2020<\/b><\/p>\n<\/td>\n<\/tr>\n\n| \n Operating revenues<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | | \n\n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | | <\/tr>\n
\n| \n \nElectric\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n2,870\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n2,203\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n |
\n| \n \nNatural gas\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n647\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n583\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n |
\n| \n \nOther\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n24\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n25\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n |
\n| \n \nTotal operating revenues\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n3,541\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n2,811\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n |
\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | | \n\n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | | <\/tr>\n
\n| \n Operating expenses<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | | \n\n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | | <\/tr>\n
\n| \n \nElectric fuel and purchased power\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n1,386\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n797\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n |
\n| \n \nCost of natural gas sold and transported\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n299\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n285\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n |
\n| \n \nCost of sales \u2014 other\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n8\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n9\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n |
\n| \n \nOperating and maintenance expenses\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n584\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n579\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n |
\n| \n \nConservation and demand side management expenses\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n73\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n74\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n |
\n| \n \nDepreciation and amortization\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n521\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n463\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n |
\n| \n \nTaxes (other than income taxes)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n163\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n149\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n |
\n| \n \nTotal operating expenses\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n3,034\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n2,356\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n |
\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | | \n\n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | | <\/tr>\n
\n| \n Operating income<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n507\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n455\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n |
\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | | \n\n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | | <\/tr>\n
\n| \n \nOther income (expense), net\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n5\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(11\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n<\/tr>\n |
\n| \n \nEquity earnings of unconsolidated subsidiaries\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n14\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n11\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n |
\n| \n \nAllowance for funds used during construction \u2014 equity\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n14\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n23\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n |
\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | | \n\n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | | <\/tr>\n
\n| \n Interest charges and financing costs<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | | \n\n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | | <\/tr>\n
\n| \n \nInterest charges \u2014 includes other financing costs of $7 and $7, respectively\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n205\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n199\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n |
\n| \n \nAllowance for funds used during construction \u2014 debt\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(5\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(10\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n<\/tr>\n |
\n| \n \nTotal interest charges and financing costs\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n200\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n189\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n |
\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | | \n\n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | | <\/tr>\n
\n| \n Income before income taxes<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n340\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n289\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n |
\n| \n \nIncome tax benefit\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(22\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(6\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n<\/tr>\n |
\n| \n Net income<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n362\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n295\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n |
\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | | \n\n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | | <\/tr>\n
\n| \n Weighted average common shares outstanding:<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | | \n\n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | | <\/tr>\n
\n| \n \nBasic\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n538\n<\/p>\n<\/td>\n | | \n\n \n\u00a0\n<\/p>\n<\/td>\n | \n \n526\n<\/p>\n<\/td>\n | | <\/tr>\n
\n| \n \nDiluted\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n539\n<\/p>\n<\/td>\n | | \n\n \n\u00a0\n<\/p>\n<\/td>\n | \n \n527\n<\/p>\n<\/td>\n | | <\/tr>\n
\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | | \n\n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | | <\/tr>\n
\n| \n Earnings per average common share:<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | | \n\n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | | <\/tr>\n
\n| \n \nBasic\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n0.67\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n0.56\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n |
\n| \n \nDiluted\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n0.67\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n0.56\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n<\/table>\n XCEL ENERGY INC. AND SUBSIDIARIES
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<\/b>Notes to Investor Relations Earnings Release (Unaudited)\n<\/p>\n \nDue to the seasonality of Xcel Energy\u2019s operating results, quarterly financial results are not an appropriate base from which to project annual results.\n<\/p>\n Non-GAAP Financial Measures<\/b><\/p>\n \nThe following discussion includes financial information prepared in accordance with generally accepted accounting principles (GAAP), as well as certain non-GAAP financial measures such as ongoing return on equity (ROE), electric margin, natural gas margin, ongoing earnings and ongoing diluted EPS. Generally, a non-GAAP financial measure is a measure of a company\u2019s financial performance, financial position or cash flows that excludes (or includes) amounts that are adjusted from measures calculated and presented in accordance with GAAP. Xcel Energy\u2019s management uses non-GAAP measures for financial planning and analysis, for reporting of results to the Board of Directors, in determining performance-based compensation and communicating its earnings outlook to analysts and investors. Non-GAAP financial measures are intended to supplement investors\u2019 understanding of our performance and should not be considered alternatives for financial measures presented in accordance with GAAP. These measures are discussed in more detail below and may not be comparable to other companies\u2019 similarly titled non-GAAP financial measures.\n<\/p>\n Ongoing ROE<\/span><\/p>\n\nOngoing ROE is calculated by dividing the net income or loss of Xcel Energy or each subsidiary, adjusted for certain nonrecurring items, by each entity\u2019s average stockholder\u2019s equity. We use these non-GAAP financial measures to evaluate and provide details of earnings results.\n<\/p>\n Electric and Natural Gas Margins<\/span><\/p>\n\nElectric margin is presented as electric revenues less electric fuel and purchased power expenses. Natural gas margin is presented as natural gas revenues less the cost of natural gas sold and transported. Expenses incurred for electric fuel and purchased power and the cost of natural gas are generally recovered through various regulatory recovery mechanisms. As a result, changes in these expenses are generally offset in operating revenues. Management believes electric and natural gas margins provide the most meaningful basis for evaluating our operations because they exclude the revenue impact of fluctuations in these expenses. These margins can be reconciled to operating income, a GAAP measure, by including other operating revenues, cost of sales – other, operating and maintenance (O&M) expenses, conservation and demand side management (DSM) expenses, depreciation and amortization and taxes (other than income taxes).\n<\/p>\n Earnings Adjusted for Certain Items (Ongoing Earnings and Ongoing Diluted EPS)<\/span><\/p>\n\nGAAP diluted EPS reflects the potential dilution that could occur if securities or other agreements to issue common stock (i.e., common stock equivalents) were settled. The weighted average number of potentially dilutive shares outstanding used to calculate Xcel Energy Inc.\u2019s diluted EPS is calculated using the treasury stock method. Ongoing earnings reflect adjustments to GAAP earnings (net income) for certain items. Ongoing diluted EPS is calculated by dividing the net income or loss of each subsidiary, adjusted for certain items, by the weighted average fully diluted Xcel Energy Inc. common shares outstanding for the period. Ongoing diluted EPS for each subsidiary is calculated by dividing the net income or loss of such subsidiary, adjusted for certain items, by the weighted average fully diluted Xcel Energy Inc. common shares outstanding for the period.\n<\/p>\n \nWe use these non-GAAP financial measures to evaluate and provide details of Xcel Energy\u2019s core earnings and underlying performance. We believe these measurements are useful to investors to evaluate the actual and projected financial performance and contribution of our subsidiaries. For the three months ended March 31, 2021 and 2020, there were no such adjustments to GAAP earnings and therefore GAAP earnings equal ongoing earnings for these periods.\n<\/p>\n Note 1. Earnings Per Share Summary<\/span><\/b><\/p>\n\nXcel Energy\u2019s 2021 first quarter earnings were $0.67 per share compared to $0.56 per share in 2020, primarily reflecting higher electric and natural gas margins (driven by capital investment recovery and regulatory outcomes), which more than offset additional depreciation, interest charges, less AFUDC and declining sales primarily due to the impacts of COVID-19. First quarter earnings also reflect margin from proprietary commodity trading transactions, primarily entered into under Xcel Energy\u2019s ordinary practices prior to the weather event. See Note 5 for further discussion.\n<\/p>\n \nSummarized diluted EPS for Xcel Energy:\n<\/p>\n \n\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n Three Months Ended March 31<\/b><\/p>\n<\/td>\n<\/tr>\n\n| \n Diluted Earnings (Loss) Per Share<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n 2021<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n 2020<\/b><\/p>\n<\/td>\n<\/tr>\n\n| \n \nPSCo\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n0.31\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n0.24\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nNSP-Minnesota\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n0.24\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n0.20\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nSPS\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n0.11\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n0.08\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nNSP-Wisconsin\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n0.06\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n0.06\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nEquity earnings of unconsolidated subsidiaries\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n0.01\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n0.01\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nRegulated utility (a)<\/sup><\/p>\n<\/td>\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n0.73\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n0.60\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nXcel Energy Inc. and Other\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(0.06\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(0.04\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n Total (a)<\/sup><\/b><\/p>\n<\/td>\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n $<\/b><\/p>\n<\/td>\n | \n 0.67<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n $<\/b><\/p>\n<\/td>\n | \n 0.56<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n<\/table>\n (a) <\/sup>Amounts may not add due to rounding.\n<\/p>\nPSCo <\/i><\/b>\u2014 Earnings increased $0.07 per share for the first quarter of 2021, reflecting higher natural gas and electric margins (primarily capital investment recovery and regulatory outcomes), partially offset by additional depreciation and taxes (other than income taxes).\n<\/p>\n NSP-Minnesota <\/i><\/b>\u2014 Earnings increased $0.04 per share for the first quarter of 2021, reflecting higher electric margin (primarily capital investment recovery), partially offset by increased depreciation.\n<\/p>\n SPS <\/i><\/b>\u2014 Earnings increased $0.03 per share for the first quarter of 2021, reflecting higher electric margin (regulatory outcomes in Texas and New Mexico), partially offset by increased depreciation.\n<\/p>\n NSP-Wisconsin <\/i><\/b>\u2014 Earnings were flat for the first quarter of 2021.\n<\/p>\n Xcel Energy Inc. and Other <\/i><\/b>\u2014 Primarily includes financing costs at the holding company.\n<\/p>\n \nComponents significantly contributing to changes in 2021 EPS compared to 2020:\n<\/p>\n \n\n| \n Diluted Earnings (Loss) Per Share<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n Three Months
\n
Ended March 31<\/b><\/p>\n<\/td>\n<\/tr>\n\n| \n GAAP and ongoing diluted EPS – 2020<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n $<\/b><\/p>\n<\/td>\n | \n 0.56<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nComponents of change – 2021 vs. 2020\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nHigher electric margin\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n0.11\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nHigher natural gas margins\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n0.07\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nLower ETR (a)<\/sup><\/p>\n<\/td>\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n0.06\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nHigher other income (expense), net\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n0.02\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nHigher depreciation and amortization\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(0.08\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nLower AFUDC\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(0.02\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nHigher interest charges\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(0.01\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nHigher O&M\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(0.01\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nOther, net\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(0.03\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n GAAP and ongoing diluted EPS – 2021<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n $<\/b><\/p>\n<\/td>\n | \n 0.67<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n<\/table>\n (a)<\/sup> Includes production tax credits (PTCs) and plant regulatory amounts, which are primarily offset in electric margin.\n<\/p>\nNote 2. Regulated Utility Results<\/span><\/b><\/p>\nEstimated Impact of Temperature Changes on Regulated Earnings <\/i><\/b>\u2014 Unusually hot summers or cold winters increase electric and natural gas sales, while mild weather reduces electric and natural gas sales. The estimated impact of weather on earnings is based on the number of customers, temperature variances, the amount of natural gas or electricity historically used per degree of temperature and excludes any incremental related operating expenses that could result due to storm activity or vegetation management requirements. As a result, weather deviations from normal levels can affect Xcel Energy\u2019s financial performance.\n<\/p>\n \nDegree-day or Temperature-Humidity Index (THI) data is used to estimate amounts of energy required to maintain comfortable indoor temperature levels based on each day\u2019s average temperature and humidity. Heating degree-days (HDD) is the measure of the variation in the weather based on the extent to which the average daily temperature falls below 65\u00b0 Fahrenheit. Cooling degree-days (CDD) is the measure of the variation in the weather based on the extent to which the average daily temperature rises above 65\u00b0 Fahrenheit. Each degree of temperature above 65\u00b0 Fahrenheit is counted as one CDD, and each degree of temperature below 65\u00b0 Fahrenheit is counted as one HDD. In Xcel Energy\u2019s more humid service territories, a THI is used in place of CDD, which adds a humidity factor to CDD. HDD, CDD and THI are most likely to impact the usage of Xcel Energy\u2019s residential and commercial customers. Industrial customers are less sensitive to weather. Typically, sales are not impacted in the first or fourth quarter due to THI or CDD.\n<\/p>\n \nNormal weather conditions are defined as either the 10, 20 or 30-year average of actual historical weather conditions. The historical period of time used in the calculation of normal weather differs by jurisdiction, based on regulatory practice. To calculate the impact of weather on demand, a demand factor is applied to the weather impact on sales. Extreme weather variations, windchill and cloud cover may not be reflected in weather-normalized estimates.\n<\/p>\n \nPercentage increase (decrease) in normal and actual HDD:\n<\/p>\n \n\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n Three Months Ended March 31<\/b><\/p>\n<\/td>\n<\/tr>\n\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n 2021 vs.
\n
Normal<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n 2020 vs.
\n
Normal<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n 2021 vs. 2020<\/b><\/p>\n<\/td>\n<\/tr>\n\n| \n \nHDD\n<\/p>\n<\/td>\n | \n \n1.3\n<\/p>\n<\/td>\n | \n \n%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(5.5)\n<\/p>\n<\/td>\n | \n \n%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n6.5\n<\/p>\n<\/td>\n | \n \n%\n<\/p>\n<\/td>\n<\/tr>\n | \n | \n | \n | \n | \n | \n | \n | \n | \n\u00a0<\/td>\n<\/tr>\n<\/table>\n Weather<\/i><\/b> \u2014 Estimated impact of temperature variations on EPS compared with normal weather conditions:\n<\/p>\n\n\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n Three Months Ended March 31<\/b><\/p>\n<\/td>\n<\/tr>\n\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n 2021 vs.
\n
Normal<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n 2020 vs.
\n
Normal<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n 2021 vs. 2020<\/b><\/p>\n<\/td>\n<\/tr>\n\n| \n \nRetail electric\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n\u2014\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n(0.011\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n0.011\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nDecoupling and sales true-up\n<\/p>\n<\/td>\n | \n \n0.002\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n0.006\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(0.004\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nElectric total\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n0.002\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n(0.005\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n0.007\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nFirm natural gas\n<\/p>\n<\/td>\n | \n \n0.003\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(0.007\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n0.010\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nTotal\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n0.005\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n(0.012\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n0.017\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n<\/table>\n Sales <\/i><\/b>\u2014 Sales growth (decline) for actual and weather-normalized sales in 2021 compared to 2020:\n<\/p>\n\n\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n Three Months Ended March 31<\/b><\/p>\n<\/td>\n<\/tr>\n\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n PSCo<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n NSP-Minnesota<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n SPS<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n NSP-Wisconsin<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n Xcel Energy<\/b><\/p>\n<\/td>\n<\/tr>\n\n| \n Actual (a)<\/sup><\/b><\/p>\n<\/td>\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | | \n\n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nElectric residential\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n6.3\n<\/p>\n<\/td>\n | \n \n%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n5.1\n<\/p>\n<\/td>\n | \n \n%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n8.8\n<\/p>\n<\/td>\n | \n \n%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n4.7\n<\/p>\n<\/td>\n | \n \n%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n6.0\n<\/p>\n<\/td>\n | \n \n%\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nElectric C&I\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(4.8\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(6.6\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(7.1\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(1.8\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(5.8\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nTotal retail electric sales\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(1.0\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(2.9\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(4.3\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n0.2\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(2.4\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nFirm natural gas sales\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n4.7\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n0.5\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \nN\/A\n<\/p>\n<\/td>\n | | \n\n \n\u00a0\n<\/p>\n<\/td>\n | \n \n0.8\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n3.1\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n<\/table>\n \n\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n Three Months Ended March 31<\/b><\/p>\n<\/td>\n<\/tr>\n\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n PSCo<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n NSP-Minnesota<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n SPS<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n NSP-Wisconsin<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n Xcel Energy<\/b><\/p>\n<\/td>\n<\/tr>\n\n| \n Weather-Normalized (a)<\/sup><\/b><\/p>\n<\/td>\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nElectric residential\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n4.9\n<\/p>\n<\/td>\n | \n \n%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n4.5\n<\/p>\n<\/td>\n | \n \n%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n3.8\n<\/p>\n<\/td>\n | \n \n%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n2.9\n<\/p>\n<\/td>\n | \n \n%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n4.4\n<\/p>\n<\/td>\n | \n \n%\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nElectric C&I\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(5.1\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(6.7\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(7.3\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(1.9\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(6.0\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nTotal retail electric sales\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(1.7\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(3.1\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(5.4\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(0.4\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(3.0\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nFirm natural gas sales\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(0.9\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(1.3\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \nN\/A\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(2.7\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(1.2\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n<\/tr>\n<\/table>\n \n\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n Three Months Ended March 31 (2020 Leap Year Adjusted)<\/b><\/p>\n<\/td>\n<\/tr>\n\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n PSCo<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n NSP-Minnesota<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n SPS<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n NSP-Wisconsin<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n Xcel Energy<\/b><\/p>\n<\/td>\n<\/tr>\n\n| \n Weather-Normalized (a)<\/sup><\/b><\/p>\n<\/td>\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nElectric residential\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n6.1\n<\/p>\n<\/td>\n | \n \n%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n5.7\n<\/p>\n<\/td>\n | \n \n%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n5.0\n<\/p>\n<\/td>\n | \n \n%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n4.0\n<\/p>\n<\/td>\n | \n \n%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n5.6\n<\/p>\n<\/td>\n | \n \n%\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nElectric C&I\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(4.1\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(5.6\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(6.3\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(0.8\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(5.0\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nTotal retail electric sales\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(0.6\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(2.0\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(4.3\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n0.7\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(1.9\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nFirm natural gas sales\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n0.2\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(0.2\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \nN\/A\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(1.5\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u2014\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n<\/table>\n (a)<\/sup> Higher residential sales and lower commercial and industrial (C&I) sales were primarily attributable to COVID-19.\n<\/p>\nWeather-normalized and leap-year adjusted electric sales growth (decline) \u2014 year-to-date (excluding leap day)<\/span><\/p>\n\nEach of our utility subsidiaries experienced higher residential sales and lower C&I sales as a result of COVID-19 beginning in March 2020. In addition, the following items impacted sales:\n<\/p>\n \n- \nPSCo \u2014 Residential sales rose based on an increased number of customers and higher use per customer. The decline in C&I sales was primarily due to decreases in the manufacturing and service industries, partially offset by an increase in the energy sector.\n<\/li>\n
- \nNSP-Minnesota \u2014 Residential sales growth reflects higher use per customer and increased customer additions. The decline in C&I sales was primarily due to decreases within the manufacturing and service sectors.\n<\/li>\n
- \nSPS \u2014 Residential sales increased due to customer growth and higher use per customer. The decline in C&I sales was driven by decreases within the energy and manufacturing sectors.\n<\/li>\n
- \nNSP-Wisconsin \u2014 Residential sales growth was attributable to customer additions and higher use per customer. The decline in C&I sales was largely related to decreases in the energy and manufacturing industries, partially offset by an increase in the service sector.\n<\/li>\n<\/ul>\n
Weather-normalized and leap-year adjusted natural gas sales growth (decline) \u2014 year-to-date (excluding leap day)<\/span><\/p>\n\n- \nNatural gas sales primarily reflect lower customer use, offset by an increase in the number of customers.\n<\/li>\n<\/ul>\n
Electric Margin <\/i><\/b>\u2014 Electric revenues and fuel and purchased power expenses are impacted by fluctuations in the price of natural gas, coal and uranium. However, these price fluctuations have minimal impact on electric margin due to fuel recovery mechanisms that recover fuel expenses. In addition, electric customers receive a credit for PTCs generated, which reduced electric revenue and margin. See Note 5 for discussion on the impact of Winter Storm Uri.\n<\/p>\n \nElectric revenues and margin:\n<\/p>\n \n\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n Three Months Ended March 31<\/b><\/p>\n<\/td>\n<\/tr>\n\n| \n (Millions of Dollars)<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n 2021<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n 2020<\/b><\/p>\n<\/td>\n<\/tr>\n\n| \n \nElectric revenues\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n2,870\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n2,203\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nElectric fuel and purchased power\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(1,386\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(797\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nElectric margin\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n1,484\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n1,406\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n<\/table>\n \nChanges in electric margin:\n<\/p>\n \n\n| \n (Millions of Dollars)<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n Three Months
\n
Ended March 31,
\n
2021 vs. 2020<\/b><\/p>\n<\/td>\n<\/tr>\n\n| \n \nNon-fuel riders\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n44\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nRegulatory rate outcomes (Colorado, Texas, New Mexico, Wisconsin and North Dakota)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n44\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nProprietary commodity trading, net of sharing (see Note 5)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n27\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nWholesale transmission revenue (net)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n11\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nEstimated impact of weather (net of decoupling\/sales true-up)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n5\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nPTCs flowed back to customers (offset by lower ETR)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(37\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nSales and demand (a)<\/sup><\/p>\n<\/td>\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(14\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nOther (net)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(2\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nTotal increase in electric margin\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n78\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n<\/table>\n (a)<\/sup> Sales excludes weather impact, net of decoupling\/sales true-up, and demand is net of sales true-up.\n<\/p>\nNatural Gas Margin <\/i><\/b>\u2014 Natural gas expense varies with changing sales and the cost of natural gas. However, fluctuations in the cost of natural gas has minimal impact on natural gas margin due to cost recovery mechanisms. See Note 5 for discussion on the impact of Winter Storm Uri.\n<\/p>\n \nNatural gas revenues and margin:\n<\/p>\n \n\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n Three Months Ended March 31<\/b><\/p>\n<\/td>\n<\/tr>\n\n| \n (Millions of Dollars)<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n 2021<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n 2020<\/b><\/p>\n<\/td>\n<\/tr>\n\n| \n \nNatural gas revenues\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n647\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n583\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nCost of natural gas sold and transported\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(299\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(285\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nNatural gas margin\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n348\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n298\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n<\/table>\n \nChanges in natural gas margin:\n<\/p>\n \n\n| \n (Millions of Dollars)<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n Three Months
\n
Ended March 31,
\n
2021 vs. 2020<\/b><\/p>\n<\/td>\n<\/tr>\n\n| \n \nRegulatory rate outcomes (Colorado)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n40\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nEstimated impact of weather\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n7\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nOther (net)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n3\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nTotal increase in natural gas margin\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n50\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n<\/table>\n O&M Expenses<\/i><\/b> \u2014 O&M expenses increased $5 million, or 0.9%, for the first quarter of 2021. The increase was primarily due to expenses associated with new wind farms, software and infrastructure costs, compensation, damage prevention and storms, partially offset by continuous improvement initiatives.\n<\/p>\n Depreciation and Amortization <\/i><\/b>\u2014 Depreciation and amortization increased $58 million, or 12.5%, for the first quarter of 2021. The increase was primarily driven by several wind farms going into service, as well as normal system expansion. In addition, 2021 depreciation expense increased as a result of implementation of new depreciation rates in Colorado, New Mexico and Texas.\n<\/p>\n Other Income (Expense) <\/i><\/b>\u2014<\/i> Other income (expense) increased $16 million for the first quarter of 2021, largely related to rabbi trust performance primarily offset in O&M expenses (compensation).\n<\/p>\n AFUDC, Equity and Debt <\/i><\/b>\u2014 AFUDC decreased $14 million for the first quarter of 2021. Decrease was driven by various wind projects placed into service.\n<\/p>\n Interest Charges <\/i><\/b>\u2014 Interest charges increased $6 million, or 3.0%, for the first quarter of 2021. The increase was largely attributable to higher debt levels to fund capital investments, partially offset by lower long-term and short-term interest rates.\n<\/p>\n Income Taxes <\/i><\/b>\u2014<\/i> Effective income tax rate:\n<\/p>\n\n\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n Three Months Ended March 31<\/b><\/p>\n<\/td>\n<\/tr>\n\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n 2021<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n 2020<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n 2021 vs 2020<\/b><\/p>\n<\/td>\n<\/tr>\n\n| \n \nFederal statutory rate\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n21.0\n<\/p>\n<\/td>\n | \n \n%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n21.0\n<\/p>\n<\/td>\n | \n \n%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u2014\n<\/p>\n<\/td>\n | \n \n%\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nState tax (net of federal tax effect)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n4.9\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n4.9\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u2014\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \n(Decreases) increases:\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nWind PTCs\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(24.6\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(17.2\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(7.4\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nPlant regulatory differences (a)<\/sup><\/p>\n<\/td>\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(6.1\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(8.4\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n2.3\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nOther (net)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(1.7\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(2.4\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n0.7\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nEffective income tax rate\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(6.5\n<\/p>\n<\/td>\n | \n \n)%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(2.1\n<\/p>\n<\/td>\n | \n \n)%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(4.4\n<\/p>\n<\/td>\n | \n \n)%\n<\/p>\n<\/td>\n<\/tr>\n<\/table>\n (a)<\/sup> Regulatory differences for income tax primarily relate to the credit of excess deferred taxes to customers. Income tax benefits associated with the credit of excess deferred credits are generally offset by corresponding revenue reductions.\n<\/p>\n\nIncome tax benefit increased $16 million for the first quarter of 2021. The increase was primarily driven by an increase in wind PTCs due to additional wind facilities going into service. Wind PTCs are credited to customers (recorded as a reduction to revenue) and do not have a material impact on net income. Impact of wind PTCs was partially offset by higher pretax earnings in 2021.\n<\/p>\n Note 3. Capital Structure, Liquidity, Financing and Credit Ratings<\/span><\/b><\/p>\n\nXcel Energy\u2019s capital structure:\n<\/p>\n \n\n| \n (Millions of Dollars)<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n March 31, 2021<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n Percentage of Total
\n
Capitalization<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n Dec. 31, 2020<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n Percentage of Total
\n
Capitalization<\/b><\/p>\n<\/td>\n<\/tr>\n\n| \n \nCurrent portion of long-term debt\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n21\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u2014\n<\/p>\n<\/td>\n | \n \n%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n421\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n1\n<\/p>\n<\/td>\n | \n \n%\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nShort-term debt\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n1,477\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n4\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n584\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n2\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nLong-term debt\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n21,470\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n57\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n19,645\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n56\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nTotal debt\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n22,968\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n61\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n20,650\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n59\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nCommon equity\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n14,700\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n39\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n14,575\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n41\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nTotal capitalization\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n37,668\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n100\n<\/p>\n<\/td>\n | \n \n%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n35,225\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n100\n<\/p>\n<\/td>\n | \n \n%\n<\/p>\n<\/td>\n<\/tr>\n<\/table>\n Liquidity<\/i><\/b> \u2014<\/b>As of April 26, 2021, Xcel Energy Inc. and its utility subsidiaries had the following committed credit facilities available to meet liquidity needs:\n<\/p>\n\n\n| \n (Millions of Dollars)<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n Credit Facility <\/b>(a)<\/sup><\/p>\n<\/td>\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n Drawn <\/b> | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |