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Summary of Significant Accounting Policies | 12 Months Ended
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Sep. 30, 2020
Accounting Policies [Abstract] |
Summary of Significant Accounting Policies | Note 2 — Summary of Significant Accounting Policies Basis of Presentation Our consolidated financial statements are prepared in accordance with GAAP. The preparation of financial statements in accordance with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, expenses and costs. These estimates are based on management’s knowledge of current events, historical experience and various other assumptions that are believed to be reasonable under the circumstances. Accordingly, actual results may be different from these estimates and assumptions. Certain prior-year amounts have been reclassified to conform to the current-year presentation. Principles of Consolidation The consolidated financial statements include the accounts of UGI and its controlled subsidiary companies which are majority owned. We report outside ownership interests in other consolidated but less than 100%-owned subsidiaries, as noncontrolling interests. Prior to the AmeriGas Merger, we also reported the public’s interest in the Partnership as a noncontrolling interest. We eliminate intercompany accounts and transactions when we consolidate. We account for privately held equity securities of entities without readily determinable fair values in which we do not have control, but have significant influence over operating and financial policies, under the equity method. Investments in equity securities related to entities in which we do not have significant influence over operating and financial policies are valued at their cost less impairment (if any). Our investments in such entities totaled $256 and $242 at September 30, 2020 and 2019, respectively, and are included in “Other assets” on the Consolidated Balance Sheets. Our equity method investments primarily comprise PennEast and Pennant. Equity Method Investments Pennant. During Fiscal 2019, Energy Services completed the CMG Acquisition including CMG’s approximately 47% interest in Pennant. Pennant is accounted for as an equity method investment as we have the ability to exercise significant influence, but not control, over Pennant. Our investment in Pennant at September 30, 2020 and 2019 totaled $94 and $91, respectively. For additional information regarding the CMG Acquisition, see Note 5. PennEast. UGI PennEast, LLC, and four other members comprising wholly owned subsidiaries of Southern Company, New Jersey Resources, South Jersey Industries, and Enbridge, Inc., each hold a 20% membership interest in PennEast. PennEast was formed to construct an approximate 120-mile natural gas pipeline from Luzerne County, Pennsylvania to the Trenton-Woodbury interconnection in New Jersey. Affiliates of all members plan to be customers of the pipeline under 15-year contracts. PennEast is accounted for as an equity method investment as we have the ability to exercise significant influence, but not control, over PennEast. We are obligated to provide capital contributions based upon our ownership percentage. Our investment in PennEast at September 30, 2020 and 2019 totaled $96 and $85, respectively. In September 2019, a panel of the U.S. Court of Appeals for the Third Circuit ruled that New Jersey’s Eleventh Amendment immunity barred PennEast from bringing an eminent domain lawsuit in federal court, under the Natural Gas Act, against New Jersey or its agencies. The Third Circuit subsequently denied PennEast’s petition for rehearing en banc. PennEast also filed a petition for declaratory order with the FERC regarding interpretation of the Natural Gas Act; the FERC issued an order favorable to PennEast’s position on January 30, 2020. PennEast filed a petition for a writ of certiorari to seek U.S. Supreme Court review of the Third Circuit decision on February 18, 2020. On June 29, 2020, the U.S. Supreme Court invited the U.S. Solicitor General to file a brief in the case expressing the views of the U.S. The ultimate outcome of these matters cannot be determined at this time, and could result in delays, additional costs, or the inability to move forward with the project, resulting in an impairment of all or a portion of our investment in PennEast. Effects of Regulation UGI Utilities accounts for the financial effects of regulation in accordance with the FASB’s guidance in ASC 980. In accordance with this guidance, incurred costs and estimated future expenditures that would otherwise be charged to expense are capitalized and recorded as regulatory assets when it is probable that the incurred costs or estimated future expenditures will be recovered through rates in the future. Similarly, we recognize regulatory liabilities when it is probable that regulators will require customer refunds through future rates or when revenue is collected from customers for expenditures that have not yet been incurred. Regulatory assets and liabilities are classified as current if, upon initial recognition, the entire amount related to that item will be recovered or refunded within a year of the balance sheet date. Generally, regulatory assets and regulatory liabilities are amortized into expense and income over the periods authorized by the regulator. For additional information regarding the effects of rate regulation on our utility operations, see Note 9. Fair Value Measurements The Company applies fair value measurements on a recurring and, as otherwise required under ASC 820, on a nonrecurring basis. Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability (an exit price) in an orderly transaction between market participants at the measurement date. Fair value measurements performed on a recurring basis principally relate to derivative instruments and investments held in supplemental executive retirement plan grantor trusts. ASC 820 establishes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value into three levels. The hierarchy gives the highest priority to quoted prices in active markets for identical assets or liabilities (Level 1 measurements) and the lowest priority to unobservable inputs (Level 3 measurements). A level within the fair value hierarchy is based on the lowest level of any input that is significant to the fair value measurement. We use the following fair value hierarchy, which prioritizes the inputs to valuation techniques used to measure fair value into three broad levels: •Level 1 — Quoted prices (unadjusted) in active markets for identical assets and liabilities that we have the ability to access at the measurement date. •Level 2 — Inputs other than quoted prices included within Level 1 that are either directly or indirectly observable for the asset or liability, including quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, inputs other than quoted prices that are observable for the asset or liability, and inputs that are derived from observable market data by correlation or other means. •Level 3 — Unobservable inputs for the asset or liability including situations where there is little, if any, market activity for the asset or liability. Fair value is based upon assumptions that market participants would use when pricing an asset or liability, including assumptions about risk and risks inherent in valuation techniques and inputs to valuations. This includes not only the credit standing of counterparties and credit enhancements but also the impact of our own nonperformance risk on our liabilities. We evaluate the need for credit adjustments to our derivative instrument fair values. These credit adjustments were not material to the fair values of our derivative instruments. Derivative Instruments Derivative instruments are reported on the Consolidated Balance Sheets at their fair values, unless the NPNS exception is elected. The accounting for changes in fair value depends upon the purpose of the derivative instrument, whether it is subject to regulatory ratemaking mechanisms or if it qualifies and is designated as a hedge for accounting purposes. Certain of our derivative instruments qualify and are designated as cash flow hedges. For cash flow hedges, changes in the fair values of the derivative instruments are recorded in AOCI, to the extent effective at offsetting changes in the hedged item, until earnings are affected by the hedged item. We discontinue cash flow hedge accounting if occurrence of the forecasted transaction is determined to be no longer probable. Hedge accounting is also discontinued for derivatives that cease to be highly effective. We do not designate our commodity and certain foreign currency derivative instruments as hedges under GAAP. Changes in the fair values of these derivative instruments are reflected in net income. Gains and losses on substantially all of the commodity derivative instruments used by UGI Utilities are included in regulatory assets or liabilities because it is probable such gains or losses will be recoverable from, or refundable to, customers. From time to time, we also enter into net investment hedges. Gains and losses on net investment hedges that relate to our foreign operations are included in the cumulative translation adjustment component in AOCI until such foreign net investment is sold or liquidated. Cash flows from derivative instruments, other than certain cross-currency swaps and net investment hedges, if any, are included in cash flows from operating activities on the Consolidated Statements of Cash Flows. Cash flows from the interest portion of our cross-currency hedges, if any, are included in cash flows from operating activities while cash flows from the currency portion of such hedges, if any, are included in cash flows from financing activities. Cash flows from net investment hedges, if any, are included in cash flows from investing activities on the Consolidated Statements of Cash Flows. For a more detailed description of the derivative instruments we use, our accounting for derivatives, our objectives for using them and other information, see Note 19. Business Combination Purchase Price Allocations From time to time, the Company enters into material business combinations. The purchase price is allocated to the various assets acquired and liabilities assumed at their estimated fair value as of the acquisition date with the residual of the purchase price allocated to goodwill. Fair values of assets acquired and liabilities assumed are based upon available information. Estimating fair values is generally subject to significant judgment, estimates and assumptions especially with respect to intangible assets. The allocation of the purchase price may be modified up to one year after the acquisition date, under certain circumstances, as more information is obtained about the fair value of assets acquired and liabilities assumed. Foreign Currency Translation Balance sheets of international subsidiaries are translated into U.S. dollars using the exchange rate at the balance sheet date. Income statements and equity investee results are translated into U.S. dollars using an average exchange rate for each reporting period. Where the local currency is the functional currency, translation adjustments are recorded in other comprehensive income. Transactions denominated in currencies other than the functional currency are recorded based on exchange rates at the time such transactions arise with the impact of subsequent changes in such rates reflected in the income statement. The functional currency of a significant portion of our international operations is the euro. Revenue Recognition In accordance with ASC 606, the Company recognizes revenue when control of promised goods or services is transferred to customers in an amount that reflects the consideration to which we expect to be entitled in exchange for those goods or services. Certain revenues such as revenue from leases, financial instruments and other revenues are not within the scope of ASC 606 because they are not from contracts with customers. Such revenues are accounted for in accordance with other GAAP. Revenue-related taxes collected on behalf of customers and remitted to taxing authorities, principally sales and use taxes, are not included in revenues. Gross receipts taxes at Midstream & Marketing and Electric Utility are presented on a gross basis. The Company has elected to use the practical expedient to expense the costs to obtain contracts when incurred for contracts that have a term less than one year. The costs incurred to obtain contracts that have durations of longer than one year are not material. See Note 4 for additional disclosures regarding the Company’s revenue from contracts with customers. Accounts Receivable Accounts receivable are reported on the Consolidated Balance Sheets at the gross outstanding amount adjusted for an allowance for doubtful accounts. Accounts receivable that are acquired are initially recorded at fair value on the date of acquisition. Provisions for uncollectible accounts are established based upon our collection experience and the assessment of the collectability of specific amounts. Accounts receivable are written off in the period in which the receivable is deemed uncollectible. LPG Delivery Expenses Expenses associated with the delivery of LPG to customers of the Partnership and our UGI International operations (including vehicle expenses, expenses of delivery personnel, vehicle repair and maintenance and general liability expenses) are classified as “Operating and administrative expenses” on the Consolidated Statements of Income. Depreciation expense associated with the Partnership and UGI International delivery vehicles is classified in “Depreciation and amortization” on the Consolidated Statements of Income. Income Taxes AmeriGas Partners and AmeriGas OLP are not directly subject to federal income taxes. Instead, their taxable income or loss is allocated to the individual partners which, prior to the AmeriGas Merger, included public holders of AmeriGas Partners Common Units. We record income taxes on (1) our share of the Partnership’s current taxable income or loss and (2) the differences between the book and tax basis of our investment in the Partnership. AmeriGas OLP has subsidiaries which operate in corporate form and are directly subject to federal and state income taxes. Legislation in certain states allows for taxation of partnership income and the accompanying financial statements reflect state income taxes resulting from such legislation. For additional information regarding the tax effects of the AmeriGas Merger, see Note 7. UGI Utilities records deferred income taxes in the Consolidated Statements of Income resulting from the use of accelerated tax depreciation methods based upon amounts recognized for ratemaking purposes. UGI Utilities also records a deferred income tax liability for tax benefits, principally the result of accelerated tax depreciation for state income tax purposes, that are flowed through to ratepayers when temporary differences originate and records a regulatory income tax asset for the probable increase in future revenues that will result when the temporary differences reverse. We record interest on underpayments and overpayments of income taxes, and income tax penalties, in “Income tax expense” on the Consolidated Statements of Income. Interest income or expense recognized in “Income tax expense” on the Consolidated Statements of Income was not material for all periods presented. The TCJA was enacted on December 22, 2017, and included a broad range of tax reform provisions affecting the Company, including, among other things, changes in the U.S. corporate income tax rate. The TCJA reduced the corporate income tax rate from 35% to 21% for tax years beginning after December 31, 2017. We were subject to a 24.5% blended U.S. federal income tax rate for Fiscal 2018 because our fiscal year contained the effective date of the rate change from 35% to 21%. In accordance with GAAP, at the date of enactment of the TCJA our federal deferred income taxes, including deferred income taxes related to items included in AOCI, were remeasured based upon the new corporate income tax rate. For our non-utility businesses, existing deferred income tax assets or liabilities were adjusted for the reduction in the corporate income tax rate and the adjustment recorded in the provision for income taxes. Our utility businesses were also required to adjust deferred income tax assets and liabilities for the change in income tax rates. However, because it was probable that the effect of the change in income tax rates on deferred income tax balances would be recovered or refunded in future rates, our rate-regulated utility businesses recorded a regulatory asset or liability associated with these deferred income tax assets and liabilities. For additional information regarding the impact of the TCJA and associated regulatory effects, see Notes 7 and 9. Earnings Per Common Share Basic earnings per share attributable to UGI Corporation stockholders reflect the weighted-average number of common shares outstanding. Diluted earnings per share attributable to UGI Corporation include the effects of dilutive stock options and common stock awards. Shares used in computing basic and diluted earnings per share are as follows:
(Thousands of shares) |  | 2020 |  | 2019 |  | 2018
Weighted-average common shares outstanding for basic computation (a) |  | 208,928 |  |  | 178,417 |  |  | 173,908 |
Incremental shares issuable for stock options and common stock awards (b) |  | 941 |  |  | 2,694 |  |  | 2,997 |
Weighted-average common shares outstanding for diluted computation |  | 209,869 |  |  | 181,111 |  |  | 176,905 |
(a)Fiscal 2019 includes the partial-year impact from the August 2019 issuance of 34,613 shares of UGI Common Stock in connection with the AmeriGas Merger (see Note 5). (b)For Fiscal 2020 and Fiscal 2019, there were 7,056 shares and 1,162 shares, respectively, associated with outstanding stock option awards that were not included in the computation of diluted earnings per share because their effect was antidilutive. Cash, Cash Equivalents and Restricted Cash Cash and cash equivalents include cash on hand, cash in banks and highly liquid investments with maturities of three months or less when purchased. Restricted cash principally represents those cash balances in our commodity futures brokerage accounts that are restricted from withdrawal. The following table provides a reconciliation of the total cash, cash equivalents and restricted cash reported on the Consolidated Balance Sheets to the corresponding amounts reported on the Consolidated Statements of Cash Flows.
|  | 2020 |  | 2019 |  | 2018 |  | 2017
Cash and cash equivalents |  | $ | 336 |  |  | $ | 447 |  |  | $ | 452 |  |  | $ | 558 |
Restricted cash |  | 21 |  |  | 64 |  |  | 10 |  |  | 11 |
Cash, cash equivalents and restricted cash |  | $ | 357 |  |  | $ | 511 |  |  | $ | 462 |  |  | $ | 569 |
Inventories Our inventories are stated at the lower of cost or net realizable value. We determine cost using an average cost method for non-utility LPG and natural gas and Gas Utility and Electric Utility inventories; specific identification for appliances; and the FIFO method for all other inventories. Property, Plant and Equipment and Related Depreciation We record property, plant and equipment at the lower of original cost or fair value, if impaired. Capitalized costs include labor, materials and other direct and indirect costs, and for certain operations subject to cost-of-service rate regulation, AFUDC. We also include in property, plant and equipment costs associated with computer software we develop or obtain for use in our business. The amounts assigned to property, plant and equipment of acquired businesses are based upon estimated fair value at date of acquisition. When we retire or otherwise dispose of non-utility plant and equipment, we eliminate the associated cost and accumulated depreciation and recognize any resulting gain or loss in "Other operating income, net" on the Consolidated Statements of Income. We record depreciation expense on non-utility plant and equipment on a straight-line basis over estimated economic useful lives. At September 30, 2020, estimated useful lives by asset type were as follows:
Asset Type |  | Minimum Estimated Useful Life (in years) |  | Maximum Estimated Useful Life (in years)
Buildings and improvements |  | 10 |  | 40
Equipment, primarily cylinders and tanks |  | 5 |  | 30
Electricity generation facilities |  | 25 |  | 40
Pipeline and related assets |  | 25 |  | 40
Transportation equipment and office furniture and fixtures |  | 3 |  | 10
Computer software |  | 1 |  | 10
We record depreciation expense for UGI Utilities’ plant and equipment on a straight-line basis based upon the projected service lives of the various classes of its depreciable property. The average composite depreciation rates at our Gas Utility and Electric Utility were as follows:
| 2020 |  | 2019 |  | 2018
Gas Utility | 2.5 | % |  | 2.2 | % |  | 2.3 | %
Electric Utility | 2.2 | % |  | 2.1 | % |  | 2.2 | %
UGI Utilities’ IT costs associated with major IT system installations, conversions and improvements, such as software training, data conversion, business process reengineering costs, preliminary project stage costs and cloud computing, are deferred as a regulatory asset and included as a component of property, plant and equipment. As of September 30, 2020 and 2019, such costs included as a component of property, plant and equipment and not yet requested in a rate proceeding were not material. UGI Utilities amortizes computer software and related IT system installation costs on a straight-line basis over expected periods of benefit not exceeding 15 years once the installed software is ready for its intended use. We classify amortization of computer software and related IT system installation costs included in property, plant and equipment as depreciation expense. Depreciation expense totaled $416, $389 and $397 for Fiscal 2020, Fiscal 2019 and Fiscal 2018, respectively. For property subject to cost of service rate regulation including substantially all of UGI Utilities depreciable utility plant and equipment, upon retirement we charge the original cost to accumulated depreciation for financial accounting purposes. Costs incurred to retire utility plant and equipment, net of salvage, are recorded in regulatory assets and amortized over five years, consistent with prior ratemaking treatment. No depreciation expense is included in cost of sales on the Consolidated Statements of Income. Goodwill and Intangible Assets Intangible Assets. We amortize intangible assets over their estimated useful lives unless we determine their lives to be indefinite. Estimated useful lives of definite-lived intangible assets, primarily consisting of customer relationships (other than customer relationships acquired in the CMG Acquisition), certain tradenames and noncompete agreements, generally do not exceed 15 years. The estimated useful lives of customer relationships acquired in the CMG Acquisition is 35 years (see Note 5). We test definite-lived intangible assets for impairment whenever events or changes in circumstances indicate that the associated carrying amounts may be impaired. Determining whether an impairment loss occurred requires comparing the carrying amount to the estimated fair value of the asset in accordance with ASC 820. Intangible assets with indefinite lives are not amortized but are tested for impairment annually (and more frequently if events or changes in circumstances between annual tests indicate that it is more likely than not that they are impaired) and written down to fair value, if impaired. In April 2018, the Partnership’s senior management approved a plan to discontinue the use of indefinite-lived tradenames and trademarks associated with the Partnership’s January 2012 acquisition of Heritage Propane over a period of approximately three years. As a result, the Partnership recorded a non-cash, pre-tax impairment charge of $75 during Fiscal 2018 which is reflected in “Impairment of Partnership tradenames and trademarks” on the 2018 Consolidated Statement of Income, and is amortizing the remaining fair value of these tradenames and trademarks of $8 over their estimated period of benefit of three years. Goodwill. We do not amortize goodwill, but test it at least annually for impairment at the reporting unit level. A reporting unit is an operating segment, or one level below an operating segment (a component) if it constitutes a business for which discrete financial information is available and regularly reviewed by segment management. Components are aggregated into a single reporting unit if they have similar economic characteristics. Each of our reporting units with goodwill is required to perform impairment tests annually or whenever events or circumstances indicate that the value of goodwill may be impaired. For certain of our reporting units with goodwill, we assess qualitative factors to determine whether it is more likely than not that the fair value of such reporting unit is less than its carrying amount. For our other reporting units with goodwill, we bypass the qualitative assessment and perform the quantitative assessment by comparing the fair values of the reporting units with their carrying amounts, including goodwill. If the carrying amount of a reporting unit exceeds its fair value, an impairment loss is recognized in an amount equal to such excess but not to exceed the total amount of the goodwill of the reporting unit. There were no accumulated goodwill impairment losses at September 30, 2020 and 2019, and no provisions for goodwill impairments were recognized for all periods presented. For further information on our goodwill and intangible assets, see Note 12. Impairment of Long-Lived Assets Impairment testing for long-lived assets (or an asset group) is required when circumstances indicate that such assets may be impaired. If it is determined that a triggering event has occurred, we perform a recoverability test based upon estimated undiscounted cash flow projections expected to be realized over the remaining useful life of the long-lived asset. If the undiscounted cash flows used in the recoverability test are less than the long-lived asset's carrying amount, we determine its fair value. If the fair value is determined to be less than its carrying amount, the long-lived asset is reduced to its estimated fair value and an impairment loss is recognized in an amount equal to such shortfall. When determining whether a long-lived asset has been impaired, management groups assets at the lowest level that has identifiable cash flows. No material provisions for impairments of long-lived assets were recorded during Fiscal 2019 or Fiscal 2018. See Note 5 for further information on the losses associated with the dispositions of Conemaugh and HVAC during Fiscal 2020. Debt Issuance Costs We defer and amortize debt issuance costs and debt premiums and discounts over the expected lives of the respective debt issues considering maturity dates. Deferred debt issuance costs associated with long-term debt are reflected as a direct deduction from the carrying amount of such debt. Deferred debt issuance costs associated with revolving credit facilities reflected as short-term borrowings are classified as “Other assets” on our Consolidated Balance Sheets. Amortization of debt issuance costs is reported as interest expense. Unamortized costs associated with redemptions of debt prior to their stated maturity are generally recognized and recorded in “Loss on extinguishments of debt” on the Consolidated Statements of Income. As permitted by regulatory authorities, gains or losses resulting from refinancings of UGI Utilities’ debt are deferred and amortized over the lives of the new issuances. Leases Effective October 1, 2019, the Company adopted ASU No. 2016-02, "Leases," which, as amended, is included in ASC 842. This new accounting guidance supersedes previous lease accounting guidance in ASC 840 and requires entities that lease assets to recognize the assets and liabilities for the rights and obligations created by those leases on its balance sheet. The new guidance also requires additional disclosures about the amount, timing and uncertainty of cash flows from leases. We adopted this new guidance using the modified retrospective transition method. Amounts and disclosures related to periods prior to October 1, 2019 have not been restated and continue to be reported in accordance with ASC 840. We elected to apply the following practical expedients in accordance with the guidance upon adoption: •Short-term leases: We did not recognize short-term leases (term of 12 months or less) on the balance sheet; •Easements: We did not re-evaluate existing land easements that were not previously accounted for as leases; and •Other: We did not reassess the classification of expired or existing contracts or determine whether they are or contain a lease. We also did not reassess whether initial direct costs qualify for capitalization under ASC 842. Upon adoption, we recorded ROU assets and lease liabilities of $452 related to our operating leases. Our accounting for finance leases remained substantially unchanged. There were no cumulative-effect adjustments made to retained earnings as of October 1, 2019. The adoption did not have a significant impact on our consolidated statements of income or cash flows. See Note 16 for additional disclosures regarding our leases. Refundable Tank and Cylinder Deposits Included in “Other noncurrent liabilities” on our Consolidated Balance Sheets are customer paid deposits on tanks and cylinders primarily owned by subsidiaries of UGI France of $300 and $280 at September 30, 2020 and 2019, respectively. Deposits are refundable to customers when the tanks or cylinders are returned in accordance with contract terms. Environmental Matters We are subject to environmental laws and regulations intended to mitigate or remove the effects of past operations and improve or maintain the quality of the environment. These laws and regulations require the removal or remedy of the effect on the environment of the disposal or release of certain specified hazardous substances at current or former operating sites. Environmental reserves are accrued when assessments indicate that it is probable that a liability has been incurred and an amount can be reasonably estimated. Amounts recorded as environmental liabilities on the Consolidated Balance Sheets represent our best estimate of costs expected to be incurred or, if no best estimate can be made, the minimum liability associated with a range of expected environmental investigation and remediation costs. These estimates are based upon a number of factors including whether the Company will be responsible for such remediation, the scope and cost of the remediation work to be performed, the portion of costs that will be shared with other potentially responsible parties, the timing of the remediation and possible impact of changes in technology, and the regulations and requirements of local governmental authorities. Our estimated liability for environmental contamination is reduced to reflect anticipated participation of other responsible parties but is not reduced for possible recovery from insurance carriers. Under GAAP, if the amount and timing of cash payments associated with environmental investigation and cleanup are reliably determinable, such liabilities are discounted to reflect the time value of money. We intend to pursue recovery of incurred costs through all appropriate means, including regulatory relief. UGI Utilities receives ratemaking recognition of environmental investigation and remediation costs associated with in-state environmental sites. This ratemaking recognition balances the accumulated difference between historical costs and rate recoveries with an estimate of future costs associated with the sites. For further information, see Note 17. Loss Contingencies Subject to Insurance We are subject to risk of loss for general, automobile and product liability, and workers’ compensation claims for which we obtain insurance coverage under insurance policies that are subject to self-insured retentions or deductibles. In accordance with GAAP, we record accruals when it is probable that a liability exists and the amount or range of amounts can be reasonably estimated. When no amount within a range of possible loss is a better estimate than any other amount within the range, liabilities recorded are based upon the low end of the range. For litigation and pending claims including those covered by insurance policies, the analysis of probable loss is performed on a case by case basis and includes an evaluation of the nature of the claim, the procedural status of the matter, the probability or likelihood of success in prosecuting or defending the claim, the information available with respect to the claim, the opinions and views of outside counsel and other advisors, and past experience in similar matters. With respect to unasserted claims arising from unreported incidents, we may use the work of specialists to estimate the ultimate losses to be incurred using actuarially determined loss development factors applied to actual claims data. Our estimated reserves for loss contingencies may differ materially from the ultimate liability and such reserves may change materially as more information becomes available and estimated reserves are adjusted. We maintain insurance coverage such that our net exposure for claims covered by insurance would be limited to the self-insured retentions or deductibles, claims above which would be paid by the insurance carrier. For such claims, we record a receivable related to the amount of the liability expected to be paid by insurance. Employee Retirement Plans We use a market-related value of plan assets and an expected long-term rate of return to determine the expected return on assets of our U.S. pension and other postretirement plans. The market-related value of plan assets, other than equity investments, is based upon fair values. The market-related value of equity investments is calculated by rolling forward the prior-year’s market-related value with contributions, disbursements and the expected return on plan assets. One third of the difference between the expected and the actual value is then added to or subtracted from the expected value to determine the new market-related value (see Note 8). Equity-Based Compensation All of our equity-based compensation, principally comprising UGI stock options, grants of UGI stock-based equity instruments and, prior to the AmeriGas Merger, grants of AmeriGas Partners equity instruments (together with UGI stock-based equity instruments, “Units” or “Unit Awards”), are measured at fair value on the grant date, date of modification or end of the period, as applicable. Compensation expense is recognized on a straight-line basis over the requisite service period. Depending upon the settlement terms of the awards, all or a portion of the fair value of equity-based awards may be presented as a liability or as equity on our Consolidated Balance Sheets. Equity-based compensation costs associated with the portion of Unit Awards classified as equity are measured based upon their estimated fair value on the date of grant or modification. Equity-based compensation costs associated with all or a portion of Unit Awards classified as liabilities are measured based upon their estimated fair value at the grant date and remeasured as of the end of each period. We record deferred tax assets for awards that we expect will result in deductions on our income tax returns based on the amount of compensation cost recognized and the statutory tax rate in the jurisdiction in which we will receive a deduction. Differences between the deferred tax assets recognized for financial reporting purposes and the actual tax benefit received on the income tax return are recorded on the Consolidated Statements of Income. Excess tax benefits and tax deficiencies associated with employee share-based awards that vest or are exercised are recognized as income tax benefit or expense in the reporting period in which they occur, and assumed proceeds under the treasury stock method used for computing diluted shares outstanding do not include windfall tax benefits in the diluted shares calculation. We account for forfeitures of share-based payments when they occur. For additional information on our equity-based compensation plans and related disclosures, see Note 14.

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