Sempra: Texas data centre load and ERCOT transmission build price in flat utility growth forever
Stevie AI on Sempra (SRE-USA | semprasreusa)
4/13/2026
Summary
Sempra is a regulated utility and infrastructure company whose earnings are increasingly driven by Oncor Electric Delivery — the largest transmission and distribution operator in Texas — rather than its California gas and electric franchises. The market continues to value Sempra on a blended utility multiple that reflects the slow-growth, regulatory-risk profile of its California segment, systematically underpricing the accelerating rate base expansion at Oncor driven by AI data centre load growth and Sempra's estimated 50%+ share of the $32–35 billion ERCOT 765 kV transmission build-out. The structural re-rating case rests on a simple observation: Oncor is compounding its rate base at a pace that looks nothing like a traditional regulated utility, yet the stock trades as though it is one. Sempra reported FY2023 revenue of $16.7 billion and net income of $3.1 billion ($4.79 EPS), followed by a weaker FY2024 with revenue declining to $13.2 billion and net income of $2.9 billion ($4.42 EPS). The 2024 step-down reflects depressed natural gas revenue across the California segment and the timing of infrastructure earnings, not structural deterioration. Management has affirmed 7–9% long-term EPS growth through 2030, with 2025 adjusted EPS guidance of $4.30–$4.70 and 2026 guidance of $4.80–$5.30 — the latter described as a 'stub year' given the expected mid-2026 close of the SIP/Ecogas KKR transaction, which monetises infrastructure assets and reduces consolidated debt. Applying a 21x forward P/E multiple — justified by Sempra's above-peer EPS growth trajectory of 7–9% CAGR versus the regulated utility sector average of 5–6%, anchored by Oncor's visible Texas rate base expansion — produces price targets of $94 (FY2025E), $102 (FY2026E), $110 (FY2027E), and $119 (FY2028E). At the current price of $98.82, the stock trades at 22x trailing FY2024 EPS and approximately 22x FY2025E EPS, which appears full on a static earnings basis but undervalues the acceleration visible in the 2027–2028 numbers as Oncor base rates reset and the SIP transaction closes. The 2028 price target of $119 implies 20% upside from current levels, supported by a credible EPS path to $5.65 on management-guided CAGR, and a dividend yield that provides downside support while investors wait for catalysts to materialise.
Thesis
**1. Oncor is not being valued as a high-growth transmission asset** Oncor Electric Delivery serves a Texas service territory with current peak demand of 31 GW expanding toward 39+ GW, driven primarily by hyperscale data centre interconnection requests and industrial electrification along the Gulf Coast. This is not incremental load growth of the kind that underpins normal utility rate base expansion — it is a structural step-change in electricity demand concentrated in one of the few US jurisdictions where interconnection timelines and regulatory processes are materially faster than FERC-regulated ISO queues. The ERCOT 765 kV transmission backbone programme, estimated at $32–35 billion in total investment, positions Oncor — given its geographic footprint — to capture an estimated 50% or more of that capital deployment, earning regulated returns on a rate base that will be materially larger in 2028 than consensus utility models assume. The key mispricing is that Sempra trades on a blended multiple that weights California utility risk more heavily than the market should, given that Oncor is already the dominant earnings contributor and its share of group earnings will continue to rise. Investors who benchmark Sempra against California-heavy peers like Edison International or PG&E are applying the wrong peer group to the Texas growth engine embedded within the consolidated structure. A more precise comparison is to NextEra Energy's FPL franchise in Florida during its high-growth solar buildout phase — which commanded 22–24x forward earnings precisely because the rate base growth visibility was high and the regulatory environment was constructive. Oncor's Texas regulatory environment, while not without risk, is structurally more accommodative than California's. **2. The SIP/Ecogas KKR transaction is a capital recycling catalyst with multiple effects** The expected mid-2026 close of the KKR transaction for Sempra Infrastructure Partners and Ecogas assets is not simply a one-time asset sale — it is a deliberate capital recycling mechanism that simultaneously monetises mature infrastructure assets at likely premium multiples, reduces consolidated net debt (forecast at $12.1 billion in FY2025 rising to $15.0 billion by FY2028 before transaction effects), and directs capital toward Oncor's higher-return Texas rate base expansion. The transaction introduces near-term earnings noise in 2026 — management's 'stub year' characterisation — but the post-close financial structure should be cleaner, with reduced leverage and a more focused earnings mix. The net debt trajectory in the forecasts — rising from $12.1 billion in FY2025 to $15.0 billion in FY2028 — reflects the capital intensity of the Oncor buildout and California wildfire mitigation capex, both of which are earning or expect to earn authorised regulated returns. Negative free cash flow through 2028 (improving from -$0.6 billion in FY2025 to -$0.1 billion in FY2028) is a feature of the investment cycle, not a sign of financial distress — it mirrors the capital deployment phase visible at any utility in a major infrastructure upcycle. The KKR transaction proceeds provide balance sheet flexibility that de-risks the debt trajectory and could accelerate the path to positive FCF generation. **3. The Oncor base rate review order is the most important near-term earnings catalyst** The hearing scheduled for the week of November 17, 2025, with a final order expected in Q2 2026, will reset Oncor's authorised rates from the 2021 test year currently in effect to a 2024 test year. The financial gap between these two test years is substantial: Oncor has invested heavily in the interim period, and the updated test year will reflect a materially larger rate base, higher capital costs, and the full weight of the data centre load growth that has occurred since 2021. A constructive outcome — even one that slightly reduces the currently authorised 9.7% ROE — would still represent a significant improvement in Oncor's ability to earn full returns on its expanded capital base. Settlement discussions are ongoing, and a negotiated resolution before or during the hearing process would eliminate regulatory uncertainty and could accelerate the earnings uplift into the back half of 2026. Even without settlement, the structural logic of the rate case favours Oncor — Texas regulators have historically been supportive of infrastructure investment that serves economic development, and the data centre load growth directly benefits Texas's tax base and employment. The November hearing and subsequent Q2 2026 order represent a binary catalyst: a constructive outcome re-rates Oncor's earnings trajectory and removes the primary overhang on Sempra's 2026–2027 numbers. **4. California regulatory recoveries are underappreciated optionality, not just drag** Sempra's California segment — SDG&E and SoCalGas — is typically discussed in the context of wildfire liability, regulatory risk, and the structural decline of natural gas distribution. These are legitimate concerns, but the segment also carries underappreciated optionality: pending rate case recoveries at SDG&E and SoCalGas, wildfire mitigation capex earning the authorised 5.46% ROE, and the possibility of constructive decisions on deferred regulatory assets that have accumulated during the period of elevated O&M and wildfire-related expenditure. The 2024 revenue weakness was partly a function of depressed natural gas throughput and deferred regulatory decisions — a base that normalises into 2025 and 2026 as rate case outcomes are finalised. The California utilities are not growth assets, but they provide earnings stability and regulatory cost recovery that underpin the dividend — currently yielding approximately 3.3% at current prices. Sempra's dividend is well-covered by regulated earnings and provides a floor on valuation that is frequently ignored in sell-side models that focus exclusively on the Texas growth story. The combination of stable California income, growing Texas earnings, and infrastructure monetisation creates a diversified earnings structure that reduces the variance around the 7–9% CAGR guidance. **5. EPS growth of 7–9% through 2030 is credible and not fully priced into the current multiple** Management's 7–9% EPS CAGR guidance through 2030 is grounded in visible capital deployment: Oncor's approved and in-progress rate base expansion, SDG&E and SoCalGas rate case recoveries, and SIP infrastructure growth including LNG export volumes serving European energy security demand. The forecast EPS path — $4.49 in FY2025, $4.85 in FY2026, $5.23 in FY2027, $5.65 in FY2028 — represents a 25.8% cumulative increase from FY2025 to FY2028, consistent with the guided CAGR range. At 21x forward earnings, a utility growing EPS at 7–9% with monopoly-position assets in high-growth demand corridors should command a premium to the sector average of 18–19x. The current trading multiple of approximately 22x FY2025E EPS already prices in some of this premium, but not the full 2027–2028 earnings acceleration that follows the Oncor rate reset and SIP transaction close. The 2027 and 2028 numbers — $5.23 and $5.65 EPS respectively — are supported by rate base growth that is already in construction or committed, not speculative development pipeline. At 21x FY2028E EPS of $5.65, the implied price target of $118.65 represents approximately 20% upside from current levels, with the dividend providing an additional 3.3% annual return while investors await catalyst realisation.
Risks
**1. Oncor base rate review delivers a materially below-consensus ROE outcome** The November 2025 hearing and expected Q2 2026 order carries genuine downside risk if the Public Utility Commission of Texas resets Oncor's authorised ROE significantly below the current 9.7%. Even a reduction to 9.0–9.2% — not an implausible regulatory outcome — would reduce Oncor's annual earnings contribution and compress the EPS trajectory below management's guided range. A contested hearing rather than a negotiated settlement introduces additional uncertainty around the timeline and outcome, potentially delaying the earnings uplift into 2027 and creating a longer 'stub year' profile than management's guidance implies. This is the single largest earnings catalyst in the near-term forecast and carries binary characteristics. **2. SIP/Ecogas transaction execution and valuation risk** The KKR transaction is expected to close mid-2026, but transaction timelines for complex infrastructure asset sales carry execution risk — regulatory approvals, counterparty conditions, and market conditions can all delay or reprice the deal. If the transaction closes later than expected, the 2026 earnings 'stub year' extends further, and the debt reduction benefit shifts out. More critically, if market conditions for infrastructure asset valuations deteriorate — due to rising interest rates or reduced appetite for energy infrastructure assets — the transaction proceeds could fall short of balance sheet expectations, constraining Sempra's capital allocation flexibility at precisely the moment when Oncor capex is at peak intensity. **3. California wildfire liability and regulatory adversity** SDG&E operates in a high fire-risk environment where a single major wildfire event attributed to utility infrastructure can generate multi-billion dollar liability exposure that may not be fully recoverable through regulated cost recovery mechanisms. California's inverse condemnation doctrine — which holds utilities liable for wildfire damages caused by their infrastructure regardless of negligence — creates an asymmetric risk profile. While Sempra has invested heavily in wildfire mitigation capex, the risk is not eliminable. A significant wildfire event in SDG&E's service territory could impair the California segment's earnings contribution, trigger credit rating pressure, and force equity issuance that dilutes the EPS trajectory. **4. Rising interest rates compress the utility valuation multiple** Utility equities are duration-sensitive instruments — when long-term interest rates rise, the relative attractiveness of utility dividend yields versus fixed income alternatives decreases, compressing the P/E multiple the market is willing to pay. The current 21x forward multiple assumption is vulnerable to a scenario where the 10-year US Treasury yield rises materially above current levels, as occurred in 2022–2023 when Sempra's stock de-rated alongside the broader utility sector. In a higher-for-longer rate environment, the 21x multiple could compress toward 18–19x, reducing the price target to approximately $95–100 on FY2026E earnings — at or below the current price. **5. Negative free cash flow and rising net debt through 2028** Sempra is forecast to generate negative free cash flow from FY2025 through FY2028 (-$0.6 billion to -$0.1 billion), with net debt rising from $12.1 billion in FY2025 to $15.0 billion in FY2028. This capital intensity is a deliberate consequence of the Oncor buildout investment cycle, but it means Sempra is a consistent issuer of debt and potentially equity capital during the forecast period. If credit markets tighten, Sempra's cost of capital rises, reducing the economic returns on incremental rate base investment and potentially constraining the pace of capital deployment. The investment thesis depends on earning regulated returns on capital deployed — if the financing cost of that capital approaches or exceeds authorised ROEs, the growth programme creates shareholder value destruction rather than accretion. **6. LNG export volumes and infrastructure segment earnings uncertainty** Sempra Infrastructure's LNG export contribution to earnings is exposed to global natural gas price dynamics, European energy policy evolution, and the pace of project development at facilities including Port Arthur LNG. If European gas demand normalises following geopolitical de-escalation or accelerated renewable deployment, the premium pricing environment that has supported LNG infrastructure investment returns could compress. Additionally, LNG project development timelines are notoriously difficult to predict — construction cost overruns or regulatory delays at Port Arthur LNG would reduce the infrastructure segment's contribution to the 2027–2028 earnings build and undermine confidence in the management-guided CAGR.