Continental Resources, BPX Energy, Chord Energy and Ranger Energy Services Team with Enverus to Build Field Safety Platform on Enverus ONE™

Continental Resources, BPX Energy, Chord Energy and Ranger Energy Services Team with Enverus to Build Field Safety Platform on Enverus ONE™

AUSTIN, Texas (May 5, 2026) — Continental Resources, BPX Energy, Chord Energy and Ranger Energy Services, together with Enverus, today introduced LifeSaver, a field safety initiative being developed on the Enverus ONE™ platform. Field pilots are planned during 2026, beginning in the Bakken.

LifeSaver is being designed to help energy field crews access timely, job-specific safety guidance before and during work. The platform will bring together company safety procedures, job context, site conditions and relevant operational learnings through a field-ready, mobile-first experience for workers and supervisors.

The initiative reflects a shared commitment among the participating companies to apply technology to one of the industry’s most important priorities: helping people work more safely in dynamic field environments.

“This initiative brings together two of Continental’s core values — an unwavering commitment to safety and a drive to innovate in everything we do,” said Aaron Chang, COO, Continental Resources. “We helped convene this consortium because we believe the next meaningful improvement in field safety will come from putting better, contextual guidance directly in the hands of the people doing the work. Safety has always been at the heart of our operations, and LifeSaver represents an exciting step forward in how we apply advanced technology to help protect our people in real time.  We’re proud to stand alongside our industry partners in bringing that vision to the field.”

Built for the realities of field work

Energy field operations are complex, dynamic and constantly changing. Crews work across shifting job scopes, equipment configurations, contractor teams, weather conditions and site-specific risks. Traditional safety systems remain essential, but many were designed primarily around planning, documentation and compliance workflows before or after the job. LifeSaver is being developed to support the work as it happens.

The platform is being designed to help crews access relevant safety guidance without requiring them to leave the worksite, sort through documentation or rely solely on memory in high-pressure moments. It will support company safety programs by making procedures, risk prompts and field-relevant information easier to access at the point of work.

LifeSaver is being engineered for the conditions of field work, including intermittent connectivity, high-noise environments and mobile-first access for crews in the field. It will also help supervisors and safety leaders maintain better visibility into field conditions, supporting stronger communication between frontline teams and enterprise safety organizations.

“Our crews have always carried strong safety practices into the field. What they haven’t had is technology that can adapt with them there,” said Jordie Harrell, Chief Technology Officer, BPX Energy. “LifeSaver is being designed to put job-specific guidance into workers’ hands in the moments that matter, on the devices they already use. That kind of technology, built around how field work actually happens, is how we extend the safety culture our people already live every day.”

How LifeSaver will work

LifeSaver will run on the Enverus ONE platform and is being designed for the operational realities of energy field work. The platform will connect company-specific safety content, job-specific contexts, operating inputs and relevant historical learnings through an experience built for field crews and supervisors.

For field teams, LifeSaver is expected to support:

  • Voice-first access to safety guidance designed for use in field conditions.
  • Job-specific risk prompts informed by task type, crew configuration, site context and work sequence.
  • Relevant operating inputs such as weather, nearby activity, equipment context and contractor presence, where available.
  • Company-specific safety procedures delivered in a format that is easier for crews to access during work.
  • Supervisor visibility that helps connect field conditions, work activity and safety leadership in near real time.
  • Shared safety learnings developed through consortium-led data controls and designed to improve safety intelligence across participating organizations.

LifeSaver is not intended to replace company safety programs, supervisor judgment or established operating procedures. It is being designed to strengthen them by making relevant safety guidance more accessible, specific to the work and timely.

“The hardest part of safety is that risk often emerges during work that looks routine,” said Colin Westmoreland, Chief Innovation Officer, Enverus. “The companies behind LifeSaver understand that reality, and they are choosing to address it together. We are proud to be developing the platform that will bring field context, safety intelligence and operational workflows together in a way that supports the people doing the work.”

A partner-led safety initiative

The companies behind LifeSaver are competitors, and their decision to build together carries significance well beyond their own operations. They have come together around a shared belief: the next meaningful improvement in field safety will require more than better forms or better documentation. It will require timely support that reflects the job, the site and the conditions around the work, built on strong governance, trusted data controls and deep operational expertise.

The consortium model will allow participating companies to collaborate on a common safety challenge while maintaining appropriate control over their own safety content, procedures and data. Shared learnings will be governed by content controls designed to protect company-specific information while helping the industry improve over time.

“Across each of our companies, the health and safety of our people is a core value,” said Danny Brown, CEO, Chord Energy. “LifeSaver represents a meaningful step forward in how our industry can use technology to support field teams. We are proud to help build and deploy a platform focused on protecting people where the work happens.”

Pilots planned during 2026, starting in the Bakken

Field pilots are planned during 2026, beginning in well service and workover operations in the Bakken, one of North America’s most active and operationally demanding producing regions. The Bakken was selected because field operations in the region often involve high activity levels, variable conditions and complex multi-contractor coordination.

“Well service and workover crews face some of the most dynamic risk conditions in the field,” said Stuart Bodden, CEO, Ranger Energy Services. “A platform that can keep pace with those conditions and put practical safety guidance directly in the hands of our people is exactly the kind of technology our industry needs.”

From there, LifeSaver is expected to expand into additional basins across North America and, over time, into adjacent high-consequence operating environments such as power plant maintenance, wind and solar construction, substation operations, water infrastructure and other industrial field settings.

A portion of future LifeSaver proceeds is expected to support a consortium-established non-profit dedicated to advancing worker safety across the energy industry through research, training and community investment.

About LifeSaver
LifeSaver is an AI-enabled field safety initiative being developed on the Enverus ONE platform and designed for energy and industrial operations. By combining voice-first workflows, mobile field tools and job-specific safety guidance, LifeSaver is being designed to help crews strengthen pre-job planning, access relevant safety information and make more informed decisions before and during work. Field pilots are planned during 2026 in oil and gas operations, with potential to expand into adjacent industrial sectors over time.

Enverus and Xpansiv broaden partnership to deliver a unified price discovery platform across energy

Enverus and Xpansiv broaden partnership to deliver a unified price discovery platform across energy and environmental markets through MarketView®

NEW YORK and AUSTIN – May 5, 2026 – Enverus and Xpansiv today announced an expanded partnership that brings Xpansiv CBL spot exchange transaction data and Evolution Markets forward indicative pricing for energy and environmental commodity markets into MarketView®, creating a consolidated price discovery and workflow platform across energy and environmental commodity markets.

Currently, exchange prices, OTC broker assessments, and core commodity data have lived in separate systems, forcing traders and risk teams to reconcile incomplete views of the market. The new offering harmonizes disparate environmental commodity data for market participants, including trading houses, brokers, financial institutions and corporate buyers.

MarketView now eliminates that fragmentation by bringing the most critical pricing signals together.

MarketView already serves more than 8,000 users across 500+ client sites, delivering real-time access to energy, commodity, and financial data from more than 500 providers across all major global exchanges, North American power ISOs, and leading price reporting agencies including OPIS, Argus, Platts, ICIS, and Fastmarkets. The addition of CBL and Evolution Markets data extends that trusted foundation into environmental commodity markets.

With the addition of CBL and Evolution Markets data from Xpansiv, market participants can now access:

  • Verified exchange transactions and firm orders from CBL, the world’s largest spot marketplace for environmental commodities, including renewable energy certificates (RECs) and carbon credits.
  • OTC broker spot and forward pricing from Evolution Markets, an Xpansiv company, covering a broad range of energy and environmental markets.

All data is delivered within a single, continuous workflow used for pricing, risk, and trading decisions.

The integration enables faster and more accurate:

  • Defensible mark-to-market valuations grounded in both executable transactions and broker-informed forward curves
  • Comprehensive cross-market risk analysis across environmental and traditional energy exposures
  • Liquidity-aware trading decisions informed by both exchange activity and OTC market depth

“Environmental markets didn’t lack data, they lacked cohesion,” said Matt Wilcoxson, EVP of Strategic Development, Enverus. “Traders were forced to piece together exchange prices, broker views, and their core positions across multiple systems. MarketView now brings those signals together into a single, trusted view of the market.”

“Xpansiv offers an unmatched source of end-of-day and historical data for environmental and energy commodities, covering both exchange and OTC markets,” said Russell Karas, Senior Vice President, Strategic Market Solutions, Xpansiv. “With Enverus, we’re bringing together spot exchange and OTC data in one place, providing trading, risk, and compliance teams the clarity they need to make faster, more confident decisions grounded in comprehensive market insights.”

CBL is the largest global spot exchange for REC and carbon credit transactions. The venue is integrated with Xpansiv’s comprehensive infrastructure platform and registry network, with a leading position in electricity that covers approximately 30% of global REC issuance, 7% of global renewable electricity generation, and 4% of total global electricity generation.

Its data provides the most authoritative view of executable prices and is a standard reference for mark-to-market valuation, risk modeling, and settlement. Spot market data covering North American and International RECs, carbon credits, Low Carbon Fuel Standard (LCFS) credits and Australian Carbon Credit Units (ACCUs) will be available on MarketView. Historical data for RECs and carbon credits extend back to 2016.

Evolution Markets is a leading intermediary in the energy and environmental commodity markets. It disseminates daily forward market data for a range of carbon, renewable energy, US emissions, natural gas, coal, power, and nuclear markets. Historical data dates back as far as 2000 (coal), 2002 (US emissions), 2006 (nuclear), and 2008 (RECs).

By combining exchange-verified data with OTC market color and the broader energy complex, MarketView gives trading desks a complete and consistent view of price formation across markets that were previously siloed.

Learn more at https://www.enverus.com/products/trading-and-risk-marketview

About Enverus
Enverus is the energy industry’s AI and data platform, serving more than 8,000 energy companies across 50 countries. Built on 25+ years of proprietary intelligence — 2.7 petabytes of continuously updated data, 350 million+ courthouse records, and $500 billion+ in annual transaction covering the full energy value chain across upstream, midstream, power, renewables, utilities, and capital markets. Enverus is 100% dedicated to energy. Learn more at Enverus.com.

About Xpansiv
Xpansiv is the leading infrastructure provider for the energy transition markets. The company’s comprehensive platform includes registries, online marketplaces, market execution services, wholesale power solutions, and market data for energy and environmental commodity markets. Trusted worldwide, Xpansiv helps market participants capture opportunities and drive environmental impact. Xpansiv provides solutions that enable stakeholders to deliver transparent, credible, and auditable environmental claims to address the growing global demand for assurance and accountability on climate action and sustainability performance. Company investors include Blackstone Group, Bank of America, Goldman Sachs, Aramco Ventures, Macquarie Group Ltd., S&P Global Ventures, Aware Super, BP Ventures, Commonwealth Bank, and the Australian Clean Energy Finance Corporation. Learn more at xpansiv.com.

Enverus Intelligence® Research Press Release - Until LNG demand arrives, natural gas expected to struggle at $3

The Week in Energy – May 1, 2026

This week’s energy headlines spotlight major upstream and services consolidation, private-capital rotation in gas infrastructure, accelerating Appalachian momentum, and a long-anticipated LNG milestone. Here are five stories that stood out: 

Top Stories 

  • Shell inks its largest deal in a decade with C$22B ARC buy 
    Shell agreed to acquire ARC Resources in its biggest transaction in more than ten years, materially expanding its position in the Montney. The deal doubles down on integrated gas and secures long-duration inventory directly tied to LNG Canada, reinforcing Western Canada’s role in global LNG supply as disruptions persist elsewhere. 

  • Helix & Hornbeck to merge, uniting well intervention with OSVs 
    Helix Energy Solutions and Hornbeck Offshore reached an all-stock merger combining Helix’s well intervention and robotics business with Hornbeck’s offshore support vessel fleet. The transaction creates a diversified deepwater services platform with nearly $2 billion in pro forma revenue and a balance sheet positioned for a prolonged offshore upcycle. 

  • KKR sells stake in Pembina processing JV to Apollo Funds 
    KKR agreed to sell its 40% interest in Pembina Gas Infrastructure to Apollo-managed funds, reshaping one of Western Canada’s largest gas processing and gathering systems. The asset serves the Montney and Duvernay and operates roughly 5 Bcf/d of capacity, highlighting sustained private-capital appetite for scaled, LNG-linked gas infrastructure. 

  • Antero races ahead on HG integration, cashing in on demand 
    Antero Resources is moving faster than planned on integrating assets acquired from HG Energy, already capturing operational synergies through longer laterals, faster drilling cycles and lower costs. Management also flagged accelerating gas-fired power demand tied to datacenter development as a tightening force in Appalachian markets.

  • QatarEnergyXOM’s Golden Pass LNG ships its inaugural cargo 
    Golden Pass LNG loaded its first cargo from Sabine Pass, marking the long-awaited startup of one of the most strategic liquefaction projects on the Gulf Coast. The project provides QatarEnergy with diversification as Middle East exports face disruption and underscores the growing role of U.S. LNG in global energy security.

Additional Stories

Also this week: Enterprise sanctioned new Permian processing capacity, NOV posted its weakest quarter since early 2023, hydrogen-capable gas engines cleared a key datacenter power milestone, and power developers reported rising interest in behind-the-meter solutions.

To learn more, reach out to businessdevelopment@enverus.com or visit www.enverus.com. 

Enverus Press Release - Class VI wave expected to hit US

Solar PPA Activity Persists | A New Price Regime

Figure: Solar Getting Built Despite Rising PPA Prices
Source | Enverus Intelligence® Research, Enverus FOUNDATIONS® – Power & Renewables

NextEra recently announced it signed contracts for 4 GW of new generation projects during the first quarter of 2026, comprised of 2.2 GW of solar, 1.3 GW of battery storage, and 0.5 GW of wind. The news landed as some reassurance amid growing pessimism around renewables demand, but it also validates a structural shift Enverus Intelligence® Research (EIR) has been tracking: projects are still getting built, just at materially higher prices (Figure 1). In particular, solar PPA prices and commercial solar PPA pricing have reset into a higher band, with the average solar PPA price in 2026 reflecting this new regime. For many buyers, the power purchase agreement cost is being re-evaluated as solar ppa rates and the typical PPA rate embed higher financing and equipment costs.

EIR’s analysis shows estimated PPA prices for new solar and onshore wind have risen sharply since their 2020 trough, roughly double the lows of five years ago (Figure 1). The shift in solar PPA prices has been especially notable in commercial solar PPA pricing, where solar PPA rates have climbed alongside supply chain and interconnection costs. The average solar PPA price in 2026 now captures higher expected capacity factors in some regions but also higher risk premiums, lifting the headline PPA rate and total power purchase agreement cost for offtakers.

Buildout of solar has continued, driven by data center and industrial offtakers absorbing the cost re-rating. Many corporates are recalibrating expectations around the PPA rate, prioritizing reliability and time-of-day shaping even as the power purchase agreement cost rises. Solar PPA prices may be higher, but the need to hedge power exposure and decarbonize keeps demand resilient, particularly where commercial solar PPA pricing can align with on-site load profiles or flexible contract structures.

Wind tells a more cautious story: onshore construction has dropped well below prior-year levels amid permitting rollbacks and accelerated tax credit phaseouts, while offshore has been hit by a wave of project cancellations under the new administration. This makes NEE’s 0.5 GW of wind signings a relative outlier in an otherwise challenging development environment. By contrast, solar PPA rates and the average solar PPA price in 2026, while elevated, have found a firmer footing due to modularity, faster deployment, and the ability to pair with storage to enhance value—factors that support stable commercial solar PPA pricing even as overall power purchase agreement cost metrics rise.

This blog offers just a glimpse of the powerful analysis Energy Transition Research delivers on the trending themes. Don’t miss the full picture.

Get the Full Picture

Research Highlights:

  • Power and Renewables | Shifting to Stability: Reliability’s Growing Importance for the Grid – This report examines how rising power demand is colliding with interconnection delays, policy headwinds and supply chain constraints, driving independent system operators to fast-track dispatchable generation. We highlight shifting economics, surging gas valuations, renewable cost pressures and diverging trends in solar and battery storage markets. It also contextualizes how solar PPA prices and the PPA rate structure are evolving under these market forces.

  • The One Big Beautiful Bill Act (OBBBA) | LCOEs Without a Lifeline – We analyze how the removal of Inflation Reduction Act tax credits affects the levelized cost of energy for solar and onshore wind. The findings help explain upward pressure on commercial solar PPA pricing and why the power purchase agreement cost has increased across multiple regions.

  • Long-Term Capacity Expansion | The Three Eras of Capacity Growth – This report encompasses Enverus Intelligence® Research’s capacity expansion model for the Lower 48, based on forecast load, risked interconnection queues and technology cost curves. It illustrates how solar PPA prices, the average solar PPA price in 2026, and the PPA rate trajectory influence build decisions, particularly for data center and industrial offtakers sensitive to commercial solar PPA pricing.

What it means for buyers and developers: In today’s environment, the power purchase agreement cost is shaped by grid constraints, equipment pricing, and financing. Buyers should benchmark solar PPA rates against the average solar PPA price in 2026 and regional indices for commercial solar PPA pricing to ensure competitive terms. Developers, meanwhile, are structuring contracts with step-ups, indexation, and storage adders to manage risk while keeping the headline PPA rate attractive. These dynamics underpin resilient activity—even as solar PPA prices remain above prior‑cycle lows—because the value of reliability, price certainty, and decarbonization benefits often outweighs higher nominal costs.

DID YOU KNOW?

The amount of solar energy that reaches Earth’s surface in just 1.5 hours is enough to power all humanity’s energy consumption for an entire year.

Top 3 Takeaways

1. Are solar projects still moving forward despite weaker sentiment around renewables?

Yes. Solar development is continuing, as shown by NextEra signing 2.2 GW of new solar contracts in early 2026. Projects are still getting built, but buyers now have to accept higher prices than in the past.

2. What has changed in solar PPA pricing?

Solar PPA prices have reset higher. Prices today are roughly double their 2020 lows due to higher financing costs, equipment costs, interconnection challenges, and added risk premiums. This higher pricing now defines the average solar PPA price in 2026, especially in the commercial market.

3. Why does solar look more resilient than wind right now?

Solar remains attractive because it can be built faster, scaled more easily, and paired with battery storage to improve reliability and time-of-day value. Wind faces tougher permitting, fewer tax incentives, and more project cancellations, making solar the more dependable option even at higher PPA rates.

About Enverus Intelligence® | Research

Enverus Intelligence® | Research, Inc. (EIR) is a subsidiary of Enverus that publishes energy-sector research focused on the oil, natural gas, power and renewable industries. EIR publishes reports including asset and company valuations, resource assessments, technical evaluations, and macro-economic forecasts and helps make intelligent connections for energy industry participants, service companies, and capital providers worldwide. See additional disclosures here.

Enverus Press Release - Welcome to EVOLVE 2025: Where visionaries converge to shape the future of energy

Permian Basin: The Intervals Keep Coming 

People have been calling the top of the Permian for years. And yet, they keep having to walk it back. 

Our latest Permian inventory analysis from the Enverus Intelligence® Research (EIR) team shows why the basin continues to defy those calls. The Permian Basin Play Fundamentals report gives operators a detailed view of where inventory sits, who controls it, where it is expanding, and where hidden risks are quietly eroding future value. 

Every year for the last several years, roughly 6,000 Permian wells turn in line. Despite that pace, the economically viable location count has stayed roughly flat, because well costs keep falling and delineation keeps converting geologically viable locations into the economic tier. In other words, Permian Basin cost reductions and interval expansion are offsetting depletion. 

Economically viable Permian inventory grew approximately 10% year over year. Lower well costs and high-quality resource expansion into formations that were not on most operators’ radar five years ago are replacing what gets drilled each year. That dynamic is what makes the Permian Basin fundamentally different from every other oil play in North America. 

Scale no other basin can match 

The Permian now holds roughly 55,000 sub-$50-per-barrel economically viable locations, nearly double the combined total of the Eagle Ford, Williston, DJ, Anadarko, and Montney. 

Two forces drove that growth. First, well costs came in around 5% lower on a dollar-per-foot basis compared to last year’s analysis, shifting a meaningful number of $40 to $45 breakeven locations into the sub-$40 tier. Second, resource delineation stepped out materially, particularly in the northern Delaware, converting geologically viable inventory into economically viable inventory at scale. 

That conversion mechanism is the engine behind the Permian’s self-replenishing character, and it is not something the Eagle Ford or DJ can replicate. 

When a geologically viable resource is included, total undeveloped inventory approaches 100,000 locations. That adds 42% to location count and 29% to oil resource. More than 60% of that additional resource sits in emerging deep zones, with the Barnett-Woodford and Wolfcamp D as the primary contributors in both the Delaware and Midland. 

Figure 1: North American and Vaca Muerta Oil-Directed Cost Curves | Source: EIR

The majors hold 70%, but the remaining 30% is in play 

The top five public operators control approximately 70% of high-quality net inventory across the basin. Consolidation over the past five years has made the inventory distribution top heavy, meaning future M&A activity is increasingly driven by public-to-public corporate consolidation. 

Private operators now hold just 16% of sub$50 breakeven inventory, with roughly 7% tied to family-owned companies. Our analysis identifies specific acquisition targets in both the Delaware and Midland that screen well on remaining inventory quality and count, some with more than 100 high quality locations at competitive break-evens. At current development pace, that represents real runway for a buyer. 

Inventory life: the Permian’s structural advantage 

Combined, the Delaware and Midland hold roughly 11 years of sub$50 per barrel runway at current development cadence. 

One driver that matters more than many appreciate is the Known Potash Leasing Area in New Mexico. Historically, the KPLA blocked development across large portions of northern Delaware acreage, with permitting regularly denied due to conflicts with potash mining. 

That friction is now largely resolved. Operators have struck agreements with mining companies, and extended reach laterals have changed the equation. Development that would have stranded a one-mile lateral can now be cleared with laterals exceeding four miles. The result is a large, relatively undeveloped area of the northern Delaware that has re-entered the economic inventory set and materially contributes to this year’s inventory gains. 

The Barnett-Woodford: the largest expansion opportunity in the Lower 48 

The Midland Basin Barnett-Woodford stands out as the biggest expansion story in this year’s analysis. We track more than 6,000 combined economically and geologically viable locations in this interval, making it the largest oil-directed expansion opportunity in the contiguous United States. 

Well performance exceeded the broader Midland average by more than 30% in 2025. At roughly $800 per foot well costs, break-evens converge with primary Wolfcamp targets in the low $40s. 

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The geological framework explains why this interval works. In the Midland core, Lower Mississippian thickness is typically absent, meaning the Barnett and Woodford effectively merge into a single reservoir and are developed as one flow unit. Further north, where the Lower Mississippian is present, the zones can be separated and landed individually, although the Woodford tends to be thinner and adds limited incremental upside on its own. 

In the Delaware, the story is different. Oil-directed Woodford development is constrained to a narrow fairway where preserved thickness, structure, faulting, and liquids-rich maturity align. Basin-ward, the Woodford quickly becomes overmature and gas prone. Platform-ward, it is immature and lacks sufficient pressure to deliver economic results. Full-section pilots within that narrow corridor have demonstrated sub$40 breakeven potential. 

Lease terms add urgency. Approximately 420 Barnett-Woodford locations sit on leases with depth clauses and primary term expirations through early 2028. For operators exposed to those rights, the development clock is already running. 

Depletion risk is real, and not evenly distributed 

In the Delaware, the Lower Wolfcamp accounts for nearly 20% of remaining locations, but more than half of that inventory carries lagged development risk from overlying Upper Wolfcamp depletion. 

Carbonate barriers play a critical role. In the northern Delaware, cemented carbonate layers limit communication between zones and help protect Lower Wolfcamp performance. In the southern and western Delaware, those barriers are largely absent, increasing depletion exposure. 

In the Midland, Spraberry zones are particularly sensitive to Wolfcamp depletion across the Central subplay. Lower Spraberry recoveries can effectively halve once cumulative parent recovery crosses roughly two million barrels per acre, pushing break-evens from the low $40s into the mid $50s or worse. 

The takeaway is simple. Inventory quality is inseparable from development sequencing. Full interval development that targets multiple zones simultaneously produces materially better outcomes in areas with high depletion sensitivity. 

The Yeso offers the best break-evens in North America, for unexpected reasons 

The Yeso formation on the Northwest Shelf leads all North American oil plays on average breakeven economics, at roughly $39 per barrel over the past two years. That is lower than both the Delaware and Midland. 

Why the Yeso works economically 

The Yeso is not a shale resource play. It is semi-conventional and sits at shallow depths of roughly 2,500 to 5,500 feet on the New Mexico Shelf. While the area has a long history of vertical production from carbonate platform rocks, lower historical recoveries left substantial oil in place. 

Operators are now targeting that oil with horizontal infill wells in conventional and semi-conventional facies. Shallow depth, high liquids yield, lower completion intensity, and strong productivity combine to deliver very low break-evens. Subsurface variability and reservoir heterogeneity remain real risks, meaning performance is not uniform across the play. 

The Central subplay drives most of the outperformance, with break-evens as low as $32 per barrel on recent wells. REPX and Spur Energy control the majority of remaining inventory, each holding close to 200 sub-$50 locations and more than a decade of development runway at current pace. 

Figure 2: Yeso Subplays and Recent Horizontal Development | Source: EIR

Associated gas: the infrastructure question operators need to answer now 

Permian oil development is inseparable from gas. Our analysis projects 6.9 Bcf per day of associated gas growth by 2030, even with no increase in gas-directed drilling. 

Western Delaware and southern Midland acreage are the most gas price sensitive. At zero-dollar gas, several Lower Wolfcamp intervals generate negative net present value. At $2 gas, they flip positive. Realized gas price is no longer a macro assumption. It is a core economic input that belongs directly in development models. 

Alpine High is also showing renewed interest as a standalone gas story. Recent programs delivered the largest Permian gas EURs in several years, and at $3 to $4 gas, returns are competitive with the Haynesville. 

What to do next 

The Permian has not plateaued. It continues to unlock new intervals, new acreage, and new cost efficiencies. 

Operators who understand which zones are converting from geologically viable to economically viable, which acreage carries hidden depletion exposure, and which private positions represent real acquisition value will make better capital decisions than those working from a static inventory picture. 

EIR covers this analysis in depth, operator by operator and interval by interval. If you want to understand how your acreage stacks up on inventory quality, depletion exposure, and acquisition value, talk with our team. 

About Enverus Intelligence® | Research

Enverus Intelligence® | Research, Inc. (EIR) is a subsidiary of Enverus that publishes energy-sector research focused on the oil, natural gas, power and renewable industries. EIR publishes reports including asset and company valuations, resource assessments, technical evaluations, and macro-economic forecasts and helps make intelligent connections for energy industry participants, service companies, and capital providers worldwide. See additional disclosures here.

Carbon storage in question: Illinois regulation could threaten key CCUS projects

Four Signals the Power Market Sent at S&P Global 

The S&P Global Commodities conference in Las Vegas brought together investors, developers, utilities, and hyperscalers at an inflection point for the power sector. Four themes dominated the conversation. Each one is directionally right. Each one is also commercially incomplete. Here’s what the conference said, and the nuances our analysts think were missed. 

Gas Development M&A: Gas Is Back — But Buyers Want Cash Flow, Not Risk

New gas capacity is actively coming online in ERCOT, and the market is taking notice. As incremental supply builds, participants widely expect power curves to improve and stabilize — welcome relief after years of volatility. 

But M&A activity tells a more selective story. Consolidation is happening, yet buyers are overwhelmingly focused on operating assets. Greenfield development is being passed over in favor of de-risked, cash-flowing positions. The risk appetite that once fueled new-build speculation has cooled considerably. 

Buyers are prioritizing assets that are already generating — the market has decisively shifted toward capital efficiency over growth-at-any-cost.

What Was Missed

Capital has moved toward operating assets, but the valuations being paid are pushing close enough to new-build costs that the greenfield math changes. Enverus Intelligence® Research (EIR) priced Blackstone’s Hill Top acquisition at an implied 12.2% WACC. When operating multiples get this close to new-build costs, the greenfield math starts working again — especially for a future resale to a public IPP. 

The purchase price equates to a multiple of ~$1.6 million/MW, representing a premium to recent gas generation M&A, approaching the estimated cost of new-build gas generation of ~$2-$3 million/MW.

– Blackstone Strikes Again | Plugging Into PJM’s Load Growth Deal Insight | September 24, 2025 

What This Means 

For developers, the operating-asset premium is a signal — not a barrier. With multiples approaching new-build costs, greenfield projects with a credible operational path are increasingly attractive to institutional capital positioning for IPP resale. For utilities, this compression creates asymmetric opportunity: acquire now at private-equity multiples, or hold assets that re-rate to public-IPP valuations as load growth materializes. 

Nuclear & Hyperscaler Strategy: Hyperscalers Are Underwriting Nuclear — For 15 Years 

Nuclear M&A is accelerating, and hyperscalers are the engine behind it. What has changed is conviction: the largest technology companies are no longer approaching nuclear cautiously — they are leaning in hard, driven by carbon commitments and mounting regulatory pressure. 

Through 10–15 year nuclear PPAs, hyperscalers are effectively locking in stable, carbon-free power while completely sidestepping gas price volatility over that horizon. It is less a power procurement strategy and more a long-term hedge against regulatory and commodity risk. 

What Was Missed

The premium hyperscalers pay for nuclear has grown 73% in two years. EIR priced every public deal: Susquehanna at $65/MWh, Comanche Peak at $90, Crane Clean Energy Center at $101. Uplifts to forward LMP run $22–$49/MWh across the six disclosed agreements. The “hyperscalers want nuclear” headline is directionally right. The commercial detail is in what each hyperscaler has paid, which plants are already under contract, and where pricing power sits going forward. 

CEG, TLN and VST have signed significant offtake agreements for their nuclear facilities, with an average price premium of $34/MWh above zonal forwards at date of signing.

– Gone Fission | Nuclear PPA Comp Sheet Research | March 24, 2026 

What This Means

For utilities with nuclear assets, this is a pricing event, not just a demand event. The $34/MWh average premium establishes a floor on what sophisticated off-takers will pay, and the 73% growth in willingness-to-pay since March 2024 signals the premium is still expanding. For developers, hyperscaler off-take terms are now a prerequisite for financing conversations — know which plants are contracted, which have capacity available, and what each hyperscaler has been willing to sign. 

Investment Criteria Shifts: IRR Is the New Baseload

The old framework of ‘baseload good, variable bad’ is no longer the primary lens investors use. The conversation at S&P Global made clear that IRR, contract structure, and asset durability have overtaken traditional generation classifications as the dominant investment criteria. 

Investors are less interested in what type of asset it is and more interested in whether it delivers the return profile they need — with defensible contracts and a durable operating life.

This shift creates opportunity for well-structured renewable and storage projects that previously struggled against baseload comparisons, while simultaneously raising the bar for anything that looks speculative or contractually exposed. 

What Was Missed

IRR is a relative-value framework, not a market direction. The shift from “baseload good, variable bad” to IRR-and-contract-structure is real, but the same lens produces very different answers across the IPP universe. EIR ran the NAV on all five publicly-traded IPPs and found meaningful dispersion — some names trade at discounts to intrinsic value, others at premiums, with the gap driven by contract quality, capital cost exposure, and regulatory risk. The “IRR over baseload” framing is the right instinct. The discipline it requires is knowing which multiples, discount rates, and contract structures actually justify the valuation. 

Recent PJM load forecast revisions and rising behind-the-meter data center development have put downward pressure on IPP stock prices, creating differentiated opportunities across names.

– IPP NAV Compass | Underappreciated PPA Upside Research | February 23, 2026 

What This Means

For developers, contract quality isn’t a nice-to-have — it sets whether your project clears institutional return thresholds. For utilities and asset owners, the sector’s NAV dispersion is the actionable signal: durable cash flows and defensible contracts are being rewarded, while exposure to capital cost inflation and regulatory reform is being discounted. The acquisition and divestiture windows look very different depending on where in the dispersion your assets sit. 

Data Center Growth & M&A Impact: Cheap Gas Wins the Data Center Race 

Data center demand is no longer just a load growth story — it is becoming an ownership story. Hyperscalers are increasingly recognizing the value of controlling more of their own energy development pipeline, and they are entering the M&A market to do it. This is introducing a new class of buyers — some highly disciplined, others willing to pay prices that challenge conventional underwriting logic. 

But the most consistent signal from the conference was geographic: the next wave of data center development will concentrate where natural gas prices are lowest. Hyperscalers are acutely cost-focused, and cheap gas today is widely expected to translate directly into data center construction over the next five years. 

Regions with the lowest natural gas prices are not just attractive for power generation — they are likely to become the physical home of the AI economy.

What Was Missed

Cheap gas isn’t driving data centers into the Permian — it’s driving E&P operators into ERCOT. Waha averaged minus $6.83/MMBtu the week of April 14, 2026. The commercial response isn’t hyperscaler siting — it’s E&P operators monetizing stranded gas by building merchant generation into ERCOT. Riley Permian’s JV with Conduit Power is deploying four sub-10MW sites through ERCOT’s small generation queue. Continental and Mercuria announced a 452MW project in Pecos County converting ~80 MMcf/d of associated gas into power. The model is gas monetization, not data center attraction. 

Permian gas is sometimes so cheap (or negative) that the normal relationship between fuel cost, efficiency, and dispatch breaks down, resulting in a small generator fleet that may look like peaker plants but are dispatched more like baseload power plants.

– Think ERCOT, Not Waha | April 23, 2026 

What This Means

For utilities in the Permian and adjacent ERCOT zones, the near-term load growth isn’t coming from hyperscalers — it’s coming from E&P operators building behind-the-meter generation and selling into the grid. For developers, the hyperscaler siting conversation and the cheap-gas conversation are two different trades; don’t confuse the basis differential with the data center map. 

See Where These Trends Hit Your Markets 

Enverus tracks gas price dynamics, interconnect queue positioning, and hyperscaler demand signals across every major market. Reach out to our Enverus Intelligence® Research team to see how these shifts affect your specific territory, portfolio, or pipeline. 

About Enverus Intelligence® | Research

Enverus Intelligence® | Research, Inc. (EIR) is a subsidiary of Enverus that publishes energy-sector research focused on the oil, natural gas, power and renewable industries. EIR publishes reports including asset and company valuations, resource assessments, technical evaluations, and macro-economic forecasts and helps make intelligent connections for energy industry participants, service companies, and capital providers worldwide. See additional disclosures here.

Enverus Press Release - Decoding CCUS project success

EV Lines Meet the Grid | LG Energy and Samsung SDI Pivot to Grid Storage

Impact of IRA credits on manufacturing cost in battery cell
Source | Enverus Intelligence Research, Bloomberg

South Korea’s leading battery makers are redirecting U.S. capacity toward the grid. As EV demand cools and the market for battery energy storage systems (BESS) accelerates, LG Energy Solution and Samsung SDI are shifting capital, product strategy and manufacturing lines toward stationary grid energy storage. LG has already started large-scale battery cell production for grid applications, targeting grid scale battery storage projects that support renewable energy storage solutions. Samsung SDI is preparing to convert part of its Indiana capacity for BESS production and has secured cathode supply to support its North American storage buildout. The common theme is clear: grid energy storage is emerging as the most credible outlet for underused EV battery capacity, and grid scale battery storage is becoming a core pillar of renewable energy storage solutions in the U.S. power mix.

Tariffs are raising the cost of imported battery supplies just as developers become more selective in their sourcing. Enverus Intelligence® Research (EIR) shows imported battery cell costs increasing from $95.00/kWh to $104.50/kWh after tariffs (Figure 1), reinforcing the case for U.S.-based manufacturing of battery energy storage systems and other grid energy storage hardware. With much of the clean energy supply chain still tied to China, non-Chinese battery majors have an opportunity to localize component manufacturing, reduce foreign-entity-of-concern exposure and capture market share in a more restrictive procurement environment. For developers, domestic grid scale battery storage capacity can help de-risk project timelines, while also aligning with IRA-driven content rules and long-term strategies for renewable energy storage solutions.

The next risk is not under-building supply but overshooting near-term demand. EIR suggests the risk is real. We expect renewable installations to peak in 2028 as developers rush to capture remaining policy support, with batteries growing in tandem to support grid reliability and to underpin renewable energy storage solutions across major markets. Battery energy storage systems deployed at utility scale will be essential to firm intermittent wind and solar, but the buildout of grid energy storage may be more front-loaded than many capacity plans assume. Growth in grid scale battery storage doesn’t disappear after 2028, but it becomes less straightforward as policy support steps down and interconnection queues, market design and local transmission constraints increasingly shape project economics.

For LG Energy Solution and Samsung SDI, the pivot toward stationary storage is therefore a race to capture the most attractive tranche of near-term demand. Both companies are aligning their battery energy storage systems with U.S. grid needs, emphasizing safety, duration and cost per kWh for grid scale battery storage projects. As more ISO markets introduce capacity accreditation frameworks for storage and as hybrid solar-plus-storage plants become the default in new-build renewables, the role of grid energy storage in balancing supply and demand will expand. Yet, battery makers must calibrate manufacturing expansions carefully to avoid a glut of BESS inventory if renewable additions slow after the policy-driven peak.

In our view, the most resilient opportunities lie in applications where grid energy storage is indispensable: ramping support for high-solar systems, frequency regulation, capacity resource adequacy and black-start capabilities. These use cases are best served by flexible, modular battery energy storage systems that can be deployed at substation scale and integrated into broader renewable energy storage solutions. LG and Samsung’s moves to retool EV lines for grid scale battery storage signal that the industry sees this shift clearly. The challenge now is sequencing investment to match the actual adoption curve for grid energy storage rather than a straight-line extrapolation of today’s project pipeline.

This blog offers just a glimpse of the powerful analysis Energy Transition Research delivers on the trending themes. Don’t miss the full picture.

Get the Full Picture

Research Highlights:

  • RIN Repricing – RVO Finalization and Iran War Reshape Returns – EIR analyzes the impact of finalized 2026-27 renewable volume obligations (RVOs) and the Iran war on renewable identification number prices and renewable fuel returns. We also examine how refiner RVO exposure has shifted and what it means for margins.

  • Ethanol With CCS – Rail Gains Momentum as Summit Stalls – We examine the opportunity to integrate CCS into ethanol facilities, highlighting optimized economic pathways, strategies to mitigate execution risk and the potential for additional revenue through carbon dioxide removal credits.

DID YOU KNOW?

Wind turbines now routinely exceed 15 MW or more, enough to power thousands of homes. Installing them requires specialized heavy-lift vessels up to 175 meters (about 575 feet) long.

Top 3 Takeaways

1. Why are major EV battery makers shifting toward grid storage?

As electric vehicle demand cools, LG Energy Solution and Samsung SDI are redirecting underused EV battery capacity to grid-scale storage. Grid energy storage is growing quickly as utilities add more wind and solar and need batteries to keep the grid reliable. For battery makers, stationary storage is now the most credible near-term use for excess EV manufacturing capacity.

2. How do tariffs and supply chain risks factor into this shift?

Tariffs are raising the cost of imported battery cells, strengthening the case for U.S.-based battery manufacturing. Domestic production helps developers reduce project risk, comply with IRA content rules, and avoid reliance on Chinese supply chains. This creates a competitive opening for non-Chinese battery makers to localize production and win market share in U.S. grid storage projects.

3. What is the biggest risk facing the grid storage buildout?

The main risk is building too much capacity too fast. Renewable and battery installations are expected to peak around 2028 as policy support drives near-term demand, then become more constrained by grid interconnection, transmission limits, and market rules. Battery makers that pace investment carefully and focus on essential grid use cases like reliability, capacity, and grid support are best positioned to avoid oversupply.

About Enverus Intelligence® | Research

Enverus Intelligence® | Research, Inc. (EIR) is a subsidiary of Enverus that publishes energy-sector research focused on the oil, natural gas, power and renewable industries. EIR publishes reports including asset and company valuations, resource assessments, technical evaluations, and macro-economic forecasts and helps make intelligent connections for energy industry participants, service companies, and capital providers worldwide. See additional disclosures here.

Enverus Press Release - Looking past the CCUS power plant pipe dream

The Week in Energy – April 24, 2026

This week’s energy headlines spotlight offshore services consolidation, continued privatecapital rotation in midstream, renewed fundraising momentum, a return to the Gulf of Mexico, and shifting policy signals for carbon management. Here are five stories that stood out: 

Top Stories 

  • Helix & Hornbeck to merge, uniting well intervention with OSVs 
    Helix Energy Solutions and Hornbeck Offshore agreed to merge in an all-stock transaction that brings together Helix’s well intervention and robotics capabilities with Hornbeck’s offshore support vessel fleet. The combination creates a more diversified deepwater services platform with nearly $2 billion in pro forma revenue and a strengthened balance sheet positioned for a longer offshore up-cycle. 

  • KKR sells stake in Pembina processing JV to Apollo Funds 
    KKR agreed to sell its 40% interest in Pembina Gas Infrastructure to funds managed by Apollo, reshaping a major Western Canadian gas processing and gathering platform. The business serves the Montney and Duvernay and operates roughly 5 Bcf/d of processing capacity, underscoring continued private capital interest in scaled gas infrastructure tied to longcycle supply. 

  • EIV raises $1.1B for new midstream and nonop E&P funds 
    EIV Capital announced the final close of two new funds totaling about $1.1 billion, targeting U.S. midstream investments and non-operated upstream working interests. The raise reflects renewed investor appetite for infrastructure-linked strategies offering durable cash flows and lower capital intensity.  

  • Talos founder Duncan returns to U.S. GOM with 1947 Oil & Gas 
    Talos Energy founder Tim Duncan is reentering the Gulf of Mexico through newly formed 1947 Oil & Gas, which is acquiring Renaissance Offshore. The move signals continued private backing for mature shallow-water assets offering near-term cash flow and development optionality. 

  • DOE reverses course, restores DAC hubs in Texas and Louisiana 
    The Department of Energy restored federal funding for two flagship direct-air-capture hubs in Texas and Louisiana after previously pausing support. The decision removes near-term uncertainty for large-scale DAC deployment, though longer-term funding and commercialization questions remain. 

Additional Stories

Also this week: Crescent Energy shifted toward steady-state development, EQT flagged faster-than-expected data-center-driven gas demand, Halliburton sees a rebound in North American completions, and BrightNight gained full control of six gigawatts of renewable projects. 

To learn more, reach out to businessdevelopment@enverus.com or visit www.enverus.com. 

Shell strikes C$22 billion deal for Arc Resources

Shell strikes C$22 billion deal for Arc Resources

After a break from strategic deal making since October 2023, one of the supermajors has a significant acquisition in hand with Shell’s purchase of Montney producer Arc Resources for $22 billion (US$16.4 billion). The acquisition boosts Shell from the seventh-largest producer in the Montney, based on gross operated volumes, to second place trailing only Ovtintiv. The premium screens relatively attractive for Arc shareholders, particularly compared to the sub-20% premiums generally offered in U.S. corporate consolidation. That reflects the relative value of Canadian producers in the market, and of Arc in particular, with the company screening attractive relative to peers on valuation. That follows a period of relative underperformance over the last year that makes timing advantages for Shell even with the premium.

The lack of strategic acquisitions recently by supermajors, or since Chevron agreed to purchase Hess in October 2023, reflects a global oil and gas industry with a dearth of attractive, long-duration resource. Within a global framework, Canada represents one of the most attractive opportunities with duration of high-quality resource for both gas in the Montney and crude in the oil sands. For Shell, with a large focus on an integrated global gas business, targeting the Montney makes sense and is a firm confirmation of the prolific play’s competitive position in the global gas landscape. The commencement of shipments from LNG Canada, where Shell holds a 40% stake, is key in helping debottleneck Montney gas and an important strategic component of the deal for Shell. Arc’s assets will be absorbed into Shell’s integrated gas division. The acquisition, plus a global disruption in LNG supply from the Iran conflict, supports the case for a positive FID on LNG Canada Phase 2. While sourcing LNG feedgas looks to be a key strategic rationale for the transaction, the 40% liquids production, which generated 70% of 2025 revenues, also provides in-demand condensate for use as diluent for oil sands production.

Duration of high-quality resource, or lack thereof, is a key concern for the industry and where a Montney acquisition provides a critical competitive advantage. The Montney leads all non-oil sands plays in North America for drilling longevity, albeit at a significantly less active development cadence than the Permian. Following this acquisition, Shell will have the second highest net inventory count in the play, trailing only Canadian Natural Resources.

The transaction is the largest purchase for Shell since it acquired BG for $82 billion more than a decade ago. It represents a further commitment to the company’s hydrocarbon business, particularly integrated gas, at a time the world is facing severe energy supply disruptions from the conflict in the Middle East. LNG Canada Phase 2 provides the potential for additional value realization from the position that would move pricing from 40% AECO and 60% international pricing to 80% international exposure. LNG Canada is geographically advantaged for shipping LNG to Asian markets that gives it a competitive edge over U.S. Gulf Coast competitors.

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About Enverus Intelligence® Research
Enverus Intelligence ® | Research, Inc. (EIR) is a subsidiary of Enverus that publishes energy-sector research focused on the oil, natural gas, power and renewable industries. EIR publishes reports including asset and company valuations, resource assessments, technical evaluations and macro-economic forecasts; and helps make intelligent connections for energy industry participants, service companies and capital providers worldwide. Enverus is the most trusted, energy-dedicated SaaS company, with a platform built to create value from generative AI, offering real-time access to analytics, insights and benchmark cost and revenue data sourced from our partnerships to 95% of U.S. energy producers, and more than 40,000 suppliers. Learn more at Enverus.com.

Enverus Press Release - Alternative fuels M&A focus turns from policy boosts to business resilience

AI Needs Context: Why Invoice-Only AI Isn’t Enough

This is the fourth installment in our series of blog articles dealing with source-to-pay and upstream oil and gas. Read the previous blog here.  

Artificial intelligence is quickly becoming a priority for finance and procurement teams. The value is clear. Faster processing, less manual work, and better visibility into spend.

Most organizations are starting to roll out much of their AI software in their accounts payable departments, and that makes sense. Invoices are structured, consistent, and already central to financial workflows. Applying AI here can definitely drive real efficiency gains.

But even with those improvements, things can still go wrong.

Disputes continue. Price mismatches still show up. Budget surprises still appear late in the cycle, when there is little time to react. So, AI is helping, but it’s not changing outcomes in a meaningful way.

That gap comes down to one thing: context.

Decorative stock image of Source-to-Pay
AI can process invoices faster, but it can’t change outcomes on its own. Real impact comes from the context created upstream in Source-to-Pay.

Key takeaways

Why does invoice-only AI struggle to deliver full value?

  • Because invoices reflect decisions made upstream, AI lacks the context needed to understand or prevent issues.

What limits the effectiveness of AI in finance workflows?

  • AI is only as effective as the data it can access. Invoice data alone is often incomplete.

Why are organizations expanding AI into Source-to-Pay?

  • Because connected data across pricing, orders, execution, and invoicing gives AI the context needed to improve outcomes.

AI in Accounts Payable Has Limits

My introduction to the subject aside, AI in accounts payable is delivering real value. It can extract data, automate workflows, and flag inconsistencies faster than manual processes ever could.

At the invoice level, AI can:

  • Improve processing speed
  • Reduce manual effort
  • Extract and structure data from documents
  • Identify potential mismatches or duplicates

These are meaningful improvements, especially for companies dealing with high volumes of invoices.

That said, the limitations of this system tend to show up pretty quickly. For instance:

  • AI can identify a price mismatch, but it can’t see the agreement behind it.
  • It can flag unapproved work, but it does not know how that work was initiated.
  • It can detect anomalies, but it lacks the full picture needed to explain them.

In other words, it’s working with the final output of a process, not the decisions that created it.

Invoices Are Incomplete Signals

Invoices are important, but they only tell part of the story. Before an invoice is created, a series of decisions have already taken place:

  • Suppliers have been selected and pricing agreements have been established
  • Purchase orders and approvals have been made
  • Field execution and work verification has occurred
  • Delivery of materials and services have taken place

By the time an invoice arrives, those decisions are already locked in.

AI applied at this stage is inherently reactive. It can help process what has already happened, but it cannot influence the decisions that shaped the outcome.

That is why invoices function as late-stage signals. They only show what happened, but not why it happened.

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Why AI in Procurement Needs More Context

When AI falls short, the immediate reaction is often to feed it more data. More invoices, more transaction history, or more examples in hope that volume alone will resolve the issue.

But while that can improve pattern recognition, it doesn’t actually solve the core issue.

This is because AI doesn’t just need more data. It actually needs connected data.

So, if the system only sees invoices, it will continue to operate within that boundary. It may get better at spotting patterns, but it will still lack the context behind them.

Context changes everything – when AI has visibility into pricing, orders, and execution, it can begin to understand how decisions flow through the system. It can connect cause and effect, not just identify outcomes.

This is where the shift becomes clear, and context carries more weight than volume.

How Source-to-Pay Platforms Improve AI Outcomes

This is where a full source-to-pay approach becomes critical. Instead of applying AI to a single step, organizations are beginning to apply it across the full lifecycle of spend. That includes:

When these elements are connected, AI can operate with far greater context.

It can:

  • Detect issues earlier in the process
  • Connect upstream decisions to financial outcomes
  • Surface risks before they reach accounts payable
  • Guide users toward better decisions as work is happening

This is a fundamentally different model than the one I was talking about at the start of the article. Instead of reacting to issues at the end of the process, organizations can start addressing them much earlier.

From Workflow Automation to Continuous Intelligence

There is also a shift happening in how AI fits into daily work.

Traditional workflows are task-based. Teams move step by step, often reacting to issues as they appear. AI has typically been used to automate parts of that process.

What’s emerging now is a lot more dynamic.

Rather than simply automating tasks, AI is now beginning to act as a continuous layer across the workflow, analyzing activity and surfacing what actually matters in time to make measurable improvements. Instead of searching for problems, teams are increasingly being presented with the signals that need attention.

This might include:

  • Pricing deviations before invoices are submitted
  • Work that does not align with approved scope
  • Spend patterns that could impact budgets

The focus moves away from processing tasks and toward managing outcomes.

What This Means for Finance and IT Leaders

For executives and IT leaders, this is not just about adopting AI. It is about applying it in a way that actually improves control and predictability.

Point solutions (tools that solve a single, specific problem) can deliver efficiency gains, but they rarely change financial outcomes in a meaningful way. The underlying issues still remain, because they originate outside the scope of those tools.

A platform-first approach aligns AI with how the business actually operates. It connects systems, improves data quality, and creates a stronger foundation for decision-making.

It also makes future AI investments more effective, since new capabilities can build on a connected system rather than being layered on top of fragmented workflows.

AI in Source-to-Pay Starts with Context

AI will continue to expand across finance and procurement. The question is not whether to adopt it, but how.

Starting with invoices is a logical first step. It is visible, structured, and relatively easy to implement. But it is only one part of a much larger system.

The real opportunity lies in applying AI across the full Source-to-Pay lifecycle, where decisions are made and outcomes are shaped.

When that context is in place, AI becomes more than a tool for automation. It becomes a way to improve how decisions are made, how risks are managed, and how financial outcomes are achieved.

Want to learn more?

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