Uranium supply, Ohio transmission oversight, Iran sanctions, and storage capital set the Energy morning

Key Developments

U.S. uranium output rose, but reactor fuel buying remains import-heavy

EIA reported that U.S. uranium concentrate production totaled 2.1 million pounds of triuranium octoxide, or U3O8, in 2025, the highest annual level since 2017 and more than triple 2024 output (EIA). The upstream response was visible in drilling activity: exploration drilling reached 1,824 holes and more than 1.0 million feet in 2025, versus 1,324 holes and 0.6 million feet in 2024, while development drilling rose to 3,708 holes and 1.30 million feet from 2,462 holes and 1.26 million feet (EIA).

The bottleneck is not just mined volume. EIA said owners and operators of U.S. nuclear plants bought 46.9 million pounds of U3O8 equivalent in 2025, down from 55.9 million pounds in 2024, at a weighted-average price of $58.46 per pound, 11% above the 2024 weighted-average price of $52.71 per pound (EIA). Most delivered U3O8 remained foreign-origin, with Canada at 32% of 2025 deliveries, Kazakhstan at 28%, Australia at 15%, and U.S.-origin material at 7% (EIA).

Figure 1 — Most 2025 U.S. reactor uranium deliveries remained foreign-origin: Canada 32%, Kazakhstan 28%, Australia 15%, and U.S.-origin material just 7%, with the remaining share from other origins. Source: (EIA).

The read-through is that domestic mining recovery is a necessary but incomplete part of nuclear fuel security. If reactor demand remains materially larger than domestic concentrate output, the more important stress points stay in conversion, enrichment, long-term contracting, and supplier-country exposure rather than in mine production alone.

What to watch: Track whether 2026 drilling and production continue above the 2025 base, and whether future EIA uranium marketing data show the U.S.-origin share moving above the 7% of deliveries reported for 2025 (EIA).

Ohio’s transmission complaint puts local grid spending back in front of FERC

Utility Dive reported that the Office of the Ohio Consumers’ Counsel urged FERC on Aug. 27, 2026, to act on a three-year-old complaint over Ohio utilities’ local transmission and supplemental projects (Utility Dive). Since the September 2023 complaint was filed, FirstEnergy, AEP and other Ohio utilities have included more than $4.3 billion of local transmission and supplemental projects in PJM’s Regional Transmission Expansion Plan, according to the ratepayer advocate cited by Utility Dive (Utility Dive).

The dispute is narrower than systemwide transmission planning, but it lands inside the same cost-allocation fight created by large-load growth. Utility Dive reported that the complaint covers projects owned by American Electric Power, FirstEnergy, AES and Duke Energy utilities, and said the OCC contends that project plans have “ballooned” partly to handle large-load data centers owned by companies such as Meta, Amazon and Google (Utility Dive). The OCC also argued that PJM’s Attachment M-3 process lacks transparency and has not produced substantive responses on consumer impacts, according to the report (Utility Dive).

The operational implication is that data-center grid costs are moving from headline load forecasts into local transmission work that may receive less review than regional baseline projects. If FERC forces more scrutiny into the local-project channel, utilities may face a slower but more defensible path for customer-driven network upgrades; if it does not, ratepayer advocates are likely to keep treating supplemental transmission as the hidden layer of the data-center power bill.

What to watch: Watch whether FERC takes up the Ohio complaint before the next PJM local-transmission cycle and whether Attachment M-3 disclosures begin separating aging-infrastructure replacement from large-load interconnection work (Utility Dive).

Banque Misr UAE sanctions extend Iran pressure into payment plumbing

CNBC reported that the Treasury Department moved Friday to sanction the United Arab Emirates branch of Egyptian bank Banque Misr over financial ties to Iran, with Treasury intending to revoke the branch’s access to U.S. financial institutions (CNBC). According to Treasury figures cited by CNBC, Banque Misr UAE processed about $1.8 billion over the past two years for roughly 100 companies potentially tied to Iran’s shadow banking network (CNBC).

The timing matters for energy because the action follows Treasury Secretary Scott Bessent’s Aug. 24 launch of “Operation Economic Outcast,” a sanctions campaign aimed at severing Iran’s economic ties globally, CNBC reported (CNBC). Recent Energy issues have focused on whether physical Hormuz traffic can normalize; this development shifts the parallel question to whether banks, payment intermediaries and company networks can still support Iranian oil-related commerce if U.S. enforcement tightens.

The more consequential angle is that payment friction can constrain barrels even when shipping routes appear to reopen. A physical corridor through Hormuz lowers one set of risks, but a sanction that removes financial-institution access can raise the cost and complexity of settling trades, obtaining insurance, and using intermediary companies. That makes the sanctions channel a separate energy-market variable rather than a footnote to route security.

What to watch: Track whether Treasury names additional financial institutions or non-U.S. intermediaries after the Banque Misr UAE action, and whether future sanctions guidance links payment activity to specific oil, petrochemical or shipping counterparties (CNBC).

Storage attachment is absorbing more renewable capital as standalone solar slows

PV Magazine, citing BloombergNEF, reported that global renewable energy investment reached $327.5 billion in the first half of 2026, roughly unchanged from the previous six months but 21% below the record set in the second half of 2024 (PV Magazine). The composition changed more than the headline total: standalone utility-scale solar investment fell 20% year over year to $75.4 billion, while co-located solar-plus-storage projects attracted a record $25 billion in H1 2026, nearly double the second-half 2025 total and three times the first-half 2025 level (PV Magazine).

The U.S. was the second-largest renewable investment market behind China, recording 54% year-over-year growth, PV Magazine reported (PV Magazine). U.S. solar investment rose 41% to a record $45.8 billion, and wind investment reached $13.8 billion, more than double the prior-year figure, as developers accelerated financing before tax-credit deadlines and responded to electricity-demand growth tied partly to data centers (PV Magazine). Globally, wind investment totaled $92.3 billion, down 27% year over year, with offshore wind down 72% and onshore wind down 4% to $80.7 billion (PV Magazine).

The read-through is that flexibility is becoming a financing attribute, not just an operations feature. Solar-plus-storage can reduce exposure to curtailment, negative pricing and congestion, so the shift toward hybrid projects says as much about revenue quality as it does about technology cost.

What to watch: Watch whether H2 financing keeps co-located solar-plus-storage above the $25 billion H1 run rate and whether BNEF’s expected 2026 decline in new renewable installations is concentrated in standalone assets or spreads into hybrid projects (PV Magazine).

This is an AI Briefing — AI-generated analysis published under TLCapital.AI. It is not personal research or positions, and it is not investment advice. Figures are sourced to primary filings with dates noted throughout. Do your own diligence.