Xcel Energy(XEL) - 2021 Q4 - Annual Report

PART I Item 1 — Business Xcel Energy is a major U.S. regulated electric and natural gas delivery company focused on clean energy transition and customer experience Definitions of Abbreviations Where to Find More Information Forward-Looking Statements Overview Key Operational and Financial Metrics | Metric | Value | | :--- | :--- | | Electric customers | 3.7 million | | Natural gas customers | 2.1 million | | Total assets | $57.9 billion | | Electric generating capacity | 20,653 MW | | Natural gas storage capacity | 53.4 Bcf | | Electric transmission lines (conductor miles) | 111,434 miles | | Electric distribution lines (conductor miles) | 210,470 miles | | Natural gas transmission lines | 2,293 miles | | Natural gas distribution lines | 36,510 miles | Strategy - Strategic Priorities: Lead the Clean Energy Transition, Enhance the Customer Experience, Keep Bills Low[17] - Sustainability Commitment: First U.S. energy provider to set aggressive GHG reduction goals across electricity, natural gas, and transportation sectors[18] - Net-zero methane emissions on natural gas system by 2030[20] Values and Culture - Core values are Connected, Committed, Safe, Trustworthy, underpinning all business operations and strategic priorities[21][22] Lead the Clean Energy Transition - Carbon-free electricity target: 100% by 2050, interim 80% reduction by 2030 (from 2005 levels)[24] - Estimated 50% carbon emission reduction from generation serving customers by 2021 (from 2005 levels)[26] - Coal-free by 2034[32] - Projected ~80% of energy will come from carbon-free resources by 2030[34] - Planned ~10,000 MW of additional renewables over the next decade[37] - Commitment to reduce natural gas GHG emissions by 25% by 2030 (from 2020 levels) and net-zero natural gas service by 2050[37] - Aim to enable 1.5 million EVs across its states by 2030, representing a nearly $2 billion investment[37] Enhance the Customer Experience - Installed over 300,000 smart meters in 2021 and plans to install more than one million in 2022[39] - Launched 12 EV programs for residential and commercial customers[40] - Initiated 20 economic development projects in 2021, projected to lead to over $1 billion in capital investments and 5,000 jobs[40] Keep Bills Low - Managed average residential bill growth to below 1% annually since 2013 (electric: 0.8%, natural gas: 0.3%)[41] - Invested more than $2 billion over the past decade in conservation programs[42] - Delivered more than $1.8 billion in customer savings by adding owned wind to the system[43] - Anticipates sales growth from electric vehicles will help keep bills low for all customers, providing approximately $1 billion in annual fuel savings by 2030[43] Deliver a Competitive Total Return to Investors Investor Return Targets and Performance | Metric | Target/Performance | | :--- | :--- | | Total Shareholder Return | ~8-10% | | EPS Growth | 5-7% | | Dividend Yield | ~3% | | Dividend Growth (CAGR) | 5-7% | | Payout Ratio | 60-70% | | GAAP earnings growth (past 5 years) | 6% annually | | Annual dividend growth (past 5 years) | 6.1% | | Senior secured debt credit ratings | A range | | Senior unsecured debt credit ratings | BBB+ to A range | Human Capital - Prioritizes continuous elevation of workplace quality and safety with a 'Safety Always' approach[48] - Board of Directors oversees workforce strategy, including diversity and inclusion initiatives, with 70% of annual incentive pay tied to safety, system reliability, and DEI metrics in 2021[54] - Approximately 44% of employees were covered by collective bargaining agreements as of Dec. 31, 2021[58] - Overall employee turnover for 2021 was 12%, with 31% due to retirements; 26% of employees are eligible for retirement within the next 5 years, and 40% within the next 10 years[59] Workforce Diversity and Inclusion Metrics (as of Dec. 2021) | Demographic (as of Dec. 2021) | Female | Ethnically Diverse | | :--- | :--- | :--- | | Board of Directors | 23 % | 15 % | | CEO direct reports | 36 % | 18 % | | Management | 22 % | 11 % | | Employees | 24 % | 17 % | | New hires | 39 % | 26 % | | Interns (hired throughout 2021) | 34 % | 27 % | Utility Subsidiaries Utility Subsidiary Key Metrics | Subsidiary | Electric Customers | Natural Gas Customers | Total Assets | Rate Base (estimated) | ROE | | :--- | :--- | :--- | :--- | :--- | :--- | | NSP-Minnesota | 1.5 million | 0.5 million | $22.8 billion | $13.7 billion | 8.45% | | NSP-Wisconsin | 0.3 million | 0.1 million | $3.1 billion | $2.0 billion | 9.92% | | PSCo | 1.5 million | 1.5 million | $22.0 billion | $14.0 billion | 8.23% | | SPS | 0.4 million | N/A | $9.3 billion | $6.4 billion | 9.22% | Operations Overview Electric Operations Electric Operations Performance Metrics | Metric | 2021 | 2020 | | :--- | :--- | :--- | | Electric sales volume | 115,474 million kWh | N/A | | Electric customers | 3.7 million | N/A | | Electric revenues | $11,205 million | $9,802 million | | kWh sales per retail customer | 23,968 | 23,910 | | Revenue per retail customer | $2,405 | $2,199 | | Total retail revenue per kWh | 10.03 cents | 9.20 cents | - Carbon-free energy as a percentage of total energy for 2021: 50% (includes wind, nuclear, hydroelectric, biomass, solar)[71] - Total owned wind capacity: 4,075 MW in 2021 (up from 3,566 MW in 2020)[72] - Total solar PPA capacity: 2,767 MW in 2021[76] - Nuclear capacity: ~1,700 MW from two plants[80] - Approved early coal plant retirements: Comanche 1 (2022), Sherco 2 (2023), Harrington (2024, conversion to natural gas), Comanche 2 (2025), Craig 1 (2025), Sherco 1 (2026), Craig 2 (2028), A.S. King (2028), Sherco 3 (2030)[84] - Proposed coal plant retirements: Pawnee (2025, conversion to natural gas), Hayden 2 (2027), Hayden 1 (2028), Tolk 1 & 2 (2034), Comanche 3 (2034)[85] - Natural gas plants capacity: ~7,900 MW from 22 plants[87] Electric Fuel Cost and Requirements by Type | Fuel Type | 2021 Cost per MMBtu | 2020 Cost per MMBtu | 2021 % of Fuel Requirements | 2020 % of Fuel Requirements | | :--- | :--- | :--- | :--- | :--- | | Nuclear (NSP System) | $0.77 | $0.80 | 46% | 51% | | Coal (NSP System) | $1.60 | $1.97 | 39% | 31% | | Coal (PSCo) | $1.43 | $1.41 | 62% | 51% | | Coal (SPS) | $2.07 | $2.28 | 66% | 40% | | Natural Gas (NSP System) | $4.98 | $2.67 | 15% | 17% | | Natural Gas (PSCo) | $8.38 | $3.01 | 38% | 49% | | Natural Gas (SPS) | $6.72 | $1.43 | 34% | 60% | Transmission - Owns more than 111,000 conductor miles of transmission lines[93] - Colorado Pathway project (if approved) will provide over 560 miles of transmission lines and enable nearly 5,500 MW of new renewables by 2027[95] Distribution - Owns and operates approximately 210,000 conductor miles of distribution lines[96] - Plans to invest approximately $1.7 billion in digitizing the distribution grid (new network infrastructure, smart meters, advanced software, equipment sensors, data analytics)[97] - Spent approximately $568 million on these investments to date[97] Natural Gas Operations Natural Gas Operations Performance Metrics | Metric | 2021 | 2020 | | :--- | :--- | :--- | | Natural gas deliveries | 405,895 thousand MMBtu | N/A | | Natural gas customers | 2.1 million | N/A | | Natural gas revenues | $2,132 million | $1,636 million | | MMBtu sales per retail customer | 114 | 118 | | Revenue per retail customer | $917 | $720 | | Residential revenue per MMBtu | $8.61 | $6.64 | | C&I revenue per MMBtu | $7.20 | $5.22 | Natural Gas Average Delivered Cost per MMBtu by Subsidiary | Utility Subsidiary | 2021 Average Delivered Cost per MMBtu | 2020 Average Delivered Cost per MMBtu | | :--- | :--- | :--- | | NSP-Minnesota | $7.48 | $3.32 | | NSP-Wisconsin | $7.11 | $3.08 | | PSCo | $6.06 | $2.52 | General - Demand for electric power and natural gas is affected by seasonal weather patterns, leading to fluctuations in operating results[105] - Subject to competition from industrial and large commercial customers generating their own electricity, and distributed generation (e.g., solar)[106] - FERC Order No. 1000 established competition for ownership of certain new electric transmission facilities[112] - FERC Order 2222 requires RTO and ISO markets to allow participation of aggregations of distributed energy resources[113] Governmental Regulations - Facilities are regulated by federal and state agencies with jurisdiction over air emissions, water quality, wastewater discharges, solid and hazardous wastes[116] - Future environmental regulations may result in substantial costs, but Xcel Energy believes these costs or replacement generation would be recoverable through rates[120] - SPS will convert the Harrington plant from coal to natural gas by Jan. 1, 2025, to attain Federal Clean Air Act standards for SO2 emissions[122] - Estimated average annual environmental expense of approximately $425 million from 2022–2026[125] - Capital expenditures for environmental improvements were approximately $60 million in 2021, $30 million in 2020, and $30 million in 2019[127] Capital Spending and Financing Executive Officers Executive Officer Information (as of Feb. 23, 2022) | Name | Age (as of Feb. 23, 2022) | Current and Recent Positions | Time in Position | | :--- | :--- | :--- | :--- | | Robert C. Frenzel | 51 | Chairman, President, Chief Executive Officer and Director, Xcel Energy Inc.; Chief Executive Officer, NSP-Minnesota, NSP-Wisconsin, PSCo, and SPS | December 2021 — Present (Chairman); August 2021 — Present (President, CEO, Director); August 2021 — Present (CEO Subsidiaries) | | Brett C. Carter | 55 | Executive Vice President and Chief Customer and Innovation Officer, Xcel Energy Inc. | May 2018 — Present | | Patricia Correa | 48 | Senior Vice President, Chief Human Resources Officer, Xcel Energy Inc. | February 2022 — Present | | Timothy O'Connor | 62 | Executive Vice President, Chief Operations Officer, Xcel Energy Inc. | August 2021 — Present | | Frank Prager | 59 | Senior Vice President, Strategy, Planning and External Affairs, Xcel Energy Inc. | March 2020 — Present | | Amanda Rome | 41 | Executive Vice President, General Counsel, Xcel Energy Inc. | June 2020 — Present | | Jeffrey S. Savage | 50 | Senior Vice President, Controller, Xcel Energy Inc. | January 2015 — Present | | Brian J. Van Abel | 40 | Executive Vice President, Chief Financial Officer, Xcel Energy Inc. | March 2020 — Present | Item 1A — Risk Factors The company faces diverse operational, financial, macroeconomic, public policy, and environmental risks impacting its business Oversight of Risk and Related Processes - The Board of Directors is responsible for the oversight of material risk and maintaining an effective risk monitoring process[133] - Management identifies and analyzes risks through formal risk assessment, financial disclosure process, hazard risk procedures, internal audit, and compliance with financial and operational controls[134] - Risk mitigation includes adherence to the Code of Conduct and compliance policies, operation of formal risk management structures, and overall business management[135] Operational Risks - Natural gas and electric operations involve inherent hazards and operating risks such as leaks, explosions, outages, property damage, and environmental pollution[141] - Long-term operational planning is subject to risks from significant changes in the electric utility sector, including increased energy efficiency, wider adoption of distributed generation, and shifts away from fossil fuels, potentially leading to stranded costs[148] - Highly dependent on suppliers to deliver components; shortages could significantly impact project plans, budgets, and timelines[152] - Subject to commodity risks and other risks associated with energy markets and production, including fuel cost increases that may not be fully recovered despite existing mechanisms[153] - Failure to attract and retain a qualified workforce, especially technical employees, could adversely affect the ability to manage and operate the business[161] - Reliance on third-party contractors introduces risks of poor performance or unavailability, impacting operations and reputation[162] - NSP-Minnesota's nuclear generation facilities are subject to risks associated with radioactive material, limited insurance, and technological/financial uncertainties related to decommissioning costs[165] Financial Risks - Profitability depends on the ability of utility subsidiaries to recover costs and earn a return on capital investment through regulated rates, with no assurance of full recovery for all costs[167] - Reductions in credit ratings could increase financing costs, impact access to capital markets, and trigger collateral requirements in contractual relationships[176] - Subject to capital market and interest rate risks, which can impact the ability to fund operations, the cost of capital, and the value of assets held in trusts for nuclear decommissioning and employee benefit plans[178] - Exposed to credit risks from customers' inability to pay bills and counterparties' nonperformance on contractual obligations, potentially leading to bad debt expense and financial losses[180] - Increasing costs of defined benefit pension and postretirement plans, influenced by actuarial assumptions and funding requirements, may adversely affect results[184] - Ability to make dividend payments relies on cash from subsidiaries, which is subject to statutory and contractual restrictions, as well as limitations imposed by state utility commissions[186] Macroeconomic Risks - Economic conditions, including inflation, monetary fluctuations, and supply chain constraints, can impact sales growth, customers' ability to pay, and the cost of materials for utility infrastructure[192] - Health epidemics like COVID-19 can cause sales volatility and workforce impacts, though financial impacts have been largely mitigated by regulatory mechanisms[194] - Operations are vulnerable to war, terrorism, and major catastrophic events (e.g., severe storms, wildfires, widespread pandemics), potentially leading to decreased revenues, increased repair costs, and supply chain disruptions[197] - Cyber incidents or security breaches could disrupt critical business functions, limit generating/transmitting capabilities, delay projects, and cause data breaches, leading to financial penalties and reputational damage[204] - Operating results may fluctuate seasonally, with milder winters and cooler summers adversely affecting revenues and income due to reduced demand for heating and cooling[214] Public Policy Risks - Subject to legislative and regulatory responses to climate change, which may create financial risk through additional regulations and costly compliance requirements, potentially impacting cost recovery[215] - Risk of climate change lawsuits, which could require substantial capital expenditures, penalties, or damages, and incur significant defense costs[219] - Increased risks of regulatory penalties (e.g., up to $1.3 million per violation per day by FERC) for non-compliance with statutes, rules, and NERC electric reliability standards[221] - Public policy advocacy targeting the continued use of natural gas could result in limitations on its use for power generation and heating, potentially leading to stranded costs and impacting service reliability and affordability[225] Environmental Risks - Subject to environmental laws and regulations (air emissions, water quality, waste disposal) that may require significant compliance costs, facility modifications, or early retirements, with no assurance of full cost recovery[226] - Physical and financial risks associated with climate change and extreme weather events (e.g., thunderstorms, floods, tornadoes, wildfires, droughts) could increase service costs, impact sales, and affect access to capital[228] - Drought or water depletion could adversely impact electricity provision, cause early power plant retirements, and increase energy costs[231] - Failure to achieve long-term climate change goals could negatively impact reputation and potentially result in financial risk[234][236] Item 1B — Unresolved Staff Comments There are no unresolved staff comments to report for Xcel Energy Inc Item 2 — Properties This section details the utility plant property of Xcel Energy's operating companies, largely subject to first mortgage bond indentures - Virtually all of the utility plant property of the operating companies is subject to the lien of their respective first mortgage bond indentures[241] Owned Generation Facilities by Subsidiary and Fuel Type | Subsidiary | Fuel Type | Installed Capacity (MW) | | :--- | :--- | :--- | | NSP-Minnesota | Coal | 2,390 | | | Nuclear | 1,040 | | | Natural Gas | 1,960 | | | Wood/Refuse | 36 | | | Wind | 2,031 | | NSP-Wisconsin | Wood/Natural Gas | 41 | | | Wood/Refuse | 16 | | | Oil | 122 | | | Natural Gas/Oil | 234 | | | Hydro | 135 | | PSCo | Coal | 1,747 | | | Natural Gas | 2,454 | | | Hydro | 235 | | | Wind | 1,059 | | SPS | Natural Gas | 1,545 | | | Coal | 2,085 | | | Wind | 984 | Electric Transmission and Distribution Conductor Miles (as of Dec. 31, 2021) | Conductor Miles (as of Dec. 31, 2021) | NSP-Minnesota | NSP-Wisconsin | PSCo | SPS | | :--- | :--- | :--- | :--- | :--- | | Total Transmission | 34,155 | 12,409 | 24,116 | 40,754 | | Total Distribution | 81,406 | 27,701 | 78,712 | 22,651 | Natural Gas Mains Mileage (as of Dec. 31, 2021) | Natural Gas Mains (miles, as of Dec. 31, 2021) | NSP-Minnesota | NSP-Wisconsin | PSCo | SPS | WGI | | :--- | :--- | :--- | :--- | :--- | :--- | | Transmission | 85 | 3 | 2,174 | 20 | 11 | | Distribution | 10,741 | 2,526 | 23,243 | — | — | Item 3 — Legal Proceedings The company is involved in various litigation, with management deeming ultimate liabilities immaterial to consolidated financials - Xcel Energy is involved in various litigation matters in the ordinary course of business[250] - Management maintains accruals for losses probable of being incurred and subject to reasonable estimation[252] - Management does not anticipate that the ultimate liabilities, if any, from current proceedings (not specifically reported) would have a material effect on Xcel Energy's consolidated financial statements[677] - One remaining active multi-district litigation matter (Arandell Corp.) related to natural gas trading allegations, for which a loss is deemed remote[677] Item 4 — Mine Safety Disclosures Xcel Energy Inc. has no mine safety disclosures to report PART II Item 5 — Market for Registrant's Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities Xcel Energy's common stock (XEL) is listed on Nasdaq, with approximately 49,137 stockholders of record as of Feb 2022 - Xcel Energy Inc.'s common stock (XEL) is listed on the Nasdaq Global Select Market[253] - The number of common stockholders of record as of Feb. 17, 2022, was approximately 49,137[258] - No equity securities registered pursuant to Section 12 of the Securities Exchange Act of 1934 were purchased by or on behalf of Xcel Energy Inc. or any of its affiliated purchasers for the quarter ended Dec. 31, 2021[258] Item 6 — [Reserved] This item is reserved and contains no information Item 7 — Management's Discussion and Analysis of Financial Condition and Results of Operations This section analyzes Xcel Energy's financial performance, condition, cash flows, regulatory impacts, and liquidity Non-GAAP Financial Measures - Xcel Energy's management uses non-GAAP measures (ongoing ROE, ongoing earnings, ongoing diluted EPS) for financial planning, analysis, reporting to the Board of Directors, determining performance-based compensation, and communicating its earnings outlook[260] - For the years ended Dec. 31, 2021 and 2020, GAAP earnings equaled ongoing earnings, indicating no adjustments were made for certain nonrecurring items[263] Results of Operations Diluted EPS by Subsidiary/Segment | Subsidiary/Segment | 2021 Diluted EPS | 2020 Diluted EPS | Change | | :--- | :--- | :--- | :--- | | PSCo | $1.22 | $1.11 | +$0.11 | | NSP-Minnesota | $1.12 | $1.12 | $0.00 | | SPS | $0.59 | $0.56 | +$0.03 | | NSP-Wisconsin | $0.20 | $0.20 | $0.00 | | Earnings from equity method investments — WYCO | $0.05 | $0.05 | $0.00 | | Regulated utility total | $3.18 | $3.04 | +$0.14 | | Xcel Energy Inc. and Other | $(0.22) | $(0.25) | +$0.03 | | Total Xcel Energy | $2.96 | $2.79 | +$0.17 | Statement of Income Analysis Impact on Diluted EPS from Key Components (2021 vs. 2020) | Component of Change (2021 vs. 2020) | Impact on Diluted EPS | | :--- | :--- | | Higher electric revenues, net of electric fuel and purchased power | $0.26 | | Lower ETR | $0.17 | | Higher natural gas revenues, net of cost of natural gas sold and transported | $0.15 | | Changes in taxes (other than income taxes) | $(0.03) | | Lower AFUDC | $(0.10) | | Higher depreciation and amortization | $(0.24) | | Other (net) | $(0.04) | | Total Change | $0.17 | Return on Equity (ROE) by Entity | ROE | 2021 (GAAP and Ongoing) | 2020 (GAAP and Ongoing) | | :--- | :--- | :--- | | NSP-Minnesota | 8.45 % | 9.20 % | | PSCo | 8.23 | 8.06 | | SPS | 9.22 | 9.54 | | NSP-Wisconsin | 9.92 | 10.52 | | Operating Companies | 8.58 | 8.87 | | Xcel Energy | 10.58 | 10.59 | - Estimated impact of temperature variations on EPS compared with normal weather conditions for 2021 vs. 2020 was a decrease of $0.033[274] - Weather-normalized and leap-year adjusted total retail electric sales growth for Xcel Energy was 1.7% in 2021 vs. 2020[276] - Weather-normalized and leap-year adjusted firm natural gas sales growth for Xcel Energy was 0.4% in 2021 vs. 2020[277] - Electric margin increased by $182 million in 2021 vs. 2020, driven by non-fuel riders and regulatory rate outcomes, partially offset by PTCs flowed back to customers[281] - Natural gas margin increased by $104 million in 2021 vs. 2020, primarily due to regulatory rate outcomes and infrastructure riders[285] - O&M expenses decreased $3 million year-to-date, while depreciation and amortization increased $173 million year-to-date[286] - AFUDC decreased $58 million year-to-date due to completion of various wind projects[287] - Interest charges increased $2 million year-to-date, largely due to higher debt levels to fund capital investments, partially offset by lower interest rates[288] - Income tax benefit increased $64 million year-to-date, driven by an increase in wind PTCs[289][290] Public Utility Regulation NSP-Minnesota - Regulatory bodies: MPUC, NDPSC, South Dakota Public Utilities Commission, FERC, MISO[296] - Recovery mechanisms include CIP Rider, Environmental Improvement Rider, Renewable Development Fund, RES, Renewable Energy Rider, State Energy Policy Rider, TCR, Infrastructure Rider, FCA, Purchased Gas Adjustment, and Sales True-up[298] - 2022 Minnesota Natural Gas Rate Case: Filed for a $36 million annual increase (6.6%), based on a 10.5% ROE, $934 million rate base, and 52.50% equity ratio; Interim rates of $25 million approved from Jan. 1, 2022[299] - 2022 Minnesota Electric Rate Case: Filed for a three-year electric rate case with a total request of $677 million (2022-2024), based on a 10.2% ROE, 52.50% equity ratio, and $10.931 billion rate base (2022); Interim rates of $247 million approved from Jan. 1, 2022[300] - 2020 North Dakota Electric Rate Case: Settlement approved for a $7 million base revenue increase, 9.5% ROE, and 52.5% equity ratio, effective Jan. 1, 2021[305] - Minnesota Resource Plan (approved Feb. 8, 2022): Includes a 10-year extension for the Monticello nuclear facility, early retirement of A.S. King (2028) and Sherco 3 (2030), and the need for 2,150 MW of new wind and 2,500 MW of new solar by 2032[307] - FERC NOPR on ROE Incentive Adders: If adopted, NSP-Minnesota would prospectively discontinue charging its current 50 basis point ROE incentive adders[311] NSP-Wisconsin - Regulatory bodies: PSCW, MPSC, FERC, MISO[323] - Recovery mechanisms include Annual Fuel Cost Plan, Power Supply Cost Recovery Factors, Wisconsin Energy Efficiency Program, Purchased Gas Adjustment, and Natural Gas Cost Recovery Factor (MI)[324] - Wisconsin Electric and Natural Gas Settlement (approved Dec. 2021): Approved electric rate increases of $35 million (4.9%) for 2022 and $18 million (2.5%) for 2023, and natural gas rate increases of $10 million (8.4%) for 2022 and $3 million (2.3%) for 2023; ROE set at 9.80% for 2022 and 10.00% for 2023, with an equity ratio of 52.5%[325] - Michigan Electric Rate Case: Reached a settlement in principle for an electric revenue increase of $1.6 million in 2022, based on a 9.7% ROE and an equity ratio of 52.5%[325] PSCo - Regulatory bodies: CPUC, FERC, SPP Western Energy Imbalance Service Market[331] - Recovery mechanisms include ECA, Purchased Capacity Cost Adjustment, Steam Cost Adjustment, DSM Cost Adjustment, RES Adjustment, Colorado Energy Plan Adjustment, Wind Cost Adjustment, Transmission Cost Adjustment, Clean Air Clean Jobs Act, FCA, GCA, PSIA, Decoupling, and Transportation Electrification Plan[332] - Colorado Natural Gas Rate Case (Jan. 2022 filing): Seeking a net increase of $107 million, based on a 10.25% ROE, 55.66% equity ratio, and a 2022 current test year[333] - Colorado Electric Rate Request (July 2021 filing, settlement Jan. 2022): A net electric rate increase of $177 million was approved, with a 9.3% ROE and 55.69% equity ratio[336] - Pathway Transmission Expansion Settlement: Agreed to a cost estimate of $1.7 billion for the project, with recovery through the transmission rider, and conditional CPCN approval for a 345 kV extension project[339] - Resource Plan Settlement (Nov. 2021): Expected 87% carbon reduction and an 80% renewable mix by 2030; Includes early retirement of Hayden units, conversion of Pawnee to natural gas, early retirement of Comanche 3, and significant additions of wind, solar, storage, and flexible generation[340] - Partial Settlement (Oct. 2021): Allows full recovery of Winter Storm Uri deferred costs ($263 million electric, $287 million natural gas) over 24-30 months with no carrying charges; PSCo will refund $41 million for the 2020 electric decoupling pilot and forego recovery of $14 million for Comanche Unit 3 replacement power costs[348] SPS - Regulatory bodies: PUCT, NMPRC, SPP RTO[357] - Recovery mechanisms include Distribution Cost Recovery Factor, Energy Efficiency Cost Recovery Factor, Energy Efficiency Rider, Fuel and Purchased Power Cost Adjustment Clause, Power Cost Recovery Factor, Renewable Portfolio Standards, TCR Factor, Fixed Fuel and Purchased Recovery Factor, and Wholesale Fuel and Purchased Energy Cost Adjustment[358] - 2021 New Mexico Electric Rate Case: A $62 million rate increase was approved (Feb. 2022), with a 9.35% ROE and 54.72% equity ratio[364] - 2021 Texas Rate Case: A blackbox settlement for an $89 million base rate increase was reached, effective March 15, 2021, with a 9.35% ROE[367] - Wind Operating Commitments: Annual generation for Hale and Sagamore wind projects must exceed a net capacity factor of 48%; the 2021 factor was 48.4%, resulting in no refund liability[701] - Contract Termination: Finalized a settlement with LP&L to terminate a 170 MW partial requirements contract upon LP&L's move to ERCOT (expected 2023), with LP&L paying SPS $78 million[702] Other Public Utility Matters - Comanche Unit 3 Outage (Jan. 2022): Expected to last approximately two months, with estimated incremental replacement power costs of ~$10 million; PSCo will not seek recovery of costs above expected[373] - Marshall Wildfire (Dec. 2021): Cause pending; Xcel Energy operates under a commission-approved wildfire mitigation plan and carries liability insurance[374] - Winter Storm Uri (Feb. 2021): Incurred approximately $1 billion in net natural gas, fuel, and purchased energy costs, largely deferred as regulatory assets[377] - Regulatory recovery for Winter Storm Uri costs: NSP-Minnesota (recovery of $179 million extraordinary costs over 27-63 months), North Dakota (recovery of $32 million over 15 months), NSP-Wisconsin (recovery of $45 million over 9 months), Michigan (recovery of $2 million over 10 months), PSCo (full recovery of $263 million electric and $287 million natural gas costs over 24-30 months), SPS (interim rates to collect up to $110 million over 30 months)[378][381] Potential Tax Reform - Potential federal tax law changes, such as the Build Back Better Act, are not expected to have a material impact on Xcel Energy's earnings if enacted[382] Critical Accounting Policies and Estimates Regulatory Accounting - Xcel Energy applies accounting for Regulated Operations, deferring incurred costs as regulatory assets and credits as regulatory liabilities based on the probability of future recovery from or refund to customers[385] - As of Dec. 31, 2021, Xcel Energy had regulatory assets of $3.8 billion and regulatory liabilities of $5.7 billion[388] - The assessment of future recoveries and obligations considers the current regulatory environment, recently issued rate orders, and historical precedents[388] Income Tax Accruals - Income tax accruals involve significant judgment and estimates due to the application of tax statutes and regulations, and outcomes of tax audits and appeals[390] - Changes in tax laws and rates may affect recorded deferred tax assets and liabilities and the future effective tax rate (ETR)[391] - Valuation allowances are applied to deferred tax assets if it is more likely than not that at least a portion may not be realized[393] Employee Benefits - Xcel Energy sponsors noncontributory, defined benefit pension plans and other postretirement benefit plans covering almost all employees and certain retirees[395] - Key assumptions for 2021 include a 6.49% rate of return on assets for pension costs and 4.10% for postretirement health care costs, with discount rates of 3.08% and 3.09% respectively[396] - Pension funding contributions were $131 million in 2021 and are expected to decline in following years[400] - Projected pension costs for financial reporting are $77 million in 2022 and $60 million in 2023, primarily due to reductions in loss amortizations[403][405][406] Nuclear Decommissioning - Xcel Energy recognizes Asset Retirement Obligations (AROs) for the expected cost of retiring tangible long-lived assets, with a significant portion related to nuclear plant decommissioning[413] - The nuclear decommissioning obligation was $2.1 billion in 2021 and $2.0 billion in 2020, funded by an external decommissioning trust fund[414] - Estimates are based on periodic independent cost studies, considering retirement dates (Monticello 2030, PI Unit 1 2033, PI Unit 2 2034), the DECON method, escalation rates (3.2%), and discount rates (ranging from 3% to 7%)[416][418](index=418&type=chunk] - Changes in estimates have minimal impact on results of operations as NSP-Minnesota expects to continue to recover all costs in future rates[420][421] Derivatives, Risk Management and Market Risk - Xcel Energy manages commodity price risk through long- and short-term physical purchase and sales contracts for energy products and fuels, and through financial derivative instruments[427] - Wholesale and commodity trading activities are conducted within guidelines and limitations approved by the risk management committee[429] - Fair value of net commodity trading contracts as of Dec. 31, 2021, was $(98) million for futures/forwards and $65 million for options[429] - A 10% increase or decrease in market prices for commodity trading contracts would impact pretax income from continuing operations by approximately $13 million[431] - The Value at Risk (VaR) for commodity trading operations reached a high of $52 million on Feb. 17, 2021, due to unprecedented market conditions during Winter Storm Uri[432] - NSP-Minnesota's nuclear fuel supply from Russia (approximately 30% of average enriched nuclear material requirements through 2030) could be impacted by sanctions[433] - Interest rate risk is managed through fixed rate debt, floating rate debt, and interest rate derivatives; a 100 basis point change in the benchmark rate on variable rate debt would impact pretax interest expense annually by approximately $11 million in 2021[436] - Credit risk from counterparties' nonperformance is managed through credit policies, parental guarantees, and collateral requirements[436] Liquidity and Capital Resources Cash Flow Activities (Millions of Dollars) | Cash Flow Activity | 2021 (Millions of Dollars) | 2020 (Millions of Dollars) | Change (2021 vs 2020) | | :--- | :--- | :--- | :--- | | Net cash provided by operating activities | $2,189 | $2,848 | $(659) | | Net cash used in investing activities | $(4,287) | $(4,740) | +$453 | | Net cash provided by financing activities | $2,135 | $1,773 | +$362 | - Net cash provided by operating activities decreased by $659 million in 2021 compared to 2020, primarily due to the deferral of net natural gas, fuel, and purchased energy costs related to Winter Storm Uri[444] - Net cash used in investing activities decreased by $453 million in 2021 compared to 2020, largely due to decreased capital expenditures from the sale of MEC and completion of various wind projects[445] - Net cash provided by financing activities increased by $362 million in 2021 compared to 2020, primarily attributable to higher debt issuances, lower repayments of long-term debt, and incremental financing due to the lag in recovery costs associated with Winter Storm Uri[446] - Total base capital expenditures forecast for 2022-2026 is $26 billion[451] - Key capital expenditure areas for 2022-2026 include electric distribution ($7,930 million), electric transmission ($7,420 million), electric generation ($3,195 million), natural gas ($3,340 million), and renewables ($1,605 million)[455] - Planned financing for 2022-2026 includes $17,640 million from cash from operations, $7,110 million from new debt, $450 million from DRIP and benefit programs, and $800 million from other equity[466] - Planned financing activity for 2022 includes approximately $600 million in unsecured bonds for Xcel Energy Inc. and $1.35 billion in first mortgage bonds for utility subsidiaries[467] - As of Dec. 31, 2021, Xcel Energy Inc. issued 5.33 million shares of common stock with net proceeds of $347 million through an At-the-Market (ATM) program[467] Earnings Guidance and Long-Term EPS and Dividend Growth Rate Objectives - Xcel Energy's 2022 GAAP and ongoing earnings guidance is a range of $3.10 to $3.20 per share[468] - Key assumptions for 2022 guidance include constructive outcomes in regulatory proceedings, normal weather patterns, ~1% weather-normalized retail electric sales increase, 0-1% weather-normalized retail firm natural gas sales increase, 1-2% O&M expense increase, $255-265 million depreciation expense increase, $55-65 million interest expense increase, and an ETR of ~(3%) to (5%)[472] - Long-term annual EPS growth objective: 5% to 7% (based off a 2021 base of $2.96 per share)[472] - Long-term annual dividend increase objective: 5% to 7%[472] - Target dividend payout ratio: 60% to 70%[472] - Objective to maintain senior secured debt credit ratings in the A range[472] Item 7A — Quantitative and Qualitative Disclosures About Market Risk This item refers to the 'Derivatives, Risk Management and Market Risk' section within Item 7 for market risk disclosures Item 8 — Financial Statements and Supplementary Data This section presents Xcel Energy's audited consolidated financial statements, including income, cash flows, balance sheets, and notes Management Report on Internal Control Over Financial Reporting - Management is responsible for establishing and maintaining adequate internal control over financial reporting[474] - Xcel Energy Inc.'s internal control over financial reporting was assessed as effective as of Dec. 31, 2021, based on criteria set forth by COSO (2013)[476] Report of Independent Registered Public Accounting Firm - Deloitte & Touche LLP issued an unqualified opinion on Xcel Energy Inc.'s consolidated financial statements for the three years ended Dec. 31, 2021[480] - Deloitte & Touche LLP also issued an unqualified opinion on the effectiveness of the Company's internal control over financial reporting as of Dec. 31, 2021[480] - The critical audit matter identified was the 'Regulatory Assets and Liabilities - Impact of Rate Regulation on the Financial Statements' due to significant management judgments and high subjectivity in assessing future regulatory orders[489] Consolidated Statements of Income Consolidated Statements of Income (Millions of Dollars) | Metric (Millions of Dollars) | 2021 | 2020 | 2019 | | :--- | :--- | :--- | :--- | | Total operating revenues | $13,431 | $11,526 | $11,529 | | Total operating expenses | $11,228 | $9,410 | $9,425 | | Operating income | $2,203 | $2,116 | $2,104 | | Income before income taxes | $1,527 | $1,467 | $1,500 | | Income tax (benefit) expense | $(70) | $(6) | $128 | | Net income | $1,597 | $1,473 | $1,372 | | Diluted EPS | $2.96 | $2.79 | $2.64 | Consolidated Statements of Comprehensive Income Consolidated Statements of Comprehensive Income (Millions of Dollars) | Metric (Millions of Dollars) | 2021 | 2020 | 2019 | | :--- | :--- | :--- | :--- | | Net income | $1,597 | $1,473 | $1,372 | | Other comprehensive income (loss) | $18 | $0 | $(17) | | Total comprehensive income | $1,615 | $1,473 | $1,355 | Consolidated Statements of Cash Flows Consolidated Statements of Cash Flows (Millions of Dollars) | Cash Flow Activity (Millions of Dollars) | 2021 | 2020 | 2019 | | :--- | :--- | :--- | :--- | | Net cash provided by operating activities | $2,189 | $2,848 | $3,263 | | Net cash used in investing activities | $(4,287) | $(4,740) | $(4,343) | | Net cash provided by financing activities | $2,135 | $1,773 | $1,181 | | Net change in cash and cash equivalents | $37 | $(119) | $101 | | Cash, cash equivalents and restricted cash at end of period | $166 | $129 | $248 | Consolidated Balance Sheets Consolidated Balance Sheets (Millions of Dollars) | Metric (Millions of Dollars) | Dec. 31, 2021 | Dec. 31, 2020 | | :--- | :--- | :--- | | Total current assets | $4,239 | $3,275 | | Property, plant and equipment, net | $45,457 | $42,950 | | Total other assets | $8,155 | $7,732 | | Total assets | $57,851 | $53,957 | | Total current liabilities | $5,046 | $4,239 | | Total deferred credits and other liabilities | $15,414 | $15,498 | | Long-term debt | $21,779 | $19,645 | | Total common stockholders' equity | $15,612 | $14,575 | | Total liabilities and equity | $57,851 | $53,957 | Consolidated Statements of Common Stockholders' Equity Consolidated Statements of Common Stockholders' Equity (Millions of Dollars) | Metric (Millions of Dollars) | Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | | :--- | :--- | :--- | :--- | | Total Common Stockholders' Equity | $15,612 | $14,575 | $13,239 | | Common Stock (Par Value) | $1,360 | $1,344 | $1,311 | | Additional Paid In Capital | $7,803 | $7,404 | $6,656 | | Retained Earnings | $6,572 | $5,968 | $5,413 | | Accumulated Other Comprehensive Loss | $(123) | $(141) | $(141) | Notes to Consolidated Financial Statements 1. Summary of Significant Accounting Policies - Xcel Energy's regulated operations include NSP-Minnesota, NSP-Wisconsin, PSCo, SPS, WGI, and WYCO, while non-regulated subsidiaries include Eloigne, Capital Services, Venture Holdings, and Nicollet Project Holdings[505] - Applies regulatory accounting, deferring certain costs as regulatory assets and credits as regulatory liabilities based on the expected ability to recover or return amounts in future rates[506] - Accounts for income taxes using the asset and liability method, recognizing deferred tax assets and liabilities for temporary differences[514] - Property, plant, and equipment are stated at original cost and depreciated using the straight-line method over commission-approved useful lives[516] - Recognizes Asset Retirement Obligations (AROs) at fair value, with nuclear decommissioning being a significant component[526] - Environmental costs are recorded when probable and estimable, and deferred as a regulatory asset if future recovery from customers is probable[530][531] - Revenue from contracts with customers is recognized as energy is delivered, with unbilled revenue estimated at month-end[537] - Uses derivative instruments (forward contracts, futures, swaps, options) to manage interest rate, utility commodity price, and commodity trading activities[540][548] 2. Accounting Pronouncements - Xcel Energy implemented ASC Topic 326 (Credit Losses) on Jan. 1, 2020, using a modified-retrospective approach[560] - The adoption resulted in a cumulative effect charge of $2 million (after tax) to retained earnings[561] - The guidance did not have a significant impact on Xcel Energy's consolidated financial statements, other than the first-time recognition of an allowance for bad debts on accrued unbilled revenues[561] 3. Property, Plant and Equipment Property, Plant and Equipment, Net (Millions of Dollars) | Property, Plant and Equipment (Millions of Dollars) | Dec. 31, 2021 | Dec. 31, 2020 | | :--- | :--- | :--- | | Electric plant | $48,680 | $47,104 | | Natural gas plant | $7,758 | $7,135 | | Common and other property | $2,602 | $2,503 | | Plant to be retired | $1,200 | $677 | | CWIP | $1,969 | $1,877 | | Total property, plant and equipment | $62,209 | $59,296 | | Less accumulated depreciation | $(17,060) | $(16,657) | | Nuclear fuel | $3,081 | $2,970 | | Less accumulated amortization | $(2,773) | $(2,659) | | Property, plant and equipment, net | $45,457 | $42,950 | Jointly Owned Assets (Millions of Dollars, Dec. 31, 2021) | Jointly Owned Assets (Millions of Dollars, Dec. 31, 2021) | Plant in Service | Accumulated Depreciation | Percent Owned | | :--- | :--- | :--- | :--- | | NSP-Minnesota Total | $1,814 | $694 | Various (50-80%) | | NSP-Wisconsin Total | $346 | $43 | Various (37-80%) | | PSCo Total | $1,626 | $506 | Various (7-82%) | 4. Regulatory Assets and Liabilities Regulatory Assets (Millions of Dollars) | Regulatory Assets (Millions of Dollars) | Dec. 31, 2021 | Dec. 31, 2020 | | :--- | :--- | :--- | | Pension and retiree medical obligations | $1,021 | $1,350 | | Deferred natural gas, electric, steam energy/fuel costs | $1,047 | $32 | | Recoverable deferred taxes on AFUDC | $289 | $283 | | Excess deferred taxes — TCJA | $233 | $245 | | Depreciation differences | $189 | $170 | | Environmental remediation costs | $106 | $129 | | Texas revenue surcharges | $84 | $71 | | Sales true-up and revenue decoupling | $89 | $129 | | Renewable resources and environmental initiatives | $218 | $141 | | Contract valuation adjustments | $56 | $71 | | Total regulatory assets | $3,844 | $3,377 | Regulatory Liabilities (Millions of Dollars) | Regulatory Liabilities (Millions of Dollars) | Dec. 31, 2021 | Dec. 31, 2020 | | :--- | :--- | :--- | | Deferred income tax adjustments and TCJA refunds | $3,256 | $3,388 | | Plant removal costs | $1,655 | $1,520 | | Effects of regulation on employee benefit costs | $235 | $221 | | Renewable resources and environmental initiatives | $102 | $64 | | ITC deferrals | $53 | $51 | | Revenue decoupling | $50 | $51 | | Contract valuation adjustments | $57 | $19 | | Deferred natural gas, electric, steam energy/fuel costs | $50 | $84 | | Conservation programs | $42 | $49 | | DOE settlement | $28 | $23 | | Total regulatory liabilities | $5,676 | $5,613 | - Regulatory assets not earning a return primarily included the unfunded portion of pension and retiree medical obligations and net AROs, as well as $1,718 million in 2021 and $812 million in 2020 of past expenditures not earning a return[568] 5. Borrowings and Other Financing Instruments Short-Term Debt (Millions of Dollars) | Short-Term Debt (Millions of Dollars) | 2021 | 2020 | 2019 | | :--- | :--- | :--- | :--- | | Borrowing limit | $3,100 | $3,100 | $3,600 | | Amount outstanding at period end | $1,005 | $584 | $595 | | Average amount outstanding | $1,399 | $1,126 | $1,115 | | Maximum amount outstanding | $2,054 | $2,080 | $1,780 | | Weighted average interest rate (daily basis) | 0.57 % | 1.45 % | 2.72 % | - The total borrowing limit under the amended credit agreements is $3.1 billion, maturing in June 2024[573] - As of Dec. 31, 2021, Xcel Energy Inc. and its utility subsidiaries had $2,076 million in available capacity under committed credit facilities[575] - Long-term debt obligations for Xcel Energy Inc. and its utility subsidiaries totaled $21,779 million in 2021, up from $19,645 million in 2020[580] - Maturities of long-term debt include $601 million in 2022, $1,150 million in 2023, $552 million in 2024, $1,102 million in 2025, and $501 million in 2026[582] - Through its ATM Equity Offering, Xcel Energy Inc. issued 5.33 million shares of common stock with net proceeds of $347 million as of Dec. 31, 2021[583] - Utility subsidiaries' dividends are subject to FERC jurisdiction, prohibiting payments from capital accounts, and state regulatory commissions impose more restrictive dividend limitations[584] 6. Revenues Operating Revenues by Type (Millions of Dollars) | Revenue Type (Millions of Dollars) | 2021 | 2020 | 2019 | | :--- | :--- | :--- | :--- | | Total operating revenues | $13,431 | $11,526 | $11,529 | | Revenue from contracts with customers: | | | | | Residential | $4,461 | $4,083 | $4,045 | | C&I | $5,720 | $5,085 | $5,440 | | Wholesale | $1,540 | $759 | $737 | | Transmission | $604 | $579 | $507 | | Other (contracts) | $209 | $210 | $169 | | Alternative revenue and other | $763 | $679 | $497 | 7. Income Taxes - Federal income tax returns for 2014-2016 and 2018 are open for audit, and state audits are in progress for Colorado (2014), Minnesota (2015), Texas (2016), and Wisconsin (2016)[591] - The total unrecognized tax benefit was $58 million in 2021, up from $52 million in 2020[592] - Federal NOL carryforward was $765 million in 2021, and federal tax credit carryforwards were $1,172 million in 2021[595] - State NOL carryforwards were $1,648 million in 2021[595] Effective Income Tax Rate Reconciliation | Effective Income Tax Rate | 2021 | 2020 | 2019 | | :--- | :--- | :--- | :--- | | Federal statutory rate | 21.0 % | 21.0 % | 21.0 % | | State income tax on pretax income, net of federal tax effect | 5.0 | 4.9 | 4.9 | | (Decreases) increases in tax from: | | | | | Wind PTCs | (23.4) | (15.7) | (9.4) | | Plant regulatory differences | (6.2) | (7.6) | (5.8) | | Other tax credits, net NOL & tax credit allowances | (1.1) | (1.2) | (1.7) | | NOL Carryback | — | (0.9) | — | | Change in unrecognized tax benefits | 0.4 | 0.5 | 0.5 | | Other, net | (0.3) | (1.4) | (1.0) | | Effective income tax rate | (4.6)% | (0.4)% | 8.5 % | 8. Share-Based Compensation - Xcel Energy's incentive plan includes restricted stock, other equity awards (time-based and performance-based), and stock equivalent units for non-employee directors[600] - Performance conditions for a portion of equity awards are based on relative Total Shareholder Return (TSR) and environmental goals[604] - TSR liability awards are accounted for as liabilities, with their fair value remeasured each period[607] - Compensation cost for share-based awards was $31 million in 2021, down from $73 million in 2020[609] - Total unrecognized compensation cost related to nonvested share-based compensation awards was approximately $28 million in 2021, expected to be recognized over a weighted average period of 1.6 years[612] 9. Earnings Per Share Shares Outstanding for EPS Calculation (Millions) | Shares (Millions) | 2021 | 2020 | 2019 | | :--- | :--- | :--- | :--- | | Basic | 539 | 527 | 519 | | Diluted | 540 | 528 | 520 | - Diluted common shares outstanding included common stock equivalents of 0.3 million, 1.1 million, and 1.3 million shares for 2021, 2020, and 2019, respectively[616] 10. Fair Value of Financial Assets and Liabilities - Xcel Energy uses a three-level hierarchical framework for fair value measurements, with Level 1 for quoted prices in active markets, Level 2 for observable inputs other than quoted prices, and Level 3 for significant unobservable inputs[621] - The nuclear decommissioning fund assets were $3.256 billion as of Dec. 31, 2021, up from $2.777 billion in 2020[629] - Assets held in rabbi trusts were $109 million as of Dec. 31, 2021, up from $102 million in 2020[635] - Fair value of net commodity trading contracts as of Dec. 31, 2021, was $(98) million for futures/forwards and $65 million for options[429] - As of Dec. 31, 2021, six of Xcel Energy's 10 most significant counterparties for commodity activities (38% of credit exposure) had investment grade credit ratings, and three (20% of credit exposure) were unrated but internally consistent with investment grade[644] - Accumulated other comprehensive loss related to settled interest rate derivatives included $5 million of net losses expected to be reclassified into earnings during the next 12 months[638] 11. Benefit Plans and Other Postretirement Benefits Pension and Postretirement Benefit Funded Status (Millions of Dollars) | Metric (Millions of Dollars) | Pension Benefits (Dec. 31, 2021) | Postretirement Benefits (Dec. 31, 2021) | | :--- | :--- | :--- | | Fair value of plan assets | $3,670 | $442 | | Obligation at Dec. 31 | $3,718 | $511 | | Funded status of plans at Dec. 31 | $(48) | $(69) | - Pension plan assets were $3,670 million in 2021, up from $3,599 million in 2020[663] - Postretirement benefit plan assets were $442 million in 2021, down from $452 million in 2020[664] - Benefit obligations for both pension and postretirement plans decreased from Dec. 31, 2020, to Dec. 31, 2021, primarily due to benefit payments and increases in discount rates[665] - Significant assumptions for 2021 include a pension discount rate of 3.08%, a postretirement discount rate of 3.09%, an expected return on pension assets of 6.49%, and an expected return on postretirement assets of 4.10%[670] - Net periodic pension cost was $121 million in 2021, up from $117 million in 2020[671] - Projected pension benefit payments are $323 million in 2022 and $257 million in 2023[671] - Projected net postretirement health care benefit payments are $40 million in 2022 and $39 million in 2023[671] - Total expense for defined contribution plans was approximately $43 million in 2021[671] 12. Commitments and Contingencies - Legal proceedings include one active multi-district litigation matter (Arandell Corp.) related to natural gas trading, for which a loss is deemed remote[677] - NSP-Minnesota is participating in a contested case regarding the prudency of incremental natural gas costs incurred during Winter Storm Uri, with potential disallowances up to $179 million recommended by the OAG[680] - Xcel Energy is investigating, remediating, or performing post-closure actions at 16 historical MGP, landfill, or other disposal sites[709] - PSCo is evaluating options for corrective action at two coal ash locations, with total potential costs up to $35 million[712] - NSP-Minnesota's public liability for claims from any nuclear incident is limited to $13.5 billion under the Price-Anderson Act, with $450 million covered by insurance[732] - NSP-Minnesota owns temporary on-site storage facilities for spent nuclear fuel and is seeking a Certificate of Need (CON) for additional storage at the Monticello site[736] - The discounted nuclear decommissioning cost obligation on a regulatory basis was $6,554 million in 2021, with $3,256 million of assets held in the external decommissioning trust[743] - Operating lease Right-of-Use (ROU) assets were $1,291 million in 2021, primarily related to Power Purchase Agreements (PPAs)[750] - Finance lease ROU assets were $125 million in 2021, primarily related to gas storage and pipeline facilities[755] - Total operating lease expense was $287 million in 2021, and total finance lease expense was $24 million in 2021[451] - Unconditional purchase obligations, including fuel and non-lease PPAs, totaled $4,837 million as of Dec. 31, 2021, with $1,718 million due in less than one year[762] - Certain IPPs under PPAs and TUCO Inc. (coal supplier) are Variable Interest Entities (VIEs) for which Xcel Energy is not the primary beneficiary; however, low-income housing limited partnerships are consolidated[766] - Guarantees and bond indemnities issued and outstanding for Xcel Energy totaled $60 million as of Dec. 31, 2021[774] 13. Other Comprehensive Income Accumulated Other Comprehensive Loss (Millions of Dollars) | Component (Millions of Dollars) | 2021 | 2020 | | :--- | :--- | :--- | | Accumulated other comprehensive loss at Jan. 1 | $(141) | $(141) | | Net current period other comprehensive income (loss) | $18 | $0 | | Accumulated other comprehensive loss at Dec. 31 | $(123) | $(141) | 14. Segment Information - Xcel Energy has two reportable segments: Regulated Electric (generates, transmits, and distributes electricity in eight states, including wholesale operations) and Regulated Natural Gas (transports, stores, and distributes natural gas in five states)[780] - The 'All Other' category includes operating segments with revenues below quantitative thresholds, such as steam revenue, appliance repair services, non-utility real estate, refuse-derived fuel processing, low-