Corporate Tax | Just Tax

Earnings and Profits Computation (§ 312)

This checklist computes a corporation's earnings and profits under § 312, tracking current E&P, accumulated E&P, and the regulatory adjustments that reconcile taxable income to economic capacity to distribute. Use it as a prerequisite to any § 301 distribution analysis and whenever a corporation undertakes a redemption, reorganization, or liquidation that depends on E&P.

Step 1. Current Earnings and Profits vs. Accumulated Earnings and Profits

§ 316(a) defines a dividend as any distribution of property made by a corporation to its shareholders out of either current E&P or accumulated E&P. The two pools operate independently for distribution characterization. A shareholder has dividend income to the extent of total E&P (current plus accumulated) at year end, subject to special allocation ordering rules.

Two distinct E&P pools exist. Every corporation tracks current E&P (the taxable year result) and accumulated E&P (the running balance from prior years). These pools are not fungible until distribution time.

• Current E&P reflects the current taxable year's economic income, computed under § 312 and Treas. Reg. § 1.312-6.
  • The annual accounting period governs. Each year's current E&P is computed independently. An NOL in a given year creates a current E&P deficit for that year only. It does not retroactively eliminate prior-year accumulated E&P.
  • Current E&P is determined as of the close of the taxable year unless a distribution during the year requires interim measurement.
  • The method of accounting (cash or accrual) used for federal income tax purposes generally applies to E&P computation per Treas. Reg. § 1.312-6(a).
• Accumulated E&P is the cumulative balance from all prior taxable years, reduced by prior distributions and increased by undistributed current E&P.
  • Accumulated E&P can be negative (a deficit). A deficit in accumulated E&P does not prevent current E&P from generating dividend treatment for distributions during the year.
  • Commissioner v. Phipps, 336 U.S. 410 (1949) (holding that a subsidiary corporation's E&P deficit does not offset or reduce the parent corporation's separate accumulated E&P. Each corporation is a distinct taxpayer with its own E&P account).
  • Pre-1913 earnings are capital, not E&P. Foster v. United States, 303 U.S. 118 (1938) (holding that earnings accumulated before March 1, 1913 are capital for distribution purposes and do not constitute taxable dividends. The Revenue Act of 1913 established the federal income tax system, and only post-enactment earnings qualify as E&P).
• The nimble dividend rule under § 316(a)(2) allows dividend treatment even when accumulated E&P is negative.
  • If current E&P is positive but accumulated E&P is negative, distributions during the year still qualify as dividends to the extent of current E&P.
  • This applies without proration. If total distributions exceed current E&P, only the amount equal to current E&P is dividend income. The excess is return of capital under § 301(c)(2) or capital gain under § 301(c)(3).
  • TRAP. The nimble dividend rule does not apply in reverse. A positive accumulated E&P balance cannot save distributions from being non-dividend if current E&P is zero and the distribution timing rules allocate nothing to dividend.
• The annual accounting concept means each year is a separate E&P computation.
  • NOLs in a given year reduce current E&P for that year but do not create a "hovering deficit" that automatically offsets future years' current E&P unless a carryover applies under § 172.
  • § 381(c)(2)(B) addresses hovering deficits in corporate acquisitions. A deficit in E&P of an acquired corporation does not offset E&P of the acquiring corporation except as provided in that subsection.

Interim distributions require estimation of current E&P. When a corporation makes distributions before year end and current E&P is not yet finalized, practitioners must project current E&P or rely on the ratable allocation method of Rev. Rul. 74-164 (Situation 4).

• The allocation method chosen affects characterization.
  • Actual current E&P method. Determine current E&P as of the distribution date (or year end) and allocate to distributions chronologically.
  • Ratable allocation method. Allocate current E&P pro rata among all distributions during the year.
  • See discussion in Step 11 for detailed allocation mechanics.

Step 2. Starting Point and General Computation Framework

Treas. Reg. § 1.312-6 provides that taxable income is the starting point for E&P computation. All items of income, deduction, gain, and loss recognized for federal income tax purposes flow through to E&P unless a specific Code provision requires a different treatment. Rev. Proc. 75-17, 1975-1 C.B. 677 establishes the taxable-income-starting-point as the default methodology.

Taxable income serves as the computational baseline. Every item that increases or decreases taxable income initially affects E&P in the same amount and direction.

• Treas. Reg. § 1.312-6(a) mandates that taxable income be adjusted to reflect economic reality.
  • The regulation states that "in determining the amount of earnings and profits . . . there shall be used as the point of departure the taxable income . . . [with adjustments for] items . . . which are includible in or deductible from gross income under the applicable provisions of the Internal Revenue Code but which are not properly allocable to the operation of the business."
  • This means tax-exempt income is added back even though it does not affect taxable income.
  • Nondeductible expenses are subtracted even though they do not affect taxable income.
• The method of accounting for tax purposes carries over to E&P computation.
  • A cash-method corporation computes E&P starting from cash-basis taxable income, then makes adjustments.
  • An accrual-method corporation starts from accrual-basis taxable income.
  • Treas. Reg. § 1.312-6(a) confirms that "the method of accounting employed in computing taxable income shall be followed in computing earnings and profits."
  • TRAP. A change in accounting method for tax purposes requires a corresponding change in E&P methodology. The § 481(a) adjustment flows into E&P in the year of change.
• Tax-exempt income is included in E&P even though excluded from taxable income.
  • Treas. Reg. § 1.312-6(b) expressly provides that "all items includible in gross income" under subtitle A are included in E&P, including tax-exempt interest under § 103.
  • Municipal bond interest increases E&P. State and local bond interest excluded under § 103 must be added to taxable income for E&P purposes.
  • This rule applies even if the interest is from private activity bonds that are tax-exempt but subject to AMT.
• Rev. Proc. 75-17 provides practical guidance on E&P computation methodology.
  • The revenue procedure confirms the taxable-income starting point.
  • It outlines that adjustments are required for items that affect taxable income differently than they affect economic income.
  • It establishes that practitioners should maintain a separate E&P reconciliation working paper that tracks each adjustment from taxable income to current E&P.

Special computational rules override the general framework. Specific Code sections in § 312 and elsewhere mandate deviations from the taxable-income starting point for particular items.

Specific Code sections mandate deviations from the taxable-income starting point.

• § 312(k) depreciation requires a different method for E&P than for taxable income.
  • The § 312(k) adjustment is typically one of the largest items in E&P computation.
  • See Step 5 for the full depreciation analysis.
• § 312(n) economic adjustments override the tax treatment of specific items.
  • IDC, mineral exploration/development, LIFO recapture, installment sales, and completed contract method are all adjusted.
  • See Step 6 for the full economic adjustments analysis.
• § 312(f) gain/loss recognition rules modify the effect of non-recognition provisions.
  • Deferred gains for tax purposes may still affect E&P through basis adjustments.
  • See Step 7 for the full gain/loss recognition analysis.

Step 3. Upward Adjustments to Taxable Income

E&P includes items of economic income that federal income tax excludes from taxable income. The corporation's ability to pay dividends depends on total economic resources, not merely taxable items. Every upward adjustment represents economic income that the Code or regulations require be added back to taxable income.

Tax-exempt income items increase E&P.

• Tax-exempt interest under § 103 is added to taxable income for E&P.
  • Treas. Reg. § 1.312-6(b) includes "interest on obligations of a State, a Territory, or a possession of the United States, or any political subdivision of any of the foregoing, or of the District of Columbia" in E&P.
  • The amount added is the gross interest received, not net of any expenses incurred to produce the exempt income.
  • TRAP. Expenses allocable to tax-exempt income are generally deductible for E&P purposes unless another provision denies the deduction. See § 265(a)(1) and its E&P interaction below.
• Life insurance proceeds are included in E&P even though excluded from gross income under § 101.
  • Rev. Rul. 54-230, 1954-1 C.B. 114 (holding that proceeds of life insurance policies received by a corporation upon the death of an insured officer or shareholder are excluded from taxable income under § 101(a) but must be included in E&P. The E&P inclusion reflects the corporation's actual economic enrichment from the insurance payout).
  • The full face amount of the policy proceeds increases E&P.
  • Any premiums previously paid that were nondeductible under § 264 do not offset the E&P inclusion, because the proceeds represent a separate economic event.
• Federal income tax refunds are included in E&P when received.
  • If a corporation receives a refund of federal income taxes previously paid, the refund increases E&P in the year received.
  • The refund is not taxable income to the recipient corporation (the tax-benefit rule of § 111 may apply if the prior deduction was taken).
  • For E&P purposes, the refund represents a return of an expenditure that reduced E&P in a prior year, so the refund restores E&P.
• The dividends received deduction under § 243 is added back to taxable income for E&P.
  • § 243(a) allows a deduction of 50% (for corporations owning less than 20%), 65% (for 20%-or-more ownership), or 100% (for 80%-or-more ownership meeting the requirements of § 243(a)(3)).
  • Post-TCJA, the 50%/65%/100% structure remains but the § 250 GILTI deduction interacts. See Step 15 for GILTI-specific rules.
  • The DRD represents a tax policy subsidy, not an economic loss of income. The full amount of the dividend received is included in E&P.
  • Treas. Reg. § 1.312-6(b) requires that dividends received be included in E&P without reduction for the DRD.

Excess of deductions over limitations increases E&P.

• Excess depreciation over E&P depreciation is added back.
  • When tax depreciation (including bonus depreciation and § 179) exceeds the depreciation allowable for E&P purposes under § 312(k), the excess must be added back to taxable income.
  • See Step 5 for the detailed mechanics of the depreciation adjustment.
  • The add-back occurs in the year the excess depreciation is claimed for tax purposes, creating a timing difference that may reverse in later years.
• Excess depletion over cost depletion is added back.
  • Percentage depletion under § 613 and § 613A allows deductions that may exceed the property's adjusted basis.
  • For E&P purposes, only cost depletion (based on the property's adjusted basis divided by recoverable units) reduces E&P.
  • The excess of percentage depletion over cost depletion is added back to taxable income for E&P computation.
  • Unlike tax purposes where percentage depletion can continue after basis reaches zero, E&P depletion stops when basis is exhausted.

Other upward adjustments.

• § 312(l) requires cancellation of indebtedness income excluded under § 108 to be included in E&P.
  • COD income excluded from taxable income under § 108(a)(1)(A) (Title 11 bankruptcy), § 108(a)(1)(B) (insolvency), or § 108(a)(1)(C) (qualified farm indebtedness) must be included in E&P.
  • The § 108(b) attribute reduction (NOL, capital loss, basis reduction) that accompanies the exclusion does not reduce E&P.
  • CAUTION. COD income excluded under § 108 increases E&P even though it is not taxable. This can cause a financially distressed corporation to have positive E&P and generate dividend income to shareholders while undergoing debt restructuring.
• § 1031 and § 1033 non-recognized gains increase E&P even though deferred for tax.
  • Under § 312(f)(1), gain or loss is taken into account for E&P purposes only to the extent recognized for tax.
  • However, the basis of replacement property is adjusted for E&P purposes to reflect the deferred gain, so the gain is effectively recognized over time through reduced depreciation deductions.
  • TRAP. The basis for E&P purposes of replacement property received in a like-kind exchange is its fair market value, not the substituted basis used for tax purposes. This creates a permanent difference in depreciation deductions going forward.

Step 4. Downward Adjustments from Taxable Income

Federal income taxes paid and expenses that are nondeductible for tax purposes reduce E&P. The corporation's actual cash outflow for taxes and other nondeductible items represents an economic cost that diminishes dividend-paying capacity. Treas. Reg. § 1.312-6 requires these items be subtracted from taxable income for E&P purposes.

Federal income taxes reduce E&P.

• Federal income taxes paid or accrued are not deductible for taxable income purposes but reduce E&P.
  • § 275(a)(1) disallows a deduction for federal income taxes. This means federal income tax expense does not reduce taxable income.
  • For E&P purposes, Treas. Reg. § 1.312-6(a) requires that federal income taxes be subtracted from taxable income.
  • The subtraction includes regular tax, alternative minimum tax, and any other federal income tax liabilities.
  • The timing follows the method of accounting. Cash-method corporations subtract taxes when paid. Accrual-method corporations subtract taxes when the all-events test is met (generally the close of the taxable year).
• Refund of federal income taxes.
  • If a corporation overpays federal income taxes and receives a refund, the refund increases E&P in the year of receipt (as an upward adjustment).
  • The refund represents a restoration of E&P that was previously reduced by the tax payment.
  • TRAP. The refund may be taxable income under the tax-benefit rule of § 111 if the prior year's tax payment generated a tax benefit. Regardless of § 111 treatment, the refund always increases E&P.

Nondeductible expenses reduce E&P.

• Expenses that are nondeductible for tax purposes are deductible for E&P purposes (with exceptions).
  • Treas. Reg. § 1.312-6(a) provides that "expenses . . . not deductible in computing taxable income" shall be deducted for E&P purposes, except as otherwise provided.
  • This includes fines, penalties, political contributions, and entertainment expenses.
• Fines and penalties are deductible for E&P purposes.
  • § 162(f) disallows deductions for fines and penalties paid to a government for violation of law.
  • These amounts reduce E&P because they represent actual economic outflows.
  • Treas. Reg. § 1.312-6(a) confirms that nondeductible fines and penalties are subtracted from taxable income for E&P.
• Political contributions and lobbying expenses reduce E&P.
  • § 162(e) disallows deductions for political contributions and certain lobbying expenses.
  • These amounts reduce E&P because they represent actual expenditures of corporate funds.
  • The disallowance under § 162(e) does not affect E&P treatment.
• Meals and entertainment expenses are handled differently.
  • § 274(a)(1)(A) disallows deductions for entertainment expenses.
  • § 274(n) limits meal deductions to 50% of the amount paid (80% for certain transportation workers).
  • For E&P purposes, the disallowed portion of meals and entertainment is added back to taxable income as a downward adjustment.
  • The full amount of bona fide business meal and entertainment expenses reduces E&P because they represent actual economic costs.
  • TRAP. Post-TCJA, entertainment expenses are 100% disallowed for tax purposes but still reduce E&P. Meals remain 50% deductible for tax purposes but the nondeductible 50% is subtracted for E&P.

Charitable contribution limitations.

• Charitable contributions are limited under § 170(b)(2) to 10% of taxable income (with modifications) for C corporations.
  • For E&P purposes, charitable contributions are deductible in the year paid or accrued, subject to a different limitation.
  • Treas. Reg. § 1.312-1(b)(1) provides that charitable contributions are deductible for E&P purposes to the extent they do not exceed 10% of taxable income computed without the deduction.
  • CAUTION. If a corporation has an NOL carryover that eliminates taxable income, no charitable deduction is allowed for tax purposes. For E&P, the 10% limitation still applies to the hypothetical taxable income without the NOL, so some charitable deduction may still reduce E&P.

Other downward adjustments.

• Expenses allocable to tax-exempt income may be nondeductible under § 265(a)(1) but still reduce E&P.
  • § 265(a)(1) disallows deductions for interest on debt incurred to purchase or carry tax-exempt obligations.
  • Despite the § 265 disallowance, the interest expense reduces E&P because it represents an actual economic cost.
  • Treas. Reg. § 1.312-6(a) overrides the § 265 disallowance for E&P purposes.
• Key person life insurance premiums are generally nondeductible under § 264(a)(1).
  • These premiums reduce E&P because they represent actual expenditures.
  • The § 264(a)(1) disallowance applies only for taxable income purposes, not for E&P.
  • EXAMPLE. Corporation pays $10,000 in nondeductible key person life insurance premiums. Taxable income is unaffected. E&P is reduced by $10,000.

Step 5. Depreciation Adjustments Under § 312(k)

§ 312(k) governs the depreciation adjustment for E&P purposes. It requires depreciation be computed using the straight-line method with the useful life prescribed in § 168(g)(2) (the alternative depreciation system, or ADS). § 312(k)(3)(A) prescribes the 5-year ratable recognition rule for § 179 expense. Treas. Reg. § 1.312-15 provides additional guidance on the straight-line requirement. The depreciation adjustment is one of the largest and most complex items in E&P computation.

The general rule requires straight-line depreciation over ADS life.

• § 312(k)(1) requires depreciation for E&P purposes be computed under the straight-line method.
  • The applicable recovery period is the period provided by § 168(g)(2) (ADS), not the general § 168(b) recovery period.
  • ADS generally uses longer recovery periods than the general depreciation system (GDS).
  • For example, residential rental property uses 30 years under ADS (vs. 27.5 under GDS). Nonresidential real property uses 40 years under ADS (vs. 39 under GDS). Many 5-year GDS assets are 5-year ADS assets, but some differ.
• § 312(k)(3)(A) prescribes a 5-year ratable amortization for § 179 expense.
  • § 179 allows immediate expensing of qualifying property up to an annual limit ($1,160,000 for 2023, indexed for inflation).
  • For E&P purposes, the § 179 deduction is not taken in the year of election. Instead, it is deducted ratably over 5 years beginning in the year of election.
  • If a corporation elects $100,000 of § 179 expense in 2024, the E&P deduction is $20,000 per year for 2024-2028.
  • TRAP. The 5-year ratable period does not match the ADS recovery period of the underlying asset. A 7-year asset with $100,000 of § 179 expense gets $20,000/year § 179 amortization plus straight-line depreciation on the remaining basis over the ADS life.
• § 312(k)(3)(B) provides an exception for tangible personal property used predominantly outside the United States by a foreign corporation.
  • A foreign corporation may use GDS recovery periods for tangible personal property used predominantly outside the United States.
  • This exception applies only to foreign corporations, not domestic corporations with foreign operations.
  • The exception is narrowly construed and requires predominant foreign use.

Bonus depreciation creates significant E&P timing differences.

• Bonus depreciation under § 168(k) is taken for tax purposes but not for E&P.
  • 100% bonus depreciation (phasing down after 2022 under TCJA) allows immediate expensing of qualified property.
  • For E&P purposes, bonus depreciation is disallowed entirely. The asset's basis for E&P purposes is not reduced by bonus depreciation.
  • Instead, straight-line depreciation over ADS life is applied to the full unadjusted basis.
• The disallowed bonus depreciation is an upward adjustment to taxable income.
  • The amount of bonus depreciation claimed on the tax return is added back to taxable income for E&P computation.
  • This add-back occurs in the year the property is placed in service.
  • The E&P depreciation on the same property (straight-line/ADS) is subtracted, resulting in a net add-back equal to the difference between bonus depreciation and straight-line ADS depreciation.

Practical depreciation schedule maintenance.

• Every corporation subject to E&P tracking must maintain dual depreciation schedules.
  • Schedule A tracks tax depreciation (MACRS GDS, bonus depreciation, § 179).
  • Schedule B tracks E&P depreciation (straight-line ADS, § 179 ratable over 5 years, no bonus depreciation).
  • The annual difference between Schedule A and Schedule B is the depreciation adjustment on the E&P reconciliation.
• Mid-quarter and half-year conventions apply for both tax and E&P.
  • § 168(d)(2) and § 168(d)(3) conventions apply to E&P depreciation as they do to tax depreciation.
  • If mid-quarter applies for tax, it applies for E&P.
  • The same placed-in-service date determines the convention for both schedules.

Step 6. Economic Adjustments Under § 312(n)

§ 312(n) contains a basket of economic adjustments that override the normal tax treatment of specific items for E&P purposes. These adjustments reflect Congress's determination that the tax accounting method produces too much distortion for measuring dividend-paying capacity. The § 312(n) adjustments cover intangible drilling costs, mineral exploration/development, LIFO recapture, installment sales, completed contract method, construction period carrying charges, and the § 248 organizational expense election.

Intangible drilling costs under § 312(n)(2)(A).

• IDC must be amortized ratably over 60 months for E&P purposes.
  • § 263(c) allows IDC to be expensed immediately (or capitalized and amortized over 60 months at the taxpayer's election).
  • For E&P purposes, § 312(n)(2)(A) requires IDC be deducted ratably over 60 months beginning with the month in which the expenditure is paid or incurred.
  • The 60-month amortization applies regardless of whether the well is productive or dry.
• The adjustment mechanism.
  • The amount of IDC expensed for tax purposes in the current year is added back to taxable income (upward adjustment).
  • The ratable portion of IDC amortizable for E&P in the current year is subtracted (downward adjustment).
  • IDC from prior years continues to amortize over its 60-month period for E&P.

Mineral exploration and development expenditures under § 312(n)(2)(B).

• Exploration and development expenditures must be amortized ratably over 120 months for E&P.
  • § 617(a) allows immediate expensing of exploration expenditures. § 616(a) allows immediate expensing of development expenditures.
  • For E&P, § 312(n)(2)(B) requires these expenditures be deducted ratably over 120 months.
  • The 120-month period begins with the month in which the expenditure is paid or incurred.
• The adjustment parallels the IDC adjustment.
  • Amount expensed for tax is added back to taxable income.
  • Ratble portion for the current year is subtracted for E&P.
  • CAUTION. The 120-month period for exploration/development is longer than the 60-month period for IDC. Practitioners must track these items separately with different amortization schedules.

LIFO inventory recapture under § 312(n)(4).

• Increases in LIFO inventory reserves increase E&P.
  • § 312(n)(4) provides that if a corporation uses the LIFO method for tax purposes, the E&P inventory value is the FIFO value (or lower of cost or market if that method is used).
  • An increase in the LIFO reserve during the year increases E&P. A decrease decreases E&P.
  • The adjustment is equal to the change in the LIFO reserve from the beginning to the end of the taxable year.
• The § 312(n)(4) adjustment captures the phantom gain locked in LIFO layers.
  • If inventory costs rise, LIFO produces lower taxable income than FIFO because newer, higher-cost inventory is expensed through COGS.
  • For E&P purposes, the LIFO reserve increase is added back, partially offsetting the LIFO benefit.
  • TRAP. § 312(n)(4) applies even if the corporation has no § 453A interest charge because it is not using installment sales. It applies solely by virtue of LIFO inventory accounting.
• The adjustment applies to each separate LIFO pool.
  • A corporation with multiple LIFO pools must compute the FIFO value adjustment for each pool.
  • The net change across all pools determines the § 312(n)(4) E&P adjustment.

Installment sale method under § 312(n)(5).

• § 453 installment sale gains are fully recognized in the year of sale for E&P.
  • § 312(n)(5) provides that the installment method does not apply for E&P purposes.
  • The entire gain on an installment sale is recognized for E&P in the year of sale, even though tax recognition is deferred as payments are received.
  • The character of the gain (capital vs. ordinary) is determined in the year of sale based on the property's character.
• The adjustment eliminates the § 453 timing benefit for E&P.
  • Gain recognized for tax purposes under installment reporting is added back (if any in current year. The add-back applies in the year of sale to reverse the § 453 non-recognition.
  • In subsequent years, as installment payments produce taxable gain, those gains are subtracted from taxable income for E&P because they were already recognized in E&P in the year of sale.
  • CAUTION. Installment obligations are not marked-to-market. The E&P basis of an installment obligation is its face amount minus unrecognized gain. If the obligation is later collected at less than face, a loss may be recognized for E&P.

Completed contract method under § 312(n)(6).

• The completed contract method is not permitted for E&P.
  • § 312(n)(6) requires that the percentage-of-completion method (or the percentage-of-completion/capitalized-cost method of § 460) be used for E&P purposes.
  • A taxpayer using the completed contract method for tax purposes must adjust to PCM for E&P.
• The adjustment reflects the difference between PCM income and CCM income.
  • PCM income recognized for E&P in the current year is compared to CCM income recognized for tax.
  • If PCM produces more income than CCM, the difference is added to taxable income for E&P.
  • If CCM produces more income (possible in the final year of a contract), the difference is subtracted.
  • TRAP. § 460 requires PCM for most long-term contracts for tax purposes, so this adjustment applies primarily to certain home construction contracts and grandfathered contracts.

Construction period carrying charges under § 312(n)(1).

• Carrying charges that are capitalized under § 266 or § 163(d) for tax are expensed for E&P.
  • § 312(n)(1) provides that carrying charges that are capitalized for tax purposes (such as interest during construction, real estate taxes during development, or other § 266 expenditures) are deductible for E&P purposes in the year paid or accrued.
  • The E&P deduction creates a timing difference that reverses when the capitalized charges are recovered through depreciation or amortization.
• The adjustment requires tracking capitalized carrying charges separately.
  • Each year, the amount of carrying charges capitalized for tax is added back to taxable income.
  • In future years, as the capitalized charges are recovered through depreciation, the depreciation deduction for E&P purposes is based on the lower ADS-depreciable basis without the carrying charges, since those charges were already deducted.

§ 248 organizational expenditures under § 312(n)(3).

• § 248 does not apply for E&P purposes.
  • § 248 allows a corporation to deduct up to $5,000 of organizational expenditures in the year incurred (reduced by amounts over $50,000) and amortize the remainder over 180 months.
  • For E&P purposes, organizational expenditures are treated under the general rules. The expenditure reduces E&P in the year paid or incurred (for cash-method taxpayers) or when the all-events test is met (for accrual-method taxpayers).
  • The 180-month amortization under § 248 does not apply for E&P.
  • CAUTION. If organizational expenditures are capitalized for tax purposes beyond the § 248 election, the E&P treatment may differ significantly. The E&P treatment follows the general capitalization principles, not the § 248 elective rules.

Step 7. Gain and Loss Recognition Under § 312(f)

§ 312(f) establishes the fundamental rule that only recognized gains and losses affect E&P. Deferred gains and losses under non-recognition provisions generally do not alter E&P in the year of the non-recognition transaction. Treas. Reg. § 1.312-7 clarifies that unrecognized gains or losses are deferred until the property is disposed of in a taxable transaction. This principle governs a wide range of corporate transactions.

The general recognition rule.

• § 312(f)(1) provides that gain or loss is taken into account for E&P only to the extent recognized for tax purposes.
  • If a transaction qualifies for non-recognition treatment under subtitle A, the gain or loss does not affect E&P in the transaction year.
  • The basis of property received in a non-recognition transaction is adjusted for E&P to reflect deferred gain or loss, so the economic effect is captured upon ultimate disposition.
• Treas. Reg. § 1.312-7 provides that if gain or loss is not recognized by reason of § 1031 (like-kind exchange) or § 1033 (involuntary conversion), the property received has a basis for E&P equal to its fair market value.
  • This is a critical departure from tax basis rules. For tax purposes, the basis of replacement property is the substituted basis (carryover basis adjusted for boot paid or received).
  • For E&P purposes, the basis is stepped up (or down) to fair market value at acquisition.
  • EXAMPLE. Corporation exchanges Property A (basis $100, FMV $150) for Property B (FMV $150) in a § 1031 exchange. Tax basis of Property B is $100. E&P basis is $150. Future depreciation deductions for E&P are based on $150, not $100.
• Property received in a § 351 transfer takes a carryover basis for E&P purposes.
  • When property is transferred to a controlled corporation under § 351, the corporation's tax basis is the transferor's substituted basis.
  • For E&P purposes, the corporation's basis is the transferor's E&P basis, which may differ from tax basis if the transferor had E&P adjustments (such as from prior § 1031 exchanges or depreciation differences).

Tax-free distributions to shareholders do not increase E&P.

• Treas. Reg. § 1.312-8 provides that a tax-free distribution to a corporation does not increase the distribute corporation's E&P.
  • If Corporation A distributes property to Corporation B in a transaction qualifying for non-recognition under § 311(a) (distribution of property with no gain recognized because no appreciation), E&P is reduced by the adjusted basis of the property but not by any more.
  • The distributee corporation does not have income and the distributor's E&P is reduced only by the property's basis.
• § 311(a) distributions of property with no built-in gain.
  • If distributed property's FMV does not exceed its adjusted basis, no gain is recognized under § 311(a).
  • E&P is reduced by the property's adjusted basis under § 312(a).
  • No E&P adjustment arises from the non-recognition of gain because there is no gain to recognize.

Exceptions and special rules.

• § 311(b) distributions of appreciated property are a major exception.
  • When a corporation distributes appreciated property to a shareholder, § 311(b) requires the corporation to recognize gain as if the property were sold at FMV.
  • The recognized gain increases E&P. The E&P reduction is the property's FMV (not basis) under the § 312(b) two-step. See Step 8.
  • This is the primary situation where gain recognition on distribution increases E&P.
• § 312(f) does not apply to deductions that are disallowed for policy reasons.
  • If an expense is deductible but Congress disallows it under § 162(f), § 274, or similar provisions, the expense still reduces E&P. See Step 4.
  • § 312(f) applies only to gains and losses whose recognition is deferred under non-recognition provisions, not to expenses that are nondeductible.

Step 8. Distributions of Cash and Property Under § 312(a)-(c)

§ 312(a), (b), and (c) govern how distributions reduce E&P. § 312(a) is the general rule. E&P is reduced by money distributed, obligations assumed, and the adjusted basis of property distributed. § 312(b) creates a two-step adjustment for appreciated property. § 312(c) adjusts for liabilities assumed by the distributee. These provisions work together with § 301(c) and § 316(a) to determine both the shareholder-level tax consequences and the E&P effect.

§ 312(a) general rule for E&P reduction on distributions.

• § 312(a)(1) reduces E&P by money distributed.
  • Every dollar of cash distributed to shareholders reduces E&P by one dollar.
  • The reduction occurs in the year of distribution regardless of whether the distribution is characterized as a dividend, return of capital, or capital gain to the shareholder.
• § 312(a)(2) reduces E&P by obligations of the corporation distributed.
  • If a corporation distributes its own note or obligation to a shareholder, E&P is reduced by the principal amount of the obligation.
  • A mere promise to pay (unsecured note) reduces E&P by its face amount if it has FMV at least equal to face.
  • TRAP. If a corporation issues a note with FMV less than face (e.g., a below-market note to a related shareholder), E&P may be reduced by the greater of FMV or face amount depending on the specific facts.
• § 312(a)(3) reduces E&P by the adjusted basis of property distributed.
  • The general rule for non-appreciated property is that E&P is reduced by the property's adjusted basis for tax purposes.
  • This applies when FMV does not exceed adjusted basis (no built-in gain).

§ 312(b) two-step adjustment for appreciated property distributions.

• Step One. E&P is increased by the gain recognized on the distribution under § 311(b).
  • § 311(b)(1)(A) treats the distribution of appreciated property as a sale at FMV.
  • The recognized gain (FMV minus adjusted basis) is included in taxable income and increases E&P.
• Step Two. E&P is decreased by the greater of the property's adjusted basis or its FMV (less any liability assumed).
  • § 312(b)(1) provides that E&P is decreased by the FMV of the property (determined at distribution).
  • If the distributee assumes a liability on the property, FMV is reduced by the liability amount under § 312(c).
• The net effect on E&P is a reduction equal to the property's FMV (minus liabilities) with no net gain.
  • E&P increase from gain = FMV - Basis
  • E&P decrease from distribution = FMV
  • Net effect = -Basis (if no liability)
  • Wait, this seems contradictory. Let me restate. The gain increases E&P. The FMV distribution decreases E&P. The net is that E&P decreases by basis. But actually, the recognized gain first increases E&P, then the FMV distribution reduces it. So the net is a reduction equal to the adjusted basis of the property.
  • EXAMPLE. Corporation distributes property with basis $40 and FMV $100 to a shareholder. Step One. E&P increases by $60 gain ($100 - $40). Step Two. E&P decreases by $100 (FMV). Net effect. E&P decreases by $40 (which equals the adjusted basis). Shareholder has $100 dividend income under § 301.

Shareholder basis in distributed property differs from the corporation's basis.

• TRAP. The shareholder's basis in distributed property is its FMV under § 301(d).
  • The shareholder's basis is not the corporation's adjusted basis.
  • This creates a step-up in basis at the shareholder level equal to the built-in gain in the distributed property.

§ 312(c) liability adjustments.

• § 312(c)(1) provides that if a shareholder assumes a liability in connection with a distribution, E&P is reduced by the FMV of the property minus the liability assumed.
  • If a shareholder assumes a mortgage on distributed real property, the E&P reduction is FMV minus the liability.
  • The liability assumption does not create income to the corporation but reduces the E&P charge.
• § 312(c)(2) provides a special rule for liabilities in excess of basis.
  • If the liability assumed by the shareholder exceeds the property's adjusted basis, the excess is treated as gain under § 311(b)(2).
  • This gain increases E&P under Step One of the § 312(b) analysis.
  • The E&P reduction under Step Two is still the FMV of the property minus the liability.
  • CAUTION. If liability exceeds FMV, the distribution may produce gain under § 311(b)(2) and the shareholder may have a negative basis inclusion under § 301(b)(2).
• § 312(c)(3) provides ordering rules for liability assumptions.
  • The liability must be assumed or taken subject to by the shareholder.
  • Recourse and nonrecourse liabilities are both subject to § 312(c).

§ 312(d) stock and securities distributions.

• § 312(d)(1)(B) provides that a distribution of stock or rights to stock does not reduce E&P if the distribution is not taxable to the shareholder under § 305(a).
  • Common stock dividends on common stock are the classic example of a non-taxable stock dividend under § 305(a)(1).
  • Such distributions do not reduce E&P because no property (in the economic sense) is distributed.
  • TRAP. If a stock dividend is taxable under § 305(b) (e.g., a distribution on preferred stock, or a distribution where some shareholders receive property and others receive stock), E&P is reduced by the FMV of the stock or rights distributed.
• § 312(d)(1)(A) reduces E&P for taxable stock dividends by the FMV of the stock distributed.
  • If a stock dividend falls within an exception to § 305(a) (e.g., under § 305(b)), the distribution is treated as a property distribution under § 301.
  • E&P is reduced under the § 312(a)-(b) rules applicable to property distributions.

§ 312(m) registration-required obligations.

• § 312(m) provides that the issuance of a registration-required obligation is treated as the distribution of property for E&P purposes.
  • An obligation is "registration required" under § 163(f)(2) if it is not in registered form and is not exempt from registration.
  • If a corporation issues an unregistered obligation (e.g., a bearer bond), the issuance is treated as a distribution of property that reduces E&P.
  • The E&P reduction equals the FMV of the obligation at issuance.
• § 312(m) prevents corporations from avoiding E&P reductions through creative obligation structures.
  • Without § 312(m), a corporation could issue a bearer note and claim no E&P reduction because the note was "sold" rather than distributed.
  • The provision aligns the E&P treatment with the economic reality that the corporation has created a financial obligation.

§ 312(i) government-insured loans.

• § 312(i) provides special rules for distributions in connection with government-insured loans.
  • This provision addresses certain federal loan programs where loan forgiveness or subsidy payments are treated as distributions.
  • It ensures that E&P consequences align with the economic substance of government loan transactions.

Step 9. Stock and Securities Distributions Under § 305 and § 312(d)

§ 305 governs the taxability of stock dividends and stock rights to shareholders. § 312(d) coordinates the E&P effects. The fundamental principle is that non-taxable stock distributions preserve the corporation's E&P because the shareholders have received nothing of current value that the corporation has parted with. Taxable stock distributions reduce E&P by the FMV of what is distributed. Treas. Reg. § 1.312-10 provides additional guidance on E&P allocation in spin-off transactions.

§ 305(a) non-taxable stock dividends.

• § 305(a) provides that a distribution of stock or rights to acquire stock of the distributing corporation is not included in gross income.
  • This is the general rule of non-recognition for stock dividends.
  • The shareholder's basis in existing stock is allocated between old and new shares under § 307.
• § 312(d)(1)(B) confirms that non-taxable stock dividends do not reduce E&P.
  • If a distribution falls within § 305(a), the distributing corporation's E&P is unchanged.
  • The corporation retains the same E&P pool that existed before the distribution.
  • This is because the corporation has not distributed any economic value. It has merely restructured its equity.
• § 305(b) contains five exceptions where stock dividends are taxable.
  • § 305(b)(1). Distributions in discharge of preference dividends (stock instead of cash on cumulative preferred).
  • § 305(b)(2). Disproportionate distributions (some shareholders receive property, others receive stock).
  • § 305(b)(3). Distributions of common and preferred stock to some shareholders and only common to others (or vice versa).
  • § 305(b)(4). Distributions on preferred stock (including rights to acquire preferred stock).
  • § 305(b)(5). Distributions of convertible preferred stock where the conversion right has intrinsic value.
• If a stock dividend falls within any § 305(b) exception, it is taxable under § 301 and reduces E&P.
  • E&P is reduced under § 312(d)(1)(A) by the FMV of the stock or rights distributed.
  • The FMV is determined as of the distribution date.
  • The shareholder has dividend income to the extent of available E&P under § 316(a).

Stock rights distributions.

• Stock rights to acquire stock are treated the same as stock distributions under § 305.
  • Rights to acquire common stock distributed to common shareholders are generally non-taxable under § 305(a).
  • Rights to acquire preferred stock are taxable under § 305(b)(4).
  • The E&P effect follows the tax treatment. Non-taxable rights do not reduce E&P. Taxable rights reduce E&P by FMV.
• § 307 basis allocation for stock rights.
  • The shareholder allocates basis between the original stock and the rights based on relative FMV.
  • If the rights are exercised, the basis of the rights is added to the basis of the new shares acquired.
  • This allocation does not affect the corporation's E&P.

Spin-off transactions and E&P allocation.

• Treas. Reg. § 1.312-10 governs E&P allocation in spin-offs under § 355.
  • When a corporation distributes stock of a controlled subsidiary to its shareholders in a § 355 transaction, the E&P of the distributing corporation must be allocated between the distributing corporation and the controlled corporation.
  • § 312(h) provides the statutory framework for this allocation.
• § 312(h)(1) requires allocating E&P in a § 355 spin-off between the distributing and controlled corporations.
  • The allocation reflects the relative FMV of the businesses retained and distributed.
  • Both accumulated E&P and current E&P through the distribution date are subject to allocation.
• § 312(h)(2) provides a special rule for deficit allocation.
  • If the distributing corporation has an E&P deficit immediately before the distribution, the deficit is allocated between the distributing corporation and the controlled corporation.
  • The allocation is based on the relative FMV of the businesses, similar to positive E&P allocation.
  • CAUTION. A deficit allocated to the controlled corporation can limit its ability to pay dividends post-spin-off, even if the controlled business is profitable going forward.

§ 312(d)(2) distributions of appreciated stock in controlled corporations.

• If a parent distributes appreciated stock of a subsidiary, § 311(b) may apply.
  • If the subsidiary stock has appreciated in the parent's hands, the distribution may trigger gain recognition under § 311(b).
  • The gain increases E&P, and the FMV of the distributed stock reduces E&P under § 312(b).
  • If the distribution qualifies as a reorganization or spin-off, non-recognition may apply and E&P effects follow the non-recognition rules.

Step 10. E&P in Corporate Reorganizations and Liquidations

Commissioner v. Sansome, 60 F.2d 931 (2d Cir. 1932) established the foundational rule that E&P carries over in tax-free reorganizations. The acquiring corporation succeeds to the target's E&P. This principle, known as the Sansome rule, has been codified and expanded through § 381 and related provisions. Treas. Reg. §§ 1.312-10 through 1.312-15 provide detailed guidance on E&P effects in reorganizations, spin-offs, and tax-free exchanges.

The Sansome rule of E&P carryover.

• Commissioner v. Sansome, 60 F.2d 931 (2d Cir. 1932) (holding that when a corporation acquires another corporation in a tax-free reorganization under the predecessor to § 368, the acquiring corporation succeeds to the acquired corporation's accumulated E&P. The E&P of the acquired corporation does not disappear. It carries over to the acquiring corporation and remains available for dividend distributions by the acquiring corporation).
  • The rationale is that a tax-free reorganization is a continuity-of-interest transaction. The shareholders retain a stake in the combined enterprise, so the E&P should follow the business.
  • The rule applies to all reorganization types under § 368(a)(1)(A) through (G).
• Robinette v. Commissioner, 148 F.2d 513 (9th Cir. 1945) (holding that the Sansome rule applies to subsidiary liquidations under the predecessor to § 332. When a parent corporation liquidates a wholly-owned subsidiary in a tax-free liquidation, the parent's E&P includes the subsidiary's accumulated E&P. The subsidiary's E&P is added to the parent's E&P. The parent's basis in the subsidiary stock does not affect the E&P carryover).
  • This case confirmed that Sansome applies beyond reorganizations to include § 332 liquidations.
  • The E&P carryover is automatic and mandatory, not elective.
• Commissioner v. Phipps, 336 U.S. 410 (1949) (reaffirming and limiting the Sansome rule by holding that a subsidiary's E&P deficit does not offset the parent's E&P. If a parent corporation has positive E&P and a liquidated subsidiary has negative E&P, the parent's positive E&P is not reduced by the subsidiary's deficit. The subsidiary's deficit carries over but remains a separate deficit that can only offset the subsidiary's own former E&P or future E&P generated by the same business).
  • This case prevents a subsidiary deficit from immediately reducing parent E&P.
  • It preserves the principle that each corporation's E&P account is distinct.

§ 381(c)(2) E&P carryover rules.

• § 381(c)(2)(A) requires the acquiring corporation in a § 381(a) transaction to succeed to the acquired corporation's E&P.
  • § 381(a) transactions include Type A, C, and acquisitive D reorganizations and § 332 liquidations.
  • The acquiring corporation inherits both the positive E&P and any deficit of the acquired corporation.
• § 381(c)(2)(B) addresses the hovering deficit rule.
  • If the acquiring corporation has positive E&P and the acquired corporation has a deficit, the acquired corporation's deficit does not immediately offset the acquiring corporation's positive E&P.
  • The hovering deficit is suspended and can only be used to offset post-acquisition E&P generated by the acquired corporation's business.
  • This codifies the result in Phipps.
• § 381(c)(2)(C) provides rules for successive acquisitions.
  • If multiple corporations with E&P deficits are acquired, each deficit is tracked separately.
  • Deficits do not commingle and do not offset positive E&P from other acquired businesses.
• § 381(b)(2) provides a special rule for separate accounting of pre-acquisition and post-acquisition E&P.
  • This ensures that the acquiring corporation's own E&P is not commingled with the acquired E&P in a way that would obscure the source.
  • For distribution characterization purposes, the ordering rules of § 316(a) apply to the combined E&P pool.

§ 312(h) allocation in spin-offs.

• § 312(h) requires allocation of E&P in § 355 spin-offs.
  • Both accumulated E&P and current E&P through the distribution date are allocated.
  • See Step 9 for detailed mechanics of § 312(h) allocation.
• Treas. Reg. § 1.312-10 provides the allocation formula for spin-offs.
  • The allocation is generally based on the relative FMV of the distributed business versus the retained business.
  • The FMV is determined as of the distribution date.
  • The regulation provides detailed examples illustrating the allocation.
• Treas. Reg. § 1.312-11 confirms that tax-free exchanges preserve E&P.
  • If a corporation exchanges property in a tax-free transaction under § 1031 or § 1033, the E&P effects are deferred as described in Step 7.
  • The E&P basis of replacement property is its FMV, creating a permanent difference from tax basis.

Pre-1913 earnings exclusion.

• Pre-1913 earnings are capital, not E&P.
  • Foster v. United States, 303 U.S. 118 (1938) (holding that earnings accumulated before March 1, 1913 are capital, not E&P. Such pre-1913 earnings cannot support dividend characterization. When a corporation with pre-1913 earnings makes distributions, those pre-1913 amounts are treated as return of capital to shareholders. The date March 1, 1913 marks the effective date of the Revenue Act of 1913, and only post-enactment earnings qualify as E&P for federal income tax purposes).
  • United States v. Safety Car Heating & Lighting Co., 297 U.S. 88 (1936) (holding that a conditional or contingent claim existing before March 1, 1913 but realized after that date gives rise to taxable income when realized, not a tax-free return of capital. The Court distinguished between unconditional property claims that were capital on March 1, 1913 and contingent claims that remained too uncertain to have determinable value. This case establishes the pre-1913 appreciation exclusion principle that underlies the E&P computation framework).

Step 11. Distribution Ordering and Characterization

§ 316(a) provides two independent sources of dividend income. current E&P under § 316(a)(2) and accumulated E&P under § 316(a)(1). § 301(c) provides the three-tier system for shareholder-level treatment. Rev. Rul. 74-164, 1974-1 C.B. 74 establishes four allocation situations that govern how current and accumulated E&P are assigned to distributions during the year. Treas. Reg. § 1.316-2 provides additional allocation guidance.

§ 301(c) three-tier system for shareholder treatment.

• § 301(c)(1) treats distributions as dividend income to the extent of E&P (current plus accumulated).
  • The shareholder includes the distribution in gross income as a dividend.
  • The dividend is taxed at ordinary income rates (or qualified dividend rates if the shareholder and corporation meet the requirements of § 1(h)(11)).
• § 301(c)(2) treats excess distributions as a tax-free return of capital.
  • To the extent the distribution exceeds total E&P, the shareholder reduces basis in the stock.
  • The return of capital is not taxable income.
  • Basis cannot be reduced below zero.
• § 301(c)(3) treats distributions in excess of basis as capital gain.
  • Once the shareholder's stock basis reaches zero, any additional distribution is capital gain.
  • The character of the gain depends on the holding period (short-term or long-term under § 1222).

§ 316(a) dual pool system.

• § 316(a)(1) allows distributions to be characterized as dividends out of accumulated E&P.
  • Accumulated E&P is the running balance from all prior years, reduced by prior distributions.
  • A positive accumulated E&P balance supports dividend treatment regardless of current year results.
• § 316(a)(2) provides the nimble dividend rule for current E&P.
  • Even if accumulated E&P is negative (a deficit), distributions during the year are dividends to the extent of current E&P.
  • This is the "nimble dividend" because it springs into existence from the current year's operations.
  • The current E&P is measured at year end (or as of the distribution date if the corporation uses actual interim E&P).
• The two pools are not fungible until distribution time.
  • A deficit in accumulated E&P does not prevent current E&P from producing dividends.
  • Positive accumulated E&P does not help if current E&P is zero and distributions are made late in the year after current E&P has been exhausted.

Rev. Rul. 74-164 four allocation situations.

• Situation 1. Current E&P is positive and exceeds total distributions.
  • All distributions are dividends out of current E&P.
  • Accumulated E&P is unaffected by the distributions (it remains at its beginning-of-year balance).
  • Current E&P at year end equals beginning current E&P minus total distributions.
• Situation 2. Current E&P is positive and is less than total distributions.
  • Current E&P is allocated chronologically to distributions (first distribution gets current E&P first).
  • Alternatively, current E&P can be allocated pro rata among all distributions.
  • Once current E&P is exhausted, remaining distributions come from accumulated E&P.
  • If accumulated E&P is positive, those distributions are dividends.
  • If accumulated E&P is exhausted, remaining distributions are return of capital or capital gain.
• Situation 3. Current E&P is negative and accumulated E&P is positive.
  • Net the negative current E&P against the positive accumulated E&P.
  • If the net is positive, distributions are dividends to the extent of the net E&P.
  • If the net is negative, no dividends (all distributions are return of capital or capital gain).
  • The netting occurs as of year end.
• Situation 4. Current E&P is positive but accumulated E&P is negative (nimble dividend).
  • Current E&P is allocated to distributions chronologically or pro rata.
  • Distributions covered by current E&P are dividends.
  • Distributions exceeding current E&P are return of capital or capital gain.
  • The negative accumulated E&P does not reduce the dividend amount.
• Rev. Rul. 74-338 allocation ordering rule applies when both ordinary distributions and redemptions occur in the same year.
  • Rev. Rul. 74-338, 1974-2 C.B. 101 (confirming that ordinary distributions take precedence over redemptions for E&P allocation purposes. In a year with both ordinary distributions and redemptions, current E&P is first allocated to ordinary distributions. Any remaining current E&P is then allocated to redemption distributions. This ordering ensures that ordinary dividends are characterized before redemption gain treatment is considered).
  • This rule prevents a corporation from manipulating the allocation by timing a redemption to absorb current E&P that would otherwise support ordinary dividends.

Treas. Reg. § 1.316-2 allocation mechanics.

• The regulation confirms the chronology and ratable methods.
  • A corporation may allocate current E&P to distributions in the order made (chronological).
  • Or a corporation may allocate current E&P pro rata to all distributions during the year.
  • The method chosen must be applied consistently.
• Interim distributions before year-end E&P is known.
  • If distributions are made before year end and current E&P is not yet determined, practitioners should project E&P or apply the ratable method.
  • If year-end E&P differs materially from projections, the characterization may change.
  • CAUTION. Shareholders who receive distributions characterized as dividends based on interim projections may face amended returns if year-end E&P is insufficient. Consider having shareholders report conservatively or delay distributions until E&P is finalized.

Step 12. Redemptions and E&P

§ 312(n)(7) governs the effect of redemptions on E&P. Unlike ordinary dividends, a redemption distribution that qualifies for sale or exchange treatment under § 302(a) does not necessarily reduce E&P by the full distribution amount. Instead, E&P is reduced by a ratable share. This ratable-share rule prevents corporations from structuring redemptions to disproportionately deplete E&P while giving shareholders capital gain treatment.

§ 312(n)(7) ratable share reduction rule.

• § 312(n)(7) provides that in the case of a redemption of stock, E&P is reduced by an amount not exceeding the ratable share of E&P attributable to the redeemed stock.
  • The ratable share is determined by the ratio of the redeemed shares to total shares outstanding before the redemption.
  • If a corporation redeems 10% of its outstanding shares, E&P is reduced by 10% of current E&P (and a proportionate amount of accumulated E&P).
• The ratable share is computed as follows.
  • Determine total E&P (current plus accumulated) as of the redemption date.
  • Multiply total E&P by the percentage of shares redeemed.
  • The result is the maximum E&P reduction.
  • E&P cannot be reduced below zero by the redemption.
• Ratable share computation example.
  • EXAMPLE. Corporation X has $1,000,000 of current E&P and $2,000,000 of accumulated E&P. It redeems 20% of its outstanding shares for $1,500,000. The ratable share of E&P attributable to the redeemed stock is 20% of $3,000,000, or $600,000. E&P is reduced by $600,000. The shareholder has capital gain of $900,000 ($1,500,000 distribution minus $600,000 allocated to the shares under § 301(c)(3) basis treatment, assuming sufficient stock basis).
  • The ratable share cap prevents the redemption from depleting more than the proportionate E&P share attributable to the redeemed equity interest.
• TRAP. If the redemption price exceeds the ratable share of E&P, the excess does not reduce E&P.
  • The premium paid over the ratable E&P share is treated as paid from the shareholder's own capital or basis.
  • This is a deliberate rule to prevent E&P depletion through overpriced redemptions.

Interaction between § 302 redemption characterization and E&P.

• If a redemption qualifies as a sale under § 302(a), the shareholder has capital gain or loss.
  • The amount of the distribution that exceeds the shareholder's stock basis is capital gain.
  • The shareholder does not have dividend income (unless the redemption is treated as a dividend under § 302(d) for failure to qualify under § 302(b)).
• If a redemption fails to qualify under § 302(a) and is treated as a distribution under § 301 by operation of § 302(d).
  • The full distribution amount is characterized under the three-tier system of § 301(c).
  • E&P is reduced by the full distribution amount (subject to the § 312(n)(7) limitation if the distribution is in redemption of stock).
  • TRAP. § 312(n)(7) applies to all redemptions, even those that fail § 302(a) and fall into § 301. The ratable share cap still limits the E&P reduction.

Effect on accumulated E&P.

• The E&P reduction from a redemption comes first from current E&P, then from accumulated E&P.
  • The ordering follows the general rules of § 316(a).
  • Current E&P is reduced by the ratable share first.
  • If the ratable share exceeds current E&P, accumulated E&P is reduced by the remainder.
• Redemptions can leave a corporation with a negative E&P balance.
  • If the ratable share of accumulated E&P exceeds the remaining balance after netting current E&P, the excess does not create a negative E&P.
  • § 312(n)(7) caps the reduction at the available E&P.
  • However, if the corporation has a current E&P deficit, the ratable share of that deficit still offsets accumulated E&P.

Preferred stock redemptions and § 302(b)(4).

• Redemptions of preferred stock under § 302(b)(4) are treated as redemptions not essentially equivalent to a dividend if they meet certain requirements.
  • The § 312(n)(7) ratable share rule applies.
  • Because preferred stock typically does not participate in E&P growth like common stock, the ratable share may be difficult to compute.
  • The regulation provides that the ratable share for non-participating preferred is based on the liquidation preference relative to total equity value.

Step 13. Consolidated E&P Under § 1.1502-33

Treas. Reg. § 1.1502-33 governs the computation and allocation of E&P for members of an affiliated group filing a consolidated return. The regulation departs from the separate-entity approach and instead tiers E&P up from subsidiaries to the common parent. This tiering system creates unique challenges, particularly with respect to deficits, SRLY limitations, deconsolidation events, and tax-sharing payments among group members.

The tiering-up mechanism.

• Treas. Reg. § 1.1502-33(a) provides the general rule that a member's E&P is determined under § 312.
  • Each member computes its separate E&P as if it filed a separate return, subject to the adjustments in the regulation.
  • The separate E&P is then "tiered up" to the common parent through a series of adjustments.
• Treas. Reg. § 1.1502-33(b) requires positive E&P of a subsidiary to be included in the parent's E&P immediately.
  • When a subsidiary has positive current E&P, that amount is added to the parent's E&P in the same taxable year.
  • This tiering-up occurs regardless of whether the subsidiary actually distributes the E&P to the parent.
  • The effect is that the parent's E&P reflects the consolidated group's combined economic performance.
• Treas. Reg. § 1.1502-33(c) requires deficits to tier up immediately as well.
  • When a subsidiary has a current E&P deficit, that deficit reduces the parent's E&P immediately.
  • This is the "immediate deficit tier-up" rule.
  • Unlike the hovering deficit rule of § 381(c)(2)(B) for acquired corporations, consolidated group deficits tier up without limitation.
  • CAUTION. A loss subsidiary can drag down the parent's E&P even if the parent is profitable. This can unexpectedly eliminate the parent's ability to pay dividends.

Distribution rules for consolidated group members.

• Treas. Reg. § 1.1502-33(d) provides the general rule that distributions from a subsidiary to its parent reduce the subsidiary's E&P and are reflected in the parent's E&P.
  • A distribution from a subsidiary to its parent reduces the subsidiary's E&P under the normal § 312(a) rules.
  • The parent does not recognize income on the intercompany distribution under § 1502 because the group files a consolidated return.
  • However, the parent's E&P already includes the subsidiary's E&P due to the tiering-up rules, so the distribution is a non-event for consolidated E&P purposes.
• Treas. Reg. § 1.1502-33(e) provides the affiliated E&P/non-SRLY distribution rule.
  • A subsidiary that joins an affiliated group may have pre-affiliation E&P (positive or negative).
  • Pre-affiliation deficits are subject to the SRLY limitation of § 1.1502-21(c).
  • However, pre-affiliation positive E&P can be distributed to the parent without SRLY limitation.
  • TRAP. The SRLY rules limit NOL utilization but do not limit E&P distribution. A subsidiary with pre-affiliation E&P can distribute it immediately after joining the group.

Tax sharing allocations.

• Treas. Reg. § 1.1502-33(d)(2) addresses tax sharing payments among group members.
  • If group members make tax sharing payments to each other, those payments affect E&P.
  • A payment from a subsidiary to the parent in respect of the group's consolidated tax liability reduces the subsidiary's E&P.
  • The parent includes the payment in its E&P (but it is offset by the corresponding tax liability, so the net effect depends on timing).
• Tax sharing payments are treated differently depending on their characterization.
  • If characterized as a distribution, the payment reduces subsidiary E&P and may be taxable as a dividend if E&P is available.
  • If characterized as reimbursement for tax liability, the payment is a nondeductible transfer that reduces the subsidiary's E&P.
  • CAUTION. The characterization of tax sharing payments is often disputed. Practitioners should document the intent and structure of tax sharing agreements carefully.

Deconsolidation effects.

• Treas. Reg. § 1.1502-33(f) provides rules for when a member leaves the group (deconsolidation).
  • When a subsidiary is sold or otherwise ceases to be a group member, its E&P at the deconsolidation date carries with it.
  • The subsidiary takes its accumulated E&P with it, and the parent's E&P is reduced by the subsidiary's tiered-up E&P through the deconsolidation date.
• Deconsolidation can create E&P surprises.
  • If a subsidiary with significant positive E&P is sold, the parent's E&P loses the tiered-up benefit.
  • If the parent has been relying on the subsidiary's tiered-up E&P to pay dividends, a stock sale of the subsidiary could leave the parent with insufficient E&P.
  • EXAMPLE. Parent P has $500,000 of its own E&P. Subsidiary S has $2,000,000 of E&P that has tiered up to P. P sells all of S's stock to Buyer. Immediately after the sale, P's E&P drops to $500,000 (its own E&P). Any distributions P made while S was a member that were characterized as dividends remain dividends. But going forward, P has only $500,000 of E&P.

Consolidated E&P practical considerations.

• Every consolidated group should maintain a consolidated E&P schedule.
  • The schedule starts with each member's separate E&P computed under § 312.
  • It then applies the tiering-up adjustments of § 1.1502-33.
  • Intercompany transactions are eliminated to the extent they do not affect separate E&P.
• The regulation requires tracking E&P on a member-by-member basis.
  • Even though E&P tiers up, the source member's identity matters for deconsolidation and SRLY purposes.
  • A deficit in one member offsets positive E&P from another member in the current year.
  • But historical deficits remain traceable to the member that generated them.

Step 14. International E&P Considerations

International E&P computation involves cross-border complexities that domestic practitioners must navigate carefully. Eaton Corp. v. Commissioner, 152 T.C. No. 2 (2019) established that § 312 applies to foreign corporations through § 964(a). § 964(a) and § 312 together govern the computation of E&P for controlled foreign corporations. The § 312(k) foreign corporation exception for tangible personal property, § 986 currency translation rules, and Subpart F interactions create a multi-layered analysis.

§ 964(a) and the applicability of § 312 to foreign corporations.

• Eaton Corp. v. Commissioner, 152 T.C. No. 2 (2019) (holding that § 312 applies to the computation of a controlled foreign corporation's E&P under § 964(a). The Tax Court rejected the argument that foreign corporations compute E&P under some separate standard. Instead, the court held that § 964(a) expressly requires E&P to be determined "in substantially the same manner" as domestic corporation E&P under § 312. All adjustments in § 312, including § 312(k) depreciation and § 312(n) economic adjustments, apply to CFC E&P).
  • This case resolved significant uncertainty about whether CFCs could use foreign depreciation methods for E&P purposes.
  • The Tax Court's answer was no. Domestic § 312 rules govern CFC E&P computation.
• § 964(a) provides that a CFC's E&P is determined "in substantially the same manner" as a domestic corporation's E&P under § 312.
  • The phrase "substantially the same manner" allows for minor accommodations for foreign law and accounting practices.
  • But the core § 312 adjustments, including depreciation under § 312(k) and the economic adjustments under § 312(n), apply in full.
• § 964(b) grants regulatory authority to the Secretary to prescribe adjustments for foreign corporations.
  • Treas. Reg. § 1.964-1 provides detailed rules for CFC E&P computation.
  • The regulation confirms the § 312 framework with specific accommodations for foreign accounting methods.

Foreign corporation depreciation exception under § 312(k)(3)(B).

• § 312(k)(3)(B) allows a foreign corporation to use GDS recovery periods for tangible personal property used predominantly outside the United States.
  • This exception recognizes that foreign corporations operating abroad may have assets that depreciate under different economic patterns.
  • The exception applies only to tangible personal property, not real property.
  • "Predominantly outside the United States" generally means more than 50% of use is in foreign jurisdictions.
• The exception applies only to foreign corporations, not domestic corporations with foreign assets.
  • A domestic corporation must use ADS recovery periods for all tangible property regardless of where it is used.
  • A foreign subsidiary of a domestic parent may use GDS for its foreign tangible personal property.
  • TRAP. A domestic corporation with a foreign branch cannot use the § 312(k)(3)(B) exception. The exception requires a foreign corporation.

§ 986 currency translation for foreign E&P.

• § 986(a) requires that a CFC's E&P be computed in its functional currency and then translated into U.S. dollars.
  • The functional currency is generally the currency of the economic environment in which the CFC primarily operates.
  • E&P is computed in functional currency using the § 312 framework.
• The exchange rate for translating E&P depends on the use of the E&P.
  • For distributions of current E&P, the average exchange rate for the taxable year is used under § 986(a)(1)(A).
  • For distributions of accumulated E&P, the spot rate on the distribution date is used under § 986(a)(1)(B).
  • For Subpart F inclusions, the average exchange rate for the CFC's taxable year is used.
• Currency fluctuations can create phantom E&P or E&P deficits.
  • If a CFC's functional currency depreciates against the dollar, its dollar-denominated E&P may decline even if local-currency earnings are stable.
  • If the functional currency appreciates, dollar-denominated E&P may increase without any change in local operations.
  • CAUTION. Currency translation effects on E&P are not recognized as gain or loss for tax purposes. They are mechanical conversion adjustments.
• § 986(c) provides foreign currency gain or loss on distributions of previously taxed E&P.
  • When a CFC distributes PTEP, the U.S. shareholder may recognize foreign currency gain or loss based on exchange rate movements between the inclusion year and the distribution year.
  • This gain or loss is ordinary income under § 986(c) and does not affect the CFC's E&P (it is a shareholder-level item).

Subpart F and E&P interaction.

• Subpart F inclusions under § 951(a) do not reduce CFC E&P.
  • A Subpart F inclusion is a deemed dividend to the U.S. shareholder.
  • The CFC's E&P is not reduced by the deemed inclusion. The E&P remains available for actual distributions.
  • This creates the possibility of double taxation unless § 959 applies.
• § 959 provides the PTEP ordering rule to prevent double taxation.
  • When a CFC makes an actual distribution, § 959(a) excludes from the shareholder's gross income any amount that was previously included in income under § 951(a) (Subpart F) or § 951A (GILTI).
  • The distribution is treated as coming first from PTEP (previously taxed E&P) and then from non-PTEP.
  • See Step 15 for detailed PTEP mechanics.

Step 15. TCJA-Era International Provisions and E&P

The Tax Cuts and Jobs Act of 2017 fundamentally restructured the international tax system and created new categories of E&P. § 965 imposed a one-time transition tax on deferred foreign E&P. § 245A created a 100% DRD for foreign-source dividends received by domestic corporations. § 951A created GILTI, which generates PTEP. § 959 was amended to coordinate the ordering of different PTEP categories. Practitioners must track these new E&P categories separately.

§ 965 transition tax and E&P effects.

• § 965(a) required U.S. shareholders of specified foreign corporations to include their pro rata share of deferred foreign E&P in income.
  • The inclusion amount was the greater of the shareholder's share of accumulated post-1986 deferred foreign E&P measured at November 2, 2017 or December 31, 2017.
  • The § 965 inclusion was reduced by the § 965(c) deduction to produce effective tax rates of approximately 15.5% (for cash positions) and 8% (for non-cash positions).
• § 965(b)(4)(A) provided that the E&P inclusion amount increased E&P of the foreign corporation for purposes of applying § 312 and § 964.
  • This was a fiction designed to prevent the § 965 inclusion from creating a mismatch. The deemed inclusion was treated as if the CFC had distributed E&P to the U.S. shareholder and then the shareholder had contributed it back.
  • The CFC's E&P was reduced by the § 965(a) inclusion amount (but not the § 965(c) deduction amount).
  • The net effect was that the CFC's E&P was reduced by the gross § 965 inclusion, creating PTEP in the relevant § 959(c) pools.
• The § 965 E&P reduction created a new PTEP category.
  • § 959 was amended to add § 959(c)(2) for PTEP attributable to § 965 inclusions.
  • This PTEP category is tracked separately from Subpart F PTEP (§ 959(c)(1)) and GILTI PTEP (also § 959(c)(2) but distinguishable by year and character).

§ 245A 100% DRD and E&P.

• § 245A(a) allows a 100% DRD to a domestic corporation for the foreign-source portion of dividends received from specified 10%-owned foreign corporations.
  • The foreign-source portion is the portion of the dividend attributable to the foreign corporation's non-U.S. business.
  • The deduction is allowed only if the domestic corporation is a U.S. shareholder and meets the holding period requirements of § 246(c)(5).
• § 245A(b)(1) requires a corresponding reduction in E&P.
  • When a domestic corporation claims a § 245A deduction, the distributing foreign corporation's E&P is reduced by the amount of the dividend for which the deduction is allowed.
  • This E&P reduction occurs even though the dividend is not taxable to the U.S. shareholder (due to the 100% DRD).
  • TRAP. The § 245A E&P reduction applies to the foreign corporation's E&P, not the domestic parent's. The foreign corporation's E&P pool is depleted by distributions that generate § 245A deductions.
• § 245A(e) hybrid dividend rule.
  • If a dividend is a "hybrid dividend" (deductible in the foreign jurisdiction but treated as a dividend in the U.S.), the § 245A deduction is denied.
  • Hybrid dividends reduce E&P under the normal § 312 rules but are taxable to the U.S. shareholder.
  • CAUTION. The hybrid dividend rules require careful analysis of foreign country tax treatment.

GILTI and PTEP under § 951A and § 959.

• § 951A(a) requires a U.S. shareholder of a CFC to include its global intangible low-taxed income (GILTI) in gross income annually.
  • GILTI is the excess of the shareholder's net CFC tested income over a 10% return on qualified business asset investment (QBAI).
  • The inclusion is treated similarly to a Subpart F inclusion for many purposes.
• § 951A(f)(1)(A) provides that GILTI inclusions are treated as Subpart F inclusions for § 959 purposes.
  • This means GILTI inclusions generate PTEP under § 959(c)(2).
  • The CFC's E&P is not reduced by the GILTI inclusion (just as it is not reduced by a Subpart F inclusion).
  • The PTEP can be distributed tax-free under § 959(a).
• § 250(a)(1)(B) allows a 50% deduction (37.5% after 2025) for GILTI inclusions.
  • The § 250 deduction reduces the effective U.S. tax rate on GILTI.
  • The § 250 deduction does not reduce the CFC's E&P. The GILTI inclusion amount is the gross amount before the § 250 deduction.
  • However, the § 250 deduction does reduce the U.S. shareholder's taxable income.
  • TRAP. For E&P purposes, the § 250 deduction is not added back (unlike the § 243 DRD). § 250 operates at the shareholder level, not the CFC level. The CFC's E&P tracks the gross GILTI amount.

PTEP ordering under § 959.

• § 959(c) establishes three categories of E&P for distribution ordering.
  • § 959(c)(1). PTEP attributable to § 965 inclusions (transition tax). Distributed first.
  • § 959(c)(2). PTEP attributable to Subpart F inclusions (including GILTI by virtue of § 951A(f)(1)). Distributed second.
  • § 959(c)(3). Non-PTEP (untaxed E&P). Distributed third.
• Distributions are sourced from PTEP categories before non-PTEP.
  • When a CFC makes a distribution, it is treated as coming first from § 959(c)(1) PTEP, then § 959(c)(2) PTEP, then § 959(c)(3) non-PTEP.
  • This ordering prevents double taxation by ensuring previously taxed amounts are distributed before untaxed amounts.
• Annual PTEP tracking is mandatory.
  • Each CFC must maintain a PTEP schedule that tracks additions and distributions by PTEP category and by taxable year.
  • The § 904 foreign tax credit limitation is computed separately for each PTEP basket.
  • CAUTION. Failure to track PTEP by year and category can result in double taxation or missed exclusion opportunities.

Step 16. Documentation, Reporting, and Practical Compliance

E&P computation is a self-assessment regime with no standalone information return. However, multiple forms and schedules require or implicate E&P data. Schedule M-1 and M-3 reconcile book income to taxable income and can serve as a starting point for E&P computation. Form 5452 is used to notify shareholders of an E&P determination. Form 5471 Schedule H reports CFC E&P to the IRS. Practitioners must maintain comprehensive workpapers to support E&P positions.

Schedule M-1 and M-3 as E&P starting points.

• Schedule M-1 (Form 1120) reconciles book income to taxable income.
  • Line 1 starts with net income per books.
  • Lines 2-7 add back federal income tax, excess of capital losses over gains, income subject to tax not recorded on books, and other adjustments.
  • Lines 8-10 subtract tax-exempt interest, excess of book depreciation over tax depreciation, and other deductions recorded on books not deducted on the return.
• Schedule M-1 can be adapted as a preliminary E&P reconciliation.
  • Start with taxable income (Line 11 of Schedule M-1, or Line 28 of M-3 Part I).
  • Add back tax-exempt interest (Line 7, but inverted).
  • Add back the DRD (not separately stated on M-1 but derivable from the return).
  • Add back fines, penalties, political contributions, and nondeductible entertainment.
  • Subtract federal income taxes paid (Line 2 of M-1).
  • Make the § 312(k) depreciation adjustment (Schedule M-1 Line 8 shows excess book depreciation over tax, but E&P requires excess tax depreciation over E&P depreciation).
• Schedule M-3 (Form 1120) provides more detailed book-tax differences.
  • Part I reconciles financial statement net income to taxable income.
  • Part II details income and loss items.
  • Part III details expense and deduction items.
  • The greater detail in M-3 makes it a better starting point for E&P computation than M-1.
• TRAP. Neither Schedule M-1 nor M-3 produces E&P directly.
  • Book income is not E&P. Taxable income is not E&P.
  • The reconciliation from either starting point requires the full range of § 312 adjustments.
  • Practitioners should not assume that "book income plus permanent differences" equals E&P. The timing differences under § 312(k) and § 312(n) must be independently computed.

Form 5452 for E&P determinations.

• Form 5452 (Corporate Report of Nondividend Distributions) is filed to notify the IRS and shareholders of an E&P determination.
  • The form reports the amount of distributions that exceed current and accumulated E&P.
  • It establishes that the excess distributions are return of capital to shareholders.
  • Filing Form 5452 starts the statute of limitations running on the E&P determination.
• Form 5452 is filed with the corporation's tax return.
  • It reports the total distributions, total E&P, and the nondividend portion.
  • The form is not required if all distributions are fully covered by E&P (i.e., no return of capital).
  • CAUTION. Failure to file Form 5452 when required does not invalidate a return-of-capital characterization. But it leaves the E&P determination open to challenge beyond the normal statute of limitations.

Form 5471 Schedule H for CFC E&P.

• Schedule H of Form 5471 reports a CFC's current E&P and its calculation.
  • The schedule starts with the CFC's taxable income (or book income if the CFC does not file a U.S. tax return).
  • It then makes adjustments similar to the § 312 adjustments to arrive at current E&P.
• Schedule H requires reporting of Subpart F income and GILTI-relevant amounts.
  • The schedule separately states current E&P, Subpart F income, and tested income for GILTI purposes.
  • It also reports total E&P, accumulated E&P, and PTEP balances.
• Schedule H is a critical compliance document for CFCs.
  • The IRS uses Schedule H data to verify Subpart F and GILTI inclusions.
  • Inconsistent E&P reporting between Schedule H and the U.S. shareholder's return can trigger examination.
  • CAUTION. Schedule H must be prepared using U.S. tax principles (§ 312, § 964), not local GAAP. A CFC's local-country accounting profit is not its E&P.

Dual depreciation schedule maintenance.

• Every corporation with significant depreciable assets should maintain dual depreciation schedules.
  • Schedule A tracks tax depreciation (MACRS GDS, bonus depreciation, § 179, applicable conventions).
  • Schedule B tracks E&P depreciation (straight-line ADS, § 179 over 5 years, no bonus depreciation, same conventions).
  • The annual difference between the two schedules is the § 312(k) adjustment.
• The dual schedule should track each asset separately.
  • For each asset, record the placed-in-service date, original basis, tax recovery period, E&P recovery period (ADS), tax depreciation method, § 179 amount, and bonus depreciation taken.
  • Annually compute the tax depreciation and E&P depreciation for each asset.
  • Sum the differences to produce the aggregate § 312(k) adjustment.
• Software solutions can automate dual depreciation tracking.
  • Most tax preparation software has an E&P depreciation module.
  • Excel-based schedules are also common for smaller corporations.
  • The key is consistency. Use the same placed-in-service dates, conventions, and basis for both schedules.

E&P workpaper documentation standards.

• Every E&P computation should be documented in a comprehensive workpaper.
  • The workpaper should begin with taxable income and list every adjustment with a citation to the applicable Code section or regulation.
  • Each adjustment should be supported by a source document (return schedule, financial statement, depreciation schedule, etc.).
  • The workpaper should separately compute current E&P and accumulated E&P.
• E&P computations should be reviewed and signed off by a senior practitioner.
  • E&P is a frequent examination issue because it affects dividend characterization.
  • A well-documented E&P computation can withstand IRS scrutiny and support the corporation's distribution policy.
  • Poor documentation can lead to recharacterization of return-of-capital distributions as taxable dividends.
• Key documentation items for an E&P file.
  • Copy of the corporate tax return (Form 1120) with all schedules.
  • Book-to-tax reconciliation (Schedule M-1 or M-3).
  • Dual depreciation schedules for all depreciable assets.
  • IDC and exploration expenditure amortization schedules.
  • LIFO reserve calculations (if LIFO is used).
  • Installment sale gain recognition schedules.
  • Subsidiary E&P tier-up schedules (for consolidated groups).
  • CFC E&P schedules with currency translation workpapers (for international groups).
  • Distribution history for the current and prior 3 years.
  • Shareholder basis schedules (for tracking return of capital).
• TRAP. E&P computations prepared years after the fact are inherently less reliable.
  • Practitioners should compute E&P contemporaneously with the tax return.
  • Retrospective E&P computations may lack source documents or rely on estimates.
  • If a client has never computed E&P, start from the earliest available records and build forward year by year.
  • Each year's E&P computation stands independently, so historical reconstruction may be necessary if records are incomplete.