The third quarter earnings release and a supplement presentation that accompany our call are available on our website at targaresources.com. We had another outstanding quarter with record adjusted EBITDA driven by record volumes across our footprint. With three quarters completed, we now expect our full year 2025 adjusted EBITDA will be around the top end of our previously provided guidance range. Our Permian volumes grew more than 340 million cu ft per day and nearly 700 million cu ft per day compared to this time last year.

Our Permian growth is driving additional NGL volumes through our integrated system, as NGL volumes increased about 180,000 bbl per day compared to this time last year. Incrementally, the customer success we achieved in 2024 has started to show up in our volumes, some this year, but really adding to our longer-term confidence of continued Permian volume growth. Also, our previously announced Forza natural gas pipeline in the Delaware had a successful open season, and we are moving ahead with that project. We continue to expect meaningful long-term growth in Permian gas and NGL volumes across our footprint.

We have a lot of projects in progress, which means growth capital is elevated in 2025 and 2026, and these attractive investments will drive significant increases in adjusted EBITDA. Once these projects are online, we expect our downstream capital spending will be significantly lower for years to come, driving a substantial increase in free cash flow. This expected increase in free cash flow will be durable, meaning even if we are in a stronger growth environment driving elevated spending on the G&P side, our downstream spending should still be modest. So in late 2027, our downstream NGL capital is expected to be significantly lower than today's, and our adjusted EBITDA is expected to be much higher than today's.

What went well
  • Targa delivered record adjusted EBITDA of $1.275 billion, up 19% year-over-year and 10% sequentially, driven by record volumes across its footprint.
  • Permian natural gas inlet volumes averaged a record 6.6 billion cubic feet per day, up 11% versus a year ago, while NGL pipeline transportation volumes reached a record 1.02 million barrels per day and fractionation volumes ramped to a record 1.13 million barrels per day.
  • Given the strength of 2025 performance, management now expects full year adjusted EBITDA to be around the top end of its $4.65 billion-$4.85 billion guidance range.
  • Commercial success continued with new acreage dedications and multiple newly announced growth projects (Speedway, Yeti and Copperhead plants, Buffalo Run, Forza pipeline).
  • Management intends to recommend a 25% increase to the annual common dividend to $5 per share effective Q1 2026, and repurchased $156 million of shares in the quarter ($642 million year-to-date including post-quarter purchases).
  • Leverage was approximately 3.6x, comfortably within the 3x-4x target range.
What went wrong
  • In October, Permian volumes were impacted by producer shut-ins from low commodity prices and storms, an unusual occurrence management said it had not seen before, though volumes are now largely back online.
  • Continued maintenance on a number of natural gas pipes out of the Permian was expected for November, contributing to potential choppiness over the final two months.
  • Capital spending is elevated in 2025 and 2026 (net growth capex of approximately $3.3 billion for 2025) ahead of larger downstream projects coming online in 2027, and plant costs have risen modestly due to more sour gas in the mix and tariffs.

Guidance Changes

MetricPeriodCurrent guidance
Full year 2025 adjusted EBITDAFY2025Around the top end of $4.65B-$4.85B (Raised toward top end)
Permian volume growthFY2025At least 10% growth
Permian volume growth2026Strong low double-digit growth
Net growth capital spendingFY2025Approximately $3.3 billion
Net maintenance capital spendingFY2025$250 million
Annual common dividendFY2026$5 per share (recommended) (+25%)

Performance Breakdown

MetricYoYNote
Adjusted EBITDA +19% (and +10% sequentially) Record Permian NGL transportation and fractionation volumes generating higher margin across G&P and L&T segments
Permian natural gas inlet volumes +11% (record 6.6 Bcf/d) Materialized second-half volume ramp from producers and continued commercial success
NGL pipeline transportation volumes Record 1.02 million bbl/d Permian growth driving additional NGL volumes through the integrated system
Fractionation volumes Record 1.13 million bbl/d (+17% sequentially) Fracs fully back online after planned maintenance in Q1/Q2; system essentially full

Earnings Call Themes & Trends

TopicPrevious mentionCurrent periodTrend
Permian volume growthForecast a big back-half ramp at start of yearRamp materialized; at least 10% growth in 2025, low double-digit expected in 2026Strengthening
Downstream free cash flow inflection—Speedway and LPG export expansion online late 2027, after which downstream capex drops significantly and free cash flow grows durablyImproving
Intra-basin residue / gas takeaway strategy—Building out residue capabilities to manage tight Permian egress until new takeaway arrives in 2026, at returns comparable to rest of businessExpanding
Sour gas positionImplemented sour gas strategy many years ago as first moverMore than 2.5 Bcf/d sour capacity and seven AGI wells; growing sour production as competitors try to enterStrengthening
Capital returnAll-of-the-above approach with opportunistic buybacks25% dividend increase plus continued opportunistic repurchases; 40%-50% payout over multiple yearsImproving

Q&A Summary

What is driving the upside versus original expectations toward the top end of guidance?
The big back-half volume ramp largely materialized consistent to better than expected, driving record Permian NGL transportation and fractionation volumes. Volatility across the year also provided incremental natural gas and NGL marketing opportunities not typically forecast, and producers performed on track to a little better than expectations with no material change in activity.
Why guide around the top end when the exact top would imply Q4 EBITDA down versus Q3 — any headwinds?
Management said it tends to be conservative with two months left in the year; October saw shut-ins from lower commodity prices and there is continued November pipe maintenance. The next couple of months may be choppy, but it is likelier they are above the top end than below it.
On the decision to increase the dividend 25% versus leaning into buybacks?
Management favors an all-of-the-above approach, has room to meaningfully grow the dividend over multiple years, and plans to remain opportunistic with share repurchases that bounce around quarter to quarter, supported by growing EBITDA and free cash flow.
On Speedway, when would you expand to the full 1 million bbl/d design capacity and would it be phased?
Most of the capital goes into the initial 500,000 bbl/d capacity; moving to 1 million bbl/d is largely just adding pump stations at a fraction of the cost, so they would stage it in ratably over time as volumes ramp, much like Grand Prix.
Has cost escalation on processing plants changed margin expectations?
The 225-275 million range still holds (around 250 million for sour, low end for sweet). Capital costs are not directly passed back to producers but factor into overall rates; Targa remains highly competitive and continues to earn good returns through its integrated system.
Are tariffs a risk to the $1.6 billion Speedway cost?
Management feels good about the budget; the engineering and supply teams procured pipe long before the public go-ahead, positioning the project to potentially come in under budget, and there is contingency built in as with all projects.

More on Targa Resources Corp.

Reported 2025-11-05 · figures from the Targa Resources Corp. Q3 2025 earnings call.

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