PPL Financial Model

• Total assets: Approximately $35 billion to $40 billion.
• Key asset categories: Property, Plant and Equipment (PP&E) represents the vast majority of assets, forming the physical grid and generation fleet that dictates the regulatory rate base.
• Goodwill & intangibles: Approximately $1.2 billion, primarily stemming from the 2022 Rhode Island Energy acquisition.
• Working capital profile:
• Days Sales Outstanding (DSO): 35 to 45 days.
• Days Inventory Outstanding (DIO): 20 to 30 days (primarily fuel inventory).
• Days Payable Outstanding (DPO): 30 to 40 days.
• Net working capital as % of revenue: Typically negative or near zero.
• The company operates with negative working capital, which is standard for utilities that collect receivables quickly but carry large deferred tax liabilities and payables.
• PP&E: Consists of generation facilities, transmission lines, and distribution networks depreciated over 30 to 50 years. Capex is heavily skewed towards growth and modernisation.
• Right-of-use assets: Operating leases are present but not material relative to owned PP&E.

• Capex as % of revenue: 60% to 80%, reflecting the highly capital-intensive nature of the industry.
• Maintenance capex vs. growth capex: Approximately 70% growth capex and 30% maintenance capex.
• Major capex programmes underway: A $23 billion capital plan from 2026 through 2029 focused on grid modernisation, transmission expansion for data centres, and clean energy transition.
• Capitalised software: Present for IT transformation but minor compared to hard infrastructure.
• M&A pattern: Currently focused on organic rate base growth following the transformational Rhode Island acquisition.
• Typical acquisition multiple paid: Regulated utilities are typically acquired at 1.2x to 1.5x rate base.

• Total debt: Approximately $15 billion to $17 billion.
• Debt/EBITDA ratio: Typically 4.5x to 5.5x.
• Credit rating: Baa1 (Moody's) and A- (S&P).
• Key debt instruments: First mortgage bonds at the operating company level, unsecured debt at the holding company, and commercial paper.
• Maturity profile: Laddered long-term maturities extending 10 to 30 years.
• Interest rate profile: Predominantly fixed-rate long-term debt to match long-lived assets.
• Covenants: Standard debt-to-capitalisation limits (typically maximum 65% to 70%).
• Share repurchase programme: Not active; the company issues equity via At-The-Market (ATM) programmes to fund growth.
• Dividend policy: Target payout ratio of 60% to 65%, with a current quarterly dividend of $0.2850 per share.

• Operating cash flow conversion: 1.5x to 2.0x of Net Income due to massive non-cash depreciation and deferred taxes.
• Free cash flow margin: Consistently negative. The company outspends its operating cash flow to grow the rate base.
• Major non-cash items: Depreciation, deferred income taxes, and the equity component of Allowance for Funds Used During Construction (AFUDC).
• Working capital cash flow impact: Minor fluctuations based on seasonal fuel inventory and receivable collections.
• Capex intensity: Extremely high, requiring constant access to debt and equity capital markets.
• Cash tax rate vs. GAAP effective tax rate: Cash taxes are minimal due to accelerated depreciation and production tax credits.

1. Assumptions: Hardcoded drivers for rate base growth, allowed ROE, equity thickness, O&M inflation, and financing costs.
2. Rate Base Schedule: Roll-forward of rate base for Kentucky, Pennsylvania, and Rhode Island (Beginning Balance + Capex - Depreciation = Ending Balance).
3. Revenue Build: Calculation of revenue by segment based on rate base, allowed returns, and recovery of fuel and O&M costs.
4. Income Statement: Consolidated view showing Operating Revenues, Fuel and Purchased Power, O&M, Depreciation, Taxes Other Than Income, Operating Income, Interest Expense, and Net Income.
5. Balance Sheet: Assets (Cash, Receivables, Fuel Inventory, PP&E, Goodwill, Regulatory Assets) and Liabilities (Payables, Short-Term Debt, Long-Term Debt, Regulatory Liabilities, Deferred Taxes, Equity).
6. Cash Flow Statement: OCF (Net Income plus D&A and deferred taxes), CFI (Capex), and CFF (Debt issuance, equity issuance, dividends).
7. Debt Schedule: Roll-forward of short-term and long-term debt, calculating interest expense based on weighted average interest rates.
8. Valuation: Dividend Discount Model (DDM) and Sum-of-the-Parts (SOTP) based on P/E multiples.

1. Kentucky Rate Base = Prior Year Kentucky Rate Base + Kentucky Capex - Kentucky Depreciation
2. Pennsylvania Rate Base = Prior Year Pennsylvania Rate Base + Pennsylvania Capex - Pennsylvania Depreciation
3. Rhode Island Rate Base = Prior Year Rhode Island Rate Base + Rhode Island Capex - Rhode Island Depreciation
4. Total Rate Base = Kentucky Rate Base + Pennsylvania Rate Base + Rhode Island Rate Base
5. Segment Earnings = (Average Segment Rate Base x Equity Thickness x Allowed ROE) + AFUDC Equity
6. Segment Revenue = Fuel Costs + O&M + Depreciation + Taxes + Interest Expense + Segment Earnings
7. Total Operating Revenue = Kentucky Revenue + Pennsylvania Revenue + Rhode Island Revenue
8. Total Capex = Kentucky Capex + Pennsylvania Capex + Rhode Island Capex
9. Interest Expense = Average Total Debt x Weighted Average Interest Rate
10. Dividends Paid = Prior Year EPS x Target Payout Ratio x Shares Outstanding
11. External Financing Need = Cash Flow from Operations - Total Capex - Dividends Paid
12. New Debt Issued = External Financing Need x Target Debt-to-Capital Ratio

The Assumptions sheet feeds the Rate Base Schedule (capex and depreciation rates) and the Revenue Build (allowed ROE and equity thickness). The Rate Base Schedule feeds the Revenue Build (calculating the return on investment) and the Balance Sheet (PP&E roll-forward). The Revenue Build feeds the top line of the Income Statement. The Income Statement generates Net Income, which feeds the top of the Cash Flow Statement and Retained Earnings on the Balance Sheet. The Cash Flow Statement determines the External Financing Need, which feeds the Debt Schedule. The Debt Schedule calculates Interest Expense, which creates a circularity by feeding back into the Income Statement and Revenue Build because interest is a recoverable cost in regulatory mechanisms.

• Revenue and income items are positive.
• Expense items (Fuel, O&M, Depreciation, Interest) are positive in their specific build schedules but subtracted in the Income Statement totals.
• Assets are positive. Liabilities and Equity are positive.
• Cash Flow Statement: Cash inflows are positive. Cash outflows (Capex, Dividends) are negative.
• External Financing Need is positive if cash is required, and negative if surplus cash is generated.

• Failing to model fuel costs as a direct pass-through, which distorts operating margins if commodity prices spike.
• Ignoring the AFUDC equity component, which inflates reported earnings but does not provide immediate cash flow.
• Applying a standard DCF valuation instead of a Dividend Discount Model, which misvalues utilities due to their perpetual negative free cash flow.
• Miscalculating the rate base roll-forward by confusing total PP&E with the actual regulatory rate base approved by commissions.
• Overlooking the circularity between debt issuance, interest expense, and net income, requiring an iterative calculation toggle.
• Forgetting to account for regulatory lag, where capital investments do not earn a return until the next base rate case is resolved.
• Misinterpreting O&M savings targets as revenue drivers rather than margin protectors against inflation.
• Failing to adjust for the seasonality of weather-driven volume sales in quarterly models.

• Total Rate Base should grow at approximately 10.3% CAGR through 2029 based on management guidance.
• EPS growth should fall within the 6% to 8% target range.
• Dividend payout ratio should remain between 60% and 65%.
• Total Capex from 2026 through 2029 should sum to approximately $23 billion.
• Balance sheet must balance: Total Assets = Total Liabilities + Equity in every period.
• OCF/Net Income conversion should be consistently above 1.2x due to high depreciation.
• Debt-to-Capital ratio should remain near 50% to align with regulatory capital structures.
• Effective tax rate should be lower than the 21% statutory rate due to utility-specific tax credits.

• SEC EDGAR for PPL Corporation 10-K and 10-Q filings.
• PPL Investor Relations website for the Q4 2025 Investor Update and EEI Financial Conference presentations.
• Key peers for benchmarking: Southern Company (SO), Duke Energy (DUK), American Electric Power (AEP), and FirstEnergy (FE).
• Regulatory dockets from the KPSC, PAPUC, and RIPUC for detailed rate case filings and approved ROEs.
• S&P Global Market Intelligence for consensus EPS estimates and utility sector data.

• PPL Corporation Form 10-K for the year ended December 31, 2024 (filed February 2025).
• PPL Corporation Q4 2025 Investor Update Presentation (February 20, 2026).
• PPL Corporation Q4 2025 Earnings Release (February 20, 2026).
• PPL Corporation Q3 2025 Investor Update Presentation (November 5, 2025).
• Rhode Island Public Utilities Commission (RIPUC) filings and dockets.