Aug 6, 2026 earnings call — Permian growth drives record volumes and guidance
Updated 2026 adjusted EBITDA expected toward the top end of $5.7 billion to $5.9 billion.
Revenue $4.4B (est $4.9B) · EPS $3.54 (est $2.83)
Key quotes
"We reported record volumes again in the Permian, up more than 900 million cubic feet per day from a year ago and up 450 million cubic feet per day compared to Q1."
"The constrained gas egress environment across the past several quarters has created increased marketing opportunities for Targa with our marketing businesses outperforming our expectations by approximately $250 million in the first half of the year, much of which occurred in the second quarter."
"Lastly, we expect our large LPG export expansion that will increase our capacity to around 19 million barrels per month will be much needed and remains on track for the third quarter of 2027."
Analyst Q&A 9
Volume trends and plant additions pace
Q (Jeremy Tonet · JPMorgan): Analyst asked how volumes are trending, which curtailments remain, and outlook into 2027. He also asked how many gas processing plants the company expects to add each year going forward.
A: Volumes are growing strongly across the system despite Q2 shut-ins; July was another strong month and the company is tracking ahead of expectations with continued growth into '27. On plants, two Midland plants came online this year, five are under construction, and the pace (illustrative 3 per year) could accelerate depending on contracts and commercial wins.
"So as I said, for the year now, I'd say that we are tracking ahead of expectations with a view of continued volume growth across the back half of the year." — Jennifer Kneale (PRESIDENT)
Export/frac needs and guidance assumptions
Q (Spiro Dounis · Citi): Analyst asked if downstream export or fractionation will need expansion if more plants come online, and to clarify guidance assumptions and what could create upside versus the company view.
A: The company says it has operating leverage from Speedway and the LPG export expansion coming in third quarter 2027, and will evaluate timing for the next fractionator as plants are added. Management also noted a conservative view on back-half marketing gains and that they didn't include about $250 million of optimization margin they had seen, while volumes are strong and many shut-ins have returned.
"But we also pointed to $250 million of optimization margin that we weren't counting on." — Matt Meloy (CEO)
Ethane exports and fee-floor sensitivity
Q (Jacqueline Koletas · Goldman Sachs): Analyst asked whether the company is considering ethane export capacity at Galena Park versus relying on LPG exports. She also asked when the company might move off fee floors into 2027 and how that affects outlook.
A: The company has evaluated ethane export opportunities for years, has large ethane supply, and has managed by selling domestically and to peers who export; they continue to evaluate ethane exports but don't feel they must pursue it unless returns match other investments. On fee floors, moving off them would be welcome, they've been below fee floors much of the time, and fee-floor benefits depend on both gas and NGL prices; price tailwinds would help results over time.
"But of course, we're always evaluating opportunities across the entire value chain and ethane exports is no different." — Jennifer Kneale (PRESIDENT)
What drives plant growth and sales strategy
Q (Julien Dumoulin-Smith · Jefferies): Analyst asked which variables can create upside versus the 3-plants-per-year framework — Permian activity or commercial wins — and if they are tracking ahead. He also asked how the commercial strategy is evolving amid Permian consolidation.
A: Management said upside comes from both stronger Permian trends (activity and rising GORs) and episodic commercial wins; they already have five plants coming and are evaluating timing for additional Midland and Delaware plants. On commercial strategy, the company uses a portfolio approach and works creatively with each producer to meet their needs and win and retain contracts.
"I think overall, just trends in the Permian Basin with just strong activity, increasing GORs is going to put us in good position to continue to add multiple plants a year for years to come." — Matt Meloy (CEO)
Will export capacity be tied to long-term contracts
Q (Gabriel Moreen · Mizuho): Analyst asked if the extra LPG export volume from butane co-loading can be underwritten into long-term contracts and asked directionally about pricing in new contracts.
A: The company had a strong Q2 on exports and was able to load more butane to move extra volume. They came into the quarter highly contracted, remain contracted through LEP 4 start-up and years thereafter, and have underwritten the current environment into their long-term export outlook; they are also shifting more butane loadings into longer-term contracts.
"We're contracted through LEP 4 start-up and for years thereafter." — Benjamin Branstetter (PRESIDENT)
Use of extra cash and tech impact
Q (Manav Gupta · UBS): Analyst asked how incremental free cash flow after Speedway starts will be used. He also asked whether new technologies could drive materially higher Permian recovery and volumes.
A: The company plans to keep investing in the business, materially increase the common dividend, opportunistically repurchase stock, and strengthen the balance sheet as free cash flow grows when Speedway and the LPG export facility come online. On technology, management said producers are best placed to judge results, technology should help over time but is a smaller part of the expected volume tailwinds.
"I think that for us, it's going to continue to be really the approach that we've taken over the last several years, which is we'll continue to invest in the business." — Jennifer Kneale (PRESIDENT)
Why per-unit G&P margins fell
Q (Burke Sansiviero · Wolfe): Analyst noted G&P volumes rose but per-unit margins fell and asked what caused the per-unit margin decline and how it should trend.
A: Management said they have moved many G&P contracts to fee-based, but some contracts remain commodity sensitive which was a slight headwind. Other items like fuel gains and fixed recovery gains also affect results, and overall commodity prices were a modest offset in the quarter.
"But overall, a really strong quarter for our G&P, but I'd say it's largely commodity price, which was a slight offset to our G&P business in the quarter." — Matt Meloy (CEO)
Plant lead times and fee-floor effect
Q (Jason Gabelman · TD Cowen): Analyst asked if plant lead time is still about 20–24 months and how supply-chain pressure is managed. He also asked whether lower marketing margins in Q3 will be offset by higher Waha-driven fee floors versus Q2.
A: Lead times have extended due to electrical infrastructure and certain vessels, but the company has adapted and now plans for about 18 to 24 months from sanction to start-up, with construction taking roughly 10 to 12 months. On fee floors and marketing, management said Q3 will be a headwind versus Q2 because the second-quarter marketing benefits were strong; they expect to remain below fee floors in aggregate in Q3 though gas prices could rise and be a tailwind over time.
"I'd say it's more like 18 to 24 months is kind of the time frame that we look at." — Patrick McDonie (PRESIDENT)
Shut-ins, gas projects, and marketing impact
Q (Sunil Sibal · Seaport Global): Analyst asked whether remaining Permian shut-ins are price-related or from other issues. He also asked if gas egress projects will raise base gas-marketing earnings or just help G&P, and about behind-the-meter power projects for data centers and implications for gas marketing.
A: Most shut-ins were price-related or for frac protection and the vast majority are back online, with a bit more returning in the third quarter. The company will benefit from higher equity earnings on its 17.5% interest in the Blackcomb and Traverse projects when they come online, while gas marketing margins depend on market opportunities and the team's ability to move gas to higher-priced markets. Management also said multiple behind-the-meter power projects exist and the gas marketing team is talking about potentially supplying some of those projects.
"We will benefit in terms of our equity earnings as a result of the 17.5% interest that we have in those projects, benefiting from higher equity earnings when those projects come online." — Jennifer Kneale (PRESIDENT)