Phillip Jungwirth

What is the appetite or value-creation opportunity to add to this liquids-rich position where others might not have the same technical understanding

You reached an agreement with Western Gas during the quarter to restructure Delaware gas contracts

I was hoping you can talk to how this improves ROCE by the end of the decade

Curious if you've looked at lightweight proppant, something -- is this something you'd consider implementing within your Delaware development?

I wanted to come back to some of the major projects in Culberson this year, the Barba-Row Phase 1 and the Bowler Row, see if you had any updates or takeaways as far as cost efficiencies, early time...

what you've derisked to date or could by year-end? And then how does this compare to the acquisition underwriting on the upper end of locations?

would you see this benefiting Coterra? And then would something like this make constitution less attractive from a producer standpoint?

I wanted to ask about U.S. climate litigation because that has been an overhang

how do you view the benefits to Chevron of owning more of CPChem? Are there things you could do differently

what you're already doing on the marketing side here and also what you think you can do in the future to further maximize value?

can you talk about the importance of domestic oil and gas production to contributing to these or other power ambitions?

can you just talk about your optimism around future prospects, Paleogene or brownfield tiebacks?

could you give more color around the fully autonomous artificial lift optimization—how to think about this relative to gas lift or ESP or basin-specific

Is there any ability to shield taxable gain for the pro forma company, or is this something that will have to be factored in

how do you see the commercial opportunity for Devon stand-alone? And where is the current focus now for the company?

You mentioned being open to additional investments in the midstream space. And I was just hoping you could expand on this and maybe what part of the value chain that could be

can you talk about just generally how performance has been versus expectations? Any key learnings so far?

does this make you more encouraged about pursuing additional bolt-ons in the Eagle Ford or elsewhere

update us on what you are seeing on the productivity side now that you have some EOG-drilled and completed wells on

could you help us understand how you would resume oil production growth? Which assets drive that

could you just talk to the drivers, positive surprises now that you have operated the asset for six months

how similar do you think it would look also considering the 20% longer laterals this year?

in Lea County specifically, what's the maximum wells per DSU you think you can get to now

just wondering how you view this demand opportunity. And is it something that EQT could look to partner with

as you see projects like this or others in the Midwest announced, how do you see these projects securing gas

can you update us on any discussions or plans this year around placing LNG offtake between Asia and Europe or securing regas

do you see value in adding storage further from the wellhead as part of a broader gas marketing strategy

Wondering if you could talk about how offtake terms have evolved maybe before and after the LNG export pause

whether the changes in the marketplace, greater pull on gas demand, more favorable permit regime, provide any reason to maybe revisit the project scope

Is there any reason to think you wouldn't also be supplying volumes? And if this is still to come, how much does midstream give you a competitive advantage here

on MVP Boost, the open season here, I'm not sure how much you want to get into it, but are there any initial expectations as far as interest from demand pull type customers versus producers

Just what all does this entail this imply that you'd look to take additional offtake from the project?

how do you see the opportunities for Expand here versus the Gulf Coast considering the different competitive dynamics?

can you talk through how this will benefit Expand this year also as Golden Pass starts up?

can you just talk about the advantages of selling gas to this hub?

just with the lower crude price, I was wondering how associated gas plays into your outlook and generally what type of -- what level of oil production does that assume

Just your medium-term outlook there for differentials or netbacks, just with several new pipes starting up in the play

how you'd characterize the ability to privates in the Permian to respond to what we're now seeing as far as higher oil prices versus a couple of years ago

Can you talk about how you're viewing Viper ownership and what's optimal for Diamondback just because you did sell some in the quarter

for Diamondback, assuming a green light scenario, just how do you think about a sustainable growth rate that can be achieved for the company over a multiyear period

how you see Barnett variability across either your or other operator wells across the northwestern side of the basin versus Southeast

curious how you see a green light scenario playing out for the Permian broadly. Can you just talk about how less capital efficient it is to grow first stay and maintenance

how much of FANG's leadership do you think can be attributed to you guys just have more core acreage, maybe less power, less Southern Midland exposure

how you're viewing the cost of capital advantage right now for Viper vs FANG and how this shapes capital allocation decisions

is there any reason, as shale more mature, to think that this could be less upside to capital efficiency for the industry

how do you see these changes influencing ethane prices? And then also, just impacting your NGL plant production and BANGL volumes?

do you think the West Coast has set up the run pretty hard in '26 and and that you're past a lot of the downtime?

how much of dock space you view is utilized? And is that at all a bottleneck to future supply

I was hoping you could talk through the planned crude slate and also just what you're seeing in the market as far as sourcing more advantaged barrels

any view on how you would see some of the changes impacting market conditions, potential changes, or just helping to offset some of the impact from closures?

what other areas of the value chain could you see yourselves participating in across the midstream build-out?

Once the Strait opens up, how do you see the progression for getting back to normal operations for CPChem

how does the higher crude prices change, how you're thinking about investment opportunities

How important is Phillips integration between midstream and refining and designing and executing this project

how meaningful do you think this could be to help bring balance back into the market?

wondering if there's more to do on the divestiture side here where there's crude or refined product pipelines

in a quarter where WCS didn't really give you much help, what do you guys look at as far as really attributing and driving that relative outperformance?

if you could talk about any changes you made specific to the North Atlantic region

where would you put the level of government support here what would be an unintended consequences

how are you seeing the EU refinery loophole sanctions impacting diesel markets

given the regime changes in in in Venezuela, is there any reason you might revisit this stance

when do you kind of reach the point of no return here just given preparations needed

can you just talk through the moving pieces here with Mexico production declining, the Venezuela uncertainty

any shift in your medium-term outlook for efficiency gains in light vehicle fleet

what does the affordability or supply conversation looks like here or in broader Europe