Public Service Enterprise Group (PSEG) generated $362 million of cash after property and equipment investment in the first half of 2026, leaving a $306 million gap against $668 million of dividends. Operating cash flow improved, but still did not cover those investments and distributions combined. Borrowing helped fund overall cash needs, while energy-contract valuation changes weighed on reported earnings. For this regulated utility and nuclear generator, recovering investment through customer rates and managing financing costs matter alongside electricity sales. Q2 2026 Form 10-Q, consolidated cash flows, p. 5; management discussion, pp. 67–71.
1. Infrastructure Increased More in Dollars Than Internally Retained Profit
Net property and equipment rose $867M, while retained earnings increased $407M. Infrastructure therefore increased more in dollars than accumulated profit after dividends, but grew more slowly in percentage terms: 2.06% versus 3.03%. That comparison describes balance-sheet growth; the cash-flow statement shows how investment and distributions were funded. Dollar amounts below are in millions unless otherwise stated.
1-1. Physical Assets Accounted for Most of the Expansion
The largest dollar increase below is in infrastructure, rather than customer receivables.
| Consolidated item ($M) | Dec. 31, 2025 | June 30, 2026 | Change |
|---|---|---|---|
| Cash and equivalents | 132 | 192 | 45.5% |
| Accounts receivable, net | 1,888 | 1,903 | 0.8% |
| Fuel inventory | 282 | 222 | −21.3% |
| Materials and supplies, net | 873 | 868 | −0.6% |
| Property and equipment, net | 42,064 | 42,931 | 2.1% |
| Intangible assets | Not separately presented | Not separately presented | — |
| Total assets | 57,576 | 58,813 | 2.1% |
Capital additions outpaced depreciation, although those two lines alone do not reconcile the entire asset movement. Fuel stocks fell, but the filing does not establish a demand conclusion from that decline. Unbilled customer revenue—revenue earned but not yet billed—is separate from the receivables shown above. Consolidated balance sheets, p. 3.
1-2. Borrowings Rose Even as Short-Term Funding Fell
Reported borrowings increased from $24,074M to $24,541M, calculated by adding long-term debt, debt due within one year, and commercial paper and loans. Commercial paper is short-term borrowing. Accounts payable, an operating obligation, fell from $1,489M to $1,305M. First-half interest expense increased from $489M to $541M, reflecting additional debt and refinancing at higher rates.
Long-term debt due within one year was $850M. A complete three-year maturity percentage and weighted average interest rate across the debt portfolio are not disclosed in this quarterly report. Operating lease assets, representing the right to use leased property, were $150M versus $138M; noncurrent operating lease liabilities were $137M versus $128M. These balance-sheet comparisons are June 30, 2026, against December 31, 2025. Balance sheets, pp. 3–4; management discussion, pp. 66, 68–70.
1-3. Retained Earnings Supported Equity Despite Distributions
Retained earnings rose from $13,446M to $13,853M: $1,075M of profit less $668M of dividends. Retained earnings are accumulated accounting profits, not a cash reserve. The common-stock capital account fell from $5,062M to $5,026M, while treasury stock’s negative balance increased from $1,435M to $1,471M. Accumulated other comprehensive losses, which track certain changes outside net income, narrowed from $91M to $79M.
Together, these movements lifted equity from $16,982M to $17,329M. Calculated total liabilities of $41,484M plus equity reconcile to $58,813M of assets. Treasury stock represents the company’s own shares held by the company; movements in that account should not be equated with cash buybacks without the corresponding transaction detail. Consolidated equity statement, p. 6; balance sheet, p. 4.
2. Utility Earnings Improved While Group Margins Fell
Revenue growth did not translate into higher consolidated profit. First-half sales rose 6.2%, but operating income fell 4.8% and net income declined 8.4%.
2-1. Profit Remained Above 2024 Despite the Latest Decline
Compare margins with revenue: a larger sales base produced less profit than last year.
| Consolidated measure | H1 2024 | H1 2025 | H1 2026 | Annualized change, 2024–26 |
|---|---|---|---|---|
| Revenue ($M) | 5,183 | 6,027 | 6,402 | 11.1% |
| Operating income ($M) | 1,267 | 1,614 | 1,536 | 10.1% |
| Operating margin | 24.4% | 26.8% | 24.0% | — |
| Net income ($M) | 966 | 1,174 | 1,075 | 5.5% |
| Net margin | 18.6% | 19.5% | 16.8% | — |
Operating margin is the share of revenue left after operating expenses, before interest and taxes. PSEG earned about $24 in operating profit per $100 of sales, down from $26.80. Net margin measures the share remaining as net income. These are three comparable half-years; annualized growth spans two years, calculated as (2026 amount / 2024 amount)^(1/2) − 1. 2026 10-Q, p. 1; 2025 10-Q, p. 1.
The second quarter was weaker on a reported net-income basis: net income fell from $585M to $334M. Management attributes much of the generation-revenue decline to energy contracts being revalued at current market prices. Such changes can affect profit before contracts settle in cash; they are not automatically exceptional items to remove from “normal” earnings.
The earnings release provides an important counterpoint. PSEG’s adjusted profit measure, called non-GAAP Operating Earnings, rose from $384M to $425M in Q2 and from $1,102M to $1,203M in H1. It excludes energy-contract valuation effects, investment results from funds reserved for future nuclear-plant dismantling, and certain other items. This company-defined measure differs from both reported net income and the operating income in the table above. PSEG also maintained its full-year 2026 adjusted earnings outlook of $4.28–$4.40 per share; that is management guidance, not a reported result. PSEG Q2 2026 earnings release.
Meanwhile, regulated subsidiary Public Service Electric and Gas Company (PSE&G) increased first-half net income from $878M to $919M. Group diluted earnings per share, which allow for potentially dilutive shares from items such as stock awards, fell from $2.35 to $2.15. Average diluted shares were only slightly lower, at 499M versus 500M. The profit decline overwhelmingly explains the per-share decline. 2026 10-Q, pp. 1, 7, 67–68.
2-2. Higher Energy Bills Did Not Necessarily Add Profit
First-half energy costs rose from $2,012M to $2,373M, while operation and maintenance expense increased from $1,773M to $1,843M. PSE&G passes supply costs through to customers without earning a margin on that service. Some program-related revenues similarly reimburse costs, making sales growth an imperfect measure of underlying improvement.
Dividing the 4.8% operating-profit decline by the 6.2% revenue increase gives approximately −0.8. This simply compares two percentage changes; it does not show that each 1% increase in sales caused profit to fall by 0.8%. Contract revaluations and cost recovery affect the two measures differently, and the filing does not provide a complete split between costs that stay fixed and those that vary with business activity. The useful finding is that higher revenue did not translate into higher operating profit in this half-year. Consolidated operations, p. 1; management discussion, pp. 65–68.
3. Cash Improved, but Dividends Still Required Other Funding
Operating cash flow rose 19.3%, yet the residual after capital spending remained below dividends.
The final two rows show how much cash remained and how much was distributed. Free cash flow here means operating cash flow less property and equipment additions; it is a calculated measure, not a separate line in the financial statements.
| Consolidated cash measure ($M) | H1 2025 | H1 2026 | Year-over-year change ($M) |
|---|---|---|---|
| Operating cash flow | 1,527 | 1,821 | 294 |
| Investing cash flow | −1,388 | −1,451 | −63 |
| Financing cash flow | −78 | −310 | −232 |
| Ending cash, including restricted cash | 215 | 216 | 1 |
| Property and equipment additions | 1,415 | 1,459 | 44 |
| Free cash flow: operating cash less additions | 112 | 362 | 250 |
| Cash dividends | 629 | 668 | 39 |
The $1M increase in ending cash compares June 2026 with June 2025. During H1 2026 itself, cash including restricted cash rose $60M, from $156M to $216M: $1,821M of operating inflows less $1,451M of investing outflows and $310M of financing outflows.
The cash-flow statement includes restricted cash—cash whose use is limited; the balance-sheet cash and equivalents amount was $192M. Net long-term borrowing was $1,050M, calculated as $1,500M issued less $450M repaid. Commercial paper declined $579M, so borrowing both supported spending and changed the funding mix. Cash flows, p. 5; Note 1, p. 14.
Operating cash flow exceeded accounting profit by a wider margin, but that alone does not establish how sustainable the earnings are. The table pairs each cash total with the profit used in the calculation.
| Cash conversion | H1 2024 | H1 2025 | H1 2026 |
|---|---|---|---|
| Operating cash / net income ($M) | 1,143 / 966 | 1,527 / 1,174 | 1,821 / 1,075 |
| Ratio | 1.18× | 1.30× | 1.69× |
Depreciation and amortization added back $650M, versus $628M a year earlier. These expenses allocate asset costs over time and reduce profit without representing a current-period operating cash payment. The reconciliation also added back $300M of energy-contract and other derivative losses, versus subtracting $13M of gains previously.
Cash timing mattered too. Net tax refunds were $263M versus $55M. Changes in regulatory assets and liabilities—balances associated with costs and revenues recovered or returned through customer rates—contributed $298M versus $110M. Offsetting these benefits, prepayments absorbed $350M versus $248M, and cash posted as collateral absorbed $192M versus $13M. These are selected drivers, not a complete reconciliation, and help explain why cash improved while profit fell. 2026 cash flows, p. 5; 2025 cash flows, p. 5.
Capital additions were 22.8% of revenue: $1,459M divided by $6,402M. Disclosed uses include grid reliability, nuclear projects and technology; no maintenance-versus-growth split is provided. Energy-efficiency program spending of $263M already reduced operating cash, while customer equipment financing also used investing cash. Consequently, the $362M measure is not cash remaining after every investment activity. Cash flows, p. 5; capital requirements, p. 71.
4. Higher Nuclear Capacity Payments Face Regulatory Counterweights
Contracted capacity prices support nuclear revenue, but regulation can offset part of the benefit. Capacity payments compensate generators for being available, separately from electricity actually sold. Expected average prices rose from $270 to $329 per megawatt-day for delivery years beginning June 2025 and June 2026, with 3,500 megawatts accepted in the capacity market in each year. A megawatt-day measures one megawatt of capacity available for one day. That is a 21.9% price increase, not an equivalent increase in total nuclear profit. Note 2, p. 20.
Another offset is the end of New Jersey’s zero-emission certificate payments, which compensated eligible nuclear plants for producing electricity without carbon emissions. ZEC eligibility ended effective June 1, 2025, but PSE&G’s final ZEC payment to PSEG Power settled in August 2025. PSEG identified their absence as a partial offset to higher realized power prices and nuclear generation in Q2 2026. PSEG Q2 2026 earnings release.
Recovering regulated investment through customer rates is the second key measure. Approval of a $23M annual gas revenue increase supports recovery of completed pipeline investments. Pending rate requests remain uncertain, while mandatory regional grid membership could remove an incentive currently included in the returns PSE&G is allowed to earn on transmission investment. Note 4, p. 21; regulatory discussion, p. 59.
Environmental exposure also remains open. PSEG recorded an approximately $66M liability for the Lower Passaic River matter, but says additional costs could be material and cannot be estimated. That recorded amount is therefore not a maximum potential loss. Note 8, p. 32.
5. Investment Recovery Must Keep Pace With Financing Costs
The regulated utility grew earnings, and higher capacity payments support nuclear revenue. Group profit nevertheless remains exposed to contract valuations, borrowing costs and regulatory decisions. Reported net income fell even as the company’s adjusted earnings measure improved. Property and equipment investment plus dividends exceeded operating cash flow, making continued financing access part of the operating plan.
If approved investments translate into timely recovery through customer rates, the expanding asset base can support future earnings. If recovery slows or refinancing becomes more expensive, more revenue may be needed merely to preserve returns. PSEG’s predominantly regulated business is best assessed through that funding relationship, rather than assigning it a commodity-cycle peak or trough.
Source: SEC Form 10-Q dated August 4, 2026, accession 0001193125-26-332943; historical comparisons use Form 10-Q dated August 5, 2025. Additional context on adjusted earnings, guidance and nuclear support payments comes from PSEG’s August 4, 2026 earnings release, linked above. Interim financial results are unaudited; year-end balance-sheet comparisons are derived from audited financial statements. H1 means the six months ended June 30. Group figures are consolidated; PSE&G figures are explicitly identified. Dollar amounts are in millions unless otherwise stated. Changes, margins, growth rates, borrowing totals and cash-conversion measures are calculated from the filing amounts as presented, before rounding the resulting calculations.
This analysis is based on filings submitted to the U.S. Securities and Exchange Commission and is provided for informational purposes only. It is not investment advice.