Permian Energy Dialogues

• What price assumptions and market signals are guiding drilling and development plans?
• How are companies thinking about inventory quality and pacing development as the basin matures?
• Inventory considerations: as Tier 1 inventory continues to consolidate, how are operators assessing the long-term depth, quality, and durability of the Permian?
• How do efficiency gains and longer laterals impact the direction operators take?
• What role is consolidation and scale playing in improving capital efficiency and operational performance?
• What is the role of smaller, independent producers in identifying new inventory and how does size matter?
• Are water and power requirements now becoming as important to long-term output as subsurface quality and access to capital?

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• Where are the most impactful opportunities for collaboration and coordination across agencies, and how can they better enable infrastructure buildout, permitting speed and operational planning?
• How are fragmented federal and state approaches to permitting, water oversight, and environmental enforcement affecting project development and investment planning in the Permian?
• How is the regulatory treatment of produced water disposal, reuse, surface discharge, and cross-border transfers shaping the next phase of water infrastructure in the Permian?
• As power demand rises from electrification, data centers, and industrial growth, what regulatory alignment or policy clarity is most needed to support infrastructure buildout?
• How are differences between Texas and New Mexico impacting operator decisions across the basin?

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• Where does closer coordination with federal agencies and fellow state agencies unlock the most gains in permitting speed and infrastructure buildout?
• Where are there still challenges and misalignments?
• How is RRC evolving its approach to produced water disposal, reuse, and surface discharge permitting, and what’s needed on cross-border transfers with New Mexico?
• As power demand climbs, what are the regulatory/permitting priorities to ensure gas supply and pipeline infrastructure can expand at the pace required?

• The Water Reuse Action Plan 2.0 includes produced water as a reuse source and explores regulatory flexibility for industrial cooling, mineral extraction, and agriculture. What options are being explored?
• What federal effluent and monitoring standards is EPA setting?
• Who holds ownership, liability, and stewardship for produced water once it is treated and transferred?
• How is EPA coordinating with states?

• SB 1145 consolidates regulatory authority over produced water at TCEQ.
• What end uses will TCEQ authorize, and what stays with the RRC?
• What’s the hardest part of standing up this new lane: the science, the politics, or public trust? How will TCEQ allocate financial assurance and long-term liability once water is treated and transferred?
• Where do the proposed rules stand today, and what still needs to be resolved on the technical, policy, and public acceptance fronts before adoption?
• How do you see that permitting pathway evolving into 2027?

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• Produced water handling, reuse, desalination and disposal – what progress and solutions are we seeing? Which non-discharge uses look most realistic today?
• What is the intersection of water needs with energy development and future data center demand? Where can broader collaborations help? What industries – other than energy – should join the dialogue?
• How can industry, investors, and policy makers accelerate alternative solutions while maintaining the disposal backbone? What is the potential for cost reduction through technology advancement, and repeatable project economics?
• What kind of commercial structure, infrastructure, and policy support is still missing if reuse is going to move beyond pilots and become part of the basin’s water strategy?
• What is needed to move non-discharge reuse to beyond pilots and into broader commercial use? Technology, policy, economics, social.

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• Will improved takeaway and growing global demand unlock more gas-focused drilling, or does volatility deter development?
• What investments do we see to connect Permian gas to LNG and other markets?
• How are changing gas composition and quality requirements (especially lower nitrogen content) influencing development and midstream investment decisions in the basin? Are there opportunities to optimize and scale nitrogen removal and gas processing solutions to meet stricter feedgas specs and preferred buyer criteria?
• How are producers thinking about lower carbon intensity, certification, measurement, and the role of frameworks like OGMP 2.0 and MiQ? Where is the market headed and is the EU Methane Regulation influencing that market? How is the balance of sustainability, affordability and reliability evolving across markets?
• How are takeaway constraints, flaring limits, midstream buildout, and processing capacity affecting the basin’s trajectory and competitiveness?

• What does good early engagement look like? What are the top priorities for communities and landowners in the Permian? Where and how can we find alignment and common solutions?
• What common challenges are operators and infrastructure developers now running into around land, water, power, permitting, and community response, and where could more alignment help?
• What have we learnt from landowner disputes, litigation risk, and local opposition groups when it comes to project timing, cost, and execution for energy and digital infrastructure? What else can be done to optimize outcomes?

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• As load growth keeps rising, how are companies thinking about what the Permian power system can realistically support over the next five years?
• How much relief can the Permian Basin Reliability Plan provide, and where do the biggest reliability risks sit before that new capacity is in place?
• What are operators and midstream companies seeing on the ground today around transmission, curtailment risk, and power reliability, and what’s the operational impact?
• What prevents dispatchable generation from keeping pace with demand, and where will additional firm power come from?
• How different are the power outlooks in Texas and New Mexico. How do differences in market structure, regulation, and transmission planning affect development?

• What continues to drive consolidation across E&Ps, midstream and minerals and how are investors thinking about asset quality and inventory depth?
• As more international capital and institutional money comes into U.S. upstream and related infrastructure, how is competition for Permian positions changing?
• Water, power, midstream, data center-related infrastructure, and other verticals: Where is new capital going beyond traditional upstream?
• How much are policy risks and the differences between Texas and New Mexico starting to shape where capital gets deployed?
• How durable does the investment case look if prices soften, and how are investors and operators stress-testing longer-term bets against lower oil, cost pressure, and maturity? What does the picture look like in a sustained high-price oil environment?

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• Where are operators actually seeing returns from AI, automation, and digital tools today?
• How much can technology still do to improve recovery, completion performance, and asset life as more of the basin moves beyond Tier 1 inventory?
• What role are oilfield service companies and technology firms playing in adoption, and who is driving implementation on the ground?
• How much are workforce shortages and value-chain disruptions slowing the rollout of technologies that already exist?
• How are operators deciding which digital tools are worth scaling versus which ones remain experimental?

• As power demand keeps rising from electrification, gas processing, data centers, and other large loads, how important are behind-the-meter and self-supplied generation becoming in the Permian?
• What problems do behind-the-meter and bring-your-own-generation models solve for E&Ps, midstream companies, and data center projects? What still depends on grid interconnection, backup, and system stability?
• What role could geothermal, gas+CCS, or small modular nuclear realistically play in meeting long-term power demand in the Permian? How comfortable can hyperscalers get with gas solutions?
• What kinds of self-supplied or co-located power models are financeable today, and how much depends on customer commitments, load certainty, emissions requirements, and project scale?
• How are E&Ps, infrastructure developers, and large power users weighing reliability, cost, emissions, permitting, and equipment lead times when deciding between grid power, gas-fired generation, and other emerging solutions?

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• Are midstream companies, EPCs, and infrastructure developers running into bottlenecks across power, water, gas, and industrial buildout?
• How much are supply chain pressures around transformers, turbines, compressors, steel, and other critical inputs starting to affect timing, sequencing, and cost?
• What part of the delivery chain is most likely to fall behind first over the next few years: labor, equipment, permitting, or coordination?
• As infrastructure needs become more interconnected, who is taking the lead on execution and where can better coordination speed up delivery?