EXE · Q1 2026 Earnings

Bullish

Expand Energy

Reported April 28, 2026

30-second summary

30-second take: Expand Energy printed Q1 revenue of $4.40B (+100% YoY), non-GAAP EPS of $3.83, and $1.70B of free cash flow on production of 7.44 Bcfe/d — an emphatic answer to the Q4 watch list, with net debt down $1.6B from year-end 2025. The signal hiding underneath: management hit and exceeded the full-year $1B debt-reduction target in a single quarter (gross debt down $1.3B per the press release), and the FY26 capital-allocation language now pivots from the quantified debt-reduction commitment toward "strengthen its balance sheet…while also returning cash to shareholders." Production, capex and rig count are reaffirmed exactly as guided in February; the capital-allocation mix is the change, with $150M of buybacks already executed through April 24 and new CFO Marcel Tunison confirming in Q&A that the company will "lean a bit more and shift…to shareholder returns in the form of buyback."

Headline numbers

EPS

Q1 FY2026

$3.83

Revenue

Q1 FY2026

$4.40B

+100.1% YoY

Free cash flow

Q1 FY2026

$1.70B

Operating margin

Q1 FY2026

34.8%

Key financials

Q1 FY2026

Metric	Q1 FY2026	YoY	Q4 FY2025	QoQ
Revenue	$4.40B	+100.1%	$3.27B	+34.4%
EPS	$3.83	—	$2.00	+91.5%
Operating margin	34.8%	—	22.8%	+1200bps
Free cash flow	$1.70B	—	$0.21B	+688.4%

Guidance

Expand Energy reaffirmed full-year 2026 production (7.5 Bcfe/d), capex ($2.85B), and rig count (11–12) guidance; Q1 2026 production at 7.44 Bcfe/d tracks in-line, but explicit debt reduction target withdrawn in favor of qualitative language.

Guidance is issued for the full year only, refreshed each quarter. Prior and new below are the same FY updated this quarter.

Actuals vs prior guidance

Metric	Period	Prior guide	Actual	Δ	Result
Production	Q1 FY2026	~7.5 Bcfe/d (full-year 2026 guidance)	7.44 Bcfe/d	in-line (0.06 Bcfe/d below full-year target, within tolerance)	Met

Changes to prior guidance

Metric	Period	Prior guide	New guide	Δ	Result
Debt Reduction	FY 2026	at least $1 billion	Withdrawn — no replacement	—	Withdrawn

Reaffirmed unchanged this quarter: Production (~7.5 Bcfe/d), Capital Expenditure (approximately $2.85 billion), Rig Count (11 to 12 rigs)

Other KPIs

Q1 FY2026

Segment	Q1 FY2026
Q1 2026 Production	7.44 Bcfe/d (93% natural gas)
Average Realized Natural Gas Price	$4.28/Mcf
Average Realized Oil Price	$64.77/Bbl
Average Realized NGL Price	$25.49/Bbl
Adjusted EBITDAX	$1,968 million
Operating Cash Flow	$2,402 million
Net Debt	$2,805 billion
Share Repurchases	$150 million YTD (through April 24, 2026)

Management tone

Customer optimization → embedded synergies → balance-sheet primacy → balance-sheet won, pivot to buybacks.

The debt-reduction priority has flipped from "non-negotiable" to "achieved, now rebalancing." One quarter ago the Q4 release led with debt paydown of at least $1B. This quarter the press release confirms $1.3B of gross debt redeemed YTD, and new CFO Marcel Tunison told Wolfe Research that the company can now "rebalance…lean a bit more and shift…to shareholder returns in the form of buyback." The release-level disclosure of $150M in buybacks through April 24 is the first concrete evidence the rebalance is already underway. The signal: investors should now model buybacks as a meaningful annual line, not opportunistic top-ups.

LNG strategy moved from concept to signed offtake. Q3 2025 introduced Lake Charles Methanol as the first marketing proof point; Q4 quantified the $500M EBITDA prize from a $0.20/unit realization uplift; this quarter Expand signed the Delfin SPA at 1.15M tons/year, replacing a previously terminated agreement on better terms. Asked by TPH's Matthew Portillo why Delfin was attractive, management framed it as "a natural extension of the Haynesville business" and noted LNG facilities are now the largest customers, with international JKM/TTF pricing exposure. This is the second deal in two quarters — the cadence is starting to look like a thesis lever rather than a one-off.

Western Haynesville reframed from confident to "methodical." Q3 management expressed confidence that well costs would not 2x the NFZ baseline; this quarter, with the first well actually online for ~7 weeks and the second just spudded, management's tone shifted to "still early" and "methodical appraisal." Per Pickering's Kevin McCurdy exchange, the company is "already on lower end of cost curve relative to competitors on the first well." That's a positive datapoint, but the willingness to slow the language reflects appropriate empiricism — and means the appraisal program will read out in 2H26 prints, not now.

CEO search remains on track. Management characterized the search as "still kind of at the money" on the six-month timeline laid out on the prior call, with no drift versus the Q4 framing of Q3/Q4 2026. Within the band but no upside surprise on an early announcement.

Q&A highlights

Matthew Portillo · TPH

Why was Delphin LNG attractive to Xpand? How does the company think about the global gas market supply-demand balance and its implications for LNG marketing strategy and time-to-market?

Management explained that Delphin LNG is a foundational contract to capture LNG market opportunities and premium international pricing (JKM, TTF). The deal is larger, reaches markets sooner, and is cheaper than the previous terminated agreement. LNG is positioned as a natural extension of the Hainesville business, allowing exposure to premium markets through both Gulf Coast demand and international sales.

New Delphin SPA: 1.15 million tons per yearPrevious agreement terminatedGas will come from both Sabine Pass and Calcasieu PassLNG facilities are currently largest customers

Doug Liggett · Wolf Research

Why did new CFO Marcel Tunison join Xpand, what does he bring to the breakeven reduction and marketing strategy? How should investors think about capital structure balance between cash returns and deleveraging given the strong balance sheet?

Tunison has 25+ years energy sector experience across upstream, midstream, downstream, and all global regions, with 25 years at Shell on integrated gas and recent downstream experience. He brings expertise in capturing margin through value chain integration. On capital allocation, the company achieved its $1B debt reduction goal in Q1, and will now rebalance toward shareholder returns (buybacks) while maintaining investment-grade status through cycle.

Tunison background: 25 years at Shell, 5 years in downstream retailBreakeven price: below $3 per unitPeer-leading leverage achieved post-Q1Reduced gross debt by $1.3B in Q1

Kevin McCurdy · Pickering Energy Partners

What progress is being made on leading-edge well costs and operational efficiencies? What early findings from the first Western Hainesville well and expectations for cost and production there?

Management reports continued progress on well cost reductions, including drilling the fastest well in Utica program in recent weeks. Western Hainesville first well came online in early March and performance has been encouraging. Company expects continued cost curve improvements leveraging existing expertise in deep hot wells. Already on lower end of cost curve relative to competitors on the first well.

First Western Hainesville well online early MarchSecond Western Hainesville well spud last week, 15 miles north of first wellCompany is most proficient Hainesville operatorFastest Utica well ever drilled recently

Neomita · Goldman Sachs

What is the mark-to-market on CEO search timeline and process? What is the right hedging strategy given volatile gas environment and peer companies running unhedged programs?

CEO search remains on track for Q3/Q4 timeframe ('at the money' on six-month timeline). Management seeking energy sector leader with proven track record. Hedge-to-Wedge strategy is appropriate for the company's size, counterparty obligations, and cyclical business nature. Strategy is not static and will optimize around market positions while managing downside risk and preserving upside.

CEO search timeline: Q3/Q4 expectedGas price range referenced: $2 to $6 historicallyHedging protects downside while preserving upsideCompany captures prices well above spot through hedging program

Scott Hannell · RBC Capital Markets

How should investors think about ideal allocation across LNG, industrial, and power end-users? Is industrial being overlooked relative to other demand segments?

LNG will materialize first and is most valuable near-term opportunity. Industrial projects are coming but larger FIDs not yet visible. Power demand is widespread but timing TBD. Company is chasing all three but LNG is priority due to nearer-term visibility and ability to plan assets around it. International demand for LNG is much more optimistic than U.S. perception.

LNG opportunity materialize first on Gulf CoastIndustrial opportunities in pipeline but FIDs not yet visiblePower generation growth widespread across regions but timing uncertainCurrently supplying 2 BCF/day to LNG facilities

Answers to last quarter's watch list

FY26 debt-reduction pace. Resolved emphatically — net debt fell $1.6B from year-end 2025 in a single quarter, and the press release confirms $1.3B of gross debt redeemed YTD, exceeding the full-year $1B target. The bar was not back-end loaded; it was annihilated up-front. The corollary: forward FCF allocation now tilts toward buybacks rather than incremental debt paydown.

Resolved positively

Southwest Appalachia trajectory. The basin printed flat YoY (0%) this quarter versus -3.1% in Q4 — stabilization rather than recovery. Within the reaffirmed 11–12 rig FY26 program, this suggests deliberate maintenance rather than active de-prioritization, but the basin remains the weakest of the three segments.

Continue monitoring

Marketing deal flow. Half-resolved positively. The Delfin LNG SPA at 1.15M tons/year — replacing a previously terminated agreement at better terms — is the first concrete 2026 deal, on top of Lake Charles Methanol from Q3. That's two deals in three quarters. Management framed it as priced "at the cost of liquefaction" with JKM/TTF exposure, which matches the premium-pricing thesis, but the "two-plus deals in 1H26" bar would need another announcement by July.

Continue monitoring

CEO search milestones. On track. Management described the search as "still kind of at the money" on the six-month prediction from the prior call. No drift, but no upside either.

Continue monitoring

Q1 FCF recovery. Resolved emphatically — Q1 FCF of $1.70B versus the $215M Q4 trough is a ~8x sequential step-up. Realized gas at $4.28/Mcf is the primary driver, supported by the synergized cost base. The $1B debt-paydown commitment is no longer at risk of being pressured; it's already done.

Resolved positively

What to watch into next quarter

Buyback cadence. With $150M repurchased through April 24 and the debt-reduction bar already cleared, watch whether Q2 quarterly buyback pace lands above $200M — that would confirm a structural shift to capital-return emphasis rather than a one-time gesture while the new CFO settles in.

Realized gas price spread vs. mid-cycle anchor. Q1's $4.28/Mcf realization is doing most of the heavy lifting on EBITDAX. A sub-$3.50 Q2 realization would test whether the operating model holds without commodity tailwind.

Western Haynesville second-well results. The first well has been online ~7 weeks at print; the second spud last week sits 15 miles north. Q2 will be the first quarter with two wells producing — watch for any quantified production rate or cost-per-foot disclosure versus the NFZ baseline.

Third marketing/LNG offtake announcement. Delfin makes two LNG-linked deals in three quarters. A third deal by Q2 print would convert "thesis lever" into "operating model"; absence would mean the cadence remains episodic.

Southwest Appalachia inflection. A second consecutive flat-to-positive YoY print would confirm the basin has stabilized. A return to negative growth would suggest the 11–12 rig program is increasingly tilted toward Haynesville, with implications for the FY27 capital framework.

Sources

Expand Energy Q1 2026 press release, filed with SEC: https://www.sec.gov/Archives/edgar/data/895126/000089512626000027/exe-ex_991x20260331x8kxpr.htm
Expand Energy Q1 2026 earnings call Q&A excerpts.

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