierra.com.

Contact Information

For investor and media inquiries please contact:

Gary Guidry
President & Chief Executive Officer

Ryan Ellson
Executive Vice President & Chief Financial Officer

+1-403-265-3221

info@grantierra.com

About Gran Tierra Energy Inc.

Gran Tierra Energy Inc., together with its subsidiaries is an independent international energy company currently focused on oil and natural gas exploration and production in Canada, Colombia and Ecuador. The Company is currently developing its existing portfolio of assets in Canada, Colombia and Ecuador and will continue to pursue additional new growth opportunities that would further strengthen the Company’s portfolio. The Company’s common stock trades on the NYSE American, the Toronto Stock Exchange and the London Stock Exchange under the ticker symbol GTE. Additional information concerning Gran Tierra is available at www.grantierra.com. Except to the extent expressly stated otherwise, information on the Company’s website or accessible from our website or any other website is not incorporated by reference into and should not be considered part of this press release. Investor inquiries may be directed to info@grantierra.com or (403) 265-3221.

Gran Tierra’s Securities and Exchange Commission (the “SEC”) filings are available on the SEC website at http://www.sec.gov. The Company’s Canadian securities regulatory filings are available on SEDAR+ at http://www.sedarplus.ca and UK regulatory filings are available on the National Storage Mechanism website at https://data.fca.org.uk/#/nsm/nationalstoragemechanism.

Forward Looking Statements and Legal Advisories:

This press release contains opinions, forecasts, projections, and other statements about future events or results that constitute forward-looking statements within the meaning of the United States Private Securities Litigation Reform Act of 1995, Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended, and financial outlook and forward looking information within the meaning of applicable Canadian securities laws (collectively, “forward-looking statements”). All statements other than statements of historical facts included in this press release regarding our business strategy, plans and objectives of our management for future operations, capital spending plans and benefits of the changes in our capital program or expenditures, our liquidity and financial condition, and those statements preceded by, followed by or that otherwise include the words “expect,” “plan,” “can,” “will,” “should,” “guidance,” “forecast,” “budget,” “estimate,” “signal,” “progress”, “anticipates” and “believes,” derivations thereof and similar terms identify forward-looking statements. In particular, but without limiting the foregoing, this press release contains forward-looking statements regarding: : the Company’s expectations regarding committed funding (including but not limited to the signing of a mandate for prepayment structure backed by crude oil deliveries), liquidity and its leverage ratio target, the Company’s plans regarding strategic investments, acquisitions, dispositions, synergies, and growth, the Company’s drilling program and capital expenditures and the Company’s expectations of commodity prices, exploration and production trends and its positioning for 2025. The forward-looking statements contained in this press release reflect several material factors and expectations and assumptions of Gran Tierra including, without limitation, that Gran Tierra will continue to conduct its operations in a manner consistent with its current expectations, pricing and cost estimates (including with respect to commodity pricing and exchange rates), the general continuance of assumed operational, regulatory and industry conditions in Canada, Colombia and Ecuador, and the ability of Gran Tierra to execute its business and operational plans in the manner currently planned.

Among the important factors that could cause our actual results to differ materially from the forward-looking statements in this press release include, but are not limited to: our ability to successfully integrate the assets and operations of i3 Energy Plc (“i3Energy”) and realize the anticipated benefits and operating synergies expected from the 2024 acquisition of i3 Energy; certain of our operations are located in South America and unexpected problems can arise due to guerilla activity, strikes, local blockades or protests; technical difficulties and operational difficulties may arise which impact the production, transport or sale of our products; other disruptions to local operations; global health events; global and regional changes in the demand, supply, prices, differentials or other market conditions affecting oil and gas, including inflation and changes resulting from actual or anticipated tariffs and trade policies, global health crises, geopolitical events, including the conflicts in Ukraine and the Middle East, or from the imposition or lifting of crude oil production quotas or other actions that might be imposed by OPEC and other producing countries and the resulting company or third-party actions in response to such changes; changes in commodity prices, including volatility or a prolonged decline in these prices relative to historical or future expected levels; the risk that current global economic and credit conditions may impact oil prices and oil consumption more than we currently predict, which could cause further modification of our strategy and capital spending program; prices and markets for oil and natural gas are unpredictable and volatile; the effect of hedges; the accuracy of productive capacity of any particular field; geographic, political and weather conditions can impact the production, transport or sale of our products; our ability to execute our business plan, which may include acquisitions, and realize expected benefits from current or future initiatives; the risk that unexpected delays and difficulties in developing currently owned properties may occur; the ability to replace reserves and production and develop and manage reserves on an economically viable basis; the accuracy of testing and production results and seismic data, pricing and cost estimates (including with respect to commodity pricing and exchange rates); the risk profile of planned exploration activities; the effects of drilling down-dip; the effects of waterflood and multi-stage fracture stimulation operations; the extent and effect of delivery disruptions, equipment performance and costs; actions by third parties; the timely receipt of regulatory or other required approvals for our operating activities; the failure of exploratory drilling to result in commercial wells; unexpected delays due to the limited availability of drilling equipment and personnel; volatility or declines in the trading price of our common stock or bonds; the risk that we do not receive the anticipated benefits of government programs, including government tax refunds; our ability to access debt or equity capital markets from time to time to raise additional capital, increase liquidity, fund acquisitions or refinance debt; the risk that we are unable to successfully negotiate final terms and close an anticipated prepayment structure backed by crude oil deliveries, our ability to comply with financial covenants in our indentures and make borrowings under our credit agreements; and the risk factors detailed from time to time in Gran Tierra’s periodic reports filed with the Securities and Exchange Commission, including, without limitation, under the caption “Risk Factors” in Gran Tierra’s Annual Report on Form 10-K for the year ended December 31, 2024 filed February 24, 2025 and its other filings with the SEC. These filings are available on the SEC website at http://www.sec.gov and on SEDAR+ at www.sedarplus.ca.

The forward-looking statements contained in this press release are based on certain assumptions made by Gran Tierra based on management’s experience and other factors believed to be appropriate. Gran Tierra believes these assumptions to be reasonable at this time, but the forward-looking statements are subject to risk and uncertainties, many of which are beyond Gran Tierra’s control, which may cause actual results to differ materially from those implied or expressed by the forward looking statements. The risk that the assumptions on which the 2025 outlook are based prove incorrect may increase the later the period to which the outlook relates. All forward-looking statements are made as of the date of this press release and the fact that this press release remains available does not constitute a representation by Gran Tierra that Gran Tierra believes these forward-looking statements continue to be true as of any subsequent date. Actual results may vary materially from the expected results expressed in forward-looking statements. Gran Tierra disclaims any intention or obligation to update or revise any forward-looking statements, whether as a result of new information, future events or otherwise, except as expressly required by applicable law. In addition, historical, current and forward-looking sustainability-related statements may be based on standards for measuring progress that are still developing, internal controls and processes that continue to evolve, and assumptions that are subject to change in the future.

The forecasts of expected liquidity to address bond amortization in the fourth quarter of 2026 and that Gran Tierra’s credit facilities would have a zero balance by the end of the year may be considered to be future-oriented financial information or a financial outlook for the purposes of applicable Canadian securities laws. Financial outlook and future-oriented financial information contained in this press release about prospective financial performance, financial position or cash flows are provided to give the reader a better understanding of the potential future performance of the Company in certain areas and are based on assumptions about future events, including economic conditions and proposed courses of action, based on management’s assessment of the relevant information currently available, and to become available in the future. In particular, this press release contains projected operational and financial information for the end of 2025 and the fourth quarter of 2026. These projections contain forward-looking statements and are based on a number of material assumptions and factors set out above. Actual results may differ significantly from the projections presented herein. The actual results of Gran Tierra’s operations for any period could vary from the amounts set forth in these projections, and such variations may be material. See above for a discussion of the risks that could cause actual results to vary. The future-oriented financial information and financial outlooks contained in this press release have been approved by management as of the date of this press release. Readers are cautioned that any such financial outlook and future-oriented financial information contained herein should not be used for purposes other than those for which it is disclosed herein. The Company and its management believe that the prospective financial information has been prepared on a reasonable basis, reflecting management’s best estimates and judgments, and represent, to the best of management’s knowledge and opinion, the Company’s expected course of action. However, because this information is highly subjective, it should not be relied on as necessarily indicative of future results.

Non-GAAP Measures

This press release includes non-GAAP financial measures as further described herein. These non-GAAP measures do not have a standardized meaning under GAAP. Investors are cautioned that these measures should not be construed as alternatives to net income or loss, cash flow from operating activities or other measures of financial performance as determined in accordance with GAAP. Gran Tierra’s method of calculating these measures may differ from other companies and, accordingly, they may not be comparable to similar measures used by other companies. Each non-GAAP financial measure is presented along with the corresponding GAAP measure so as to not imply that more emphasis should be placed on the non-GAAP measure.

Operating netback, as presented, is defined as oil sales less operating and transportation expenses. See the table entitled Financial and Operational Highlights above for the components of consolidated operating netback and corresponding reconciliation.

Cash netback as presented is defined as net income or loss adjusted for DD&A expenses, deferred tax expense or recovery, stock-based compensation expense or recovery, amortization of debt issuance costs, non-cash lease expense, lease payments, unrealized foreign exchange gain or loss, other gain or loss and unrealized derivative instruments gain or loss. Management believes that operating netback and cash netback are useful supplemental measures for investors to analyze financial performance and provide an indication of the results generated by Gran Tierra’s principal business activities prior to the consideration of other income and expenses. A reconciliation from net income or loss to cash netback is as follows:

	Three Months Ended June 30,						Three Months Ended March 31,			Six Months Ended June 30,
Cash Netback – (Non-GAAP) Measure ($000s)		2025			2024			2025			2025			2024
Net (Loss) Income	$	(12,741	)	$	36,371		$	(19,280	)	$	(32,021	)	$	36,293
Adjustments to reconcile net loss or income to cash netback
DD&A expenses		68,635			55,490			72,202			140,837			111,640
Deferred tax expense (recovery)		2,453			(51,361	)		(4,712	)		(2,259	)		(37,882	)
Stock-based compensation expense (recovery)		546			6,160			(517	)		29			9,521
Amortization of debt issuance costs		4,082			2,760			3,833			7,915			6,066
Non-cash lease expense		1,725			1,381			1,736			3,461			2,794
Lease payments		(1,545	)		(1,311	)		(1,567	)		(3,112	)		(2,369	)
Unrealized foreign exchange loss (gain)		3,114			(3,323	)		1,687			4,801			(5,589	)
Other loss		38			—			52			90			—
Unrealized derivative instrument (gain) loss		(12,401	)		—			1,910			(10,491	)		—
Cash netback	$	53,906		$	46,167		$	55,344		$	109,250		$	120,474

EBITDA, as presented, is defined as net income or loss adjusted for DD&A expenses, interest expense and income tax expense or recovery. Adjusted EBITDA, as presented, is defined as EBITDA adjusted for non-cash lease expense, lease payments, foreign exchange gain or loss, stock-based compensation expense or recovery, other gain or loss and unrealized derivative instruments gain or loss. Management uses this supplemental measure to analyze performance and income generated by our principal business activities prior to the consideration of how non-cash items affect that income, and believes that this financial measure is useful supplemental information for investors to analyze our performance and our financial results. A reconciliation from net income or loss to EBITDA and adjusted EBITDA is as follows:

	Three Months Ended June 30,						Three Months Ended March 31,			Six Months Ended June 30,						Twelve Month Trailing June 30,
EBITDA – (Non-GAAP) Measure ($000s)		2025			2024			2025			2025			2024			2025
Net (Loss) Income	$	(12,741	)	$	36,371		$	(19,280	)	$	(32,021	)	$	36,293		$	(65,098	)
Adjustments to reconcile net loss or income to EBITDA and Adjusted EBITDA
DD&A expenses		68,635			55,490			72,202			140,837			111,640			259,816
Interest expense		24,366			18,398			23,235			47,601			36,822			91,245
Income tax expense (recovery)		4,648			(9,072	)		3,553			8,201			8,323			41,267
EBITDA	$	84,908		$	101,187		$	79,710		$	164,618		$	193,078		$	327,230
Non-cash lease expense		1,725			1,381			1,736			3,461			2,794			6,590
Lease payments		(1,545	)		(1,311	)		(1,567	)		(3,112	)		(2,369	)		(5,778	)
Foreign exchange loss (gain)		3,716			(4,413	)		3,838			7,554			(5,228	)		3,974
Stock-based compensation expense (recovery)		546			6,160			(517	)		29			9,521			215
Other loss		38			—			52			90			—			90
Unrealized derivative instrument (gain) loss		(12,401	)		—			1,910			(10,491	)		—			(7,117	)
Adjusted EBITDA	$	76,987		$	103,004		$	85,162		$	162,149		$	197,796		$	325,204

Funds flow from operations, as presented, is defined as net income or loss adjusted for DD&A expenses, deferred tax expense or recovery, stock-based compensation expense or recovery, amortization of debt issuance costs, non-cash lease expense, lease payments, unrealized foreign exchange gain or loss, other gain or loss and unrealized gain or loss on derivative instruments. Management uses this financial measure to analyze performance and income or loss generated by our principal business activities prior to the consideration of how non-cash items affect that income or loss, and believes that this financial measure is also useful supplemental information for investors to analyze performance and our financial results. Free cash flow, as presented, is defined as funds flow from operations adjusted for capital expenditures. Management uses this financial measure to analyze cash flow generated by our principal business activities after capital requirements and believes that this financial measure is also useful supplemental information for investors to analyze performance and our financial results. A reconciliation from net income or loss to both funds flow from operations and free cash flow is as follows:

	Three Months Ended June 30,						Three Months Ended March 31,			Six Months Ended June 30,						Twelve Month Trailing June 30,
Funds Flow From Operations – (Non-GAAP) Measure ($000s)		2025			2024			2025			2025			2024			2025
Net (Loss) Income	$	(12,741	)	$	36,371		$	(19,280	)	$	(32,021	)	$	36,293		$	(65,098	)
Adjustments to reconcile net loss or income to funds flow from operations
DD&A expenses		68,635			55,490			72,202			140,837			111,640			259,816
Deferred tax expense (recovery)		2,453			(51,361	)		(4,712	)		(2,259	)		(37,882	)		7,735
Stock-based compensation expense (recovery)		546			6,160			(517	)		29			9,521			215
Amortization of debt issuance costs		4,082			2,760			3,833			7,915			6,066			14,767
Non-cash lease expense		1,725			1,381			1,736			3,461			2,794			6,590
Lease payments		(1,545	)		(1,311	)		(1,567	)		(3,112	)		(2,369	)		(5,778	)
Unrealized foreign exchange loss (gain)		3,114			(3,323	)		1,687			4,801			(5,589	)		2,497
Other loss		38			—			52			90			—			90
Unrealized derivative instrument (gain) loss		(12,401	)		—			1,910			(10,491	)		—			(7,117	)
Funds flow from operations	$	53,906		$	46,167		$	55,344		$	109,250		$	120,474		$	213,717
Capital expenditures	$	51,170		$	61,273		$	94,727		$	145,897		$	116,604		$	285,471
Free cash flow	$	2,736		$	(15,106	)	$	(39,383	)	$	(36,647	)	$	3,870		$	(71,754	)

Net debt as of June 30, 2025, was $746 million, calculated using the sum of the aggregate principal amount of 7.75% Senior Notes, 9.50% Senior Notes outstanding and amount drawn on credit facilities, excluding deferred financing fees, totaling $807 million, less cash and cash equivalents of $61 million. Management believes that net debt is a useful supplemental measure for management and investors in order to evaluate the financial sustainability of the Company’s business and leverage. The most directly comparable GAAP measure is total debt.

Presentation of Oil and Gas Information

Boes have been converted on the basis of six thousand cubic feet (“Mcf”) natural gas to 1 boe of oil. Boes may be misleading, particularly if used in isolation. A boe conversion ratio of 6 Mcf: 1 boe is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. In addition, given that the value ratio based on the current price of oil as compared with natural gas is significantly different from the energy equivalent of six to one, utilizing a boe conversion ratio of 6 Mcf: 1 boe would be misleading as an indication of value.

References to a formation where evidence of hydrocarbons has been encountered is not necessarily an indicator that hydrocarbons will be recoverable in commercial quantities or in any estimated volume. Gran Tierra’s reported production is a mix of light crude oil and medium heavy crude oil, tight oil, conventional natural gas, shale gas and natural gas liquids for which there is no precise breakdown since the Company’s sales volumes typically represent blends of more than one product type. Well test results should be considered as preliminary and not necessarily indicative of long-term performance or of ultimate recovery. Well log interpretations indicating oil and gas accumulations are not necessarily indicative of future production or ultimate recovery. If it is indicated that a pressure transient analysis or well-test interpretation has not been carried out, any data disclosed in that respect should be considered preliminary until such analysis has been completed. References to thickness of “oil pay” or of a formation where evidence of hydrocarbons has been encountered is not necessarily an indicator that hydrocarbons will be recoverable in commercial quantities or in any estimated volume.

This press release contains certain oil and gas metrics, including operating netback and cash netback, which do not have standardized meanings or standard methods of calculation and therefore such measures may not be comparable to similar measures used by other companies and should not be used to make comparisons. These metrics are calculated as described in this press release and management believes that they are useful supplemental measures for the reasons described in this press release.

Such metrics have been included herein to provide readers with additional measures to evaluate the Company’s performance; however, such measures are not reliable indicators of the future performance of the Company and future performance may not compare to the performance in previous periods.

The MIL Network –

July 31, 2025

MIL-Evening Report: Just as NZ began collecting meaningful data on rainbow communities, census changes threaten their visibility

Source: The Conversation (Au and NZ) – By Lori Leigh, Research Fellow in Public Health, University of Otago

Getty Images

New Zealand’s 2023 census was the first to collect data on gender identity and sexual orientation, showing one in 20 adults identify as LGBTQIA+.

But just as reports from this more inclusive census are being released, Minister of Statistics Shane Reti announced a change to existing administrative data collected by government departments as part of their normal business, scrapping a 150-year history of the census.

Currently, there are no sources of administrative data that include adequate rainbow demographic markers such as sexual orientation, gender, transgender experience or variations of sex characteristics.

Without high-quality data, the policy reforms needed to address underserved and historically marginalised populations become harder to make. How can we create evidence-based policy with no evidence?

A snapshot of homelessness in rainbow communities

The slogan of the 2023 census was “tatau tātou – all of us count”.

Rainbow communities had been invisible in the census since its inception in 1851. The 2023 Census was a watershed moment, born out of decades of determined activism and advocacy from the community.

For us, as housing and homelessness researchers, it was particularly important to finally have whole-of-population data about rates of homelessness among LGBTQIA+ communities. Data on housing showed rainbow communities pay higher rents, live in mouldier housing and move more frequently than non-rainbow communities.

Adding LGBTQIA+ data to the census meant we were the first country in the world to have such data on the housing experiences of these communities. We were applauded internationally by colleagues who have long been wanting similar homelessness and rainbow data from their own national censuses.

This data will be a great advocacy tool, but it is bittersweet that we will never have such information again.

History of advocacy

There is a nearly 50-year history of various community movements, from boycotts to activism, chronicling the queer struggle to be appropriately counted in the census.

In 1981, a group of Wellington lesbians held a “dykecott” of the New Zealand census to protest their exclusion. This included sending blank census forms to the Human Rights Commission with various explanations essentially saying “no rights, no responsibilities.”

Then, in the 1990s, the Wellington City Council’s lesbian and gay advisory group came together to lobby Stats NZ about the need for inclusive census data. In 1996, census forms were changed to be able to count same-sex partners.

In 2002, the former editor of the New Zealand LGBTQIA+ magazine Express Victor van Wetering went so far as to lodge a formal complaint against Stats NZ, stating the agency was in clear breach of the Human Rights Act. He alleged it was failing to meet its statutory requirements.

Stats NZ’s present and historical stance towards sexual orientation data amounts to a consistent denial that any imperative exists for it to develop a statistical picture of our queer communities. This statistical invisibility deprives queer communities of knowledge and power.

Advocacy continued throughout the 2000s and 2010s, and in 2018, Stats NZ released their statistical standards for measuring sexual orientation. The possibility of inclusive census data started to become more of a reality.

The decision to halt the census as we know it means there will be no longitudinal comparative data for rainbow communities. Just as the community has been allowed out of the statistical closet, people will be put back in.

It had long been argued that accuracy of rainbow data would improve over subsequent censuses. Now we will never know what developments might have emerged.

A short-lived win

Community advocates and the Human Rights Commission continued to raise the lack of rainbow data collection at the population level.

In 2020, the Human Rights Commission released a report which found New Zealand’s data collection processes fail to accurately count the country’s rainbow community members.

Stats NZ had already started significant work to evaluate and update their sex and gender identity standards. Weeks after the report, the agency committed to what would become the 2023 census. Rainbow community groups applauded, felt finally listened to and called the shift a major win.

After decades of advocacy, rainbow populations were finally counted in the 2023 Census.
Instagram/Insideoutkoaro, CC BY-SA

This sense of pride continues as reports and data are released from the census.

Research and survey data consistently show rainbow communities in Aotearoa New Zealand experience multiple forms of discrimination. This includes violence, family rejection, bullying and social exclusion.

These experiences contribute to disproportionately high rates of serious negative outcomes such as suicidality, health inequities, homelessness and substance use. Despite this, we continue to lack data comparing the experiences of rainbow communities with those of the general population.

As a result, health and social disparities affecting LGBTQIA+ people are systematically under-recognised in government strategies and across health and social service systems. Efforts to address these inequities are also frequently under-resourced and inadequately prioritised.

Former government statistician Len Cook said:

There is no time over the past 50 years when the scope and quality of population statistics has been of such importance in public life in Aotearoa New Zealand as now.

Scrapping the census is a cost-cutting exercise. But what is the real cost of losing data and which communities will disproportionately bear this cost? The decision renders LGBTQIA+ people, once again, invisible.

Lori Leigh is affiliated with the Trans Health Research Network, Kawe Mahara Queer Archives Aotearoa and receives funding from MBIE’s Endeavour Fund programme as part of their work for the University of Otago, Wellington.

Brodie Fraser is affiliated with the Trans Health Research Network and currently funded by two MBIE Endeavour Fund programmes, and has previously been funded by the Health Research Council and the University of Otago.

– ref. Just as NZ began collecting meaningful data on rainbow communities, census changes threaten their visibility – https://theconversation.com/just-as-nz-began-collecting-meaningful-data-on-rainbow-communities-census-changes-threaten-their-visibility-261753

MIL OSI Analysis – EveningReport.nz –

July 31, 2025

MIL-OSI USA: Senate Homeland Security Committee unanimously passes Kennedy, Peters bill to end government payments to deceased Americans

US Senate News:

Source: United States Senator John Kennedy (Louisiana)

WASHINGTON – The U.S. Senate Homeland Security and Governmental Affairs Committee (HSGAC) today unanimously voted to advance Sen. John Kennedy (R-La.) and Sen. Gary Peters’ (D-Mich.) Ending Improper Payments to Deceased People Act, which would save hard-earned taxpayer money by curbing erroneous payments to individuals who have passed away.

Kennedy’s original bipartisan legislation set up key provisions to save federal taxpayer dollars by curbing erroneous government payments to individuals for a temporary three-year period, and this new Kennedy-Peters bill would make the temporary provisions permanent. The original bill is expected to save at least $330 million from 2024 to 2026.

“Today’s unanimous Senate Homeland Security Committee vote to pass my Ending Improper Payments to Deceased People Act is a major win for every American worried about waste, fraud, and abuse in our federal budget. There’s no reason hardworking Americans should have to pay for the government’s mistaken payments to dead people. I look forward to the full Senate passing our bill right away,” said Kennedy.

“This bill would help save millions of taxpayer dollars by ensuring that the Social Security Administration can permanently share important data with the Treasury’s Do Not Pay system, preventing wrongful payments to deceased individuals. I have long supported this legislation because I believe it is a vital step in safeguarding taxpayer dollars and ensuring the integrity of our payment systems,” said Peters.

In January 2025, the Treasury Department announced that it recovered $31 million in fraud and improper payments during the first five months of the implementation of Kennedy’s Stopping Improper Payments to Deceased People Act, in which the Social Security Administration shared its Death Master File with the Treasury Department to avoid erroneous payments temporarily.

The Ending Improper Payments to Deceased People Act would permanently amend the Social Security Act to allow the Social Security Administration to share the Death Master File – a record of deceased individuals – with the Treasury Department’s Do Not Pay system. This change would rein in the government’s ability to make improper payments to deceased people in the future.

The bill would also allow the Treasury’s Do Not Pay working system to compare death information from the Social Security Administration with personal information from other federal entities and to share this information with any paying or administering agency that is authorized to use the Do Not Pay system.

Background:

Kennedy has championed the cause of saving billions of dollars in taxpayer money by ending improper payments to deceased Americans in recent years:

In December 2024, Kennedy urged his colleagues to save taxpayer dollars and support the Ending Improper Payments to Deceased Americans Act on the Senate floor.

In May 2024, the Senate Committee on Homeland Security and Governmental Affairs unanimously passed Kennedy’s Ending Improper Payments to Deceased People Act.

Kennedy’s Stopping Improper Payments to Deceased People Act became law in December 2020. The bill mandates the sharing of the Social Security Administration’s Death Master File with the Department of the Treasury’s Do Not Pay working system within three years after enactment. The three-year exchange runs from December 27, 2023, to December 27, 2026.

In 2021, Kennedy wrote this op-ed sounding the alarm on the government’s sending more than $1 billion to deceased Americans.

In 2019, Kennedy questioned U.S. Government Accountability Office Comptroller General Hon. Gene L. Dodaro about improper payments sent to deceased people.

Full bill text is available here.

MIL OSI USA News –

July 31, 2025

MIL-OSI United Nations: With Gaza smouldering, ministers renew push for two-State solution at UN

Source: United Nations 4

The High-level International Conference for the Peaceful Settlement of the Question of Palestine and the Implementation of the Two-State Solution took place in New York from 28 to 30 July.

The United States and Israel did not participate.

France and Saudi Arabia, co-chairs of the Conference, called on all UN Member States to support a declaration urging collective action to end the war in Gaza and to achieve a just, peaceful and lasting settlement of the Israeli-Palestinian conflict.

The New York Declaration on the Peaceful Settlement of the Question of Palestine and the Implementation of the Two-State Solution outlines political, humanitarian, and security steps to be taken on a timebound and irreversible basis.

The co-chairs urged countries to endorse the declaration by the end of the 79th session of the General Assembly, in early September, should they so wish.

Act before it is too late

In his stark opening remarks on Monday, Secretary-General Guterres stressed that the two-State solution is the only viable path to ending the longstanding conflict and achieving lasting peace in the region, warning that there is no alternative.

“A one-State reality where Palestinians are denied equal rights and forced to live under perpetual occupation and inequality? A one-State reality where Palestinians are expelled from their land? That is not peace. That is not justice. And that is not acceptable,” he said.

He condemned both Hamas’ 7 October 2023 attacks and the scale of Israel’s military response, reiterating his call for an immediate and permanent ceasefire, the unconditional release of hostages, and unfettered humanitarian access.

“This conflict cannot be managed. It must be resolved,” Mr. Guterres concluded. “We must act before it is too late.”

UN Photo/Evan Schneider

Secretary-General António Guterres addresses the high-level conference on the peaceful settlement of the question of Palestine and the implementation of the two-State solution.

Calls for peace

Over the three days, more than 125 speakers took the floor during the general debate, including high-level representatives from across the globe and major regional and international organizations such as the Organization of Islamic Cooperation (OIC) and the International Committee of the Red Cross (ICRC).

Delegates underscored the urgency of concrete steps to realise a two-State solution, highlighting the need to empower and reform the Palestinian Authority, reconstruct Gaza and ensure accountability for violations of international law.

France, which co-chaired the Conference, recalled its support for Israel as it joined the community of nations and affirmed that Palestinians deserve the same right to a homeland.

“At a time where the two-State solution is more threatened than ever, France is ready to fully recognise the State of Palestine,” said Jean-Noël Barrot, Minister for Europe and Foreign Affairs. That recognition, he added, would come in September when leaders reconvene for the General Assembly’s 80th session.

Co-chair Saudi Arabia’s Foreign Minister, Faisal bin Farhan al Saud, emphasised the suffering of thousands of civilians in Gaza under bombardment, while Israeli settlements expand in Jerusalem and the West Bank to alter the region’s demographic nature.

“Peace and security do not take place through deprivation of rights or force,” he said, underscoring the need for a genuine and irreversible peace process.

UN Photo/Loey Felipe

Foreign Secretary David Lammy of the United Kingdom addresses the high-level conference.

The United Kingdom’s Foreign Secretary, David Lammy, outlined recent UK actions – including the suspension of arms exports and sanctions on extremist settlers, and restoring of funding to the UN Relief and Works Agency for Palestine Refugees.

“It is with the hand of history on our shoulders that His Majesty’s Government therefore intends to recognise the State of Palestine when the UN General Assembly gathers in September here in New York,” he declared.

“We will do this unless the Israeli Government acts to end the appalling situation in Gaza, ends its military campaign and commits to a long-term sustainable peace based on a two-State solution.”

MIL OSI United Nations News –

July 31, 2025

MIL-OSI United Nations: World News in Brief: Violence in Somalia, cholera in Haiti, tax support for sustainable development

Source: United Nations MIL OSI

Clashes intensified in the town of Mahas in the Hiraan region, Hirshabelle state, on 26 July forcing the entire population – over 28,000 people – to flee their homes.

Another 38,000 people were displaced in the Gedo region, Jubaland state, between 23 and 26 July, some of whom crossed into Kenya. 

Security concerns have forced seven health facilities in the Hiraan region to suspend operations, leaving thousands of people without essential healthcare and emergency services. Humanitarian access also has been restricted, particularly in areas that were already hard to reach.  

OCHA noted that only a limited number of aid partners are able to operate in these locations given the insecurity as well as financial constraints. Meanwhile, affected communities urgently need shelter, food, clean water, healthcare and protection.

The situation is unfolding as aid agencies grapple with severe funding cuts. A $1.4 billion humanitarian plan for Somalia this year is around 16 per cent funded, with $229 million received to date.

Cholera haunts displaced families in Haiti

Cholera continues to impact the fragile public health system in Haiti, particularly in sites hosting displaced people where there is limited access to safe water and sanitation.

The Caribbean country is confronting multiple political, security and socio-economic crises, including rampant gang activity mainly in the capital, Port-au-Prince.

The UN World Health Organization (WHO) said that between 13 and 19 July, 34 new suspected cholera cases were reported across six of the nation’s 10 departments. Most were linked to displacement sites.

Five active transmission hotspots have been identified, including in Port-au-Prince and in the northern regions. 

Since December 2024, over 2,800 suspected cholera cases have been recorded across Haiti, with 91 laboratory-confirmed cases and 36 fatalities.

Despite funding shortfalls, UN humanitarian partners continue to carry out key cholera prevention and response activities. 

Families in Artibonite department received water purification tablets and oral rehydration salt, for example, while partners in central Haiti have installed handwashing stations and scaled up community outreach. 

Experts to help countries create tax policies that advance sustainable development

Secretary-General António Guterres has appointed 25 experts to a UN committee to help countries design tax policies that advance their social, environmental and economic development objectives. 

The UN Committee of Experts on International Cooperation in Tax Matters supports governments in navigating complex policy trade-offs. Its work provides countries with practical options and tools based on real-world experiences from tax systems across the globe. 

The 25 experts, who will serve for the 2025-2029 term, have diverse expertise in tax policy design and administration, as well as international tax cooperation.

They represent various geographical regions and tax systems, and the majority are women, reflecting the UN’s commitment to strengthening inclusivity in tax leadership.

MIL OSI United Nations News –

July 31, 2025

MIL-OSI Canada: Remarks by the Minister of Foreign Affairs, Anita Anand at the Ministerial Conference on the Peaceful Settlement of the Question of Palestine and the Implementation of the Two-State Solution

Source: Government of Canada News

July 28, 2025
New York, New York

Check against delivery

Excellencies, distinguished delegates, honoured colleagues.

The Palestinian question is at the heart of any hope for long-term stability in the Middle East.

Despite the complexity of the situation, our collective presence here today reflects strong international support for a negotiated solution.

One that ensures Palestinian self-determination and Israeli security.

And one that charts a path toward lasting regional peace and prosperity.

As article 1 of the UN Declaration of Human Rights states: “All human beings are born free and equal in dignity and rights.”

Canada remains firmly committed to a two-state solution: an independent, viable and sovereign Palestinian state living side by side with Israel in peace and security.

Canada supports the Palestinian people’s right to self-determination.

And we endorse the principle of Palestinian statehood.

We shall continue to discuss with the Palestinian Authority the next steps in our relationship.

A workable Palestinian state needs legitimate, democratic governance that serves all Palestinian people.

Crucially important is the Palestinian Authority’s commitment to undertake the comprehensive reforms necessary to govern Gaza and the West Bank.

To that end, today Canada is pledging an additional $10 million this year to accelerate reform and capacity building for the Palestinian Authority.

Canada’s commitment to a two-state solution is rooted in our desire to see the Palestinian people living with freedom and dignity AND to see Israelis live in peace and security.

In this light, this path is not only the most just course, it is the only sustainable one.

In Gaza, the humanitarian situation is catastrophic.

Multitudes of Palestinians are dying of starvation, being killed trying to access food and water or are in military operations that have resulted in mass casualties. And those who survive are at risk of preventable disease and death.

This is unacceptable.

We condemn the continued detention of hostages held captive by Hamas since 7 October, 2023, and call for their immediate and unconditional release.

Hamas is a terrorist organization, and it must immediately and unconditionally release all hostages.

Hamas can have no role in Gaza’s future governance.

Israel’s right to live in peace and security with its neighbours has long been, and continues to be, a key principle of Canada’s Middle East policy.

I believe this right must be recognized by all partners who are committed to peace.

To this principle must be joined our shared commitment to Palestine’s right to live in peace and security.

Joined by international partners, Canada also recently condemned the ongoing civilian suffering:

We condemn the inhumane killing of civilians, including children.
We condemn the ongoing expansion of settlements and settler violence in the West Bank.
And we condemn the forced displacement of the Palestinians population.

The actions outlined just now are all violations of international humanitarian law.

We urge all partners to continue to support a principled response through non-governmental humanitarian organizations—organizations with proven capacity to deliver humanitarian assistance at scale.

Canada has committed more than $315 million in humanitarian aid to Gaza—making us the third-largest bilateral donor in response to this crisis.

This includes:

Support to the World Food Programme to address critical food assistance needs.
Support to the International Committee of the Red Cross [and] Red Crescent to provide emergency medical care and protection.
Support to UNICEF to deliver urgent nutritional supplies to malnourished children.
And support to other experienced humanitarian partners and NGOs.

Announcement

Today, given the ongoing and urgent need, Canada is announcing an additional $30 million in new money this year for those in Gaza.

This funding will allow more aid to be prepositioned in the region and ready to be delivered at scale as soon as logistically possible.

For this critical aid to reach those in need, humanitarian partners must be granted safe and unhindered access to civilians in Gaza.

But how do we get to a place where recovery and healing can begin?

Canada sees this conference as a reaffirmation of principles—and a call to action.

A lasting political solution requires a permanent ceasefire to begin the hard work of rebuilding institutions, restoring trust and the conditions for a viable two-state solution.

[In this regard, Canada commends the efforts of Qatar, Egypt and the United States in looking to secure a ceasefire.]

No durable solution can emerge without all parties at the table.

Until that time, and after a ceasefire, the Government of Canada will be present with humanitarian aid and will play a leading role in building bridges to more and more aid for Gaza with international partners.

MIL OSI Canada News –

July 31, 2025

MIL-OSI USA: SBA Offers Relief to Washington Small Businesses and Private Nonprofits Affected by Drought

Source: United States Small Business Administration

SACRAMENTO, Calif. – The U.S. Small Business Administration (SBA) announced the availability of low interest federal disaster loans to small businesses and private nonprofit (PNP) organizations in Washington to offset economic losses caused by drought beginning July 8.

The declaration covers the Washington counties of Adams, Asotin, Columbia, Franklin, Garfield, Lincoln, Spokane and Whitman as well as Idaho counties of Benewah, Latah and Nez Perce and the Oregon county of Wallowa.

Under this declaration, SBA’s Economic Injury Disaster Loan (EIDL) program is available to small businesses, small agricultural cooperatives, nurseries, and PNPs including faith-based with financial losses directly related to the disaster. The SBA is unable to provide disaster loans to agricultural producers, farmers, or ranchers, except for small aquaculture enterprises.

EIDLs are available for working capital needs caused by the disaster and are available even if the business or PNP did not suffer any physical damage. The loans may be used to pay fixed debts, payroll, accounts payable and other bills not paid due to the disaster.

“Through a declaration by the U.S. Secretary of Agriculture, SBA provides critical financial assistance to help communities recover,” said Chris Stallings, associate administrator of the Office of Disaster Recovery and Resilience at the SBA. “We’re pleased to offer loans to small businesses and private nonprofits impacted by these disasters.”

The loan amount can be up to $2 million with interest rates as low as 4% for businesses and 3.625% for PNPs with terms up to 30 years. Interest does not accrue, and payments are not due until 12 months after the date of the first loan disbursement. The SBA sets loan amounts and terms based on each applicant’s financial condition.

To apply online, visit sba.gov/disaster. Applicants may also call SBA’s Customer Service Center at (800) 659-2955 or email disastercustomerservice@sba.gov for more information on SBA disaster assistance. For people who are deaf, hard of hearing, or have a speech disability, please dial 7-1-1 to access telecommunications relay services.

Submit completed loan applications to SBA no later than March 16, 2026.

###

About the U.S. Small Business Administration

The U.S. Small Business Administration helps power the American dream of business ownership. As the only go-to resource and voice for small businesses backed by the strength of the federal government, the SBA empowers entrepreneurs and small business owners with the resources and support they need to start, grow, expand their businesses, or recover from a declared disaster. It delivers services through an extensive network of SBA field offices and partnerships with public and private organizations. To learn more, visit www.sba.gov.

MIL OSI USA News –

July 31, 2025

MIL-OSI USA: SBA Offers Relief to Kansas Small Businesses and Private Nonprofits Affected by May Drought

Source: United States Small Business Administration

SACRAMENTO, Calif. – The U.S. Small Business Administration (SBA) announced the availability of low interest federal disaster loans to small businesses and private nonprofit (PNP) organizations in Kansas to offset economic losses caused by drought beginning May 20.

The declaration covers the Kansas counties of Decatur, Graham, Norton, Phillips, Rawlins, Sheridan and Thomas as well as the Nebraska counties of Furnas, Harlan and Red Willow.

Under this declaration, SBA’s Economic Injury Disaster Loan (EIDL) program is available to small businesses, small agricultural cooperatives, nurseries, and PNPs including faith-based with financial losses directly related to the disaster. The SBA is unable to provide disaster loans to agricultural producers, farmers, or ranchers, except for small aquaculture enterprises.

EIDLs are available for working capital needs caused by the disaster and are available even if the business or PNP did not suffer any physical damage. The loans may be used to pay fixed debts, payroll, accounts payable and other bills not paid due to the disaster.

“Through a declaration by the U.S. Secretary of Agriculture, SBA provides critical financial assistance to help communities recover,” said Chris Stallings, associate administrator of the Office of Disaster Recovery and Resilience at the SBA. “We’re pleased to offer loans to small businesses and private nonprofits impacted by these disasters.”

The loan amount can be up to $2 million with interest rates as low as 4% for businesses and 3.625% for PNPs with terms up to 30 years. Interest does not accrue, and payments are not due until 12 months after the date of the first loan disbursement. The SBA sets loan amounts and terms based on each applicant’s financial condition.

To apply online, visit sba.gov/disaster. Applicants may also call SBA’s Customer Service Center at (800) 659-2955 or email disastercustomerservice@sba.gov for more information on SBA disaster assistance. For people who are deaf, hard of hearing, or have a speech disability, please dial 7-1-1 to access telecommunications relay services.

Submit completed loan applications to SBA no later than March 16, 2026.

###

About the U.S. Small Business Administration

The U.S. Small Business Administration helps power the American dream of business ownership. As the only go-to resource and voice for small businesses backed by the strength of the federal government, the SBA empowers entrepreneurs and small business owners with the resources and support they need to start, grow, expand their businesses, or recover from a declared disaster. It delivers services through an extensive network of SBA field offices and partnerships with public and private organizations. To learn more, visit www.sba.gov.

MIL OSI USA News –

July 31, 2025

MIL-OSI USA: SBA Offers Relief to Nebraska Small Businesses and Private Nonprofits Affected by May Drought

Source: United States Small Business Administration

SACRAMENTO, Calif. – The U.S. Small Business Administration (SBA) announced the availability of low interest federal disaster loans to small businesses and private nonprofit (PNP) organizations in Nebraska to offset economic losses caused by drought beginning May 13.

The declaration covers the Nebraska counties of Buffalo, Butler, Chase, Clay, Colfax, Dawson, Dodge, Dundy, Fillmore, Franklin, Frontier, Furnas, Gosper, Hamilton, Harlan, Hayes, Hitchcock, Jefferson, Kearney, Lancaster, Lincoln, Merrick, Nuckolls, Perkins, Phelps, Platte, Polk, Red Willow, Saline, Saunders, Seward, Thayer and York as well as Kansas counties of Decatur, Norton and Rawlins.

Under this declaration, SBA’s Economic Injury Disaster Loan (EIDL) program is available to small businesses, small agricultural cooperatives, nurseries, and PNPs including faith-based with financial losses directly related to the disaster. The SBA is unable to provide disaster loans to agricultural producers, farmers, or ranchers, except for small aquaculture enterprises.

EIDLs are available for working capital needs caused by the disaster and are available even if the business or PNP did not suffer any physical damage. The loans may be used to pay fixed debts, payroll, accounts payable and other bills not paid due to the disaster.

“Through a declaration by the U.S. Secretary of Agriculture, SBA provides critical financial assistance to help communities recover,” said Chris Stallings, associate administrator of the Office of Disaster Recovery and Resilience at the SBA. “We’re pleased to offer loans to small businesses and private nonprofits impacted by these disasters.”

The loan amount can be up to $2 million with interest rates as low as 4% for small businesses and 3.625% for PNPs with terms up to 30 years. Interest does not accrue, and payments are not due until 12 months after the date of the first loan disbursement. The SBA sets loan amounts and terms based on each applicant’s financial condition.

To apply online, visit sba.gov/disaster. Applicants may also call SBA’s Customer Service Center at (800) 659-2955 or email disastercustomerservice@sba.gov for more information on SBA disaster assistance. For people who are deaf, hard of hearing, or have a speech disability, please dial 7-1-1 to access telecommunications relay services.

Submit completed loan applications to SBA no later than March 16, 2026.

###

About the U.S. Small Business Administration

The U.S. Small Business Administration helps power the American dream of business ownership. As the only go-to resource and voice for small businesses backed by the strength of the federal government, the SBA empowers entrepreneurs and small business owners with the resources and support they need to start, grow, expand their businesses, or recover from a declared disaster. It delivers services through an extensive network of SBA field offices and partnerships with public and private organizations. To learn more, visit www.sba.gov.

MIL OSI USA News –

July 31, 2025

MIL-OSI USA: SBA Offers Relief to Idaho Small Businesses and Private Nonprofits Affected by July Drought

Source: United States Small Business Administration

SACRAMENTO, Calif. – The U.S. Small Business Administration (SBA) announced the availability of low‑interest federal disaster loans to small businesses and private nonprofit (PNP) organizations in Idaho to offset economic losses caused by drought.

The disaster declarations cover the counties listed below:

Declaration Number	Primary Counties/Parishes	Neighboring Counties/Parishes	Incident Type	Incident Date	Deadline
ID 21214	Clearwater, Idaho, Lemhi, Lewis and Shoshone	Adams, Benewah, Bonner, Butte, Clark, Custer, Kootenai, Latah, Nez Perce and Valley in Idaho; Beaverhead, Mineral, Missoula, Ravalli and Sanders in Montana; Wallowa in Oregon.	Drought	Beginning July 1, 2025	3/16/26
ID 21217	Benewah, Latah and Nez Perce	Clearwater, Idaho, Kootenai, Lewis and Shoshone in Idaho; Wallowa in Oregon; Asotin, Spokane and Whitman in Washington.	Drought	Beginning July 8, 2025	3/16/26

Under these declarations, SBA’s Economic Injury Disaster Loan (EIDL) program is available to small businesses, small agricultural cooperatives, nurseries, and PNPs including faith-based with financial losses directly related to the disaster. The SBA is unable to provide disaster loans to agricultural producers, farmers, or ranchers, except for small aquaculture enterprises.

EIDLs are available for working capital needs caused by the disaster and are available even if the business or PNP did not suffer any physical damage. The loans may be used to pay fixed debts, payroll, accounts payable and other bills not paid due to the disaster.

“Through a declaration by the U.S. Secretary of Agriculture, SBA provides critical financial assistance to help communities recover,” said Chris Stallings, associate administrator of the Office of Disaster Recovery and Resilience at the SBA. “We’re pleased to offer loans to small businesses and private nonprofits impacted by these disasters.”

The loan amount can be up to $2 million with interest rates as low as 4% for businesses and 3.625% for PNPs with terms up to 30 years. Interest does not accrue, and payments are not due until 12 months from the date of the first loan disbursement. The SBA sets loan amounts and terms based on each applicant’s financial condition.

To apply online and receive additional disaster assistance information visit sba.gov/disaster. Applicants may also call SBA’s Customer Service Center at (800) 659-2955 or email disastercustomerservice@sba.gov for more information on SBA disaster assistance. For people who are deaf, hard of hearing, or have a speech disability, please dial 7-1-1 to access telecommunications relay services.

Submit completed loan applications to the SBA no later than March 16, 2026.

###

About the U.S. Small Business Administration

The U.S. Small Business Administration helps power the American dream of business ownership. As the only go-to resource and voice for small businesses backed by the strength of the federal government, the SBA empowers entrepreneurs and small business owners with the resources and support they need to start, grow, expand their businesses, or recover from a declared disaster. It delivers services through an extensive network of SBA field offices and partnerships with public and private organizations. To learn more, visit www.sba.gov.

MIL OSI USA News –

July 31, 2025

MIL-OSI USA: SBA Offers Relief to Colorado Small Businesses and Private Nonprofits Affected by May Drought

Source: United States Small Business Administration

SACRAMENTO, Calif. – The U.S. Small Business Administration (SBA) announced the availability of low interest federal disaster loans to small businesses and private nonprofit (PNP) organizations in Colorado to offset economic losses caused by drought beginning May 13.

The declaration covers the Colorado counties of Eagle, Garfield, Grand, Jackson, Lake, Moffat, Pitkin, Rio Blanco, Routt and Summit as well as Utah counties of Daggett and Uintah, and the Wyoming counties of Carbon and Sweetwater.

Under this declaration, SBA’s Economic Injury Disaster Loan (EIDL) program is available to small businesses, small agricultural cooperatives, nurseries, and PNPs including faith-based with financial losses directly related to the disaster. The SBA is unable to provide disaster loans to agricultural producers, farmers, or ranchers, except for small aquaculture enterprises.

EIDLs are available for working capital needs caused by the disaster and are available even if the business or PNP did not suffer any physical damage. The loans may be used to pay fixed debts, payroll, accounts payable and other bills not paid due to the disaster.

“Through a declaration by the U.S. Secretary of Agriculture, SBA provides critical financial assistance to help communities recover,” said Chris Stallings, associate administrator of the Office of Disaster Recovery and Resilience at the SBA. “We’re pleased to offer loans to small businesses and private nonprofits impacted by these disasters.”

The loan amount can be up to $2 million with interest rates as low as 4% for small businesses and 3.625% for PNPs with terms up to 30 years. Interest does not accrue, and payments are not due until 12 months after the date of the first loan disbursement. The SBA sets loan amounts and terms based on each applicant’s financial condition.

To apply online, visit sba.gov/disaster. Applicants may also call SBA’s Customer Service Center at (800) 659-2955 or email disastercustomerservice@sba.gov for more information on SBA disaster assistance. For people who are deaf, hard of hearing, or have a speech disability, please dial 7-1-1 to access telecommunications relay services.

Submit completed loan applications to SBA no later than March 16, 2026.

###

About the U.S. Small Business Administration

The U.S. Small Business Administration helps power the American dream of business ownership. As the only go-to resource and voice for small businesses backed by the strength of the federal government, the SBA empowers entrepreneurs and small business owners with the resources and support they need to start, grow, expand their businesses, or recover from a declared disaster. It delivers services through an extensive network of SBA field offices and partnerships with public and private organizations. To learn more, visit www.sba.gov.

MIL OSI USA News –

July 31, 2025

Category: Politics

Key challenges

Structural barriers

Turning identity into an asset

There’s more we can do

Jul 30, 2025 Oil and Natural Gas Trades Support Bipartisan SPEED Act for Permitting Reform

Time for change

1. A national action plan, driven by human rights

2. An independent oversight body

3. A bigger role for local government

The gap between promise and evidence

Economic impact from AI will unfold gradually

The educational risk

A multi-partner infrastructure strategy

Australia’s AI future

Time to pay up: Toughest crackdown on late payments in a generation unveiled in plan to back small businesses

Prime Minister Keir Starmer said:

Business and Trade Secretary Jonathan Reynolds said:

Small Business Minister Gareth Thomas said:

Policy Chair of the Federation of Small Businesses (FSB), Tina McKenzie, said:

Charlie Shaw, owner of Flock and Herd butchers in Peckham said:

Notes to editors

Michelle Ovens CBE, Founder, Small Business Britain, said:

Simon Groom, CEO of MagnifyB, said:

Julianne Ponan MBE, Founder of Creative Nature, a small business that exports top 14 Allergen Free Baking Mixes and Snacks to 16 countries, said:

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Updates to this page

A snapshot of homelessness in rainbow communities

History of advocacy

A short-lived win

Act before it is too late

Calls for peace

Cholera haunts displaced families in Haiti

Experts to help countries create tax policies that advance sustainable development

Announcement

Business and Trade Secretary Jonathan Reynolds said:  