Eagle Natural Resources

10/16/2026

The 4th Quarter Conversation Every High Earner Should Be Having

By mid-October, your income for the year is largely known and the window for decisions that affect this year’s tax return is closing. For accredited investors in the upper brackets, that makes now the right time to look at energy.

When you hold a working interest in a drilling program, much of the upfront capital goes toward intangible drilling costs, which can generally be deducted in the year they’re incurred and applied against active income. Costs prepaid before December 31 can count toward this year, provided drilling begins within 90 days of year-end. A decision made now can apply to income you’ve already earned.

The production picture behind it is strong. EIA expects U.S. crude output to reach a record 14.3 million barrels per day in 2027, with LNG exports climbing to 19 billion cubic feet per day (EIA, Short-Term Energy Outlook, October 2026).

Speak with your CPA before the holidays about how a working interest position fits your 2026 return. If you’d like to see how Eagle structures its joint ventures, we’d be glad to walk you through it.

This post is for general information only and is not tax advice.

10/09/2026

Two Forecasts, Almost the Same Number

The EIA expects WTI to average $97 a barrel this quarter and then ease steadily through next year as Middle East supply returns and inventories rebuild, landing at around $70 by the end of 2027. Its full-year 2027 average comes in at $79.74 (EIA STEO, October 2026).

Last week, the oil and gas executives surveyed by the Dallas Fed put their own two-year expectation at $79 (Dallas Fed Energy Survey, Q3 2026).

A federal agency modeling the global market and 125 operators running wells across Texas and New Mexico, working independently, arrived at nearly the same figure.

That figure matters because it's the price most of today's new wells will be living with. A well drilled this quarter produces its strongest volumes through 2027, so its economics depend far more on where prices settle than on where they sit today.

When you're evaluating an energy investment, ask whether the plan works at $80 oil. If it does, today's prices are a bonus.

Read the full outlook: https://www.eia.gov/outlooks/steo/

10/08/2026

The EIA Just Raised Its Oil Price Outlook

The EIA's October Short-Term Energy Outlook, released this week, lifted its oil price forecast. WTI is now expected to average $88.21 a barrel in 2026, up from the $84.65 it projected in September, with the fourth quarter alone averaging $97 (EIA STEO, October 2026).

U.S. production is rising alongside it. The EIA now expects American crude output to reach a record 13.9 million barrels per day this year, above last month's 13.8 million forecast, and climb to 14.3 million in 2027.

With supply from the Middle East still constrained, more of the world's marginal barrels are coming from American fields, and the Permian remains the country's largest producing region.

Higher prices and higher output arriving together is the environment where well-run producing assets do their best work.

Read the full outlook: https://www.eia.gov/outlooks/steo/

10/01/2026

What the People Running Oil Companies Expect Next

The Dallas Fed released its third-quarter energy survey yesterday, drawing on 125 oil and gas firms across Texas, northern Louisiana and southern New Mexico. It's one of the clearest windows into how operators themselves are reading the market.

Production rose for the second straight quarter. WTI averaged $98.70 while the survey was in the field, and executives expect it to finish the year closer to $88, with longer-range expectations of $79 in two years and $82 in five (Dallas Fed Energy Survey, Q3 2026).

In other words, the operators closest to the wells are planning for prices to come down from here. How each producer prepares for that shift will do a lot to determine which investments hold up once today's prices fade.

Many are putting this year's strength to work already. Free cash flow rose for many producers through the first three quarters of 2026, and half of large E&P executives expect to return that surplus to shareholders and owners.

If you're evaluating an energy investment, it's worth asking which price an operator's plans are built around. The strongest answers tend to come from the operators who plan for $79 while the market is paying $99.

Read the full survey:

Activity in the oil and gas sector further expanded in third quarter 2026, according to oil and gas executives responding to the Dallas Fed Energy Survey.

09/24/2026

How Experienced Operators Plan for the Prices That Come Next

Oil markets have rarely moved this fast. Supply disruptions in the Middle East have pushed crude back to its highest levels since May, and U.S. diesel prices passed $200 a barrel in early September, 94% above where they stood before the conflict began (IEA, September 2026).

The EIA expects prices to stay elevated through the end of the year and then ease through 2027 as shut-in production returns and global inventories rebuild. It also warns that short-term swings are likely to be sharper than its own forecast shows (EIA STEO, September 2026).

High prices make most projects look good on paper, so the more useful question for investors is how an operator prepares for the prices that come next.

Hedging is usually the first tool. When prices sit well above a well's breakeven, an operator can lock in a portion of future production at today's levels.

That protects cash flow if the market falls the way forecasters expect. It trades away some upside for revenue that can actually be planned around.

Cost control matters just as much, because volatility hits both sides of the ledger. Diesel powers the rigs, frac fleets and trucks that keep a field running, so the same disruption lifting crude prices also raises the cost of producing each barrel.

Operators who manage service contracts carefully and keep overhead lean hold on to more of that barrel's value.

Selective drilling is where discipline shows most clearly. A new well delivers most of its oil in its first year or two, which means wells drilled today will produce their strongest volumes into 2027, when the EIA expects prices to be meaningfully lower.

Experienced operators drill the locations that still make sense at those lower prices and leave the ones that only work at today's.

Markets like this one tend to reward the operators who plan for the downturn while prices are still high. If you're evaluating an energy investment, ask how the operator is preparing for a market that won't stay where it is today.

We're always happy to talk through the questions worth asking.

09/16/2026

Permian M&A activity signals institutional confidence in the basin.

Capital doesn't lie about where it thinks the opportunity is.

Upstream M&A activity in the U.S. reached $38 billion in the first quarter of 2026, the highest quarterly total in two years, according to Enverus Intelligence Research.

Deal activity cooled in the second quarter as crude price volatility slowed dealmaking, but competition for premium Permian acreage has remained strong, and activity is expected to accelerate again in the second half of the year.

That's not just domestic capital, either.

UK-based BritENERGY recently acquired a controlling interest in 13 oil and gas wells across 3,000 acres in the Permian's New Mexico footprint, citing an "uninvestable" home market as the reason for the move.

The company is targeting 5 million barrels of production from the acreage by 2032, backed by roughly $50 million in capital investment.

When operators are paying premium prices for acreage and international capital is actively exiting other markets to get into this one, that's a signal worth paying attention to.

Institutional and international investors aren't buying the Permian because it's a good story – they're buying it because the numbers work at current prices, and they're willing to compete for position.

If you're weighing where the Permian fits into your own portfolio, the opportunities page has more on how we're positioned in the basin.

09/11/2026

How rising U.S. oil production supports investor confidence

US crude output is on track for a record 13.8 million barrels per day in 2026, surpassing the previous high of 13.7 million bpd set in 2025 (EIA, September 2026 Short-Term Energy Outlook).

For investors watching the sector, that's the kind of number that separates a cyclical bounce from structural growth.

The growth is concentrated, not diffuse.

Permian Basin production is forecast to average 6.8 million bpd this year, up 3% from 2025, while federal Gulf of America output climbed 10% in the first half of the year as new projects came online.

Both regions are producing well above their breakeven costs –
Permian operators reported breakevens of $63-69/bbl in the Dallas Fed's survey – against WTI that's averaged $84/bbl through August.

That spread between cost to produce and price received is where returns get made.

Records like this don't happen by accident.

They happen when pricing gives operators room to keep drilling instead of just holding the line – and when that room exists, capital tends to follow.

That's the environment shaping our current offering, the Income
& Development Joint Venture I.

If you'd like to see how it's structured to take advantage of this backdrop, the details are on the portal.

09/10/2026

How Reserve Replacement Supports Long-Term Oil & Gas Value

Pull a barrel of oil out of the ground and it's gone. The well doesn't refill itself.

Production is what generates the returns – it's the whole point.

But production alone only tells you about today. Reserve replacement tells you what happens after today.

Reserve replacement ratio measures how many barrels a company adds to its proved reserves against how many it produces in a given year.

Below 100%, the company is depleting faster than it's discovering – a countdown clock on future cash flow.

Above 100%, it's building the runway for years of production still ahead.

For anyone holding a working interest, this ratio tells the difference between a well that pays out once and an asset base
positioned to keep producing for years to come.

Strong production and strong reserve replacement go hand in hand.

The two aren't in tension – an operator producing well today and finding new reserves at the same time is exactly what a healthy, growing asset base looks like. Reserve replacement is simply the second half of the picture: it tells you whether today's production is being backed up by tomorrow's supply.

This is also why the source of a replacement matters, not just the number.

Reserves can be added in a few ways – new discoveries, extensions of existing fields, or buying proved reserves from someone else.

A company that replaces its production through the drill bit, by actually finding and developing new barrels, is demonstrating something different than one that's replacing reserves by writing a check for someone else's.

The first is a sign of operational strength. The second can look identical on paper while meaning something thinner underneath.

This is where the structure of your investment comes in. A working interest tied to a single well rises and falls with that well's decline curve.

A working interest in an operator that's producing strongly and replacing reserves through active drilling is tied to something bigger – a business built to keep producing today and keep finding tomorrow.

Curious how this plays out in our current Permian program? Send us a message – happy to walk through it.

09/04/2026

The Basin Keeping America Supplied: What the Data Says About the Permian

Half of American crude oil production comes from one basin.

In 2024, the Permian region accounted for 48% of total U.S. crude oil output – averaging 6.3 million barrels a day. The Bakken and Eagle Ford, two of the country's other premier formations, together produced the majority of the rest.

Scale tells one part of the story. Efficiency tells the other.

Production grew by 370,000 barrels per day compared to 2023, even as the active rig count fell by 26.

Operators achieved this through AI-assisted drilling, electronic hydraulic fracturing, and automated processes that improved well productivity without adding headcount or equipment. (EIA, April 2025)

Then there's what's still in the ground. The USGS assessed the Permian's Delaware Basin alone as containing an estimated 46.3 billion barrels of undiscovered, technically recoverable oil and 281 trillion cubic feet of natural gas.

A January 2026 assessment of the Woodford and Barnett shales – deeper formations within the same basin, previously unreachable – identified a further 1.6 billion barrels of oil and 28.3 trillion cubic feet of gas. Enough gas to supply the entire U.S. for 10 months. (USGS, January 2026)

Production is forecast to reach 6.6 million barrels a day in 2025, with new pipeline infrastructure expanding the capacity to move it. (EIA, 2025)

Eagle Natural Resources operates in this basin. For accredited investors, that means direct exposure to the most productive, most technologically advanced, and most resource-rich oil region in the United States – at a stage when production is still climbing.

If you’d like to learn more about opportunities in oil and natural gas, feel free to contact us directly on our page.

Accredited investors can learn more about Eagle's current offering by visiting the link in bio.

09/03/2026

Record U.S. LNG Exports: A Tailwind for Gas-Focused Investors

The numbers just came in, and they're the kind gas investors like to see.

U.S. LNG exports averaged 17.4 billion cubic feet per day in the first half of 2026, up 23% from the same period last year – the fastest growth the industry has seen since large-scale U.S. exports began in 2016 (EIA, September 2026).

And EIA doesn't expect this to be a one-quarter blip. Exports are projected to hold near 17.3 Bcf/d through the second half of the year, then climb to 18.7 Bcf/d by the first half of 2027 as new terminal capacity keeps coming online.

That growth is showing up in new infrastructure, not just favorable weather or a temporary price spike.

Plaquemines LNG is now exporting at full capacity.

Corpus Christi's newest expansion is running six of its seven liquefaction trains.

Golden Pass LNG shipped its first cargoes in April and is still ramping toward full output.

Every one of those additions is new, durable demand for the gas coming out of the ground on U.S. wells.

Global gas prices have stayed high enough throughout the year to pull U.S. exports toward maximum output rather than sitting on the sidelines.

Europe's benchmark price averaged $14.74 per MMBtu in the first half of 2026, the highest since 2022.

Asia's benchmark hit a four-year high. Buyers in both regions are competing hard for supply, and U.S. shipments to Asia alone roughly doubled year-over-year.

For an investor holding a working interest in a gas asset, this is what durable demand looks like: not a single good quarter, but a structural shift where new export terminals lock in buyers years into the future, and global prices are strong enough to keep that gas moving.

Every incremental cubic foot of export capacity is another buyer standing at the dock, and that's exactly what supports realized pricing at the wellhead over the long run.

Want to see how this plays into the economics of our current oil & gas opportunities? Reach out and we'll walk you through the numbers.