ET Stock Outlook 2026: Energy Transfer's 7.5% Yield — The Full Picture Including What They Don't Advertise

The 7.5% distribution yield on Energy Transfer (ET) is real. So is the 2020 distribution cut that wiped half of it away. And so is the K-1 tax form that most yield-comparison tables conveniently leave out of the fine print.

I want to start there, because ET is exactly the kind of investment that looks compelling on a simple screen — highest midstream yield in the sector — and gets more complicated the deeper you go. If you’re a US investor in a taxable account with tolerance for K-1 complexity, ET deserves serious consideration. If you’re in an IRA, or you’re outside the US, the analysis gets much harder very quickly.

ET is a massive midstream infrastructure business. It moves crude oil through the Bakken (Dakota Access Pipeline), natural gas through Appalachia (Rover Pipeline) and the heartland (Panhandle Eastern), and NGLs across the central and eastern US. FY2025 EBITDA reached $14.71 billion — larger than EPD’s. The distribution has been rebuilt from 2020’s emergency cut and now sits at $0.3225/quarter. The Lake Charles LNG project, if it ever gets to FID, adds a meaningful long-term growth catalyst.

But the 2020 cut happened. The leverage is still 4.0–4.5× debt/EBITDA. The governance has drawn scrutiny. And the K-1 will complicate your tax return regardless of where you live.

Snapshot: ET Key Metrics (May 2026)

Metric	Value
Quarterly Distribution	$0.3225 / unit
Annualized Distribution	~$1.29 / unit
Trailing Yield	~7.5%
FY2025 EBITDA	$14.71 billion
FY2025 Revenue	$85.54 billion
FY2025 Net Income	$4.17 billion
Net Debt / EBITDA	~4.0–4.5×
2020 Distribution Cut	Yes — 50% reduction
Structure	MLP — issues K-1
Pipeline network	125,000+ miles

The gap between EBITDA ($14.7B) and net income ($4.2B) reflects two things: high depreciation (long-lived pipeline assets) and significant interest expense from a large debt load. ET’s interest bill is one of the largest in the midstream space.

Business Model: America’s Most Sprawling Midstream Network

ET operates across essentially the entire US hydrocarbon value chain. Scale is both its strength and its organizational challenge.

Crude oil pipelines: Dakota Access Pipeline is the flagship. Moves ~570,000 barrels/day from North Dakota’s Bakken shale to Midwest/Gulf Coast markets. Bakken production has grown consistently; DAPL runs at high utilization.

Natural gas pipelines: Rover Pipeline connects Marcellus and Utica shale gas production in West Virginia, Ohio, and Pennsylvania to the Dawn Hub in Ontario, Canada and other Midwest markets. Panhandle Eastern Pipe Line moves gas across Oklahoma, Kansas, Missouri, and the Midwest. Combined, ET operates one of the most extensive natural gas transmission networks in the country.

NGL and midstream: Gathering, processing, and transportation of NGLs across multiple basins. Less dominant than EPD at Mont Belvieu, but significant scale.

Intrastate natural gas: Texas intrastate operations that feed Gulf Coast industrial and LNG-adjacent customers.

Sunoco LP: ET is the general partner and controlling unitholder of Sunoco LP (SUN), which operates refined products distribution and convenience stores. This diversification adds revenue but also organizational complexity — and it’s one reason ET’s K-1 is more involved than EPD’s.

The geographic and product breadth means ET is essentially a bet on US energy infrastructure broadly. That’s a reasonable bet. The question is whether the returns compensate for the leverage and governance risks.

Dakota Access Pipeline: The Asset That Keeps Getting Sued

DAPL generates substantial cash for ET and runs at consistently high utilization. It is also the most legally contested pipeline in the US midstream sector.

The Standing Rock Sioux Tribe’s opposition to DAPL isn’t simply political — it rests on claims that the pipeline crosses under Lake Oahe, an Army Corps of Engineers-controlled water body, without adequate tribal consultation. Multiple federal courts have questioned the validity of the original easement. Under the previous Biden administration, the Army Corps conducted an environmental impact assessment that created multi-year uncertainty. Under the current administration (Trump 2), the political environment has been more supportive of pipeline operations.

As of mid-2026, DAPL is operating at full capacity. But calling the legal risk “resolved” would be inaccurate. A change in administration or an adverse appellate court ruling could reopen permit challenges. This is a genuine tail risk that isn’t priced into most yield discussions.

Lake Charles LNG: The Growth Story That Keeps Getting Delayed

The Lake Charles LNG project has been ET’s most prominent growth initiative for nearly a decade. The premise is straightforward: liquefy US Gulf Coast natural gas and ship it to Asia and Europe, which want diversified LNG supply chains away from Russian gas.

The economics are attractive in theory. US natural gas is cheap relative to global LNG prices, and European buyers have been desperate for non-Russian supply since 2022. ET’s site on the Gulf of Mexico has existing infrastructure. Capacity of 16+ million tonnes per year would place it among the largest US LNG export facilities alongside Cheniere Energy’s Sabine Pass.

The execution has been painful:

• 2020: Shell, the original project partner with offtake commitments, walked away
• 2021–2023: ET sought replacement partners and financing; multiple potential deals announced, none closed
• 2024: US LNG export policy uncertainty under the Biden moratorium briefly created additional headwinds
• 2026: FID remains unresolved

The problem is circular: lenders want long-term offtake contracts before financing; buyers want confirmed construction schedules before signing 20-year contracts. ET has struggled to break this impasse. LNG Cheniere Energy — which did reach FID on all its facilities — provides a contrast showing how this can work when all the pieces align.

If Lake Charles gets built: meaningful EBITDA addition, distribution growth acceleration, significant stock re-rating potential. If it doesn’t: years of development spending written off, and ET’s growth story narrows to organic pipeline expansion.

Distribution History: Acknowledging the 2020 Cut

ET bulls sometimes wave away the 2020 distribution cut as a “COVID black swan.” That framing understates the underlying issue.

ET Distribution per Unit (Annual)

Year	Distribution	Notes
2018	~$1.22	Pre-cut peak
2019	~$1.22	Maintained
2020	~$0.61	50% cut — Q3 2020
2021	~$0.61	Held flat
2022	~$0.87	Recovery begins
2023	~$1.22	Back to 2019 levels
2024	~$1.27	Modest growth
2025	~$1.29	Modest growth

The cut was enabled by high leverage (net debt/EBITDA above 4.5× at the time) and an aggressive M&A pipeline that left minimal cushion when EBITDA fell. COVID was the trigger; the vulnerability was self-made.

The counter-argument: ET did cut, delever, and rebuild. The distribution is now back at 2019 levels and growing. Management has stated a commitment to distribution growth while maintaining leverage targets. For investors who can look past 2020, the track record is recovering.

But EPD never cut. That difference in management judgment — EPD’s insistence on 1.7× coverage even in bad years versus ET’s willingness to cut when leverage got stretched — is not a minor data point. It’s a core insight into how these two companies manage the interests of unitholders versus growth ambitions.

The K-1 Problem: ET’s Version Is More Complex Than Average

Both EPD and ET are MLPs and both issue K-1s. But ET’s K-1 is often noted by tax professionals as being among the more complex partnership returns in the sector.

Why? ET’s corporate structure includes multiple operating entities, general partner interests, and subsidiary MLPs (Sunoco LP). The consolidated ET K-1 passes through income, losses, and deductions from multiple layers of the partnership structure. The resulting K-1 document is longer and more detailed than a simpler MLP’s.

For US investors:

• K-1 arrives in March or April — often requiring a tax filing extension
• Potential obligations to file in multiple states where ET operates
• UBTI in IRA accounts if held there
• Basis tracking is complex (distributions include return-of-capital components)

For non-US investors:

• ET’s operating partnership income is US-source ECI (Effectively Connected Income)
• ECI is subject to US withholding at graduated rates (not the 15–30% treaty rate applied to portfolio dividends)
• Non-US ET holders have found this creates significant additional tax friction
• Many non-US brokerages simply refuse to process MLP holdings

K-1 Complexity vs. Alternatives

Investment	Tax Form	IRA-Compatible	Non-US Friendly	Complexity
ET (MLP)	K-1 (complex)	No	No	Very High
EPD (MLP)	K-1 (moderate)	No	No	High
KMI (C-corp)	1099-DIV	Yes	Yes (treaty rate)	Low
WMB (C-corp)	1099-DIV	Yes	Yes (treaty rate)	Low
OKE (C-corp)	1099-DIV	Yes	Yes (treaty rate)	Low

For anyone outside the US or holding in tax-advantaged accounts, the verdict is clear: get midstream exposure from KMI, WMB, or OKE.

Peer Comparison: ET in the Midstream Universe

Midstream Peer Comparison (May 2026)

Company	Ticker	Yield	Leverage	K-1	Cut History
Energy Transfer	ET	~7.5%	~4.2×	Yes	Yes (2020)
Enterprise Products	EPD	~5.7%	~3.3×	Yes	Never
MPLX LP	MPLX	~7.8%	~3.5×	Yes	Never
Kinder Morgan	KMI	~4.3%	~4.0×	No	Yes (2016)
Williams Companies	WMB	~3.8%	~3.5×	No	No
ONEOK	OKE	~5.0%	~3.5×	No	No

ET sits at the high-yield end of the group, with the highest leverage and the most recent distribution cut. MPLX offers a comparable yield with better leverage metrics and cleaner governance — though MPLX also issues a K-1.

For yield-focused MLP investors who can handle K-1s and want the highest payout, ET and MPLX are the leading options. For investors who want yield without K-1 complexity, OKE provides a useful middle ground.

Financial Performance: Improving but Debt-Heavy

ET Annual Financials (USD billions)

Year	Revenue	EBITDA	Net Income
FY2022	$89.9B	$11.9B	$4.3B
FY2023	$78.6B	$12.7B	$3.5B
FY2024	$82.7B	$14.3B	$4.4B
FY2025	$85.5B	$14.7B	$4.2B

EBITDA growth has been consistent and meaningful — from $11.9B in 2022 to $14.7B in 2025, nearly 24% growth over three years. This growth came from organic pipeline expansion, M&A, and higher utilization. The management team is operationally competent; the Kelcy Warren-era criticism is about financial structure and unitholder treatment, not operations.

The net income is notably low relative to EBITDA. Two causes: substantial D&A (long-lived infrastructure assets) and significant interest expense from the large debt load. At roughly 4.2× leverage and a large absolute debt balance, ET pays several hundred million dollars per year more in interest than EPD per unit of EBITDA.

Risks: Ranking Them Honestly

1. Distribution cut risk (high): Leverage of 4.0–4.5× means a 10–15% EBITDA decline could compress coverage and pressure distributions. The 2020 precedent confirms management will cut if necessary.

2. DAPL legal risk (medium): The pipeline operates today, but an adverse court ruling or administration change could reopen permit review. The revenue impact of a sustained DAPL shutdown would be substantial.

3. Lake Charles perpetual delay (medium): Every year Lake Charles doesn’t reach FID, it erodes credibility of ET’s growth narrative and represents stranded development costs.

4. Interest rate sensitivity (medium): High absolute debt × floating rate exposure means a 100bps rate increase meaningfully reduces free cash flow.

5. K-1 limits natural buyer universe (low near-term, structural): Institutional investors that can’t hold K-1 partnerships, plus all IRA and international investors, are effectively excluded. This perpetually caps the valuation multiple relative to C-corp peers.

Scenario Analysis

Bull case: Lake Charles LNG reaches FID in 2026/2027, adding ~$2B of incremental annual EBITDA upon completion. DAPL legal challenges definitively resolved. Leverage reduced to 3.5× as cash flow improves. Distribution raised 6–8% annually through 2028. Unit price re-rates to $22–25.

Base case: Core pipeline business grows organically at 3–5% annually. Lake Charles delayed but not dead. Leverage stays 4.0–4.5×. Distribution grows modestly (~$1.35 by 2027). Unit prices stay range-bound. Total return is approximately yield (~7.5%) with minimal price appreciation.

Bear case: EBITDA softens (NGL price correction + macro slowdown), leverage exceeds 4.5×, and management reduces distribution again. Unit prices fall to $13–15. A 2020 repeat is never the base case but has a higher probability than for EPD given the leverage profile.

ET’s Acquisition History: Growth Engine or Value Destroyer?

Understanding ET requires understanding Kelcy Warren’s acquisition philosophy. Since 2012, ET has executed over $50 billion in acquisitions, creating the sprawling infrastructure network it operates today. The deals that defined the company:

Regency Energy Partners (2015): ET acquired Regency for ~$18 billion, adding significant NGL gathering and processing scale. The deal was well-timed, acquiring midstream assets before the 2014–2016 oil price collapse compressed valuations.

Sunoco (2012) and Sunoco Logistics (2016): ET acquired Sunoco’s refined products and logistics businesses, adding crude oil pipelines and retail fuel distribution. These deals created the Sunoco LP structure that now exists as a subsidiary MLP.

Energy Transfer Equity consolidation (2018): ET consolidated its GP and several subsidiary MLPs into a simpler structure. The exchange ratios offered to subsidiary unitholders were contested by some investors who believed they reflected below-market valuations. Lawsuits followed; the consolidation was completed.

Crestwood (2023): ET acquired Crestwood Equity Partners for approximately $7.1 billion, adding crude oil gathering in the Permian and Williston basins and natural gas storage. A more recent example of ET’s acquisition appetite.

The pattern: ET buys assets, sometimes at premium prices, often with debt. When commodity markets are strong, the strategy works. When markets turn, the leverage becomes a liability. The 2020 distribution cut was the clearest evidence that management’s growth instinct had outrun its financial cushion.

The counter-argument for ET bulls: the asset base assembled through these acquisitions is genuinely irreplaceable. At $14.7B of annual EBITDA, ET generates more cash than it could easily reinvest organically. The question is whether management can maintain financial discipline going forward — and whether the Lake Charles investment represents the same mistake again or a truly transformative opportunity.

The Natural Gas Demand Story: ET’s Structural Tailwind

Beyond the risks, there’s a legitimate structural growth case for ET that doesn’t depend on Lake Charles.

US natural gas production is at record highs, driven by associated gas from Permian oil wells and continued Appalachian shale development. That production needs to get to market — to power plants, industrial users, LNG export facilities, and cross-border pipelines into Mexico. ET’s network is positioned to capture meaningful portions of all these flows.

The power sector angle is particularly interesting in 2025–2026. Data centers for AI training are enormous electricity consumers. Natural gas power plants are being built or kept online specifically to meet data center demand in states where renewables can’t provide reliable baseload power. Texas, where ET has extensive intrastate gas infrastructure, is a center of this data center-driven gas demand growth.

This isn’t a speculative thesis — it’s already showing up in elevated Texas intrastate gas utilization rates. ET’s Henry Hub exposure through the Panhandle Eastern system and its Texas intrastate operations position it to benefit as natural gas demand proves more durable in the near term than many energy transition models assumed.

None of this eliminates the leverage and governance concerns. But it does mean ET’s cash generation is backed by genuine infrastructure demand, not a declining asset base. The distribution coverage — even after the 2020 cut — has been restored through real EBITDA growth, not financial engineering.

Comparing ET and EPD: A Side-by-Side Working Example

Here’s a concrete example to illustrate the choice between ET and EPD for a US investor in a taxable account with $100,000 to invest.

Scenario: $100,000 investment, 5-year hold

	EPD	ET
Starting yield	~5.7%	~7.5%
Year 1 distribution	~$5,700	~$7,500
Distribution growth (base case)	3.5%/yr	2.5%/yr
Year 5 distribution	~$6,750	~$8,250
K-1 complexity	High	Very High
Distribution cut risk (5-yr)	Very Low	Low-Medium
Leverage risk	Low	Moderate
Estimated total distribution (5yr)	~$31,000	~$38,500

The ~$7,500 difference in 5-year total distributions is real money. But it comes with a ~3× higher probability of a distribution cut event, more complex K-1 filings, and governance uncertainty. For investors who’ve stress-tested a hypothetical 25% cut in Year 3 (which would reduce ET’s 5-year total to ~$35,000 and possibly compress the unit price), the risk-adjusted case for EPD becomes clearer.

Neither investment is “wrong” in absolute terms. The choice is about matching the risk profile to the investor’s priorities.

Who Should Own ET

Own ET if:

• Taxable US brokerage account, comfortable with K-1 complexity
• You specifically want Bakken crude oil exposure (DAPL), which KMI/WMB don’t provide
• You want the highest available yield in the midstream MLP space
• You’ve stress-tested your position against a second distribution cut scenario
• You believe Lake Charles LNG will eventually reach FID

Don’t own ET if:

• Investing inside an IRA, 401(k), or Roth IRA
• You’re outside the US (ECI/K-1 complications make this impractical for most)
• The 2020 distribution cut history makes you uncomfortable — trust your instincts
• You want corporate governance certainty — buy EPD instead

Conclusion: The 7.5% Has a Price

Energy Transfer is a legitimate, large, cash-generating midstream business. The 7.5% yield reflects real distributable cash flow, not financial engineering. The pipeline network is critical infrastructure. EBITDA has grown every year since 2022.

But three things are permanently part of the ET investment thesis: the 2020 cut happened and could happen again given the leverage, the K-1 eliminates ET from consideration for most IRA investors and most international investors, and Lake Charles LNG has been a promised but undelivered growth catalyst for years.

For US taxable-account investors who want the highest midstream yield and can accept these conditions, ET offers a defensible income position. For everyone else — buy KMI or WMB, accept the lower yield, and sleep better.

For additional energy sector context, see our coverage of COP ConocoPhillips and XOM ExxonMobil.