EX-99.2 3 d528900dex992.htm EX-99.2

Second Quarter 2013 Earnings Conference Call May 1, 2013 Exhibit 99.2

May 1, 2013 2 About This Presentation This presentation contains certain forward-looking statements that management believes to be reasonable as of today’s date only. Actual results may differ significantly because of risks and uncertainties that are difficult to predict and many of which are beyond management’s control. You should read UGI’s Annual Report on Form 10-K for a more extensive list of factors that could affect results. Among them are adverse weather conditions, cost volatility and availability of all energy products, including propane, natural gas, electricity and fuel oil, increased customer conservation measures, the impact of pending and future legal proceedings, domestic and international political, regulatory and economic conditions including currency exchange rate fluctuations (particularly the euro), the timing of development of Marcellus Shale gas production, the timing and success of our commercial initiatives and investments to grow our business, and our ability to successfully integrate acquired businesses, including Heritage Propane, and achieve anticipated synergies. UGI undertakes no obligation to release revisions to its forward-looking statements to reflect events or circumstances occurring after today.

John Walsh President & CEO, UGI Kirk Oliver Chief Financial Officer, UGI Jerry Sheridan President & CEO, AmeriGas

Second Quarter EPS +28% over Q2 of Fiscal 12 An almost 30% increase in EPS over Q2 of FY12 May 1, 2013 4

May 1, 2013 5 Weather vs Normal - 1.5% -21.7% 10.1% 1.2% 5.1% -2.1% 1.9% - 19.3% -25% -20% - 15% -10% - 5% 0% 5% 10% 15% FY2013 FY2012 AmeriGas Antargaz Flaga Utility

AmeriGas VOLUME Colder weather Full-period impact of Heritage OPEX Full-period impact of Heritage Higher sales activity Synergies Transition expenses: $2.7 MM lower than prior year Increase in miscellaneous income Total Margin * Opex includes all operating expenses, net of miscellaneous income. 195.0 266.1 82.9 (0.3) 4.4 (11.9) (3.8) $100 $150 $200 $250 $300 Operating Income, $ MM May 1, 2013 6 Total margin represents total revenues less total cost of sales.

International Propane VOLUME Colder weather Timing of deliveries in Q2 of FY12 MARGIN Higher unit margins at Antargaz Higher natural gas marketing margin OPEX Antargaz operating expenses Transition expense of $1 million in prior period Total Margin * Opex includes all operating expenses, net of miscellaneous income. 62.1 74.1 (5.7) 18.1 (2.4) 1.4 0.6 $40 $50 $60 $70 $80 Income Before Taxes , $ MM May 1, 2013 7 Total margin represents total revenues less total cost of sales.

Gas Utility MARGIN Colder weather Conversions from heating oil OPEX Higher pension and system maintenance expenses * Opex includes all operating expenses, net of miscellaneous income. 74.9 96.4 24.6 5.3 (8.7) (0.5) 0.8 $60 $70 $80 $90 $100 $110 Income Before Taxes , $ MM Total Margin May 1, 2013 8 Total margin represents total revenues less total cost of sales.

May 1, 2013 9 Midstream & Marketing MARGIN Colder weather Gas price volatility in January Lower power marketing margins due to lower average unit prices D&A Increase due to Temple II Total Margin * Opex includes all operating expenses, net of miscellaneous income. 29.3 43.2 8.4 4.2 3.5 (1.4) (1.3) 0.5 $10 $20 $30 $40 $50 Income Before Taxes, $ MM Total margin represents total revenues less total cost of sales.

May 1, 2013 10 Liquidity Int'l Corporate/ Total AmeriGas Propane Utilities Midstream Other Cash on hand 446.3 $ 123.1 $ 165.7 $ 58.3 $ 11.8 $ 87.4 $ Revolving Credit Facilities 525.0 $ 125.0 $ 300.0 $ 240.0 $ NA Accounts receivable facility NA NA NA 59.1 $ NA Drawn on facilities (115.9) $ (14.8) $ - $ (47.0) $ NA Letters of credit (54.1) $ (24.9) $ (2.0) $ - $ NA Available facilities 355.0 $ 85.3 $ 298.0 $ 252.1 $ - $ Available liquidity 478.1 $ 251.0 $ 356.3 $ 263.9 $ 87.4 $ Excluding cash residing at operating subsidiaries, UGI had $78.4 million of cash at 3/31/13 compared with $63.3 million at 3/31/12.

Jerry Sheridan CEO of AmeriGas

Q2 Adjusted EBITDA 29% over Q2 of Fiscal 12 * See appendix for Adjusted EBITDA reconciliation 29% over Q2 of Fiscal 12 * See appendix for Adjusted EBITDA reconciliation 246.0 317.6 $150 $200 $250 $300 $350 Adjusted EBITDA*, $ Millions May 1, 2013 12

May 1, 2013 13 Operational Update Operations • Weather: Warmer than normal, much colder than LY • Volume up in line with expectations • Lower COGS, Mt. Belvieu prices down 39 cents, or 31% Growth Initiatives • AmeriGas Cylinder Exchange (ACE): • National Accounts: • Acquisitions: Volume growth of 6% y/y, results muted by a colder March Volume increased 14 MM gallons y/y, 22 MM gallons ytd No acquisitions closed during the quarter

May 1, 2013 14 Guidance & Heritage Update • FY13 Guidance remains $620MM - $645MM, trending toward the midpoint • Final stages of Heritage integration: Planning to consolidate over 200 stores • Increased estimated transition expenses for the year by $5 MM reflecting additional severance costs • On track to realize at least $60MM in total net synergies

May 1, 2013 15 Distribution Increase $2.00 $2.20 $2.40 $2.60 $2.80 $3.00 $3.20 $3.40 2006 2007 2008 2009 2010 2011 2012 2013 AmeriGas: Distributions per unit (excluding special distributions) 5.4% CAGR

John Walsh President & CEO

May 1, 2013 17 Operational Update Gas Utility • Infrastructure Replacement Program approved by PUC; Gas Utility infrastructure capex expected to be approximately 25% above FY12 levels • Demand for natural gas remains at unprecedented levels: Net customer growth expected to exceed 2% in FY13 AmeriGas • . Final phase of Heritage integration is now underway and will conclude this summer • Superior distribution network covering the entire United States and very strong leadership team in place

May 1, 2013 18 Operational Update International • Focused on operational efficiencies: Broader base of operations in Europe will help reduce costs and enhance efficiencies in areas such as product sourcing • BP Poland acquisition: Expected to close in Q4 of FY13 • 20% drop in propane costs a positive for both UGI and our customers Midstream & Marketing • Expanding LNG services with Temple II • Auburn II pipeline in field execution phase. Expected in-service date remains early FY14 • New Tenaska gathering system expected in early 2014

May 1, 2013 19 Concluding Remarks • FY13 Guidance remains $2.40-$2.50, trending toward lower half • FY13 Will mark UGI’s 129 consecutive year of dividends and 26 consecutive year of dividend increases th th $0.60 $0.80 $1.00 $1.20 2006 2007 2008 2009 2010 2011 2012 2013 UGI: Dividends per share (excluding special distributions) 6.9% CAGR

Q&A

Appendix

May 1, 2013 22 AmeriGas Supplemental Information: Footnotes The enclosed supplemental information contains a reconciliation of earnings before interest expense, income taxes, depreciation and amortization ("EBITDA") and Adjusted EBITDA to Net Income. EBITDA and Adjusted EBITDA are not measures of performance or financial condition under accounting principles generally accepted in the United States ("GAAP"). Management believes EBITDA and Adjusted EBITDA are meaningful non-GAAP financial measures used by investors to compare the Partnership's operating performance with that of other companies within the propane industry. The Partnership's definitions of EBITDA and Adjusted EBITDA may be different from those used by other companies. EBITDA and Adjusted EBITDA should not be considered as alternatives to net income (loss) attributable to AmeriGas Partners, L.P. Management uses EBITDA to compare year-over-year profitability of the business without regard to capital structure as well as to compare the relative performance of the Partnership to that of other master limited partnerships without regard to their financing methods, capital structure, income taxes or historical cost basis. Management uses Adjusted EBITDA to exclude from AmeriGas Partners’ EBITDA gains and losses that competitors do not necessarily have to provide additional insight into the comparison of year-over-year profitability to that of other master limited partnerships. In view of the omission of interest, income taxes, depreciation and amortization from EBITDA and Adjusted EBITDA, management also assesses the profitability of the business by comparing net income attributable to AmeriGas Partners, L.P. for the relevant years. Management also uses EBITDA to assess the Partnership's profitability because its parent, UGI Corporation, uses the Partnership's EBITDA to assess the profitability of the Partnership, which is one of UGI Corporation’s industry segments. UGI Corporation discloses the Partnership's EBITDA in its disclosures about its industry segments as the profitability measure for its domestic propane segment.

May 1, 2013 23 AmeriGas Propane EBITDA Reconciliation (1) Adjusted EBITDA is a non-GAAP financial measure. Management believes the presentation of this measure provides useful information to investors to more effectively evaluate the year-over-year results of operations of the Partnership. Management uses Adjusted EBITDA to exclude from AmeriGas Partners' EBITDA gains and losses that competitors do not necessarily have to provide additional insight into the comparison of year-over-year profitability to that of other master limited partnerships. This measure is not comparable to measures used by other entities and should only be considered in conjunction with net income attributable to AmeriGas Partners, L.P. for the relevant periods. 2013 2012 2013 2012 2013 2012 Net income attributable to AmeriGas Partners, L.P. 221,820 $ 133,885 $ 318,485 $ 176,410 $ 153,100 $ 122,063 $ Income tax (benefit) expense (52) 764 575 1,214 1,292 1,256 Interest expense 41,776 45,045 82,972 61,578 164,035 93,374 Depreciation 37,607 35,351 75,930 56,282 153,873 98,841 Amortization 11,022 9,441 22,050 12,698 44,250 18,978 EBITDA 312,173 $ 224,486 $ 500,012 $ 308,182 $ 516,550 $ 334,512 $ Heritage Propane acquisition and transition expense 5,396 8,138 10,884 11,855 45,216 11,855 Loss (gain) on extinguishments of debt - 13,379 - 13,379 (30) 32,695 Adjusted EBITDA (1) 317,569 $ 246,003 $ 510,896 $ 333,416 $ 561,736 $ 379,062 $ March 31, Twelve Months Ended March 31, Three Months Ended Six Months Ended March 31,

Investor Relations: 610-337-1000 Hugh Gallagher (x1029) gallagherh@ugicorp.com Simon Bowman (x3645) bowmans@ugicorp.com