Spiro Dounis

Randy Fowler said 80%-plus of the $3 billion 2027 growth CapEx is already spoken for by sanctioned and announced projects, and that $3 billion may be the near-term level given Permian growth.

Jim was candid on the potential range ($500-700M) and confident outsized spreads would materialize; Tug added Q2 would be the main beneficiary.

Jim confirmed he expects to beat the 'modest' 2026 growth guide; Randy added 2026 shaping up much stronger than expected, with new plants additive to 2027.

Jim described Q4 as more ratable given normalized spreads. Randy clarified modest growth in 2026, probably at lower end of 3-5% range.

Zach confirmed Frac 14 full at startup. Processing plants at 90% combined utilization. NRT ramp tied to VLEC deliveries. LPG 85-90% contracted.

Randy confirmed $200-$300M buyback pace for 2025 but will be opportunistic. Larger buyback opportunity comes in 2026 with much more free cash flow.

Management confirmed processing plants ramp fast (60-100% in Permian), fracs come on full, LPG exports 85-90% contracted. Most projects fairly full at startup.

Tony detailed $65 base case vs $60 reality, $55-60 maintenance mode, $50 below maintenance. Most at-risk are 75 rigs run by small operators with 3 or fewer rigs.

Randy cited mid-single-digit cash flow growth potential with larger projects contributing in second half. Setting up a strong year on industry fundamentals.

Graham Bacon declined to confirm or deny a 2025 FID was less likely. Confirmed air permit renewed to 2028 and not worried about permit renewals.

Norton framed growth as multiple reinforcing drivers across all five segments, not just white-space fill.

Walt clarified winter storm was already in guidance and the raise reflects volume, commodity, and differential upside. He noted 75% hedged at year start with incremental volumes getting full commodity benefit.

Walt laid out a clear timeline: large CapEx done by mid-2027, free cash flow accelerates from there. Priorities are high-return projects first, then debt paydown and shareholder returns.

Walt noted $55-$60 WTI assumption is intentionally conservative, with higher prices benefiting spreads and producer activity. Pierce listed upsides: discretionary Bakken ethane recovery, Permian spot offloads, Conway-Belvieu spreads, and butane-to-unleaded timing.

Pierce confirmed deals are scaling up from initial smaller projects, with advanced negotiations with hyperscalers and multiple projects in advanced stages.

Walt emphasized expand-and-extend strategy with more opportunities post-acquisitions, noting expectation for CapEx to trend down with significant operating leverage in place.

Sheridan highlighted competitive advantage from connectivity to Mid-Con and Gulf Coast refiners, existing capacity for efficient expansion between Gulf Coast and El Paso.

Walt emphasized 2026 growth driven by project completions (refined products expansion, West Texas LPG, Easton connections) more than producer activity.

Sheridan noted contracted industrial demand on the Mississippi corridor, growing EnLink asset optimization, with formal guidance expected in 2026.

Chad said projects will add scale and longer tenors, and the JV recycles capital into the next round; direct.

Zamarin positioned Williams as a comprehensive infrastructure solutions provider, not limited to one model. Exploring bring-your-own-power, grid complement, and larger-scale solutions.

Porter confirmed contracted base CAGR moved from 8% to 9% with new projects. Said they feel good about three focus areas driving toward 10%+ target.

Porter said long-range forecast shows high-returning organic investments filling balance sheet capacity within 3.5-4x leverage. Power innovation projects' quick cycle and cash tax deferrals accelerate capacity creation.

Zamarin said every utility customer they visited recognizes natural gas as the affordability solution. Wilson said NESE on quicker track than Constitution. Neither affected by election outcomes.

Zamarin said Saber extends gathering north of Haynesville footprint with strong counterparty credit and MVCs. Over time can route volumes south through LEG to Gulf Coast markets. M&A disciplined and opportunistic.

Zamarin described bookending decade with SSE in 2027 and Power Express in 2030, with power innovation projects filling gaps due to quick FID-to-in-service cycles. May tick up capital but within balance sheet capacity.

Armstrong said culture and business are in great shape, making it the right time to bring Zamarin's energy to bear on opportunities. Zamarin emphasized mandate is more of the same strategy.

Porter noted ever-increasing balance sheet capacity with leverage at 3.65x well within 3.5-4x target. Armstrong highlighted Socrates-type projects return capital quickly at 5x multiple in 18 months.

Matt attributed the conservative second-half view to not forecasting continued marketing gains (~$250M first-half benefit) while underlying volumes keep climbing as shut-ins return.

Meloy confirmed that once Speedway and LPG export come online in late 2027, downstream spending drops to ratable fracs only. Currently evaluating Train 13 timing. Free cash flow profile expected to be durable for years.

Muraro described the residue strategy as coordinated with producers for reliability and redundancy, underwritten by existing flowing volumes. Returns commensurate with the rest of the portfolio.

Pryor emphasized Targa's source-of-supply advantage from GMP footprint, long-term contracts, and growing global LPG demand. Competitive dynamics already factored in.

Meloy attributed outperformance to largest footprint, best rock, large/active producers who haven't varied drilling plans. Same factors expected to continue into 2026 and beyond.

Meloy confirmed below fee floors system-wide with 90% of remaining non-fee margin hedged through 2026. Even at Waha near zero, setting EBITDA records.

Meloy confirmed Q1 beat expectations on marketing by about $10M sequentially, benefiting more on gas marketing side. Not to the magnitude of 2024 yet.

Kim confirmed the incremental projects are primarily gas-related and driven by well-understood demand themes in areas needing pipeline capacity.

Kim listed tailwinds: full year of 2025 projects plus partial 2026 projects, contract escalators in Terminals and Products, declining interest rates, and minimal tax increases from bonus depreciation. Headwinds include potential oil volume decline and unknown commodity prices.

Kim said FERC eliminating 871 waiting period shortens regulated project cycles to just over 3 years. Compression is the gating item. Gathering and Texas intrastate projects have shorter cycles. Detailed capital capacity: $5.5B DCF less $2.6B dividends equals $2.9B plus 3.9x leverage with $800M per 0.1x of balance sheet room. Not worried about financing capacity.

Kim confirmed $8.1B backlog plus assumed fill-in gets to roughly $10B over four years. Called 2024 spectacular for backlog additions. Expects continued growth but cautioned on timing uncertainty.

Kim said no material impact from California fires (two days downtime, volumes expected to be recovered) or cold weather (operations team kept systems running with minimal disruption).