Category: Canada

MIL-OSI USA: Cortez Masto Calls on Trump Administration to Increase Transparency on Trade Negotiations

US Senate News:

Source: United States Senator for Nevada Cortez Masto

Following Announcement of Recent Trade Agreement, Indonesian Authorities Have Publicly Disputed Announced Agreements

Washington, D.C. – Today, U.S. Senator Catherine Cortez Masto (D-Nev.) sent a letter to U.S. Trade Representative (USTR) Jamieson Greer calling on the Trump Administration to provide more transparency to Congress on their trade negotiations with other nations, in light of recent reporting showing that a trade agreement announced with Indonesia has been publicly disputed by Indonesian authorities. Her letter comes one day before President Trump’s tariffs on other nations are scheduled to go into effect.

In a recent statement, the White House has asserted that Indonesia had committed to lifting its ban on nickel exports. “However, Indonesian officials are now saying that they made no such commitment,” the Senator wrote. “Indonesia’s Coordinating Minister of Economic Affairs, Airlangga Hartarto, has said that the U.S.-Indonesia agreement does not touch Indonesia’s export restrictions and that ‘nothing will be removed.’ Similarly, Indonesia’s Ministry of Energy and Mineral Resources – which oversees Indonesia’s mining sector – has confirmed that Indonesia will not export raw minerals to the United States and that there are no directives or policy revisions permitting such exports to the United States. Key industry groups in Indonesia – like the Indonesia Mining Association – are also unaware of any forthcoming changes to the country’s export ban, and continue to tout the success of this policy.”

“As we look ahead, I strongly urge you to adopt greater transparency and Congressional consultation in your negotiations. Indonesia’s export ban policy is not only an important economic issue impacting U.S. firms, but given Chinese investment in Indonesia’s nickel sector, it has national security implications for our country. I stand ready to work with you to ensure real commitments and real enforceability in our trade agreements, and encourage you to adopt a more effective and transparent approach in your negotiations,” the Senator concluded.

Read the full letter here.

Senator Cortez Masto has continued to push the Trump Administration to address the impacts of Trump’s tariffs on working families and Nevada small businesses. During a Senate Finance Committee hearing, Cortez Masto pressed USTR Greer about the impacts of President Trump’s blanket tariffs on Nevadans, particularly those employed in the tourism and hospitality industry. The Senator introduced the Tariff Transparency Act to require the U.S. International Trade Commission to publicly investigate how Donald Trump’s proposed tariffs on imports from Mexico and Canada would impact the American people.

MIL OSI USA News –

August 5, 2025

MIL-OSI: Shell Plc 2nd QUARTER 2025 HALF YEAR UNAUDITED RESULTS

Source: GlobeNewswire (MIL-OSI)

SHELL PLC
2nd QUARTER 2025 AND HALF YEAR UNAUDITED RESULTS



SUMMARY OF UNAUDITED RESULTS
Quarters				$ million		Half year
Q2 2025	Q1 2025	Q2 2024	%¹		Reference	2025	2024	%
3,601	4,780	3,517	-25	Income/(loss) attributable to Shell plc shareholders		8,381	10,874	-23
4,264	5,577	6,293	-24	Adjusted Earnings	A	9,841	14,027	-30
13,313	15,250	16,806	-13	Adjusted EBITDA	A	28,563	35,517	-20
11,937	9,281	13,508	+29	Cash flow from operating activities		21,218	26,838	-21
(5,406)	(3,959)	(3,338)		Cash flow from investing activities		(9,365)	(6,866)
6,531	5,322	10,170		Free cash flow	G	11,853	19,972
5,817	4,175	4,719		Cash capital expenditure	C	9,993	9,211
8,265	8,575	8,950	-4	Operating expenses	F	16,840	17,947	-6
8,145	8,453	8,651	-4	Underlying operating expenses	F	16,598	17,704	-6
9.4%	10.4%	12.8%		ROACE	D	9.4%	12.8%
75,675	76,511	75,468		Total debt	E	75,675	75,468
43,216	41,521	38,314		Net debt	E	43,216	38,314
19.1%	18.7%	17.0%		Gearing	E	19.1%	17.0%
2,682	2,838	2,817	-5	Oil and gas production available for sale (thousand boe/d)		2,760	2,864	-4
0.61	0.79	0.55	-23	Basic earnings per share ($)		1.40	1.70	-18
0.72	0.92	0.99	-22	Adjusted Earnings per share ($)	B	1.64	2.19	-25
0.3580	0.3580	0.3440	—	Dividend per share ($)		0.7160	0.6880	+4

1.Q2 on Q1 change

Quarter Analysis1

Income attributable to Shell plc shareholders, compared with the first quarter 2025, reflected lower trading and optimisation margins and lower realised liquids and gas prices, partly offset by higher Marketing margins and lower operating expenses.

Second quarter 2025 income attributable to Shell plc shareholders also included impairment charges, gains on disposal of assets and favourable movements due to the fair value accounting of commodity derivatives. These items are included in identified items amounting to a net loss of $0.3 billion in the quarter. This compares with identified items in the first quarter 2025 which amounted to a net loss of $0.8 billion.

Adjusted Earnings and Adjusted EBITDA2 were driven by the same factors as income attributable to Shell plc shareholders and adjusted for the above identified items and the cost of supplies adjustment of $0.3 billion.

Cash flow from operating activities for the second quarter 2025 was $11.9 billion and primarily driven by Adjusted EBITDA. This inflow was partly offset by tax payments of $3.4 billion.

Cash flow from investing activities for the second quarter 2025 was an outflow of $5.4 billion, and included cash capital expenditure of $5.8 billion. This outflow was partly offset by interest received of $0.5 billion.

Net debt and Gearing: At the end of the second quarter 2025, net debt was $43.2 billion, compared with $41.5 billion at the end of the first quarter 2025. This reflects free cash flow of $6.5 billion, more than offset by share buybacks of $3.5 billion, cash dividends paid to Shell plc shareholders of $2.1 billion, lease additions of $1.4 billion and interest payments of $1.2 billion. Gearing was 19.1% at the end of the second quarter 2025, compared with 18.7% at the end of the first quarter 2025, mainly driven by higher net debt.

Shareholder distributions

Total shareholder distributions in the quarter amounted to $5.7 billion comprising repurchases of shares of $3.5 billion and cash dividends paid to Shell plc shareholders of $2.1 billion. Dividends to be paid to Shell plc shareholders for the

SHELL PLC
2nd QUARTER 2025 AND HALF YEAR UNAUDITED RESULTS

second quarter 2025 amount to $0.3580 per share. Shell has now completed $3.5 billion of share buybacks announced in the first quarter 2025 results announcement. Today, Shell announces a share buyback programme of $3.5 billion which is expected to be completed by the third quarter 2025 results announcement.

Half Year Analysis1

Income attributable to Shell plc shareholders, compared with the first half 2024, reflected lower trading and optimisation margins, lower realised liquids and LNG prices, and lower refining and chemical margins, partly offset by lower operating expenses and favourable tax movements.

Our continued focus on performance, discipline and simplification has helped deliver $3.9 billion of pre-tax structural cost reductions3 since 2022. Of these reductions, $0.8 billion was delivered in the first half 2025.

First half 2025 income attributable to Shell plc shareholders also included impairment charges, a charge related to the UK Energy Profits Levy and favourable movements due to the fair value accounting of commodity derivatives. These items are included in identified items amounting to a net loss of $1.2 billion. This compares with identified items in the first half 2024 which amounted to a net loss of $3.3 billion.

Adjusted Earnings and Adjusted EBITDA2 for the first half 2025 were driven by the same factors as income attributable to Shell plc shareholders and adjusted for identified items and the cost of supplies adjustment of $0.3 billion.

Cash flow from operating activities for the first half 2025 was $21.2 billion, and primarily driven by Adjusted EBITDA. This inflow was partly offset by tax payments of $6.3 billion and working capital outflows of $3.0 billion.

Cash flow from investing activities for the first half 2025 was an outflow of $9.4 billion and included cash capital expenditure of $10.0 billion, and net other investing cash outflows of $0.9 billion, which included the drawdowns on loan facilities provided at completion of the sale of The Shell Petroleum Development Company of Nigeria Limited (SPDC) in Nigeria. These outflows were partly offset by interest received of $1.0 billion.

This Unaudited Condensed Interim Financial Report, together with supplementary financial and operational disclosure for this quarter, is available at www.shell.com/investors 4.

1.All earnings amounts are shown post-tax, unless stated otherwise.

2.Adjusted EBITDA is without taxation, exploration well write-offs and depreciation, depletion and amortisation (DD&A) expenses.

3.Structural cost reductions describe decreases in underlying operating expenses as a result of operational efficiencies, divestments, workforce reductions and other cost-saving measures that are expected to be sustainable compared with 2022 levels.

4.Not incorporated by reference.

PORTFOLIO DEVELOPMENTS

Integrated Gas

In June 2025, we announced that the first cargo of liquefied natural gas (LNG) had left the LNG Canada facility on the west coast of Canada. Shell has a 40% working interest in the LNG Canada joint venture. Located in Kitimat, British Columbia, the facility will export LNG from two processing units or “trains” with a total capacity of 14 million tonnes per annum (mtpa).

Upstream

In May 2025, we completed the previously announced agreement to increase our working interest in the Shell-operated Ursa platform in the Gulf of America from 45.39% to 61.35%.

In May 2025, we announced the start of production at the floating production storage and offloading facility (FPSO) Alexandre de Gusmão in the Mero field in the Santos Basin offshore Brazil. The unitized Mero field is operated by Petrobras (38.6%), in partnership with Shell Brasil (19.3%), TotalEnergies (19.3%), CNPC (9.65%), CNOOC (9.65%) and Pré-Sal Petróleo S.A. (PPSA) (3.5%) representing the Government in the non-contracted area.

In May 2025, we signed an agreement to acquire a 12.5% interest in the OML 118 Production Sharing Contract (OML 118 PSC) from TotalEnergies EP Nigeria Limited. Upon completion, Shell’s working interest in the OML 118 PSC is expected to increase from 55% to a maximum of 67.5%.

Chemicals and Products

In April 2025, we completed the previously announced sale of our Energy and Chemicals Park in Singapore to CAPGC Pte. Ltd. (CAPGC), a joint venture between Chandra Asri Capital Pte. Ltd. and Glencore Asian Holdings Pte. Ltd.

In April 2025, we agreed to sell our 16.125% interest in Colonial Enterprises, Inc. (“Colonial”) to Colossus AcquireCo LLC, a wholly owned subsidiary of Brookfield Infrastructure Partners L.P. and its institutional partners (collectively, “Brookfield”), for $1.45 billion. The transaction is subject to regulatory approvals.

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SHELL PLC
2nd QUARTER 2025 AND HALF YEAR UNAUDITED RESULTS

PERFORMANCE BY SEGMENT



INTEGRATED GAS
Quarters				$ million		Half year
Q2 2025	Q1 2025	Q2 2024	%¹		Reference	2025	2024	%

1,838	2,789	2,454	-34	Income/(loss) for the period		4,627	5,215	-11
101	306	(220)		Of which: Identified items	A	407	(1,139)
1,737	2,483	2,675	-30	Adjusted Earnings	A	4,220	6,354	-34
3,875	4,735	5,039	-18	Adjusted EBITDA	A	8,610	11,175	-23
3,629	3,463	4,183	+5	Cash flow from operating activities	A	7,092	8,895	-20
1,196	1,116	1,151		Cash capital expenditure	C	2,313	2,192
129	126	137	+2	Liquids production available for sale (thousand b/d)		128	137	-7
4,545	4,644	4,885	-2	Natural gas production available for sale (million scf/d)		4,594	4,919	-7
913	927	980	-2	Total production available for sale (thousand boe/d)		920	986	-7
6.72	6.60	6.95	+2	LNG liquefaction volumes (million tonnes)		13.32	14.53	-8
17.77	16.49	16.41	+8	LNG sales volumes (million tonnes)		34.26	33.28	+3

1.Q2 on Q1 change

Integrated Gas includes liquefied natural gas (LNG), conversion of natural gas into gas-to-liquids (GTL) fuels and other products. It includes natural gas and liquids exploration and extraction, and the operation of the upstream and midstream infrastructure necessary to deliver these to market. Integrated Gas also includes the marketing, trading and optimisation of LNG.

Quarter Analysis1

Income/(loss) for the period was driven by the same factors as Adjusted Earnings and includes identified items.

Adjusted Earnings, compared with the first quarter 2025, reflected the combined effect of lower contributions from trading and optimisation and lower realised prices (decrease of $589 million), and higher depreciation, depletion and amortisation expenses (increase of $162 million).

Identified items in the second quarter 2025 included favourable movements of $454 million due to the fair value accounting of commodity derivatives, partly offset by impairment charges of $423 million. These favourable movements and impairment charges compare with the first quarter 2025 which included favourable movements of $362 million due to the fair value accounting of commodity derivatives. As part of Shell’s normal business, commodity derivative contracts are entered into as hedges for mitigation of economic exposures on future purchases, sales and inventory.

Adjusted EBITDA2 was driven by the same factors as Adjusted Earnings.

Cash flow from operating activities for the second quarter 2025 was primarily driven by Adjusted EBITDA, net cash inflows related to derivatives of $542 million and working capital inflows of $352 million. These inflows were partly offset by tax payments of $967 million.

Total oil and gas production, compared with the first quarter 2025, decreased by 2% mainly due to higher planned maintenance across the portfolio. LNG liquefaction volumes increased by 2% mainly due to ramp-up in Australia, following unplanned maintenance and weather constraints in the first quarter, partly offset by higher planned maintenance across the portfolio.

Half Year Analysis1

Income/(loss) for the period was driven by the same factors as Adjusted Earnings and includes identified items.

Adjusted Earnings, compared with the first half 2024, reflected the combined effect of lower contributions from trading and optimisation and lower realised prices (decrease of $1,894 million), lower volumes (decrease of $373 million), and higher depreciation, depletion and amortisation expenses (increase of $120 million), partly offset by lower operating expenses (decrease of $107 million), and favourable deferred tax movements ($99 million).

Identified items in the first half 2025 included favourable movements of $817 million due to the fair value accounting of commodity derivatives, partly offset by impairment charges of $423 million. These favourable movements and charges are part of identified items and compare with the first half 2024 which included unfavourable movements of $985 million due

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SHELL PLC
2nd QUARTER 2025 AND HALF YEAR UNAUDITED RESULTS

to the fair value accounting of commodity derivatives. As part of Shell’s normal business, commodity derivative contracts are entered into for mitigation of economic exposures on future purchases, sales and inventory.

Adjusted EBITDA2 was driven by the same factors as Adjusted Earnings.

Cash flow from operating activities for the first half 2025 was primarily driven by Adjusted EBITDA, and net cash inflows related to derivatives of $1,084 million. These inflows were partly offset by tax payments of $1,741 million and working capital outflows of $335 million.

Total oil and gas production, compared with the first half 2024, decreased by 7% mainly due to higher maintenance across the portfolio and weather constraints in Australia. LNG liquefaction volumes decreased by 8% mainly due to higher maintenance across the portfolio.

1.All earnings amounts are shown post-tax, unless stated otherwise.

2.Adjusted EBITDA is without taxation, exploration well write-offs and DD&A expenses.

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SHELL PLC
2nd QUARTER 2025 AND HALF YEAR UNAUDITED RESULTS



UPSTREAM
Quarters				$ million		Half year
Q2 2025	Q1 2025	Q2 2024	%¹		Reference	2025	2024	%

2,008	2,080	2,179	-3	Income/(loss) for the period		4,088	4,451	-8
276	(257)	(157)		Of which: Identified items	A	19	182
1,732	2,337	2,336	-26	Adjusted Earnings	A	4,068	4,270	-5
6,638	7,387	7,829	-10	Adjusted EBITDA	A	14,024	15,717	-11
6,500	3,945	5,739	+65	Cash flow from operating activities	A	10,445	11,466	-9
2,826	1,923	1,829		Cash capital expenditure	C	4,749	3,839
1,334	1,335	1,297	—	Liquids production available for sale (thousand b/d)		1,334	1,314	+2
2,310	3,020	2,818	-24	Natural gas production available for sale (million scf/d)		2,663	2,977	-11
1,732	1,855	1,783	-7	Total production available for sale (thousand boe/d)		1,793	1,828	-2

1.Q2 on Q1 change

The Upstream segment includes exploration and extraction of crude oil, natural gas and natural gas liquids. It also markets and transports oil and gas, and operates the infrastructure necessary to deliver them to the market.

Quarter Analysis1

Income/(loss) for the period was driven by the same factors as Adjusted Earnings and includes identified items.

Adjusted Earnings, compared with the first quarter 2025, reflected lower realised liquids and gas prices (decrease of $594 million) and higher depreciation, depletion and amortisation expenses (increase of $154 million), partly offset by higher volumes (increase of $112 million).

Identified items in the second quarter 2025 included gains of $350 million from disposal of assets. These favourable movements compare with the first quarter 2025 which included a charge of $509 million related to the UK Energy Profits Levy, partly offset by gains of $159 million from disposal of assets and gains of $95 million related to the impact of the strengthening Brazilian real on a deferred tax position.

Adjusted EBITDA2 was driven by the same factors as Adjusted Earnings.

Cash flow from operating activities for the second quarter 2025 was primarily driven by Adjusted EBITDA, dividends (net of profits) from joint ventures and associates of $1,542 million and working capital inflows of $655 million. These inflows were partly offset by tax payments of $1,948 million.

Total production, compared with the first quarter 2025, decreased mainly due to the SPDC divestment and higher planned maintenance, partly offset by new oil production.

Half Year Analysis1

Income/(loss) for the period was driven by the same factors as Adjusted Earnings and includes identified items.

Adjusted Earnings, compared with the first half 2024, reflected lower realised prices (decrease of $1,262 million) and the comparative unfavourable impact of gas storage effects (decrease of $499 million), partly offset by lower exploration well write-offs (decrease of $574 million), lower depreciation, depletion and amortisation expenses (decrease of $375 million), lower operating expenses (decrease of $245 million) and favourable tax movements ($143 million).

Identified items in the first half 2025 included gains of $509 million from disposal of assets and a gain of $168 million related to the impact of the strengthening Brazilian real on a deferred tax position, offset by a charge of $509 million related to the UK Energy Profits Levy. These favourable movements and charges compare with the first half 2024 which included gains of $599 million related to the impact of inflationary adjustments in Argentina on a deferred tax position, partly offset by a loss of $191 million related to the impact of the weakening Brazilian real on a deferred tax position and impairment charges of $169 million.

Adjusted EBITDA2 was driven by the same factors as Adjusted Earnings.

Cash flow from operating activities for the first half 2025 was primarily driven by Adjusted EBITDA and dividends (net of profits) from joint ventures and associates of $1,384 million. These inflows were partly offset by tax payments of $3,946 million.

Total production, compared with the first half 2024, decreased mainly due to the SPDC divestment and field decline largely offset by new oil production.

1.All earnings amounts are shown post-tax, unless stated otherwise.

2.Adjusted EBITDA is without taxation, exploration well write-offs and DD&A expenses.

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SHELL PLC
2nd QUARTER 2025 AND HALF YEAR UNAUDITED RESULTS



MARKETING
Quarters				$ million		Half year
Q2 2025	Q1 2025	Q2 2024	%¹		Reference	2025	2024	%

766	814	202	-6	Income/(loss) for the period		1,580	1,099	+44
(354)	(49)	(825)		Of which: Identified items	A	(402)	(832)

1,199	900	1,082	+33	Adjusted Earnings	A	2,100	1,863	+13
2,181	1,869	1,999	+17	Adjusted EBITDA	A	4,049	3,686	+10
2,718	1,907	1,958	+43	Cash flow from operating activities	A	4,625	3,277	+41
429	256	644		Cash capital expenditure	C	684	1,109
2,813	2,674	2,868	+5	Marketing sales volumes (thousand b/d)		2,744	2,816	-3

1.Q2 on Q1 change

The Marketing segment comprises the Mobility, Lubricants, and Sectors and Decarbonisation businesses. The Mobility business operates Shell’s retail network including electric vehicle charging services and the Wholesale commercial fuels business which provides fuels for transport and industry. The Lubricants business produces, markets and sells lubricants for road transport, and machinery used in manufacturing, mining, power generation, agriculture and construction. The Sectors and Decarbonisation business sells fuels, speciality products and services including low-carbon energy solutions to a broad range of commercial customers including the aviation, marine, and agricultural sectors.

Quarter Analysis1

Income/(loss) for the period was driven by the same factors as Adjusted Earnings and includes identified items.

Adjusted Earnings, compared with the first quarter 2025, reflected higher Marketing margins (increase of $282 million) mainly due to higher Mobility unit margins and seasonal impact of higher volumes, stable Lubricants margins and Sectors and Decarbonisation margins, and favourable tax movements ($92 million). These net gains were partly offset by higher operating expenses (increase of $41 million).

Identified items in the second quarter 2025 included net impairment charges and reversals of $285 million, net losses of $44 million related to the sale of assets, and charges of $44 million related to redundancy and restructuring. These charges and net losses compare with the first quarter 2025 which included net losses of $61 million related to the sale of assets.

Adjusted EBITDA2 was driven by the same factors as Adjusted Earnings.

Cash flow from operating activities for the second quarter 2025 was primarily driven by Adjusted EBITDA, inflows relating to the timing impact of payments related to emission certificates and biofuel programmes of $515 million, dividends (net of profits/losses) from joint ventures and associates of $161 million and working capital inflows of $67 million. These inflows were partly offset by tax payments of $132 million, and non-cash cost of supplies adjustment of $104 million.

Marketing sales volumes (comprising hydrocarbon sales), compared with the first quarter 2025, increased mainly due to seasonality.

Half Year Analysis1

Income/(loss) for the period was driven by the same factors as Adjusted Earnings and includes identified items.

Adjusted Earnings, compared with the first half 2024, reflected lower operating expenses (decrease of $199 million) and higher Marketing margins (increase of $71 million) including higher Mobility and Lubricants margins due to improved unit margins, partly offset by lower Sectors and Decarbonisation margins.

Identified items in the first half 2025 included net impairment charges and reversals of $278 million and net losses of $105 million related to sale of assets. These charges and net losses compare with the first half 2024 which included impairment charges of $786 million mainly relating to an asset in the Netherlands, charges of $65 million related to redundancy and restructuring, and net losses of $56 million related to the sale of assets, partly offset by favourable movements of $50 million relating to the fair value accounting of commodity derivatives.

Adjusted EBITDA2 was driven by the same factors as Adjusted Earnings.

Cash flow from operating activities for the first half 2025 was primarily driven by Adjusted EBITDA, inflows relating to the timing impact of payments related to emission certificates and biofuel programmes of $1,055 million, dividends (net of

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SHELL PLC
2nd QUARTER 2025 AND HALF YEAR UNAUDITED RESULTS

profits/losses) from joint ventures and associates of $365 million. These inflows were partly offset by tax payments of $306 million, working capital outflows of $277 million and non-cash cost of supplies adjustment of $156 million.

Marketing sales volumes (comprising hydrocarbon sales), compared with the first half 2024, decreased mainly in Mobility due to portfolio changes and in Sectors and Decarbonisation.

1.All earnings amounts are shown post-tax, unless stated otherwise.

2.Adjusted EBITDA is without taxation and DD&A expenses.

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SHELL PLC
2nd QUARTER 2025 AND HALF YEAR UNAUDITED RESULTS



CHEMICALS AND PRODUCTS
Quarters				$ million		Half year
Q2 2025	Q1 2025	Q2 2024	%¹		Reference	2025	2024	%

(174)	(77)	545	-125	Income/(loss) for the period		(252)	1,856	-114
(51)	(581)	(499)		Of which: Identified items	A	(631)	(956)

118	449	1,085	-74	Adjusted Earnings	A	567	2,700	-79
864	1,410	2,242	-39	Adjusted EBITDA	A	2,274	5,068	-55
1,372	130	2,249	+956	Cash flow from operating activities	A	1,502	1,900	-21
775	458	638		Cash capital expenditure	C	1,233	1,138
1,156	1,362	1,429	-15	Refinery processing intake (thousand b/d)		1,258	1,429	-12
2,164	2,813	3,052	-23	Chemicals sales volumes (thousand tonnes)		4,977	5,934	-16

1.Q2 on Q1 change

The Chemicals and Products segment includes chemicals manufacturing plants with their own marketing network, and refineries which turn crude oil and other feedstocks into a range of oil products which are moved and marketed around the world for domestic, industrial and transport use. The segment also includes the pipeline business, trading and optimisation of crude oil, oil products and petrochemicals, and Oil Sands activities (the extraction of bitumen from mined oil sands and its conversion into synthetic crude oil).

Quarter Analysis1

Income/(loss) for the period was driven by the same factors as Adjusted Earnings and includes identified items.

Adjusted Earnings, compared with the first quarter 2025, reflected lower Products margins (decrease of $450 million) mainly driven by lower margins from trading and optimisation, partly offset by higher refining margins. Adjusted Earnings also reflected lower Chemicals margins (decrease of $103 million). These net losses were partly offset by favourable tax movements ($96 million) and lower operating expenses (decrease of $58 million).

In the second quarter 2025, Chemicals had negative Adjusted Earnings of $192 million and Products had positive Adjusted Earnings of $310 million.

Identified items in the second quarter 2025 included impairment charges of $62 million. These charges compare with the first quarter 2025 which included impairment charges of $277 million and unfavourable movements of $202 million due to the fair value accounting of commodity derivatives that, as part of Shell’s normal business, are entered into as hedges for mitigation of economic exposures on future purchases, sales and inventory.

Adjusted EBITDA2 was driven by the same factors as Adjusted Earnings.

Cash flow from operating activities for the second quarter 2025 was primarily driven by Adjusted EBITDA, inflows relating to the timing impact of payments relating to emission certificates and biofuel programmes of $367 million and working capital inflows of $383 million. These inflows were partly offset by non-cash cost of supplies adjustment of $333 million.

Refinery utilisation was 94% compared with 85% in the first quarter 2025, mainly due to lower planned and unplanned maintenance.

Chemicals manufacturing plant utilisation was 72% compared with 81% in the first quarter 2025, mainly due to higher planned maintenance, and unplanned maintenance mainly in Monaca.

Half Year Analysis1

Income/(loss) for the period was driven by the same factors as Adjusted Earnings and includes identified items.

Adjusted Earnings, compared with the first half 2024, reflected lower Products margins (decrease of $1,960 million), driven mainly by lower margins from trading and optimisation and lower refining margins. Adjusted Earnings also reflected lower Chemicals margins (decrease of $415 million). These net losses were partly offset by lower operating expenses (decrease of $180 million) and favourable tax movements ($70 million).

Identified items in the first half 2025 included impairment charges of $339 million and unfavourable movements of $153 million due to the fair value accounting of commodity derivatives. These charges and unfavourable movements compare with the first half 2024 which included net impairment charges and reversals of $860 million mainly relating to assets in Singapore, and unfavourable movements of $163 million relating to the fair value accounting of commodity derivatives.

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2nd QUARTER 2025 AND HALF YEAR UNAUDITED RESULTS

Adjusted EBITDA2 was driven by the same factors as Adjusted Earnings.

In the first half 2025, Chemicals had negative Adjusted Earnings of $329 million and Products had positive Adjusted Earnings of $896 million.

Cash flow from operating activities for the first half 2025 was primarily driven by Adjusted EBITDA, inflows related to the timing impact of payments relating to emission certificates and biofuel programmes of $492 million, and dividends (net of profits) from joint ventures and associates of $124 million. These inflows were partly offset by working capital outflows of $698 million, net cash outflows relating to commodity derivatives of $504 million, and non-cash cost of supplies adjustment of $266 million.

Refinery utilisation was 89% compared with 92% in the first half 2024, mainly due to higher planned and unplanned maintenance.

Chemicals manufacturing plant utilisation was 77%, at the same level as in the first half 2024.

1.All earnings amounts are shown post-tax, unless stated otherwise.

2.Adjusted EBITDA is without taxation and DD&A expenses.

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RENEWABLES AND ENERGY SOLUTIONS
Quarters				$ million		Half year
Q2 2025	Q1 2025	Q2 2024	%¹		Reference	2025	2024	%

(254)	(247)	(75)	-3	Income/(loss) for the period		(501)	478	-205
(245)	(205)	112		Of which: Identified items	A	(450)	501
(9)	(42)	(187)	+78	Adjusted Earnings	A	(51)	(24)	-116
102	111	(91)	-8	Adjusted EBITDA	A	213	175	+21
1	367	847	-100	Cash flow from operating activities	A	368	3,313	-89
555	403	425		Cash capital expenditure	C	958	863
70	76	74	-9	External power sales (terawatt hours)2		146	151	-3
132	184	148	-28	Sales of pipeline gas to end-use customers (terawatt hours)3		315	338	-7

1.Q2 on Q1 change

2.Physical power sales to third parties; excluding financial trades and physical trade with brokers, investors, financial institutions, trading platforms, and wholesale traders.

3.Physical natural gas sales to third parties; excluding financial trades and physical trade with brokers, investors, financial institutions, trading platforms, and wholesale traders. Excluding sales of natural gas by other segments and LNG sales.

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

Quarter Analysis1

Income/(loss) for the period was driven by the same factors as Adjusted Earnings and includes identified items.

Adjusted Earnings, compared with the first quarter 2025, reflected lower operating expenses (decrease of $54 million) and favourable tax movements ($33 million), partly offset by lower margins (decrease of $56 million).

Most Renewables and Energy Solutions activities were loss-making in the second quarter 2025, which was partly offset by positive Adjusted Earnings from trading and optimisation.

Identified items in the second quarter 2025 included unfavourable movements of $217 million due to the fair value accounting of commodity derivatives and impairment charges of $136 million, partly offset by gains of $108 million on sales of assets. These charges and favourable movements compare with the first quarter 2025 which included a loss of $143 million related to the disposal of assets. As part of Shell’s normal business, commodity derivative contracts are entered into as hedges for mitigation of economic exposures on future purchases, sales and inventory.

Adjusted EBITDA2 was driven by the same factors as Adjusted Earnings.

Cash flow from operating activities for the second quarter 2025 was primarily driven by Adjusted EBITDA. This inflow was offset by working capital outflows of $128 million.

Half Year Analysis1

Income/(loss) for the period was driven by the same factors as Adjusted Earnings and includes identified items.

Adjusted Earnings, compared with the first half 2024, reflected lower margins (decrease of $140 million), mainly from trading and optimisation, partly offset by lower operating expenses (decrease of $115 million).

Most Renewables and Energy Solutions activities were loss-making for the first half 2025, which was partly offset by positive Adjusted Earnings from trading and optimisation.

Identified items in the first half 2025 included unfavourable movements of $196 million relating to the fair value accounting of commodity derivatives and impairment losses of $167 million. These net charges compare with the first half 2024 which included favourable movements of $529 million relating to the fair value accounting of commodity derivatives, partly offset by net impairment charges and reversals of $78 million. As part of Shell’s normal business, commodity derivative contracts are entered into for mitigation of economic exposures on future purchases, sales and inventory.

Adjusted EBITDA2 was driven by the same factors as Adjusted Earnings.

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2nd QUARTER 2025 AND HALF YEAR UNAUDITED RESULTS

Cash flow from operating activities for the first half 2025 was primarily driven by working capital inflows of $252 million and Adjusted EBITDA. These inflows were partly offset by net cash outflows related to derivatives of $235 million.

1.All earnings amounts are shown post-tax, unless stated otherwise.

2.Adjusted EBITDA is without taxation and DD&A expenses.

Additional Growth Measures


Quarters					Half year
Q2 2025	Q1 2025	Q2 2024	%¹		2025	2024	%
				Renewable power generation capacity (gigawatt):
3.9	3.5	3.3	+10	– In operation2	3.9	3.3	+16
3.8	4.0	3.8	-5	– Under construction and/or committed for sale3	3.8	3.8	-1

1.Q2 on Q1 change

2.Shell’s equity share of renewable generation capacity post commercial operation date. It excludes Shell’s equity share of associates where information cannot be obtained.

3.Shell’s equity share of renewable generation capacity under construction and/or committed for sale under long-term offtake agreements (PPA). It excludes Shell’s equity share of associates where information cannot be obtained.



CORPORATE
Quarters			$ million		Half year
Q2 2025	Q1 2025	Q2 2024		Reference	2025	2024

(539)	(483)	(1,656)	Income/(loss) for the period		(1,022)	(2,010)
(77)	(26)	(1,080)	Of which: Identified items	A	(102)	(1,066)
(463)	(457)	(576)	Adjusted Earnings	A	(920)	(944)
(346)	(261)	(213)	Adjusted EBITDA	A	(607)	(304)
(2,283)	(531)	(1,468)	Cash flow from operating activities	A	(2,814)	(2,013)

The Corporate segment covers the non-operating activities supporting Shell. It comprises Shell’s holdings and treasury organisation, headquarters and central functions, self-insurance activities and centrally managed longer-term innovation portfolio. All finance expense, income and related taxes are included in Corporate Adjusted Earnings rather than in the earnings of business segments.

Quarter Analysis1

Income/(loss) for the period was driven by the same factors as Adjusted Earnings and includes identified items.

Adjusted Earnings, compared with the first quarter 2025, reflected unfavourable tax movements and unfavourable currency exchange rate effects, partly offset by favourable net interest movements.

Adjusted EBITDA2 was mainly driven by unfavourable currency exchange rate effects.

Cash flow from operating activities for the second quarter 2025 was primarily driven by working capital outflows of $1,715 million, which included a reduction in joint venture deposits, and Adjusted EBITDA.

Half Year Analysis1

Income/(loss) for the period was driven by the same factors as Adjusted Earnings and includes identified items.

Adjusted Earnings, compared with the first half 2024, were primarily driven by favourable tax movements, partly offset by unfavourable currency exchange rate effects and unfavourable net interest movements.

Identified items in the first half 2024 included reclassifications from equity to profit and loss of cumulative currency translation differences related to funding structures resulting in unfavourable movements of $1,122 million. These currency

translation differences were previously recognised in other comprehensive income and accumulated in equity as part of

accumulated other comprehensive income.

Adjusted EBITDA2 was mainly driven by unfavourable currency exchange rate effects.

Cash flow from operating activities for the first half 2025 was primarily driven by working capital outflows of $1,734 million, which included a reduction in joint venture deposits, and Adjusted EBITDA.

1.All earnings amounts are shown post-tax, unless stated otherwise.

2.Adjusted EBITDA is without taxation and DD&A expenses.

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OUTLOOK FOR THE THIRD QUARTER 2025

Full year 2024 cash capital expenditure was $21 billion. Our cash capital expenditure range for the full year 2025 is expected to be within $20 – $22 billion.

Integrated Gas production is expected to be approximately 910 – 970 thousand boe/d. LNG liquefaction volumes are expected to be approximately 6.7 – 7.3 million tonnes.

Upstream production is expected to be approximately 1,700 – 1,900 thousand boe/d.

Marketing sales volumes are expected to be approximately 2,600 – 3,100 thousand b/d.

Refinery utilisation is expected to be approximately 88% – 96%. Chemicals manufacturing plant utilisation is expected to be approximately 78% – 86%.

Corporate Adjusted Earnings1 were a net expense of $463 million for the second quarter 2025. Corporate Adjusted Earnings are expected to be a net expense of approximately $500 – $700 million in the third quarter 2025.

1.For the definition of Adjusted Earnings and the most comparable GAAP measure see Reference A.

FORTHCOMING EVENTS



Date			Event
October 30, 2025			Third quarter 2025 results and dividends

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2nd QUARTER 2025 AND HALF YEAR UNAUDITED RESULTS

UNAUDITED CONDENSED CONSOLIDATED INTERIM FINANCIAL STATEMENTS



CONSOLIDATED STATEMENT OF INCOME
Quarters			$ million	Half year
Q2 2025	Q1 2025	Q2 2024		2025	2024
65,406	69,234	74,463	Revenue1	134,640	146,942
712	615	898	Share of profit/(loss) of joint ventures and associates	1,327	2,216
326	302	(305)	Interest and other income/(expenses)2	628	602
66,443	70,152	75,057	Total revenue and other income/(expenses)	136,596	149,760
44,099	45,849	49,417	Purchases	89,948	96,284
4,909	5,549	5,593	Production and manufacturing expenses	10,459	11,403
3,077	2,840	3,094	Selling, distribution and administrative expenses	5,917	6,069
278	185	263	Research and development	464	475
360	210	496	Exploration	569	1,246
6,670	5,441	7,555	Depreciation, depletion and amortisation2	12,111	13,436
1,075	1,120	1,235	Interest expense	2,194	2,399
60,468	61,194	67,653	Total expenditure	121,662	131,312
5,975	8,959	7,404	Income/(loss) before taxation	14,934	18,447
2,332	4,083	3,754	Taxation charge/(credit)2	6,415	7,358
3,644	4,875	3,650	Income/(loss) for the period	8,519	11,089
43	95	133	Income/(loss) attributable to non-controlling interest	138	215
3,601	4,780	3,517	Income/(loss) attributable to Shell plc shareholders	8,381	10,874
0.61	0.79	0.55	Basic earnings per share ($)3	1.40	1.70
0.60	0.79	0.55	Diluted earnings per share ($)3	1.39	1.68

1.See Note 2 “Segment information”.

2.See Note 7 “Other notes to the unaudited Condensed Consolidated Interim Financial Statements”.

3.See Note 3 “Earnings per share”.



CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME
Quarters			$ million	Half year
Q2 2025	Q1 2025	Q2 2024		2025	2024
3,644	4,875	3,650	Income/(loss) for the period	8,519	11,089
			Other comprehensive income/(loss) net of tax:
			Items that may be reclassified to income in later periods:
4,127	1,711	698	– Currency translation differences1	5,837	(1,296)
7	6	(12)	– Debt instruments remeasurements	14	(19)
(109)	(25)	14	– Cash flow hedging gains/(losses)	(135)	67
5	(42)	(6)	– Deferred cost of hedging	(37)	(20)
113	74	(50)	– Share of other comprehensive income/(loss) of joint ventures and associates	187	(62)
4,143	1,723	644	Total	5,866	(1,330)
			Items that are not reclassified to income in later periods:
158	306	310	– Retirement benefits remeasurements	465	749
(8)	(16)	(81)	– Equity instruments remeasurements	(24)	(3)
(23)	(36)	44	– Share of other comprehensive income/(loss) of joint ventures and associates	(59)	55
128	254	273	Total	381	801
4,270	1,977	917	Other comprehensive income/(loss) for the period	6,248	(529)
7,914	6,852	4,567	Comprehensive income/(loss) for the period	14,767	10,560
122	105	123	Comprehensive income/(loss) attributable to non-controlling interest	227	180
7,792	6,748	4,443	Comprehensive income/(loss) attributable to Shell plc shareholders	14,540	10,381

1.See Note 7 “Other notes to the unaudited Condensed Consolidated Interim Financial Statements”.

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2nd QUARTER 2025 AND HALF YEAR UNAUDITED RESULTS



CONDENSED CONSOLIDATED BALANCE SHEET
$ million
	June 30, 2025	December 31, 2024
Assets
Non-current assets
Goodwill	16,332	16,032
Other intangible assets	11,338	9,480
Property, plant and equipment	186,461	185,219
Joint ventures and associates	23,456	23,445
Investments in securities	2,225	2,255
Deferred tax	7,524	6,857
Retirement benefits	10,980	10,003
Trade and other receivables	7,315	6,018
Derivative financial instruments1	692	374
	266,323	259,683
Current assets
Inventories	23,283	23,426
Trade and other receivables	45,570	45,860
Derivative financial instruments1	9,443	9,673
Cash and cash equivalents	32,682	39,110
	110,978	118,069
Assets classified as held for sale2	10,619	9,857
	121,597	127,926
Total assets	387,920	387,609
Liabilities
Non-current liabilities
Debt	65,218	65,448
Trade and other payables	5,876	3,290
Derivative financial instruments1	1,037	2,185
Deferred tax	12,921	13,505
Retirement benefits	6,983	6,752
Decommissioning and other provisions	20,777	21,227
	112,813	112,407
Current liabilities
Debt	10,457	11,630
Trade and other payables	58,379	60,693
Derivative financial instruments1	6,451	7,391
Income taxes payable	3,642	4,648
Decommissioning and other provisions	5,234	4,469
	84,164	88,831
Liabilities directly associated with assets classified as held for sale2	7,856	6,203
	92,020	95,034
Total liabilities	204,832	207,441
Equity attributable to Shell plc shareholders	181,137	178,307
Non-controlling interest	1,951	1,861
Total equity	183,088	180,168
Total liabilities and equity	387,920	387,609

1. See Note 6 “Derivative financial instruments and debt excluding lease liabilities”.

2. .See Note 7 “Other notes to the unaudited Condensed Consolidated Interim Financial Statements”.

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CONSOLIDATED STATEMENT OF CHANGES IN EQUITY
	Equity attributable to Shell plc shareholders
$ million	Share capital1	Shares held in trust	Other reserves²	Retained earnings	Total	Non-controlling interest	Total equity
At January 1, 2025	510	(803)	19,766	158,834	178,307	1,861	180,168
Comprehensive income/(loss) for the period	—	—	6,159	8,381	14,540	227	14,767
Transfer from other comprehensive income	—	—	18	(18)	—	—	—
Dividends³	—	—	—	(4,302)	(4,302)	(113)	(4,415)
Repurchases of shares4	(17)	—	17	(7,038)	(7,038)	—	(7,038)
Share-based compensation	—	516	(486)	(426)	(396)	—	(396)
Other changes	—	—	—	29	29	(24)	5
At June 30, 2025	493	(288)	25,473	155,458	181,137	1,951	183,088
At January 1, 2024	544	(997)	21,145	165,915	186,607	1,755	188,362
Comprehensive income/(loss) for the period	—	—	(494)	10,874	10,381	180	10,560
Transfer from other comprehensive income	—	—	170	(170)	—	—	—
Dividends3	—	—	—	(4,387)	(4,387)	(150)	(4,537)
Repurchases of shares4	(17)	—	17	(7,020)	(7,020)	—	(7,020)
Share-based compensation	—	544	(213)	(406)	(76)	—	(76)
Other changes	—	—	—	(96)	(96)	(1)	(98)
At June 30, 2024	528	(454)	20,625	164,709	185,407	1,783	187,190

1. See Note 4 “Share capital”.

2. See Note 5 “Other reserves”.

3. The amount charged to retained earnings is based on prevailing exchange rates on payment date.

4. Includes shares committed to repurchase under an irrevocable contract and repurchases subject to settlement at the end of the quarter.

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CONSOLIDATED STATEMENT OF CASH FLOWS
Quarters			$ million	Half year
Q2 2025	Q1 2025	Q2 2024		2025	2024
5,975	8,959	7,404	Income before taxation for the period	14,934	18,447
			Adjustment for:
515	636	619	– Interest expense (net)	1,151	1,195
6,670	5,441	7,555	– Depreciation, depletion and amortisation1	12,111	13,436
206	28	269	– Exploration well write-offs	234	823
(128)	127	(143)	– Net (gains)/losses on sale and revaluation of non-current assets and businesses	(1)	(154)
(712)	(615)	(898)	– Share of (profit)/loss of joint ventures and associates	(1,327)	(2,216)
2,361	523	792	– Dividends received from joint ventures and associates1	2,884	1,530
(27)	854	(954)	– (Increase)/decrease in inventories	827	(1,562)
3,635	(2,610)	1,965	– (Increase)/decrease in current receivables	1,025	1,770
(3,994)	(907)	(1,269)	– Increase/(decrease) in current payables	(4,901)	(3,218)
626	(244)	253	– Derivative financial instruments	381	1,638
(17)	(100)	(332)	– Retirement benefits	(118)	(392)
(425)	(480)	(332)	– Decommissioning and other provisions	(906)	(931)
684	570	2,027	– Other1	1,254	2,536
(3,432)	(2,900)	(3,448)	Tax paid	(6,331)	(6,064)
11,937	9,281	13,508	Cash flow from operating activities	21,218	26,838
(5,393)	(3,748)	(4,445)	Capital expenditure	(9,141)	(8,424)
(406)	(413)	(261)	Investments in joint ventures and associates	(819)	(761)
(17)	(15)	(13)	Investments in equity securities	(32)	(25)
(5,817)	(4,175)	(4,719)	Cash capital expenditure	(9,993)	(9,211)
(57)	559	710	Proceeds from sale of property, plant and equipment and businesses1	502	1,033
1	33	57	Proceeds from joint ventures and associates from sale, capital reduction and repayment of long-term loans	34	190
19	5	2	Proceeds from sale of equity securities	24	570
508	508	648	Interest received	1,016	1,224
360	506	883	Other investing cash inflows	866	1,740
(420)	(1,394)	(920)	Other investing cash outflows	(1,814)	(2,414)
(5,406)	(3,959)	(3,338)	Cash flow from investing activities	(9,365)	(6,866)
(208)	80	(179)	Net increase/(decrease) in debt with maturity period within three months	(127)	(286)
			Other debt:
180	139	132	– New borrowings	319	299
(4,075)	(2,514)	(4,154)	– Repayments	(6,589)	(5,686)
(1,212)	(846)	(1,287)	Interest paid	(2,059)	(2,198)
896	326	(115)	Derivative financial instruments	1,222	(412)
—	(25)	(1)	Change in non-controlling interest	(25)	(5)
			Cash dividends paid to:
(2,122)	(2,179)	(2,177)	– Shell plc shareholders	(4,300)	(4,387)
(27)	(86)	(82)	– Non-controlling interest	(113)	(150)
(3,533)	(3,311)	(3,958)	Repurchases of shares	(6,844)	(6,782)
(5)	(768)	(24)	Shares held in trust: net sales/(purchases) and dividends received	(773)	(486)
(10,106)	(9,183)	(11,846)	Cash flow from financing activities	(19,289)	(20,094)
655	353	(126)	Effects of exchange rate changes on cash and cash equivalents	1,008	(505)
(2,919)	(3,509)	(1,801)	Increase/(decrease) in cash and cash equivalents	(6,428)	(627)
35,601	39,110	39,949	Cash and cash equivalents at beginning of period	39,110	38,774
32,682	35,601	38,148	Cash and cash equivalents at end of period	32,682	38,148

1.See Note 7 “Other notes to the unaudited Condensed Consolidated Interim Financial Statements”.

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NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED INTERIM FINANCIAL STATEMENTS

1. Basis of preparation

These unaudited Condensed Consolidated Interim Financial Statements of Shell plc (“the Company”) and its subsidiaries (collectively referred to as “Shell”) have been prepared in accordance with IAS 34 Interim Financial Reporting as issued by the International Accounting Standards Board (“IASB”) and adopted by the UK, and on the basis of the same accounting principles as those used in the Company’s Annual Report and Accounts (pages 240 to 312) for the year ended December 31, 2024, as filed with the Registrar of Companies for England and Wales and as filed with the Autoriteit Financiële Markten (the Netherlands) and Amendment No. 1 to Form 20-F (“Form 20-F/A”) (pages 10 to 83) for the year ended December 31, 2024, as filed with the US Securities and Exchange Commission, and should be read in conjunction with these filings.

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

Going Concern

These unaudited Condensed Consolidated Interim Financial Statements have been prepared on the going concern basis of accounting. In assessing the appropriateness of the going concern assumption over the period to December 31, 2026 (the ‘going concern period’), management have stress-tested Shell’s most recent financial projections to incorporate a range of potential future outcomes by considering Shell’s principal risks, potential downside pressures on commodity prices and long-term demand, and cash preservation measures, including reduced cash capital expenditure and shareholder distributions. This assessment confirmed that Shell has adequate cash, other liquid resources and undrawn credit facilities to enable it to meet its obligations as they fall due in order to continue its operations during the going concern period. Therefore, the Directors consider it appropriate to continue to adopt the going concern basis of accounting in preparing these unaudited Condensed Consolidated Interim Financial Statements.

Key accounting considerations, significant judgements and estimates

Future commodity price assumptions, which represent a significant estimate, were subject to change in the second quarter 2025 (See Note 7). Noting continued volatility in markets, price assumptions remain under review.

The discount rates applied for impairment testing and the discount rate applied to provisions are reviewed on a regular basis. Both discount rates applied in the first half year 2025 remain unchanged compared with 2024.

2. Segment information

With effect from January 1, 2025, segment earnings are presented on an Adjusted Earnings basis (Adjusted Earnings), which is the earnings measure used by the Chief Executive Officer, who serves as the Chief Operating Decision Maker, for the purposes of making decisions about allocating resources and assessing performance. This aligns with Shell’s focus on performance, discipline and simplification.

The Adjusted Earnings measure is presented on a current cost of supplies (CCS) basis and aims to facilitate a comparative understanding of Shell’s financial performance from period to period by removing the effects of oil price changes on inventory carrying amounts and removing the effects of identified items. Identified items are in some cases driven by external factors and may, either individually or collectively, hinder the comparative understanding of Shell’s financial results from period to period.

The segment earnings measure used until December 31, 2024 was CCS earnings. The difference between CCS earnings and Adjusted Earnings are the identified items. Comparative periods are presented below on an Adjusted Earnings basis.

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ADJUSTED EARNINGS BY SEGMENT



Q2 2025	$ million
	Integrated Gas	Upstream	Marketing	Chemicals and Products	Renewables and Energy Solutions	Corporate	Total
Income/(loss) attributable to Shell plc shareholders							3,601
Income/(loss) attributable to non-controlling interest							43
Income/(loss) for the period	1,838	2,008	766	(174)	(254)	(539)	3,644
Add: Current cost of supplies adjustment before taxation			104	333			436
Add: Tax on current cost of supplies adjustment			(24)	(91)			(115)
Less: Identified items before taxation	(102)	271	(460)	(64)	(300)	(63)	(717)
Add: Tax on identified items	(203)	(5)	(106)	(13)	(55)	14	(369)
Adjusted Earnings	1,737	1,732	1,199	118	(9)	(463)	4,314
Adjusted Earnings attributable to Shell plc shareholders							4,264
Adjusted Earnings attributable to non-controlling interest							50



Q1 2025	$ million
	Integrated Gas	Upstream	Marketing	Chemicals and Products	Renewables and Energy Solutions	Corporate	Total
Income/(loss) attributable to Shell plc shareholders							4,780
Income/(loss) attributable to non-controlling interest							95
Income/(loss) for the period	2,789	2,080	814	(77)	(247)	(483)	4,875
Add: Current cost of supplies adjustment before taxation			52	(67)			(15)
Add: Tax on current cost of supplies adjustment			(14)	12			(2)
Less: Identified items before taxation	348	121	(44)	(679)	(260)	4	(510)
Add: Tax on identified items	43	378	4	(99)	(54)	29	301
Adjusted Earnings	2,483	2,337	900	449	(42)	(457)	5,670
Adjusted Earnings attributable to Shell plc shareholders							5,577
Adjusted Earnings attributable to non-controlling interest							94



Q2 2024	$ million
	Integrated Gas	Upstream	Marketing	Chemicals and Products	Renewables and Energy Solutions	Corporate	Total
Income/(loss) attributable to Shell plc shareholders							3,517
Income/(loss) attributable to non-controlling interest							133
Income/(loss) for the period	2,454	2,179	202	545	(75)	(1,656)	3,650
Add: Current cost of supplies adjustment before taxation			74	59			133
Add: Tax on current cost of supplies adjustment			(19)	(17)			(36)
Less: Identified items before taxation	(260)	(215)	(1,111)	(333)	198	(1,105)	(2,826)
Add: Tax on identified items	(40)	(58)	(286)	165	87	(25)	(157)
Adjusted Earnings	2,675	2,336	1,082	1,085	(187)	(576)	6,415
Adjusted Earnings attributable to Shell plc shareholders							6,293
Adjusted Earnings attributable to non-controlling interest							122

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2nd QUARTER 2025 AND HALF YEAR UNAUDITED RESULTS



Half year 2025	$ million
	Integrated Gas	Upstream	Marketing	Chemicals and Products	Renewables and Energy Solutions	Corporate	Total
Income/(loss) attributable to Shell plc shareholders							8,381
Income/(loss) attributable to non-controlling interest							138
Income/(loss) for the period	4,627	4,088	1,580	(252)	(501)	(1,022)	8,519
Add: Current cost of supplies adjustment before taxation			156	266			422
Add: Tax on current cost of supplies adjustment			(38)	(79)			(116)
Less: Identified items before taxation	246	392	(504)	(743)	(559)	(59)	(1,227)
Add: Tax on identified items	(160)	373	(102)	(111)	(110)	43	(68)
Adjusted Earnings	4,220	4,068	2,100	567	(51)	(920)	9,984
Adjusted Earnings attributable to Shell plc shareholders							9,841
Adjusted Earnings attributable to non-controlling interest							144



Half year 2024	$ million
	Integrated Gas	Upstream	Marketing	Chemicals and Products	Renewables and Energy Solutions	Corporate	Total
Income/(loss) attributable to Shell plc shareholders							10,874
Income/(loss) attributable to non-controlling interest							215
Income/(loss) for the period	5,215	4,451	1,099	1,856	478	(2,010)	11,089
Add: Current cost of supplies adjustment before taxation			(79)	(148)			(227)
Add: Tax on current cost of supplies adjustment			11	37			48
Less: Identified items before taxation	(1,336)	(261)	(1,123)	(908)	668	(1,111)	(4,070)
Add: Tax on identified items	(197)	(443)	(290)	48	167	(45)	(761)
Adjusted Earnings	6,354	4,270	1,863	2,700	(24)	(944)	14,219
Adjusted Earnings attributable to Shell plc shareholders							14,027
Adjusted Earnings attributable to non-controlling interest							192

CASH CAPITAL EXPENDITURE BY SEGMENT

Cash capital expenditure is a measure used by the Chief Executive Officer for the purposes of making decisions about allocating resources and assessing performance.



Q2 2025	$ million
	Integrated Gas	Upstream	Marketing	Chemicals and Products	Renewables and Energy Solutions	Corporate	Total
Capital expenditure	988	2,774	427	704	468	32	5,393
Add: Investments in joint ventures and associates	209	52	1	71	72	1	406
Add: Investment in equity securities	—	—	—	—	16	2	17
Cash capital expenditure	1,196	2,826	429	775	555	36	5,817



Q1 2025	$ million
	Integrated Gas	Upstream	Marketing	Chemicals and Products	Renewables and Energy Solutions	Corporate	Total
Capital expenditure	943	1,727	252	451	358	17	3,748
Add: Investments in joint ventures and associates	174	197	4	7	30	1	413
Add: Investments in equity securities	—	—	—	—	14	—	15
Cash capital expenditure	1,116	1,923	256	458	403	19	4,175

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Q2 2024	$ million
	Integrated Gas	Upstream	Marketing	Chemicals and Products	Renewables and Energy Solutions	Corporate	Total
Capital expenditure	1,024	1,769	644	601	377	30	4,445
Add: Investments in joint ventures and associates	127	60	—	37	35	1	261
Add: Investments in equity securities	—	—	—	—	13	—	13
Cash Capital expenditure	1,151	1,829	644	638	425	32	4,719



Half year 2025	$ million
	Integrated Gas	Upstream	Marketing	Chemicals and Products	Renewables and Energy Solutions	Corporate	Total
Capital expenditure	1,930	4,501	679	1,155	826	49	9,141
Add: Investments in joint ventures and associates	383	248	5	78	102	3	819
Add: Investment in equity securities	—	—	—	—	30	2	32
Cash capital expenditure	2,313	4,749	684	1,233	958	54	9,993



Half year 2024	$ million
	Integrated Gas	Upstream	Marketing	Chemicals and Products	Renewables and Energy Solutions	Corporate	Total
Capital expenditure	1,882	3,535	1,071	1,074	797	64	8,424
Add: Investments in joint ventures and associates	310	304	38	63	43	2	761
Add: Investments in equity securities	—	—	—	—	22	3	25
Cash capital expenditure	2,192	3,839	1,109	1,138	863	69	9,211

REVENUE BY SEGMENT

Third-party revenue includes revenue from sources other than from contracts with customers, which mainly comprises the impact of fair value accounting of commodity derivatives.



Q2 2025	$ million
	Integrated Gas	Upstream	Marketing	Chemicals and Products	Renewables and Energy Solutions	Corporate	Total
Revenue:
Third-party	9,576	1,193	28,241	18,388	7,996	12	65,406
Inter-segment	2,412	8,502	2,177	8,775	835	—	22,701



Q1 2025	$ million
	Integrated Gas	Upstream	Marketing	Chemicals and Products	Renewables and Energy Solutions	Corporate	Total
Revenue:
Third-party	9,602	1,510	27,083	21,610	9,417	12	69,234
Inter-segment	2,675	9,854	1,849	8,255	1,164	—	23,797

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Q2 2024	$ million
	Integrated Gas	Upstream	Marketing	Chemicals and Products	Renewables and Energy Solutions	Corporate	Total
Revenue:
Third-party	9,052	1,590	32,005	24,583	7,222	11	74,463
Inter-segment	2,157	10,102	1,363	9,849	957	—	24,428



Half year 2025	$ million
	Integrated Gas	Upstream	Marketing	Chemicals and Products	Renewables and Energy Solutions	Corporate	Total
Revenue:
Third-party	19,179	2,703	55,324	39,998	17,413	23	134,640
Inter-segment	5,086	18,356	4,026	17,030	1,999	—	46,498



Half year 2024	$ million
	Integrated Gas	Upstream	Marketing	Chemicals and Products	Renewables and Energy Solutions	Corporate	Total
Revenue:
Third-party	18,247	3,349	62,045	48,319	14,959	22	146,942
Inter-segment	4,560	20,390	2,718	20,161	1,962	—	49,791

Identified items

The objective of identified items is to remove material impacts on net income/loss arising from transactions which are generally uncontrollable and unusual (infrequent or non-recurring) in nature or giving rise to a mismatch between accounting and economic results, or certain transactions that are generally excluded from underlying results in the industry.

Identified items comprise: divestment gains and losses, impairments and impairment reversals, redundancy and restructuring, fair value accounting of commodity derivatives and certain gas contracts that gives rise to a mismatch between accounting and economic results, the impact of exchange rate movements and inflationary adjustments on certain deferred tax balances, and other items.

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Q2 2025	$ million
	Integrated Gas	Upstream	Marketing	Chemicals and Products	Renewables and Energy Solutions	Corporate	Total
Identified items included in Income/(loss) before taxation
Divestment gains/(losses)	63	344	(56)	(9)	119	(4)	457
Impairment reversals/(impairments)	(672)	(3)	(370)	(78)	(138)	—	(1,261)
Redundancy and restructuring	(7)	(6)	(57)	(37)	(1)	(12)	(119)
Fair value accounting of commodity derivatives and certain gas contracts1	514	1	23	61	(280)	—	319
Other2	—	(65)	—	(1)	—	(47)	(113)
Total identified items included in Income/(loss) before taxation	(102)	271	(460)	(64)	(300)	(63)	(717)
Less: Total identified items included in Taxation charge/(credit)	(203)	(5)	(106)	(13)	(55)	14	(369)
Identified items included in Income/(loss) for the period
Divestment gains/(losses)	54	350	(44)	(7)	108	(3)	458
Impairment reversals/(impairments)	(423)	(2)	(285)	(62)	(136)	—	(908)
Redundancy and restructuring	(4)	(2)	(44)	(29)	—	(8)	(88)
Fair value accounting of commodity derivatives and certain gas contracts1	454	—	19	49	(217)	—	307
Impact of exchange rate movements and inflationary adjustments on tax balances3	20	22	—	—	—	(19)	23
Other2	—	(92)	—	(1)	—	(47)	(139)
Impact on Adjusted Earnings	101	276	(354)	(51)	(245)	(77)	(348)
Impact on Adjusted Earnings attributable to non-controlling interest	—	—	—	—	—	—	—
Impact on Adjusted Earnings attributable to Shell plc shareholders	101	276	(354)	(51)	(245)	(77)	(348)

1.Fair value accounting of commodity derivatives and certain gas contracts: In the ordinary course of business, Shell enters into contracts to supply or purchase oil and gas products, as well as power and environmental products. Shell also enters into contracts for tolling, pipeline and storage capacity. Derivative contracts are entered into for mitigation of resulting economic exposures (generally price exposure) and these derivative contracts are carried at period-end market price (fair value), with movements in fair value recognised in income for the period. Supply and purchase contracts entered into for operational purposes, as well as contracts for tolling, pipeline and storage capacity, are, by contrast, recognised when the transaction occurs; furthermore, inventory is carried at historical cost or net realisable value, whichever is lower. As a consequence, accounting mismatches occur because: (a) the supply or purchase transaction is recognised in a different period; or (b) the inventory is measured on a different basis. In addition, certain contracts are, due to pricing or delivery conditions, deemed to contain embedded derivatives or written options and are also required to be carried at fair value even though they are entered into for operational purposes. The accounting impacts are reported as identified items.

2.Other identified items represent other credits or charges that based on Shell management’s assessment hinder the comparative understanding of Shell’s financial results from period to period.

3.Impact of exchange rate movements and inflationary adjustments on tax balances represents the impact on tax balances of exchange rate movements and inflationary adjustments arising on: (a) the conversion to dollars of the local currency tax base of non-monetary assets and liabilities, as well as recognised tax losses (this primarily impacts the Integrated Gas and Upstream segments); and (b) the conversion of dollar-denominated inter-segment loans to local currency, leading to taxable exchange rate gains or losses (this primarily impacts the Corporate segment).

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Q1 2025	$ million
	Integrated Gas	Upstream	Marketing	Chemicals and Products	Renewables and Energy Solutions	Corporate	Total
Identified items included in Income/(loss) before taxation
Divestment gains/(losses)	(1)	154	(57)	(15)	(187)	—	(106)
Impairment reversals/(impairments)	—	(21)	10	(293)	(38)	—	(341)
Redundancy and restructuring	(1)	(15)	(9)	(13)	(9)	4	(44)
Fair value accounting of commodity derivatives and certain gas contracts1	420	(1)	12	(258)	20	—	194
Other1	(70)	4	—	(101)	(46)	—	(212)
Total identified items included in Income/(loss) before taxation	348	121	(44)	(679)	(260)	4	(510)
Less: Total identified items included in Taxation charge/(credit)	43	378	4	(99)	(54)	29	301
Identified items included in Income/(loss) for the period
Divestment gains/(losses)	—	8	(61)	(12)	(143)	—	(208)
Impairment reversals/(impairments)	—	(15)	6	(277)	(31)	—	(317)
Redundancy and restructuring	(1)	(5)	(1)	(12)	(7)	2	(24)
Fair value accounting of commodity derivatives and certain gas contracts1	362	—	7	(202)	20	—	187
Impact of exchange rate movements and inflationary adjustments on tax balances1	4	132	—	—	—	(28)	108
Other1	(59)	(377)	—	(77)	(45)	—	(558)
Impact on Adjusted Earnings	306	(257)	(49)	(581)	(205)	(26)	(811)
Impact on Adjusted Earnings attributable to non-controlling interest	—	—	—	—	—	—	—
Impact on Adjusted Earnings attributable to Shell plc shareholders	306	(257)	(49)	(581)	(205)	(26)	(811)

1.For a detailed description, see the corresponding footnotes to the Q2 2025 identified items table above.



Q2 2024	$ million
	Integrated Gas	Upstream	Marketing	Chemicals and Products	Renewables and Energy Solutions	Corporate	Total
Identified items included in Income/(loss) before taxation
Divestment gains/(losses)	2	131	(60)	(8)	79	—	143
Impairment reversals/(impairments)	(18)	(80)	(1,055)	(619)	(161)	—	(1,932)
Redundancy and restructuring	(9)	(56)	(69)	(30)	(45)	(2)	(211)
Fair value accounting of commodity derivatives and certain gas contracts1	(102)	(29)	63	211	318	—	461
Other1,2	(133)	(181)	10	113	7	(1,103)	(1,287)
Total identified items included in Income/(loss) before taxation	(260)	(215)	(1,111)	(333)	198	(1,105)	(2,826)
Less: Total identified items included in Taxation charge/(credit)	(40)	(58)	(286)	165	87	(25)	(157)
Identified items included in Income/(loss) for the period
Divestment gains/(losses)	1	114	(45)	(6)	71	—	135
Impairment reversals/(impairments)	(15)	(67)	(783)	(708)	(155)	—	(1,728)
Redundancy and restructuring	(6)	(33)	(50)	(23)	(33)	(1)	(147)
Fair value accounting of commodity derivatives and certain gas contracts1	(98)	(7)	45	156	223	—	319
Impact of exchange rate movements and inflationary adjustments on tax balances1	10	(4)	—	—	—	43	49
Other1,2	(113)	(160)	7	83	5	(1,122)	(1,298)
Impact on Adjusted Earnings	(220)	(157)	(825)	(499)	112	(1,080)	(2,669)
Impact on Adjusted Earnings attributable to non-controlling interest	—	—	—	18	—	—	18
Impact on Adjusted Earnings attributable to Shell plc shareholders	(220)	(157)	(825)	(517)	112	(1,080)	(2,687)

1.For a detailed description, see the corresponding footnotes to the Q2 2025 identified items table above.

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2.Corporate includes reclassifications from equity to profit and loss of cumulative currency translation differences related to funding structures resulting in unfavourable movements of $1,122 million. These currency translation differences were previously recognised in other comprehensive income and accumulated in equity as part of accumulated other comprehensive income.



Half year 2025	$ million
	Integrated Gas	Upstream	Marketing	Chemicals and Products	Renewables and Energy Solutions	Corporate	Total
Identified items included in Income/(loss) before taxation
Divestment gains/(losses)	62	498	(113)	(24)	(68)	(4)	351
Impairment reversals/(impairments)	(672)	(24)	(360)	(371)	(176)	—	(1,602)
Redundancy and restructuring	(8)	(21)	(66)	(50)	(10)	(9)	(164)
Fair value accounting of commodity derivatives and certain gas contracts1	934	—	35	(196)	(260)	—	512
Other1	(70)	(61)	—	(102)	(46)	(47)	(325)
Total identified items included in Income/(loss) before taxation	246	392	(504)	(743)	(559)	(59)	(1,227)
Less: Total identified items included in Taxation charge/(credit)	(160)	373	(102)	(111)	(110)	43	(68)
Identified items included in Income/(loss) for the period
Divestment gains/(losses)	53	358	(105)	(19)	(35)	(3)	250
Impairment reversals/(impairments)	(423)	(17)	(278)	(339)	(167)	—	(1,225)
Redundancy and restructuring	(5)	(7)	(45)	(42)	(7)	(6)	(112)
Fair value accounting of commodity derivatives and certain gas contracts1	817	—	26	(153)	(196)	—	494
Impact of exchange rate movements and inflationary adjustments on tax balances1	24	154	—	—	—	(47)	131
Other1	(59)	(469)	—	(78)	(45)	(47)	(697)
Impact on Adjusted Earnings	407	19	(402)	(631)	(450)	(102)	(1,160)
Impact on Adjusted Earnings attributable to non-controlling interest	—	—	—	—	—	—	—
Impact on Adjusted Earnings attributable to Shell plc shareholders	407	19	(402)	(631)	(450)	(102)	(1,160)

1.For a detailed description, see the corresponding footnotes to the Q2 2025 identified items table above.

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Half year 2024	$ million
	Integrated Gas	Upstream	Marketing	Chemicals and Products	Renewables and Energy Solutions	Corporate	Total
Identified items included in Income/(loss) before taxation
Divestment gains/(losses)	(1)	158	(75)	(17)	89	—	154
Impairment reversals/(impairments)	(26)	(176)	(1,059)	(797)	(102)	—	(2,159)
Redundancy and restructuring	(10)	(69)	(90)	(49)	(60)	(7)	(284)
Fair value accounting of commodity derivatives and certain gas contracts1	(1,169)	(31)	69	(205)	717	—	(619)
Other1,2	(129)	(143)	33	158	24	(1,103)	(1,161)
Total identified items included in Income/(loss) before taxation	(1,336)	(261)	(1,123)	(908)	668	(1,111)	(4,070)
Less: Total identified items included in Taxation charge/(credit)	(197)	(443)	(290)	48	167	(45)	(761)
Identified items included in Income/(loss) for the period
Divestment gains/(losses)	—	124	(56)	(13)	77	—	131
Impairment reversals/(impairments)	(20)	(169)	(786)	(860)	(78)	—	(1,914)
Redundancy and restructuring	(6)	(42)	(65)	(37)	(44)	(5)	(200)
Fair value accounting of commodity derivatives and certain gas contracts1	(985)	(8)	50	(163)	529	—	(576)
Impact of exchange rate movements and inflationary adjustments on tax balances1	(17)	408	—	—	—	61	452
Other1,2	(110)	(131)	25	118	18	(1,122)	(1,202)
Impact on Adjusted Earnings	(1,139)	182	(832)	(956)	501	(1,066)	(3,310)
Impact on Adjusted Earnings attributable to non-controlling interest	—	—	—	18	—	—	18
Impact on adjusted earnings attributable to Shell plc shareholders	(1,139)	182	(832)	(974)	501	(1,066)	(3,328)

1.For a detailed description, see the corresponding footnotes to the Q2 2025 identified items table above.

The identified items categories above may include after-tax impacts of identified items of joint ventures and associates which are fully reported within “Share of profit/(loss) of joint ventures and associates” in the Consolidated Statement of Income, and fully reported as identified items included in Income/(loss) before taxation in the table above. Identified items related to subsidiaries are consolidated and reported across appropriate lines of the Consolidated Statement of Income.

3. Earnings per share



EARNINGS PER SHARE
Quarters				Half year
Q2 2025	Q1 2025	Q2 2024		2025	2024
3,601	4,780	3,517	Income/(loss) attributable to Shell plc shareholders ($ million)	8,381	10,874

			Weighted average number of shares used as the basis for determining:
5,947.9	6,033.5	6,355.4	Basic earnings per share (million)	5,990.5	6,397.7
6,004.7	6,087.8	6,417.6	Diluted earnings per share (million)	6,046.0	6,461.0

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2nd QUARTER 2025 AND HALF YEAR UNAUDITED RESULTS

4. Share capital



ISSUED AND FULLY PAID ORDINARY SHARES OF €0.07 EACH
	Number of shares	Nominal value ($ million)
At January 1, 2025	6,115,031,158	510
Repurchases of shares	(202,687,052)	(17)
At June 30, 2025	5,912,344,106	493
At January 1, 2024	6,524,109,049	544
Repurchases of shares	(199,993,563)	(17)
At June 30, 2024	6,324,115,486	528

At Shell plc’s Annual General Meeting on May 20, 2025, the Board was authorised to allot ordinary shares in Shell plc, and to grant rights to subscribe for, or to convert, any security into ordinary shares in Shell plc, up to an aggregate nominal amount of approximately €140 million (representing approximately 2,007 million ordinary shares of €0.07 each), and to list such shares or rights on any stock exchange. This authority expires at the earlier of the close of business on August 19, 2026, or the end of the Annual General Meeting to be held in 2026, unless previously renewed, revoked or varied by Shell plc in a general meeting.

5. Other reserves



OTHER RESERVES
$ million	Merger reserve	Share premium reserve	Capital redemption reserve	Share plan reserve	Accumulated other comprehensive income	Total
At January 1, 2025	37,298	154	270	1,417	(19,373)	19,766
Other comprehensive income/(loss) attributable to Shell plc shareholders	—	—	—	—	6,159	6,159
Transfer from other comprehensive income	—	—	—	—	18	18
Repurchases of shares	—	—	17	—	—	17
Share-based compensation	—	—	—	(486)	—	(486)
At June 30, 2025	37,298	154	287	930	(13,196)	25,473
At January 1, 2024	37,298	154	236	1,308	(17,851)	21,145
Other comprehensive income/(loss) attributable to Shell plc shareholders	—	—	—	—	(494)	(494)
Transfer from other comprehensive income	—	—	—	—	170	170
Repurchases of shares	—	—	17	—	—	17
Share-based compensation	—	—	—	(213)	—	(213)
At June 30, 2024	37,298	154	253	1,095	(18,175)	20,625

The merger reserve and share premium reserve were established as a consequence of Shell plc (formerly Royal Dutch Shell plc) becoming the single parent company of Royal Dutch Petroleum Company and The “Shell” Transport and Trading Company, p.l.c., now The Shell Transport and Trading Company Limited, in 2005. The merger reserve increased in 2016 following the issuance of shares for the acquisition of BG Group plc. The capital redemption reserve was established in connection with repurchases of shares of Shell plc. The share plan reserve is in respect of equity-settled share-based compensation plans.

6. Derivative financial instruments and debt excluding lease liabilities

As disclosed in the Consolidated Financial Statements for the year ended December 31, 2024, presented in the Annual Report and Accounts and Form 20-F/A for that year, Shell is exposed to the risks of changes in fair value of its financial assets and liabilities. The fair values of the financial assets and liabilities are defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Methods and assumptions used to estimate the fair values at June 30, 2025, are consistent with those used in the year ended December 31, 2024, though the carrying amounts of derivative financial instruments have changed since that date.

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The movement of the derivative financial instruments between December 31, 2024 and June 30, 2025, is a decrease of $230 million for the current assets and a decrease of $940 million for the current liabilities.

The table below provides the comparison of the fair value with the carrying amount of debt excluding lease liabilities, disclosed in accordance with IFRS 7 Financial Instruments: Disclosures.



DEBT EXCLUDING LEASE LIABILITIES
$ million	June 30, 2025	December 31, 2024
Carrying amount1	46,720	48,376
Fair value2	42,864	44,119

1. Shell issued no debt under the US shelf or under the Euro medium-term note programmes since November 2021 and September 2020, respectively. The US shelf programme has lapsed and management aims to renew it during the second half of 2025.

2. Mainly determined from the prices quoted for these securities.

7. Other notes to the unaudited Condensed Consolidated Interim Financial Statements

Consolidated Statement of Income

Interest and other income



Quarters			$ million	Half year
Q2 2025	Q1 2025	Q2 2024		2025	2024
326	302	(305)	Interest and other income/(expenses)	628	602
			Of which:
559	481	616	Interest income	1,040	1,204
44	1	30	Dividend income (from investments in equity securities)	45	53
128	(127)	143	Net gains/(losses) on sales and revaluation of non-current assets and businesses	1	154
(447)	(137)	(1,169)	Net foreign exchange gains/(losses) on financing activities	(584)	(1,103)
42	85	74	Other	127	293

Depreciation, depletion and amortisation



Quarters			$ million	Half year
Q2 2025	Q1 2025	Q2 2024		2025	2024
6,670	5,441	7,555	Depreciation, depletion and amortisation	12,111	13,436
			Of which:
5,463	5,130	5,642	Depreciation	10,593	11,296
1,238	311	1,984	Impairments	1,549	2,365
(31)	(1)	(71)	Impairment reversals	(32)	(225)

Impairments recognised in the second quarter 2025 of $1,238 million pre-tax ($877 million post-tax) principally relate to Integrated Gas ($666 million) and Marketing ($399 million). Impairments recognised in Integrated Gas were triggered by lower commodity prices applied in impairment testing.

Impairments recognised in the second quarter 2024 of $1,984 million pre-tax ($1,778 million post-tax) mainly relate to Marketing ($1,055 million), Chemicals and Products ($690 million) and Renewables and Energy Solutions ($141 million).

Taxation charge/credit

Quarters

$ million

Half year

Q2 2025

Q1 2025

Q2 2024

2025

2024

2,332

4,083

3,754

Taxation charge/(credit)

6,415

7,358

Of which:

2,277

4,024

3,666

Income tax excluding Pillar Two income tax

6,301

7,192

Income tax related to Pillar Two income tax

113

167

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As required by IAS 12 Income Taxes, Shell has applied the exception to recognising and disclosing information about deferred tax assets and liabilities related to Pillar Two income taxes.

Consolidated Statement of Comprehensive Income

Currency translation differences

Quarters

$ million

Half year

Q2 2025

Q1 2025

Q2 2024

2025

2024

4,127

1,711

698

Currency translation differences

5,837

(1,296)

Of which:

4,117

1,618

(406)

Recognised in Other comprehensive income

5,736

(2,388)

1,104

(Gain)/loss reclassified to profit or loss

101

1,092

Condensed Consolidated Balance Sheet

Assets classified as held for sale



$ million
	June 30, 2025	December 31, 2024
Assets classified as held for sale	10,619	9,857
Liabilities directly associated with assets classified as held for sale	7,856	6,203

Assets classified as held for sale and associated liabilities at June 30, 2025, principally relate to Shell’s UK offshore oil and gas assets in Upstream and mining interests in Canada in Chemicals and Products. Upon completion of the sale, Shell’s UK offshore assets will be derecognised in exchange for a 50% interest in a newly formed joint venture.

The major classes of assets and liabilities classified as held for sale at June 30, 2025, are Property, plant and equipment ($9,759 million; December 31, 2024: $8,283 million), Deferred tax liabilities ($3,312 million; December 31, 2024: $2,042 million) and Decommissioning and other provisions ($3,165 million; December 31, 2024: $3,053 million).

Consolidated Statement of Cash Flows

Cash flow from operating activities – Other

Quarters

$ million

Half year

Q2 2025

Q1 2025

Q2 2024

2025

2024

684

570

2,027

Other

1,254

2,536

‘Cash flow from operating activities – Other’ for the second quarter 2025 includes $979 million of net inflows (first quarter 2025: $652 million net inflows; second quarter 2024: $620 million net inflows) due to the timing of payments relating to emission certificates and biofuel programmes in Europe and North America and $439 million in relation to reversal of currency exchange gains on Cash and cash equivalents (first quarter 2025: $255 million gains; second quarter 2024: $96 million losses). In addition, the second quarter 2024 includes $1,104 million inflow representing reversal of the non-cash recycling of currency translation losses from other comprehensive income.

Dividends received from joint ventures and associates

Quarters

$ million

Half year

Q2 2025

Q1 2025

Q2 2024

2025

2024

2,361

523

792

Dividends received from joint ventures and associates

2,884

1,530

In the second quarter 2025, a cash dividend of $1,727 million was received from a joint venture in Upstream.

Proceeds from sale of property, plant and equipment and businesses

Page 28

SHELL PLC
2nd QUARTER 2025 AND HALF YEAR UNAUDITED RESULTS

Quarters

$ million

Half year

Q2 2025

Q1 2025

Q2 2024

2025

2024

(57)

559

710

Proceeds from sale of property, plant and equipment and businesses

502

1,033

In the second quarter 2025, Shell completed the sale of a business that held $216 million of cash and cash equivalents, that was agreed to be transferred in the sale, resulting in a cash outflow in ‘Proceeds from sale of property, plant and equipment and businesses’. Sales proceeds were received and recognised in the Consolidated statement of Cash Flows in the first quarter 2025.

8. Reconciliation of Operating expenses and Total Debt



RECONCILIATION OF OPERATING EXPENSES
Quarters			$ million	Half year
Q2 2025	Q1 2025	Q2 2024		2025	2024
4,909	5,549	5,593	Production and manufacturing expenses	10,459	11,403
3,077	2,840	3,094	Selling, distribution and administrative expenses	5,917	6,069
278	185	263	Research and development	464	475
8,265	8,575	8,950	Operating expenses	16,840	17,947



RECONCILIATION OF TOTAL DEBT


June 30, 2025	March 31, 2025	June 30, 2024	$ million	June 30, 2025	June 30, 2024
10,457	11,391	10,849	Current debt	10,457	10,849
65,218	65,120	64,619	Non-current debt	65,218	64,619
75,675	76,511	75,468	Total debt	75,675	75,468

9. Post-balance sheet events

On July 1, 2023, new pension legislation (“Wet Toekomst Pensioenen” (WTP)) came into effect in the Netherlands, with an expected implementation required prior to January 1, 2028. In July 2025, the Trustee Board of the Stichting Shell Pensioen Fonds (“SSPF”), Shell’s defined benefit pension fund in the Netherlands, formally accepted the transition plan to transition from a defined benefit pension fund to a defined contribution plan with effect from January 1, 2027, subject to the local funding level of the plan remaining above an agreed level (125%) during a predetermined transition period.

In accordance with asset ceiling principles, in the third quarter 2025, Shell will recognise an adjustment to reduce the pension fund surplus (June 30, 2025: $5,521 million) to nil, and recognise a liability for a minimum funding requirement estimated at $750 million, resulting in a loss in Other Comprehensive Income. In addition, a net deferred tax liability of $1,617 million will be unwound, leading to an overall net post-tax loss of $4,654 million recognised in Other Comprehensive Income resulting in an increase in gearing of 0.4 percentage points. Subsequently, at the date of transition and settlement (expected December 31, 2026), the surplus at that date will be de-recognised, resulting in an identified loss in the Consolidated Statement of Income. The extent to which the funding level will meet the agreed 125% threshold is subject to uncertainty and the asset ceiling recognised will continue to be monitored in accordance with IAS 19 Employee Benefits.

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SHELL PLC
2nd QUARTER 2025 AND HALF YEAR UNAUDITED RESULTS

ALTERNATIVE PERFORMANCE (NON-GAAP) MEASURES

A.Adjusted Earnings, Adjusted earnings before interest, taxes, depreciation and amortisation (“Adjusted EBITDA”) and Cash flow from operating activities

The “Adjusted Earnings” measure aims to facilitate a comparative understanding of Shell’s financial performance from period to period by removing the effects of oil price changes on inventory carrying amounts and removing the effects of identified items. These items are in some cases driven by external factors and may, either individually or collectively, hinder the comparative understanding of Shell’s financial results from period to period. This measure excludes earnings attributable to non-controlling interest when presenting the total Shell Group result but includes these items when presenting individual segment Adjusted Earnings as set out in the table below.

See Note 2 “Segment information” for the reconciliation of Adjusted Earnings.

We define “Adjusted EBITDA” as “Income/(loss) for the period” adjusted for current cost of supplies; identified items; tax charge/(credit); depreciation, amortisation and depletion; exploration well write-offs and net interest expense. All items include the non-controlling interest component. Management uses this measure to evaluate Shell’s performance in the period and over time.



Q2 2025	$ million
	Integrated Gas	Upstream	Marketing	Chemicals and Products	Renewables and Energy Solutions	Corporate	Total
Adjusted Earnings							4,264
Add: Non-controlling interest							50
Adjusted Earnings plus non-controlling interest	1,737	1,732	1,199	118	(9)	(463)	4,314
Add: Taxation charge/(credit) excluding tax impact of identified items	497	2,205	413	(103)	20	(217)	2,815
Add: Depreciation, depletion and amortisation excluding impairments	1,585	2,353	557	872	90	6	5,463
Add: Exploration well write-offs	3	203	—	—	—	—	206
Add: Interest expense excluding identified items	53	171	12	16	2	820	1,074
Less: Interest income	—	26	—	39	2	492	559
Adjusted EBITDA	3,875	6,638	2,181	864	102	(346)	13,313
Less: Current cost of supplies adjustment before taxation			104	333			436
Joint ventures and associates (dividends received less profit)	92	1,542	161	70	10	—	1,876
Derivative financial instruments	542	25	13	3	(66)	410	928
Taxation paid	(967)	(1,948)	(132)	(87)	(60)	(238)	(3,432)
Other	(265)	(413)	533	471	142	(395)	74
(Increase)/decrease in working capital	352	655	67	383	(128)	(1,715)	(386)
Cash flow from operating activities	3,629	6,500	2,718	1,372	1	(2,283)	11,937



Q1 2025	$ million
	Integrated Gas	Upstream	Marketing	Chemicals and Products	Renewables and Energy Solutions	Corporate	Total
Adjusted Earnings							5,577
Add: Non-controlling interest							94
Adjusted Earnings plus non-controlling interest	2,483	2,337	900	449	(42)	(457)	5,670
Add: Taxation charge/(credit) excluding tax impact of identified items	803	2,619	391	99	63	(191)	3,784
Add: Depreciation, depletion and amortisation excluding impairments	1,404	2,213	566	852	90	6	5,130
Add: Exploration well write-offs	—	29	—	—	—	—	28
Add: Interest expense excluding identified items	51	200	12	14	2	841	1,119
Less: Interest income	4	11	—	4	2	461	481
Adjusted EBITDA	4,735	7,387	1,869	1,410	111	(261)	15,250
Less: Current cost of supplies adjustment before taxation			52	(67)			(15)
Joint ventures and associates (dividends received less profit)	(286)	(159)	203	54	10	—	(178)
Derivative financial instruments	542	14	10	(508)	(169)	73	(38)
Taxation paid	(773)	(1,999)	(174)	63	52	(68)	(2,900)
Other	(68)	(386)	396	125	(17)	(257)	(206)
(Increase)/decrease in working capital	(687)	(913)	(344)	(1,081)	380	(19)	(2,663)
Cash flow from operating activities	3,463	3,945	1,907	130	367	(531)	9,281

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SHELL PLC
2nd QUARTER 2025 AND HALF YEAR UNAUDITED RESULTS



Q2 2024	$ million
	Integrated Gas	Upstream	Marketing	Chemicals and Products	Renewables and Energy Solutions	Corporate	Total
Adjusted Earnings							6,293
Add: Non-controlling interest							122
Adjusted Earnings plus non-controlling interest	2,675	2,336	1,082	1,085	(187)	(576)	6,415
Add: Taxation charge/(credit) excluding tax impact of identified items	940	2,312	359	297	(10)	49	3,947
Add: Depreciation, depletion and amortisation excluding impairments	1,375	2,750	548	867	95	6	5,642
Add: Exploration well write-offs	5	264	—	—	—	—	269
Add: Interest expense excluding identified items	44	166	10	23	1	904	1,149
Less: Interest income	—	(1)	—	30	(9)	595	616
Adjusted EBITDA	5,039	7,829	1,999	2,242	(91)	(213)	16,806
Less: Current cost of supplies adjustment before taxation			74	59			133
Joint ventures and associates (dividends received less profit)	96	(288)	(54)	46	64	—	(135)
Derivative financial instruments	(133)	9	7	304	607	(79)	713
Taxation paid	(1,039)	(1,955)	(17)	(186)	(138)	(113)	(3,448)
Other	(104)	(341)	(57)	263	180	20	(38)
(Increase)/decrease in working capital	324	484	153	(361)	225	(1,083)	(258)
Cash flow from operating activities	4,183	5,739	1,958	2,249	847	(1,468)	13,508



Half year 2025	$ million
	Integrated Gas	Upstream	Marketing	Chemicals and Products	Renewables and Energy Solutions	Corporate	Total
Adjusted Earnings							9,841
Add: Non-controlling interest							144
Adjusted Earnings plus non-controlling interest	4,220	4,068	2,100	567	(51)	(920)	9,984
Add: Taxation charge/(credit) excluding tax impact of identified items	1,299	4,824	804	(3)	83	(408)	6,599
Add: Depreciation, depletion and amortisation excluding impairments	2,988	4,566	1,123	1,724	180	13	10,593
Add: Exploration well write-offs	3	232	—	—	—	—	234
Add: Interest expense excluding identified items	104	371	24	29	4	1,661	2,193
Less: Interest income	4	37	1	43	3	953	1,040
Adjusted EBITDA	8,610	14,024	4,049	2,274	213	(607)	28,563
Less: Current cost of supplies adjustment before taxation			156	266			422
Joint ventures and associates (dividends received less profit)	(194)	1,384	365	124	20	—	1,698
Derivative financial instruments	1,084	39	23	(504)	(235)	484	891
Taxation paid	(1,741)	(3,946)	(306)	(24)	(8)	(306)	(6,331)
Other	(332)	(799)	928	597	126	(651)	(132)
(Increase)/decrease in working capital	(335)	(257)	(277)	(698)	252	(1,734)	(3,049)
Cash flow from operating activities	7,092	10,445	4,625	1,502	368	(2,814)	21,218



Half year 2024	$ million
	Integrated Gas	Upstream	Marketing	Chemicals and Products	Renewables and Energy Solutions	Corporate	Total
Adjusted Earnings							14,027
Add: Non-controlling interest							192
Adjusted Earnings plus non-controlling interest	6,354	4,270	1,863	2,700	(24)	(944)	14,219
Add: Taxation charge/(credit) excluding tax impact of identified items	1,936	4,834	717	635	(9)	(42)	8,071
Add: Depreciation, depletion and amortisation excluding impairments	2,785	5,477	1,084	1,737	201	12	11,296
Add: Exploration well write-offs	13	811	—	—	—	—	823
Add: Interest expense excluding identified items	87	335	22	40	2	1,825	2,312
Less: Interest income	—	9	—	44	(5)	1,155	1,204
Adjusted EBITDA	11,175	15,717	3,686	5,068	175	(304)	35,517
Less: Current cost of supplies adjustment before taxation			(79)	(148)			(227)
Joint ventures and associates (dividends received less profit)	(101)	(834)	38	102	78	—	(717)
Derivative financial instruments	(1,213)	5	(32)	(98)	2,585	(228)	1,019
Taxation paid	(1,506)	(3,757)	(191)	(205)	(382)	(23)	(6,064)
Other	(59)	(572)	337	(115)	151	124	(135)
(Increase)/decrease in working capital	599	905	(639)	(3,000)	706	(1,581)	(3,010)
Cash flow from operating activities	8,895	11,466	3,277	1,900	3,313	(2,013)	26,838

Page 31

SHELL PLC
2nd QUARTER 2025 AND HALF YEAR UNAUDITED RESULTS

Identified items

See Note 2 “Segment information” for details.

B. Adjusted Earnings per share

Adjusted Earnings per share is calculated as Adjusted Earnings (see Reference A), divided by the weighted average number of shares used as the basis for basic earnings per share (see Note 3).

C. Cash capital expenditure

Cash capital expenditure represents cash spent on maintaining and developing assets as well as on investments in the period. Management regularly monitors this measure as a key lever to delivering sustainable cash flows. Cash capital expenditure is the sum of the following lines from the Consolidated Statement of Cash Flows: Capital expenditure, Investments in joint ventures and associates and Investments in equity securities.

See Note 2 “Segment information” for the reconciliation of cash capital expenditure.

D. Capital employed and Return on average capital employed

Return on average capital employed (“ROACE”) measures the efficiency of Shell’s utilisation of the capital that it employs.

The measure refers to Capital employed which consists of total equity, current debt, and non-current debt reduced by cash and cash equivalents.

In this calculation, the sum of Adjusted Earnings (see Reference A) plus non-controlling interest (NCI) excluding identified items for the current and previous three quarters, adjusted for after-tax interest expense and after-tax interest income, is expressed as a percentage of the average capital employed excluding cash and cash equivalents for the same period.



$ million	Quarters
	Q2 2025	Q1 2025	Q2 2024
Current debt	10,849	11,046	12,114
Non-current debt	64,619	68,886	72,252
Total equity	187,190	188,304	192,094
Less: Cash and cash equivalents	(38,148)	(39,949)	(45,094)
Capital employed – opening	224,511	228,286	231,366
Current debt	10,457	11,391	10,849
Non-current debt	65,218	65,120	64,619
Total equity	183,088	180,670	187,190
Less: Cash and cash equivalents	(32,682)	(35,601)	(38,148)
Capital employed – closing	226,081	221,580	224,511
Capital employed – average	225,296	224,933	227,939

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SHELL PLC
2nd QUARTER 2025 AND HALF YEAR UNAUDITED RESULTS



$ million	Quarters
	Q2 2025	Q1 2025	Q2 2024
Adjusted Earnings – current and previous three quarters (Reference A)	19,529	21,558	27,558
Add: Income/(loss) attributable to NCI – current and previous three quarters	351	441	409
Add: Current cost of supplies adjustment attributable to NCI – current and previous three quarters	25	25	(25)
Less: Identified items attributable to NCI (Reference A) – current and previous three quarters	0	18	7
Adjusted Earnings plus NCI excluding identified items – current and previous three quarters	19,904	22,005	27,935
Add: Interest expense after tax – current and previous three quarters	2,577	2,639	2,650
Less: Interest income after tax on cash and cash equivalents – current and previous three quarters	1,206	1,329	1,395
Adjusted Earnings plus NCI excluding identified items before interest expense and interest income – current and previous three quarters	21,274	23,315	29,190
Capital employed – average	225,296	224,933	227,939
ROACE on an Adjusted Earnings plus NCI basis	9.4%	10.4%	12.8%

E. Net debt and gearing

Net debt is defined as the sum of current and non-current debt, less cash and cash equivalents, adjusted for the fair value of derivative financial instruments used to hedge foreign exchange and interest rate risk relating to debt, and associated collateral balances. Management considers this adjustment useful because it reduces the volatility of net debt caused by fluctuations in foreign exchange and interest rates, and eliminates the potential impact of related collateral payments or receipts. Debt-related derivative financial instruments are a subset of the derivative financial instrument assets and liabilities presented on the balance sheet. Collateral balances are reported under “Trade and other receivables” or “Trade and other payables” as appropriate.

Gearing is a measure of Shell’s capital structure and is defined as net debt (total debt less cash and cash equivalents) as a percentage of total capital (net debt plus total equity).



$ million
	June 30, 2025		March 31, 2025		June 30, 2024
Current debt	10,457		11,391		10,849
Non-current debt	65,218		65,120		64,619
Total debt	75,675		76,511		75,468
Of which: Lease liabilities	28,955		28,488		25,600
Add: Debt-related derivative financial instruments: net liability/(asset)	589		1,905		2,460
Add: Collateral on debt-related derivatives: net liability/(asset)	(366)		(1,295)		(1,466)
Less: Cash and cash equivalents	(32,682)		(35,601)		(38,148)
Net debt	43,216		41,521		38,314
Total equity	183,088		180,670		187,190
Total capital	226,304		222,190		225,505
Gearing	19.1	%	18.7	%	17.0	%

F. Operating expenses and Underlying operating expenses

Operating expenses

Operating expenses is a measure of Shell’s cost management performance, comprising the following items from the Consolidated Statement of Income: production and manufacturing expenses; selling, distribution and administrative expenses; and research and development expenses.

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SHELL PLC
2nd QUARTER 2025 AND HALF YEAR UNAUDITED RESULTS



Q2 2025	$ million
	Integrated Gas	Upstream	Marketing	Chemicals and Products	Renewables and Energy Solutions	Corporate	Total
Production and manufacturing expenses	899	1,940	179	1,459	431	—	4,909
Selling, distribution and administrative expenses	30	43	2,319	441	138	106	3,077
Research and development	36	71	49	38	23	61	278
Operating expenses	965	2,055	2,547	1,939	592	168	8,265



Q1 2025	$ million
	Integrated Gas	Upstream	Marketing	Chemicals and Products	Renewables and Energy Solutions	Corporate	Total
Production and manufacturing expenses	947	2,139	349	1,621	486	8	5,549
Selling, distribution and administrative expenses	38	42	2,053	442	153	111	2,840
Research and development	22	32	42	25	21	43	185
Operating expenses	1,006	2,213	2,444	2,088	661	162	8,575



Q2 2024	$ million
	Integrated Gas	Upstream	Marketing	Chemicals and Products	Renewables and Energy Solutions	Corporate	Total
Production and manufacturing expenses	1,050	2,219	320	1,573	422	10	5,593
Selling, distribution and administrative expenses	64	62	2,295	293	279	101	3,094
Research and development	32	61	47	37	24	62	263
Operating expenses	1,146	2,341	2,662	1,902	725	173	8,950



Half year 2025	$ million
	Integrated Gas	Upstream	Marketing	Chemicals and Products	Renewables and Energy Solutions	Corporate	Total
Production and manufacturing expenses	1,846	4,079	528	3,080	916	8	10,459
Selling, distribution and administrative expenses	67	85	4,371	884	292	218	5,917
Research and development	57	103	92	63	44	104	464
Operating expenses	1,971	4,268	4,991	4,027	1,253	330	16,840



Half year 2024	$ million
	Integrated Gas	Upstream	Marketing	Chemicals and Products	Renewables and Energy Solutions	Corporate	Total
Production and manufacturing expenses	2,006	4,487	685	3,207	1,001	16	11,403
Selling, distribution and administrative expenses	126	120	4,483	713	437	190	6,069
Research and development	58	119	81	71	36	111	475
Operating expenses	2,190	4,726	5,249	3,990	1,475	317	17,947

Underlying operating expenses

Underlying operating expenses is a measure aimed at facilitating a comparative understanding of performance from period to period by removing the effects of identified items, which, either individually or collectively, can cause volatility, in some cases driven by external factors.

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SHELL PLC
2nd QUARTER 2025 AND HALF YEAR UNAUDITED RESULTS

Quarters

$ million

Half year

Q2 2025

Q1 2025

Q2 2024

2025

2024

8,265

8,575

8,950

Operating expenses

16,840

17,947

(119)

(44)

(210)

Redundancy and restructuring (charges)/reversal

(162)

(283)

(1)

(101)

(212)

(Provisions)/reversal

(102)

(212)

—

123

Other

252

(120)

(121)

(299)

Total identified items

(241)

(242)

8,145

8,453

8,651

Underlying operating expenses

16,598

17,704

G. Free cash flow and Organic free cash flow

Free cash flow is used to evaluate cash available for financing activities, including dividend payments and debt servicing, after investment in maintaining and growing the business. It is defined as the sum of “Cash flow from operating activities” and “Cash flow from investing activities”.

Cash flows from acquisition and divestment activities are removed from Free cash flow to arrive at the Organic free cash flow, a measure used by management to evaluate the generation of free cash flow without these activities.



Quarters			$ million	Half year
Q2 2025	Q1 2025	Q2 2024		2025	2024
11,937	9,281	13,508	Cash flow from operating activities	21,218	26,838
(5,406)	(3,959)	(3,338)	Cash flow from investing activities	(9,365)	(6,866)
6,531	5,322	10,170	Free cash flow	11,853	19,972
(36)	597	769	Less: Divestment proceeds (Reference I)	560	1,794
98	45	—	Add: Tax paid on divestments (reported under “Other investing cash outflows”)	143	—
792	130	189	Add: Cash outflows related to inorganic capital expenditure1	921	251
7,458	4,899	9,590	Organic free cash flow2	12,357	18,429

1.Cash outflows related to inorganic capital expenditure includes portfolio actions which expand Shell’s activities through acquisitions and restructuring activities as reported in capital expenditure lines in the Consolidated Statement of Cash Flows.

2.Free cash flow less divestment proceeds, adding back outflows related to inorganic expenditure.

H. Cash flow from operating activities excluding working capital movements

Working capital movements are defined as the sum of the following items in the Consolidated Statement of Cash Flows: (i) (increase)/decrease in inventories, (ii) (increase)/decrease in current receivables, and (iii) increase/(decrease) in current payables.

Cash flow from operating activities excluding working capital movements is a measure used by Shell to analyse its operating cash generation over time excluding the timing effects of changes in inventories and operating receivables and payables from period to period.

Quarters

$ million

Half year

Q2 2025

Q1 2025

Q2 2024

2025

2024

11,937

9,281

13,508

Cash flow from operating activities

21,218

26,838

(27)

854

(954)

(Increase)/decrease in inventories

827

(1,562)

3,635

(2,610)

1,965

(Increase)/decrease in current receivables

1,025

1,770

(3,994)

(907)

(1,269)

Increase/(decrease) in current payables

(4,901)

(3,218)

(386)

(2,663)

(258)

(Increase)/decrease in working capital

(3,049)

(3,010)

12,323

11,944

13,766

Cash flow from operating activities excluding working capital movements

24,267

29,848

I. Divestment proceeds

Divestment proceeds represent cash received from divestment activities in the period. Management regularly monitors this measure as a key lever to deliver free cash flow.

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SHELL PLC
2nd QUARTER 2025 AND HALF YEAR UNAUDITED RESULTS



Quarters			$ million	Half year
Q2 2025	Q1 2025	Q2 2024		2025	2024
(57)	559	710	Proceeds from sale of property, plant and equipment and businesses	502	1,033
1	33	57	Proceeds from joint ventures and associates from sale, capital reduction and repayment of long-term loans	34	190
19	5	2	Proceeds from sale of equity securities	24	570
(36)	597	769	Divestment proceeds	560	1,794

J. Structural cost reduction

The structural cost reduction target is used for the purpose of demonstrating how management drives cost discipline across the entire organisation, simplifying our processes and portfolio, and streamlining the way we work.

Structural cost reduction describes the decrease in underlying operating expenses (see Reference F above) as a result of operational efficiencies, divestments, workforce reductions and other cost-saving measures that are expected to be sustainable compared with 2022 levels.

The total change between periods in underlying operating expenses will reflect both structural cost reductions and other changes in spend, including market factors, such as inflation and foreign exchange impacts, as well as changes in activity levels and costs associated with new operations.

Structural cost reductions are stewarded internally to support management’s oversight of spending over time. The 2028 target reflects annualised saving achieved by end-2028.



			$ million
Structural cost reduction up to second quarter 2025 compared with 2022 levels			(3,905)

Underlying operating expenses 2024			35,707
Underlying operating expenses 2022			39,456
Total decrease in Underlying operating expenses			(3,749)
Of which:
Structural cost reductions			(3,119)
Change in Underlying operating expenses excluding structural cost reduction			(630)

Underlying operating expenses first half 2025			16,598
Underlying operating expenses first half 2024			17,704
Total decrease in Underlying operating expenses			(1,106)
Of which:
Structural cost reductions			(786)
Change in Underlying operating expenses excluding structural cost reduction			(320)

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SHELL PLC
2nd QUARTER 2025 AND HALF YEAR UNAUDITED RESULTS

PRINCIPAL RISKS AND UNCERTAINTIES

The principal risks and uncertainties affecting Shell are described in the Risk management and risk factors section of the Annual Report and Accounts (pages 134 to 144) and Form 20-F (pages 25 to 34) for the year ended December 31, 2024 and are summarised below. There are no material changes expected in those Risk Factors for the remaining six months of the financial year.

1.Portfolio risks

We are exposed to risks that could adversely affect the resilience of our overall portfolio of businesses. These include external risks such as macroeconomic risks, including fluctuating commodity prices and competitive forces. Our future performance depends on the successful development and deployment of new technologies that provide new products and solutions. In addition, our future hydrocarbon production depends on the delivery of integrated projects and our ability to replace proved oil and gas reserves. Many of our major projects and operations are conducted in joint arrangements or with associates. This could reduce our degree of control and our ability to identify and manage risks.

2.Climate change and the energy transition

Rising concerns about climate change and the effects of the energy transition pose multiple risks to Shell, including declines in the demand for and prices of our products, commercial risks from growing our low-carbon business, and adverse litigation and regulatory developments. The physical impacts of climate change could also adversely affect our assets and supply chains.

3.Country risks

We operate in more than 70 countries which have differing degrees of political, legal and fiscal stability. This has exposed, and could expose, us to a wide range of political developments that could result in changes to contractual terms, laws and regulations.

4.Financial risks

We are exposed to treasury risks, including liquidity risk, interest rate risk, foreign exchange risk and credit risk. We are affected by the global macroeconomic environment and the conditions of financial markets. These, and changes to certain demographic factors, also impact our pension assets and liabilities.

5.Trading risks

We are exposed to market, regulatory and conduct risks in our trading operations.

6.Health, safety, security and the environment

The nature of our operations exposes us, and the communities in which we work, to a wide range of health, safety, security and environment risks.

7.Information technology and cybersecurity risks

We rely heavily on information technology systems in our operations.

8.Litigation and regulatory compliance

Violations of laws carry fines and could expose us and/or our employees to criminal sanctions and civil suits. We have faced, and could also face, the risk of litigation and disputes worldwide.

9.Reputation and risks to our licence to operate

An erosion of our business reputation could have a material adverse effect on our brand, on our ability to secure new hydrocarbon or low-carbon opportunities, to access capital markets, and to attract and retain people, and on our licence to operate.

10.Our people and culture

The successful delivery of our strategy is dependent on our people and on a culture that aligns to our goals and reflects the changes we need to make as part of the energy transition.

11.Other (generally applicable to an investment in securities)

The Company’s Articles of Association determine the jurisdiction for shareholder disputes. This could limit shareholder remedies.

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2025 PORTFOLIO DEVELOPMENTS

Integrated Gas

In March 2025, we completed the previously announced acquisition of 100% of the shares in Pavilion Energy Pte. Ltd. (Pavilion Energy). Pavilion Energy, headquartered in Singapore, operates a global LNG trading business with contracted supply volume of approximately 6.5 million tonnes per annum (mtpa).

Upstream

In January 2025, we announced the start of production at the Shell-operated Whale floating production facility in the Gulf of America. The Whale development is owned by Shell (60%, operator) and Chevron U.S.A. Inc. (40%).

In February 2025, we announced production restart at the Penguins field in the UK North Sea with a modern floating, production, storage and offloading (FPSO) facility (Shell 50%, operator; NEO Energy 50%). The previous export route for this field was via the Brent Charlie platform, which ceased production in 2021 and is being decommissioned.

In March 2025, we completed the sale of SPDC to Renaissance, as announced in January 2024.

In March 2025, we announced the Final Investment Decision (FID) for Gato do Mato, a deep-water project in the pre-salt area of the Santos Basin, offshore Brazil. The Gato do Mato Consortium includes Shell (operator, 50%), Ecopetrol (30%), TotalEnergies (20%) and Pré-Sal Petróleo S.A. (PPSA) acting as the manager of the production sharing contract (PSC).

In May 2025, we completed the previously announced agreement to increase our working interest in the Shell-operated Ursa platform in the Gulf of America from 45.39% to 61.35%.

Chemicals and Products

In January 2025, CNOOC and Shell Petrochemicals Company Limited (CSPC), a 50:50 joint venture between Shell and CNOOC Petrochemicals Investment Ltd, took an FID to expand its petrochemical complex in Daya Bay, Huizhou, south China.

Renewables and Energy Solutions

In January 2025, we completed the previously announced acquisition of a 100% equity stake in RISEC Holdings, LLC, which owns a 609-megawatt (MW) two-unit combined-cycle gas turbine power plant in Rhode Island, USA.

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RESPONSIBILITY STATEMENT

It is confirmed that to the best of our knowledge: (a) the unaudited Condensed Consolidated Interim Financial Statements have been prepared in accordance with IAS 34 Interim Financial Reporting as issued by the International Accounting Standards Board (“IASB”) and as adopted by the UK; (b) the interim management report includes a fair review of the information required by Disclosure Guidance and Transparency Rule (DTR) 4.2.7R (indication of important events during the first six months of the financial year, and their impact on the unaudited Condensed Consolidated Interim Financial Statements, and description of principal risks and uncertainties for the remaining six months of the financial year); and (c) the interim management report includes a fair review of the information required by DTR 4.2.8R (disclosure of related parties transactions and changes thereto).

The Directors of Shell plc are shown on pages 152 to 155 in the Annual Report and Accounts for the year ended December 31, 2024.

On behalf of the Board

Wael Sawan

Sinead Gorman

Chief Executive Officer

Chief Financial Officer

July 31, 2025

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2nd QUARTER 2025 AND HALF YEAR UNAUDITED RESULTS

INDEPENDENT REVIEW REPORT TO SHELL PLC

Conclusion

We have been engaged by Shell plc to review the Condensed Consolidated Interim Financial Statements (“Interim Statements”) and half year unaudited results (“half-yearly financial report”) for the six months ended June 30, 2025, which comprise the Consolidated Statement of Income, the Consolidated Statement of Comprehensive Income, the Condensed Consolidated Balance Sheet, the Consolidated Statement of Changes in Equity, the Consolidated Statement of Cash Flows and Notes 1 to 9. We have read the other information contained in the half-yearly financial report and considered whether it contains any apparent misstatements or material inconsistencies with the information in the Interim Statements.

Based on our review, nothing has come to our attention that causes us to believe that the Interim Statements in the half-yearly financial report for the six months ended June 30, 2025 are not prepared, in all material respects, in accordance with UK adopted International Accounting Standard 34 and the Disclosure Guidance and Transparency Rules of the United Kingdom’s Financial Conduct Authority.

Basis for Conclusion

We conducted our review in accordance with International Standard on Review Engagements (“ISRE”) 2410 (UK), “Review of Interim Financial Information Performed by the Independent Auditor of the Entity” (ISRE) issued by the Financial Reporting Council. A review of interim financial information consists of making enquiries, primarily of persons responsible for financial and accounting matters, and applying analytical and other review procedures. A review is substantially less in scope than an audit conducted in accordance with International Standards on Auditing (UK) and consequently does not enable us to obtain assurance that we would become aware of all significant matters that might be identified in an audit. Accordingly, we do not express an audit opinion.

As disclosed in Note 1, Shell’s annual financial statements are prepared in accordance with UK adopted international accounting standards. The Interim Statements included in the half-yearly financial report have been prepared in accordance with UK adopted International Accounting Standard 34 “Interim Financial Reporting”.

Conclusions Relating to Going Concern

Based on our review procedures, which are less extensive than those performed in an audit as described in the Basis of Conclusion section of this report, nothing has come to our attention to suggest that management have inappropriately adopted the going concern basis of accounting or that management have identified material uncertainties relating to going concern that are not appropriately disclosed.

This conclusion is based on the review procedures performed in accordance with this ISRE, however future events or conditions may cause the entity to cease to continue as a going concern.

Responsibilities of the Directors

The Directors are responsible for preparing the half-yearly financial report in accordance with the Disclosure Guidance and Transparency Rules of the United Kingdom’s Financial Conduct Authority.

In preparing the half-yearly financial report, the Directors are responsible for assessing the company’s ability to continue as a going concern, disclosing, as applicable, matters related to going concern and using the going concern basis of accounting unless the Directors either intend to liquidate the company or to cease operations, or have no realistic alternative but to do so.

Auditor’s Responsibilities for the review of the financial information

In reviewing the half-yearly financial report, we are responsible for expressing to Shell plc a conclusion on the Interim Statements in the half-yearly financial report. Our conclusion, including our Conclusions Relating to Going Concern are based on procedures that are less extensive than audit procedures, as described in the Basis for Conclusion paragraph of this report.

Use of our report

This report is made solely to Shell plc in accordance with guidance contained in the International Standard on Review Engagements 2410 (UK) “Review of Interim Financial Information Performed by the Independent Auditor of the Entity” issued by the Financial Reporting Council. To the fullest extent permitted by law, we do not accept or assume responsibility to anyone other than Shell plc, for our work, for this report, or for the conclusions we have formed.

Ernst & Young LLP

London

July 31, 2025

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CAUTIONARY STATEMENT

All amounts shown throughout this Unaudited Condensed Interim Financial Report are unaudited. All peak production figures in Portfolio Developments are quoted at 100% expected production. The numbers presented throughout this Unaudited Condensed Interim Financial Report may not sum precisely to the totals provided and percentages may not precisely reflect the absolute figures, due to rounding.

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

Forward-Looking statements

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

Shell’s net carbon intensity

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

Shell’s net-zero emissions target

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

Forward-Looking non-GAAP measures

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

The contents of websites referred to in this Unaudited Condensed Interim Financial Report do not form part of this Unaudited Condensed Interim Financial Report.

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

This announcement contains inside information.

July 31, 2025


The information in this Unaudited Condensed Interim Financial Report reflects the unaudited consolidated financial position and results of Shell plc. Company No. 4366849, Registered Office: Shell Centre, London, SE1 7NA, England, UK.

Contacts:

– Sean Ashley, Company Secretary

– Media: International +44 (0) 207 934 5550; U.S. and Canada: https://www.shell.us/about-us/news-and-insights/media/submit-an-inquiry.html

LEI number of Shell plc: 21380068P1DRHMJ8KU70

Classification: Half yearly financial reports and audit reports / limited reviews; Inside Information

Page 42

The MIL Network –

August 5, 2025

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

Source: GlobeNewswire (MIL-OSI)

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

Dr. Sean Guest, President and CEO commented:

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

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

For further information, please contact:

Valeura Energy Inc. (General Corporate Enquiries) Sean Guest, President and CEO Yacine Ben-Meriem, CFO Contact@valeuraenergy.com	+65 6373 6940

Valeura Energy Inc. (Investor and Media Enquiries) Robin James Martin, Vice President, Communications and Investor Relations IR@valeuraenergy.com	+1 403 975 6752 / +44 7392 940495

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

About the Company

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

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

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

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

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

The MIL Network –

August 5, 2025

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

Source: GlobeNewswire (MIL-OSI)

London, July 31, 2025

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

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

Shell plc Chief Executive Officer, Wael Sawan

ROBUST CASH GENERATION; STRONG OPERATIONAL PERFORMANCE

Adjusted Earnings¹ of $4.3 billion despite lower trading contribution in a weaker margin environment.
Robust CFFO of $11.9 billion, supported by strong operational performance, enables commencement of another $3.5 billion share buyback programme for the next three months.
Strong balance sheet, with gearing of 19%. 2025 cash capex outlook unchanged at $20 – 22 billion. Total shareholder distributions paid over the last 4 quarters were 46% of CFFO.
Achieved $0.8 billion of structural cost reductions in the first half of 2025, of which $0.5 billion is through non-portfolio actions; cumulative reductions since 2022 are $3.9 billion, against CMD25 target of $5 – 7 billion by end of 2028.
First cargo shipped from LNG Canada, strengthening our leading LNG position and supporting our ambition to achieve LNG sales cumulative annual growth rate of 4 – 5% to 2030.
Further enhanced peer-leading deep-water position with start-up of Mero-4 (Brazil) and announced increase of interests in Gato do Mato (Brazil) and Bonga (Nigeria); continued to high-grade Downstream and R&ES portfolio.

$ million¹		Adj. Earnings	Adj. EBITDA	CFFO	Cash capex
Integrated Gas		1,737	3,875	3,629	1,196
Upstream		1,732	6,638	6,500	2,826
Marketing		1,199	2,181	2,718	429
Chemicals & Products²		118	864	1,372	775
Renewables & Energy Solutions (R&ES)		(9)	102	1	555
Corporate		(463)	(346)	(2,283)	36
Less: Non-controlling interest (NCI)		50
Shell	Q2 2025	4,264	13,313	11,937	5,817
Shell	Q1 2025	5,577	15,250	9,281	4,175

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

CFFO excluding working capital of $12.3 billion is helped by derivative inflows and JV dividends received.
Working capital outflow of $0.4 billion reflects a reduction in JV deposits. $1.7 billion of the JV dividends received were previously held in deposit in the Corporate segment.
Net debt excluding leases is $14.3 billion.

$ billion¹	Q2 2024	Q3 2024	Q4 2024	Q1 2025	Q2 2025
Working capital	(0.3)	2.7	2.4	(2.7)	(0.4)
Divestment proceeds	0.8	0.2	0.8	0.6	(0.0)
Free cash flow	10.2	10.8	8.7	5.3	6.5
Net debt	38.3	35.2	38.8	41.5	43.2

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

Q2 2025 FINANCIAL PERFORMANCE DRIVERS

INTEGRATED GAS

Key data	Q1 2025	Q2 2025	Q3 2025 outlook
Realised liquids price ($/bbl)	64	60	—
Realised gas price ($/thousand scf)	7.4	7.2	—
Production (kboe/d)	927	913	910 – 970
LNG liquefaction volumes (MT)	6.6	6.7	6.7 – 7.3
LNG sales volumes (MT)	16.5	17.8	—

Adjusted Earnings were lower than in Q1 2025, reflecting lower prices and significantly lower trading and optimisation results.

UPSTREAM

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

Adjusted Earnings were lower than in Q1 2025, reflecting lower prices.

MARKETING

Key data	Q1 2025	Q2 2025	Q3 2025 outlook
Marketing sales volumes (kb/d)	2,674	2,813	2,600 – 3,100
Mobility (kb/d)	1,964	2,044	—
Lubricants (kb/d)	87	85	—
Sectors & Decarbonisation (kb/d)	623	684	—

Adjusted Earnings were higher than in Q1 2025, driven mainly by improved Mobility unit margins and seasonally higher volumes.

CHEMICALS & PRODUCTS

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

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

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

RENEWABLES & ENERGY SOLUTIONS

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

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

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

CORPORATE

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

UPCOMING INVESTOR EVENTS

October 30, 2025

Third quarter 2025 results and dividends

USEFUL LINKS

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

ALTERNATIVE PERFORMANCE (NON-GAAP) MEASURES

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

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

CAUTIONARY STATEMENT

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

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

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

Shell’s Net Carbon Intensity

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

Shell’s Net-Zero Emissions Target

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

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

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

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

CONTACTS

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

The MIL Network –

August 5, 2025

MIL-OSI: Shell plc Second Quarter 2025 Interim Dividend

Source: GlobeNewswire (MIL-OSI)

London, July 31, 2025 − The Board of Shell plc (the “Company”) (XLON: SHEL, XNYS: SHEL, XAMS: SHELL) today announced an interim dividend in respect of the second quarter of 2025 of US$ 0.358 per ordinary share.

Details relating to the second quarter 2025 interim dividend

Per ordinary share (GB00BP6MXD84)	Q2 2025
Shell Shares (US$)	0.358

Shareholders will be able to elect to receive their dividends in US dollars, euros or pounds sterling.

An alternative ‘Electronic Election Entitlement’ (‘EEE’) process is available in CREST for dividends with options elections.

Absent any valid election to the contrary, persons holding their ordinary shares through Euroclear Nederland will receive their dividends in euros.

Absent any valid election to the contrary, shareholders (both holding in certificated and uncertificated form (CREST members)) and persons holding their shares through the Shell Corporate Nominee will receive their dividends in pounds sterling.

The pound sterling and euro equivalent dividend payments will be announced on September 8, 2025.

Per ADS (US7802593050)	Q2 2025
Shell ADSs (US$)	0.716

Cash dividends on American Depositary Shares (“ADSs”) will be paid, by default, in US dollars.

Each ADS represents two ordinary shares. ADSs are evidenced by an American Depositary Receipt (“ADR”) certificate. In many cases the terms ADR and ADS are used interchangeably.

Dividend timetable for the second quarter 2025 interim dividend

Event	Date
Announcement date	July 31, 2025
Ex- Dividend Date for ADSs	August 15, 2025
Ex- Dividend Date for ordinary shares	August 14, 2025
Record date	August 15, 2025
Closing of currency election date (see Note below)	September 1, 2025
Pound sterling and euro equivalents announcement date	September 8, 2025
Payment date	September 22, 2025

Note

A different currency election date may apply to shareholders holding shares in a securities account with a bank or financial institution ultimately holding through Euroclear Nederland. This may also apply to other shareholders who do not hold their shares either directly on the Register of Members or in the corporate sponsored nominee arrangement. Shareholders can contact their broker, financial intermediary, bank or financial institution for the election deadline that applies.

Taxation – cash dividends

If you are uncertain as to the tax treatment of any dividends you should consult your tax advisor.

Dividend Reinvestment Programmes (“DRIP”)

The following organisations offer Dividend Reinvestment Plans (“DRIPs”) which enable the Company’s shareholders to elect to have their dividend payments used to purchase the Company’s shares:

Equiniti Financial Services Limited (“EFSL”), for those holding shares (a) directly on the register as certificate holder or as CREST Member and (b) via the Shell Corporate Nominee;

ABN-AMRO NV (“ABN”) for Financial Intermediaries holding shares via Euroclear Nederland;

JPMorgan Chase Bank, N.A. (“JPM”) for holders of ADSs; and

Other DRIPs may also be available from the intermediary through which investors hold their shares and ADSs.

These DRIP offerors provide their DRIPs fully on their account and not on behalf of the Company. Interested parties should contact the relevant DRIP offeror directly.

More information can be found at https://www.shell.com/drip

To be eligible to participate in the DRIPs for the next dividend, shareholders must make a valid dividend reinvestment election before the published date for the close of elections.

Enquiries
Media: International +44 (0) 207 934 5550; U.S. and Canada: https://www.shell.us/about-us/news-and-insights/media/submit-an-inquiry.html

Cautionary Note

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

Forward-Looking statements

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

Shell’s net carbon intensity

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

Shell’s net-zero emissions target

Forward-Looking non-GAAP measures

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

The contents of websites referred to in this announcement do not form part of this announcement.

LEI number of Shell plc: 21380068P1DRHMJ8KU70
Classification: Additional regulated information required to be disclosed under the laws of the United Kingdom

The MIL Network –

August 5, 2025

MIL-OSI Banking: Secretary-General of ASEAN meets with Minister of Agriculture and Agri-Food of Canada

Source: ASEAN

Secretary-General of ASEAN, Dr. Kao Kim Hourn, today received the Minister of Agriculture and Agri-Food of Canada, H.E. Mr. Heath MacDonald, at the ASEAN Headquarters/ASEAN Secretariat. They discussed potential areas of cooperation between ASEAN and Canada, particularly in sustainable agriculture, the reduction of harmful agrochemicals, and the promotion of regenerative agriculture. On ASEAN-Canada Free Trade Agreement (FTA) negotiations, SG Dr. Kao encouraged Canada to adopt a constructive approach, especially in areas such as equivalence and risk assessment, which could help expedite the conclusion of the Sanitary and Phytosanitary (SPS) Chapter.

The post Secretary-General of ASEAN meets with Minister of Agriculture and Agri-Food of Canada appeared first on ASEAN Main Portal.

MIL OSI Global Banks –

August 5, 2025
MIL-OSI: International Petroleum Corporation to release Second Quarter 2025 Financial and Operational Results on August 5, 2025
Source: GlobeNewswire (MIL-OSI)

International Petroleum Corporation (IPC) (TSX, Nasdaq Stockholm: IPCO) will publish its financial and operating results and related management’s discussion and analysis for the three and six months ended June 30, 2025, on Tuesday, August 5, 2025 at 07:30 CEST, followed by an audiocast at 09:00 CEST.

Listen to William Lundin, President and CEO, and Christophe Nerguararian, CFO, commenting on the second quarter 2025 financial and operating results and the latest developments from IPC.

Follow the presentation live starting at 09:00 CEST on Tuesday, August 5, 2025 on www.international-petroleum.com or using the link or dial-in details below:

Presentation Link: https://ipc.videosync.fi/2025-08-05

Dial-in numbers

Canada/USA: +1 786 697 3501
UK: +44 33 0551 0200
Sweden: +46 8 5052 0424

Password

Quote “IPC” when prompted by the operator

International Petroleum Corp. (IPC) is an international oil and gas exploration and production company with a high quality portfolio of assets located in Canada, Malaysia and France, providing a solid foundation for organic and inorganic growth. IPC is a member of the Lundin Group of Companies. IPC is incorporated in Canada and IPC’s shares are listed on the Toronto Stock Exchange (TSX) and the Nasdaq Stockholm under the symbol “IPCO”.

For further information, please contact:

Rebecca Gordon
SVP Corporate Planning and Investor Relations
rebecca.gordon@international-petroleum.com
Tel: +41 22 595 10 50 Robert Eriksson
Media Manager
reriksson@rive6.ch
Tel: +46 701 11 26 15

Forward-Looking Statements
This press release contains statements and information which constitute “forward-looking statements” or “forward-looking information” (within the meaning of applicable securities legislation). Such statements and information (together, “forward-looking statements”) relate to future events, including the Corporation’s future performance, business prospects or opportunities. Actual results may differ materially from those expressed or implied by forward-looking statements. The forward-looking statements contained in this press release are expressly qualified by this cautionary statement. Forward-looking statements speak only as of the date of this press release, unless otherwise indicated. IPC does not intend, and does not assume any obligation, to update these forward-looking statements, except as required by applicable laws.

All statements other than statements of historical fact may be forward-looking statements. Any statements that express or involve discussions with respect to predictions, expectations, beliefs, plans, projections, forecasts, guidance, budgets, objectives, assumptions or future events or performance (often, but not always, using words or phrases such as “seek”, “anticipate”, “plan”, “continue”, “estimate”, “expect”, “may”, “will”, “project”, “forecast”, “predict”, “potential”, “targeting”, “intend”, “could”, “might”, “should”, “believe”, “budget” and similar expressions) are not statements of historical fact and may be “forward-looking statements”.

Attachment
- IPC PR 2025_Q2 release advance 31-07-2025
The MIL Network –
August 5, 2025
MIL-OSI Russia: Canada to recognize Palestinian state in September: PM

Translation. Region: Russian Federal

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

An important disclaimer is at the bottom of this article.

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

OTTAWA, July 30 (Xinhua) — Canada plans to recognize the State of Palestine in September, Prime Minister Mark Carney announced on Wednesday.

According to a statement from his office, Canada intends to recognize a Palestinian state at the 80th session of the UN General Assembly, since the prospects for realizing the “two-state solution” have been seriously and fundamentally undermined.

“This intention is based on the Palestinian National Authority’s (PNA) commitment to urgently needed reforms, including PNA President Mahmoud Abbas’s commitment to fundamentally transform the system of governance, hold general elections in 2026 in which Hamas will not be able to participate, and demilitarize the Palestinian state,” the statement said.

Canada also reiterated that Hamas should immediately release all hostages and disarm. The movement should have no role in the future governance of Palestine, the prime minister’s office said. -0-

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

.

MIL OSI Russia News –

August 5, 2025
MIL-OSI Russia: Palestine recognition for Australian federal government ‘when, not if’ – Treasurer

Translation. Region: Russian Federal

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

An important disclaimer is at the bottom of this article.

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

CANBERRA, July 31 (Xinhua) — For the Australian federal government, recognizing Palestine is a matter of “when, not if,” Treasurer Jim Chalmers told ABC on Thursday.

“There are still a number of obstacles to recognizing a Palestinian state. For example, the treatment of hostages, their release, ensuring that Hamas plays absolutely no role,” Chalmers said.

He made the statement shortly before Canadian Prime Minister Mark Carney announced his country’s intention to recognize Palestinian statehood at the 80th session of the UN General Assembly in September.

On Tuesday, foreign ministers from 15 countries, including Australia and Canada, issued a joint statement reaffirming their “unwavering commitment” to a two-state solution for Palestine.

Australian Prime Minister Anthony Albanese is under pressure from his fellow party members to recognize Palestinian statehood, ABC reported Thursday. –0–

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

.

MIL OSI Russia News –

August 5, 2025
MIL-OSI Europe: Joint statement by Canada and Sweden on sustained engagement on critical raw materials, battery value chains and emerging technologies

Source: Government of Sweden

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

MIL OSI Europe News –

August 5, 2025
MIL-OSI: Sidetrade charts its course in responsible AI with the publication of its 2024 CSR report
Source: GlobeNewswire (MIL-OSI)

In a digital world where algorithms grow more powerful by the day, Sidetrade, a pioneer in AI-powered cash flow management, reaffirms its role as a responsible leader. Today, the company releases its 2024 CSR Report, marking a new milestone in its commitment to sustainable technology, ethical governance, and inclusive growth.

Structured in accordance with the voluntary CSRD VSME framework, Sidetrade’s 2024 report tells a standout story in the tech industry: a company that, in 2024, achieved remarkable revenue growth (+26%) while reducing its carbon footprint by 3.3%. This contrast reflects Sidetrade’s core ambition: to decouple business growth from environmental impact.

“Cash is still the oxygen that fuels business growth. But that growth must no longer come at any cost. We have set a new standard, one that aligns performance with purpose,” said Olivier Novasque, CEO and founder at Sidetrade. “Our agentic AI, Aimie, must be useful, efficient, and capable of delivering business value, operational excellence, and positive societal impact.”

In 2024, Sidetrade launched an ambitious digital sobriety program. With a virtualization rate of 95.6%, data centers powered by renewable energy (both in Europe and North America), and a Power Usage Effectiveness of 1.39 (well below the EU average*), Sidetrade is redefining SaaS industry benchmarks.

Sidetrade also made a notable impact in non-financial ratings, earning a Platinum Medal from EthiFinance and a Silver Medal from EcoVadis, placing it among the top 15% of rated companies in Europe. This recognition highlights both its tangible carbon reductions and the strength of its CSR governance, led by a dedicated committee reporting to executive leadership.

“Excellence and ambition are the dual engines of our CSR journey,” said Philippe Gangneux, CFO and CSR Ambassador at Sidetrade. “Excellence ensures discipline in our commitments; ambition pushes us to aim higher, to reach further, and to generate lasting impact.”

As an active member of the United Nations Global Compact, Sidetrade has aligned its roadmap with 10 of the UN’s Sustainable Development Goals, including climate action, workplace equity, ethical governance, and digital resilience.

The 2024 Sidetrade CSR report, with detailed performance indicators, is available here.

*source: ADEME, 2024

Investor & Media relations @Sidetrade
Christelle Dhrif +33 6 10 46 72 00 cdhrif@sidetrade.com

About Sidetrade (www.sidetrade.com)
Sidetrade (Euronext Growth: ALBFR.PA) provides a SaaS platform designed to revolutionize how cash flow is secured and accelerated. Leveraging its new-generation agentic AI, nicknamed Aimie, Sidetrade analyzes $7.2 trillion worth of B2B payment transactions daily in its Cloud, thereby anticipating customer payment behavior and the attrition risk of 40 million buyers worldwide. Sidetrade has a global reach, with 400+ talented employees based in Europe, the United States, and Canada, serving global businesses in more than 85 countries. Among them: AGFA, BMW Financial Services, Bunzl, DXC, Engie, Inmarsat, KPMG, Lafarge, Manpower, Morningstar, Page, Randstad, Safran, Saint-Gobain, Securitas, Siemens, UGI, Veolia.
For further information, visit us at www.sidetrade.com and follow @Sidetrade on LinkedIn.
In the event of any discrepancy between the French and English versions of this press release, only the French version is to be taken into account.

Attachments
- Sidetrade charts its course in responsible AI with the publication of its 2024 CSR report.
- Sidetrade: 2024 CSR Report
The MIL Network –
August 5, 2025
MIL-OSI: Prospera Energy Inc. Provides Operations Update

Source: GlobeNewswire (MIL-OSI)

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

For Further Information:

Shawn Mehler, PR
Email: investors@prosperaenergy.com

Chris Ludtke, CFO
Email: cludtke@prosperaenergy.com

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

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

Although Prospera believes that the expectations and assumptions on which the forward-looking statements are based are reasonable, undue reliance should not be placed on the forward-looking statements because Prospera can give no assurance that they will prove to be correct. Since forward-looking statements address future events and conditions, by their very nature they involve inherent risks and uncertainties. Actual results could differ materially from those currently anticipated due to a number of factors and risks. These include, but are not limited to, risks associated with the oil and gas industry in general (e.g., operational risks in development, exploration and production; delays or changes in plans with respect to exploration or development projects or capital expenditures; the uncertainty of reserve estimates; the uncertainty of estimates and projections relating to production, costs and expenses, and health, safety and environmental risks), commodity price and exchange rate fluctuations and uncertainties resulting from potential delays or changes in plans with respect to exploration or development projects or capital expenditures.

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

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

The MIL Network –

August 5, 2025
MIL-OSI: Introducing Commerce, the New Parent Brand of BigCommerce, Feedonomics and Makeswift, Powering an AI-Driven Future
Source: GlobeNewswire (MIL-OSI)

Commerce’s open, intelligent ecosystem connects the tools and systems that drive growth and empower businesses to unlock data potential and deliver seamless, personalized experiences at scale

Commerce unveils unified AI vision to enable every merchant to thrive in the agentic commerce era

AUSTIN, Texas, July 31, 2025 (GLOBE NEWSWIRE) — BigCommerce Holdings, Inc. (Nasdaq: BIGC), a leading open SaaS ecommerce platform for B2C and B2B businesses, today announced the launch of its new parent brand, Commerce, and that it has officially changed its corporate name to Commerce.com, Inc. (“Commerce” or the “Company”), unifying BigCommerce, Feedonomics and Makeswift to power the next era of agentic commerce. In connection with the name change and rebranding, effective on or about August 1, 2025, the Company’s common stock will begin trading on the Nasdaq Global Market under the ticker symbol “CMRC” and cease trading under “BIGC.” This strategic move introduces a bold vision for the future where AI navigates choices for consumers and businesses adapt with intelligent, composable tools.

In conjunction with the rebrand, Commerce also unveiled the company’s vision and strategy for powering agentic commerce where AI acts on behalf of consumers to research, recommend and even transact. To support this shift, Commerce is focused on enabling merchants with the data infrastructure and intelligent storefronts needed to thrive in this next chapter of digital commerce.

“Launching the Commerce brand is about more than a new name and logo,” said Commerce CEO Travis Hess. “It is a clear declaration to our customers, partners, investors and team that we are doubling down on innovation to give brands, retailers, manufacturers, distributors and wholesalers the flexibility, connectivity and care to help them move faster, scale smarter and grow on their terms. Agentic commerce requires a new playbook, and Commerce is here to deliver it with an open ecosystem built for speed, intelligence and flexibility.”

Unifying Three Market-leading Solutions

The individual BigCommerce, Feedonomics and Makeswift brands will continue to exist as three powerful solutions with a unified purpose:
- BigCommerce is the flexible ecommerce platform that grows with merchants. It is trusted by teams that value speed and scalability, empowering innovation without constraint.
- Feedonomics turns data into a competitive advantage, ensuring every product is AI-ready and optimized across hundreds of global channels.
- Built for both marketers and developers, Makeswift is the intuitive visual editor that lets whole teams collaborate to create cutting-edge, personalized digital experiences.
Together, Commerce connects the tools and systems that drive growth, whether it is part of our family of brands or a trusted outside partner. Its open, intelligent ecosystem empowers businesses to unlock data potential and deliver seamless, personalized experiences at scale.

“Commerce is more than just another ecommerce company,” said Hess. “We are a trusted partner, an innovation engine and a champion that stands behind what we promise, and one of those promises is to provide an AI-driven ecosystem that aligns innovation with outcomes.”

Delivering AI to Drive Results

The way consumers discover and purchase products online is undergoing a dramatic transformation. Traditional organic search is rapidly losing ground as the “front door” of the internet. Instead, shoppers are turning to answer engines—AI-powered platforms like ChatGPT, Perplexity, Copilot and Google Cloud with Gemini—to find what they need and even buy it. In this new era, AI agents act on behalf of shoppers, searching, comparing, and even checking out across multiple channels, often without ever visiting a merchant’s website. These AI-driven experiences are seamless, contextual and increasingly the default for how consumers interact with commerce online.

For large retail brands and technology companies, this means that web traffic is already shifting as the old playbook of SEO and paid ads becomes less effective. The conversation is focused on regaining visibility and relevance in a fundamentally new digital landscape.

Commerce offers a complete solution for the AI era. Feedonomics optimizes merchant data for every touchpoint and holds strategic partnerships with leading AI platforms. BigCommerce provides the operating system for merchants of record. Makeswift powers AI-optimized storefronts. Every merchant needs an end-to-end strategy with these pillars for success in AI-driven commerce.

Over the last few weeks, Commerce brands BigCommerce and Feedonomics have expanded partnerships with AI leaders Perplexity and Google Cloud to help businesses capitalize on agentic commerce opportunities to meet consumer expectations and create a competitive advantage.

“At Commerce, we leverage AI where it delivers real, measurable results: powering personalization, automation and data orchestration across the entire customer journey from discovery to checkout,” said Vipul Shah, chief product officer at Commerce. “By delivering relevant, context-optimized data to digital channels including answer engines, and creating agentic tools to help merchants optimize their operations, Commerce helps businesses adapt in real time and grow intelligently. We’re not just following the AI wave; we’re in the room with the product and engineering teams from the leading AI companies shaping the future of the internet so that we are positioned to help our customers win.”

Adventure brand Revelyst, the parent company of Bell, Bushnell, CamelBak and Giro; global consumer brand URBN, the parent company of Urban Outfitters, Anthropologie and many others; and Tapestry, the parent company of fashion brands such as Coach and Kate Spade New York; and Dell Technologies are already leveraging Commerce’s product data integrations to improve visibility, protect brand consistency and boost performance across AI-driven search experiences.

“Since Travis stepped into the CEO role, he has assembled an experienced and visionary leadership team that came together with clarity and conviction to transform the company,” said Ellen Siminoff, executive chair of the board of directors at Commerce. “The launch of Commerce is the culmination of bold thinking, careful planning and hard work during a period of rapid industry change. This transformation positions the company for a return to long-term, sustainable growth. We are proud of our progress thus far and look forward to continuous execution.”

Conference Call Information

Commerce will host its first quarterly earnings call under the Commerce name later this morning at 7:00 a.m. CT (8:00 a.m. ET) Thursday, July 31, 2025. The conference call can be accessed by dialing (833) 634-1254 from the United States and Canada or (412) 317-6012 internationally and requesting to join the “Commerce conference call.” The live webcast of the conference call can be accessed from BigCommerce’s investor relations website at http://investors.bigcommerce.com.

Following the completion of the call through 11:59 p.m. ET on Thursday, August 7, 2025, a telephone replay will be available by dialing (877) 344-7529 from the United States, (855) 669-9658 from Canada or (412) 317-0088 internationally with conference ID 7863771. A webcast replay will also be available at http://investors.bigcommerce.com for 12 months.

About Commerce

Commerce empowers businesses to innovate, grow, and thrive by providing an open, AI-driven commerce ecosystem. As the parent company of BigCommerce, Feedonomics, and Makeswift, Commerce connects the tools and systems that power growth, enabling businesses to unlock the full potential of their data, deliver seamless and personalized experiences across every channel, and adapt swiftly to an ever-changing market. Trusted by leading businesses like Coldwater Creek, Cole Haan, Harvey Nichols, King Arthur Baking Co., Melissa & Doug, Mizuno, Patagonia, Perry Ellis, Puma, SportsShoes, and Uplift Desk, Commerce delivers the storefront control, optimized data, and AI-ready tools businesses need to grow, serve diverse buyers, and operate with confidence in an increasingly intelligent, multi-surface world. For more information, visit commerce.com or follow us on X and LinkedIn.

BigCommerce,® the Commerce logo, and other brands are the trademarks or registered trademarks of BigCommerce Pty. Ltd. Third-party trademarks and service marks are the property of their respective owner.

Forward-Looking Statements

This press release contains “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. In some cases, you can identify forward-looking statements by terms such as “anticipate,” “believe,” “estimate,” “expect,” “intend,” “outlook,” “may,” “might,” “plan,” “project,” “will,” “would,” “should,” “could,” “can,” “predict,” “potential,” “strategy, “target,” “explore,” “continue,” or the negative of these terms, and similar expressions intended to identify forward-looking statements. However, not all forward-looking statements contain these identifying words. These statements may relate to our ability to successfully execute our rebranding initiative, our increased focus on AI enablement, market size and growth strategy, our estimated and projected costs, margins, revenue, expenditures and customer and financial growth rates, our plans and objectives for future operations, growth, initiatives or strategies. By their nature, these statements are subject to numerous uncertainties and risks, including factors beyond our control, that could cause actual results, performance or achievement to differ materially and adversely from those anticipated or implied in the forward-looking statements. These assumptions, uncertainties and risks include that, among others, our business would be harmed by any decline in new customers, renewals or upgrades, our limited operating history makes it difficult to evaluate our prospects and future results of operations, we operate in competitive markets, we may not be able to sustain our revenue growth rate in the future, our business would be harmed by any significant interruptions, delays or outages in services from our platform or certain social media platforms, and a cybersecurity-related attack, significant data breach or disruption of the information technology systems or networks could negatively affect our business. Additional risks and uncertainties that could cause actual outcomes and results to differ materially from those contemplated by the forward-looking statements are included under the caption “Risk Factors” and elsewhere in our filings with the Securities and Exchange Commission (the “SEC”), including our Annual Report on Form 10-K for the year ended December 31, 2024 and the future quarterly and current reports that we file with the SEC. Forward-looking statements speak only as of the date the statements are made and are based on information available to Commerce at the time those statements are made and/or management’s good faith belief as of that time with respect to future events. Commerce assumes no obligation to update forward-looking statements to reflect events or circumstances after the date they were made, except as required by law.

Media Contact:
Brad Hem
pr@commerce.com

A photo accompanying this announcement is available at https://www.globenewswire.com/NewsRoom/AttachmentNg/0e3864e0-299e-4612-a8de-892adb7645e8

The MIL Network –
August 5, 2025

MIL-OSI: Cenovus announces second-quarter 2025 results

Source: GlobeNewswire (MIL-OSI)

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

Highlights

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

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

Financial summary

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

Production and throughput

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

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

Second-quarter results

Operating¹

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

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

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

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

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

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

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

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

Financial

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

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

Growth projects

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

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

2025 guidance update

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

Changes to the company’s 2025 guidance include:

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

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

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

Dividend declarations and share purchases

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

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

Preferred shares dividend summary

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

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

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

2025 planned maintenance

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

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

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

Potential turnaround expenses

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

Conference call today

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

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

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

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

Advisory

Basis of Presentation

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

Barrels of Oil Equivalent

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

Product types

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

Forward‐looking Information

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

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

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

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

Specified Financial Measures

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

Upstream Operating Margin and Downstream Operating Margin

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

Total Operating Margin

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

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

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

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

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

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

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

Adjusted Market Capture

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

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

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

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

Cenovus Energy Inc.

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

Find Cenovus on Facebook, LinkedIn, YouTube and Instagram.

Cenovus contacts

Investors
Investor Relations general line
403-766-7711

Media
Media Relations general line
403-766-7751

The MIL Network –

August 5, 2025

MIL-OSI USA: Secretary Noem is Taking a Sledgehammer to Criminal Human Trafficking Rings

Source: US Federal Emergency Management Agency

Headline: Secretary Noem is Taking a Sledgehammer to Criminal Human Trafficking Rings

lass=”text-align-center”>On this World Day Against Trafficking in Persons, Kristi Noem and the Department of Homeland Security continue taking action to disrupt criminal human trafficking organizations
WASHINGTON – On this year’s World Day Against Trafficking in Persons, the Department of Homeland Security (DHS) is announcing a series of major crack downs against the worst of the worst criminal organizations: human trafficking rings

The previous administration’s open border policies empowered human traffickers and allowed over 450,000 unaccompanied children to be illegally smuggled over the border

Under President Trump and DHS Secretary Kristi Noem, the full weight of the American government is bringing the hammer down on human trafficking rings

In just the first few months, the Trump administration has developed leads on thousands of human trafficking cases

DHS has also cracked down on the criminal terrorist gang Tren de Aragua, which enriches itself through the sex trafficking of vulnerable young women

The Trump administration has arrested more than 2,700 members of Tren de Aragua so far

This crisis is fueled by organized crime networks: sophisticated cartels that exploited the weakness of the previous administration, especially its open border and refusal to enforce immigration law, to rake in billions from forced labor, brutal sexual exploitation, coercing innocent people into drug running, and other heinous crimes

“The brave men and women of DHS are the best in the world at going after traffickers

They are always able to track down those who are trafficking individuals, find the ringleaders, and rip that evil off by its head,” said Secretary Kristi Noem

“I’m so thankful that I get the chance to lead individuals like that, and agents who get up every day to help save our children and to save women and men from the kind of slavery that we’ve seen

”
Below are some examples of how DHS is fighting to put human traffickers out of business:

July 28, 2025: As part of Operation Apex Predator, a Child Exploitation Investigations Unit initiative with the Cyber Crimes Center, Immigration and Customs Enforcement (ICE) Newark arrested four illegal alien child predators over the course of four days

All four are registered sex offenders

July 23, 2025: ICE arrested 243 illegal aliens in the Denver metro area

Among those arrested were aliens wanted for human trafficking, and several members of transnational criminal organizations (TCOs), including Tren de Aragua (TdA), Los Zetas, and the Sinaloa Cartel

July 22, 2025: Following an ICE Homeland Security Investigations (HSI) investigation, a resident of Laredo, Texas was sentenced to 63 months in prison for smuggling 101 migrants in a locked trailer

Among the illegal aliens smuggled were 12 children

The suspect was sentenced after pleading guilty to conspiracy to transport migrants

July 21, 2025: As a result of an investigation by ICE HSI Rio Grande Valley, a convicted human smuggler was sentenced to 20 years in prison for possessing images of sexual assaults of prepubescent children

July 10, 2025: ICE and Customs and Border Protection (CBP) executed criminal warrant operations at marijuana facilities in Carpinteria and Camarillo, California

In these facilities, at least 14 migrant children were rescued from potential exploitation, forced labor, and human trafficking

During this operation, federal officers also arrested at least 361 illegal aliens

Among those arrested were criminals with convictions for kidnapping, rape, attempted rape, and attempted child molestation, among other charges

July 10, 2025: As the result of an ICE New York investigation, the leader of a Mexican sex trafficking organization was sentenced to 188 months in prison for sex trafficking multiple victims by force, fraud, and coercion

July 9, 2025: An ICE Del Rio investigation resulted in an illegal Honduran alien being sentenced to 10 years in prison, with three years of supervised release, for his role in smuggling thousands of aliens into the United States for financial gain

His smuggling conspiracy spanned three years and involved thousands of aliens from 11 different countries

July 7, 2025: Border Patrol agents assisted the U

S

Marshals in executing an arrest warrant on a high-priority target linked to a criminal syndicate operating in human exploitation

The suspect, a U

S

citizen, was wanted for multiple charges, including procurement of persons, placing individuals into prostitution, residing in a house of prostitution, and profiting from the earnings of prostitution

The suspect was arrested without incident in Yuma, Arizona

June 24, 2025: HSI Nashville identified one child victim and one adult victim of labor trafficking

During an immigration court proceeding, the child victim revealed that she and her 18-year-old brother had been forced by their sponsor to work to pay off their smuggling fees and to pay for the sponsor’s household expenses

June 16, 2025: A worksite enforcement operation by ICE HSI targeted employers and subcontractors who knowingly hire illegal aliens

During this operation, HSI Mobile identified and rescued a child and arrested eight foreign nationals for violating immigration law

The child was found to be working among adults and was believed to have never attended school since entering the United States two years ago

June 6, 2025: The Department of Justice (DOJ) indicted Kilmar Abrego Garcia, a Venezuelan illegal alien and member of MS-13 arrested by ICE, on charges of alien smuggling and conspiracy to commit alien smuggling

Despite the mainstream media insisting for months that Garcia was an innocent “Maryland father,” he is now standing trial after evidence emerged of his involvement in criminal smuggling rings

June 2, 2025: ICE Rio Grande Valley discovered a stash house in South Texas and subsequently arrested 16 illegal aliens

The owner of the property admitted to harboring the illegal aliens, who came from five different countries

A Mexican national was taken in for questioning for his role in human smuggling

May 28, 2025: HSI New York special agents arrested an adult male from Ecuador at his residence for violations relating to the sexual exploitation of a child

New York received information regarding a 15-year-old female who was apprehended near El Paso, Texas, after illegally entering the United States

At that time, she was pregnant with the adult’s child and had been in a relationship with him in Ecuador since the age of thirteen

The subject organized the smuggling of the teenager across the border to engage in sexual acts

His mother sponsored her after her illegal entry, and the subject continued his relationship with the children, living with his mother in Harlem

May 28, 2025: CBP issued a Withhold Release Order against Zhen Fa 7, a Chinese-flagged fishing vessel

As a result, CBP officers at all U

S

ports of entry will detain seafood harvested by Zhen Fa 7 based on reasonable suspicion that the vessel uses forced labor to harvest such seafood

May 28, 2025: Border Patrol agents in the San Diego Sector prevented an attempt to smuggle two Mexican nationals into the United States

The attempt involved one United States citizen and one Mexican national, who attempted to smuggle the illegal aliens across the border using a truck

Inside the truck were three fully loaded firearms, including a “ghost gun

” The suspected smugglers face felony charges of bringing in and harboring aliens, and unlawful acts involving firearms

May 12, 2025: HSI Austin identified and rescued a child, arrested two Guatemalan nationals for violating immigration law, and initiated an HSI-led investigation of state and federal charges of human trafficking and statutory rape

During a welfare check, HSI Agents, assisted by the FBI, identified a pregnant 14-year-old female residing with an unrelated adult male sponsor, later determined to be the biological father of the unborn child

May 7, 2025: CBP’s Air and Marine Operations (AMO) interdicted a vessel with four illegal aliens from Uzbekistan that were being smuggled into Puerto Rico

The vessel attempted to enter Puerto Rico on the island of Vieques; onboard were the four illegal aliens from Uzbekistan and three United States citizens

The Uzbeki nationals did not have any documents for an authorized entry or stay in the United States

May 4, 2025: Border Patrol agents in the Tucson Sector arrested a United States citizen and two Mexican nationals after a high-speed pursuit

The United States citizen, who was driving the car and had an extensive criminal history, fled from law enforcement at high speed after failing to stop at an immigration checkpoint

After crashing into another car, the three occupants fled on foot before being arrested

The driver faces federal charges that include human smuggling, fleeing law enforcement, and endangering human life

May 2, 2025: Four Mexican nationals in the United States illegally were charged for their roles in an international human smuggling conspiracy that brought aliens across the Canadian border into the United States for profit

The smuggling organization had been operating for two years and smuggled hundreds of aliens per week through Canada

The aliens or their family members would pay thousands of dollars to be smuggled into the United States

April 29, 2025: CBP officers at the Area Port of San Luis arrested a woman in connection with the failed smuggling attempt of a child

The suspect, a Mexican citizen, had sedated the child prior to attempting to cross the border

The suspect also presented a false birth certificate and alleged that she was the mother; the officers discovered that there was no family relationship between the woman and the child

April 2, 2025: CBP issued a Withhold Release Order against Taepyung Salt Farm, based on information that reasonably indicates the use of forced labor in the production of the company’s sea salt products

As a result, CBP personnel at all U

S

ports of entry will detain sea salt products from Taepyung Salt Farm in South Korea

March 25, 2025: After an ICE Arizona investigation with law enforcement partners, a human smuggling coordinator was sentenced to 30 months in prison for her role in smuggling over 100 Colombians into the United States

She had been operating a travel agency in her native country, Colombia, where she would charge the victims a fee to travel to Mexico, with additional bribes required at Mexican airports

February 14, 2025: Working with the Tennessee Bureau of Investigation, an ICE investigation led to a four-count indictment against eight defendants with ties to Tren de Aragua on charges related to their involvement with a transnational commercial sex enterprise

Everyone can be part of the fight against human trafficking

The DHS Blue Campaign can help you recognize human trafficking and provide resources to report suspicious activity to law enforcement

###

MIL OSI USA News –

August 5, 2025

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

Source: GlobeNewswire (MIL-OSI)

Solid execution and asset performance support higher 2025 financial outlook

Market fundamentals drive customer demand for incremental capacity projects

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

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

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

Operational Highlights

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

Project Highlights

The Southeast Gateway pipeline is in service and we commenced the collection of tolls from the Comisión Federal de Electricidad (CFE) beginning May 2025. In July 2025, the newly constituted Comisión Nacional de Energía (CNE) approved our regulated rates required to provide service to potential future interruptible service users on the Southeast Gateway pipeline other than the CFE
The East Lateral XPress (ELXP) project, an expansion project on the Columbia Gulf system that connects supply to U.S. Gulf Coast LNG export markets, was placed in service in May 2025, with total project costs of approximately US$0.3 billion
On July 1, 2025, Columbia Gas notified FERC that it has reached a settlement-in-principle on the Columbia Gas Section 4 Rate Case. Columbia Gas expects the final settlement to include an increase relative to pre-filed rates, subject to revision following completion and approval of settlement terms, anticipated in fourth quarter 2025
Upsized capacity on the previously announced Maysville and Pulaski projects — mainline extension projects off Columbia Gulf — to support incremental load growth in the region, including data centre development
Reached positive FID on $0.4 billion of expansion projects as part of the Multi-Year Growth Plan (MYGP). With in-service dates expected in 2027, the projects are designed to serve system demand growth and new supply on the NGTL System.


	three months ended June 30						six months ended June 30
(millions of $, except per share amounts)		2025			2024¹			2025			2024¹

Income
Net income (loss) attributable to common shares from continuing operations		862			804			1,840			1,792
per common share – basic	$	0.83		$	0.78		$	1.77		$	1.73

Segmented earnings (losses)
Canadian Natural Gas Pipelines		551			514			1,067			1,015
U.S. Natural Gas Pipelines		907			762			2,016			1,805
Mexico Natural Gas Pipelines		191			266			402			478
Power and Energy Solutions		312			220			447			472
Corporate		(7	)		(26	)		(12	)		(87	)
Total segmented earnings (losses)		1,954			1,736			3,920			3,683

Comparable EBITDA from continuing operations
Canadian Natural Gas Pipelines		923			846			1,813			1,692
U.S. Natural Gas Pipelines		1,089			1,003			2,456			2,309
Mexico Natural Gas Pipelines		319			286			552			500
Power and Energy Solutions		301			227			525			547
Corporate		(7	)		(14	)		(12	)		(30	)
Comparable EBITDA from continuing operations		2,625			2,348			5,334			5,018
Depreciation and amortization		(671	)		(633	)		(1,349	)		(1,268	)
Interest expense		(847	)		(783	)		(1,687	)		(1,563	)
Allowance for funds used during construction		114			184			362			341
Foreign exchange gains (losses), net included in comparable earnings		55			(51	)		45			(8	)
Interest income and other		49			68			100			143
Income tax (expense) recovery included in comparable earnings		(294	)		(143	)		(586	)		(424	)
Net (income) loss attributable to non-controlling interests included in comparable earnings		(155	)		(141	)		(332	)		(312	)
Preferred share dividends		(28	)		(27	)		(56	)		(50	)
Comparable earnings from continuing operations		848			822			1,831			1,877
Comparable earnings per common share from continuing operations	$	0.82		$	0.79		$	1.76		$	1.81

1 Results reflect continuing operations.


	three months ended June 30					six months ended June 30
(millions of $, except per share amounts)		2025			2024		2025			2024

Cash flows¹
Net cash provided by operations²		2,173			1,655		3,532			3,697
Comparable funds generated from operations^2,3		1,964			1,874		3,913			4,310
Capital spending⁴		1,379			1,591		3,188			3,488
Disposition of equity interest, net of transaction costs⁵		—			464		—			426
Dividends declared
per common share	$	0.85	⁶	$	0.96	$	1.70	⁶	$	1.92
Basic common shares outstanding(millions)
– weighted average for the period		1,040			1,037		1,040			1,037
– issued and outstanding at end of period		1,040			1,037		1,040			1,037

Includes continuing and discontinued operations.
Includes Liquids Pipelines earnings for the three and six months ended June 30, 2024 compared to Liquids Pipelines earnings of nil for the same periods in 2025. Refer to the 2024 Annual Report for additional information.
Comparable funds generated from operations is a non-GAAP measure used throughout this news release. This measure does not have any standardized meaning under GAAP and therefore is unlikely to be comparable to similar measures presented by other companies. The most directly comparable GAAP measure is net cash provided by operations. For more information on non-GAAP measures, refer to the Non-GAAP and Supplementary financial measure section of this news release.
Capital spending reflects cash flows associated with our Capital expenditures, Capital projects in development and Contributions to equity investments. Refer to Note 4, Segmented information, of our Condensed consolidated financial statements for additional information.
Included in the Financing activities section of the Condensed consolidated statement of cash flows.
Reflects dividends declared following the Spinoff Transaction.

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

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

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

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

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

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

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

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

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

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

A live webcast of the teleconference will be available on TC Energy’s website at TC Energy — Events and presentations or via the following URL: https://www.gowebcasting.com/1394 3. The webcast will be available for replay following the meeting.

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

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

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

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

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

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

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

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

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

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

	year ended December 31
(millions of Canadian $)	2024		2023		2022

Reported total debt	59,366		63,201		58,300
Management adjustments:
Debt treatment of preferred sharesⁱⁱ	1,250		1,250		1,250
Equity treatment of junior subordinated notesⁱⁱⁱ	(5,524	)	(5,144	)	(5,248	)
Cash and cash equivalents	(801	)	(3,678	)	(620	)
Operating lease liabilities	511		457		430
Adjusted debt	54,802		56,086		54,112

Comparable EBITDA from continuing operations^iv	10,049		9,472		8,483
Comparable EBITDA from discontinued operations^iv	1,145		1,516		1,418
Operating lease costs	117		105		95
Distributions received in excess of (income) loss from equity investments	67		(123	)	(29	)
Adjusted Comparable EBITDA	11,378		10,970		9,967

Adjusted Debt/Adjusted Comparable EBITDAⁱ	4.8		5.1		5.4

i	Adjusted debt and adjusted comparable EBITDA are non-GAAP measures. The calculations are based on management methodology. Individual rating agency calculations will differ.
ii	50 per cent debt treatment on $2.5 billion of preferred shares as of December 31, 2024.
iii	50 per cent equity treatment on $11.0 billion of junior subordinated notes as of December 31, 2024. U.S. dollar-denominated notes translated at December 31, 2024, USD/CAD foreign exchange rate of 1.44.
iv	Comparable EBITDA from continuing operations and Comparable EBITDA from discontinued operations are non-GAAP financial measures. See the Forward-looking information and Non-GAAP measures sections in our 2024 Annual Report for more information. Comparable EBITDA from discontinued operations represents nine months of Liquids Pipelines earnings in 2024 compared to a full year of Liquids Pipelines earnings in 2023. Refer to the Discontinued operations section in our 2024 Annual Report for additional information.

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

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

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

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

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

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

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

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

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

The MIL Network –

August 5, 2025

MIL-OSI: Real Matters Reports Third Quarter Financial Results

Source: GlobeNewswire (MIL-OSI)

(all amounts are expressed in millions of U.S. dollars, excluding per share amounts and unless otherwise stated)

TORONTO, July 31, 2025 (GLOBE NEWSWIRE) — Real Matters Inc. (TSX: REAL) (“Real Matters” or the “Company”), a leading network management services platform for the mortgage and insurance industries, today announced its financial results for the third quarter ended June 30, 2025.

“Consolidated revenues increased 22% sequentially in the third quarter to $45.4 million, in line with a seasonal uptick in U.S. Appraisal purchase mortgage market volumes and double-digit revenue growth in all three segments. We posted positive consolidated Adjusted EBITDA^(A) of $0.3 million, up from a loss of $1.9 million in the second quarter of 2025,” said Real Matters Chief Executive Officer Brian Lang.

“We continued to launch new clients in the third quarter across all three of our segments and performed at the top of lender scorecards. Subsequent to quarter end, we also went live with our second Tier 1 lender in U.S. Title and added a new top-15 lender in U.S. Appraisal,” added Lang. “Overall, we remain on track with the execution of our strategy which is focused on growing market share and readying the business to scale up when mortgage market volumes normalize.”

“The number of mortgages being originated at higher interest rates continues to rise, steadily expanding the pool of potential refinance candidates,” concluded Lang. “Currently, nearly 12 million mortgages have rates above 6%, and approximately 8 million of those mortgages have rates above 6.5%. This presents a significant opportunity for us once the rate environment begins to shift – and we are strategically positioned to capitalize on it.”

Q3 2025 Summary

Consolidated revenue of $45.4 million, down 8% year-over-year as increased revenue in our U.S. Title segment was offset by lower year-over-year U.S. Appraisal revenue
Consolidated Adjusted EBITDA^(A) of $0.3 million compared with $1.7 million in Q3’24
Net loss of $4.9 million, down from net income of $1.7 million in Q3’24 primarily due to an increase of $5.6 in net foreign exchange loss
Launched four new clients
Real Matters’ U.S. Appraisal mortgage origination volumes were down 16% year-over-year mainly due to lower purchase origination volumes
Real Matters’ U.S. Title mortgage origination volumes up 52% year-over-year due to net market share gains with clients and higher refinance origination market volumes
Cash and cash equivalents of $43.8 million and no outstanding debt as at June 30, 2025

Financial and Operational Summary

		Quarter ended																Nine months ended							%
	2025				2025			2025			2024			2024		% Change¹			2025				2024		Change¹
		Q3			Q2			Q1			Q4			Q3		Quarter over Quarter	Year over Year		June 30			June 30			Year over Year
Consolidated
Revenue	$	45.4		$	37.3		$	41.0		$	45.6		$	49.5		22%	-8%		$	123.7		$	127.1		-3%
Net Revenue^(A)	$	11.9		$	10.1		$	10.9		$	12.0		$	13.1		18%	-10%		$	32.8		$	34.3		-5%
Adjusted EBITDA^(A)	$	0.3		$	(1.9	)	$	(1.7	)	$	0.6		$	1.7		116%	-82%		$	(3.2	)	$	1.3		-351%
Net (loss) income	$	(4.9	)	$	(2.2	)	$	2.3		$	(0.2	)	$	1.7		-119%	-386%		$	(4.8	)	$	0.2		-2855%
Net (loss) income per diluted share	$	(0.07	)	$	(0.03	)	$	0.03		$	0.00		$	0.02		-133%	-450%		$	(0.06	)	$	0.00		0%
Adjusted Net (loss) income^(A)	$	(0.5	)	$	(1.2	)	$	(0.3	)	$	0.9		$	1.7		58%	-129%		$	(2.0	)	$	1.8		-211%
Adjusted Net (loss) income^(A) per diluted share	$	(0.01	)	$	(0.02	)	$	0.00		$	0.01		$	0.02		50%	-150%		$	(0.03	)	$	0.02		-250%

U.S. Appraisal segment
Revenue	$	32.6		$	26.7		$	29.4		$	33.8		$	37.5		22%	-13%		$	88.6		$	96.9		-8%
Net Revenue^(A)	$	8.5		$	7.3		$	7.8		$	9.0		$	10.3		17%	-17%		$	23.6		$	27.0		-13%
Net Revenue^(A) margin		26.2%			27.3%			26.5%			26.7%			27.6%						26.6%			27.9%
Adjusted EBITDA^(A)	$	4.0		$	2.6		$	2.4		$	4.1		$	5.5		58%	-26%		$	9.1		$	12.6		-28%
Adjusted EBITDA^(A) margin		47.7%			35.4%			30.9%			45.2%			53.2%						38.4%			46.6%

U.S. Title segment
Revenue	$	2.8		$	2.3		$	2.5		$	2.4		$	2.1		23%	30%		$	7.6		$	6.2		22%
Net Revenue^(A)	$	1.5		$	1.2		$	1.4		$	1.2		$	0.9		24%	57%		$	4.0		$	2.8		43%
Net Revenue^(A) margin		52.6%			52.1%			53.4%			49.8%			43.6%						52.7%			45.0%
Adjusted EBITDA^(A)	$	(1.7	)	$	(2.1	)	$	(1.8	)	$	(1.6	)	$	(1.9	)	19%	12%		$	(5.6	)	$	(5.2	)	-8%
Adjusted EBITDA^(A) margin		-117.7%			-179.6%			-132.3%			-131.4%			-209.8%						-140.9%			-187.3%


Canadian segment
Revenue	$	10.0		$	8.3		$	9.1		$	9.4		$	9.9		19%	1%		$	27.5		$	24.0		14%
Net Revenue^(A)	$	1.9		$	1.6		$	1.7		$	1.8		$	1.9		18%	0%		$	5.2		$	4.5		14%
Net Revenue^(A) margin		18.7%			19.0%			18.9%			18.9%			19.0%						18.9%			18.9%
Adjusted EBITDA^(A)	$	1.3		$	1.0		$	1.1		$	1.2		$	1.3		21%	-3%		$	3.4		$	2.9		19%
Adjusted EBITDA^(A) margin		67.6%			65.7%			66.1%			67.7%			69.3%						66.5%			63.7%

Corporate segment
Adjusted EBITDA^(A)	$	(3.3	)	$	(3.4	)	$	(3.4	)	$	(3.1	)	$	(3.2	)	2%	-4%		$	(10.1	)	$	(9.0	)	-13%

Note 1 – Percentage change is calculated based on figures disclosed in our MD&A which are rounded to the nearest thousands of dollars.

Conference Call and Webcast
A conference call to review the results will take place at 10:00 a.m. (ET) on Thursday, July 31, 2025, hosted by Chief Executive Officer Brian Lang and Chief Financial Officer Rodrigo Pinto. An accompanying slide presentation will be posted to the Investor section of our website shortly before the call.

To access the call:

Participants can dial-in to the conference call; however, pre-registration is required. To register, visit: https://register-conf.media-server.com/register/BI798e8af4ea274111bfa0efe3766760a2.
Once registered, you will receive an email including dial-in details and a unique access code required to join the live call.
Please ensure you have registered at least 10 minutes prior to the conference call start time.

To listen to the live webcast of the call:

The webcast will be archived and a transcript of the call will be available in the Investor section of our website following the call.

(A) Non-GAAP Measures
The non-GAAP measures used in this news release, including Net Revenue, Adjusted EBITDA and Adjusted Net Income do not have a standardized meaning prescribed by IFRS® Accounting Standards and are therefore unlikely to be comparable to similar measures presented by other issuers. These non-GAAP measures are more fully defined and discussed in the Company’s MD&A for the three and nine months ended June 30, 2025 under the heading “Non-GAAP measures”, which is incorporated by reference in this Press Release and available on SEDAR+ at www.sedarplus.ca.

Real Matters financial results for the three and nine months ended June 30, 2025 are included in the unaudited interim condensed consolidated financial statements and the accompanying MD&A, each of which are available on SEDAR+ at www.sedarplus.ca. In addition, supplemental information is available on our website at www.realmatters.com.

Net Revenue represents the difference between revenues and transaction costs. Net Revenue margin is calculated as Net Revenue divided by Revenues. The reconciling items between net income or loss and Net Revenue were as follows:

								Quarter ended								Nine months ended
		Q3 2025			Q2 2025			Q1 2025			Q4 2024			Q3 2024		June 30, 2025			June 30, 2024

Net (loss) income	$	(4.9	)	$	(2.2	)	$	2.3		$	(0.2	)	$	1.7		$	(4.8	)	$	0.2
Operating expenses		11.9			12.1			12.7			12.6			11.8			36.5			34.6
Amortization		0.7			0.7			0.7			0.8			0.8			2.1			2.4
Restructuring expenses		0.1			–			0.4			–			–			0.5			–
Interest expense		0.1			0.1			0.1			0.1			0.1			0.3			0.3
Interest income		(0.4	)		(0.5	)		(0.5	)		(0.5	)		(0.5	)		(1.3	)		(1.3	)
Net foreign exchange loss (gain)		4.7			0.2			(6.1	)		1.3			(0.9	)		(1.2	)		(1.1	)
Loss (gain) on fair value of derivatives		0.3			0.6			1.7			(1.9	)		(0.1	)		2.6			(0.2	)
Income tax (recovery) expense		(0.6	)		(0.9	)		(0.4	)		(0.2	)		0.2			(1.9	)		(0.6	)
Net Revenue	$	11.9		$	10.1		$	10.9		$	12.0		$	13.1		$	32.8		$	34.3

Adjusted EBITDA represents net income or loss before stock-based compensation expense, amortization, restructuring expenses, interest expense, interest income, net foreign exchange gain or loss, gain or loss on fair value of derivatives and income tax expense or recovery. Adjusted EBITDA margin is calculated as Adjusted EBITDA divided by Net Revenue. The reconciling items between net income or loss and Adjusted EBITDA were as follows:

								Quarter ended								Nine months ended
		Q3 2025			Q2 2025			Q1 2025			Q4 2024			Q3 2024		June 30, 2025			June 30, 2024

Net (loss) income	$	(4.9	)	$	(2.2	)	$	2.3		$	(0.2	)	$	1.7		$	(4.8	)	$	0.2
Stock-based compensation expense		0.3			0.1			0.1			1.2			0.4			0.5			1.6
Amortization		0.7			0.7			0.7			0.8			0.8			2.1			2.4
Restructuring expenses		0.1			–			0.4			–			–			0.5			–
Interest expense		0.1			0.1			0.1			0.1			0.1			0.3			0.3
Interest income		(0.4	)		(0.5	)		(0.5	)		(0.5	)		(0.5	)		(1.3	)		(1.3	)
Net foreign exchange loss (gain)		4.7			0.2			(6.1	)		1.3			(0.9	)		(1.2	)		(1.1	)
Loss (gain) on fair value of derivatives		0.3			0.6			1.7			(1.9	)		(0.1	)		2.6			(0.2	)
Income tax (recovery) expense		(0.6	)		(0.9	)		(0.4	)		(0.2	)		0.2			(1.9	)		(0.6	)
Adjusted EBITDA	$	0.3		$	(1.9	)	$	(1.7	)	$	0.6		$	1.7		$	(3.2	)	$	1.3

The reconciling items between net income or loss and Adjusted Net Income or Loss were as follows:

								Quarter ended								Nine months ended
		Q3 2025			Q2 2025			Q1 2025			Q4 2024			Q3 2024		June 30, 2025			June 30, 2024

Net (loss) income	$	(4.9	)	$	(2.2	)	$	2.3		$	(0.2	)	$	1.7		$	(4.8	)	$	0.2
Stock-based compensation expense		0.3			0.1			0.1			1.2			0.4			0.5			1.6
Amortization of intangibles		0.4			0.4			0.4			0.5			0.4			1.2			1.2
Restructuring expenses		0.1			–			0.4			–			–			0.5			–
Net foreign exchange loss (gain)		4.7			0.2			(6.1	)		1.3			(0.9	)		(1.2	)		(1.1	)
Loss (gain) on fair value of derivatives		0.3			0.6			1.7			(1.9	)		(0.1	)		2.6			(0.2	)
Related tax effects		(1.4	)		(0.3	)		0.9			–			0.2			(0.8	)		0.1
Adjusted Net (Loss) Income	$	(0.5	)	$	(1.2	)	$	(0.3	)	$	0.9		$	1.7		$	(2.0	)	$	1.8

Forward-Looking Information
This Press Release contains “forward-looking information” within the meaning of applicable Canadian securities laws. Words such as “could”, “forecast”, “target”, “may”, “will”, “would”, “expect”, “anticipate”, “estimate”, “intend”, “plan”, “seek”, “believe”, “likely” and “predict” and variations of such words and similar expressions are intended to identify such forward-looking information, although not all forward-looking information contains these identifying words.

The forward-looking information in this Press Release includes statements which reflect the current expectations of management with respect to our business and the industry in which we operate and is based on management’s experience and perception of historical trends, current conditions and expected future developments, as well as other factors that management believes appropriate and reasonable in the circumstances. The forward-looking information reflects management’s beliefs based on information currently available to management, including information obtained from third party sources, and should not be read as a guarantee of the occurrence or timing of any future events, performance or results.

The forward-looking information in this Press Release is subject to risks, uncertainties and other factors that are difficult to predict and that could cause actual results to differ materially from historical results or results anticipated by the forward-looking information. A comprehensive discussion of the factors which could cause results or events to differ from current expectations can be found in the “Risk Factors” section of our Annual Information Form for the year ended September 30, 2024, which is available on SEDAR+ at www.sedarplus.ca.

Readers are cautioned not to place undue reliance on the forward-looking information, which reflect our expectations only as of the date of this Press Release. Except as required by law, we do not undertake to update or revise any forward-looking information, whether as a result of new information, future events or otherwise.

About Real Matters
Real Matters is a leading network management services provider for the mortgage lending and insurance industries. Real Matters’ platform combines its proprietary technology and network management capabilities with tens of thousands of independent qualified field professionals to create an efficient marketplace for the provision of mortgage lending and insurance industry services. Our clients include top 100 mortgage lenders in the U.S. and some of the largest banks and insurance companies in Canada. We are a leading independent provider of residential real estate appraisals to the mortgage market and a leading independent provider of title services in the U.S. Headquartered in Markham (ON), Real Matters has principal offices in Buffalo (NY) and Middletown (RI). Real Matters is listed on the Toronto Stock Exchange under the symbol REAL. For more information, visit www.realmatters.com.

For more information:
Lyne Beauregard
Vice President, Investor Relations and Corporate Communications
Real Matters
lbeauregard@realmatters.com
416.994.5930

The MIL Network –

August 5, 2025

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

Source: GlobeNewswire (MIL-OSI)

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

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

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

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

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

About Grupo Petrópolis

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

About Descartes

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

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

Cautionary Statement Regarding Forward-Looking Statements

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

The MIL Network –

August 5, 2025
MIL-OSI: CMG Announces the Acquisition of SeisWare International Inc.

Source: GlobeNewswire (MIL-OSI)

CALGARY, Alberta, July 31, 2025 (GLOBE NEWSWIRE) — Computer Modelling Group Ltd. (“CMG” or the “Company”) (TSX: CMG) today announced the acquisition of SeisWare International Inc. (“SeisWare”), a software company specializing in geoscience solutions.

Based in Calgary, Alberta, SeisWare develops geoscience interpretation and field development software to support subsurface exploration and development projects. SeisWare’s intuitive platform offers powerful tools for seismic interpretation, attribute analysis, geological mapping and 3D well design.

“SeisWare reflects our disciplined approach in expanding our capabilities by acquiring high-quality software solutions,” stated Pramod Jain, CEO of CMG. “The company has earned a strong reputation and loyal customer base in Canada by delivering powerful, integrated geoscience tools alongside responsive and highly technical customer support. SeisWare is a platform acquisition for CMG which further builds out our seismic interpretation solutions and underscores our commitment to investing in businesses with the potential to deliver strong returns and long-term value.”

In the twelve months ended March 31, 2025, SeisWare had unaudited revenue of approximately US$3.4 million consisting of all recurring software revenue.

Total purchase price is estimated to be US$6.6 million and is subject to customary closing adjustments.

The company is also pleased to announce that Herman Nieuwoudt, who joined the company as President of Bluware in November 2024, has been promoted to Executive Vice President and President, Seismic Solutions. In his new role, he will oversee all of the company’s seismic technologies and he will formally join the executive leadership team. SeisWare’s team of over 40 employees, located in Calgary and Houston, will join this seismic solutions group. Murray Brack, CEO of SeisWare, will join CMG as General Manager, SeisWare, reporting to Mr. Nieuwoudt.

Commenting on the transaction, Murray Brack, CEO of SeisWare stated “Joining CMG is a natural next step for us, grounded in our shared Canadian roots and a mutual dedication to exceptional customer support. What makes it truly exciting is how well our values and vision align around our commitment to developing specialized, technical software that meets the evolving needs of the energy industry.”

For more information on SeisWare, visit the website.

About CMG

CMG (TSX:CMG) is a global software and consulting company that combines science and technology with deep industry expertise to solve complex subsurface and surface challenges for the new energy industry around the world. CMG is headquartered in Calgary, AB, with offices in Houston, Oxford, Dubai, Bogota, Rio de Janeiro, Bengaluru, Kuala Lumpur, Oslo, Stavanger, and Kaiserslautern. For more information, please visit www.cmgl.ca.

This press release contains “forward-looking statements”. Forward-looking statements can be identified by words such as: “aims”, “intend”, “can”, “goal”, “seek”, “believe”, “estimate”, “expect”, “strategy”, “future”, “likely”, “may”, “should”, “will”, and similar references to future periods.

Forward-looking statements are neither historical facts nor assurances of future performance. They are based only on our current beliefs, expectations, and assumptions regarding the future of our business, future plans and strategies, projections, anticipated events and trends, the economy and other future conditions. Because forward-looking statements relate to the future, they are subject to inherent uncertainties, risks and changes in circumstances that are difficult to predict and many of which are outside of our control. Our actual results and financial condition may differ materially from those indicated in the forward-looking statements. Therefore, you should not rely on any of these forward-looking statements. Important factors that could cause our actual results and financial condition to differ materially from those indicated in the forward-looking statements are detailed in the companies’ public filings.

Any forward-looking statement made by us in this press release is based only on information currently available to us and speaks only as of the date on which it is made. Except as required by applicable securities laws, we undertake no obligation to publicly update any forward-looking statement, whether written or oral, that may be made from time to time, whether as a result of new information, future developments or otherwise.

The MIL Network –

August 5, 2025

MIL-OSI: Commerce Announces Second Quarter 2025 Financial Results

Source: GlobeNewswire (MIL-OSI)

AUSTIN, Texas, July 31, 2025 (GLOBE NEWSWIRE) — Commerce.com, Inc. (Nasdaq: BIGC) (formerly BigCommerce Holdings, Inc.), a provider of an open, intelligent ecosystem of technology solutions that empower businesses to unlock data potential and deliver seamless, personalized experiences at scale, today announced financial results for its second quarter ended June 30, 2025. Earlier this morning, BigCommerce announced the launch of its new parent brand, Commerce, and that it has officially changed its corporate name to Commerce.com, Inc. (“Commerce” or the “Company”), unifying BigCommerce, Feedonomics and Makeswift to power the next era of agentic commerce. In connection with the name change and rebranding, the Company will change its ticker to the symbol “CMRC” on the Nasdaq Global Market effective on or about August 1, 2025.

“The second quarter was a defining period for our company, and today we mark an important milestone as we reintroduce ourselves as Commerce,” said Travis Hess, CEO of Commerce. “The strategy, product and go-to-market engine we have built over the past year came together behind a singular focus: powering an AI-driven commerce ecosystem at scale. Our transformation phase is over. We have moved fully into execution and growth.”

Second Quarter Financial Highlights:

Total revenue was $84.4 million, up 3% compared to the second quarter of 2024.

Total annual revenue run-rate (“ARR”) as of June 30, 2025 was $354.6 million, up 3% compared to June 30, 2024.

Subscription solutions revenue was $63.7 million, up 3% compared to the second quarter of 2024.

ARR from accounts with at least one enterprise plan (“Enterprise Accounts”) was $269.3 million as of June 30, 2025, up 6% from June 30, 2024.

ARR from Enterprise Accounts as a percent of total ARR was 76% as of June 30, 2025, compared to 73% as of June 30, 2024.

GAAP gross margin was 79%, compared to 76% in the second quarter of 2024. Non-GAAP gross margin was 80%, compared to 77% in the second quarter of 2024.

Other Key Business Metrics

Number of enterprise accounts was 5,803, down 3% compared to the second quarter of 2024.

Average revenue per account (“ARPA”) of enterprise accounts was $46,403, up 9% compared to the second quarter of 2024.

Revenue in the United States grew by 3% compared to the second quarter of 2024.

Revenue in EMEA grew by 7% and revenue in APAC declined by 4% compared to the second quarter of 2024.

Loss from Operations and Non-GAAP Operating Income (Loss)

GAAP loss from operations was ($6.8) million, compared to ($13.5) million in the second quarter of 2024.

Included in GAAP loss from operations was a restructuring charge of $1.6 million.

Non-GAAP operating income was $4.8 million, compared to $1.9 million in the second quarter of 2024.

Net Income (Loss) and Earnings Per Share

GAAP net loss was ($8.4) million, compared to ($11.3) million in the second quarter of 2024.

Non-GAAP net income was $3.2 million or 4% of revenue, compared to $4.1 million or 5% of revenue in the second quarter of 2024.

GAAP basic net loss per share was ($0.10) based on 80.1 million shares of common stock, compared to ($0.15) based on 77.5 million shares of common stock in the second quarter of 2024.

Non-GAAP basic net income per share was $0.04 based on 80.1 million shares of common stock, compared to $0.05 based on 77.5 million shares of common stock in the second quarter of 2024.

Adjusted EBITDA

Adjusted EBITDA was $5.7 million, compared to $3.0 million in the second quarter of 2024.

Cash

Cash, cash equivalents, restricted cash, and marketable securities totaled $135.6 million as of June 30, 2025.

For the three months ended June 30, 2025, net cash provided by operating activities was $13.6 million, compared to $11.7 million provided by operating activities for the same period in 2024. We reported free cash flow of $11.9 million in the three months ended June 30, 2025.

Business Highlights:

Corporate Highlights

Former Adobe Fellow and Vice President of Technology Anil Kamath joined the Company’s Board of Directors.
In July, BigCommerce scored 24 out of 24 total medals in the 2025 Paradigm B2B Combines for Digital Commerce Solutions (Enterprise and Midmarket Editions) for the third consecutive year. The Company advanced its rankings in five categories in both Editions and achieved more Gold medals in Midmarket than other platforms.
In July, BigCommerce also announced the launch of the B2B Quick Start Accelerator, a partner-led implementation program built to help mid-market B2B sellers launch faster, reduce risk and realize ROI sooner.
TrustRadius recognized Commerce with a 2025 Top Rated Award for ecommerce, based on the Company’s strong customer reviews.

Customer Highlights

Minerva Beauty, a large salon and spa equipment showroom in the United States, launched a new storefront in partnership with Commerce agency partner Forix, featuring a custom shipping app that improves service and transparency for clients.
Great Star Tools, a leading manufacturer of innovative hand and power tools, used Commerce’s Multi-Storefront functionality to build B2B and B2C sites for its companies Primeline Parts and Arrow Tool Group.
Belami e-Commerce, a fast-growing online retailer and ecommerce services provider launched three storefronts on Catalyst and Makeswift using Commerce’s Multi-Storefront functionality and leveraging Commerce’s integration with PayPal Fastlane.
NanoTemper Technologies, a manufacturer of high-quality biophysical instruments and solutions that deliver reliable, precise results to customers, primarily laboratories, across Europe and the United States, launched a new storefront using Commerce’s B2B Edition.
Bright SG, a software company that provides cloud-based solutions for accounting, payroll, and HR to businesses across the UK and Ireland, worked with Commerce partner Brave Bison to implement a custom recurring payment solution using Stripe and Bright’s ERP system, Maxio, along with a custom WordPress integration.

Partner Highlights

In June, Commerce announced their customers now have access to cutting-edge AI-powered search engine Perplexity to optimize visibility and relevance for brands in AI search results. Commerce now provides Perplexity with pre-optimized, structured product data, ensuring that the LLM understands and recognizes merchants’ products, leading to superior search results that favor the brand.
In July, Commerce announced a deepened partnership with Google Cloud to accelerate merchant performance using Google Cloud’s next-generation AI tools.
In July, Commerce announced the launch of a powerful ecommerce accelerator purpose-built for the UK building materials industry. Developed in collaboration with leading digital agency Brave Bison, Product Information Management technology provider Pimberly, and construction industry consultant The Journey, the “Branch of the Future” accelerator provides building merchants with a comprehensive toolkit to digitize operations, meet the expectations of next-generation buyers and future-proof their businesses.

Q3 and 2025 Financial Outlook:

For the third quarter of 2025, we currently expect:

Total revenue between $85 million to $87 million.

Non-GAAP operating income is expected to be between $2.3 million to $3.3 million.

For the full year 2025, we currently expect:

Total revenue between $339.6 million and $346.6 million.

Non-GAAP operating income between $19 million and $25 million.

Our third quarter and 2025 financial outlook is based on a number of assumptions that are subject to change and many of which are outside our control. If actual results vary from these assumptions, our expectations may change. There can be no assurance that we will achieve these results.

We do not provide guidance for loss from operations , the most directly comparable GAAP measure to Non-GAAP operating income, and similarly cannot provide a reconciliation between its forecasted Non-GAAP operating income and Non-GAAP income per share and these comparable GAAP measures without unreasonable effort due to the unavailability of reliable estimates for certain items. These items are not within our control and may vary greatly between periods and could significantly impact future financial results.

Conference Call Information

The financial results and business highlights will be discussed on a conference call and webcast scheduled at 7:00 a.m. CT (8:00 a.m. ET) on Thursday, July 31, 2025. The conference call can be accessed by dialing (833) 634-1254 from the United States and Canada or (412) 317-6012 internationally and requesting to join the “Commerce conference call.” The live webcast of the conference call can be accessed from Commerce’s investor relations website at http://investors.bigcommerce.com.

Following the completion of the call through 11:59 p.m. ET on Thursday, August 7, 2025, a telephone replay will be available by dialing (877) 344-7529 from the United States, (855) 669-9658 from Canada or (412) 317-0088 internationally with conference ID 7863771. A webcast replay will also be available at http://investors.bigcommerce.com for 12 months.

About Commerce

Commerce empowers businesses to innovate, grow, and thrive by providing an open, AI-driven commerce ecosystem. As the parent company of BigCommerce, Feedonomics, and Makeswift, Commerce connects the tools and systems that power growth, enabling businesses to unlock the full potential of their data, deliver seamless and personalized experiences across every channel, and adapt swiftly to an ever-changing market. Trusted by leading businesses like Coldwater Creek, Cole Haan, Harvey Nichols, King Arthur Baking Co., Melissa & Doug, Mizuno, Patagonia, Perry Ellis, Puma, SportsShoes, and Uplift Desk, Commerce delivers the storefront control, optimized data, and AI-ready tools businesses need to grow, serve diverse buyers, and operate with confidence in an increasingly intelligent, multi-surface world. For more information, visit commerce.com or follow us on X and LinkedIn.

Forward-Looking Statements

This press release contains “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. In some cases, you can identify forward-looking statements by terms such as “anticipate,” “believe,” “estimate,” “expect,” “intend,” “outlook,” “may,” “might,” “plan,” “project,” “will,” “would,” “should,” “could,” “can,” “predict,” “potential,” “strategy,” “target,” “explore,” “continue,” or the negative of these terms, and similar expressions intended to identify forward-looking statements. However, not all forward-looking statements contain these identifying words. These statements may relate to our ability to successfully execute our rebranding initiative, our increased focus on AI enablement, market size and growth strategy, our estimated and projected costs, margins, revenue, expenditures and customer and financial growth rates, our Q3 and fiscal 2025 financial outlook, our plans and objectives for future operations, growth, initiatives or strategies. By their nature, these statements are subject to numerous uncertainties and risks, including factors beyond our control, that could cause actual results, performance or achievement to differ materially and adversely from those anticipated or implied in the forward-looking statements. These assumptions, uncertainties and risks include that, among others, our business would be harmed by any decline in new customers, renewals or upgrades, our limited operating history makes it difficult to evaluate our prospects and future results of operations, we operate in competitive markets, we may not be able to sustain our revenue growth rate in the future, our business would be harmed by any significant interruptions, delays or outages in services from our platform or certain social media platforms, and a cybersecurity-related attack, significant data breach or disruption of the information technology systems or networks could negatively affect our business. Additional risks and uncertainties that could cause actual outcomes and results to differ materially from those contemplated by the forward-looking statements are included under the caption “Risk Factors” and elsewhere in our filings with the Securities and Exchange Commission (the “SEC”), including our Annual Report on Form 10-K for the year ended December 31, 2024 and the future quarterly and current reports that we file with the SEC. Forward-looking statements speak only as of the date the statements are made and are based on information available to Commerce at the time those statements are made and/or management’s good faith belief as of that time with respect to future events. Commerce assumes no obligation to update forward-looking statements to reflect events or circumstances after the date they were made, except as required by law.

Use of Non-GAAP Financial Measures

We have provided in this press release certain financial information that has not been prepared in accordance with generally accepted accounting principles in the United States (“GAAP”). Our management uses these Non-GAAP financial measures internally in analyzing our financial results and believes that use of these Non-GAAP financial measures is useful to investors as an additional tool to evaluate ongoing operating results and trends and in comparing our financial results with other companies in our industry, many of which present similar Non-GAAP financial measures. Non-GAAP financial measures are not meant to be considered in isolation or as a substitute for comparable financial measures prepared in accordance with GAAP and should be read only in conjunction with our consolidated financial statements prepared in accordance with GAAP. A reconciliation of our historical Non-GAAP financial measures to the most directly comparable GAAP measures has been provided in the financial statement tables included in this press release, and investors are encouraged to review these reconciliations.

Annual Revenue Run-Rate

We calculate annual revenue run-rate at the end of each month as the sum of: (1) contractual monthly recurring revenue at the end of the period, which includes platform subscription fees, invoiced growth adjustments, feed management subscription fees, recurring professional services revenue, and other recurring revenue, multiplied by twelve to prospectively annualize recurring revenue, and (2) the sum of the trailing twelve-month non-recurring and variable revenue, which includes one-time partner integrations, one-time fees, payments revenue share, and any other revenue that is non-recurring and variable.

Enterprise Account Metrics

To measure the effectiveness of our ability to execute against our growth strategy, we calculate ARR attributable to Enterprise Accounts. We define Enterprise Accounts as accounts with at least one unique Enterprise plan subscription or an enterprise level feed management subscription (collectively “Enterprise Accounts”). These accounts may have more than one Enterprise plan or a combination of Enterprise plans and non-enterprise plans.

Average Revenue Per Account

We calculate average revenue per account (“ARPA”) for accounts in the Enterprise cohort at the end of a period by including customer-billed revenue and an allocation of partner and services revenue, where applicable. We allocate partner revenue, where applicable, primarily based on each customer’s share of gross merchandise volume (“GMV”) processed through that partner’s solution. For partner revenue that is not directly linked to customer usage of a partner’s solution, we allocate such revenue based on each customer’s share of total platform GMV. Each account’s partner revenue allocation is calculated by taking the account’s trailing twelve-month partner revenue, then dividing by twelve to create a monthly average to apply to the applicable period in order to normalize ARPA for seasonality.

Adjusted EBITDA

We define Adjusted EBITDA as our net loss, excluding the impact of stock-based compensation expense and related payroll tax costs, amortization of intangible assets, acquisition related costs, restructuring charges, depreciation, gain on convertible notes extinguishment, interest income, interest expense, other expense, and our provision or benefit for income taxes.

Acquisition related costs include contingent compensation arrangements entered into in connection with acquisitions and achieved earnout related to an acquisition.

Restructuring charges include severance benefits, right-of-use asset impairments, lease termination gain, software impairments, accelerated depreciation and amortization, and professional services costs.

Depreciation includes depreciation expenses related to the Company’s fixed assets.

The most directly comparable GAAP measure is net loss.

Non-GAAP Operating Income (Loss)

We define Non-GAAP Operating Income (Loss) as our GAAP Loss from operations, excluding the impact of stock-based compensation expense and related payroll tax costs, amortization of intangible assets, acquisition related costs, and restructuring charges. The most directly comparable GAAP measure is our loss from operations.

Non-GAAP Net Income (Loss)

We define Non-GAAP Net Income (Loss) as our GAAP net loss, excluding the impact of stock-based compensation expense and related payroll tax costs, amortization of intangible assets, acquisition related costs, restructuring charges, and gain on convertible notes extinguishment. The most directly comparable GAAP measure is our net loss.

Non-GAAP Basic and Dilutive Net Income (Loss) per Share

We define Non-GAAP Basic and Dilutive Net Income (Loss) per Share as our Non-GAAP net income (loss), defined above, divided by our basic and diluted GAAP weighted average shares outstanding. The most directly comparable GAAP measure is our basic net loss per share.

Free Cash Flow

We define Free Cash flow as our GAAP cash flow provided by (used in) operating activities less our cash paid for website domain name and GAAP purchases of property, equipment, leasehold improvements and capitalized internal-use software (Capital Expenditures). The most directly comparable GAAP measure is our cash flow provided by (used in) operating activities.

BigCommerce,® the Commerce logo, and other brands are the trademarks or registered trademarks of BigCommerce Pty. Ltd. Third-party trademarks and service marks are the property of their respective owner.

Media Relations Contact	Investor Relations Contact
Brad Hem	Tyler Duncan
PR@Commerce.com	InvestorRelations@Commerce.com


Commerce.com, Inc. Condensed Consolidated Balance Sheets (in thousands)

	June 30,			December 31,
	2025			2024
	(unaudited)
Assets
Current assets
Cash and cash equivalents	$	46,265		$	88,877
Restricted cash		1,164			1,479
Marketable securities		88,190			89,283
Accounts receivable, net		51,767			48,117
Prepaid expenses and other assets, net		14,722			14,641
Deferred commissions		7,556			8,822
Total current assets		209,664			251,219
Property and equipment, net		8,983			9,128
Operating lease, right-of-use-assets		7,114			1,993
Prepaid expenses and other assets, net of current portion		5,797			3,146
Deferred commissions, net of current portion		4,143			5,559
Intangible assets, net		14,906			17,317
Goodwill		51,927			51,927
Total assets	$	302,534		$	340,289
Liabilities and stockholders’ equity
Current liabilities
Accounts payable	$	8,775		$	7,018
Accrued liabilities		3,464			3,194
Deferred revenue		55,738			46,590
Operating lease liabilities		1,766			2,438
Other liabilities		28,538			28,766
Total current liabilities		98,281			88,006
Convertible notes		157,545			216,466
Operating lease liabilities, net of current portion		6,709			1,680
Other liabilities, net of current portion		1,233			768
Total liabilities		263,768			306,920
Stockholders’ equity
Common stock		7			7
Additional paid-in capital		669,068			654,905
Accumulated other comprehensive income		114			145
Accumulated deficit		(630,423	)		(621,688	)
Total stockholders’ equity		38,766			33,369
Total liabilities and stockholders’ equity	$	302,534		$	340,289


Commerce.com, Inc. Condensed Consolidated Statements of Operations (in thousands, except per share amounts) (unaudited)

	For the three months ended June 30,						For the six months ended June 30,
	2025			2024			2025			2024
Revenue	$	84,433		$	81,829		$	166,803		$	162,189
Cost of revenue ⁽¹⁾		17,739			19,811			34,723			38,250
Gross profit		66,694			62,018			132,080			123,939
Operating expenses:
Sales and marketing⁽¹⁾		35,071			34,425			65,437			66,857
Research and development⁽¹⁾		18,310			20,287			37,516			40,275
General and administrative⁽¹⁾		15,855			15,436			29,499			30,365
Amortization of intangible assets		2,520			2,452			4,855			4,919
Acquisition related costs		111			334			444			667
Restructuring charges		1,614			2,572			3,526			2,572
Total operating expenses		73,481			75,506			141,277			145,655
Loss from operations		(6,787	)		(13,488	)		(9,197	)		(21,716	)
Gain on convertible note extinguishment		0			0			3,931			0
Interest income		1,171			3,196			2,471			6,374
Interest expense		(2,522	)		(720	)		(5,065	)		(1,440	)
Other expense		(23	)		(111	)		(130	)		(443	)
Loss before provision for income taxes		(8,161	)		(11,123	)		(7,990	)		(17,225	)
Provision for income taxes		(221	)		(132	)		(745	)		(422	)
Net loss	$	(8,382	)	$	(11,255	)	$	(8,735	)	$	(17,647	)
Basic net loss per share	$	(0.10	)	$	(0.15	)	$	(0.11	)	$	(0.23	)
Shares used to compute basic net loss per share		80,122			77,456			79,482			77,041

⁽¹⁾ Amounts include stock-based compensation expense and associated payroll tax costs, as follows:

	For the three months ended June 30,				For the six months ended June 30,
	2025		2024		2025		2024
Cost of revenue	$	720	$	1,028	$	1,466	$	1,684
Sales and marketing		1,820		3,138		3,595		5,005
Research and development		2,740		3,273		5,782		6,749
General and administrative		2,045		2,582		1,901		5,174


Commerce.com, Inc. Condensed Consolidated Statements of Cash Flows (in thousands) (unaudited)

	Three months ended June 30,						Six months ended June 30,
	2025			2024			2025			2024

Cash flows from operating activities
Net loss	$	(8,382	)	$	(11,255	)	$	(8,735	)	$	(17,647	)
Adjustments to reconcile net loss to net cash provided by (used in) operating activities:
Depreciation and amortization expense		3,845			3,512			8,126			6,998
Amortization of discount on convertible notes		165			497			352			994
Amortization of premium on convertible notes		(408	)		0			(810	)		0
Stock-based compensation expense		7,236			10,009			12,445			18,397
Provision for expected credit losses		1,598			850			2,528			1,713
Gain on convertible notes extinguishment		0			0			(3,931	)		0
Other		0			(37	)		0			(37	)
Changes in operating assets and liabilities:
Accounts receivable		(9,005	)		(6,790	)		(5,985	)		(9,378	)
Prepaid expenses and other assets		2,159			3,935			(2,925	)		(1,025	)
Deferred commissions		747			(402	)		2,682			(191	)
Accounts payable		444			(356	)		1,122			(1,245	)
Accrued and other liabilities		8,078			4,168			(59	)		(433	)
Deferred revenue		7,080			7,607			9,148			10,175
Net cash provided by operating activities		13,557			11,738			13,958			8,321
Cash flows from investing activities:
Cash paid for website domain name		0			0			(2,444	)		0
Cash paid for acquisition		0			(100	)		0			(100	)
Purchase of property, equipment, leasehold improvements and capitalized internal-use software		(1,651	)		(1,064	)		(2,476	)		(1,870	)
Maturity of marketable securities		13,000			62,525			41,579			91,965
Purchase of marketable securities		(32,572	)		(1,037	)		(40,517	)		(36,602	)
Net cash provided by (used in) investing activities		(21,223	)		60,324			(3,858	)		53,393
Cash flows from financing activities:
Proceeds from exercise of stock options		1,973			271			3,069			1,245
Taxes paid related to net share settlement of stock options		(126	)		0			(1,351	)		(1,325	)
Payment of convertible note issuance costs		0		0				(217	)	0
Repayment of convertible notes and financing obligation		0			(137	)		(54,528	)		(271	)
Net cash provided by (used in) financing activities		1,847			134			(53,027	)		(351	)
Net change in cash and cash equivalents and restricted cash		(5,819	)		72,196			(42,927	)		61,363
Cash and cash equivalents and restricted cash, beginning of period		53,248			62,012			90,356			72,845
Cash and cash equivalents and restricted cash, end of period	$	47,429		$	134,208		$	47,429		$	134,208
Supplemental cash flow information:
Cash paid for interest	$	0		$	6		$	5,685		$	445
Cash paid for taxes	$	259		$	42		$	479		$	182
Right-of-use asset obtained in exchange for new operating lease liability	$	0		$	0		$	5,516		$	0
Noncash investing and financing activities:
Capital additions, accrued but not paid	$	735		$	117		$	735		$	117
Fair value of shares issued as consideration for acquisition	$	0		$	248		$	0		$	248


Commerce.com, Inc. Disaggregation of Revenue

Disaggregated Revenue:

	Three months ended June 30,				Six months ended June 30,
*(in thousands)*	2025		2024		2025		2024
Subscription solutions	$	63,656	$	61,796	$	125,769	$	122,755
Partner and services		20,777		20,033		41,034		39,434
Revenue	$	84,433	$	81,829	$	166,803	$	162,189

Revenue by Geography:

	Three months ended June 30,				Six months ended June 30,
*(in thousands)*	2025		2024		2025		2024
Revenue:
United States	$	64,405	$	62,428	$	127,026	$	123,567
EMEA		9,889		9,281		19,854		18,473
APAC		6,118		6,343		12,043		12,597
Rest of World		4,021		3,777		7,880		7,552
Revenue	$	84,433	$	81,829	$	166,803	$	162,189


Commerce.com, Inc Reconciliation of GAAP to Non-GAAP Results (in thousands, except per share amounts) (unaudited)

Reconciliation of loss from operations to Non-GAAP operating income:

	Three months ended June 30,								Six months ended June 30,
	2025				2024				2025				2024
*(in thousands)*
Revenue	$	84,433			$	81,829			$	166,803			$	162,189

Loss from operations	$	(6,787	)		$	(13,488	)		$	(9,197	)		$	(21,716	)
Plus:
Stock-based compensation expense and associated payroll tax costs		7,325				10,021				12,744				18,612
Amortization of intangible assets		2,520				2,452				4,855				4,919
Acquisition related costs		111				334				444				667
Restructuring charges		1,614				2,572				3,526				2,572
Non-GAAP operating income	$	4,783			$	1,891			$	12,372			$	5,054
Non-GAAP operating income as a percentage of revenue		5.7		%		2.3		%		7.4		%		3.1		%


Reconciliation of net loss & basic net loss per share to Non-GAAP net income & Non-GAAP basic and diluted net income per share:

	Three months ended June 30,								Six months ended June 30,
	2025				2024				2025				2024
*(in thousands)*
Revenue	$	84,433			$	81,829			$	166,803			$	162,189

Net loss	$	(8,382	)		$	(11,255	)		$	(8,735	)		$	(17,647	)
Plus:
Stock-based compensation expense and associated payroll tax costs		7,325				10,021				12,744				18,612
Amortization of intangible assets		2,520				2,452				4,855				4,919
Acquisition related costs		111				334				444				667
Restructuring charges		1,614				2,572				3,526				2,572
Gain on convertible notes extinguishment		0				0				(3,931	)			0
Non-GAAP net income	$	3,188			$	4,124			$	8,903			$	9,123
Basic net loss per share	$	(0.10	)		$	(0.15	)		$	(0.11	)		$	(0.23	)
Non-GAAP basic net income per share	$	0.04			$	0.05			$	0.11			$	0.12
Non-GAAP diluted net income per share	$	0.04			$	0.05			$	0.11			$	0.12
Shares used to compute basic net loss per share and basic Non-GAAP net income per share		80,122				77,456				79,482				77,041
Shares used to compute diluted Non-GAAP net income per share		80,988				79,291				80,660				79,085
Non-GAAP net income as a percentage of revenue		3.8		%		5.0		%		5.3		%		5.6		%


Reconciliation of net loss to adjusted EBITDA:

	Three months ended June 30,								Six months ended June 30,
	2025				2024				2025				2024
*(in thousands)*
Revenue	$	84,433			$	81,829			$	166,803			$	162,189

Net loss	$	(8,382	)		$	(11,255	)		$	(8,735	)		$	(17,647	)
Plus:
Stock-based compensation expense and associated payroll tax costs		7,325				10,021				12,744				18,612
Amortization of intangible assets		2,520				2,452				4,855				4,919
Acquisition related costs		111				334				444				667
Restructuring charges		1,614				2,572				3,526				2,572
Depreciation		946				1,060				2,190				2,079
Gain on convertible notes extinguishment		0				0				(3,931	)			0
Interest income		(1,171	)			(3,196	)			(2,471	)			(6,374	)
Interest expense		2,522				720				5,065				1,440
Other expenses		23				111				130				443
Provision for income taxes		221				132				745				422
Adjusted EBITDA	$	5,729			$	2,951			$	14,562			$	7,133
Adjusted EBITDA as a percentage of revenue		6.8		%		3.6		%		8.7		%		4.4		%


Reconciliation of Cost of revenue to Non-GAAP cost of revenue:

	Three months ended June 30,						Six months ended June 30,
	2025			2024			2025			2024
*(in thousands)*
Revenue	$	84,433		$	81,829		$	166,803		$	162,189

Cost of revenue	$	17,739		$	19,811		$	34,723		$	38,250
Less:
Stock-based compensation expense and associated payroll tax costs		720			1,028			1,466			1,684
Non-GAAP cost of revenue	$	17,019		$	18,783		$	33,257		$	36,566
As a percentage of revenue		20.2	%		23.0	%		19.9	%		22.5	%


Reconciliation of Sales and marketing expense to Non-GAAP sales and marketing expense:

	Three months ended June 30,						Six months ended June 30,
	2025			2024			2025			2024
*(in thousands)*
Revenue	$	84,433		$	81,829		$	166,803		$	162,189

Sales and marketing	$	35,071		$	34,425		$	65,437		$	66,857
Less:
Stock-based compensation expense and associated payroll tax costs		1,820			3,138			3,595			5,005
Non-GAAP sales and marketing	$	33,251		$	31,287		$	61,842		$	61,852
As a percentage of revenue		39.4	%		38.2	%		37.1	%		38.1	%


Reconciliation of Research and development expense to Non-GAAP research and development expense:

	Three months ended June 30,						Six months ended June 30,
	2025			2024			2025			2024
*(in thousands)*
Revenue	$	84,433		$	81,829		$	166,803		$	162,189

Research and development	$	18,310		$	20,287		$	37,516		$	40,275
Less:
Stock-based compensation expense and associated payroll tax costs		2,740			3,273			5,782			6,749
Non-GAAP research and development	$	15,570		$	17,014		$	31,734		$	33,526
As a percentage of revenue		18.4	%		20.8	%		19.0	%		20.7	%


Reconciliation of General and administrative expense to Non-GAAP general and administrative expense:

	Three months ended June 30,						Six months ended June 30,
	2025			2024			2025			2024
*(in thousands)*
Revenue	$	84,433		$	81,829		$	166,803		$	162,189

General & administrative	$	15,855		$	15,436		$	29,499		$	30,365
Less:
Stock-based compensation expense and associated payroll tax costs		2,045			2,582			1,901			5,174
Non-GAAP general & administrative	$	13,810		$	12,854		$	27,598		$	25,191
As a percentage of revenue		16.4	%		15.7	%		16.5	%		15.5	%


Reconciliation of net cash provided by operating activities to free cash flow:

	Three months ended June 30,						Six months ended June 30,
	2025			2024			2025			2024
*(in thousands)*
Net cash provided by operating activities	$	13,557		$	11,738		$	13,958		$	8,321
Cash paid for website domain name		0			0			(2,444	)		0
Purchase of property, equipment, leasehold improvements and capitalized internal-use software		(1,651	)		(1,064	)		(2,476	)		(1,870	)
Free cash flow	$	11,906		$	10,674		$	9,038		$	6,451

The MIL Network –

August 5, 2025

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

Source: GlobeNewswire (MIL-OSI)

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

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

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

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

Slater noted the following significant business updates:

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

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

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

About DT Midstream

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

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

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

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

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

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

Forward-looking Statements

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

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

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

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

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

DT Midstream, Inc. Reconciliation of Reported to Operating Earnings (non-GAAP, unaudited)

	Three Months Ended
	June 30,								March 31,
		2025								2025
	Reported Earnings		Pre-tax Adjustments		Income Taxes⁽¹⁾		Operating Earnings		Reported Earnings		Pre-tax Adjustments		Income Taxes⁽¹⁾		Operating Earnings
	*(millions)*
Adjustments			$	—	$	—					$	—	$	—
Net Income Attributable to DT Midstream	$	107	$	—	$	—	$	107	$	108	$	—	$	—	$	108

	Six Months Ended
	June 30,								June 30,
		2025								2024
	Reported Earnings		Pre-tax Adjustments		Income Taxes⁽¹⁾		Operating Earnings		Reported Earnings		Pre-tax Adjustments		Income Taxes⁽¹⁾		Operating Earnings
	*(millions)*
Adjustments			$	—	$	—					$	—	$	—
Net Income Attributable to DT Midstream	$	215	$	—	$	—	$	215	$	193	$	—	$	—	$	193

(1) Excluding tax related adjustments, the amount of income taxes was calculated based on a combined federal and state income tax rate, considering the applicable jurisdictions of the respective segments and deductibility of specific operating adjustments

DT Midstream, Inc. Reconciliation of Reported to Operating Earnings per diluted share⁽¹⁾(non-GAAP, unaudited)

	Three Months Ended
	June 30,								March 31,
		2025								2025
	Reported Earnings		Pre-tax Adjustments		Income Taxes⁽²⁾		Operating Earnings		Reported Earnings		Pre-tax Adjustments		Income Taxes⁽²⁾		Operating Earnings
	*(per share)*
Adjustments			$	—	$	—					$	—	$	—
Net Income Attributable to DT Midstream	$	1.04	$	—	$	—	$	1.04	$	1.06	$	—	$	—	$	1.06

	Six Months Ended
	June 30,								June 30,
		2025								2024
	Reported Earnings		Pre-tax Adjustments		Income Taxes⁽²⁾		Operating Earnings		Reported Earnings		Pre-tax Adjustments		Income Taxes⁽²⁾		Operating Earnings
	*(per share)*
Adjustments			$	—	$	—					$	—	$	—
Net Income Attributable to DT Midstream	$	2.10	$	—	$	—	$	2.10	$	1.97	$	—	$	—	$	1.97

(1) Per share amounts are divided by Weighted Average Common Shares Outstanding — Diluted, as noted on the Consolidated Statements of Operations
(2) Excluding tax related adjustments, the amount of income taxes was calculated based on a combined federal and state income tax rate, considering the applicable jurisdictions of the respective segments and deductibility of specific operating adjustments

DT Midstream, Inc. Reconciliation of Net Income Attributable to DT Midstream to Adjusted EBITDA (non-GAAP, unaudited)

	Three Months Ended						Six Months Ended
	June 30,			March 31,			June 30,			June 30,
		2025			2025			2025			2024
Consolidated	*(millions)*
Net Income Attributable to DT Midstream	$	107		$	108		$	215		$	193
Plus: Interest expense		40			40			80			79
Plus: Income tax expense		34			35			69			64
Plus: Depreciation and amortization		63			63			126			103
Plus: EBITDA from equity method investees⁽¹⁾		64			73			137			142
Less: Interest income		—			(1	)		(1	)		(1	)
Less: Earnings from equity method investees		(30	)		(37	)		(67	)		(85	)
Less: Depreciation and amortization attributable to noncontrolling interests		(1	)		(1	)		(2	)		(2	)
Adjusted EBITDA	$	277		$	280		$	557		$	493

(1) Includes share of our equity method investees’ earnings before interest, taxes, depreciation and amortization, which we refer to as “EBITDA.” A reconciliation of earnings from equity method investees to EBITDA from equity method investees follows:

	Three Months Ended						Six Months Ended
	June 30,			March 31,			June 30,			June 30,
		2025			2025			2025			2024
	*(millions)*
Earnings from equity method investees	$	30		$	37		$	67		$	85
Plus: Depreciation and amortization attributable to equity method investees		19			22			41			41
Plus: Interest expense attributable to equity method investees		15			14			29			16
EBITDA from equity method investees	$	64		$	73		$	137		$	142

DT Midstream, Inc. Reconciliation of Net Income Attributable to DT Midstream to Adjusted EBITDA Pipeline Segment (non-GAAP, unaudited)

	Three Months Ended						Six Months Ended
	June 30,			March 31,			June 30,			June 30,
		2025			2025			2025			2024
Pipeline	*(millions)*
Net Income Attributable to DT Midstream	$	93		$	92		$	185			145
Plus: Interest expense		11			13			24			25
Plus: Income tax expense		29			30			59			48
Plus: Depreciation and amortization		28			28			56			37
Plus: EBITDA from equity method investees⁽¹⁾		64			73			137			142
Less: Interest income		—			(1	)		(1	)		(1	)
Less: Earnings from equity method investees		(30	)		(37	)		(67	)		(85	)
Less: Depreciation and amortization attributable to noncontrolling interests		(1	)		(1	)		(2	)		(2	)
Adjusted EBITDA	$	194		$	197		$	391		$	309

(1) Includes share of our equity method investees’ earnings before interest, taxes, depreciation and amortization, which we refer to as “EBITDA.” A reconciliation of earnings from equity method investees to EBITDA from equity method investees follows:

	Three Months Ended						Six Months Ended
	June 30,			March 31,			June 30,			June 30,
		2025			2025			2025			2024
	*(millions)*
Earnings from equity method investees	$	30		$	37		$	67		$	85
Plus: Depreciation and amortization attributable to equity method investees		19			22			41			41
Plus: Interest expense attributable to equity method investees		15			14			29			16
EBITDA from equity method investees	$	64		$	73		$	137		$	142

DT Midstream, Inc. Reconciliation of Net Income Attributable to DT Midstream to Adjusted EBITDA Gathering Segment (non-GAAP, unaudited)

	Three Months Ended				Six Months Ended
	June 30,		March 31,		June 30,		June 30,
		2025		2025		2025		2024
Gathering	*(millions)*
Net Income Attributable to DT Midstream	$	14	$	16	$	30	$	48
Plus: Interest expense		29		27		56		54
Plus: Income tax expense		5		5		10		16
Plus: Depreciation and amortization		35		35		70		66
Less: Interest income		—		—		—		—
Adjusted EBITDA	$	83	$	83	$	166	$	184

DT Midstream, Inc. Reconciliation of Net Income Attributable to DT Midstream to Distributable Cash Flow (non-GAAP, unaudited)

	Three Months Ended						Six Months Ended
	June 30,			March 31,			June 30,			June 30,
		2025			2025			2025			2024
Consolidated	*(millions)*
Net Income Attributable to DT Midstream	$	107		$	108		$	215		$	193
Plus: Interest expense		40			40			80			79
Plus: Income tax expense		34			35			69			64
Plus: Depreciation and amortization		63			63			126			103
Less: Earnings from equity method investees		(30	)		(37	)		(67	)		(85	)
Less: Depreciation and amortization attributable to noncontrolling interests		(1	)		(1	)		(2	)		(2	)
Plus: Dividends and distributions from equity method investees		30			48			78			125
Less: Cash interest expense		(76	)		—			(76	)		(74	)
Less: Cash taxes		(4	)		2			(2	)		(3	)
Less: Maintenance capital investment⁽¹⁾		(6	)		(8	)		(14	)		(13	)
Distributable Cash Flow	$	157		$	250		$	407		$	387

(1) Maintenance capital investment is defined as the total capital expenditures used to maintain or preserve assets or fulfill contractual obligations that do not generate incremental earnings.

The MIL Network –

August 5, 2025

MIL-OSI: Flow Capital Announces a C$15.0M Investment in Common Wealth

Source: GlobeNewswire (MIL-OSI)

TORONTO, ON, July 31, 2025 (GLOBE NEWSWIRE) — Flow Capital Corp. (TSXV: FW) (“Flow Capital” or the “Company”) is pleased to announce a C$15.0 million senior secured note in Common Wealth Pension Services Inc. (dba “Common Wealth”), a SaaS company serving the Canadian group retirement market, with a first tranche advance of C$4.0 million.

Common Wealth offers a modern full-stack platform for group retirement plan administration. With a user-friendly interface and expert support, the platform empowers members to build long-term financial security, enables employers of all sizes to offer competitive retirement benefits, and equips advisors with tools to better serve clients and accelerate the growth of their group retirement practices.

Flow Capital’s investment will support Common Wealth in accelerating product innovation, expanding its customer base, and scaling operations, advancing the company’s mission to make retirement security accessible to everyone in Canada.

Growing technology companies seeking flexible, covenant-light, founder-friendly growth capital are encouraged to apply directly at www.flowcap.com/get-funding.

About Common Wealth

Common Wealth is driven by its mission to make retirement security accessible to everyone, currently serving over 1,100 employers across Canada, with especially rapid adoption among SMBs and the advisors who serve them. Common Wealth’s vision is to provide its members with a “retirement plan for life” that extends beyond the workplace, and to offer its advisor partners the best platform to power the growth of their businesses. Common Wealth’s retirement technology platform has been awarded Pensions & Investments’ global Innovation Award for Best Technology.

For more information, please visit www.commonwealthretirement.com.

About Flow Capital

Flow Capital Corp. is a publicly listed provider of flexible growth capital and alternative debt solutions dedicated to supporting high-growth companies. Since its inception in 2018, the company has provided financing to businesses in the US, the UK, and Canada, helping them achieve accelerated growth without the dilutive impact of equity financing or the complexities of traditional bank loans. Flow Capital focuses on revenue-generating, VC-backed, and founder-owned companies seeking growth capital to drive their continued expansion.

Learn more at www.flowcap.com.

For further information, please contact:

Flow Capital Corp.

Alex Baluta
Chief Executive Officer
alex@flowcap.com

47 Colborne Street, Suite 303,
Toronto, Ontario M5E 1P8

Forward-Looking Information and Statements

Certain statements herein may be “forward-looking” statements that involve known and unknown risks, uncertainties and other factors that may cause the actual results, performance or achievements of Flow or the industry to be materially different from any future results, performance or achievements expressed or implied by such forward-looking statements. Forward-looking statements involve significant risks and uncertainties, should not be read as guarantees of future performance or results, and will not necessarily be accurate indications of whether such results will be achieved. A number of factors could cause actual results to vary significantly from the results discussed in the forward-looking statements. These forward-looking statements reflect current assumptions and expectations regarding future events and operating performance and are made as of the date hereof and Flow assumes no obligation, except as required by law, to update any forward-looking statements to reflect new events or circumstances.

The MIL Network –

August 5, 2025
MIL-OSI: SHARC Energy Ships SHARC WET Systems to US Government-Affiliated Project

Source: GlobeNewswire (MIL-OSI)

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

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

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

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

About SHARC Energy

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

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

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

ON BEHALF OF THE BOARD

Fred Andriano
Chairman

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

Forward-Looking Statements

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

The MIL Network –

August 5, 2025
MIL-OSI: ReconAfrica Provides a Corporate Update and Announces That the Kavango West 1X Well Has Started Drilling

Source: GlobeNewswire (MIL-OSI)

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

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

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

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

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

Corporate Update

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

Stock Option Grants

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

About ReconAfrica

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

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

For further information contact:

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

IR Inquiries Email: investors@reconafrica.com

Media Inquiries Email: media@reconafrica.com

Cautionary Note Regarding Forward-Looking Statements:

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

The MIL Network –

August 5, 2025
MIL-OSI: QuestionPro Launches Partnerships Ecosystem to Transform Research Industry

Source: GlobeNewswire (MIL-OSI)

NEW YORK, July 31, 2025 (GLOBE NEWSWIRE) — QuestionPro announces the launch of the QuestionPro Partnerships Ecosystem, a comprehensive ecosystem designed to push the traditional boundaries of speed, intelligence, and depth of research norms. This ecosystem positions itself as the definitive platform for next-generation research capabilities.

The future of research will be powered by three forces. Faster research turnaround, smarter research processes, and deeper insights.The goal of the QuestionPro Partnerships Ecosystem is to foster a new culture of collaboration to enable our clients to successfully embrace the future of research. Where the future of insights isn’t siloed but collaborative.

“The question isn’t whether organizations need faster, smarter, deeper research capabilities – it’s whether any single organization can solve all these emerging challenges alone,” said Vivek Bhaskaran, CEO of QuestionPro. “The answer is no. That is at the core of why we built this curated ecosystem.”

“The future of insights will be powered by ecosystems,” said Sumair Sayani, Global Lead AI Programs & Strategic Partnerships. “The QuestionPro Partner Ecosystem democratizes advanced research capabilities, allowing businesses of all sizes to access enterprise-grade tools without complexity.”

The QuestionPro Partnerships Ecosystem is now available worldwide. Special offers are available for early adopters, with broader availability throughout Q3 2025. Offering ready-to-launch solutions for every research need, with AI and automation capabilities that reduce time organizing data while increasing time acting on insights.

About QuestionPro
Founded in 2006, QuestionPro is a global provider of online survey and research services that help companies make better decisions through data. Our fully integrated online platform includes surveys, research & insights, customer experience (CX) and workforce/employee experience software. We additionally offer polling, journey mapping, employee 360s, and data visualization. Our clientele ranges from small businesses to Fortune 100 companies, who rely on us for insights about customers, employees, and the partnerships. With offices in the US, Canada, Mexico, U.K., Germany, Japan, Australia, the United Arab Emirates and India, we offer customers 24-7 access to highly trained support specialists and engineers. More information is available at https://www.questionpro.com/us/

The MIL Network –

August 5, 2025

MIL-OSI: Firm Capital Property Trust Announces Normal Course Issuer Bid

Source: GlobeNewswire (MIL-OSI)

TORONTO, July 31, 2025 (GLOBE NEWSWIRE) — Firm Capital Property Trust (“FCPT” or the “Trust”), (TSX: FCD.UN) announced today that the Toronto Stock Exchange (the “TSX”) has accepted a notice filed by FCPT of its intention to make a normal course issuer bid (the “NCIB”) with respect to its outstanding trust units.

The notice provides that FCPT may, during the 12 month period commencing August 5, 2025 and ending no later than August 4, 2026, purchase through the facilities of the TSX and/or alternative Canadian Trading Systems up to 3,266,775 trust units in total, being 10% of the “public float” of trust units as of July 28, 2025. The price which FCPT will pay for any trust units will be the market price at the time of acquisition. During the period of this NCIB, FCPT may make purchases under the NCIB by means of open market transactions. The actual number of trust units which may be purchased pursuant to the NCIB and the timing of any such purchases will be determined by senior management of FCPT. The average daily trading volume on the TSX from January 1, 2025 to June 30, 2025 was 24,867 trust units. Daily purchases under the NCIB will be limited to 6,216 trust units, other than block purchases. All trust units purchased by FCPT under the NCIB will be cancelled.

As of July 28, 2025, there were 36,925,682 trust units of FCPT outstanding, and the public float was 32,667,751 trust units.

FCPT believes that its trust units may from time to time trade in a price range that does not adequately reflect the value of such units in relation to the business of FCPT and its future business prospects. As a result, depending upon future price movements and other factors, FCPT believes that the outstanding trust units may represent an attractive investment to FCPT. Furthermore, purchases of trust units are expected to benefit all persons who continue to hold trust units by increasing their equity interest in FCPT.

Pursuant to a previous notice of intention to conduct a NCIB, FCPT sought and received approval from the TSX to purchase up to 3,281,995 trust units through open market purchases on the TSX and alternative Canadian trading systems for the period of July 18, 2024 to July 17, 2025. FCPT did not purchase for cancellation any of its trust units under this prior normal course issuer bid.

ABOUT FIRM CAPITAL PROPERTY TRUST (TSX : FCD.UN)

Firm Capital Property Trust is focused on creating long-term value for Unitholders, through capital preservation and disciplined investing to achieve stable distributable income. In partnership with management and industry leaders, the Trust’s plan is to own as well as to co-own a diversified property portfolio of multi-residential, flex industrial and net lease convenience retail. In addition to stand alone accretive acquisitions, the Trust will make joint acquisitions with strong financial partners and acquisitions of partial interests from existing ownership groups, in a manner that provides liquidity to those selling owners and professional management for those remaining as partners. Firm Capital Realty Partners Inc., through a structure focused on an alignment of interests with the Trust sources, syndicates and property and asset manages investments on behalf of the Trust.

FORWARD LOOKING INFORMATION

This press release contains contain forward-looking statements within the meaning of applicable securities laws including, among others, statements relating to future purchases of trust units under the NCIB. In some cases, forward-looking statements can be identified by the use of words such as “may”, “will”, “should”, “expect”, “plan”, “anticipate”, “believe”, “estimate”, “predict”, “potential”, “continue”, and by discussions of strategies that involve risks and uncertainties. The forward-looking statements are based on certain key expectations and assumptions made by the Trust. By their nature, forward-looking statements involve numerous assumptions, inherent risks and uncertainties, both general and specific, that contribute to the possibility that the predictions, forecasts, projections and various future events will not occur. Although management of the Trust believes that the expectations reflected in the forward-looking statements are reasonable, there can be no assurance that future results, levels of activity, performance or achievements will occur as anticipated. These statements are not guarantees and are based on our estimates and assumptions that are subject to risks and uncertainties. These risks include, but are not limited to, risks associated with the Trust’s financial condition and prospects; the stability of general economic and market conditions; interest rates; the underlying value of the Trust and its trust units; the ability of the Trust to complete purchases under the NCIB; the availability of cash for repurchases of outstanding trust units under the NCIB; the existence of alternative uses for the Trust’s cash resources which may be superior to effecting repurchases under the NCIB; compliance by third parties with their contractual obligations; compliance with applicable laws and regulations pertaining to the NCIB; and other risks related to the Trust’s business, including those described in the Trust’s Annual Information Form for the year ended December 31, 2024 under “Risks and Uncertainties” (a copy of which can be obtained at www.sedar.com). Neither the Trust nor any other person assumes responsibility for the accuracy and completeness of any forward-looking statements, and no one has any obligation to update or revise any forward-looking statement, whether as a result of new information, future events or such other factors which affect this information, except as required by law.

Neither the TSX nor its Regulation Services Provider (as that term is defined in the policies of the TSX) accepts responsibility for the adequacy or accuracy of this release. Additional information about the Trust is available at www.firmcapital.com or www.sedarplus.ca.

For further information, please contact:

Robert McKee President & Chief Executive Officer (416) 635-0221	Sandy Poklar Chief Financial Officer (416) 635-0221

For Investor Relations information, please contact:

Victoria Moayedi Director, Investor Relations (416) 635-0221

The MIL Network –

August 5, 2025

MIL-OSI: TAB Bank Adds Sam Cirelli to Strengthen Northeast Lending Team

Source: GlobeNewswire (MIL-OSI)

OGDEN, Utah, July 31, 2025 (GLOBE NEWSWIRE) — TAB Bank has added Sam Cirelli as Vice President, Business Development, to strengthen the Northeast lending team. Based in New York, Cirelli has spent over 30 years as a corporate lender and advisor to small and mid-sized companies. He managed, directed, and closed more than $10 billion in loan commitments across 700 transactions in multiple industries.

“I’m excited to help TAB grow its business in the Northeast region and use my expertise to develop reliable and creative financial solutions for clients,” said Cirelli. “I’m honored to be part of the TAB Bank team and be a trusted advisor in helping businesses achieve their goals.”

Cirelli has extensive experience in executive management, portfolio management, underwriting, loan origination and structuring. He was previously an originations manager and sales manager at Triumph, where he grew the Northeast region’s business. He has also founded and led two prominent asset-based lending startups.

Cirelli was a founding managing partner of Northern Lights Partners, a boutique investment bank raising capital and debt and advising on mergers and acquisitions. He has also served as global loan origination director for General Motors Finance, where he was responsible for the US, UK and Canadian markets.

Cirelli has been an adjunct professor at New York University, teaching Harvard Case Studies in corporate finance, and at Wagner College, teaching undergraduate and MBA programs in corporate finance. He received a bachelor’s degree in finance and an MBA from St. John’s University.

About TAB Bank
At TAB Bank, our mission is to unlock dreams with bold financial solutions that empower individuals and businesses nationwide. We are committed to building value in all we do through our innovative banking products. Our dedication drives us to continuously improve, ensuring that we meet the evolving needs of our clients with excellence and agility. For over 25 years, we have remained steadfast in offering tailored, technology-enabled solutions designed to simplify and enhance the banking experience.

For more information about how we can help you achieve your financial dreams, visit www.TABBank.com.

Contact Information:
Trevor Morris
Director of Marketing
801-710-6318
trevor.morris@tabbank.com

A photo accompanying this announcement is available at https://www.globenewswire.com/NewsRoom/AttachmentNg/c9726fbb-6563-49b7-a042-061dab830f6a.

The MIL Network –

August 5, 2025
MIL-OSI: NowVertical’s Integrated Model Drives Cross‑Market Growth in Strategic Accounts

Source: GlobeNewswire (MIL-OSI)

TORONTO, July 31, 2025 (GLOBE NEWSWIRE) — NowVertical Group Inc. (TSXV: NOW) (“NowVertical” or the “Company”), a leading data and AI solutions provider, today provided an update which highlights geographic expansion in two marquee engagements that illustrate how a single operating framework converts early local wins into scales enterprise‑wide programmes.

During the first half of 2025, NowVertical substantially deepened its work with one of the world’s largest insurers—a strategic account client that operates in more than forty countries. Leveraging the Company’s status as Google Cloud Partner of the Year, the engagement has evolved from a single‑country project into a Latin‑American data‑modernisation and AI initiative that migrates fragmented estates onto a common cloud architecture, delivers advanced analytics to business users and applies robust data governance. The approach delivered by NowVertical is a central, consistent, high-quality delivery capability providing services which can be tailored to meet the specific needs of each geography. Revenue generated from this account in the first six months of 2025 already surpasses the client’s full‑year 2024 spend with NowVertical, demonstrating both the speed and scale at which the integrated model can grow strategic relationships.

A similar growth trajectory is underway with a global media and telecommunications group, where NowVertical’s solution has been adopted as the enterprise standard for managing and modernizing legacy data assets in preparation for AI adoption. Initially launched in the UK & Ireland market in 2024, the solution has now been implemented across eight projects within the group, including recent expansions into Italy and Germany, with additional deployments scheduled for H2 2025. By integrating legacy and modern data through standardized schemas, automated archival processes, and unified retention and compliance controls, the platform not only delivers measurable cost savings but also unlocks significant strategic value. The transformed data estate serves as a compliant, AI-ready foundation for advanced analytics and model training—supporting both regulatory requirements and long-term innovation objectives. This rollout reflects the repeatability of NowVertical’s delivery playbook, its ability to scale across complex enterprise environments, and its alignment with clients’ global data modernization and AI-readiness agendas.

Sandeep Mendiratta, Chief Executive Officer of NowVertical, commented: “Clients are choosing to scale with NowVertical because we can help them bring one architecture, one governance model and one integrated team that can deliver quickly from country to country. These engagements prove that our ‘One Brand, One Business’ strategy is translating early successes into broad, multi‑region programmes that drive measurable value for customers and sustainable growth for NowVertical.”

Management believes that the growing contribution from these cross‑market engagements supports the Company’s ability to grow it’s strategic account base while reinforcing NowVertical’s position as a trusted, full‑stack data and AI partner.

About NowVertical Group Inc.

NowVertical is a global data and analytics company which helps clients transform data into tangible business value with AI, fast. Offering a comprehensive suite of solutions and services, the Company enables clients to quickly harness the full potential of their data, driving measurable outcomes and accelerating potential return on investment. Enterprises optimize decision-making, improve operational efficiency, and unlock long-term value from their data using the Company’s AI-Infused first party and third-party technologies. NowVertical is growing organically and through strategic acquisitions.

For further details about NowVertical, please visit www.nowvertical.com.

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

For further information, please contact:

Andre Garber, CDO 
 IR@nowvertical.com 

Investor Relations: Bristol Capital Ltd.

Stefan Eftychiou

 stefan@bristolir.com

+1(905)326-1888 x60 

Forward-Looking Statements

This news release contains forward-looking information and forward-looking information within the meaning of applicable Canadian securities laws (together “forward-looking statements“), including, with respect to the availability of funds under the Facilities, the ability of NowVertical to utilize funds under the Facilities, the effect of the Facilities on NowVertical’s operations contemplated in this press release on NowVertical’s business, finances and operations. Forward-looking statements are necessarily based upon a number of estimates and assumptions that, while considered reasonable by management, are inherently subject to significant business, economic and competitive uncertainties, and contingencies, certain of which are unknown. Forward-looking statements generally can be identified by the use of forward-looking words such as “may”, “should”, “will”, “could”, “intend”, “estimate”, “plan”, “anticipate”, “expect”, “believe” or “continue”, or the negative thereof or similar variations. Forward-looking statements involve known and unknown risks, uncertainties and other factors that may cause future results, performance, or achievements to be materially different from the estimated future results, performance or achievements expressed or implied by the forward-looking statements and the forward-looking statements are not guarantees of future performance. Forward-looking statements are qualified in their entirety by inherent risks and uncertainties, including: adverse market conditions; risks inherent in the data analytics and artificial intelligence sectors in general; regulatory and legislative changes; that future results may vary from historical results; inability to service the Company’s debt; any inability to realize the expected benefits and synergies of acquisitions or dispositions; that market competition may affect the business, results and financial condition of the Company and other risk factors identified in documents filed by the Company under its profile at www.sedarplus.com, including the Company’s management’s discussion and analysis for the year ended December 31, 2024. Further, these forward-looking statements are made as of the date of this news release and, except as expressly required by applicable law, the Company assumes no obligation to publicly update or revise any forward-looking statement, whether as a result of new information, future events or otherwise.

The MIL Network –

August 5, 2025
MIL-OSI Submissions: The quiet war: What’s fueling Israel’s surge of settler violence – and the lack of state response

Source: The Conversation – USA (3) – By Arie Perliger, Director of Security Studies and Professor of Criminology and Justice Studies, UMass Lowell

An Israeli soldier prays in the Evyatar outpost in the Israeli-occupied West Bank on July 7, 2024. AP Photo/Ohad Zwigenberg

Since Oct. 7, 2023, as Israel’s war against Hamas drags on in the Gaza Strip, a quieter but escalating war has unfolded in the West Bank between Israelis and Palestinians.

While precise figures are elusive, United Nations estimates indicate that Jewish settlers have carried out around 2,000 attacks against Palestinians since the war in Gaza began. That number represents a dramatic surge compared with any previous period during the nearly six decades Israel has controlled the West Bank.

Attacks include harassment of Palestinian villagers trying to access their crops or work outside their villages, as well as more extreme and organized violence, such as raiding villages to vandalize property. While many of the attacks are unprovoked, some are what settlers call “price tag” actions: retaliation for Palestinian violence against Israelis, such as car-rammings, rock-throwing and stabbings.

Settlers’ attacks displaced more than 1,500 Palestinians in the first year of the war in Gaza, and gun violence is increasingly common. Since October 2023, more than 1,000 Palestinians in the West Bank have been killed. While most of these fatalities resulted from military operations, some were killed by settlers.

Mourners attend the funeral of three Palestinians who were killed when Jewish settlers stormed the West Bank village of Kafr Malik, on June 26, 2025.
AP Photo/Leo Correa

As a scholar who has studied Jewish religious extremism for over two decades, I contend this campaign is not merely a result of rising tension between the settlers and their Palestinian neighbors amid the Gaza conflict. Rather, it is fueled by a confluence of ideological fervor, opportunism and far-right Israelis’ political vision for the region.

Religious redemption

Israel has occupied the West Bank since 1967’s Six-Day War against Egypt, Jordan and Syria, transforming this small region of around 2,000 square miles (5,200 square kilometers) to an amalgam of Jewish and Palestinian enclaves. Most countries other than Israel consider Jewish settlements illegal, but they have rapidly expanded in recent decades, becoming a major challenge for any settlement of the Israeli-Palestinian conflict.

The ideological roots of violence lie within religious Zionism: a worldview embraced by about 20% of Israel’s Jewish population, including most West Bank settlers.

The great majority of the leaders of the early Zionist movement held strong secular views. They pushed for the creation of a Jewish state over the objections of Orthodox figures, who argued that it should be a divine creation rather than a human-made polity.

Religious Zionists, on the other hand, view the creation of modern-day Israel and its military victories as steps in a divine redemption, which will culminate in a Jewish kingdom led by a heaven-sent Messiah. Adherents believe contemporary events, particularly those asserting Jewish control over the entire historical land of Israel, can accelerate this process.

In recent decades, influential religious Zionist leaders have argued that final redemption requires Israel’s total military triumph and the annihilation of its enemies, particularly the Palestinian national movement. From this perspective, the devastation of Oct. 7 and the subsequent war are a divine test – one the nation can only pass by achieving a complete victory.

This belief system fuels most religious Zionists’ opposition to ending the war, as well as their advocacy for scorched-earth policies in Gaza. Some hope to rebuild the Jewish settlements in the strip that Israel evacuated in 2005.

Some religious Zionists hope to reestablish Jewish settlements in Gaza.‘
Sally Hayden/SOPA Images/LightRocket via Getty Images

The violence in the West Bank reflects an extension of the same beliefs. Extreme groups within the settler population aim to solidify Jewish control by making Palestinian communities’ lives in the region unsustainable.

Opportunistic violence

Hamas’ Oct. 7 massacre, which killed over 1,200 Israelis, traumatized the nation. It also hardened many Jewish Israelis’ conviction that a Palestinian state would be an existential threat, and thus Palestinians cannot be partners for peace.

This shift in sentiment created a permissive environment for violence. While settler attacks previously drew criticism from across the political spectrum, extremist violence faces less public condemnation today – as does the government’s lack of effort to curb it.

This increase in violence is also enabled by a climate of impunity. Israeli security forces have been stretched thin by operations in Gaza, Syria, Iran and beyond. In the West Bank, the military increasingly relies on settler militias known as “Emergency Squads,” which are armed by the Israeli military for self-defense, and army units composed primarily of religious Zionist settlers, such as the Netzah Yehuda Battalion. Such groups have little incentive to stop attacks on Palestinians, and at times, they have participated.

This dynamic has dangerously blurred the line between the state military and militant settlers. The Israeli police, meanwhile, under the command of far-right National Security Minister Itamar Ben-Gvir, appear focused on protecting settlers. Police leadership has been accused of ignoring intelligence about planned attacks and failing to arrest violent settlers or enforce restraining orders. Yesh Din, an Israeli human rights group, asserts that just 3% of attacks have resulted in a conviction.

In June 2025, military attempts to curb settler militancy triggered a violent backlash, as extremist settlers attacked military commanders and tried to set fire to military facilities. Settlers view efforts to restrict their actions as illegitimate and a betrayal of Jewish interests in the West Bank.

Political vision

Violence by extremist settlers is not random; it is one arm of a coordinated pincer strategy to entrench Jewish control over the West Bank.

Emergency volunteers put out a fire during an attack by Israeli right-wing settlers on the West Bank village of Turmusaya on June 26, 2025.
Ilia Yefimovich/picture alliance via Getty Images

While militant settlers create a climate of fear, Israeli authorities have undermined legal efforts to stop the violence – ending administrative detention for settler suspects, for example. Meanwhile, the government has intensified policies that undermine Palestinians’ economic development, freedom of movement and land use. In May, finance minister and far-right leader Bezalel Smotrich approved 22 new settlements, calling it a “historic decision” that signaled a return to “construction, Zionism, and vision.”

Together, violence from below and policy from above advance a clear strategic goal: the coerced depopulation of Palestinians from rural areas to solidify Israeli sovereignty over the entire West Bank.

Levers for change

The militant elements of the settler movement constitute a fractional segment of Israeli society. When it comes to improving the situation in the West Bank, broad punitive measures against the entire country, such as economic boycotting and divestment, or blocking access to scientific, economic and cultural programs and organizations, have historically proved ineffective.

Instead, such policies seem to entrench many Israelis’ perception of international bias and double standards: the sense that critics are antisemitic, or that few outsiders understand the country’s challenges – particularly in light of threats from entitles like Iran, Hamas and Hezbollah, which openly seek Israel’s elimination.

More targeted policies aim specifically at the Israeli far right, including sanctions – economic, political or cultural – directed at settler communities and their infrastructure. Canada, Australia, New Zealand, Norway and the U.K. have imposed travel bans on Ben-Gvir and Smotrich, and frozen their assets in those countries. Similarly, I believe decisions to ban goods produced in the West Bank settlements, as Ireland has recently debated, would be more effective than banning all Israeli products.

This targeted approach, I would argue, would allow the international community to cultivate stronger alliances with the many Israelis concerned about the settlements and Palestinians’ rights in the West Bank.

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

– ref. The quiet war: What’s fueling Israel’s surge of settler violence – and the lack of state response – https://theconversation.com/the-quiet-war-whats-fueling-israels-surge-of-settler-violence-and-the-lack-of-state-response-261990

MIL OSI –

August 5, 2025
MIL-OSI Submissions: Strengthening collective labor rights can help reduce economic inequality

Source: The Conversation – USA (2) – By Skip Mark, Assistant professor of political science, University of Rhode Island

Only about 1 in 10 U.S. workers belong to unions today. champc/iStock via Getty Images Plus

Despite the strength of the U.S. economy, the gap between rich and poor Americans is increasing.

The wealthiest 1% of Americans have more than five times as much wealth as the bottom 50%, according to the U.S. Federal Reserve. That’s up from four times as much in the year 2000. In 2024 alone, the wealthiest 19 families got a total of US$1 trillion richer – the largest one-year increase on record.

And yet 59% of Americans don’t have enough money saved up to cover an unexpected $1,000 expense.

We are political scientists who study human rights and political economy.

In a 2023 study, our team looked at 145 countries, including the U.S., to understand the link between labor rights and inequality. We found evidence that strengthening collective labor rights may reduce economic inequality.

Empowering workers

Collective labor rights include the rights to form and join a union, bargain collectively for higher pay and better working conditions, go on strike, and get justice if employers punish workers who exercise these rights.

In the U.S., where less than 10% of workers belong to unions, union members typically earn higher wages than their nonunion counterparts.

Through negotiations on behalf of their members, unions can pressure employers to provide fair wages and benefits. If negotiations break down, the union can call for a strike – sometimes winning better benefits and higher wages as a result.

Some U.S. unions don’t have the right to strike, including air traffic controllers, teachers and those working on national security issues. But most unions have some ability to implement work stoppages and impose costs on employers to negotiate for raises and better benefits and conditions.

Reducing inequality

For our study, we analyzed the human rights in the CIRIGHTS dataset, which uses human rights reports from the U.S. State Department, Amnesty International and other sources to measure government respect for 24 human rights, including the rights to unionize and bargain collectively. The dataset is produced by the University of Rhode Island, Binghamton University and the University of Connecticut. One of us, Skip Mark, serves as a co-director of the project.

Using a scoring guide, a team of researchers reads human rights reports and gives each country a score of zero if they have widespread violations, one point if they have some violations, or two if they have no evidence of violations. The team has assigned scores for all 24 rights from 1994 through 2022.

Using this data, we created a measure of collective labor rights by adding scores for the right to workplace association and the right to collective bargaining. The resulting collective labor rights score ranges from zero to four.

Countries where workers’ rights are routinely violated, such as Afghanistan, China and Saudi Arabia, scored a zero. The United States, Macedonia and Zambia, three countries with little in common, were among those that tended to get two points, placing them in the middle. Countries with no reported violations of the rights to workplace association and collective bargaining, including Canada, Sweden and France, got four points.

According to the CIRIGHTS dataset, the strength of respect for collective labor rights around the world declined by 50%, from 2.06 in 1994 to 1.03 in 2022.

At the same time, according to the World Inequality Dataset, the share of income earned by the 1% with the biggest paychecks increased by 11%.

We used advanced statistical methods to figure out whether better worker protections actually reduce inequality or are just associated with it.

Gaps between individuals and ethnic groups

We also measured what’s been happening to economic inequality, using two common ways to track it.

One of them is vertical inequality, the gap between what people earn within a country – the rich versus the poor. The more unequal a society becomes, the higher its vertical inequality score gets. We measured it using the disposable income measure from the Gini index, a commonly used indicator of economic inequality that captures how much money individuals have to spend after taxes and government transfers.

We found that a one-point increase in collective labor rights on our four-point scale reduces vertical inequality by 10 times the average change in inequality. For the U.S., a one-point increase in collective labor rights would be about enough to undo the increase in inequality that occurred between 2008 and 2010 due to the Great Recession and its aftermath. It would also likely help stem the growing wealth gap between Black and white Americans. That’s because income disparities compound over time to create wealth gaps.

We also assessed the connection between horizontal inequality, which measures income inequality between ethnic or other groups, and collective labor rights.

Negative horizontal inequality measures the amount of a country’s income held by the poorest ethnic group. Higher scores for this metric indicate that the lowest-earning ethnic group has less income relative to the rest of society. Black Americans have the lowest median income of any racial or ethnic group, according to the U.S. Census Bureau.

Positive horizontal inequality measures the income earned by the richest ethnic group. When positive horizontal inequality rises, that means the richest ethnic group has more income relative to the rest of society. According to the same Census Bureau report, Asian Americans had the highest median earnings.

We found that stronger collective labor rights, both in law and in practice around the world, also reduce both types of horizontal inequality. This means they raise the floor by helping to improve the income of the poorest ethnic groups in society. They also close the gap by limiting the incomes of the richest ethnic group, which can reduce the likelihood of conflicts.

That is, our findings suggest that when workers are free to advocate for higher wages and better benefits for themselves, it also benefits society as a whole.

Stephen Bagwell is a researcher with the Human Rights Measurement Initiative, a charitable trust registered in New Zealand

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

– ref. Strengthening collective labor rights can help reduce economic inequality – https://theconversation.com/strengthening-collective-labor-rights-can-help-reduce-economic-inequality-254258

MIL OSI –

August 5, 2025

Category: Canada

Religious redemption

Opportunistic violence

Political vision

Levers for change

Empowering workers

Reducing inequality

Gaps between individuals and ethnic groups