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Derivative Instruments and Hedging Activities | 12 Months Ended
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Sep. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract] |
Disclosures About Derivative Instruments and Hedging Activities | Derivative Instruments and Hedging Activities We are exposed to certain market risks related to our ongoing business operations. Management uses derivative financial and commodity instruments, among other things, to manage these risks. The primary risks managed by derivative instruments are (1) commodity price risk, (2) interest rate risk and (3) foreign currency exchange rate risk. Although we use derivative financial and commodity instruments to reduce market risk associated with forecasted transactions, we do not use derivative financial and commodity instruments for speculative or trading purposes. The use of derivative instruments is controlled by our risk management and credit policies which govern, among other things, the derivative instruments we can use, counterparty credit limits and contract authorization limits. For information on the accounting for our derivative instruments, see Note 2. Commodity Price Risk In order to manage market price risk associated with the Partnership’s fixed-price programs the Partnership uses over-the-counter derivative commodity instruments, principally price swap contracts. In addition, the Partnership, certain other domestic business units and our UGI International operations also use over-the-counter price swap and option contracts to reduce commodity price volatility associated with a portion of their forecasted LPG purchases. In addition, the Partnership from time to time enters into price swap and put option agreements to reduce the effects of short-term commodity price volatility. At September 30, 2014 and 2013, total volumes associated with LPG commodity derivative instruments totaled 344.5 million gallons and 279.0 million gallons, respectively. The maximum period over which we are economically hedging our exposure to LPG commodity price risk is 21 months. Gas Utility’s tariffs contain clauses that permit recovery of all of the prudently incurred costs of natural gas it sells to retail core-market customers, including the cost of financial instruments used to hedge purchased gas costs. As permitted and agreed to by the PUC pursuant to Gas Utility’s annual PGC filings, Gas Utility currently uses New York Mercantile Exchange (“NYMEX”) natural gas futures and option contracts to reduce commodity price volatility associated with a portion of the natural gas it purchases for its retail core-market customers. At September 30, 2014 and 2013, the volumes of natural gas associated with Gas Utility’s unsettled NYMEX natural gas futures and option contracts totaled 16.9 million dekatherms and 15.0 million dekatherms, respectively. At September 30, 2014, the maximum period over which Gas Utility is economically hedging natural gas market price risk is 12 months. Gains and losses on natural gas futures contracts and any gains on natural gas option contracts are recorded in regulatory assets or liabilities on the Consolidated Balance Sheets in accordance with GAAP related to rate-regulated entities and reflected in cost of sales through the PGC mechanism (see Note 9). Electric Utility’s DS tariffs permit the recovery of all prudently incurred costs of electricity it sells to DS customers, including the cost of financial instruments used to hedge electricity costs. Electric Utility enters into forward electricity purchase contracts to meet a substantial portion of its electricity supply needs. Because most of these contracts currently do not qualify for the NPNS exception under GAAP, the fair values of these contracts are reflected in current and noncurrent derivative instrument assets and liabilities in the accompanying Consolidated Balance Sheets. Associated gains and losses on these forward contracts are recorded in regulatory assets and liabilities on the Consolidated Balance Sheets in accordance with GAAP related to rate-regulated entities and reflected in cost of sales through the DS mechanism (see Note 9). At September 30, 2014 and 2013, the volumes of Electric Utility’s forward electricity purchase contracts were 237.0 million kilowatt hours and 245.8 million kilowatt hours, respectively. At September 30, 2014, the maximum period over which these contracts extend is 8 months. In order to reduce volatility associated with a substantial portion of its electricity transmission congestion costs, Electric Utility obtains FTRs through an annual allocation process. Midstream & Marketing purchases FTRs to economically hedge electricity transmission congestion costs associated with its fixed-price electricity sales contracts and from time to time also enters into New York Independent System Operator (“NYISO”) capacity swap contracts to economically hedge the locational basis differences for customers it serves on the NYISO electricity grid. Gains and losses on Electric Utility FTRs are recorded in regulatory assets or liabilities in accordance with GAAP related to rate-regulated entities and reflected in cost of sales through the DS recovery mechanism (see Note 9). At September 30, 2014 and 2013, the total volumes associated with FTRs and NYISO capacity contracts totaled 232.1 million kilowatt hours and 189.3 million kilowatt hours, respectively. At September 30, 2014, the maximum period over which we are economically hedging electricity congestion and locational basis differences is 8 months. In order to manage market price risk relating to fixed-price sales contracts for natural gas and electricity, Midstream & Marketing enters into NYMEX and over-the-counter natural gas futures contracts, IntercontinentalExchange (“ICE”) natural gas basis swap contracts, and electricity futures contracts. Midstream & Marketing also uses NYMEX and over the counter electricity futures contracts to hedge the price of a portion of its anticipated future sales of electricity from its electric generation facilities. In addition, Midstream & Marketing uses NYMEX futures contracts to economically hedge the gross margin associated with the purchase and anticipated later near-term sale of natural gas or propane. During the second quarter of Fiscal 2014, Energy Services determined that it could no longer assert the NPNS exception under GAAP for new contracts entered into for the forward purchase of natural gas and pipeline transportation. These contracts, as well as other Midstream & Marketing derivative instruments described above, are not accounted for as hedges under GAAP. These derivative instruments are recorded at fair value with changes in fair value reflected in income. At September 30, 2014 and 2013, total volumes associated with Midstream & Marketing’s natural gas futures, forward and pipeline contracts totaled 113.7 million dekatherms and 24.3 million dekatherms, respectively. At September 30, 2014, the maximum period over which we are hedging our exposure to the variability in cash flows associated with natural gas commodity price risk is 41 months. At September 30, 2014 and 2013, total volumes associated with Midstream & Marketing’s electricity call contracts and electricity put contracts totaled 394.4 million kilowatt hours and 206.6 million kilowatt hours, and 754.4 million kilowatt hours and 393.0 million kilowatt hours, respectively. At September 30, 2014, the maximum period over which we are hedging our exposure to the variability in cash flows associated with electricity commodity price risk (excluding Electric Utility) is 24 months for electricity call contracts and 12 months for electricity put contracts. At September 30, 2014, the volumes associated with Midstream & Marketing’s natural gas and propane storage NYMEX contracts totaled 3.9 million dekatherms and 1.3 million gallons, respectively. At September 30, 2013, the volumes associated with Midstream & Marketing’s natural gas and propane storage NYMEX contracts totaled 2.9 million dekatherms and 2.8 million gallons, respectively. In order to reduce operating expense volatility, UGI Utilities from time to time enters into NYMEX gasoline futures and swap contracts for a portion of gasoline volumes expected to be used in the operation of its vehicles and equipment. Associated volumes, fair values and effects on net income were not material for all periods presented. A portion of our commodity derivative instruments are designated and qualify as cash flow hedges. At September 30, 2014, the amount of net losses associated with commodity price risk hedges expected to be reclassified into earnings during the next twelve months based upon current fair values is $2.3. Interest Rate Risk Antargaz’ and Flaga’s long-term debt agreements have interest rates that are generally indexed to short-term market interest rates. Antargaz and Flaga have each entered into pay-fixed, receive-variable interest rate swap agreements to hedge the underlying euribor rate of interest on their variable-rate term loans through the respective scheduled maturity dates. As of September 30, 2014 and 2013, the total notional amounts of variable-rate debt subject to interest rate swap agreements (excluding Flaga’s cross-currency swap as described below) were €401.1 and €440.5, respectively. Our domestic businesses’ long-term debt is typically issued at fixed rates of interest. As these long-term debt issues mature, we typically refinance such debt with new debt having interest rates reflecting then-current market conditions. In order to reduce market rate risk on the underlying benchmark rate of interest associated with near- to medium-term forecasted issuances of fixed-rate debt, from time to time we enter into interest rate protection agreements (“IRPAs”). At September 30, 2014 and 2013, we had no unsettled IRPAs. During Fiscal 2012, UGI Utilities reclassified pre-tax losses of $0.7 from AOCI into income as a result of the discontinuance of cash flow hedge accounting for a portion of expected interest payments associated with the issuance of long-term debt originally anticipated to occur in September 2012. Such losses are included in other income, net, in the Fiscal 2012 Consolidated Statement of Income. We account for interest rate swaps and IRPAs as cash flow hedges. At September 30, 2014, the amount of net losses associated with interest rate hedges (excluding pay-fixed, receive-variable interest rate swaps) expected to be reclassified into earnings during the next twelve months is $2.7. Foreign Currency Exchange Rate Risk In order to reduce volatility, Antargaz hedges a portion of its anticipated U.S. dollar-denominated LPG product purchases through the use of forward foreign currency exchange contracts. The amount of U.S. dollar-denominated purchases of LPG associated with such contracts generally represents approximately 15% to 30% of estimated U.S. dollar-denominated purchases of LPG to occur during the heating-season months of October through March. At September 30, 2014 and 2013, we were hedging a total of $219.8 and $200.2 of U.S. dollar-denominated LPG purchases, respectively. At September 30, 2014, the maximum period over which we are hedging our exposure to the variability in cash flows associated with U.S. dollar-denominated purchases of LPG is 27 months. From time to time we also enter into forward foreign currency exchange contracts to reduce the volatility of the U.S. dollar value on a portion of our International Propane euro-denominated net investments. At September 30, 2014 and 2013, we had no euro-denominated net investment hedges. We account for foreign currency exchange contracts associated with anticipated purchases of U.S. dollar-denominated LPG as cash flow hedges. At September 30, 2014, the amount of net losses associated with currency rate risk (other than net investment hedges) expected to be reclassified into earnings during the next twelve months based upon current fair values is $4.6. Cross-Currency Swaps During Fiscal 2013, Flaga entered into a cross-currency swap to hedge its exposure to the variability in expected future cash flows associated with foreign currency and interest rate risk resulting from the issuance of $52.0 of U.S. dollar-denominated variable-rate debt. The cross-currency hedge includes initial and final exchanges of principal from a fixed euro denomination to a fixed U.S. dollar-denominated amount, to be exchanged at a specified rate, which was determined by the market spot rate on the date of issuance. The cross-currency swap also includes an interest rate swap of a fixed foreign-denominated interest rate to a fixed U.S. dollar-denominated interest rate. We have designated this cross-currency swap as a cash flow hedge. At September 30, 2014, the amount of net gains associated with this cross-currency swap expected to be reclassified into earnings over the next twelve months is not material. Derivative Instrument Credit Risk We are exposed to risk of loss in the event of nonperformance by our derivative instrument counterparties. Our derivative instrument counterparties principally comprise large energy companies and major U.S. and international financial institutions. We maintain credit policies with regard to our counterparties that we believe reduce overall credit risk. These policies include evaluating and monitoring our counterparties’ financial condition, including their credit ratings, and entering into agreements with counterparties that govern credit limits or entering into netting agreements that allow for offsetting counterparty receivable and payable balances for certain financial transactions, as deemed appropriate. Certain of these agreements call for the posting of collateral by the counterparty or by the Company in the form of letters of credit, parental guarantees or cash. Additionally, our natural gas and electricity exchange-traded futures contracts generally require cash deposits in margin accounts. At September 30, 2014 and 2013, restricted cash in brokerage accounts totaled $16.6 and $7.0, respectively. Although we have concentrations of credit risk associated with derivative instruments, the maximum amount of loss, based upon the gross fair values of the derivative instruments, we would incur if these counterparties failed to perform according to the terms of their contracts was not material at September 30, 2014. Certain of the Partnership’s derivative contracts have credit-risk-related contingent features that may require the posting of additional collateral in the event of a downgrade of the Partnership’s debt rating. At September 30, 2014, if the credit-risk-related contingent features were triggered, the amount of collateral required to be posted would not be material. Offsetting Derivative Assets and Liabilities Derivative assets and liabilities are presented net by counterparty on our Consolidated Balance Sheets if the right of offset exists. Our derivative instruments include both those that are executed on an exchange through brokers and centrally cleared and over-the-counter transactions. Exchange contracts utilize a financial intermediary, exchange, or clearinghouse to enter, execute, or clear the transactions. Over-the-counter contracts are bilateral contracts that are transacted directly with a third party. Certain over-the-counter and exchange contracts contain contractual rights of offset through master netting arrangements, derivative clearing agreements, and contract default provisions. In addition, the contracts are subject to conditional rights of offset through counterparty nonperformance, insolvency, or other conditions. In general, most of our over-the-counter transactions and all exchange contracts are subject to collateral requirements. Types of collateral generally include cash or letters of credit. Cash collateral paid by us to our derivative counterparties, if any, is reflected in the table below to offset derivative liabilities. Cash collateral received by us from our derivative counterparties, if any, is reflected in the table below to offset derivative assets. Certain other accounts receivable and accounts payable balances recognized on our Consolidated Balance Sheets with our derivative counterparties are not included in the table below but could reduce our net exposure to such counterparties because such balances are subject to master netting or similar arrangements. Fair Value of Derivative Instruments The following table presents our derivative assets and liabilities by type, as well as the effects of offsetting, as of September 30, 2014 and 2013:
| 2014 |  | 2013 (a)
Derivative assets: |  |  |
Derivatives designated as hedging instruments: |  |  |
Commodity contracts | $ | 2.8 |  |  | $ | 18.0 |
Foreign currency contracts | 12.8 |  |  | 0.9 |
Cross-currency contracts | 2.1 |  |  | — |
Interest rate contracts | 0.1 |  |  | — |
| 17.8 |  |  | 18.9 |
Derivatives accounted for under ASC 980: |  |  |
Commodity contracts | 1.7 |  |  | — |
Derivatives not designated as hedging instruments: |  |  |
Commodity contracts | 25.9 |  |  | 7.4 |
Total derivative assets - gross | 45.4 |  |  | 26.3 |
Gross amounts offset in the balance sheet | (18.4 | ) |  | (2.1 | )
Total derivative assets - net | $ | 27.0 |  |  | $ | 24.2 |
Derivative liabilities: |  |  |
Derivatives designated as hedging instruments: |  |  |
Commodity contracts | $ | (5.3 | ) |  | $ | (4.5 | )
Foreign currency contracts | (0.1 | ) |  | (7.2 | )
Cross-currency contracts | — |  |  | (1.2 | )
Interest rate contracts | (21.0 | ) |  | (31.0 | )
| (26.4 | ) |  | (43.9 | )
Derivatives accounted for under ASC 980: |  |  |
Commodity contracts | (2.2 | ) |  | (6.7 | )
Derivatives not designated as hedging instruments: |  |  |
Commodity contracts | (46.6 | ) |  | (6.9 | )
Total derivative liabilities - gross | (75.2 | ) |  | (57.5 | )
Gross amounts offset in the balance sheet | 18.4 |  |  | 2.1 |
Total derivative liabilities - net | $ | (56.8 | ) |  | $ | (55.4 | )
(a) | Certain immaterial amounts have been revised to correct the classification of derivatives.
Effect of Derivative Instruments The following tables provide information on the effects of derivative instruments in the Consolidated Statements of Income and changes in AOCI and noncontrolling interests for Fiscal 2014, 2013 and 2012:
| Gain or (Loss) Recognized in AOCI and Noncontrolling Interests |  | Gain or (Loss) Reclassified from AOCI and Noncontrolling Interests into Income |  | Location of Gain or (Loss) Reclassified from AOCI and Noncontrolling Interests into Income
| 2014 |  | 2013 |  | 2012 |  | 2014 |  | 2013 |  | 2012 |
Cash Flow Hedges: |  |  |  |  |  |  |  |  |  |  |  |  |
Commodity contracts | $ | 50.8 |  |  | $ | 8.3 |  |  | $ | (98.0 | ) |  | $ | 67.0 |  |  | $ | (49.5 | ) |  | $ | (61.4 | ) |  | Cost of sales
Foreign currency contracts | 15.3 |  |  | (8.3 | ) |  | (0.5 | ) |  | (3.7 | ) |  | (0.1 | ) |  | 2.1 |  |  | Cost of sales
Cross-currency contracts | 3.1 |  |  | (1.2 | ) |  | — |  |  | (0.1 | ) |  | — |  |  | — |  |  | Interest expense
Interest rate contracts | (3.1 | ) |  | 22.9 |  |  | (36.8 | ) |  | (15.9 | ) |  | (14.2 | ) |  | (11.5 | ) |  | Interest expense /other income, net
Total | $ | 66.1 |  |  | $ | 21.7 |  |  | $ | (135.3 | ) |  | $ | 47.3 |  |  | $ | (63.8 | ) |  | $ | (70.8 | ) |  |
Net Investment Hedges: |  |  |  |  |  |  |  |  |  |  |  |  |
Foreign currency contracts | $ | — |  |  | $ | — |  |  | $ | 0.6 |  |  |  |  |  |  |  |  |
| Gain or (Loss) Recognized in Income | Location of Gain or (Loss) Recognized in Income |
| 2014 |  | 2013 |  | 2012
Derivatives Not Designated as Hedging Instruments: |  |  |  |  |  |  |
Commodity contracts | $ | (36.3 | ) |  | $ | 9.3 |  |  | $ | 0.1 |  | Cost of sales |
Commodity contracts | — |  |  | — |  |  | 0.2 |  | Operating and administrative expenses / other income, net |
Foreign currency contracts | — |  |  | (0.4 | ) |  | 0.5 |  | Other income, net |
Total | $ | (36.3 | ) |  | $ | 8.9 |  |  | $ | 0.8 |  |  |
The amounts of derivative gains or losses representing ineffectiveness, and the amounts of gains or losses recognized in income as a result of excluding derivatives from ineffectiveness testing, were not material for Fiscal 2014, Fiscal 2013 and Fiscal 2012. We are also a party to a number of other contracts that have elements of a derivative instrument. These contracts include, among others, binding purchase orders, contracts which provide for the purchase and delivery, or sale, of energy products, and service contracts that require the counterparty to provide commodity storage, transportation or capacity service to meet our normal sales commitments. Although many of these contracts have the requisite elements of a derivative instrument, certain of these contracts qualify for NPNS exception accounting under GAAP because they provide for the delivery of products or services in quantities that are expected to be used in the normal course of operating our business and the price in the contract is based on an underlying that is directly associated with the price of the product or service being purchased or sold.

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- Definition The entire disclosure for derivative instruments and hedging activities including, but not limited to, risk management strategies, non-hedging derivative instruments, assets, liabilities, revenue and expenses, and methodologies and assumptions used in determining the amounts. + References Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 815 -SubTopic 30 -Section 50 -Paragraph 1 -URI http://asc.fasb.org/extlink&oid=35736893&loc=d3e80748-113994 Reference 2: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 815 -SubTopic 10 -Section 50 -Paragraph 4A -URI http://asc.fasb.org/extlink&oid=35706170&loc=SL5618551-113959 Reference 3: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 815 -SubTopic 10 -Section 50 -Paragraph 4K -URI http://asc.fasb.org/extlink&oid=35706170&loc=SL5708775-113959 Reference 4: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 815 -SubTopic 25 -Section 50 -Paragraph 1 -URI http://asc.fasb.org/extlink&oid=6886632&loc=d3e76258-113986 Reference 5: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 815 -SubTopic 10 -Section 50 -Paragraph 4E -URI http://asc.fasb.org/extlink&oid=35706170&loc=SL5624181-113959 Reference 6: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 815 -SubTopic 30 -Section 45 -Paragraph 1 -URI http://asc.fasb.org/extlink&oid=6441202&loc=d3e80720-113993 Reference 7: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 815 -SubTopic 10 -Section 50 -Paragraph 4H -URI http://asc.fasb.org/extlink&oid=35706170&loc=SL5624258-113959 Reference 8: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 815 -SubTopic 10 -Section 50 -Paragraph 4B -URI http://asc.fasb.org/extlink&oid=35706170&loc=SL5624163-113959 Reference 9: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 235 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.4-08.(n)) -URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e23780-122690 Reference 10: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 815 -SubTopic 10 -Section 50 -Paragraph 4J -URI http://asc.fasb.org/extlink&oid=35706170&loc=SL5708773-113959 Reference 11: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 815 -SubTopic 30 -Section 50 -Paragraph 2 -URI http://asc.fasb.org/extlink&oid=35736893&loc=d3e80784-113994 Reference 12: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 815 -SubTopic 10 -Section 50 -Paragraph 4D -URI http://asc.fasb.org/extlink&oid=35706170&loc=SL5624177-113959 Reference 13: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 815 -SubTopic 10 -Section 50 -Paragraph 2 -URI http://asc.fasb.org/extlink&oid=35706170&loc=d3e41620-113959 Reference 14: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 815 -SubTopic 10 -Section 50 -Paragraph 1A -URI http://asc.fasb.org/extlink&oid=35706170&loc=SL5579245-113959 Reference 15: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 815 -SubTopic 10 -Section 50 -Paragraph 1B -URI http://asc.fasb.org/extlink&oid=35706170&loc=SL5580258-113959 Reference 16: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 815 -SubTopic 10 -Section 50 -Paragraph 1 -URI http://asc.fasb.org/extlink&oid=35706170&loc=SL5579240-113959 Reference 17: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 815 -SubTopic 10 -Section 50 -Paragraph 5 -URI http://asc.fasb.org/extlink&oid=35706170&loc=d3e41641-113959 Reference 18: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 815 -SubTopic 10 -Section 50 -Paragraph 4 -URI http://asc.fasb.org/extlink&oid=35706170&loc=d3e41638-113959 Reference 19: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 815 -SubTopic 10 -Section 50 -Paragraph 4C -URI http://asc.fasb.org/extlink&oid=35706170&loc=SL5624171-113959 + Details
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