Matt Portillo

I just want to make sure I heard that correctly. But maybe over the medium term, I was hoping you might be able to comment on your updated thoughts around power demand growth regionally for Northea...

I was curious if you might be able to provide a little bit more color around the timing of when those microgrids might come into service and how many megawatts you're planning on deploying.

I was curious if you might be able to talk about your views specifically in Northeast PA on the opportunity set around power demand growth.

how many additional locations do you see in the area and maybe timing of development for those pads moving forward?

Could you give us an update on what you think you might need to spend to hold oil volumes flat over a multiyear period?

how you're thinking about the returns in the Anadarko in a strip price environment versus the Permian program?

any color you might be able to provide in terms of how many wells you could drill for the remainder of this year

where do you think that new threshold is for the Upper Marcellus specifically?

I was curious if you might be able to just help us understand what might be driving the elevated capital in the play this year?

I think the plan calls for about 70 to 75 gross wells in the Bakken. And in our math, that would probably translate to around $650 million to $700 million

I was curious if you could maybe provide some context around how much that program made up in 2024, how you're thinking about it in 2025

how you think about inventory, especially in the context of higher natural gas and NGL prices, as you mentioned, progressing that program through the course of 2025 and beyond

I saw a really nice improvement in the productivity trends per foot in 2025. I was just curious if you might be able to comment on this improvement

I think the maybe missing piece around this might be the lateral length progression

do you think we need to see more pipeline capacity coming out of the Northeast to help bolster supply on the Gulf Coast

Could you perhaps discuss why the Delfin LNG project was attractive to Expand?

curious how you think about Expand's productivity trends in the Haynesville over the next few years and how that might contrast to the industry as a whole

it feels like there has been a pretty significant shift in a constructive way in the supply-demand balances for natural gas on the Gulf Coast

Just curious if you might be able to speak to the evolution of gas demand you're seeing regionally around Texas, Louisiana and Arizona

how do you think about the mid-cycle gas price? And is that right-hand side of the chart kind of closer to that $4.50 level, a good place to be thinking about?

I was curious if you might be able to talk a little bit about the Utica, just your acreage prospectivity

how you guys are thinking about the LNG market and your strategy moving forward

should we be thinking about kind of your productive capacity once you get to the 7.5 Bcf a in 2026 to hold around 7.5

if you've changed anything on the completion or spacing design? Or what's really driving the outperformance there

your views around your DJ inventory and how you might be able to flex capital in kind of a lower commodity price environment

Is shale EOR economically viable now at current crude prices and with the 45Q enhancement

Any constraints that might be on the horizon? And any opportunities that you may see to further reduce your cost on the waterfront