Oil prices make headlines, but they tell only part of the story behind an oil and gas investment. Experienced oil and gas investors also look at the operator, project costs, geology, well performance, infrastructure, ownership structure, and production profile because those factors can have just as much influence on the economics of an individual project.
A higher oil price does not make every project equal
The market price of crude oil matters. It affects the revenue producers can earn from each barrel and can influence drilling activity across the industry.
But the same oil price can produce very different economics from one project to another.
The Federal Reserve Bank of Dallas Energy Survey helps show why. In its first-quarter 2026 survey, exploration and production companies said they needed a West Texas Intermediate price of about $66 per barrel on average to profitably drill a new well. Across the regions surveyed, average break-even prices ranged from $62 to $70 per barrel.
The differences also showed up by company size. Large producers reported an average break-even price of $59 per barrel, while smaller producers reported $68.
Two wells can therefore sell oil into the same market while having very different costs and margins.
For investors, the question is not simply what oil is trading for today. A better question is how well the individual project can perform under a range of market conditions.
The operator can influence how a project performs
Oil and gas development involves hundreds of operating decisions before and after a well starts producing.
The operator determines how the well is drilled and completed, coordinates contractors, manages field operations, and oversees production. Experience within the specific basin can be valuable because operators build knowledge around local geology, drilling conditions, and techniques used across nearby acreage.
Technology matters too.
EIA has reported that improvements in horizontal drilling and hydraulic fracturing have helped producers increase well productivity. In an analysis of 34 publicly traded exploration and production companies, EIA also found that companies had increased crude oil production while keeping production costs relatively stable.
Investors can read the analysis through EIA’s report on improving well productivity and production costs.
Operator selection is therefore more than a name on an investment document. The operator’s technical experience, cost discipline, and execution can influence how efficiently the underlying wells are developed.
DW Energy Group participates as a minority non-operating working interest partner with established exploration and production companies. More information about this structure is available through DW’s Approach.
Project costs help determine the margin
Revenue gets attention, but costs help determine how much room a project has to work with.
Drilling, completion, equipment, transportation, and ongoing operating expenses can vary by basin, operator, and individual well.
The Dallas Fed break-even figures show how meaningful those differences can be. If producers require different oil prices to make a new well economic, the market price alone cannot tell an investor whether a particular project has attractive economics.
That is why experienced investors consider the relationship between expected revenue and the cost of bringing production online.
A project with disciplined costs may have more room to operate when oil prices fluctuate. A higher-cost project may require stronger commodity prices to achieve the same result.
In simple terms, it matters what the barrel sells for, but it also matters what it costs to produce it.
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Geology sets the foundation
Before drilling begins, the rock matters.
Oil and natural gas formations differ in thickness, depth, pressure, permeability, and hydrocarbon content. Conditions can also vary within the same basin.
EIA’s analysis of the Permian Basin and new well productivity explains that reservoirs in the Permian vary in thickness and depth. Improved geological understanding helps operators place wells and optimize spacing in the most productive areas.
This makes geology much more than a technical detail.
Historical results from nearby wells, reservoir characteristics, acreage position, and the operator’s understanding of the formation can all help build a clearer picture before capital is committed.
No geological analysis removes drilling risk. Better data can, however, support more informed project selection.
Well performance matters after drilling is complete
A successful completion is important, but investors also need to understand how production may change over time.
Oil and natural gas wells do not normally produce at the same rate throughout their lives. Production generally declines as reservoir pressure falls.
EIA notes that horizontal wells often begin with relatively high production but can also experience higher decline rates than traditional vertical wells. That means operators must continue bringing new wells online to offset production declines across a field or portfolio.
The full analysis is available through EIA’s report on horizontal well production declines.
For individual investors, initial production is only one number to review.
Expected decline rates, projected recoverable volumes, and how production may develop over several years can provide a fuller picture of the well.
This longer view matters for investors interested in the potential for ongoing production revenue rather than simply a strong opening month.
Infrastructure connects production with the market
A productive well still needs a reliable way to move oil or natural gas to buyers.
Pipelines, gathering systems, processing plants, and other infrastructure can affect how efficiently production reaches the market.
This is particularly relevant in fast-growing production areas.
In May 2026, EIA reported that developers plan to bring approximately 44.9 billion cubic feet per day of new U.S. natural gas pipeline capacity online during 2026 and 2027. More than 66 percent of those planned additions originate in Texas.
EIA says the Texas projects are expected to provide additional takeaway capacity from the Permian Basin, reduce constraints around the Waha Hub, and help supply LNG export terminals as well as residential, power and industrial customers. Read more about planned Texas pipeline capacity additions.
For investors, infrastructure questions may include whether pipeline connections are available, whether processing is required, and how regional transportation capacity could affect production.
These details may receive less attention than the daily oil price, but they can matter to project economics.
Ownership structure changes how investors participate
The way an investor gains exposure to oil and gas also matters.
Buying shares of an energy company is different from participating directly in a particular drilling and production project.
With a working interest, participants may share in production revenue while also being responsible for their defined share of drilling, completion, and operating costs. The specific rights and obligations depend on the investment and partnership documents.
DW participates as a minority non-operating working interest partner alongside experienced exploration and production operators. This allows DW to focus on identifying, evaluating and managing opportunities while the operator handles day-to-day field activities.
For qualified and approved investors, this makes project-level evaluation especially important. The focus is not simply a publicly traded share price. Investors can look at the actual project, including the operator, basin, expenses, production, and reporting.
Strong projects depend on several factors working together
There is rarely one number that defines a strong oil and gas opportunity.
Oil and natural gas prices matter. So do the operator, geology, drilling and completion costs, infrastructure, ownership terms, and expected production profile.
Those factors also interact.
Strong geology can support well performance. An experienced operator may improve drilling efficiency. Available infrastructure can help production reach the market. Disciplined costs can give a project more flexibility when commodity prices change.
This is why due diligence remains important even during periods of strong energy pricing.
DW Energy Group has provided domestic oil and gas investment opportunities to qualified and approved investors since 2008 and states that it has formed more than 200 oil and gas partnerships.
For experienced oil and gas investors, the price of a barrel will always be worth watching, but it should never be the only number in the conversation. Qualified and approved investors who want to understand how DW evaluates domestic opportunities can learn more through their website.
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Sources
“Oil and Gas Activity Rises Amid Elevated Uncertainty,” Federal Reserve Bank of Dallas,
https://www.dallasfed.org/research/surveys/des/2026/2601
“Improving Well Productivity Helps U.S. Oil Companies Increase Production at a Lower Cost,” U.S. Energy Information Administration,
https://www.eia.gov/todayinenergy/detail.php?id=63984
“Advances in Technology Led to Record New Well Productivity in the Permian Basin in 2021,” U.S. Energy Information Administration,
https://www.eia.gov/todayinenergy/detail.php?id=54079
“Rapid Declines From Horizontal Wells Require More Drilling to Sustain Production,” U.S. Energy Information Administration,
https://www.eia.gov/todayinenergy/detail.php?id=66564
“Most Planned Natural Gas Pipeline Capacity Additions in 2026 and 2027 Originate in Texas,” U.S. Energy Information Administration,
https://www.eia.gov/todayinenergy/detail.php?id=67707
“DW’s Approach,” DW Energy Group,
https://www.dwenergygroup.com/dw-approach/
“About Us,” DW Energy Group,
https://www.dwenergygroup.com/about-us/