Pinnacle West Capital Financial Model
Utilities Company Financials Example (Free Excel Download)
Pinnacle West Capital Corporation (NYSE: PNW) is an energy holding company that operates primarily through its principal subsidiary, Arizona Public Service Company (APS).
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About this model
This model provides a comprehensive equity valuation and regulatory scenario analysis for Pinnacle West Capital Corporation, enabling an equity research analyst to forecast earnings and cash flows based on Arizona Public Service Company's (APS) rate base growth, allowed return on equity, and customer demand trends.
Pinnacle West Capital Corporation (NYSE: PNW) is an energy holding company that operates primarily through its principal subsidiary, Arizona Public Service Company (APS). APS is a vertically integrated, regulated electric utility providing retail and wholesale electric service to approximately 1.4 million homes and businesses across Arizona.
- Business Segments: The company operates as a single reportable segment (Regulated Electricity), but revenue is driven by Retail customers (approximately 85% of revenue), Wholesale power sales (approximately 5%), and Transmission/Other (approximately 10%).
- Key Geographies: Central and Southern Arizona, specifically the rapidly growing Maricopa County and Phoenix metropolitan area.
- Business Model Type: Asset-heavy, regulated monopoly. Returns are dictated by the Arizona Corporation Commission (ACC) and the Federal Energy Regulatory Commission (FERC) based on invested capital (rate base).
- Competitive Position: APS is the largest electric utility in Arizona, operating as a regulated monopoly in its service territory. It co-owns and operates the Palo Verde Generating Station, the largest nuclear power plant in the United States by net generation.
- Recent Major Events: In 2025, APS filed a major rate case with the ACC requesting a $580 million net revenue increase (a 13.99% day-one customer impact) based on a $12.5 billion adjusted rate base and a proposed 10.70% allowed Return on Equity (ROE). The company also announced a massive $10.35 billion capital expenditure plan for 2025 to 2028 to support grid reliability and clean energy transition.
The downloadable Pinnacle West Capital financial model includes SEC-sourced historical financials, forecast assumptions, core operating schedules, and valuation outputs in an Excel workbook built for review and scenario analysis.
A turnkey financial model
Live formulas, no hardcoded values
Outputs are driven by live formulas, so the workbook updates from its assumptions instead of relying on hardcoded results.
All assumptions in one tab
Inputs are clearly marked in the Assumptions tab and separated from calculations, making it clear what to change and what to leave intact.
Statements always balancing
For integrated-statement models, the balance sheet, cash flow, and supporting schedules tie through properly.
Distinct schedules for clarity
Debt, working capital, taxes, and cash flow can get messy quickly. We group calculations in clear schedules, not across disconnected tabs.
No hidden macros or external links
There are no unexplained external workbook links or macros to undermine auditability or portability.
Changes flow through the model
Update a key driver and see the impact carry through the forecast, financing, and return outputs. We never use hardcoded numbers in formulas.
Historicals & AssumptionsPinnacle West Capital financial modelCompany, Historicals & Assumptions used
Source: SEC EDGAR · values in USD
| Line item | FY2021 | FY2022 | FY2023 | FY2024 | FY2025 |
|---|---|---|---|---|---|
| Revenue | $3.80B | $4.32B | $4.70B | $5.12B | $5.34B |
| Income Before Income Taxes | $746.0M | $575.7M | $595.7M | $736.6M | $738.4M |
| Operating income | $805.3M | $731.9M | $824.6M | $1.01B | $1.07B |
| Net income | $635.9M | $500.8M | $518.8M | $626.0M | $631.6M |
Forecast assumptions
Defaults used in the downloadable model. Forecast horizon: FY2026–FY2030.
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How to build a detailed financial model for Pinnacle West Capital
A complete walkthrough of every driver, margin, working-capital input, and capital-allocation assumption used in the downloadable model.
Revenue Deep Dive
Retail Electricity Revenue
- Segment Name: Retail Operating Revenues (Residential, Commercial, Industrial)
- Revenue Driver Formula: (Average Rate Base x Allowed ROE x Equity Ratio) + Cost of Debt + Recoverable Operating Expenses + Fuel Costs
- Historical Growth Rate: 4% to 6% CAGR over the last 3 years, driven by strong population influx and industrial expansion.
- Key Growth Levers and Headwinds: Driven by a 2.4% customer growth rate in 2025 and a 5.0% weather-normalised retail sales growth rate. Headwinds include regulatory lag (the delay between spending capital and recovering it in rates) and customer adoption of distributed generation (rooftop solar).
- Pricing Dynamics: Strictly regulated by the ACC. Base rates are set during rate cases, while adjustor mechanisms (like the Fuel and Purchased Power adjustor) allow for the pass-through of volatile commodity costs.
- Revenue Recognition Notes: Revenues are recognised as electricity is delivered. Unbilled revenues are estimated at month-end based on daily generation volumes and historical usage curves.
- Seasonality: Highly seasonal. The third quarter (July to September) generates the vast majority of net income due to extreme summer cooling demand (Cooling Degree Days) in Arizona.
Wholesale and Transmission Revenue
- Segment Name: Wholesale and Transmission Revenues
- Revenue Driver Formula: Wholesale Volume x Market Price + FERC-Regulated Transmission Rate Base x FERC Allowed ROE
- Historical Growth Rate: 2% to 4% CAGR.
- Key Growth Levers and Headwinds: Transmission revenue grows steadily with grid investments under FERC formula rates, which suffer less regulatory lag than ACC retail rates. Wholesale revenue fluctuates with excess generation capacity and regional market prices.
- Pricing Dynamics: Transmission is regulated by FERC using a formula rate mechanism that updates annually. Wholesale pricing is market-driven based on Western Interconnection spot prices.
Cost Structure
Variable Costs / COGS
- Line-by-line breakdown: Fuel and Purchased Power.
- Gross Margin Range: Utilities typically look at "Operating Revenues Less Fuel and Purchased Power" (Gross Margin), which runs at approximately 60% to 62% of total revenues.
- Key input costs: Natural gas prices, wholesale electricity market purchases, and nuclear fuel amortisation.
- How COGS scales with revenue: Highly linear with generation volume. Fuel costs are generally passed through to customers via adjustor mechanisms, meaning they inflate both revenue and COGS equally without impacting net income.
Operating Expenses
- Operations and Maintenance (O&M): The largest fixed cost, covering plant operations, grid maintenance, and customer service. Management targets flat core O&M despite 2.4% customer growth.
- Depreciation & Amortisation (D&A): Approximately 15% to 18% of revenue. Driven entirely by the massive PP&E balance and depreciation rates approved by the ACC.
- Taxes Other Than Income Taxes: Primarily property taxes assessed on utility infrastructure.
- Restructuring / one-time charges: Infrequent, though early retirement of coal facilities (like the Cholla Power Plant) can trigger accelerated depreciation or regulatory asset creation.
Margin Profile
- EBITDA Margin: 32% to 35% historically.
- Operating Margin: 18% to 21%.
- Net Margin: 10% to 12% (2025 Net Income was $616.5 million on $5.34 billion in revenue, an 11.5% margin).
- Margin trend: Margins compress during periods of regulatory lag (when costs rise faster than rates) and expand immediately following a favourable rate case decision.
Balance Sheet Structure
- Total assets: Approximately $30 billion as of late 2025.
- Key asset categories: Property, Plant, and Equipment (PP&E) makes up over 75% of total assets. Regulatory Assets are also highly material, representing costs deferred for future recovery from customers.
- Goodwill & intangibles: Minimal to zero. This is an organic growth utility, not a serial acquirer.
- Working capital profile:
- Days Sales Outstanding (DSO): 35 to 45 days.
- Days Payable Outstanding (DPO): 30 to 40 days.
- Net working capital: Typically negative or near zero. Utilities carry large current liabilities (including current maturities of long-term debt and customer deposits) relative to current assets.
- PP&E: Consists of generation plants (Palo Verde nuclear, natural gas, solar), transmission lines, and distribution networks. Useful lives range from 5 years for vehicles to 60+ years for transmission structures.
- Right-of-use assets: Material due to land leases for solar facilities and some remaining sale-leaseback arrangements for Palo Verde Unit 2.
Capital Expenditure & Investment
- Capex as % of revenue: Extremely high, typically 45% to 55% of revenue.
- Maintenance capex vs. growth capex: Approximately 40% maintenance (sustaining existing grid and nuclear operations) and 60% growth (new transmission, clean energy generation, and grid expansion for data centres).
- Major capex programmes: The 2025 to 2028 capital plan totals $10.35 billion. Annual capex scales from $2.40 billion in 2025 to $2.70 billion in 2028.
- Capitalised software / development costs: Minor compared to hard infrastructure.
- M&A pattern: Purely organic growth. The company focuses on building infrastructure in its existing Arizona footprint.
Debt & Capital Structure
- Total debt: Approximately $9.2 billion in long-term debt as of Q3 2025.
- Debt/Capitalisation ratio: Regulators target an equity ratio of approximately 52% for APS, meaning debt makes up the remaining 48% of the regulatory capital structure.
- Credit rating: Investment grade (typically A- or BBB+ range). Maintaining this is critical for favourable rate case outcomes.
- Key debt instruments: Unsecured senior notes at the APS level, term loans, and a revolving credit facility.
- Maturity profile: Laddered maturities. The company frequently issues $400 million to $800 million tranches of 10-year and 30-year notes.
- Interest rate profile: Predominantly fixed-rate long-term bonds.
- Share repurchase programme: Not active. The company is actually issuing equity (approximately $650 million to $900 million planned between 2025 and 2027) via At-The-Market (ATM) and forward sale agreements to fund its massive capex without breaching its 52% equity ratio target.
- Dividend policy: Management targets a 3.7% CAGR in the dividend, maintaining a payout ratio of 65% to 75% of earnings.
Cash Flow Characteristics
- Operating cash flow conversion: OCF is typically 2.0x to 2.5x Net Income (e.g., $1.3 billion OCF vs $616 million Net Income) due to massive non-cash D&A and deferred taxes.
- Free cash flow margin: Highly negative. OCF ($1.3 billion) is entirely consumed by Capex ($2.4 billion), resulting in negative FCF that must be funded by external capital markets.
- Major non-cash items: Depreciation, amortisation of nuclear fuel, and Allowance for Funds Used During Construction (AFUDC). AFUDC is a non-cash income item representing the estimated debt and equity costs of financing construction work in progress.
- Cash tax rate: Significantly lower than the statutory rate due to accelerated depreciation on infrastructure investments and production tax credits (PTCs) from renewable energy.
Sheet Structure
- Assumptions: Hardcoded drivers for rate base growth, allowed ROE, customer growth, weather normalisation, and financing costs.
- Rate Base & Regulatory: Calculates the rolling ACC and FERC rate base, tracking capital additions, accumulated depreciation, and deferred taxes.
- Revenue Build: Projects Retail Revenue (Residential, Commercial, Industrial) based on rate base returns and customer growth, plus Wholesale and Transmission revenue.
- Income Statement: Consolidated view mirroring the 10-K (Operating Revenues, Fuel and Purchased Power, O&M, D&A, Taxes Other Than Income, Interest Expense, AFUDC).
- Balance Sheet: Assets (heavy PP&E, Regulatory Assets), Liabilities (Long-Term Debt, Regulatory Liabilities), and Equity.
- Cash Flow Statement: Net Income to OCF (adding back D&A, deferred taxes, AFUDC equity), CFI (Capex), and CFF (Debt issuance, Equity issuance, Dividends).
- Debt & Interest Schedule: Tranches of existing debt, new debt issuances required to plug the cash deficit, and interest expense calculations.
- PP&E & Capex Schedule: Waterfall of the $10.35 billion capital plan, depreciation schedules, and AFUDC calculations.
- Valuation (DCF & DDM): Dividend Discount Model (highly relevant for utilities) and traditional Unlevered DCF.
Key Financial Relationships
- Retail Base Revenue = (Average ACC Rate Base x ACC Allowed ROE x Equity Ratio) + (Average ACC Rate Base x Cost of Debt x Debt Ratio) + Recoverable O&M + D&A + Taxes.
- Transmission Revenue = Average FERC Rate Base x FERC Allowed ROE x Equity Ratio + Recoverable Costs.
- Total Operating Revenues = Retail Base Revenue + Fuel Adjustor Revenue + Transmission Revenue + Wholesale Revenue.
- Fuel Adjustor Revenue = Fuel and Purchased Power Expense (assumes 100% pass-through with zero margin impact).
- End of Period Rate Base = Beginning Rate Base + Capex - Depreciation - Increase in Deferred Tax Liabilities.
- AFUDC (Income) = Average Construction Work in Progress (CWIP) x Weighted Average Cost of Capital.
- Total O&M Expense = Prior Year O&M x (1 + Inflation Rate) x (1 + Customer Growth Rate) - Efficiency Savings.
- Interest Expense = (Average Long-Term Debt x Weighted Average Interest Rate) + (Average Short-Term Debt x Short-Term Rate) - AFUDC Borrowed Funds.
- New Equity Required = IF( (Total Equity / (Total Debt + Total Equity)) < Target Equity Ratio of 52%, Amount needed to reach 52%, 0).
- Dividends Paid = Prior Year Dividend Per Share x (1 + 3.7% Target CAGR) x Shares Outstanding.
Cross-Sheet Dependencies
- The PP&E & Capex Schedule is the engine of the model. It feeds depreciation to the Income Statement, capital additions to the Rate Base & Regulatory sheet, and cash outflows to the Cash Flow Statement.
- The Rate Base & Regulatory sheet feeds directly into the Revenue Build, as utility earnings are a mathematical derivative of the rate base.
- The Revenue Build feeds the top line of the Income Statement.
- The Cash Flow Statement determines the funding deficit, which triggers new debt and equity issuances in the Debt & Interest Schedule.
- Circularity Warning: Interest expense reduces Net Income, which reduces Retained Earnings and Total Equity. To maintain the 52% equity ratio, the model must issue more equity and less debt, which changes the Interest expense. A circularity breaker (toggle) is mandatory for the financing loop.
Sign Convention
- Revenues and Income: Positive.
- Expenses (O&M, Fuel, D&A, Interest): Positive in their specific schedules, but subtracted in the Income Statement totals.
- Assets: Positive.
- Liabilities and Equity: Positive.
- Cash Flow Statement: Cash inflows (Net Income, D&A, debt issuance) are positive. Cash outflows (Capex, dividends, debt repayment) are negative.
Things Most Likely to Go Wrong
- Ignoring the Fuel Pass-Through: Fuel and purchased power costs are passed to customers. If you inflate fuel costs without inflating the corresponding adjustor revenue, you will artificially crush the company's margins.
- Misunderstanding AFUDC: AFUDC equity is a non-cash addition to Net Income. It must be subtracted out in the Cash Flow Statement to arrive at true Operating Cash Flow.
- Static Share Count: PNW is actively issuing equity (via ATM and forward sales) to fund its $10.35 billion capex plan. Holding the share count flat will artificially inflate EPS and distort the valuation.
- Overestimating Q1/Q2/Q4 Earnings: Arizona utilities are violently seasonal. Q3 generates the vast majority of annual earnings. If building a quarterly model, applying a flat 25% allocation per quarter will fail validation checks immediately.
- Confusing Rate Base with Total Assets: Rate base is a regulatory construct (usually Net PP&E minus deferred taxes). Do not multiply Total Assets by the Allowed ROE to forecast revenue.
- Ignoring Regulatory Lag: The model must account for the fact that capex spent in 2025 and 2026 will not earn a full return until the new rates take effect (requested for the second half of 2026).
- Capital Structure Drift: The ACC mandates a specific capital structure (roughly 52% equity). If the model funds all cash deficits with debt, the equity ratio will plummet, violating regulatory requirements and invalidating the model.
- Palo Verde Lease Accounting: APS recently purchased two Palo Verde leased interests, ending their consolidation. Historical financials before September 2025 contain noncontrolling interests that should not be projected forward.
Validation Checks
- Net Income Margin: Should remain in the 10% to 12% range. Flag if it drops below 8% or exceeds 14%.
- Equity Ratio: (Total Equity / (Total Debt + Total Equity)) must remain between 50% and 54% in all projected periods.
- Dividend Payout Ratio: Dividends Paid / Net Income should remain between 65% and 75%.
- Capex to OCF: Capex should consistently exceed Operating Cash Flow (ratio > 1.5x), reflecting the massive investment cycle.
- Balance Sheet Check: Total Assets = Total Liabilities + Total Equity. Must equal exactly zero difference.
- Effective Tax Rate: Should remain between 11% and 15%, well below the statutory 21% rate due to PTCs and accelerated depreciation.
- EPS Growth: Long-term EPS growth should align with management's 5% to 7% target CAGR off the 2024 base.
Key Assumptions (Default Values)
| Assumption | Default Value | Unit | Rationale |
|---|---|---|---|
| Retail Customer Growth | 2.40 | % | Actual 2025 customer growth rate reported by APS. |
| Weather-Normalised Sales Growth | 5.00 | % | Actual 2025 retail electricity sales growth. |
| ACC Allowed ROE | 10.70 | % | Proposed ROE in the 2025 APS rate case application. |
| Target Equity Ratio | 52.0 | % | Standard regulatory capital structure target for APS. |
| Annual Capex (2025-2028 Avg) | 2,587 | $ Millions | Based on the $10.35 billion 4-year capital plan. |
| Fuel & Purchased Power / Rev | 12.0 | % | Historical average; assumes stable natural gas prices. |
| Core O&M Growth Rate | 1.50 | % | Management target to keep O&M growth below inflation. |
| Effective Tax Rate | 13.5 | % | Blended rate reflecting statutory rate offset by renewable tax credits. |
| Dividend per Share (2025) | 3.58 | $ | Annualised dividend based on recent declarations. |
| Dividend Target CAGR | 3.70 | % | Management guidance for long-term dividend growth. |
| Cost of New Long-Term Debt | 5.50 | % | Estimated yield on new 10-year/30-year utility bonds. |
| Discount Rate (Cost of Equity) | 8.50 | % | Standard utility cost of equity (Beta ~0.6, Risk-Free ~4.2%). |
| Terminal Rate Base Growth | 4.00 | % | Long-term proxy for terminal growth in a regulated utility. |
Data Sources & Benchmarks
- SEC Filings: Pinnacle West Capital Corp (PNW) 10-K, 10-Q, and 8-K filings via SEC EDGAR.
- Regulatory Filings: Arizona Corporation Commission (ACC) docket for the 2025 APS Rate Case.
- Investor Relations: PNW Q4 2025 Earnings Presentation and 2025 EEI Financial Conference materials.
- Key Peers for Benchmarking: Xcel Energy (XEL), WEC Energy Group (WEC), Eversource Energy (ES), and Alliant Energy (LNT).
- Industry Data Sources: Edison Electric Institute (EEI) for utility capex trends, and FERC Form 1 for transmission rate base data.
Sources
- Pinnacle West Capital Corp 2024 and 2025 Form 10-K Filings
- Pinnacle West Q4 2025 Earnings Release and Financial Results
- Pinnacle West Q3 2025 Earnings Release and Presentation
- Pinnacle West 2025 Proxy Statement
- Arizona Public Service Company 2025 Rate Case Application Summaries
- Pinnacle West Capital Corp Investor Relations Website (pinnaclewest.com)
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Frequently asked
What is Pinnacle West Capital Corporation's primary business model?+
Pinnacle West Capital Corporation operates as an energy holding company, primarily through its subsidiary Arizona Public Service Company (APS). APS is a vertically integrated, regulated electric utility that serves approximately 1.4 million customers across Arizona. Its business model is characterized as an asset-heavy, regulated monopoly, with returns determined by regulatory bodies based on invested capital.
How does Pinnacle West Capital Corporation generate its revenue?+
Pinnacle West Capital Corporation generates revenue primarily from its Regulated Electricity segment. Approximately 85% of its revenue comes from retail customers, with wholesale power sales contributing about 5% and transmission/other services making up the remaining 10%. Revenue growth is driven by factors such as Arizona Public Service Company's rate base growth, allowed return on equity, and customer demand trends.
What is a key capital expenditure assumption in the Pinnacle West Capital financial model?+
A key assumption in the financial model for Pinnacle West Capital is that Capex as a percentage of revenue is approximately 37.77%. The company has a significant capital plan, totaling $10.35 billion from 2025 to 2028, with annual capital expenditures scaling from $2.40 billion to $2.70 billion. These investments are split roughly 40% for maintenance and 60% for growth initiatives.
What is the projected revenue growth rate used in the Pinnacle West Capital financial model?+
The financial model for Pinnacle West Capital assumes a revenue growth rate of approximately 7.85%. This growth is expected to be driven by factors such as rate base expansion and increasing customer demand within Arizona Public Service Company's service territory.
What is the forecast horizon for the Pinnacle West Capital financial model and what is its main purpose?+
The Pinnacle West Capital financial model has a forecast horizon from FY2026 to FY2030. Its main purpose is to provide a comprehensive equity valuation and regulatory scenario analysis, allowing analysts to forecast earnings and cash flows based on key drivers like rate base growth and customer demand.
Can an equity research analyst download and use a financial model for Pinnacle West Capital?+
Yes, an Excel-based financial model for Pinnacle West Capital is available for download. This model is designed to assist equity research analysts in forecasting the company's earnings and cash flows, as well as performing regulatory scenario analysis.
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