Filed by Bowne Pure Compliance

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q


þ		QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended March 31, 2007


o		TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from __________ to __________

Commission file number 1-11071

UGI CORPORATION

(Exact name of registrant as specified in its charter)


Pennsylvania (State or other jurisdiction of incorporation or organization)		23-2668356 (I.R.S. Employer Identification No.)

UGI CORPORATION
460 North Gulph Road, King of Prussia, PA
(Address of principal executive offices)
19406
(Zip Code)
(610) 337-1000
(Registrant’s telephone number, including area code)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes þ No o

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer. See definition of “accelerated filer and large accelerated filer” in Rule 12b-2 of the Exchange Act.


Large accelerated filer þ		Accelerated filer o		Non-accelerated filer o

Indicated by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes o No þ

At April 30, 2007, there were 106,235,792 shares of UGI Corporation Common Stock, without par value, outstanding.

UGI CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS
(unaudited)
(Millions of dollars)


	March 31,			September 30,			March 31,
	2007			2006			2006
ASSETS
Current assets:
Cash and cash equivalents	$	198.3		$	186.2		$	238.7
Restricted cash		6.4			14.2			10.4
Short-term investments (at cost, which approximates fair value)		5.7			0.6			120.0
Accounts receivable (less allowances for doubtful accounts of $45.5, $38.0 and $38.2, respectively)		782.6			387.2			684.5
Accrued utility revenues		56.1			16.6			32.9
Inventories		202.6			340.4			168.6
Deferred income taxes		36.3			55.9			29.6
Prepaid expenses and other current assets		32.4			39.5			22.5

Total current assets		1,320.4			1,040.6			1,307.2

Property, plant and equipment, at cost (less accumulated depreciation and amortization of $1,313.6, $1,246.6 and $1,033.4, respectively)		2,266.2			2,214.7			1,799.6

Goodwill		1,430.1			1,418.2			1,209.0
Intangible assets (less accumulated amortization of $72.5, $62.8 and $53.5, respectively)		162.1			163.3			165.0
Utility regulatory assets		82.5			72.9			62.0
Investments in equity investees		61.0			58.2			55.6
Other assets		117.6			112.6			124.7

Total assets	$	5,439.9		$	5,080.5		$	4,723.1


LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Current maturities of long-term debt	$	34.5		$	31.9		$	57.0
UGI Utilities bank loans		146.0			216.0			123.3
Other bank loans		9.2			9.4			11.5
Accounts payable		494.6			373.0			440.8
Other current liabilities		364.5			396.3			310.3

Total current liabilities		1,048.8			1,026.6			942.9

Long-term debt		1,985.7			1,965.0			1,636.8
Deferred income taxes		510.1			491.5			486.5
Deferred investment tax credits		6.6			6.8			7.0
Other noncurrent liabilities		367.3			351.5			319.0

Total liabilities		3,918.5			3,841.4			3,392.2

Commitments and contingencies (note 9)

Minority interests		220.9			139.5			219.9

Common stockholders’ equity:
Common Stock, without par value (authorized — 300,000,000 shares; issued — 115,152,994 shares)		820.7			807.5			800.5
Retained earnings		514.6			370.0			392.2
Accumulated other comprehensive income (loss)		34.2			(3.8	)		(6.0	)

		1,369.5			1,173.7			1,186.7

Treasury stock, at cost		(69.0	)		(74.1	)		(75.7	)

Total common stockholders’ equity		1,300.5			1,099.6			1,111.0

Total liabilities and stockholders’ equity	$	5,439.9		$	5,080.5		$	4,723.1

See accompanying notes to condensed consolidated financial statements.

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UGI CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME
(unaudited)
(Millions of dollars, except per share amounts)


	Three Months Ended						Six Months Ended
	March 31,						March 31,
	2007			2006			2007			2006

Revenues	$	2,002.1		$	1,845.5		$	3,465.3		$	3,423.4

Costs and expenses:
Cost of sales		1,372.8			1,297.0			2,367.2			2,447.7
Operating and administrative expenses		290.6			264.3			551.8			499.7
Utility taxes other than income taxes		5.1			3.7			9.7			7.0
Depreciation and amortization		41.8			35.9			83.5			72.2
Other income, net		(8.7	)		(18.0	)		(14.7	)		(26.0	)

		1,701.6			1,582.9			2,997.5			3,000.6

Operating income		300.5			262.6			467.8			422.8
Loss from equity investees		(1.3	)		(0.6	)		(1.3	)		(1.2	)
Interest expense		(35.1	)		(30.4	)		(71.1	)		(63.0	)
Loss on early extinguishments of debt		—			(18.5	)		—			(18.5	)

Income before income taxes and minority interests		264.1			213.1			395.4			340.1
Income tax expense		(75.9	)		(64.4	)		(114.0	)		(102.9	)
Minority interests, principally in AmeriGas Partners		(68.0	)		(44.7	)		(99.3	)		(75.7	)

Net income	$	120.2		$	104.0		$	182.1		$	161.5


Earnings per common share:

Basic	$	1.13		$	0.99		$	1.72		$	1.53


Diluted	$	1.12		$	0.98		$	1.69		$	1.52


Average common shares outstanding (millions):

Basic		106.331			105.365			106.133			105.261


Diluted		107.760			106.401			107.666			106.472


Dividends declared per common share	$	0.1763		$	0.1688		$	0.3525		$	0.3375

See accompanying notes to condensed consolidated financial statements.

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UGI CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(unaudited)
(Millions of dollars)


	Six Months Ended
	March 31,
	2007			2006
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income	$	182.1		$	161.5
Adjustments to reconcile to net cash provided by operating activities:
Depreciation and amortization		83.5			72.2
Minority interests		99.3			75.7
Deferred income taxes, net		3.5			8.8
Loss on early extinguishments of debt		—			18.5
Net change in settled accumulated other comprehensive income		18.3			(32.4	)
Other, net		29.2			23.0
Net change in:
Accounts receivable and accrued utility revenues		(444.4	)		(269.7	)
Inventories		139.7			71.5
Deferred fuel costs		(1.4	)		(9.9	)
Accounts payable		113.7			12.4
Other current assets and liabilities		(1.0	)		(61.1	)

Net cash provided by operating activities		222.5			70.5


CASH FLOWS FROM INVESTING ACTIVITIES:
Expenditures for property, plant and equipment		(102.2	)		(89.3	)
Net proceeds from disposals of assets		1.5			4.5
Net proceeds from sale of Energy Ventures		—			17.7
Investment in Flaga joint venture		—			(10.9	)
Acquisitions, net of cash acquired		(0.4	)		(2.9	)
PG Energy Acquisition working capital settlement		23.7			—
Short-term investments increase		(5.1	)		(50.0	)
Decrease (increase) in restricted cash		7.8			(5.5	)
Other, net		0.4			0.6

Net cash used by investing activities		(74.3	)		(135.8	)


CASH FLOWS FROM FINANCING ACTIVITIES:
Dividends on UGI Common Stock		(37.4	)		(35.5	)
Distributions on AmeriGas Partners publicly held Common Units		(37.5	)		(36.1	)
Issuances of debt		0.1			843.4
Repayments of debt including bank loans with maturities greater than three months		(5.9	)		(893.0	)
Other bank loans decrease		(0.7	)		(5.0	)
(Decrease) increase in Utilities bank loans with maturities of three months or less		(70.0	)		112.1
Issuance of UGI Common Stock		8.3			7.1
Other, net		3.4			0.5

Net cash used by financing activities		(139.7	)		(6.5	)

EFFECT OF EXCHANGE RATE CHANGES ON CASH		3.6			0.4


Cash and cash equivalents increase (decrease)	$	12.1		$	(71.4	)

Cash and cash equivalents:
End of period	$	198.3		$	238.7
Beginning of period		186.2			310.1

Increase (decrease)	$	12.1		$	(71.4	)

See accompanying notes to condensed consolidated financial statements.

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UGI CORPORATION AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements
(unaudited)
(Millions of dollars and euros, except per share amounts)

Basis of Presentation

UGI Corporation (“UGI”) is a holding company that owns and operates natural gas and electric distribution utilities, electricity generation, retail propane distribution, energy marketing and related businesses in the United States. Through foreign subsidiaries and joint-venture affiliates, UGI also distributes liquefied petroleum gases (“LPG”) in France, central and eastern Europe and China.

We conduct a national propane distribution business through AmeriGas Partners, L.P. (“AmeriGas Partners”) and its principal operating subsidiaries AmeriGas Propane, L.P. (“AmeriGas OLP”) and AmeriGas OLP’s subsidiary, AmeriGas Eagle Propane, L.P. (“Eagle OLP”). AmeriGas Partners, AmeriGas OLP and Eagle OLP are Delaware limited partnerships. UGI’s wholly owned second-tier subsidiary AmeriGas Propane, Inc. (the “General Partner”) serves as the general partner of AmeriGas Partners and AmeriGas OLP. AmeriGas OLP and Eagle OLP (collectively referred to as “the Operating Partnerships”) comprise the largest retail propane distribution business in the United States serving residential, commercial, industrial, motor fuel and agricultural customers from locations in 46 states. We refer to AmeriGas Partners and its subsidiaries together as “the Partnership” and the General Partner and its subsidiaries, including the Partnership, as “AmeriGas Propane.” At March 31, 2007, the General Partner and its wholly owned subsidiary Petrolane Incorporated (“Petrolane”) collectively held a 1% general partner interest and 42.7% limited partner interest in AmeriGas Partners, and an effective 44.3% ownership interest in AmeriGas OLP and Eagle OLP. Our limited partnership interest in AmeriGas Partners comprises 24,525,004 Common Units. The remaining 56.3% limited partner interest in AmeriGas Partners comprises 32,297,493 publicly held Common Units representing limited partner interests.

Our wholly owned subsidiary, UGI Enterprises, Inc. (“Enterprises”) (1) conducts an LPG distribution business in France (“Antargaz”); (2) conducts LPG distribution businesses and participates in an LPG joint-venture business in central and eastern Europe (collectively, “Flaga”); and (3) participates in an LPG joint-venture business in China. Enterprises’ indirect subsidiary, UGI International Holdings, B.V., holds our interests in Antargaz and Flaga. We refer to our foreign operations collectively as “International Propane.” In addition, Enterprises conducts an energy marketing business primarily in the eastern United States through its wholly owned first- and second-tier subsidiaries (collectively “Energy Services”). Energy Services owns and operates liquefied natural gas and propane storage and peak-shaving facilities in eastern Pennsylvania. Energy Services’ wholly owned subsidiary UGI Development Company (“UGID”) and UGID’s subsidiaries (1) own and operate a 48-megawatt coal-fired electric generation station and (2) own a 6% interest in Pennsylvania-based coal-fired electric generation assets. In addition, Energy Services’ wholly owned subsidiary UGI Asset Management, Inc., through its subsidiary Atlantic Energy, Inc. (collectively, “Asset Management”), owns a propane storage terminal located in Chesapeake, Virginia. Through other subsidiaries, Enterprises owns and operates a heating, ventilation, air-conditioning, refrigeration and electrical contracting services business in the Middle Atlantic states (“HVAC/R”).

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UGI CORPORATION AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements
(unaudited)
(Millions of dollars and euros, except per share amounts)

Our natural gas and electric distribution utility businesses are conducted through our wholly owned subsidiary, UGI Utilities, Inc. and its subsidiary, UGI Penn Natural Gas, Inc. (“UGIPNG”). UGI Utilities, Inc. owns and operates (1) a natural gas distribution utility in eastern Pennsylvania (“UGI Gas”), (2) a natural gas distribution utility in northeastern Pennsylvania (“PNG Gas”) which was acquired effective August 24, 2006 (the “PG Energy Acquisition”), and (3) an electric distribution utility in northeastern Pennsylvania (“Electric Utility”). UGI Gas, PNG Gas (collectively, “Gas Utility”) and Electric Utility are subject to regulation by the Pennsylvania Public Utility Commission (“PUC”). In addition, both UGI Utilities, Inc. and UGIPNG have wholly-owned subsidiaries that operate heating, ventilation and air-conditioning services businesses principally within their natural gas utilities’ service territories. The term “UGI Utilities” is used sometimes as an abbreviated reference to UGI Utilities, Inc. or UGI Utilities, Inc. and its subsidiaries.

Our condensed consolidated financial statements include the accounts of UGI and its controlled subsidiary companies, which, except for the Partnership, are majority owned, and are together referred to as “we” or “the Company.” We eliminate all significant intercompany accounts and transactions when we consolidate. We report the public’s limited partner interests in the Partnership and the outside ownership interest in a subsidiary of Antargaz as minority interests. Entities in which we own 50 percent or less and in which we exercise significant influence over operating and financial policies are accounted for by the equity method.

The accompanying condensed consolidated financial statements are unaudited and have been prepared in accordance with the rules and regulations of the U.S. Securities and Exchange Commission (“SEC”). They include all adjustments which we consider necessary for a fair statement of the results for the interim periods presented. Such adjustments consisted only of normal recurring items unless otherwise disclosed. The September 30, 2006 condensed consolidated balance sheet data was derived from audited financial statements but does not include all disclosures required by accounting principles generally accepted in the United States of America. These financial statements should be read in conjunction with the financial statements and related notes included in our Annual Report on Form 10-K for the year ended September 30, 2006 (“Company’s 2006 Annual Report”). Due to the seasonal nature of our businesses, the results of operations for interim periods are not necessarily indicative of the results to be expected for a full year.

Restricted Cash. Restricted cash representing cash deposited in our natural gas futures accounts to satisfy margin requirements totaled $6.4, $14.2 and $10.4 at March 31, 2007, September 30, 2006 and March 31, 2006, respectively.

Earnings Per Common Share. Basic earnings per share reflect the weighted-average number of common shares outstanding. Diluted earnings per share include the effects of dilutive stock options and common stock awards.

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UGI CORPORATION AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements
(unaudited)
(Millions of dollars and euros, except per share amounts)

Shares used in computing basic and diluted earnings per share are as follows:


	Three Months Ended				Six Months Ended
	March 31,				March 31,
	2007		2006		2007		2006
Denominator (millions of shares):
Average common shares outstanding for basic computation		106.331		105.365		106.133		105.261
Incremental shares issuable for stock options and awards		1.429		1.036		1.533		1.211

Average common shares outstanding for diluted computation		107.760		106.401		107.666		106.472

Comprehensive Income. The following table presents the components of comprehensive income for the three and six months ended March 31, 2007 and 2006.


	Three Months Ended				Six Months Ended
	March 31,				March 31,
	2007		2006		2007		2006
Net income	$	120.2	$	104.0	$	182.1	$	161.5
Other comprehensive income (loss)		29.2		4.8		38.0		(22.5	)

Comprehensive income	$	149.4	$	108.8	$	220.1	$	139.0

Other comprehensive income (loss) principally comprises (1) changes in the fair value of derivative commodity instruments, interest rate protection agreements and foreign currency derivatives qualifying as hedges, net of reclassifications to net income and (2) foreign currency translation adjustments.

Revenue-Related Taxes. In June 2006, the Financial Accounting Standards Board (“FASB”) reached a consensus on Emerging Issues Task Force (“EITF”) Issue No. 06-3, “How Taxes Collected from Customers and Remitted to Governmental Authorities Should Be Presented in the Income Statement (That Is, Gross versus Net Presentation)” (“EITF 06-3”). EITF 06-3 addresses accounting policies disclosure with respect to revenue-related taxes beginning with financial reports for interim or annual reporting periods beginning after December 15, 2006. The scope of EITF 06-3 includes any tax assessed by a governmental authority that is imposed concurrent with or subsequent to a revenue-producing transaction between a seller and a customer. EITF 06-3 provides that entities may adopt a policy of presenting such taxes in the income statement either on a gross basis within revenue or on a net basis. If such taxes are significant, and are presented on the income statement on a gross basis, the amounts of those taxes should also be disclosed. As a result of adopting this EITF, we are providing disclosure of our existing accounting policy and have not made any changes to that policy. We present revenue-related taxes within the scope of EITF 06-3 on a net basis.

Reclassifications. We have reclassified certain prior-year period balances to conform to the current-period presentation.

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UGI CORPORATION AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements
(unaudited)
(Millions of dollars and euros, except per share amounts)

Use of Estimates. We make estimates and assumptions when preparing financial statements in conformity with accounting principles generally accepted in the United States of America. These estimates and assumptions affect the reported amounts of assets and liabilities, revenues and expenses, as well as the disclosure of contingent assets and liabilities. Actual results could differ from these estimates.

Recently Issued Accounting Pronouncements. In March 2006, the FASB issued Statement of Financial Accounting Standards (“SFAS”) No. 156, “Accounting for Servicing of Financial Assets — An Amendment of FASB Statement No. 140” (“SFAS 156”). SFAS 156 requires that all separately recognized servicing assets and servicing liabilities be initially measured at fair value, unless it is impracticable to do so. SFAS 156 permits, but does not require, the subsequent measurement of servicing assets and servicing liabilities at fair value. Our adoption of SFAS 156 effective October 1, 2006 did not have a material impact on our Condensed Consolidated Financial Statements.

In February 2007, the FASB issued SFAS No. 159, “The Fair Value Option for Financial Assets and Financial Liabilities — Including an amendment of FASB Statement No. 115” (“SFAS 159”) which permits entities to choose to measure certain financial instruments at fair value that are not currently required to be measured at fair value. Upon adoption, a cumulative adjustment will be made to beginning retained earnings for the initial fair value option remeasurement. Subsequent unrealized gains and losses for fair value option items will be reported in earnings. SFAS No. 159 is effective for fiscal years beginning after November 15, 2007 and should not be applied retrospectively, except as permitted for certain conditions for early adoption. We are currently reviewing the provisions of SFAS 159.

PG Energy Acquisition

On August 24, 2006, UGI Utilities acquired certain assets and assumed certain liabilities of Southern Union Company’s (“SU’s”) PG Energy Division, a natural gas distribution business located in northeastern Pennsylvania, and all of the issued and outstanding stock of SU’s wholly-owned subsidiary, PG Energy Services, Inc., pursuant to a Purchase and Sale Agreement, as amended, between SU and UGI dated January 26, 2006 (the “Agreement”). UGI subsequently assigned its rights under the Agreement to UGI Utilities. On August 24, 2006 and in accordance with the terms of the Agreement, UGI Utilities paid SU $580 in cash. Pursuant to the terms of the Agreement, the purchase price was subject to a working capital adjustment equal to the difference between $68.1 and the actual working capital as of the closing date agreed to by both UGI Utilities and SU. In March 2007, UGI Utilities and SU reached an agreement on the working capital adjustment pursuant to which SU paid UGI Utilities approximately $23.7 in cash. In addition, in March 2007 UGI Utilities completed its review and determination of the fair value of the assets acquired and liabilities assumed.

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UGI CORPORATION AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements
(unaudited)
(Millions of dollars and euros, except per share amounts)

The purchase price of the PG Energy Acquisition, including transaction fees and expenses of $11.0, has been allocated to the assets acquired and liabilities assumed, as follows:


Working capital	$	47.0
Property, plant and equipment		362.3
Goodwill		162.6
Regulatory assets		15.0
Other assets		4.0
Noncurrent liabilities		(23.6	)

Total	$	567.3

Utility Regulatory Matters

In an order entered on November 30, 2006, the PUC approved a settlement of the base rate proceeding of PG Energy (PNG Gas). The settlement provided for an increase in natural gas distribution base rates of $12.5 annually or approximately 4%, effective December 2, 2006.

In accordance with Provider of Last Resort (“POLR”) settlements approved by the PUC, Electric Utility may increase its POLR rates up to certain limits through December 31, 2009. In accordance with these settlements, Electric Utility increased its POLR rates by 4.5% on January 1, 2005 and 3% on January 1, 2006 (a total of 7.5% above the total rates in effect December 31, 2004). Electric Utility also increased its POLR rates for all metered customers effective January 1, 2007 which is expected to increase the average cost to residential customers by approximately 35% over such costs in effect during calendar year 2006.

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UGI CORPORATION AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements
(unaudited)
(Millions of dollars and euros, except per share amounts)

Segment Information

We have organized our business units into six reportable segments generally based upon products sold, geographic location (domestic or international) or regulatory environment. Our reportable segments are: (1) AmeriGas Propane; (2) an international LPG segment comprising Antargaz; (3) an international LPG segment comprising Flaga and our international LPG equity investment in China (“Other”); (4) Gas Utility; (5) Electric Utility; and (6) Energy Services. We refer to both international segments collectively as “International Propane.”

The accounting policies of the six segments disclosed are the same as those described in Note 1, Organization and Significant Accounting Policies, in the Company’s 2006 Annual Report. We evaluate AmeriGas Propane’s performance principally based upon the Partnership’s earnings before interest expense, income taxes, depreciation and amortization (“Partnership EBITDA”). Although we use Partnership EBITDA to evaluate AmeriGas Propane’s profitability, it should not be considered as an alternative to net income (as an indicator of operating performance) or as an alternative to cash flow (as a measure of liquidity or ability to service debt obligations) and is not a measure of performance or financial condition under accounting principles generally accepted in the United States of America. The Company’s definition of Partnership EBITDA may be different from that used by other companies. We evaluate the performance of our International Propane, Gas Utility, Electric Utility and Energy Services segments principally based upon their income before income taxes.

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UGI CORPORATION AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements (continued)
(unaudited)
(Millions of dollars, except per share amounts)

Segment Information (continued)

Three Months Ended March 31, 2007:


							Reportable Segments
							AmeriGas			Gas			Electric			Energy		International Propane						Corporate
	Total			Elims.			Propane			Utility			Utility			Services		Antargaz			Other (a)			& Other (b)
Revenues	$	2,002.1		$	(52.9	)	$	809.8		$	459.0		$	34.9		$	444.9	$	271.0		$	11.8		$	23.6


Cost of sales	$	1,372.8		$	(52.0	)	$	500.3		$	334.2		$	20.8		$	416.4	$	132.8		$	6.4		$	13.9


Segment profit:
Operating income (c)	$	300.5		$	0.1		$	139.2		$	78.0		$	6.7		$	17.4	$	58.2		$	0.8		$	0.1
Loss from equity investees		(1.3	)		—			—			—			—			—		(1.1	)		(0.2	)		—
Interest expense		(35.1	)		—			(17.8	)		(10.4	)		(0.6	)		—		(5.7	)		(0.5	)		(0.1	)
Minority interests		(68.0	)		(0.1	)		(67.5	)		—			—			—		(0.4	)		—			—

Income before income taxes	$	196.1		$	—		$	53.9		$	67.6		$	6.1		$	17.4	$	51.0		$	0.1		$	—

Depreciation and amortization	$	41.8		$	0.1		$	18.5		$	9.6		$	0.9		$	1.8	$	9.9		$	0.9		$	0.1
Partnership EBITDA (c)							$	156.4

Segment assets (at period end)	$	5,439.9		$	(348.8	)	$	1,696.6		$	1,522.5		$	113.8		$	320.1	$	1,563.7		$	191.1		$	380.9


Investments in equity investees (at period end)	$	61.0		$	—		$	—		$	—		$	—		$	—	$	—		$	61.0		$	—


Goodwill (at period end)	$	1,430.1		$	(4.0	)	$	619.1		$	162.6		$	—		$	11.8	$	590.5		$	43.1		$	7.0

Three Months Ended March 31, 2006:


							Reportable Segments
							AmeriGas			Gas			Electric			Energy		International Propane						Corporate
	Total			Elims.			Propane			Utility			Utility			Services		Antargaz			Other (a)			& Other (b)
Revenues	$	1,845.5		$	(31.9	)	$	718.2		$	296.2		$	25.4		$	438.8	$	358.4		$	23.7		$	16.7


Cost of sales	$	1,297.0		$	(30.9	)	$	447.3		$	223.0		$	15.2		$	411.4	$	205.6		$	15.4		$	10.0


Segment profit:
Operating income (c)	$	262.6		$	—		$	116.3		$	39.9		$	3.3		$	26.1	$	74.0		$	2.5		$	0.5
Loss from equity investees		(0.6	)		—			—			—			—			—		(0.6	)		—			—
Loss on extinguishments of debt		(18.5	)		—			(17.1	)		—			—			—		(1.4	)		—			—
Interest expense		(30.4	)		—			(19.4	)		(4.6	)		(0.8	)		—		(5.3	)		(0.4	)		0.1
Minority interests		(44.7	)		(0.1	)		(44.3	)		—			—			—		(0.3	)		—			—

Income before income taxes	$	168.4		$	(0.1	)	$	35.5		$	35.3		$	2.5		$	26.1	$	66.4		$	2.1		$	0.6

Depreciation and amortization	$	35.9		$	—		$	17.9		$	5.4		$	0.9		$	1.7	$	8.8		$	1.0		$	0.2
Partnership EBITDA (c)							$	116.2

Segment assets (at period end)	$	4,723.1		$	(334.3	)	$	1,670.9		$	853.3		$	108.1		$	248.6	$	1,489.5		$	154.0		$	533.0


Investments in equity investees (at period end)	$	55.6		$	—		$	—		$	—		$	—		$	—	$	0.4		$	55.2		$	—


Goodwill (at period end)	$	1,209.0		$	(4.0	)	$	618.3		$	—		$	—		$	11.8	$	535.8		$	40.7		$	6.4


(a)		International Propane-Other principally comprises Flaga, including its central and eastern European joint venture and our joint-venture business in China.

(b)		Corporate & Other’s results principally comprise UGI Enterprises’ HVAC/R, net expenses of UGI’s captive general liability insurance company and UGI Corporation’s unallocated corporate and general expenses and interest income, and, beginning January 1, 2007, UGI Utilities’ HVAC operations. Corporate & Other’s assets principally comprise cash, short-term investments and an intercompany loan. The intercompany interest associated with the intercompany loan is removed in the segment presentation.

(c)		The following table provides a reconciliation of Partnership EBITDA to AmeriGas Propane operating income:


Three months ended March 31,	2007			2006
Partnership EBITDA	$	156.4		$	116.2
Depreciation and amortization		(18.5	)		(17.9	)
Minority interests (i)		1.3			0.9
Loss on extinguishments of debt		—			17.1

Operating income	$	139.2		$	116.3


(i)		Principally represents the General Partner’s 1.01% interest in AmeriGas OLP.

- 10 -

UGI CORPORATION AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements (continued)
(unaudited)
(Millions of dollars, except per share amounts)

Segment Information (continued)

Six Months Ended March 31, 2007:


							Reportable Segments
							AmeriGas			Gas			Electric			Energy		International Propane						Corporate
	Total			Elims.			Propane			Utility			Utility			Services		Antargaz			Other (a)			& Other (b)
Revenues	$	3,465.3		$	(95.5	)	$	1,426.4		$	733.4		$	59.8		$	789.1	$	486.3		$	22.9		$	42.9


Cost of sales	$	2,367.2		$	(93.6	)	$	889.0		$	528.0		$	33.0		$	735.1	$	237.8		$	12.3		$	25.6


Segment profit:
Operating income (c)	$	467.8		$	(0.3	)	$	214.5		$	116.2		$	12.9		$	32.6	$	91.2		$	0.9		$	(0.2	)
Loss from equity investees		(1.3	)		—			—			—			—			—		(1.1	)		(0.2	)		—
Interest expense		(71.1	)		—			(35.8	)		(21.2	)		(1.3	)		—		(11.3	)		(1.0	)		(0.5	)
Minority interests		(99.3	)		(0.1	)		(98.8	)		—			—			—		(0.4	)		—			—

Income (loss) before income taxes	$	296.1		$	(0.4	)	$	79.9		$	95.0		$	11.6		$	32.6	$	78.4		$	(0.3	)	$	(0.7	)

Depreciation and amortization	$	83.5		$	—		$	37.1		$	18.9		$	1.8		$	3.6	$	20.0		$	1.7		$	0.4
Partnership EBITDA (c)							$	249.5

Segment assets (at period end)	$	5,439.9		$	(348.8	)	$	1,696.6		$	1,522.5		$	113.8		$	320.1	$	1,563.7		$	191.1		$	380.9


Investments in equity investees (at period end)	$	61.0		$	—		$	—		$	—		$	—		$	—	$	—		$	61.0		$	—


Goodwill (at period end)	$	1,430.1		$	(4.0	)	$	619.1		$	162.6		$	—		$	11.8	$	590.5		$	43.1		$	7.0

Six Months Ended March 31, 2006:


							Reportable Segments
							AmeriGas			Gas			Electric			Energy		International Propane						Corporate
	Total			Elims.			Propane			Utility			Utility			Services		Antargaz			Other (a)			& Other (b)
Revenues	$	3,423.4		$	(66.0	)	$	1,348.4		$	516.0		$	49.3		$	890.2	$	607.2		$	42.5		$	35.8


Cost of sales	$	2,447.7		$	(64.0	)	$	855.1		$	382.9		$	26.5		$	845.1	$	352.0		$	28.1		$	22.0


Segment profit:
Operating income (c)	$	422.8		$	—		$	191.0		$	75.6		$	9.8		$	34.3	$	107.2		$	2.9		$	2.0
Loss from equity investees		(1.2	)		—			—			—			—			—		(1.2	)		—			—
Loss on extinguishments of debt		(18.5	)		—			(17.1	)		—			—			—		(1.4	)		—			—
Interest expense		(63.0	)		—			(38.3	)		(9.7	)		(1.3	)		—		(12.9	)		(0.9	)		0.1
Minority interests		(75.7	)		(0.2	)		(75.3	)		—			—			—		(0.2	)		—			—

Income before income taxes	$	264.4		$	(0.2	)	$	60.3		$	65.9		$	8.5		$	34.3	$	91.5		$	2.0		$	2.1

Depreciation and amortization	$	72.2		$	—		$	36.2		$	10.8		$	1.7		$	3.2	$	17.8		$	2.2		$	0.3
Partnership EBITDA (c)							$	208.4

Segment assets (at period end)	$	4,723.1		$	(334.3	)	$	1,670.9		$	853.3		$	108.1		$	248.6	$	1,489.5		$	154.0		$	533.0


Investments in equity investees (at period end)	$	55.6		$	—		$	—		$	—		$	—		$	—	$	0.4		$	55.2		$	—


Goodwill (at period end)	$	1,209.0		$	(4.0	)	$	618.3		$	—		$	—		$	11.8	$	535.8		$	40.7		$	6.4


(a)		International Propane-Other principally comprises Flaga, including its cental and eastern European joint venture and our joint-venture business in China.

(b)		Corporate & Other’s results principally comprise UGI Enterprises’ HVAC/R, net expenses of UGI’s captive general liability insurance company and UGI Corporation’s unallocated corporate and general expenses and interest income, and, beginning January 1, 2007, UGI Utilities’ HVAC operations. Corporate & Other’s assets principally comprise cash, short-term investments and an intercompany loan. The intercompany interest associated with the intercompany loan is removed in the segment presentation.

(c)		The following table provides a reconciliation of Partnership EBITDA to AmeriGas Propane operating income:


Six months ended March 31,	2007			2006
Partnership EBITDA	$	249.5		$	208.4
Depreciation and amortization		(37.1	)		(36.2	)
Minority interests (i)		2.1			1.7
Loss on extinguishments of debt		—			17.1

Operating income	$	214.5		$	191.0


(i)		Principally represents the General Partner’s 1.01% interest in AmeriGas OLP.

- 11 -

UGI CORPORATION AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements
(unaudited)
(Millions of dollars and euros, except per share amounts)

Intangible Assets

The Company’s intangible assets comprise the following:


	March 31,			September 30,
	2007			2006
Goodwill (not subject to amortization)	$	1,430.1		$	1,418.2


Other intangible assets:
Customer relationships, noncompete agreements and other	$	189.2		$	183.0
Trademark (not subject to amortization)		45.4			43.1

Gross carrying amount		234.6			226.1

Accumulated amortization		(72.5	)		(62.8	)

Net carrying amount	$	162.1		$	163.3

The increase in goodwill during the six months ended March 31, 2007 primarily reflects the effects of foreign currency translation partially offset by the working capital adjustment associated with the PG Energy Acquisition. Changes in intangible assets during the six months ended March 31, 2007 principally reflect the effects of foreign currency translation. Amortization expense of intangible assets was $4.1 and $8.2 for the three and six months ended March 31, 2007, respectively, and $4.5 and $8.8 for the three and six months ended March 31, 2006, respectively. Our expected aggregate amortization expense of intangible assets for the next five fiscal years is as follows: Fiscal 2007 — $15.7; Fiscal 2008 — $15.4; Fiscal 2009 — $14.7; Fiscal 2010 — $13.3; Fiscal 2011 — $12.7.

UGI Utilities’ Revolving Credit Agreement

During the six months ended March 31, 2007, the termination date of UGI Utilities’ $350 Revolving Credit Agreement was automatically extended by UGI Utilities to August 2011.

Energy Services Accounts Receivable Securitization Facility

- 12 -

UGI CORPORATION AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements
(unaudited)
(Millions of dollars and euros, except per share amounts)

During the six months ended March 31, 2007 and 2006, Energy Services sold trade receivables totaling $707.6 and $810.3, respectively, to ESFC. During the six months ended March 31, 2007 and 2006, ESFC sold an aggregate $217.0 and $543.5, respectively, of undivided interests in its trade receivables to the commercial paper conduit. At March 31, 2007, the outstanding balance of ESFC trade receivables was $118.4 which is net of $32.0 that was sold to the commercial paper conduit and removed from the balance sheet. At March 31, 2006, the outstanding balance of ESFC trade receivables was $56.5 which is net of $75.6 that was sold to the commercial paper conduit and removed from the balance sheet.

In addition, a major bank has committed to issue up to $50 of standby letters of credit, secured by cash or marketable securities (“LC Facility”) to Energy Services. At March 31, 2007, there were no letters of credit outstanding. Energy Services expects to fund the collateral requirements with borrowings under its Receivables Facility. The LC Facility expires in April 2008.

Defined Benefit Pension and Other Postretirement Plans

We sponsor two defined benefit pension plans (“Pension Plan”) for employees of UGI, UGI Utilities, including employees of UGIPNG, and certain of UGI’s other wholly owned subsidiaries. In addition, we provide postretirement health care benefits to certain retirees and postretirement life insurance benefits to nearly all domestic active and retired employees. In addition, Antargaz has retirement obligations and other post employment benefit commitments associated with certain of its retirees and employees.

- 13 -

UGI CORPORATION AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements
(unaudited)
(Millions of dollars and euros, except per share amounts)

Net periodic pension expense and other postretirement benefit costs include the following components:


							Other
	Pension Benefits						Postretirement Benefits
	Three Months Ended						Three Months Ended
	March 31,						March 31,
	2007			2006			2007			2006
Service cost	$	1.6		$	1.5		$	0.1		$	0.1
Interest cost		4.7			3.6			0.3			0.3
Expected return on assets		(5.9	)		(4.7	)		(0.2	)		(0.2	)
Amortization of:
Transition obligation		—			—			0.1			0.1
Prior service cost (benefit)		0.1			0.2			(0.1	)		(0.1	)
Actuarial loss		0.3			0.4			0.1			0.1

Net benefit cost		0.8			1.0			0.3			0.3
Change in regulatory and other assets and liabilities		(0.1	)		(0.1	)		0.7			0.7

Net expense	$	0.7		$	0.9		$	1.0		$	1.0


							Other
	Pension Benefits						Postretirement Benefits
	Six Months Ended						Six Months Ended
	March 31,						March 31,
	2007			2006			2007			2006
Service cost	$	3.3		$	3.0		$	0.2		$	0.2
Interest cost		9.4			7.0			0.7			0.6
Expected return on assets		(11.8	)		(9.4	)		(0.3	)		(0.3	)
Amortization of:
Transition obligation		—			—			0.1			0.1
Prior service cost (benefit)		0.1			0.4			(0.1	)		(0.1	)
Actuarial loss		0.5			0.9			0.1			0.1

Net benefit cost		1.5			1.9			0.7			0.6
Change in regulatory and other assets and liabilities		(0.1	)		(0.2	)		1.4			1.4

Net expense	$	1.4		$	1.7		$	2.1		$	2.0

Pension Plan assets are held in trust and consist principally of equity and fixed income mutual funds. The Company does not believe it will be required to make any contributions to the Pension Plan during the year ending September 30, 2007 for ERISA funding purposes. Pursuant to orders previously issued by the PUC, UGI Utilities has established a Voluntary Employees’ Beneficiary Association (“VEBA”) trust to fund and pay UGI Utilities’ postretirement health care and life insurance benefits referred to above by depositing into the VEBA the annual amount of postretirement benefit costs determined under SFAS No. 106, “Employers’ Accounting for Postretirement Benefits Other Than Pensions.” The difference between the annual amount calculated and the amount included in UGI Gas’ and Electric Utility’s rates is deferred for future recovery from, or refund to, ratepayers. Amounts contributed to the VEBA by UGI Utilities were not material during the six months ended March 31, 2007, nor are they expected to be material for the year ending September 30, 2007.

We also sponsor unfunded and non-qualified supplemental executive retirement income plans. We recorded pre-tax expense for these plans of $0.6 and $1.1 for the three and six months ended March 31, 2007, respectively. We recorded pre-tax expense for these plans of $0.5 and $1.0 for the three and six months ended March 31, 2006, respectively.

- 14 -

UGI CORPORATION AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements
(unaudited)
(Millions of dollars and euros, except per share amounts)

Commitments and Contingencies

On August 21, 2001, AmeriGas Partners, through AmeriGas OLP, acquired the propane distribution businesses of Columbia Energy Group (the “2001 Acquisition”) pursuant to the terms of a purchase agreement (the “2001 Acquisition Agreement”) by and among Columbia Energy Group (“CEG”), Columbia Propane Corporation (“Columbia Propane”), Columbia Propane, L.P. (“CPLP”), CP Holdings, Inc. (“CPH,” and together with Columbia Propane and CPLP, the “Company Parties”), AmeriGas Partners, AmeriGas OLP and the General Partner (together with AmeriGas Partners and AmeriGas OLP, the “Buyer Parties”). As a result of the 2001 Acquisition, AmeriGas OLP acquired all of the stock of Columbia Propane and CPH and substantially all of the partnership interests of CPLP. Under the terms of an earlier acquisition agreement (the “1999 Acquisition Agreement”), the Company Parties agreed to indemnify the former general partners of National Propane Partners, L.P. (a predecessor company of the Columbia Propane businesses) and an affiliate (collectively, “National General Partners”) against certain income tax and other losses that they may sustain as a result of the 1999 acquisition by CPLP of National Propane Partners, L.P. (the “1999 Acquisition”) or the operation of the business after the 1999 Acquisition (“National Claims”). At March 31, 2007, the potential amount payable under this indemnity by the Company Parties was approximately $58. These indemnity obligations will expire on the date that CPH acquires the remaining outstanding partnership interest of CPLP, which is expected to occur on or after July 19, 2009. Under the terms of the 2001 Acquisition Agreement, CEG agreed to indemnify the Buyer Parties and the Company Parties against any losses that they sustain under the 1999 Acquisition Agreement and related agreements (“Losses”), including National Claims, to the extent such claims are based on acts or omissions of CEG or the Company Parties prior to the 2001 Acquisition. The Buyer Parties agreed to indemnify CEG against Losses, including National Claims, to the extent such claims are based on acts or omissions of the Buyer Parties or the Company Parties after the 2001 Acquisition. CEG and the Buyer Parties have agreed to apportion certain losses resulting from National Claims to the extent such losses result from the 2001 Acquisition itself.

Samuel and Brenda Swiger and their son (the “Swigers”) sustained personal injuries and property damage as a result of a fire that occurred when propane that leaked from an underground line ignited. In July 1998, the Swigers filed a class action lawsuit against AmeriGas Propane, L.P. (named incorrectly as “UGI/AmeriGas, Inc.”), in the Circuit Court of Monongalia County, West Virginia, in which they sought to recover an unspecified amount of compensatory and punitive damages and attorney’s fees, for themselves and on behalf of persons in West Virginia for whom the defendants had installed propane gas lines, allegedly resulting from the defendants’ failure to install underground propane lines at depths required by applicable safety standards. In 2003, AmeriGas OLP settled the individual personal injury and property damage claims of the Swigers. In 2004, the court granted the plaintiffs’ motion to include customers acquired from Columbia Propane in August 2001 as additional potential class members and the plaintiffs amended their complaint to name additional parties pursuant to such ruling. Subsequently, in March 2005, AmeriGas OLP filed a crossclaim against CEG, former owner of Columbia Propane, seeking indemnification for conduct undertaken by Columbia Propane prior to AmeriGas OLP’s acquisition. Class counsel has indicated that the class is seeking compensatory damages in excess of $12 plus punitive damages, civil penalties and attorneys’ fees. We believe we have good defenses to the claims of the class members and intend to defend against the remaining claims in this lawsuit.

- 15 -

UGI CORPORATION AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements
(unaudited)
(Millions of dollars and euros, except per share amounts)

From the late 1800s through the mid-1900s, UGI Utilities and its former subsidiaries owned and operated a number of manufactured gas plants (“MGPs”) prior to the general availability of natural gas. Some constituents of coal tars and other residues of the manufactured gas process are today considered hazardous substances under the Superfund Law and may be present on the sites of former MGPs. Between 1882 and 1953, UGI Utilities owned the stock of subsidiary gas companies in Pennsylvania and elsewhere and also operated the businesses of some gas companies under agreement. Pursuant to the requirements of the Public Utility Holding Company Act of 1935, UGI Utilities divested all of its utility operations other than those which now constitute UGI Gas and Electric Utility. UGI Utilities does not expect its costs for investigation and remediation of hazardous substances at Pennsylvania MGP sites to be material to its results of operations because UGI Gas is currently permitted to include in rates, through future base rate proceedings, prudently incurred remediation costs associated with such sites.

As a result of the acquisition of PG Energy by UGI Utilities’ wholly-owned subsidiary, UGIPNG, UGIPNG became party to a Multi-Site Remediation Consent Order and Agreement between PG Energy and the Pennsylvania Department of Environmental Protection dated March 31, 2004 (“Multi-Site Agreement”). The Multi-Site Agreement requires UGIPNG to perform annually a specified level of activities associated with environmental investigation and remediation work at eleven currently owned properties on which MGP-related facilities were operated (“Properties”). Under the Multi-Site Agreement, UGIPNG is not required to spend more than $1.1 in any calendar year for such environmental expenditures, including costs to perform work on the Properties. Costs related to investigation and remediation of one property formerly owned by UGIPNG are also included in this cap. The Multi-Site Agreement terminates at the end of fifteen years but may be terminated by either party at the end of any two-year period beginning with the effective date.

UGI Utilities has been notified of several sites outside Pennsylvania on which private parties allege MGPs were formerly owned or operated by it or owned or operated by its former subsidiaries. Such parties are investigating the extent of environmental contamination or performing environmental remediation. UGI Utilities is currently litigating four claims against it relating to out-of-state sites. We accrue environmental investigation and cleanup costs when it is probable that a liability exists and the amount or range of amounts can be reasonably estimated.

Management believes that under applicable law UGI Utilities should not be liable in those instances in which a former subsidiary owned or operated an MGP. There could be, however, significant future costs of an uncertain amount associated with environmental damage caused by MGPs outside Pennsylvania that UGI Utilities directly operated, or that were owned or operated by former subsidiaries of UGI Utilities, if a court were to conclude that (1) the subsidiary’s separate corporate form should be disregarded or (2) UGI Utilities should be considered to have been an operator because of its conduct with respect to its subsidiary’s MGP.

- 16 -

UGI CORPORATION AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements
(unaudited)
(Millions of dollars and euros, except per share amounts)

On September 22, 2006, South Carolina Electric & Gas Company (“SCE&G”), a subsidiary of SCANA Corporation, filed a lawsuit against UGI Utilities in the District Court of South Carolina seeking contribution from UGI Utilities for past and future remediation costs related to the operations of a former MGP located in Charleston, South Carolina. SCE&G asserts that the plant operated from 1855 to 1954 and alleges that UGI Utilities controlled operations of the plant from 1910 to 1926 and is liable for 47% of the costs associated with the site. SCE&G asserts that it has spent approximately $22 in remediation costs and $26 in third-party claims relating to the site and estimates that future remediation costs could be as high as $2.5. SCE&G further asserts that it has received a demand from the United States Justice Department for natural resource damages. UGI Utilities believes that it has good defenses to this claim and is defending the suit.

In April 2003, Citizens Communications Company (“Citizens”) served a complaint naming UGI Utilities as a third-party defendant in a civil action pending in the United States District for the District of Maine. In that action, the plaintiff, City of Bangor, Maine (“City”) sued Citizens to recover environmental response costs associated with MGP wastes generated at a plant allegedly operated by Citizens’ predecessors at a site on the Penobscot River. Citizens subsequently joined UGI Utilities and ten other third-party defendants alleging that the third-party defendants are responsible for an equitable share of costs Citizens may be required to pay to the City for cleaning up tar deposits in the Penobscot River. Citizens alleges that UGI Utilities and its predecessors owned and operated the plant from 1901 to 1928. Studies conducted by the City and Citizens suggest that it could cost up to $18 to clean up the river. Citizens’ third-party claims have been stayed pending a resolution of the City’s suit against Citizens, which was tried in September 2005. Maine’s Department of Environmental Protection (“DEP”) informed UGI Utilities in March 2005 that it considers UGI Utilities to be a potentially responsible party for costs incurred by the State of Maine related to gas plant contaminants at this site. On June 27, 2006, the court issued an order finding Citizens responsible for 60% of the cleanup costs. On February 14, 2007, Citizens and the City entered into a settlement agreement, subject to court approval, pursuant to which Citizens agreed to pay $7.6 in exchange for a release of its liabilities. UGI Utilities is evaluating what effect, if any, the settlement agreement would have on claims against it. UGI Utilities believes that it has good defenses to Citizens’ claim and to any claim that the DEP may bring to recover its costs, and is defending the Citizens’ suit.

By letter dated March 30, 1992, Atlanta Gas Light Company (“AGL”) informed UGI Utilities that it was investigating contamination that appeared to be related to MGP operations at a site owned by AGL in Savannah, Georgia. A former subsidiary of UGI Utilities operated the MGP in the early 1900s. AGL has informed UGI Utilities that it has begun remediation of MGP wastes at the site and believes that the total cost of remediation could be as high as $55. AGL has not filed suit against UGI Utilities for a share of these costs. UGI Utilities believes that it will have good defenses to any action that may arise out of this site.

On September 20, 2001, Consolidated Edison Company of New York (“ConEd”) filed suit against UGI Utilities in the United States District Court for the Southern District of New York, seeking contribution from UGI Utilities for an allocated share of response costs associated with investigating and assessing gas plant related contamination at former MGP sites in Westchester County, New York. The complaint alleges that UGI Utilities “owned and operated” the MGPs prior to 1904. The complaint also seeks a declaration that UGI Utilities is responsible for an allocated percentage of future investigative and remedial costs at the sites. ConEd believes that the cost of remediation for all of the sites could exceed $70.

- 17 -

UGI CORPORATION AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements
(unaudited)
(Millions of dollars and euros, except per share amounts)

The trial court granted UGI Utilities’ motion for summary judgment and dismissed ConEd’s complaint. The grant of summary judgment was entered April 1, 2004. ConEd appealed and on September 9, 2005 a panel of the Second Circuit Court of Appeals affirmed in part and reversed in part the decision of the trial court. The appellate panel affirmed the trial court’s decision dismissing claims that UGI Utilities was liable under CERCLA as an operator of MGPs owned and operated by its former subsidiaries. The appellate panel reversed the trial court’s decision that UGI Utilities was released from liability at three sites where UGI Utilities operated MGPs under lease. On October 7, 2005, UGI Utilities filed for reconsideration of the panel’s order, which was denied by the Second Circuit Court of Appeals on January 17, 2006. On April 14, 2006, UGI Utilities filed a petition requesting that the United States Supreme Court review the decision of the Second Circuit Court of Appeals. The Court has not yet ruled on UGI Utilities’ petition. On April 23, 2007, the Supreme Court heard argument in another company’s case raising substantially the same issues presented in UGI Utilities’ petition and has not yet ruled in that case.

By letter dated June 24, 2004, KeySpan Energy (“KeySpan”) informed UGI Utilities that KeySpan has spent $2.3 and expects to spend another $11 to clean up an MGP site it owns in Sag Harbor, New York. KeySpan believes that UGI Utilities is responsible for approximately 50% of these costs as a result of UGI Utilities’ alleged direct ownership and operation of the plant from 1885 to 1902. By letter dated June 6, 2006, KeySpan reported that the New York Department of Environmental Conservation has approved a remedy for the site that is estimated to cost approximately $10. KeySpan believes that the cost could be as high as $20. UGI Utilities is in the process of reviewing the information provided by KeySpan and is investigating this claim.

On September 11, 2006, UGI Utilities received a complaint filed by Yankee Gas Services Company and Connecticut Light and Power Company, subsidiaries of Northeast Utilities, (together the “Northeast Companies”) in the United States District Court for the District of Connecticut seeking contribution from UGI Utilities for past and future remediation costs related to MGP operations on thirteen sites owned by the Northeast Companies in nine cities in the State of Connecticut. The Northeast Companies allege that UGI Utilities controlled operations of the plants from 1883 to 1941. The Northeast Companies estimated that remediation costs for all of the sites would total approximately $215 and asserted that UGI Utilities is responsible for approximately $103 of this amount. Based on information supplied by the Northeast Companies and UGI Utilities’ own investigation, UGI Utilities believes that it may have operated one of the sites, Waterbury North, under lease for a portion of its operating history. UGI Utilities is reviewing the Northeast Companies’ estimate that remediation costs at Waterbury North could total $23. UGI Utilities believes that it has good defenses to this claim and is defending the suit.

The French tax authorities levy taxes on legal entities and individuals regularly operating a business in France which are commonly referred to collectively as “business tax.” The amount of business tax charged annually is generally dependent upon the value of certain of the entity’s tangible fixed assets. Changes in the French government’s interpretation of the tax laws or in the tax laws themselves could either adversely or favorably affect our results of operations.

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UGI CORPORATION AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements
(unaudited)
(Millions of dollars and euros, except per share amounts)

In addition to these matters, there are other pending claims and legal actions arising in the normal course of our businesses. We cannot predict with certainty the final results of environmental and other matters. However, it is reasonably possible that some of them could be resolved unfavorably to us and result in losses in excess of recorded amounts. We are unable to estimate any such excess losses. Although we currently believe, after consultation with counsel, that damages or settlements, if any, recovered by the plaintiffs in such claims or actions will not have a material adverse effect on our financial position, damages or settlements could be material to our operating results or cash flows in future periods depending on the nature and timing of future developments with respect to these matters and the amounts of future operating results and cash flows.

10.

AmeriGas Partners’ Pending Sale of Arizona Storage Facility

In February 2007, AmeriGas Partners signed a definitive agreement with Plains LPG Services, L.P. to sell its 3.5 million barrel liquefied petroleum gas storage terminal located near Phoenix, AZ for approximately $52. The transaction is expected to close before the end of our fiscal quarter ending June 30, 2007. UGI expects to realize an after-tax gain on this sale of approximately $11 to $12.

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UGI CORPORATION AND SUBSIDIARIES

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS

Forward-Looking Statements

Information contained in this Management’s Discussion and Analysis of Financial Condition and Results of Operations may contain forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. Such statements use forward-looking words such as “believe,” “plan,” “anticipate,” “continue,” “estimate,” “expect,” “may,” “will,” or other similar words. These statements discuss plans, strategies, events or developments that we expect or anticipate will or may occur in the future.

A forward-looking statement may include a statement of the assumptions or bases underlying the forward-looking statement. We believe that we have chosen these assumptions or bases in good faith and that they are reasonable. However, we caution you that actual results almost always vary from assumed facts or bases, and the differences between actual results and assumed facts or bases can be material, depending on the circumstances. When considering forward-looking statements, you should keep in mind the following important factors which could affect our future results and could cause those results to differ materially from those expressed in our forward-looking statements: (1) adverse weather conditions resulting in reduced demand; (2) cost volatility and availability of propane and other LPG, oil, electricity and natural gas and the capacity to transport product to our market areas; (3) changes in domestic and foreign laws and regulations, including safety, tax and accounting matters; (4) the impact of pending and future legal proceedings; (5) competitive pressures from the same and alternative energy sources; (6) failure to acquire new customers thereby reducing or limiting any increase in revenues; (7) liability for environmental claims; (8) increased customer conservation measures due to high energy prices and improvements in energy efficiency and technology resulting in reduced demand; (9) adverse labor relations; (10) large customer, counterparty or supplier defaults; (11) liability in excess of insurance coverage for personal injury and property damage arising from explosions and other catastrophic events, including acts of terrorism, resulting from operating hazards and risks incidental to generating and distributing electricity and transporting, storing and distributing natural gas, propane and other LPG; (12) political, regulatory and economic conditions in the United States and in foreign countries, including foreign currency rate fluctuations, particularly in the euro; (13) reduced access to capital markets and interest rate fluctuations; (14) reduced distributions from subsidiaries; and (15) the timing and success of the Company’s efforts to develop new business opportunities.

These factors are not necessarily all of the important factors that could cause actual results to differ materially from those expressed in any of our forward-looking statements. Other unknown or unpredictable factors could also have material adverse effects on future results. We undertake no obligation to update publicly any forward-looking statement whether as a result of new information or future events except as required by the federal securities laws.

ANALYSIS OF RESULTS OF OPERATIONS

The following analyses compare our results of operations for (1) the three months ended March 31, 2007 (“2007 three-month period”) with the three months ended March 31, 2006 (“2006 three-month period”) and (2) the six months ended March 31, 2007 (“2007 six-month period”) with the six months ended March 31, 2006 (“2006 six-month period”). Our analyses of results of operations should be read in conjunction with the segment information included in Note 4 to the Condensed Consolidated Financial Statements.

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UGI CORPORATION AND SUBSIDIARIES

Executive Overview

Because most of our businesses sell energy products used in large part for heating purposes, our Company’s results are largely seasonal and dependent upon weather conditions, particularly during the peak-heating season months of November through March. As a result, our net income is generally highest in our first and second fiscal quarters. In addition to the effects of weather conditions, our volumes can reflect customers’ responses to volatile and increasing commodity prices resulting in customer conservation. Our 2007 results include the operations of PNG Gas, the natural gas utility business that we acquired in late August 2006 (the “PG Energy Acquisition”).

During the first three months of the 2007 six-month period, temperatures within each of our business units’ service territories were significantly warmer than normal and were much warmer than in the prior year. However, during the second half of the 2007 six-month period, domestic temperatures returned to a more normal level resulting in colder weather than in the prior year. Our international operations faced temperatures significantly warmer than normal and the prior year throughout the entire 2007 six-month period. Despite the challenges of much warmer heating season weather in our international businesses and during the first half of our domestic heating season, net income during the 2007 six-month period increased approximately 13% compared to the 2006 six-month period. The increase in earnings primarily reflects incremental Gas Utility income principally resulting from the PG Energy Acquisition and higher income contributed by AmeriGas Propane and Electric Utility. These increases were partially offset by decreased earnings from International Propane and lower interest income because cash and investments were used to fund a portion of the PG Energy Acquisition in August 2006. Energy Services’ results for the prior-year periods include a $5.3 million after-tax gain from the March 2006 sale of its 50% ownership in Hunlock Creek Energy Ventures (“Energy Ventures”). AmeriGas Propane’s results during the 2006 six-month period include an approximate $4.6 million after-tax loss on extinguishment of debt related to January 2006 refinancings.

Net income by business unit:


	Three Months Ended						Six Months Ended
	March 31,						March 31,
	2007			2006			2007			2006
Net income (loss):	(millions of dollars)						(millions of dollars)
AmeriGas Propane (a)	$	32.3		$	21.2		$	47.7		$	36.1
International Propane		34.8			45.0			53.1			59.9
Gas Utility		41.0			21.5			57.5			39.9
Electric Utility		3.6			1.5			6.8			5.0
Energy Services		10.3			15.4			19.3			20.3
Corporate & Other		(1.8	)		(0.6	)		(2.3	)		0.3

Total net income	$	120.2		$	104.0		$	182.1		$	161.5


(a)		Amounts are net of minority interests in AmeriGas Partners, L.P.

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UGI CORPORATION AND SUBSIDIARIES

2007 three-month period compared to the 2006 three-month period

AmeriGas Propane:


For the three months ended March 31,	2007			2006			Increase
(Millions of dollars)
Revenues	$	809.8		$	718.2		$	91.6	12.8	%
Total margin (a)	$	309.5		$	270.9		$	38.6	14.2	%
Partnership EBITDA (b)	$	156.4		$	116.2		$	40.2	34.6	%
Operating income	$	139.2		$	116.3		$	22.9	19.7	%
Retail gallons sold (millions)		370.1			341.4			28.7	8.4	%
Degree days — % warmer than normal (c)		3.7	%		12.1	%		—	—


(a)		Total margin represents total revenues less total cost of sales.

(b)		Partnership EBITDA (earnings before interest expense, income taxes and depreciation and amortization) should not be considered as an alternative to net income (as an indicator of operating performance) or as an alternative to cash flow (as a measure of liquidity or ability to service debt obligations) and is not a measure of performance or financial condition under accounting principles generally accepted in the United States of America. Management uses Partnership EBITDA as the primary measure of segment profitability for the AmeriGas Propane segment (see Note 4 to the Condensed Consolidated Financial Statements).

(c)		Deviation from average heating degree-days based upon national weather statistics provided by the National Oceanic and Atmospheric Administration (“NOAA”) for 335 airports in the United States, excluding Alaska.

Based upon heating degree-day data, temperatures were 3.7% warmer than normal in the 2007 three-month period compared to 12.1% warmer than normal in the prior-year period. Retail propane volumes sold increased approximately 8% principally due to the colder weather.

Retail propane revenues increased $86.1 million reflecting a $53.0 million increase due to the higher retail volumes sold and a $33.1 million increase due to higher average selling prices. Wholesale propane revenues in the 2007 three-month period were comparable with the 2006 three-month period. Total cost of sales increased to $500.3 million in the 2007 three-month period from $447.3 million in the 2006 three-month period, primarily reflecting the increased volumes sold and an increase in propane product costs. Total margin increased $38.6 million compared to the 2006 three-month period principally due to the higher retail propane gallons sold at higher average retail margins per gallon.

Partnership EBITDA during the 2007 three-month period was $156.4 million compared to $116.2 million during the 2006 three-month period. The $40.2 million increase in Partnership EBITDA mainly reflects the increase in total margin and the absence of a $17.1 million loss on extinguishment of debt partially offset by increases in operating and administrative expenses. Operating and administrative expenses increased $14.1 million principally reflecting higher employee compensation and benefits expenses, higher repair and maintenance expenses and increased vehicle costs.

Operating income increased $22.9 million reflecting the increase in Partnership EBITDA excluding the impact of the absence of the prior period’s $17.1 million loss on extinguishment of debt which is included in Partnership EBITDA but is excluded from operating income.

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International Propane:


For the three months ended March 31,	2007		2006		(Decrease)
(Millions of euros)
Revenues	€	214.6	€	318.0	€	(103.4	)	(32.5	)%
Total margin (a)	€	109.0	€	134.0	€	(25.0	)	(18.7	)%
Operating income	€	45.2	€	63.7	€	(18.5	)	(29.0	)%
Income before income taxes	€	39.5	€	57.3	€	(17.8	)	(31.1	)%

(Millions of dollars)
Revenues	$	282.8	$	382.1	$	(99.3	)	(26.0	)%
Total margin (a)	$	143.6	$	161.1	$	(17.5	)	(10.9	)%
Operating income	$	59.0	$	76.5	$	(17.5	)	(22.9	)%
Income before income taxes	$	51.1	$	68.5	$	(17.4	)	(25.4	)%

Antargaz retail gallons sold		95.0		125.4		(30.4	)	(24.2	)%


(a)		Total margin represents total revenues less total cost of sales.

Based upon heating degree day data, temperatures in Antargaz’ service territory were approximately 15.5% warmer than normal in the 2007 three-month period compared to temperatures that were approximately 6.5% colder than normal in the 2006 three-month period. Flaga experienced similar weather across its service territories. The monthly average currency translation rate was $1.32 per euro during the 2007 three-month period versus $1.20 per euro during the 2006 three-month period. Antargaz’ retail LPG volumes sold decreased to 95.0 million gallons in the 2007 three-month period from 125.4 million gallons in the 2006 three-month period. The decrease in Antargaz’ retail volumes sold was experienced across all of Antargaz’ classes of customers and was due in large part to the significantly warmer than normal weather and, to a much lesser extent, customer conservation. Flaga’s volumes declined largely reflecting the absence of volumes from its Czech Republic and Slovakia businesses that it contributed to Zentraleuropa LPG Holding GmbH (“ZLH”), its joint venture with a subsidiary of Progas GmbH & Co. KG, and the effects of the significantly warmer weather. The ZLH joint venture was formed in February 2006 and Flaga’s 50% ownership interest in ZLH is accounted for under the equity method.

International Propane euro-based revenues decreased during the 2007 three-month period primarily reflecting (1) a decline of approximately €62 million principally due to Antargaz’ lower retail volumes sold at slightly lower LPG prices, (2) approximately €20 million in lower revenues from Antargaz’ low-margin wholesale sales, (3) the absence of revenues from Flaga’s Czech Republic and Slovakia businesses that were contributed to ZLH, and (4) lower volumes sold in Flaga’s Austrian business largely due to the significantly warmer weather. International Propane’s total cost of sales decreased to approximately €106 million in the 2007 three-month period from €184 million in the 2006 three-month period principally reflecting the effects of the lower retail volumes sold and lower average LPG product costs, including the absence of costs of sales from Flaga’s operations that had been contributed to ZLH. Antargaz’ LPG purchases are principally denominated in U.S. dollars.

Total margin decreased €25.0 million in the 2007 three-month period reflecting the lower retail volumes sold partially offset by higher average margins per retail gallon of LPG sold. In U.S. dollars, total margin decreased $17.5 million reflecting the decrease in base-currency total margin which was partially offset by the beneficial effects of the stronger euro versus the dollar.

The €18.5 million decline in International Propane operating income largely reflects the lower total margin partially offset by decreased operating and administrative expenses. The decrease in operating and administrative expenses is attributable to lower vehicle fuel and lease and employee compensation and benefits expenses and lower expenses at Flaga partially offset by higher maintenance and repairs expense. The decrease in income before income taxes largely reflects the decline in operating income.

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UGI CORPORATION AND SUBSIDIARIES

Gas Utility:


For the three months ended March 31,	2007			2006			Increase
(Millions of dollars)
Revenues	$	459.0		$	296.2		$	162.8	55.0	%
Total margin (a)	$	124.8		$	73.2		$	51.6	70.5	%
Operating income	$	78.0		$	39.9		$	38.1	95.5	%
Income before income taxes	$	67.6		$	35.3		$	32.3	91.5	%
System throughput — billions of cubic feet (“bcf”)		49.8			27.1			22.7	83.8	%
Degree days — % colder (warmer) than normal (b)		1.4	%		(13.0	)%		—	—


(a)		Total margin represents total revenues less total cost of sales.

(b)		Deviation from average heating degree days based upon weather statistics provided by the National Oceanic and Atmospheric Administration (“NOAA”) at airports located within our service territory.

Temperatures in Gas Utility’s service territory based upon heating degree days were 1.4% colder than normal during the 2007 three-month period compared to 13.0% warmer than normal in the prior-year three-month period. Total distribution system throughput increased 22.7 bcf reflecting an 18.7 bcf increase from PNG Gas and a 4.0 bcf increase in UGI Gas distribution system throughput due to the colder weather.

Gas Utility revenues increased $162.8 million during the 2007 three-month period principally reflecting approximately $147.4 million in revenues attributable to PNG Gas, an $8.4 million increase in revenues from low-margin off-system sales, and greater revenues from sales to UGI Gas’ firm- residential, commercial and industrial (“retail core-market”) customers. Increases or decreases in retail core-market customer revenues and cost of sales principally result from changes in retail core-market volumes and the level of gas costs collected through the PGC recovery mechanism. Under this recovery mechanism, Gas Utility records the cost of gas associated with sales to retail core-market customers at amounts included in PGC rates. The difference between actual gas costs and the amount included in rates is deferred on the balance sheet as a regulatory asset or liability and represents amounts to be collected from or refunded to customers in a future period. As a result of this PGC recovery mechanism, increases or decreases in the cost of gas associated with retail core-market customers have no direct effect on retail core-market margin. Gas Utility’s cost of gas was $334.2 million in the 2007 three-month period compared to $223.0 million in the 2006 three-month period largely reflecting PNG Gas’ cost of gas and greater costs associated with the higher off-system sales.

Gas Utility total margin in the 2007 three-month period increased $51.6 million primarily reflecting margin from PNG Gas and a $10.5 million increase in UGI Gas margin due to the higher distribution system throughput.

Gas Utility operating income increased to $78.0 million in the 2007 three-month period from $39.9 million in the 2006 three-month period principally reflecting the $51.6 million increase in total margin and an increase in other income partially offset by an $11.8 million increase in operating and administrative expenses and $4.2 million of higher depreciation and amortization expense. The increase in total operating and administrative expenses reflects operating and administrative expenses attributable to PNG Gas and a decrease of $1.5 million in UGI Gas’ expenses. The increase in depreciation and amortization expense is largely attributable to PNG Gas and, to a lesser extent, capital expenditures associated with UGI Gas.

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UGI CORPORATION AND SUBSIDIARIES

The increase in Gas Utility income before income taxes reflects the higher operating income partially offset by a $5.8 million increase in interest expense. The increase in interest expense is principally due to higher long- and short-term debt outstanding, primarily a result of the PG Energy Acquisition, and higher short-term interest rates.

Electric Utility:


For the three months ended March 31,	2007		2006		Increase
(Millions of dollars)
Revenues	$	34.9	$	25.4	$	9.5	37.4	%
Total margin (a)	$	12.1	$	8.8	$	3.3	37.5	%
Operating income	$	6.7	$	3.3	$	3.4	103.0	%
Income before income taxes	$	6.1	$	2.5	$	3.6	144.0	%
Distribution sales — millions of kilowatt hours (“gwh”)		281.9		268.4		13.5	5.0	%


(a)		Total margin represents total revenues less total cost of sales and revenue-related taxes, i.e. Electric Utility gross receipts taxes, of $2.0 million and $1.4 million during the three-month periods ended March 31, 2007 and 2006, respectively. For financial statement purposes, revenue-related taxes are included in “Utility taxes other than income taxes” on the Condensed Consolidated Statements of Income.

Electric Utility’s 2007 three-month period kilowatt-hour sales were 5.0% higher than in the prior-year period which is largely attributable to approximately 3% colder than normal temperatures compared to 9% warmer than normal temperatures in the prior-year period (based upon heating degree day statistics). Electric Utility revenues increased $9.5 million in the 2007 three-month period largely reflecting the effects of an increase in its Provider of Last Resort (“POLR”) rates effective January 1, 2007 and the significantly colder temperatures than in the prior year. Electric Utility’s cost of sales increased to $20.8 million in the 2007 three-month period from $15.2 million in the 2006 three-month period reflecting higher per unit purchased power costs and the higher kilowatt-hour sales.

Electric Utility total margin in the 2007 three-month period increased $3.3 million reflecting the effects of the higher POLR rates and the higher sales partially offset by the higher per unit purchased power costs.

The increase in Electric Utility operating income and income before income taxes in the 2007 three-month period principally reflects the increase in total margin.

Energy Services:


					Increase
For the three months ended March 31,	2007		2006		(Decrease)
(Millions of dollars)
Revenues	$	444.9	$	438.8	$	6.1		1.4	%
Total margin (a)	$	28.5	$	27.4	$	1.1		4.0	%
Operating income	$	17.4	$	26.1	$	(8.7	)	(33.3	)%
Income before income taxes	$	17.4	$	26.1	$	(8.7	)	(33.3	)%


(a)		Total margin represents total revenues less total cost of sales.

Energy Services revenues increased slightly to $444.9 million in the 2007 three-month period from $438.8 million in the 2006 three-month period principally reflecting greater electric generation sales, a 12% increase in natural gas volumes sold partially offset by an approximate 18% decline in natural gas prices.

Total margin increased $1.1 million in the 2007 three-month period compared to the prior-year three-month period. The increase in total margin is primarily attributable to improved results from peaking supply and storage management activities and, to a lesser extent, the increase in natural gas volumes sold.

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UGI CORPORATION AND SUBSIDIARIES

The decrease in Energy Services operating income and income before income taxes principally reflects the absence of a $9.1 million gain on the March 2006 sale of its 50% ownership interest in Energy Ventures.

2007 six-month period compared to the 2006 six-month period

AmeriGas Propane:


For the six months ended March 31,	2007			2006			Increase
(Millions of dollars)
Revenues	$	1,426.4		$	1,348.4		$	78.0	5.8	%
Total margin (a)	$	537.4		$	493.3		$	44.1	8.9	%
Partnership EBITDA (b)	$	249.5		$	208.4		$	41.1	19.7	%
Operating income	$	214.5		$	191.0		$	23.5	12.3	%
Retail gallons sold (millions)		653.0			633.3			19.7	3.1	%
Degree days — % warmer than normal (c)		5.8	%		8.7	%		—	—


(a)		Total margin represents total revenues less total cost of sales.

(b)		Partnership EBITDA (earnings before interest expense, income taxes and depreciation and amortization) should not be considered as an alternative to net income (as an indicator of operating performance) or as an alternative to cash flow (as a measure of liquidity or ability to service debt obligations) and is not a measure of performance or financial condition under accounting principles generally accepted in the United States of America. Management uses Partnership EBITDA as the primary measure of segment profitability for the AmeriGas Propane segment (see Note 4 to the Condensed Consolidated Financial Statements).

(c)		Deviation from average heating degree-days based upon national weather statistics provided by the National Oceanic and Atmospheric Administration (“NOAA”) for 335 airports in the United States, excluding Alaska.

Based upon heating degree-day data, temperatures in the 2007 six-month period were 5.8% warmer than normal and 3.1% colder than the prior-year period. Retail propane volumes sold increased approximately 3% primarily reflecting greater demand attributable to the colder weather.

Retail propane revenues increased $74.3 million reflecting a $37.8 million increase due to higher average selling prices and $36.5 million due to the higher volumes sold. Wholesale propane revenues decreased $6.4 million reflecting a $5.9 million decrease due to lower wholesale volumes sold and a slight decrease resulting from lower average selling prices. Total cost of sales increased to $889.0 million in the 2007 six-month period from $855.1 million in the 2006 six-month period, primarily reflecting the increased volumes sold and an increase in propane product costs. Total margin increased $44.1 million compared to the 2006 six-month period principally due to higher average propane margins per gallon, higher volumes sold and, to a much lesser extent, higher fees in response to increases in operating and administrative expenses. Our total margin also benefited from higher sales resulting from customer growth in the AmeriGas cylinder exchange program.

Partnership EBITDA during the 2007 six-month period was $249.5 million compared to $208.4 million during the 2006 six-month period. The $41.1 million increase in Partnership EBITDA mainly reflects the increase in total margin and the absence of the $17.1 million loss on extinguishment of debt partially offset by a $19.1 million increase in operating and administrative expenses. Operating and administrative expenses increased principally due to higher employee compensation and benefits expenses, higher repair and maintenance expenses and increased vehicle costs.

Operating income increased $23.5 million reflecting the previously mentioned increase in Partnership EBITDA excluding the impact of the prior period’s $17.1 million loss on extinguishment of debt which is included in Partnership EBITDA but excluded from operating income.

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UGI CORPORATION AND SUBSIDIARIES

International Propane:


For the six months ended March 31,	2007		2006		(Decrease)
(Millions of euros)
Revenues	€	388.6	€	543.0	€	(154.4	)	(28.4	)%
Total margin (a)	€	197.8	€	225.3	€	(27.5	)	(12.2	)%
Operating income	€	71.1	€	92.0	€	(20.9	)	(22.7	)%
Income before income taxes	€	60.8	€	78.5	€	(17.7	)	(22.5	)%

(Millions of dollars)
Revenues	$	509.2	$	649.7	$	(140.5	)	(21.6	)%
Total margin (a)	$	259.1	$	269.6	$	(10.5	)	(3.9	)%
Operating income	$	92.1	$	110.1	$	(18.0	)	(16.3	)%
Income before income taxes	$	78.1	$	93.5	$	(15.4	)	(16.5	)%

Antargaz retail gallons sold		175.2		218.1		(42.9	)	(19.7	)%


(a)		Total margin represents total revenues less total cost of sales.

Based upon heating degree day data, temperatures in Antargaz’ service territory were approximately 18.3% warmer than normal in the 2007 six-month period compared to temperatures that were approximately 3.3% colder than normal in the 2006 six-month period. Flaga experienced similar weather across its service territories. The monthly average currency translation rate was $1.31 per euro during the 2007 six-month period versus $1.20 per euro during the 2006 six-month period. Antargaz’ retail LPG volumes sold decreased to 175.2 million gallons in the 2007 six-month period from 218.1 million gallons in the 2006 six-month period. The decrease in Antargaz’ retail volumes sold was experienced across all of Antargaz’ classes of customers and was due in large part to the significantly warmer weather and, to a much lesser extent, customer conservation. Flaga’s volumes declined reflecting the absence of volumes from its Czech Republic and Slovakia businesses that it contributed to ZLH and the effects of the significantly warmer weather.

International Propane euro-based revenues decreased during the 2007 six-month period primarily reflecting (1) a decline of approximately €78 million principally due to Antargaz’ lower retail volumes sold, (2) approximately €41 million in lower revenues from Antargaz’ low-margin wholesale sales and (3) lower ancillary sales and services and, to a much lesser extent, (4) the absence of revenues from Flaga’s Czech Republic and Slovakia businesses that were contributed to ZLH. International Propane’s total cost of sales decreased to approximately €190.8 million in the 2007 six-month period from €317.7 million in the 2006 six-month period largely reflecting the effects of the lower retail volumes sold, lower LPG product costs and, the decline in low-margin wholesale sales.

Total margin decreased €27.5 million in the 2007 six-month period largely reflecting the lower retail volumes sold partially offset by higher margin on ancillary sales and services and higher average margins per retail gallon of LPG sold. In U.S. dollars, total margin declined $10.5 million reflecting the beneficial effects of the stronger euro versus the dollar.

International Propane operating income declined €20.9 million principally reflecting the lower total margin partially offset by a €7.6 million decrease in operating and administrative expenses and slightly lower depreciation and amortization partially offset by a decrease in other income of approximately €1.2 million. The decrease in operating and administrative expenses is largely the result of (1) decreases in Antargaz’ contracted labor and employee compensation and benefits expenses partially offset by increased repair and maintenance expenses, and (2) decreases in Flaga’s expenses.

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UGI CORPORATION AND SUBSIDIARIES

The decrease in income before income taxes principally reflects the decrease in operating income partially offset by lower interest expense and the absence of a loss on extinguishment of debt related to Antargaz’ refinancing of its High Yield Bonds in January 2006.

Gas Utility:


For the six months ended March 31,	2007			2006			Increase
(Millions of dollars)
Revenues	$	733.4		$	516.0		$	217.4	42.1	%
Total margin (a)	$	205.4		$	133.1		$	72.3	54.3	%
Operating income	$	116.2		$	75.6		$	40.6	53.7	%
Income before income taxes	$	95.0		$	65.9		$	29.1	44.2	%
System throughput - billions of cubic feet (“bcf”)		83.2			50.1			33.1	66.1	%
Degree days — % warmer than normal (b)		5.4	%		8.2	%		—	—


(a)		Total margin represents total revenues less total cost of sales.

(b)		Deviation from average heating degree days based upon weather statistics provided by the National Oceanic and Atmospheric Administration (“NOAA”) at airports located within our service territory.

Temperatures in Gas Utility’s service territory based upon heating degree days were 5.4% warmer than normal during the 2007 six-month period compared to 8.2% warmer than normal during the prior-year six-month period. Total distribution system throughput increased 33.1 bcf reflecting 30.9 bcf from PNG Gas and greater UGI Gas distribution system throughput. UGI Gas’ greater distribution system throughput reflects increased sales to both retail core-market and delivery service customers.

Gas Utility revenues increased $217.4 million during the 2007 six-month period principally reflecting revenues attributable to PNG Gas and an $18.1 million increase in revenues from low-margin off-system sales. These increases were partially offset by lower revenues from UGI Gas retail core-market customers as a result of lower average PGC rates. Gas Utility’s cost of gas was $528.0 million in the 2007 six-month period compared to $382.9 million in the 2006 six-month period largely reflecting the effects of the PG Energy Acquisition and greater costs associated with the higher off-system sales partially offset by the lower average PGC rates.

Gas Utility total margin in the 2007 six-month period increased $72.3 million primarily reflecting margin resulting from the PG Energy Acquisition and a $6.4 million increase in UGI Gas margin.

Gas Utility operating income increased to $116.2 million in the 2007 six-month period from $75.6 million in the 2006 six-month period principally reflecting the $72.3 million increase in total margin and slightly higher other income partially offset by a $25.7 million increase in operating and administrative expenses and $8.0 million higher depreciation and amortization expense. The increase in total operating and administrative expenses principally reflects $23.5 million of incremental operating and administrative expenses attributable to PNG Gas and, to a much lesser extent, higher UGI Gas operating and administrative expenses. The higher depreciation and amortization expense primarily reflects depreciation expense associated with PNG Gas.

The increase in Gas Utility income before income taxes reflects the higher operating income partially offset by an increase of $11.5 million in interest expense. The increase in interest expense is principally due to higher long- and short-term debt outstanding, primarily as a result of the PG Energy Acquisition, and higher short-term interest rates.

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UGI CORPORATION AND SUBSIDIARIES

Electric Utility:


For the six months ended March 31,	2007		2006		Increase
(Millions of dollars)
Revenues	$	59.8	$	49.3	$	10.5	21.3	%
Total margin (a)	$	23.5	$	20.1	$	3.4	16.9	%
Operating income	$	12.9	$	9.8	$	3.1	31.6	%
Income before income taxes	$	11.6	$	8.5	$	3.1	36.5	%
Distribution sales — millions of kilowatt hours (“gwh”)		530.9		526.4		4.5	0.9	%


(a)		Total margin represents total revenues less total cost of sales and revenue-related taxes, i.e. Electric Utility gross receipts taxes, of $3.3 million and $2.7 million during the six-month periods ended March 31, 2007 and 2006, respectively. For financial statement purposes, revenue-related taxes are included in “Utility taxes other than income taxes” on the Condensed Consolidated Statements of Income.

Electric Utility’s 2007 six-month period kilowatt-hour sales increased approximately 1% compared to the 2006 six-month period. Electric Utility revenues increased $10.5 million in the 2007 six-month period largely reflecting the effects of the increased POLR rates effective January 1, 2007 and, to a lesser extent, the increased sales. Electric Utility’s cost of sales increased to $33.0 million in the 2007 six-month period from $26.5 million in the 2006 six-month period reflecting higher per unit purchased power costs.

Electric Utility total margin increased $3.4 million during the 2007 six-month period reflecting the effects of the higher POLR rates and, to a lesser extent, the increased sales partially offset by the higher per unit purchased power costs.

Electric Utility operating income and income before income taxes increased in the 2007 six-month period principally reflecting the increase in total margin partially offset by a slight increase in operating and administrative expenses.

Energy Services:


					Increase
For the six months ended March 31,	2007		2006		(Decrease)
(Millions of dollars)
Revenues	$	789.1	$	890.2	$	(101.1	)	(11.4	)%
Total margin (a)	$	54.0	$	45.1	$	8.9		19.7	%
Operating income	$	32.6	$	34.3	$	(1.7	)	(5.0	)%
Income before income taxes	$	32.6	$	34.3	$	(1.7	)	(5.0	)%

(a)

Total margin represents total revenues less total cost of sales.

Notwithstanding the effects of a 16% increase in natural gas volumes sold and a 15% increase in kilowatt hour sales, Energy Services revenues decreased to $789.1 million in the 2007 six-month period from $890.2 million in the 2006 six-month period principally reflecting a more than 25% decline in natural gas prices.

Total margin increased $8.9 million in the 2007 six-month period compared to the prior-year six-month period. The increase in total margin is primarily attributable to higher natural gas unit margins, improved results from peaking supply and storage management activities and, to a lesser extent, the increase in natural gas volumes sold.

The decrease in Energy Services operating income and income before income taxes principally reflects the $9.1 million gain on the sale of Energy Ventures that was recorded in the prior-year six-month period.

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UGI CORPORATION AND SUBSIDIARIES

FINANCIAL CONDITION AND LIQUIDITY

Financial Condition

Our cash, cash equivalents and short-term investments totaled $210.4 million at March 31, 2007 compared with $201.0 million at September 30, 2006. Excluding cash, cash equivalents and short-term investments that reside at UGI’s operating subsidiaries at March 31, 2007 and September 30, 2006, we had $14.6 million and $16.6 million, respectively, of cash, cash equivalents and short-term investments.

The Company’s long-term debt outstanding at March 31, 2007 totaled $2,020.2 million (including current maturities of $34.5 million) compared to $1,996.9 million of long-term debt (including current maturities of $31.9 million) at September 30, 2006.

AmeriGas OLP’s Credit Agreement expires in October 2011 and consists of (1) a $125 million Revolving Credit Facility and (2) a $75 million Acquisition Facility. The Revolving Credit Facility may be used for working capital and general purposes of AmeriGas OLP. The Acquisition Facility provides AmeriGas OLP with the ability to borrow up to $75 million to finance the purchase of propane businesses or propane business assets or, to the extent it is not so used, for working capital and general purposes. AmeriGas OLP’s short-term borrowing needs are seasonal and are typically greatest during the fall and winter heating-season months due to the need to fund higher levels of working capital. At March 31, 2007, there were no borrowings outstanding under the Credit Agreement. Issued and outstanding letters of credit under the Revolving Credit Facility, which reduce the amount available for borrowings, totaled $58.0 million at March 31, 2007 and was approximately the same amount outstanding during the entire six-month period. Issued and outstanding letters of credit under the Revolving Credit Facility totaled $58.9 million at March 31, 2006 and was approximately the same amount outstanding during the entire six-month period. The average daily and peak bank loan borrowings outstanding under the Credit Agreement were $2.4 million and $92.0 million, respectively, during the 2007 six-month period. There were no significant borrowings under the Credit Agreement during the 2006 six-month period. AmeriGas Partners has an effective unallocated debt and equity shelf registration statement with the U.S. Securities and Exchange Commission (“SEC”) under which it may issue Common Units or Senior Notes due 2016 in underwritten public offerings.

UGI Utilities has a $350 million Revolving Credit Agreement which expires in August 2011. At March 31, 2007, UGI Utilities had $146.0 million in borrowings outstanding under its Revolving Credit Agreement. From time to time, UGI Utilities has entered into short-term borrowings under uncommitted arrangements with major banks in order to meet liquidity needs. Short-term borrowings, including borrowings under its Revolving Credit Agreement, are classified as bank loans on the Condensed Consolidated Balance Sheets. During the 2007 and 2006 six-month periods, average daily bank loan borrowings were $214.6 million and $119.8 million, respectively, and peak bank loan borrowings totaled $259.0 million and $175.9 million, respectively. Peak borrowings typically occur during the peak heating season months of December and January. The increase in average and peak bank loan borrowings during the 2007 six-month period principally reflects borrowings to fund the working capital of PNG Gas. UGI Utilities also has an effective shelf registration statement with the SEC under which it may issue up to an additional $75 million of Medium-Term Notes or other debt securities. Medium-Term Notes of $20 million maturing in June 2007 are expected to be refinanced through the issuance of debt under this shelf registration.

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UGI CORPORATION AND SUBSIDIARIES

Energy Services has a receivables purchase facility (“Receivables Facility”) with an issuer of receivables-backed commercial paper expiring in April 2009. The maximum level of funding available at any one time from this facility is $200 million. Under the Receivables Facility, Energy Services transfers, on an ongoing basis and without recourse, its trade accounts receivable to its wholly owned, special purpose subsidiary, Energy Services Funding Corporation (“ESFC”), which is consolidated for financial statement purposes. ESFC, in turn, has sold, and subject to certain conditions, may from time to time sell, an undivided interest in some or all of the receivables to a commercial paper conduit of a major bank. ESFC was created and has been structured to isolate its assets from creditors of Energy Services and its affiliates, including UGI. This two-step transaction is accounted for as a sale of receivables following the provisions of Statement of Financial Accounting Standards (“SFAS”) No. 140, “Accounting for Transfers and Servicing of Financial Assets and Extinguishments of Liabilities.” Energy Services continues to service, administer and collect trade receivables on behalf of the commercial paper issuer and ESFC. During the six months ended March 31, 2007 and 2006, Energy Services sold trade receivables totaling $707.6 million and $810.3 million, respectively, to ESFC. During the six months ended March 31, 2007 and 2006, ESFC sold an aggregate $217.0 million and $543.5 million, respectively, of undivided interests in its trade receivables to the commercial paper conduit. At March 31, 2007, the outstanding balance of ESFC receivables was $118.4 million which is net of $32.0 million that was sold to the commercial paper conduit. At March 31, 2006, the outstanding balance of ESFC receivables was $56.5 million which is net of $75.6 million that was sold to the commercial paper conduit.

In addition, a major bank has committed to issue up to $50 million of standby letters of credit, secured by cash or marketable securities (“LC Facility”) to Energy Services. At March 31, 2007, there were no letters of credit outstanding. Energy Services expects to fund the collateral requirements with borrowings under its Receivables Facility. The LC Facility expires in April 2008.

Cash Flows

Operating Activities. Due to the seasonal nature of the Company’s businesses, cash flows from operating activities are generally strongest during the second and third fiscal quarters when customers pay for natural gas, LPG, electricity and other energy products consumed during the heating season months. Conversely, operating cash flows are generally at their lowest levels during the first and fourth fiscal quarters when the Company’s investment in working capital, principally accounts receivable and/or inventories, is generally greatest. AmeriGas Propane and UGI Utilities primarily use bank loans to satisfy their seasonal operating cash flow needs. Energy Services uses its Receivables Facility to satisfy its operating cash flow needs. Antargaz has historically been successful funding its operating cash flow needs without the use of its revolver.

Cash flow provided by operating activities was $222.5 million in the 2007 six-month period compared with $70.5 million in the 2006 six-month period. Cash flow from operating activities before changes in operating working capital was $415.9 million in the 2007 six-month period compared with $327.3 million in the prior-year six-month period reflecting the higher income and greater non-cash charges. Changes in operating working capital used $193.4 million in the 2007 six-month period and $256.8 million in the 2006 six-month period largely reflecting the effects of changes in accounts receivable, inventories and accounts payable.

Investing Activities. Investing activity cash flow is principally affected by capital expenditures and investments in property, plant and equipment, cash paid for acquisitions of businesses, changes in short-term investments and proceeds from sales of assets. Net cash used in investing activities was $74.3 million in the 2007 six-month period compared to $135.8 million in the prior-year period. The decrease in investing activities largely reflects cash received as a result of the PG Energy Acquisition working capital settlement and a decrease in restricted cash.

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UGI CORPORATION AND SUBSIDIARIES

Financing Activities. Cash flow used by financing activities was $139.7 million in the 2007 six-month period compared with $6.5 million in the prior-year six-month period. Financing activity cash flow changes are primarily due to issuances and repayments of long-term debt, net bank loan borrowings, dividends and distributions on UGI Common Stock and AmeriGas Partners Common Units, and proceeds from issuances of AmeriGas Partners Common Units and UGI Common Stock.

We paid cash dividends on UGI Common Stock of $37.4 million and $35.5 million during the 2007 and 2006 six-month periods, respectively. During the 2007 six-month period, the Partnership declared and paid quarterly distributions on its limited partner units for the quarters ended December 31, and September 30, 2006.

UGI Common Dividend and AmeriGas Partners Distribution Increases

On April 24, 2007, UGI’s Board of Directors approved an increase in the quarterly dividend rate on UGI Common Stock to $0.185 per common share or $0.74 per common share on an annual basis. The new quarterly dividend rate is effective with the dividend payable on July 1, 2007 to shareholders of record on June 15, 2007. On April 23, 2007, AmeriGas Propane’s Board of Directors approved an increase in its quarterly distribution rate on AmeriGas Partners Common Units to $0.61 per Common Unit or $2.44 per Common Unit on an annual basis. The new quarterly distribution rate is effective with the distribution payable on May 18, 2007 to unitholders of record on May 10, 2007. In addition, on May 4, 2007, the Partnership announced its intention to distribute a portion of the proceeds from the expected sale of its Arizona storage facility in the amount of $0.25 per Common Unit on August 18, 2007 to unitholders of record on August 10, 2007. Generally, the percentage of AmeriGas Partners’ cash distributions to the General Partner increases when the amount of any distribution to the limited partners exceeds $0.605 per Common Unit. Accordingly, beginning with the partnership distribution of $0.61 per Common Unit to be paid on May 18, 2007, the General Partner will receive a greater percentage of the total partnership distribution than its general partner ownership interest of 1%, but only with respect to the amount by which the total distribution to limited partners exceeds $0.605 per Common Unit.

PG Energy Acquisition

On August 24, 2006, UGI Utilities acquired certain assets and assumed certain liabilities of Southern Union Company’s (“SU’s”) PG Energy Division, a natural gas distribution business located in northeastern Pennsylvania, and all of the issued and outstanding stock of SU’s wholly-owned subsidiary, PG Energy Services, Inc., pursuant to a Purchase and Sale Agreement, as amended, between SU and UGI dated January 26, 2006 (the “Agreement”). On August 24, 2006 and in accordance with the terms of the Agreement, UGI Utilities paid SU $580 million in cash. Pursuant to the terms of the Agreement, the purchase price was subject to a working capital adjustment equal to the difference between $68.1 million and the actual working capital as of the closing date agreed to by both UGI Utilities and SU. In March 2007, UGI Utilities and SU reached an agreement on the working capital adjustment pursuant to which SU paid UGI Utilities $23.7 million in cash. See Note 2 to Condensed Consolidated Financial Statements.

Utility Regulatory Matters

In an order entered on November 30, 2006, the PUC approved a settlement of the base rate proceeding of PG Energy (PNG Gas). The settlement provided for an increase in natural gas distribution base rates of $12.5 million annually or approximately 4%, effective December 2, 2006.

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UGI CORPORATION AND SUBSIDIARIES

In accordance with POLR settlements approved by the PUC, Electric Utility may increase its POLR rates up to certain limits through December 31, 2009. In accordance with these settlements, Electric Utility increased its POLR rates by 4.5% on January 1, 2005 and 3% on January 1, 2006 (a total of 7.5% above the total rates in effect on December 31, 2004). Electric Utility also increased its POLR rates for all metered customers effective January 1, 2007 which is expected to increase the average cost to residential customers by approximately 35% over such costs in effect during calendar year 2006.

Antargaz Tax Matter

The French tax authorities levy taxes on legal entities and individuals regularly operating a business in France which are commonly referred to collectively as “business tax.” The amount of business tax charged annually is generally dependent upon the value of certain of the entity’s tangible fixed assets. Changes in the French government’s interpretation of the tax laws or in the tax laws themselves could adversely or favorably affect our results of operations.

AmeriGas Partners’ Pending Sale of Arizona Storage Facility

In February 2007, AmeriGas Partners signed a definitive agreement with Plains LPG Services, L.P. to sell its 3.5 million barrel liquefied petroleum gas storage terminal located near Phoenix, AZ for approximately $52 million. The transaction is expected to close before the end of the fiscal quarter ending June 30, 2007. UGI expects to realize an after-tax gain on this sale of approximately $11 million to $12 million.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Our primary market risk exposures are (1) market prices for propane and other LPG, natural gas and electricity; (2) changes in interest rates; and (3) foreign currency exchange rates.

The risk associated with fluctuations in the prices the Partnership and our International Propane operations pay for LPG is principally a result of market forces reflecting changes in supply and demand for propane and other energy commodities. Their profitability is sensitive to changes in LPG supply costs. Increases in supply costs are generally passed on to customers. The Partnership and International Propane may not, however, always be able to pass through product cost increases fully or on a timely basis, particularly when product costs rise rapidly. In order to reduce the volatility of LPG market price risk, the Partnership uses contracts for the forward purchase or sale of propane, propane fixed-price supply agreements, and over-the-counter derivative commodity instruments including price swap and option contracts and Antargaz hedges a portion of its future U.S. dollar denominated LPG product purchases through the use of forward foreign exchange contracts. Antargaz may also enter into other contracts, similar to those used by the Partnership. Flaga has and may use derivative commodity instruments to reduce market risk associated with a portion of its propane purchases. Currently, Flaga’s hedging activities are not material to the Company’s financial position or results of operations. Over-the-counter derivative commodity instruments utilized to hedge forecasted purchases of propane are generally settled at expiration of the contract. In order to minimize credit risk associated with its derivative commodity contracts, the Partnership monitors established credit limits with the contract counterparties. Although we use derivative financial and commodity instruments to reduce market price risk associated with forecasted transactions, we do not use derivative financial and commodity instruments for speculative or trading purposes.

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UGI CORPORATION AND SUBSIDIARIES

Gas Utility’s tariffs contain clauses that permit recovery of substantially all of the prudently incurred costs of natural gas it sells to its customers. The recovery clauses provide for periodic adjustments for the difference between the total amounts actually collected from customers through PGC rates and the recoverable costs incurred. Because of this ratemaking mechanism, there is limited commodity price risk associated with Gas Utility.

Electric Utility purchases power from wholesale electricity suppliers under fixed-price energy and capacity contracts and, to a much lesser extent, on the spot market. Prices for electricity can be volatile especially during periods of high demand or tight supply. Currently, Electric Utility’s fixed-price contracts with electricity suppliers mitigate most risks associated with the POLR service rate limits in effect through December 31, 2009. With respect to its existing fixed-price power and capacity contracts, should any of the counterparties fail to provide electric power or capacity under the terms of such contracts, any increases in the cost of replacement power or capacity could negatively impact Electric Utility results. In order to reduce this nonperformance risk, Electric Utility has diversified its purchases across several suppliers and entered into bilateral collateral arrangements with certain of them. From time to time, Electric Utility enters into electric price swap agreements to reduce the volatility in the cost of a portion of its anticipated electricity requirements.

In order to manage market price risk relating to substantially all of Energy Services’ fixed-price sales contracts for natural gas, Energy Services purchases exchange-traded and over-the-counter natural gas futures contracts or enters into fixed-price supply arrangements. Energy Services’ exchange-traded natural gas futures contracts are guaranteed by the New York Mercantile Exchange (“NYMEX”) and have nominal credit risk. The change in market value of these contracts generally requires daily cash deposits in margin accounts with brokers. At March 31, 2007, Energy Services had $5.2 million of restricted cash on deposit in such margin accounts. Although Energy Services’ fixed-price supply arrangements mitigate most risks associated with its fixed-price sales contracts, should any of the natural gas suppliers under these arrangements fail to perform, increases, if any, in the cost of replacement natural gas would adversely impact Energy Services’ results. In order to reduce this risk of supplier nonperformance, Energy Services has diversified its purchases across a number of suppliers.

UGID has entered into fixed-price sales agreements for a portion of the electricity expected to be generated by its electric generation assets. In the event that these generation assets would not be able to produce all of the electricity needed to supply electricity under these agreements, UGID would be required to purchase such electricity on the spot market or under contract with other electricity suppliers. Accordingly, increases in the cost of replacement power could negatively impact the Company’s results.

Asset Management has entered and may continue to enter into fixed-price sales agreements for a portion of its propane sales. In order to manage the market price risk relating to substantially all of its fixed-price sales contracts for propane, Asset Management enters into price swap and option contracts.

We have both fixed-rate and variable-rate debt. Changes in interest rates impact the cash flows of variable-rate debt but generally do not impact its fair value. Conversely, changes in interest rates impact the fair value of fixed-rate debt but do not impact their cash flows.

Our variable-rate debt includes borrowings under AmeriGas OLP’s Credit Agreement and borrowings under UGI Utilities’ Revolving Credit Agreement and a substantial portion of Antargaz’ and Flaga’s debt. These debt agreements have interest rates that are generally indexed to short-term market interest rates. Antargaz has effectively fixed the interest rate on its variable-rate long-term debt through June 2011 through the use of interest rate swaps. Flaga has effectively fixed a substantial portion of its long-term debt through September 2011 through the use of an interest rate swap. At March 31, 2007, combined borrowings outstanding under these agreements, excluding Antargaz’ and Flaga’s effectively fixed-rate debt, totaled approximately $156.6 million. Our long-term debt is typically issued at fixed rates of interest based upon market rates for debt having similar terms and credit ratings. As these long-term debt issues mature, we may refinance such debt with new debt having interest rates reflecting then-current market conditions. This debt may have an interest rate that is more or less than the refinanced debt. In order to reduce interest rate risk associated with near to medium term forecasted issuances of fixed-rate debt, from time to time we enter into interest rate protection agreements.

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UGI CORPORATION AND SUBSIDIARIES

The following table summarizes the fair values of unsettled market risk sensitive derivative instruments held at March 31, 2007. Fair values reflect the estimated amounts that we would receive or pay to terminate the contracts at the reporting date based upon quoted market prices of comparable contracts at March 31, 2007. The table also includes the changes in fair value that would result if there were a ten percent adverse change in (1) the market price of propane; (2) the market price of natural gas; (3) the market price of electricity; (4) interest rates on ten-year U.S. treasury notes and the three- and six-month Euribor and; (5) value of the euro versus the U.S. dollar. Gas Utility’s exchange-traded natural gas call option and futures contracts are excluded from the table below because any associated net gains are included in Gas Utility’s PGC recovery mechanism.


				Change in
	Fair Value			Fair Value
(Millions of dollars)
March 31, 2007:
Propane commodity price risk	$	3.4		$	(6.2	)
Natural gas commodity price risk		4.0			(11.5	)
Electricity commodity price risk		4.5			(1.0	)
Interest rate risk		16.3			(12.9	)
Foreign currency exchange rate risk		(3.3	)		(17.1	)

Because our derivative instruments generally qualify as hedges under SFAS No. 133, “Accounting for Derivative Instruments and Hedging Activities,” (“SFAS 133”), we expect that changes in the fair value of derivative instruments used to manage commodity or interest rate market risk would be substantially offset by gains or losses on the associated anticipated transactions.

Our primary exchange rate risk is associated with the U.S. dollar versus the euro. The U.S. dollar value of our foreign-denominated assets and liabilities will fluctuate with changes in the associated foreign currency exchange rates. We use derivative instruments to hedge portions of our net investments in foreign subsidiaries (“net investment hedges”). Realized gains or losses remain in other comprehensive income until such foreign operations are liquidated. At March 31, 2007, the fair value of unsettled net investment hedges was a loss of $1.4 million, which is included in foreign currency exchange rate risk in the table above. With respect to our net investments in Flaga and Antargaz, a 10% decline in the value of the euro versus the U.S. dollar, excluding the effects of any net investment hedges, would reduce their aggregate net book value by approximately $52.8 million, which amount would be reflected in other comprehensive income.

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UGI CORPORATION AND SUBSIDIARIES

ITEM 4. CONTROLS AND PROCEDURES

(a)

Evaluation of Disclosure Controls and Procedures

The Company’s management, with the participation of the Company’s Chief Executive Officer and Chief Financial Officer, evaluated the effectiveness of the Company’s disclosure controls and procedures as of the end of the period covered by this report. Based on that evaluation, the Chief Executive Officer and Chief Financial Officer concluded that the Company’s disclosure controls and procedures as of the end of the period covered by this report were designed and functioning effectively to provide reasonable assurance that the information required to be disclosed by the Company in reports filed under the Securities Exchange Act of 1934, as amended, is (i) recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms, and (ii) accumulated and communicated to our management, including the Chief Executive Officer and Chief Financial Officer, as appropriate to allow timely decisions regarding disclosure.

(b)

Change in Internal Control over Financial Reporting

Except as discussed below, during the quarter ended March 31, 2007, there has been no change in the Company’s internal control over financial reporting (as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) that has materially affected, or is reasonably likely to materially affect, the Company’s internal control over financial reporting.

For an interim period, Southern Union Company was providing certain information technology services to UGI Penn Natural Gas, Inc. (“UGIPNG”), a wholly owned subsidiary of UGI Utilities, and assisting us in migrating certain transaction-based processes and historical UGIPNG data to UGI Utilities’ systems. The migration plan is substantially complete. During October 2006, UGI and subsidiaries UGI Utilities and UGID, implemented certain financial components of a new information system (the “UGI System”) that supports human resource, accounting, purchasing and payroll transaction processing functions. Pursuant to the migration plan, UGIPNG began using certain financial components of the UGI System as of January 1, 2007. We have extended internal control procedures over quarterly financial reporting to include UGIPNG.

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UGI CORPORATION AND SUBSIDIARIES

PART II OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

Antargaz Competition Authority Matter. In June 2005, officials from France’s General Division of Competition, Consumption and Fraud Punishment (“DGCCRF”) conducted an unannounced inspection of, and obtained documents from, Antargaz’ headquarters building. Management believes that the DGCCRF performed similar unannounced inspections and document seizures at the locations of other distributors of LPG in France, as well as the industry association, Comite Francais du Butane et du Propane (“CFBP”). The DGCCRF apparently sought evidence of unlawful anticompetitive activities affecting the packaged LPG (i.e., cylinder) business in northern France.

Antargaz did not have any further contact with the DGCCRF regarding this matter until February 2007, when it received a letter from the DGCCRF requesting documents and information relating to Antargaz’ pricing policies and practices. In March 2007, the DGCCRF requested additional information from Antargaz and three joint ventures in which it participates. Based on these requests, it appears that the DGCCRF has expanded the scope of its investigation to include both bulk and cylinder markets throughout France. The Company is continuing its review of Antargaz’ pricing policies and practices and, based on the preliminary results of that review, believes Antargaz is not in violation of France’s competition laws.

Based on a recent newspaper article, we believe that France’s Conseil de la Concurrence (“Competition Council”) is conducting a related investigation regarding alleged concerted behavior among certain distributors of LPG in France. The article stated that one of the companies under investigation had applied for leniency, pursuant to the French law that allows a company to offer evidence of anti-competitive behavior in exchange for partial or total amnesty from financial sanctions. The company seeking leniency may present testimony or other evidence of anti-competitive activities that are adverse to Antargaz’ interests. As part of any investigation, the Competition Council and the DGCCRF may uncover information from other sources, including customers, suppliers or employees of Antargaz and other LPG companies, that may be adverse to Antargaz’ interests.

Management intends to continue to cooperate with the DGCCRF investigation and any investigation that may be initiated. At this time, the French authorities have not made any claim against Antargaz. However, in the event a claim is made against Antargaz and it is found to have violated the competition laws in France, it would be subject to civil penalties up to a maximum of 10% of the total annual revenues of UGI.

ITEM 1A. RISK FACTORS

In addition to the information presented below and the other information set forth in this report, you should carefully consider the factors discussed in Part I, “Item 1A. Risk Factors” in our Annual Report on Form 10-K for the fiscal year ended September 30, 2006, which could materially affect our business, financial condition or future results. The risks described below and in our Annual Report on Form 10-K are not the only risks facing the Company. Other unknown or unpredictable factors could also have material adverse effects on future results.

The expansion of our international business means that we will face increased risks, which may negatively affect our business results.

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UGI CORPORATION AND SUBSIDIARIES

Our acquisition of Antargaz in March of 2004 significantly increased our international presence. As we continue to add new subsidiaries and enter into new joint ventures in countries around the world, we face risks in doing business abroad that we do not face domestically. Certain aspects inherent in transacting business internationally could negatively impact our operating results, including:

	•		costs and difficulties in staffing and managing international operations;

	•		tariffs and other trade barriers;

	•		difficulties in enforcing contractual rights;

	•		longer payment cycles;

	•		local political and economic conditions;

	•		potentially adverse tax consequences, including restrictions on repatriating earnings and the threat of “double taxation;”

	•		fluctuations in currency exchange rates, which can affect demand and increase our costs; and

	•		regulatory requirements and changes in regulatory requirements, including French and EU competition laws that may adversely affect the terms of contracts with customers, and strict regulations applicable to the storage and handling of LPG.

In June 2005, officials from France’s General Division of Competition, Consumption and Fraud Punishment (“DGCCRF”) conducted an unannounced inspection of, and obtained documents from, Antargaz’ headquarters building. Management believes that the DGCCRF performed similar unannounced inspections and document seizures at the locations of other distributors of LPG in France, as well as the industry association, Comite Francais du Butane et du Propane (“CFBP”). The DGCCRF apparently sought evidence of unlawful anticompetitive activities affecting the packaged LPG (i.e., cylinder) business in northern France.

Based on a recent newspaper article, we believe that France’s Conseil de la Concurrence (“Competition Council”) is conducting a related investigation regarding alleged concerted behavior among certain distributors of LPG in France. The article stated that one of the companies under investigation had applied for leniency, pursuant to the French law that allows a company to offer evidence of anti-competitive behavior in exchange for partial or total amnesty from financial sanctions. The company seeking leniency may present testimony or other evidence of anti-competitive activities that are adverse to Antargaz’ interests. As a part of any investigation, the Competition Council and the DGCCRF may uncover information from other sources, including customers, suppliers or employees of Antargaz and other LPG companies, that may be adverse to Antargaz’ interests.

- 38 -

UGI CORPORATION AND SUBSIDIARIES

ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS

On February 27, 2007, the Annual Meeting of Shareholders of UGI was held. The Shareholders (i) elected all nine nominees to the Board of Directors, (ii) approved the Amended and Restated UGI Corporation 2004 Omnibus Equity Compensation Plan, and (iii) ratified the appointment of PricewaterhouseCoopers LLP as independent registered public accountants.

The number of votes cast for and withheld from election of each director nominee is set forth below. There were no abstentions or broker non-votes in the election of directors.


DIRECTOR NOMINEES	FOR		WITHHELD
Stephen D. Ban		95,791,934		1,129,499
Richard C. Gozon		94,007,334		2,914,099
Lon R. Greenberg		95,123,064		1,798,369
Ernest E. Jones		95,013,170		1,908,263
Anne Pol		95,559,482		1,361,951
Marvin O. Schlanger		95,563,649		1,359,784
James W. Stratton		94,607,243		2,314,190
Roger B. Vincent		96,175,860		745,573
John L. Walsh		95,761,028		1,160,405

The number of votes cast for and against, the number of abstentions, and the number of broker non-votes in the approval of the Amended and Restated UGI Corporation 2004 Omnibus Equity Compensation Plan is as follows:

For: 69,655,080; Against: 11,964,785; Abstain: 956,923; Broker Non-Voted: 23,280,658.

The number of votes cast for and against, the number of abstentions, and the number of broker non-votes in the ratification of the appointment of PricewaterhouseCoopers LLP is as follows:

For: 96,457,571; Against: 255,217; Abstain: 208,641; Broker Non-Voted: 8,936,016.

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UGI CORPORATION AND SUBSIDIARIES

ITEM 6. EXHIBITS

The exhibits filed as part of this report are as follows (exhibits incorporated by reference are set forth with the name of the registrant, the type of report and registration number or last date of the period for which it was filed, and the exhibit number in such filing):

EXHIBIT NO.

EXHIBIT

REGISTRANT

FILING

EXHIBIT

10.1

AmeriGas Propane, Inc. Non-Qualified Deferred Compensation Plan effective February 1, 2007.

AmeriGas Partners, L.P.

Form 10-Q
(3/31/07)

10.1

10.2

Amendment dated March 20, 2007 to the Firm Transportation Service Agreement (Rate Schedule FT) dated October 1, 1996 between UGI Utilities and Transcontinental Gas Pipe Line Corporation, as modified pursuant to various orders of the Federal Energy Regulatory Commission.

UGI Utilities, Inc

Form 8-K
(3/20/07)

10.1

10.3

UGI Corporation 2004 Omnibus Equity Compensation Plan Amended and Restated as of December 5, 2006.

UGI Corporation

Form 8-K
(2/27/07)

10.1

31.1

Certification by the Chief Executive Officer relating to the Registrant’s Report on Form 10-Q for the quarter ended March 31, 2007, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

31.2

Certification by the Chief Financial Officer relating to the Registrant’s Report on Form 10-Q for the quarter ended March 31, 2007, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

Certification by the Chief Executive Officer and the Chief Financial Officer relating to the Registrant’s Report on Form 10-Q for the quarter ended March 31, 2007, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

- 40 -


			PAGES
Part I Financial Information

	Item 1.	Financial Statements

		Condensed Consolidated Balance Sheets as of March 31, 2007, September 30, 2006 and March 31, 2006		1

		Condensed Consolidated Statements of Income for the three and six months ended March 31, 2007 and 2006		2

		Condensed Consolidated Statements of Cash Flows for the six months ended March 31, 2007 and 2006		3

		Notes to Condensed Consolidated Financial Statements	4 - 19

	Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	20 - 33

	Item 3.	Quantitative and Qualitative Disclosures About Market Risk	33 - 35

	Item 4.	Controls and Procedures		36

Part II Other Information

	Item 1.	Legal Proceedings		37

	Item 1A.	Risk Factors	37 - 39

	Item 4.	Submission of Matters to a Vote of Security Holders		39

	Item 6.	Exhibits		40

	Signatures			41


Exhibit 31.1
Exhibit 31.2
Exhibit 32


	UGI Corporation (Registrant)
Date: May 10, 2007	By:	/s/ Anthony J. Mendicino
		Anthony J. Mendicino
		Senior Vice President-Finance and Chief Financial Officer


Date: May 10, 2007	By:	/s/ Michael J. Cuzzolina
		Michael J. Cuzzolina
		Vice President-Accounting and Financial Control and Chief Risk Officer