1
FORM 10-Q
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
[X] QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended December 31, 2000
OR
[ ] 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 23-2668356
(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) 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 X No
At January 31, 2001, there were 27,050,755 shares of UGI Corporation
Common Stock, without par value, outstanding.
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UGI CORPORATION AND SUBSIDIARIES
TABLE OF CONTENTS
PAGES
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PART I FINANCIAL INFORMATION
Item 1. Financial Statements
Condensed Consolidated Balance Sheets as of
December 31, 2000, September 30, 2000
and December 31, 1999 1
Condensed Consolidated Statements of Income
for the three and twelve months ended
December 31, 2000 and 1999 2
Condensed Consolidated Statements of Cash
Flows for the three and twelve months
ended December 31, 2000 and 1999 3
Notes to Condensed Consolidated Financial
Statements 4 - 13
Item 2. Management's Discussion and Analysis of
Financial Condition and Results of
Operations 14 - 25
Item 3. Quantitative and Qualitative Disclosures
About Market Risk 25 - 27
PART II OTHER INFORMATION
Item 6. Exhibits and Reports on Form 8-K 28
Signatures 29
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UGI CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(unaudited)
(Millions of dollars)
December 31, September 30, December 31,
2000 2000 1999
------------- ------------- -------------
ASSETS
Current assets:
Cash and cash equivalents $ 108.6 $ 93.9 $ 71.3
Short-term investments, at cost which approximates market value 3.9 7.8 4.3
Accounts receivable (less allowance for doubtful accounts of
$11.0, $9.3 and $8.1, respectively) 353.1 165.7 183.2
Accrued utility revenues 37.3 10.5 25.6
Inventories 121.8 117.4 84.2
Deferred income taxes 0.5 8.8 12.1
Utility regulatory assets 18.4 7.2 3.3
Prepaid expenses and other current assets 49.9 19.0 25.4
------------- ------------- -------------
Total current assets 693.5 430.3 409.4
Property, plant and equipment, at cost (less accumulated depreciation
and amortization of $598.8, $578.9 and $532.2, respectively) 1,090.7 1,073.2 1,059.7
Intangible assets (less accumulated amortization of $195.4, $190.2 and
$171.9, respectively) 672.3 675.5 659.6
Utility regulatory assets 54.6 55.1 58.3
Other assets 56.0 41.7 46.0
------------- ------------- -------------
Total assets $ 2,567.1 $ 2,275.8 $ 2,233.0
============= ============= =============
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities:
Current maturities of long-term debt $ 85.2 $ 85.9 $ 32.5
Operating Partnership bank loans 37.0 30.0 50.0
UGI Utilities bank loans 102.6 100.4 101.8
Other bank loans 10.1 4.3 --
Accounts payable 297.3 156.7 121.9
Other current liabilities 180.1 162.1 153.2
------------- ------------- -------------
Total current liabilities 712.3 539.4 459.4
Long-term debt 1,053.1 1,029.7 1,034.9
Deferred income taxes 172.7 169.9 168.8
Other noncurrent liabilities 83.8 92.5 82.4
Commitments and contingencies (note 4)
Minority interest in AmeriGas Partners 237.3 177.1 208.2
UGI Utilities redeemable preferred stock 20.0 20.0 20.0
Common stockholders' equity:
Common Stock, without par value (authorized - 100,000,000 shares;
issued - 33,198,731 shares) 394.5 394.5 394.8
Retained earnings (accumulated deficit) 16.2 (4.9) 2.6
Accumulated other comprehensive income 18.5 -- 0.5
Unearned compensation - restricted stock (0.4) (0.7) (1.5)
------------- ------------- -------------
428.8 388.9 396.4
Treasury stock, at cost (140.9) (141.7) (137.1)
------------- ------------- -------------
Total common stockholders' equity 287.9 247.2 259.3
------------- ------------- -------------
Total liabilities and stockholders' equity $ 2,567.1 $ 2,275.8 $ 2,233.0
============= ============= =============
See accompanying notes to consolidated financial statements.
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UGI CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF INCOME
(unaudited)
(Millions, except per share amounts)
Three Months Ended Twelve Months Ended
December 31, December 31,
---------------------------- -----------------------------
2000 1999 2000 1999
---------- ---------- ---------- ----------
Revenues:
AmeriGas Propane $ 432.5 $ 301.0 $ 1,251.6 $ 935.7
UGI Utilities 166.5 121.2 482.2 429.0
International Propane 13.9 13.9 50.5 13.9
Energy Services and other 124.2 30.5 247.9 97.9
---------- ---------- ---------- ----------
737.1 466.6 2,032.2 1,476.5
---------- ---------- ---------- ----------
Costs and expenses:
AmeriGas Propane cost of sales 264.8 158.7 734.4 445.0
UGI Utilities - gas, fuel and purchased power 103.3 57.5 263.9 207.4
International Propane cost of sales 9.0 8.1 30.6 8.1
Energy Services and other cost of sales 116.2 28.6 233.1 91.2
Operating and administrative expenses 129.6 117.9 472.9 441.0
Utility taxes other than income taxes 2.4 7.2 12.3 25.8
Depreciation and amortization 26.0 23.5 100.0 91.5
Other income, net (6.2) (5.6) (27.5) (18.6)
---------- ---------- ---------- ----------
645.1 395.9 1,819.7 1,291.4
---------- ---------- ---------- ----------
Operating income 92.0 70.7 212.5 185.1
Merger fee income, net -- -- -- 19.9
Interest expense (26.4) (23.8) (101.1) (87.2)
Minority interest in AmeriGas Partners (16.3) (8.0) (14.6) (11.3)
---------- ---------- ---------- ----------
Income before income taxes, subsidiary preferred
stock dividends and accounting changes 49.3 38.9 96.8 106.5
Income tax expense (21.8) (17.4) (44.5) (46.1)
Dividends on UGI Utilities Series Preferred Stock (0.4) (0.4) (1.6) (1.6)
---------- ---------- ---------- ----------
Income before accounting changes 27.1 21.1 50.7 58.8
Cumulative effect of accounting changes, net 4.5 -- 4.5 --
---------- ---------- ---------- ----------
Net income $ 31.6 $ 21.1 $ 55.2 $ 58.8
========== ========== ========== ==========
Earnings per share:
Basic:
Income before accounting changes $ 1.00 $ 0.77 $ 1.87 $ 1.92
Cumulative effect of accounting changes, net 0.17 -- 0.16 --
---------- ---------- ---------- ----------
Net income $ 1.17 $ 0.77 $ 2.03 $ 1.92
========== ========== ========== ==========
Diluted:
Income before accounting changes $ 1.00 $ 0.77 $ 1.87 $ 1.92
Cumulative effect of accounting changes, net 0.16 -- 0.16 --
---------- ---------- ---------- ----------
Net income $ 1.16 $ 0.77 $ 2.03 $ 1.92
========== ========== ========== ==========
Average common shares outstanding:
Basic 27.073 27.295 27.153 30.553
========== ========== ========== ==========
Diluted 27.185 27.375 27.208 30.615
========== ========== ========== ==========
Dividends declared per share $ 0.3875 $ 0.375 $ 1.525 $ 1.48
========== ========== ========== ==========
See accompanying notes to consolidated financial statements.
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UGI CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(unaudited)
(Millions of dollars)
Three Months Ended Twelve Months Ended
December 31, December 31,
--------------------- ---------------------
2000 1999 2000 1999
------ ------ ------ ------
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income $ 31.6 $ 21.1 $ 55.2 $ 58.8
Reconcile to net cash provided by operating activities:
Depreciation and amortization 26.0 23.5 100.0 91.5
Cumulative effect of accounting changes (4.5) -- (4.5) --
Minority interest in AmeriGas Partners 16.3 8.0 14.6 11.3
Deferred income taxes, net 5.6 1.9 6.9 7.9
Other, net (4.7) (4.5) 15.6 6.8
------ ------ ------ ------
70.3 50.0 187.8 176.3
Net change in:
Accounts receivable and accrued utility revenues (218.1) (96.4) (185.1) (54.7)
Inventories and prepaid propane purchases (5.9) (1.5) (30.5) (15.2)
Deferred fuel costs (11.7) 0.2 (15.7) (4.9)
Accounts payable 140.0 21.5 170.5 21.1
Other current assets and liabilities 9.1 (3.1) 18.7 (6.9)
------ ------ ------ ------
Net cash provided (used) by operating activities (16.3) (29.3) 145.7 115.7
------ ------ ------ ------
CASH FLOWS FROM INVESTING ACTIVITIES:
Expenditures for property, plant and equipment (17.7) (14.2) (74.5) (68.2)
Net proceeds from disposals of assets 1.5 1.5 8.4 5.5
Acquisitions of businesses, net of cash acquired (0.1) (2.4) (63.0) (77.6)
Investments in joint venture partnerships (6.0) -- (6.0) (4.9)
Short-term investments decrease 3.7 10.8 0.2 65.9
Other, net (3.0) -- (3.9) (5.4)
------ ------ ------ ------
Net cash used by investing activities (21.6) (4.3) (138.8) (84.7)
------ ------ ------ ------
CASH FLOWS FROM FINANCING ACTIVITIES:
Dividends on Common Stock (10.4) (10.2) (41.4) (46.1)
Distributions on Partnership public Common Units (11.1) (9.8) (40.4) (39.1)
Issuance of long-term debt 23.7 57.0 176.4 230.7
Repayment of long-term debt (0.9) (2.6) (93.7) (63.5)
AmeriGas Propane bank loans increase (decrease) 7.0 28.0 (13.0) (12.0)
UGI Utilities bank loans increase 2.2 14.4 0.8 31.6
Other bank loans increase (decrease) 1.4 (11.4) 6.0 (11.4)
Issuance of Partnership public Common Units 39.8 -- 39.8 --
Issuance of Common Stock 0.8 1.5 3.1 5.2
Repurchases of Common Stock -- (2.4) (7.2) (135.5)
------ ------ ------ ------
Net cash provided (used) by financing activities 52.5 64.5 30.4 (40.1)
------ ------ ------ ------
FOREIGN CURRENCY EXCHANGE EFFECT ON CASH: 0.1 (0.1) -- (0.1)
------ ------ ------ ------
Cash and cash equivalents increase (decrease) $ 14.7 $ 30.8 $ 37.3 $ (9.2)
====== ====== ====== ======
Cash and cash equivalents:
End of period $108.6 $ 71.3 $108.6 $ 71.3
Beginning of period 93.9 40.5 71.3 80.5
------ ------ ------ ------
Increase (decrease) $ 14.7 $ 30.8 $ 37.3 $ (9.2)
====== ====== ====== ======
During the twelve months ended December 31, 2000 and 1999, UGI Utilities, Inc.
paid cash dividends to UGI of $33.9 and $49.0, respectively. During the twelve
months ended December 31, 2000 and 1999, AmeriGas, Inc. paid cash dividends to
UGI of $54.7 and $46.7, respectively. During those same periods, UGI paid cash
dividends to holders of Common Stock of $41.4 and $46.1, respectively. The
ability of UGI to declare and pay cash dividends on its Common Stock is
dependent upon its cash balances and the receipt of cash dividends from its
wholly owned subsidiaries, principally UGI Utilities, Inc. and AmeriGas, Inc.
AmeriGas's ability to pay dividends is dependent upon distributions paid by the
Partnership.
See accompanying notes to consolidated financial statements.
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UGI CORPORATION AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(unaudited)
(Millions of dollars, except per share amounts)
1. BASIS OF PRESENTATION
UGI Corporation ("UGI") is a holding company that operates gas and
electric utility, propane distribution, energy marketing and related
businesses through subsidiaries. Our utility business is conducted through
a wholly owned subsidiary, UGI Utilities, Inc. ("UGI Utilities"). UGI
Utilities owns and operates a natural gas distribution utility ("Gas
Utility") in parts of eastern and southeastern Pennsylvania and an
electric distribution utility and electricity generation business
(collectively "Electric Utility") in northeastern Pennsylvania (together
we refer to them as "Utilities"). We conduct a national propane
distribution business through AmeriGas Partners, L.P. ("AmeriGas
Partners") and its operating subsidiary, AmeriGas Propane, L.P. (the
"Operating Partnership"), both of which are Delaware limited partnerships.
We refer to AmeriGas Partners and the Operating Partnership together as
"the Partnership." In October 2000, AmeriGas Partners issued 2,300,000
Common Units in a public offering for net cash proceeds of approximately
$40 million. As a result of this issuance, at December 31, 2000, UGI,
through subsidiaries, holds an effective 2% general partner interest and a
53.5% limited partner interest in the Operating Partnership. Our wholly
owned subsidiary, UGI Enterprises, Inc. ("Enterprises"), conducts an
energy marketing business through its wholly owned subsidiary, UGI Energy
Services, Inc. ("Energy Services"). Through other subsidiaries,
Enterprises (1) owns and operates a propane distribution business in
Austria, the Czech Republic and Slovakia ("FLAGA"), (2) owns and operates
a heating, ventilation and air-conditioning service business ("HVAC") and
a retail hearth, spa and grill products business in the Middle Atlantic
region of the U.S., ("Hearth USA(TM)"), and (3) participates in propane
joint-venture projects in Romania and China.
Our condensed consolidated financial statements include the accounts of
UGI and its majority-owned subsidiaries, together referred to as "we" or
"the Company." We eliminate all significant intercompany accounts and
transactions when we consolidate. We report the public unitholders'
interest in AmeriGas Partners' results of operations and net assets as
minority interest in the condensed consolidated statements of income and
balance sheets. We have reclassified certain prior-period balances to
conform with the current period presentation.
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. These financial
statements should be read in conjunction with the financial statements and
the related notes included in our Annual Report on Form 10-K for the year
ended September
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UGI CORPORATION AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
(unaudited)
(Millions of dollars, except per share amounts)
30, 2000 ("Company's 2000 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.
Comprehensive income for the three months ending December 31, 2000 was
$50.1 million. Other comprehensive income of $18.5 million in the three
months ended December 31, 2000 consisted primarily of transition
adjustments relating to the adoption of Statement of Financial Accounting
Standards ("SFAS") No. 133, "Accounting for Derivative Instruments and
Hedging Activities" ("SFAS 133"), totaling $7.1 million, and income
associated with changes in the fair value of derivative instruments, net
of reclassification adjustments, totaling $11.4 million. Other
comprehensive income in the three months ended December 31, 1999 was less
than $0.1 million.
2. SEGMENT INFORMATION
Based upon SFAS No. 131, "Disclosures about Segments of an Enterprise and
Related Information" ("SFAS 131"), we have determined that the Company has
five business segments: (1) AmeriGas Propane, (2) Gas Utility, (3)
Electric Utility, (4) Energy Services, and (5) an international propane
segment comprising FLAGA and our equity investments in Romania and China.
The accounting policies of the five segments disclosed are the same as
those described in the Significant Accounting Policies note contained in
the Company's 2000 Annual Report and those described in Note 3 below. We
evaluate our AmeriGas Propane and International Propane segments'
performance principally based on their earnings before interest expense,
income taxes, depreciation and amortization ("EBITDA"). Although we use
EBITDA to evaluate these segments' performance, 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 generally accepted accounting
principles. We evaluate the performance of Gas Utility, Electric Utility,
and Energy Services principally based upon their earnings 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)
2. SEGMENT INFORMATION (CONTINUED)
Three Months Ended December 31, 2000:
Other
AmeriGas Gas Electric Energy International Enterprises Corp.
Total Elims. Propane Utility Utility Services Propane (a) & Other
-------- -------- -------- -------- -------- -------- -------- -------- --------
Revenues $ 737.1 $ (0.7) $ 432.5 $ 146.0 $ 20.5 $ 111.5 $ 13.9 $ 12.7 $ 0.7
======== ======== ======== ======== ======== ======== ======== ======== ========
Segment profit (loss):
EBITDA $ 118.0 $ -- $ 75.3 $ 35.5 $ 3.8 $ 1.6 $ 0.3 $ 0.1 $ 1.4
Depreciation and
amortization (26.0) -- (18.5) (4.9) (1.0) (0.1) (1.1) (0.4) --
-------- -------- -------- -------- -------- -------- -------- -------- --------
Operating income (loss) 92.0 -- 56.8 30.6 2.8 1.5 (0.8) (0.3) 1.4
Interest expense (26.4) -- (20.0) (4.4) (0.7) -- (1.2) -- (0.1)
Minority interest (16.3) -- (16.3) -- -- -- -- -- --
-------- -------- -------- -------- -------- -------- -------- -------- --------
Income (loss) before
income taxes,
subsidiary preferred
stock dividends, and
accounting changes $ 49.3 $ -- $ 20.5 $ 26.2 $ 2.1 $ 1.5 $ (2.0) $ (0.3) $ 1.3
======== ======== ======== ======== ======== ======== ======== ======== ========
Segment assets (at period
end) $2,567.1 $ (22.6) $1,439.8 $ 719.7 $ 102.5 $ 82.0 $ 125.7 $ 32.1 $ 87.9
======== ======== ======== ======== ======== ======== ======== ======== ========
Investment in equity
investees $ 16.0 $ -- $ -- $ -- $ 10.4 $ -- $ 5.6 $ -- $ --
======== ======== ======== ======== ======== ======== ======== ======== ========
Three Months Ended December 31, 1999:
AmeriGas Gas Electric Energy International Other Corp.
Total Elims. Propane Utility Utility Services Propane Enterprises & Other
-------- -------- -------- -------- -------- -------- -------- -------- --------
Revenues $ 466.6 $ (0.8) $ 301.0 $ 102.0 $ 19.2 $ 29.8 $ 13.9 $ 0.7 $ 0.8
======== ======== ======== ======== ======== ======== ======== ======== ========
Segment profit (loss):
EBITDA $ 94.2 $ -- $ 54.2 $ 32.7 $ 6.8 $ 0.8 $ 0.6 $ (1.4) $ 0.5
Depreciation and
amortization (23.5) -- (16.5) (4.9) (0.8) (0.1) (1.1) -- (0.1)
-------- -------- -------- -------- -------- -------- -------- -------- --------
Operating income (loss) 70.7 -- 37.7 27.8 6.0 0.7 (0.5) (1.4) 0.4
Interest expense (23.8) -- (18.0) (4.2) (0.5) -- (0.9) -- (0.2)
Minority interest (8.0) -- (8.0) -- -- -- -- -- --
-------- -------- -------- -------- -------- -------- -------- -------- --------
Income (loss) before
income taxes,
subsidiary preferred
stock dividends, and
accounting changes $ 38.9 $ -- $ 11.7 $ 23.6 $ 5.5 $ 0.7 $ (1.4) $ (1.4) $ 0.2
======== ======== ======== ======== ======== ======== ======== ======== ========
Segment assets (at period
end) $2,233.0 $ (28.2) $1,290.9 $ 641.7 $ 96.7 $ 15.8 $ 130.7 $ 4.7 $80.7
======== ======== ======== ======== ======== ======== ======== ======== ========
Investment in equity
investees $ 6.0 $ -- $ -- $ -- $ -- $ -- $ 6.0 $ -- $ --
======== ======== ======== ======== ======== ======== ======== ======== ========
(a) Principally comprises Hearth USA(TM), HVAC, and Enterprises' corporate
and general expenses.
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UGI CORPORATION AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
(unaudited)
(Millions of dollars, except per share amounts)
2. SEGMENT INFORMATION (CONTINUED)
Twelve Months Ended December 31, 2000:
Other
AmeriGas Gas Electric Energy International Enterprises Corp.
Total Elims. Propane Utility Utility Services Propane (a) & Other
-------- -------- -------- -------- -------- -------- -------- -------- --------
Revenues $2,032.2 $ (3.0) $1,251.6 $ 403.0 $ 79.2 $ 228.6 $ 50.5 $ 19.3 $ 3.0
======== ======== ======== ======== ======== ======== ======== ======== ========
Segment profit (loss):
EBITDA $ 312.5 $ -- $ 179.7 $ 108.1 $ 16.6 $ 3.8 $ 1.6 $ (3.5) $ 6.2
Depreciation and
amortization (100.0) -- (70.4) (19.1) (4.7) (0.2) (4.6) (0.9) (0.1)
-------- -------- -------- -------- -------- -------- -------- -------- --------
Operating income (loss) 212.5 -- 109.3 89.0 11.9 3.6 (3.0) (4.4) 6.1
Interest expense (101.1) -- (76.7) (16.4) (2.4) -- (5.1) -- (0.5)
Minority interest (14.6) -- (14.6) -- -- -- -- -- --
-------- -------- -------- -------- -------- -------- -------- -------- --------
Income (loss) before
income taxes,
subsidiary preferred
stock dividends, and
accounting changes $ 96.8 $ -- $ 18.0 $ 72.6 $ 9.5 $ 3.6 $ (8.1) $ (4.4) $ 5.6
======== ======== ======== ======== ======== ======== ======== ======== ========
Segment assets (at period
end) $2,567.1 $ (22.6) $1,439.8 $ 719.7 $ 102.5 $ 82.0 $ 125.7 $ 32.1 $ 87.9
======== ======== ======== ======== ======== ======== ======== ======== ========
Investment in equity
investees $ 16.0 $ -- $ -- $ -- $ 10.4 $ -- $ 5.6 $ -- $ --
======== ======== ======== ======== ======== ======== ======== ======== ========
Twelve Months Ended December 31, 1999:
AmeriGas Gas Electric Energy International Other Corp.
Total Elims. Propane Utility Utility Services Propane Enterprises & Other
-------- -------- -------- -------- -------- -------- -------- -------- --------
Revenues $1,476.5 $ (2.6) $ 935.7 $ 353.0 $ 76.0 $ 97.1 $ 13.9 $ 0.8 $ 2.6
======== ======== ======== ======== ======== ======== ======== ======== ========
Segment profit (loss):
EBITDA $ 276.6 $ -- $ 162.2 $ 93.5 $ 18.8 $ 2.8 $ 0.6 $ (6.4) $ 5.1
Depreciation and
amortization (91.5) -- (66.7) (19.3) (4.0) (0.1) (1.1) -- (0.3)
-------- -------- -------- -------- -------- -------- -------- -------- --------
Operating income (loss) 185.1 -- 95.5 74.2 14.8 2.7 (0.5) (6.4) 4.8
Merger fee income, net 19.9 -- -- -- -- -- -- -- 19.9
Interest expense (87.2) -- (67.9) (15.6) (2.2) -- (0.9) -- (0.6)
Minority interest (11.3) -- (11.3) -- -- -- -- -- --
-------- -------- -------- -------- -------- -------- -------- -------- --------
Income (loss) before
income taxes,
subsidiary preferred
stock dividends, and
accounting changes $ 106.5 $ -- $ 16.3 $ 58.6 $ 12.6 $ 2.7 $ (1.4) $ (6.4) $ 24.1
======== ======== ======== ======== ======== ======== ======== ======== ========
Segment assets (at period
end) $2,233.0 $ (28.2) $1,290.9 $ 641.7 $ 96.7 $ 15.8 $ 130.7 $ 4.7 $ 80.7
======== ======== ======== ======== ======== ======== ======== ======== ========
Investment in equity
investees $ 6.0 $ -- $ -- $ -- $ -- $ -- $ 6.0 $ -- $ --
======== ======== ======== ======== ======== ======== ======== ======== ========
(a) Principally comprises Hearth USA(TM), HVAC, and Enterprises' corporate
and general expenses.
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3. CHANGES IN ACCOUNTING
Effective October 1, 2000, (1) the Company adopted SFAS 133; (2) the
Partnership applied the provisions of SEC Staff Accounting Bulletin No.
101 entitled "Revenue Recognition" ("SAB 101") with respect to its
nonrefundable tank fees; and (3) the Partnership changed its method of
accounting for costs to install Partnership-owned tanks at customer
locations. These accounting changes are further described below.
(1) ACCOUNTING FOR DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES (SFAS
133)
SFAS 133, as amended by SFAS Nos. 137 and 138, establishes accounting and
reporting standards for derivative instruments and for hedging activities.
It requires that all derivative instruments be recognized as either assets
or liabilities and measured at fair value. The accounting for changes in
fair value depends upon the purpose of the derivative instrument and
whether it is designated and qualifies for hedge accounting. To the extent
derivative instruments qualify and are designated as hedges of the
variability of cash flows associated with forecasted transactions, the
effective portion of the gain or loss on such derivative instruments is
generally reported in other comprehensive income and the ineffective
portion, if any, is reported in net income. Such amounts reported in other
comprehensive income are reclassified into net income when the forecasted
transaction affects earnings. If a cash flow hedge is discontinued because
it is probable that the forecasted transaction will not occur, the net
gain or loss is immediately reclassified into earnings. To the extent
derivative instruments qualify and are designated as hedges of changes in
the fair value of an existing asset, liability or firm commitment, the
gain or loss on the hedging instrument is recognized in earnings along
with the changes in fair value of the hedged asset, liability or firm
commitment attributable to the hedged risk.
In accordance with its propane price risk management policy, the
Partnership uses derivative instruments, including price swap and option
contracts, to manage the cost of a portion of its forecasted purchases of
propane. These derivative instruments are designated by the Partnership as
cash flow hedges. The fair values of these derivative instruments are
affected by changes in propane product prices. The Partnership may also
enter into derivative contracts to manage market price risk associated
with propane storage inventories whose value is subject to market price
fluctuations. These contracts are designated as fair value hedges. In
order to provide protection from the impact of significant declines in
propane product prices, the Partnership from time to time purchases
propane put option contracts. These derivative instruments generally do
not qualify for hedge accounting treatment and, as a result, gains or
losses, if any, are reflected in other income as they occur.
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11
UGI CORPORATION AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
(unaudited)
(Millions of dollars, except per share amounts)
In addition to these derivative instruments, the Partnership also uses
contracts for the forward purchase of propane as well as fixed price
supply agreements to manage propane market price risk. These contracts
qualify for the normal purchases and normal sales exception of SFAS 133
and therefore are not adjusted to fair value.
Energy Services uses exchange-traded natural gas futures contracts to
manage market risk associated with forecasted purchases of natural gas it
sells under firm commitments. These derivative instruments are designated
as cash flow hedges. The fair value of these futures contracts are
affected by changes in natural gas prices.
On occasion we use a managed program of derivative instruments including
natural gas and oil futures contracts to preserve forecasted gross margin
associated with certain of our natural gas customers. These contracts are
designated as cash flow hedges. In addition, from time to time we may
enter into foreign currency forward contracts associated with anticipated
foreign investments. These currency contracts are generally not eligible
for hedge accounting treatment under SFAS 133 and are marked to fair value
through net income.
Gas Utility and Electric Utility are parties to a number of contracts that
have elements of a derivative instrument. These contracts include, among
others, binding purchase orders, contracts which provide for the delivery
of natural gas, and service contracts that require the counterparty to
provide commodity storage, transportation or capacity service to meet our
normal sales commitments. Although many of these contracts have the
requisite elements of a derivative instrument, we believe these contracts
are not subject to the accounting requirements of SFAS 133 because they
provide for the delivery of products or services in quantities that are
expected to be used in the normal course of operating our business or the
value of the contract is directly associated with the price or value of a
service. Other contracts do not meet the definition of a derivative
instrument because they represent requirements-based commitments. Although
the adoption of SFAS 133 did not materially impact Gas Utility's and
Electric Utility's results of operations or financial position during the
three months ended December 31, 2000, it may impact their future results
of operations or financial position depending upon the extent to which
they use derivative instruments and their designation and effectiveness as
hedges of market risk.
The Company uses fixed rate long-term debt as a source of capital. As
these long-term debt issues mature, we often refinance such debt with
fixed-rate debt bearing then-existing market interest rates. On occasion,
we enter into interest rate protection agreements ("IRPAs") to reduce
market interest rate risk associated with these forecasted debt issuances.
We designate these IRPAs as cash flow hedges. Gains or losses on IRPAs are
included in other comprehensive income and included in interest expense
when interest expense on the associated debt issue affects earnings.
-9-
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UGI CORPORATION AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
(unaudited)
(Millions of dollars, except per share amounts)
The adoption of SFAS 133 resulted in an after-tax cumulative effect charge
to net income of $0.3 million and an after-tax increase to other
comprehensive income of $7.1 million. The increase in other comprehensive
income is attributable to net gains on derivative instruments designated
and qualifying as cash flow hedges on October 1, 2000.
Gains and losses included in accumulated other comprehensive income at
December 31, 2000 relating to cash flow hedges will be reclassified into
net income when (1) the forecasted purchase of propane or natural gas
subject to the hedges impacts net income and (2) interest on anticipated
issuances of fixed-rate long-term debt is reflected in net income.
Virtually all of the net gains included in accumulated other comprehensive
income at December 31, 2000 are related to forecasted transactions that
are expected to occur in the next twelve months. The actual amount of such
gains, if any, that will ultimately be reclassified into net income will
depend upon the value of such derivative contracts when settled. The fair
value of derivative instruments is included in prepaid expenses and other
current assets in the December 31, 2000 Condensed Consolidated Balance
Sheet.
(2) REVENUE RECOGNITION
In order to comply with the provisions of SAB 101, effective October 1,
2000 the Partnership changed its method of accounting for nonrefundable
tank fees. Historically, nonrefundable tank fees for installed
Partnership-owned tanks were recorded as revenue when billed. Under the
new accounting method, revenue from nonrefundable tank fees are being
recorded on a straight-line basis over one year. Accordingly, on October
1, 2000, the Company recorded an after-tax charge of $2.1 million
representing the cumulative effect of the change in accounting method on
prior years. This change in accounting method resulted in a reduction in
revenues of approximately $1.0 million in the three months ended December
31, 2000 and would have reduced revenues for the twelve months ended
December 31, 2000, and the three and twelve months ended December 31,
1999, by approximately $0.7 million, $1.2 million, and $0.9 million,
respectively. At December 31, 2000, the deferred revenue balance relating
to nonrefundable tank fees was $7.0 million.
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UGI CORPORATION AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
(unaudited)
(Millions of dollars, except per share amounts)
(3) ACCOUNTING FOR TANK INSTALLATION COSTS
Effective October 1, 2000, the Partnership changed its method of
accounting for tank installation costs which are not billed to customers.
Prior to the change in accounting method, all such costs to install
Partnership-owned tanks at a customer location were expensed as incurred.
Under the new accounting method, all such costs, net of billings, are
capitalized and amortized using an accelerated method that reflects the
attrition of the Partnership's customers. The Partnership believes that
the new accounting method better matches the costs of installing
Partnership-owned tanks with the periods benefited. As a result of this
change in accounting, the Company recorded after-tax income of $6.9
million representing the cumulative effect of the change in accounting
method on prior years.
The effect of the change in accounting for tank installation costs in the
three months ended December 31, 2000 was to increase net income by
approximately $0.3 million.
CUMULATIVE EFFECT OF ACCOUNTING CHANGES AND PRO FORMA DISCLOSURE
The cumulative effect impact reflected on the Consolidated Statement of
Income for the three months ended December 31, 2000 resulting from the
above changes in accounting principles comprises the following:
--------------------------------------------------------------------------
INCOME DILUTED
PRE-TAX TAX AFTER-TAX EARNINGS
INCOME (EXPENSE) INCOME (LOSS)
(LOSS) BENEFIT (LOSS) PER SHARE
--------------------------------------------------------------------------
SFAS No. 133 $ (0.4) $ 0.1 $ (0.3) $ (0.01)
Revenue recognition (3.5) 1.4 (2.1) (0.08)
Tank installation costs 11.3 (4.4) 6.9 0.25
--------------------------------------------------------------------------
Total $ 7.4 $ (2.9) $ 4.5 $ 0.16
--------------------------------------------------------------------------
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UGI CORPORATION AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
(unaudited)
(Millions of dollars, except per share amounts)
The following table reflects pro forma net income and net income per share
after applying retroactively the changes in accounting for tank
installation costs and nonrefundable tank fees:
--------------------------------------------------------------------------
AS AS
REPORTED ADJUSTED
--------------------------------------------------------------------------
THREE MONTHS ENDED DECEMBER 31, 1999:
Net income $ 21.1 $ 21.1
Net income per share - basic and diluted $ 0.77 $ 0.77
TWELVE MONTHS ENDED DECEMBER 31, 2000:
Net income $ 50.7 $ 50.7
Net income per share - basic and diluted $ 1.87 $ 1.87
TWELVE MONTHS ENDED DECEMBER 31, 1999:
Net income $ 58.8 $ 58.9
Net income per share - basic and diluted $ 1.92 $ 1.93
--------------------------------------------------------------------------
4. COMMITMENTS AND CONTINGENCIES
There have been no significant subsequent developments to the commitments
and contingencies reported in the Company's 2000 Annual Report.
5. FORMATION OF HUNLOCK CREEK ENERGY VENTURES
On December 8, 2000, UGI Development Company, through a subsidiary,
contributed its coal-fired Hunlock Creek generating station ("Hunlock"),
certain related assets, and approximately $6 million in cash, to Hunlock
Creek Energy Ventures ("Energy Ventures"), a general partnership jointly
owned by the Company and a subsidiary of Allegheny Energy, Inc.,
("Allegheny"). Also on December 8, 2000, Allegheny contributed a
newly-constructed, gas-fired combustion turbine generator to be operated
at the Hunlock Site. Under the joint-venture agreement, each partner is
entitled to purchase 50% of the output of the joint venture at cost. The
Company's investment in Energy Ventures is being accounted for under the
equity method of accounting. The formation of the joint venture did not
materially impact the Company's results of operations during the three
months ended December 31, 2000.
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UGI CORPORATION AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
(unaudited)
(Millions of dollars, except per share amounts)
6. SUBSEQUENT EVENT
On January 30, 2001, the Partnership signed a definitive agreement to
purchase the retail propane distribution businesses of Columbia Energy
Group ("Columbia") for approximately $208 million. The Columbia propane
businesses currently comprise the fifth largest retail marketer of propane
in the U.S. with total sales of over 300 million gallons from 186
locations in 29 states. At closing the seller will receive approximately
$155 million cash and approximately $53 million of AmeriGas Partners
Common Units. The cash portion of the purchase price and transaction fees
will be funded with approximately $55 million of long-term debt issued by
AmeriGas Partners and approximately $108 million of first mortgage notes
issued by the Operating Partnership. The transaction is subject to
customary conditions, including regulatory approval, and is expected to
close in March 2001.
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UGI CORPORATION AND SUBSIDIARIES
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS
The following analyses compare our results of operations for (1) the three
months ended December 31, 2000 ("2000 three-month period") with the three months
ended December 31, 1999 ("1999 three-month period") and (2) the twelve months
ended December 31, 2000 ("2000 twelve-month period") with the twelve months
ended December 31, 1999 ("1999 twelve-month period"). Our analyses of results of
operations should be read in conjunction with the segment information included
in Note 2 to Condensed Consolidated Financial Statements.
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UGI CORPORATION AND SUBSIDIARIES
2000 THREE-MONTH PERIOD COMPARED WITH 1999 THREE-MONTH PERIOD
- --------------------------------------------------------------------------------
Increase
Three Months Ended December 31, 2000 1999 (Decrease)
- --------------------------------------------------------------------------------
(Millions of dollars)
AMERIGAS PROPANE:
Revenues $ 432.5 $ 301.0 $ 131.5 43.7 %
Total margin $ 167.7 $ 142.3 $ 25.4 17.8 %
EBITDA (c) $ 75.3 $ 54.2 $ 21.1 38.9 %
Operating income $ 56.8 $ 37.7 $ 19.1 50.7 %
Retail gallons sold (millions) 257.0 233.7 23.3 10.0 %
Degree days - % colder (warmer)
than normal (a) 13.4 (14.1) -- --
GAS UTILITY:
Revenues $ 146.0 $ 102.0 $ 44.0 43.1 %
Total margin (b) $ 53.6 $ 47.9 $ 5.7 11.9 %
EBITDA (c) $ 35.5 $ 32.7 $ 2.8 8.6 %
Operating income $ 30.6 $ 27.8 $ 2.8 10.1 %
System throughput - billions of
Cubic feet ("bcf") 24.2 22.1 2.1 9.5 %
Degree days - % colder (warmer)
than normal 10.0 (12.2) -- --
ELECTRIC UTILITY:
Revenues $ 20.5 $ 19.2 $ 1.3 6.8 %
Total margin (b) $ 8.7 $ 11.0 $ (2.3) (20.9)%
EBITDA (c) $ 3.8 $ 6.8 $ (3.0) (44.1)%
Operating income $ 2.8 $ 6.0 $ (3.2) (53.3)%
Sales - millions of kilowatt hours
("gwh") 241.8 225.5 16.3 7.2 %
ENERGY SERVICES:
Revenues $ 111.5 $ 29.8 $ 81.7 274.2 %
Total margin $ 2.5 $ 1.5 $ 1.0 66.7 %
EBITDA (c) $ 1.6 $ 0.8 $ 0.8 100.0 %
Operating income $ 1.5 $ 0.7 $ 0.8 114.3 %
INTERNATIONAL PROPANE:
Revenues $ 13.9 $ 13.9 $ -- -- %
Total margin $ 4.9 $ 5.8 $ (0.9) (15.5)%
EBITDA (c) (d) $ 0.3 $ 0.6 $ (0.3) (50.0)%
Operating loss (d) $ 0.8 $ 0.5 $ 0.3 60.0 %
- --------------------------------------------------------------------------------
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UGI CORPORATION AND SUBSIDIARIES
(a) 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 continental U.S.
(b) Gas and Electric utilities' total margin represents revenues less cost of
sales and revenue-related taxes, i.e. gross receipts taxes. For financial
statement purposes, revenue related taxes are included in "Utility taxes
other than incomes taxes" on the condensed consolidated statements of
income. As of January 1, 2000, the Gas Competition Act, in conjunction
with a companion bill, eliminated the gross receipts tax on sales of gas.
(c) EBITDA (earnings before interest expense, income taxes, 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 generally
accepted accounting principles.
(d) Includes equity in net income (loss) of international joint ventures.
AMERIGAS PROPANE. Based upon national heating degree day data, temperatures in
the 2000 three-month period were 13.4% colder than normal compared with weather
that was 14.1% warmer than normal in the prior year. Retail volumes of propane
sold increased 23.3 million gallons (10.0%) primarily as a result of the colder
weather. Retail volumes sold in the prior-year period were impacted by the
acceleration of purchases by some customers resulting from the anticipation of
Year 2000 ("Y2K") disruptions. The Partnership estimates that approximately 5
million to 10 million gallons sold during the 1999 three-month period may have
been a result of Y2K.
Total revenues from retail propane sales increased $97.3 million reflecting a
$73.3 million increase as a result of higher selling prices and a $24.0 million
increase as a result of higher retail volumes sold. Wholesale propane revenues
increased $38.3 million reflecting a $21.5 million increase due to higher
selling prices and a $16.8 million increase as a result of higher wholesale
volumes. The higher retail and wholesale selling prices resulted from
significantly higher propane supply prices. Other revenues decreased $4.1
million primarily reflecting lower revenues from appliance sales and service and
the impact of the change in accounting for tank installation costs on tank
installation revenue. Cost of sales in the 2000 three-month period increased
$106.1 million as a result of higher propane supply prices and greater retail
and wholesale volumes.
Total margin increased $25.4 million in the 2000 three-month period reflecting
the impact of the higher retail volumes and higher average retail unit margins.
Increasing selling prices during the 2000 three-month period, along with
derivative hedging gains and favorably priced supply arrangements, enabled the
Partnership to record higher average unit margins while maintaining
competitive prices.
The increase in EBITDA and operating income during the 2000 three-month period
principally reflects the higher total margin. Operating expenses of the
Partnership were $93.8 million in the 2000 three-month period compared with
$89.5 million in the prior year which includes $3.1 million of expenses
associated with the installation of Partnership-owned tanks at customer
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UGI CORPORATION AND SUBSIDIARIES
locations. In the 2000 three-month period, such costs were capitalized in
accordance with the Partnership's change in accounting principle. Adjusting for
these expenses in the prior-year period, operating expenses increased $7.4
million reflecting higher volume-driven distribution expenses, including vehicle
fuel and repair expenses and greater compensation costs, and growth expenses
associated with our PPX(R) grill cylinder exchange business and businesses
acquired in fiscal 2000. Depreciation and amortization expense increased $2.0
million reflecting approximately $1.1 million of depreciation associated with
tank installation costs and greater acquisition-related depreciation and
amortization.
GAS UTILITY. Weather in Gas Utility's service territory during the 2000
three-month period was 10.0% colder than normal compared to weather that was
12.2% warmer than normal in the prior-year period. The colder weather was a
major factor in a 2.1 bcf (9.5%) increase in total Gas Utility system
throughput.
The $44.0 million increase in Gas Utility revenues reflects the impact of (1)
higher average purchased gas cost ("PGC") rates in effect during the 2000
three-month period and (2) higher sales to firm residential, commercial and
industrial ("core market") customers. The higher PGC rates reflect significantly
higher costs for natural gas in the 2000 three-month period. Gas Utility cost of
gas was $92.4 million in the 2000 three-month period compared to $50.0 million
in the prior-year period reflecting the higher PGC rates and higher sales to
core market customers.
The increase in Gas Utility total margin reflects a $5.3 million increase in
core market margin resulting from the higher core market sales. Margin from
interruptible customers decreased $0.6 million to $5.7 million in the 2000
three-month period reflecting the impact of higher natural gas prices on
interruptible customer unit margins.
Gas Utility EBITDA and operating income each increased $2.8 million reflecting
the previously mentioned increase in total margin and slightly higher other
income partially offset by a $3.5 million increase in operating and
administrative expenses. The increase in operating and administrative expenses
principally reflects higher charges for uncollectible accounts and greater
distribution system maintenance expenses.
ELECTRIC UTILITY. The increase in kilowatt-hour sales in the 2000 three-month
period reflects the impact on sales resulting from weather that was 21.5% colder
than the prior year. Electric Utility revenues increased principally as a result
of the higher sales. Electric Utility cost of sales was $10.9 million in the
2000 three-month period, an increase of $3.5 million from the prior year,
reflecting higher per unit purchased power costs and, to a lesser extent, the
higher sales.
Total margin decreased $2.3 million as a result of the higher purchased power
costs. EBITDA and operating income were lower than in the prior-year period
reflecting (1) the decrease in total margin and (2) lower other income.
ENERGY SERVICES. Revenues from Energy Services increased substantially from the
prior year three-month period reflecting higher natural gas prices and
acquisition-related volume growth. Natural gas volumes increased more than 90%
principally as a result of acquisitions completed in
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20
UGI CORPORATION AND SUBSIDIARIES
fiscal 2000. Total margin, EBITDA and operating income were higher in the 2000
three-month period as a result of the acquisition-related increase in total
volumes sold.
INTERNATIONAL PROPANE. International Propane results principally reflect the
results of FLAGA. The results of FLAGA in the 2000 three-month period were
adversely impacted by weather that was 19% warmer than normal and sales volumes
that were approximately 14% lower than in the prior-year period. The decrease in
total margin principally reflects the impact of foreign currency exchange rate
differences as well as the effects of the lower volumes sold. The decline in
EBITDA and increase in operating loss reflects the decline in total propane
margin.
CORPORATE & OTHER AND OTHER ENTERPRISES. Corporate & Other operating income was
$1.4 million in the 2000 three-month period compared to $0.4 million in the
prior-year period principally reflecting higher interest income on short-term
investments. Other Enterprises' operating loss decreased to $0.3 million in the
2000 three-month period from $1.4 million in the prior year reflecting income
from Enterprises' HVAC business acquired in late fiscal 2000 and improved
results from Hearth USA(TM).
INTEREST EXPENSE. Interest expense was $26.4 million in the 2000 three month
period compared to $23.8 million in the prior-year period principally reflecting
a $2.0 million increase in Partnership interest expense from higher levels of
long-term debt outstanding and greater borrowings under the Partnership's
Acquisition Facility.
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UGI CORPORATION AND SUBSIDIARIES
2000 TWELVE-MONTH PERIOD COMPARED WITH 1999 TWELVE-MONTH PERIOD
- --------------------------------------------------------------------------------
Increase
Twelve Months Ended December 31, 2000 1999 (Decrease)
- --------------------------------------------------------------------------------
(Millions of Dollars)
AMERIGAS PROPANE:
Revenues $1,251.6 $ 935.7 $ 315.9 33.8 %
Total margin $ 517.2 $ 490.7 $ 26.5 5.4 %
EBITDA $ 179.7 $ 162.2 $ 17.5 10.8 %
Operating income $ 109.3 $ 95.5 $ 13.8 14.5 %
Retail gallons sold (millions) 794.5 796.2 (1.7) (0.2)%
Degree days - % warmer than normal 3.7 11.0 -- --
GAS UTILITY:
Revenues $ 403.0 $ 353.0 $ 50.0 14.2 %
Total margin $ 176.5 $ 165.3 $ 11.2 6.8 %
EBITDA $ 108.1 $ 93.5 $ 14.6 15.6 %
Operating income $ 89.0 $ 74.2 $ 14.8 19.9 %
System throughput - billions of
Cubic feet ("bcf") 81.9 77.9 4.0 5.1 %
Degree days - % warmer than normal 2.0 11.0 -- --
ELECTRIC UTILITY:
Revenues $ 79.2 $ 76.0 $ 3.2 4.2 %
Total margin $ 38.2 $ 39.9 $ (1.7) (4.3)%
EBITDA $ 16.6 $ 18.8 $ (2.2) (11.7)%
Operating income $ 11.9 $ 14.8 $ (2.9) (19.6)%
Sales - millions of kilowatt hours 923.5 902.8 20.7 2.3 %
("gwh")
ENERGY SERVICES:
Revenues $ 228.6 $ 97.1 $ 131.5 135.4 %
Total margin $ 7.2 $ 6.4 $ 0.8 12.5 %
EBITDA $ 3.8 $ 2.8 $ 1.0 35.7 %
Operating income $ 3.6 $ 2.7 $ 0.9 33.3 %
INTERNATIONAL PROPANE:
Revenues $ 50.5 $ 13.9 $ 36.6 N.M.
Total margin $ 19.9 $ 5.8 $ 14.1 N.M.
EBITDA $ 1.6 $ 0.6 $ 1.0 N.M.
Operating loss $ 3.0 $ 0.5 $ 2.5 N.M.
- --------------------------------------------------------------------------------
N.M. - Not Meaningful.
-19-
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UGI CORPORATION AND SUBSIDIARIES
AMERIGAS PROPANE. Temperatures based upon heating degree days during the 2000
twelve-month period were 3.7% warmer than normal but 8.6% colder than the
prior-year period. Retail propane gallons sold were 1.7 million gallons lower as
a slight decline in heating-related sales were virtually offset by higher motor
fuel and PPX(R) sales. The Partnership estimates that 5 million to 10 million
gallons of retail propane sales in the 1999 twelve-month period were a result of
customers accelerating deliveries in advance of Y2K. Wholesale volumes of
propane sold were higher in the 2000 twelve-month period due in large part to
sales associated with propane product cost management activities.
Total revenues from retail propane sales increased $211.0 million due to
significantly higher average propane selling prices. Wholesale propane revenues
increased $104.7 million reflecting (1) a $65.2 million increase as a result of
higher average wholesale prices and (2) a $39.5 million increase as a result of
higher wholesale volumes sold. Nonpropane revenues in the 2000 twelve-month
period were virtually unchanged as higher customer fees and PPX(R) cylinder
sales revenues were offset by lower appliance and service revenue. Cost of sales
increased $289.4 million reflecting the higher propane product costs and greater
wholesale volumes.
Total margin increased $26.5 million due to (1) higher average retail unit
margins and (2) greater volumes sold to higher margin PPX(R) customers. Unit
margins late in the 2000 twelve-month period benefited from derivative hedging
gains and favorably priced supply arrangements.
EBITDA increased $17.5 million in the 2000 twelve-month period as the increase
in total margin was partially offset by an $11.4 million increase in the
Partnership's operating expenses. The higher operating expenses reflect
incremental expenses from growth and operational initiatives, higher vehicle
fuel and lease expenses, and greater uncollectible account expenses. Growth and
operational initiatives include PPX(R), acquiring retail propane businesses, and
developing and implementing more efficient methods of operating our core propane
distribution business. Operating income increased $13.8 million reflecting the
higher total margin partially offset by the higher operating expenses and
greater depreciation and amortization expense principally associated with
acquisitions.
GAS UTILITY. Weather in Gas Utility's service territory was 2.0% warmer than
normal in the 2000 twelve-month period and 9.9% colder than in the prior-year
period. The increase in system throughput resulted from higher heating-related
sales to core market customers and higher interruptible delivery service
volumes.
The increase in Gas Utility revenues includes a $41.8 million increase in core
market revenues reflecting higher average PGC rates and higher sales partially
offset by the impact on revenues resulting from the elimination of the gross
receipts tax effective January 1, 2000 pursuant to the Gas Competition Act. Gas
utility cost of gas was $226.6 million in the 2000 twelve-month period compared
with $174.3 million in the 1999 twelve-month period reflecting higher PGC rates
resulting from increased natural gas prices and greater core market sales.
-20-
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UGI CORPORATION AND SUBSIDIARIES
Gas Utility total margin increased $11.2 million principally reflecting (1) an
$8.1 million increase in core market margin and (2) a $3.2 million increase in
interruptible retail and delivery service margin.
Gas Utility EBITDA and operating income each increased $14.6 million and $14.8
million, respectively, principally a result of (1) the higher total margin and
(2) a $3.9 million increase in other income. Gas Utility's net operating
expenses in the 2000 twelve-month period were about equal to the prior-year
period, notwithstanding an increase in distribution system maintenance and
uncollectible customer account expenses, due to $4.5 million of income from
insurance litigation settlements.
ELECTRIC UTILITY. Electric sales for the 2000 twelve-month period increased 2.3%
on heating-season weather that was colder than in the prior-year period.
Revenues increased as a result of the higher sales as well as an increase in
transmission revenues from wholesale transmission services which were unbundled
as a result of electric customer choice. Cost of sales increased to $37.4
million from $32.9 million reflecting (1) higher per unit purchased power costs
during the 2000 three-month period; (2) costs associated with wholesale
transmission services; and (3) the higher 2000 twelve-month period sales.
Electric Utility total margin decreased $1.7 million as a result of the higher
purchased power costs experienced primarily during the 2000 three-month period.
EBITDA and operating income during the 2000 twelve-month period were lower
principally reflecting the lower total margin, a decrease in other income and,
with respect to operating income, higher depreciation charges associated with
electric generation facilities.
ENERGY SERVICES. Energy Services revenues increased dramatically in the 2000
twelve-month period reflecting higher natural gas prices and greater
acquisition-related sales volumes. Total margin, EBITDA and operating income
were higher as a result of the significant increase in sales in the 2000
twelve-month period.
INTERNATIONAL PROPANE. International Propane results in the 2000 twelve-month
period include full year results for FLAGA while the prior-year period includes
results for FLAGA only from the date of acquisition on September 21, 1999. As a
result, revenues, total margin, EBITDA and operating loss comparisons for the
twelve-month periods ended December 31, 2000 and 1999 are not meaningful.
CORPORATE & OTHER AND OTHER ENTERPRISES. Corporate & Other operating income in
both twelve-month periods principally includes interest income on short-term
investments and, in the 2000 twelve-month period, income from the sale of
certain equity securities. The decrease in operating loss from other Enterprises
in the 2000 twelve-month period reflects lower due diligence expenses associated
with international propane business opportunities and income from Enterprises'
HVAC business acquired in late fiscal 2000.
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UGI CORPORATION AND SUBSIDIARIES
INTEREST EXPENSE. Interest expense increased $13.9 million in the 2000
twelve-month period principally as a result of greater levels of Partnership
long-term debt outstanding and the full-year's interest on FLAGA debt.
FINANCIAL CONDITION AND LIQUIDITY
FINANCIAL CONDITION
The Company's debt outstanding totaled $1,288.0 million at December 31, 2000
compared to $1,250.3 million at September 30, 2000. The increase is primarily a
result of UGI Utilities' issuance of $20 million of five-year notes under its
Medium-Term Note program. The notes bear interest at a rate of 7.135%. The
proceeds were used for working capital purposes. The Operating Partnership
expects to refinance $58 million of maturing First Mortgage Notes in April 2001.
In October 2000, the Partnership issued 2,300,000 Common Units in a public
offering. The net proceeds from the Common Unit offering and related capital
contributions from the General Partner of approximately $40.6 million were used
by the Partnership to reduce Bank Credit Agreement borrowings and for working
capital purposes. As a result of the Partnership's public offering, at December
31, 2000 the Company holds an effective 55.5% interest in the Operating
Partnership.
During the three months ended December 31, 2000, the Partnership declared and
paid the minimum quarterly distribution of $0.55 (the "MQD") for the quarter
ended September 30, 2000. The MQD for the quarter ended December 31, 2000 will
be paid on February 18, 2001 to holders of record on February 9, 2001. The
ability of the Partnership to declare and pay the MQD on all units depends upon
a number of factors. These factors include (1) the level of Partnership
earnings; (2) the cash needs of the Partnership's operations (including cash
needed for maintaining and increasing operating capacity); (3) changes in
operating working capital; and (4) the Partnership's ability to borrow under its
Bank Credit Agreement, to refinance maturing debt, and to increase its long-term
debt. Some of these factors are affected by conditions beyond our control
including weather, competition in markets we serve, and the cost of propane.
CASH FLOWS
Our cash flows are seasonal and are generally greatest during the second and
third fiscal quarters when customers pay bills incurred during the heating
season and are typically at their lowest levels during the first and fourth
fiscal quarters. Accordingly, cash flows from operations during the three months
ended December 31, 2000 are not necessarily indicative of the cash flows to be
expected for a full year. Included in consolidated cash and short-term
investments at December 31, 2000 and 1999 are $64.4 million and $38.1 million,
respectively, of cash and short-term investments held by UGI.
OPERATING ACTIVITIES. Cash used by operating activities during the three months
ended December 31, 2000 totaled $16.3 million compared with $29.3 million during
the prior-year three-month period. Cash used to fund changes in working capital
totaled $86.6 million in the 2000 three-month period compared with $79.3 million
in the prior year. Changes in working capital during the three months
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UGI CORPORATION AND SUBSIDIARIES
ended December 31, 2000 reflect significant increases in accounts receivable
(due to greater natural gas and propane sales volumes and higher natural gas and
propane product costs) and a substantial increase in accounts payable. Cash flow
from operating activities before changes in working capital increased $20.3
million reflecting the 2000 three-month period's improved results.
INVESTING ACTIVITIES. Cash spent for property, plant and equipment totaled $17.7
million in the 2000 three-month period compared to $14.2 million in the prior
year. The increase reflects in large part the capitalization of approximately
$2.1 million of Partnership tank installation costs resulting from the
Partnership's change in accounting for such costs. During the 2000 three-month
period, the Company contributed $6.0 million in cash to Hunlock Creek Energy
Ventures in addition to the net assets of Electric Utility's Hunlock Creek
generating station (see "Formation of Hunlock Creek Energy Ventures" below).
FINANCING ACTIVITIES. During the three month periods ended December 31, 2000 and
1999, we paid cash dividends on Common Stock of $10.4 million and $10.2 million,
respectively, and the Partnership paid the MQD on all publicly held Common Units
(as well as on the Common and Subordinated units we own). During the 2000
three-month period, the Partnership received net proceeds of $39.8 million from
its public offering of 2,300,000 Common Units. In addition, UGI Utilities issued
$20 million of five-year notes under its Medium-Term Note program.
CHANGES IN ACCOUNTING
Effective October 1, 2000 (1) the Company adopted SFAS 133; (2) the Partnership
applied the guidance of SEC Staff Accounting Bulletin No. 101 entitled "Revenue
Recognition" ("SAB 101") with respect to its nonrefundable tank fees; and (3)
the Partnership changed its method of accounting for costs to install
Partnership-owned tanks at customer locations. The net effect of these
accounting changes on prior periods resulted in a $4.5 million increase in net
income for the quarter ended December 31, 2000 which amount is reflected on the
Condensed Consolidated Statements of Income as "cumulative effect of accounting
changes."
The adoption of SFAS 133 resulted in a cumulative effect charge to net income of
$0.3 million and a cumulative effect increase to accumulated other comprehensive
income of $7.1 million which amount represents the fair value of derivative
instruments qualifying and designated as cash flow hedges on October 1, 2000.
Because the Company's derivative instruments historically have been highly
effective in hedging exposure to changes in cash flows associated with
forecasted purchases or sales of natural gas and propane, changes in the fair
value of propane inventories, and changes in the risk-free rate of interest on
forecasted issuances of debt, we do not expect SFAS 133 will have a material
impact on our future results of operations. However, if such instruments are not
deemed highly effective in the future, or if the Company uses derivative
instruments that do not meet the stringent requirements for hedge accounting
under SFAS 133, future results could reflect greater volatility.
The adoption of SAB 101 resulted in a cumulative effect charge to net income of
$2.1 million representing the impact on prior periods resulting from the
application of SAB 101 as it relates to
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UGI CORPORATION AND SUBSIDIARIES
the Partnership's method of recognizing revenue associated with nonrefundable
fees for installed Partnership-owned tanks. Prior to October 1, 2000, such fees,
which are generally received annually, were recorded as revenue when billed. In
accordance with SAB 101, the Partnership now records such nonrefundable fees on
a straight-line basis over one year. The adoption of this revenue recognition
method is not expected to materially impact the Company's future financial
condition or results of operations.
In order to more appropriately match the costs of installing Partnership-owned
tanks at customer locations with the associated periods of benefit, the
Partnership changed its method of accounting for tank installation costs.
Previously, such costs were expensed as incurred. Effective October 1, 2000,
such costs are capitalized and amortized using an accelerated method that
reflects the attrition of the Partnership's customers. The change in accounting
for tank installation costs resulted in a cumulative effect increase to net
income of $6.9 million representing the impact on prior periods resulting from
the accounting change.
For a more detailed discussion of these accounting changes, see Note 3 to
Condensed Consolidated Financial Statements.
FORMATION OF HUNLOCK CREEK ENERGY VENTURES
On December 8, 2000, UGI Development Company, through a subsidiary, contributed
its coal-fired Hunlock Creek generating station ("Hunlock"), certain related
assets, and approximately $6 million in cash, to Hunlock Creek Energy Ventures
("Energy Ventures"), a general partnership jointly owned by the Company and a
subsidiary of Allegheny Energy, Inc., ("Allegheny"). Also on December 8, 2000,
Allegheny contributed a newly-constructed, gas-fired combustion turbine
generator to be operated at the Hunlock Site. Under the joint-venture agreement,
each partner is entitled to purchase 50% of the output of the joint venture at
cost. The Company's investment in Energy Ventures is being accounted for under
the equity method of accounting. The formation of the joint venture did not
materially impact the Company's results of operations during the three months
ended December 31, 2000.
IMPACT OF GAS RESTRUCTURING ORDER
On June 29, 2000, the Pennsylvania Public Utility Commission issued its order
("Gas Restructuring Order") approving Gas Utility's restructuring plan filed by
Gas Utility pursuant to Pennsylvania's Natural Gas Choice and Competition Act.
Among other things, the implementation of the Gas Restructuring Order resulted
in an increase in Gas Utility base rates effective October 1, 2000. This base
rate increase was designed to generate approximately $16.7 million in additional
annual revenues. The Gas Restructuring Order also provides that effective
October 1, 2000, Gas Utility must reduce its PGC rates by an amount sufficient
to result in a total reduction in PGC revenues of $16.7 million in the first
year of the base rate increase. As a result of the increase in base rates and
the PGC refund mechanism described above, Gas Utility's operating results will
be more sensitive to the effects of heating-season weather beginning in fiscal
2001.
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UGI CORPORATION AND SUBSIDIARIES
Beginning in fiscal 2002, Gas Utility is required to reduce its PGC rates by an
amount equal to the revenues it receives from customers served under
interruptible rates who do not obtain their own pipeline capacity. As a result,
Gas Utility expects that beginning in fiscal 2002 operating results will be less
sensitive to the market prices of alternative fuels than in prior fiscal years.
SUBSEQUENT EVENT
On January 30, 2001, the Partnership signed a definitive agreement to purchase
the retail propane distribution businesses of Columbia Energy Group ("Columbia")
for approximately $208 million. The Columbia propane businesses currently
comprise the fifth largest retail marketer of propane in the U.S. with total
sales of over 300 million gallons from 186 locations in 29 states. At closing
the seller will receive approximately $155 million cash and approximately $53
million of AmeriGas Partners Common Units. The cash portion of the purchase
price and transaction fees will be funded with approximately $55 million of
long-term debt issued by AmeriGas Partners and approximately $108 million of
first mortgage notes issued by the Operating Partnership. The transaction is
subject to customary conditions, including regulatory approval, and is expected
to close in March 2001.
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Our primary market risk exposures are (1) fluctuations in market prices for
propane, natural gas and electricity; (2) changes in interest rates; and (3)
foreign currency exchange rates.
The Partnership's profitability is sensitive to changes in propane supply costs,
and the Partnership generally attempts to pass on promptly increases in such
costs to customers. There is no assurance, however, that the Partnership will be
able to do so. In order to manage a portion of the Partnership's propane market
price risk, it uses contracts for the forward purchase of propane, propane
fixed-price supply agreements, and derivative commodity instruments such as
price swap and option contracts. Due to competitive and business conditions in
the markets it serves, FLAGA is less able than the Partnership to recover
promptly increases in product costs. FLAGA does not currently use derivative
commodity instruments to hedge propane market risk. In order to manage market
price risk relating to substantially all of Energy Services' forecasted
purchases of natural gas it sells under firm commitments, we purchase
exchange-traded natural gas futures contracts. In addition, we occasionally
utilize a managed program of derivative instruments including natural gas and
oil futures contracts to preserve gross margin associated with certain of our
natural gas customers. 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.
The current regulatory framework allows Gas Utility to recover prudently
incurred gas costs from its customers. Because of this ratemaking mechanism,
there is limited commodity price risk associated with our Gas Utility
operations.
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UGI CORPORATION AND SUBSIDIARIES
Electric Utility purchases electricity it does not otherwise produce,
representing approximately 50% of its electric power needs in 2000, under power
supply arrangements of varying length terms with other producers and on the spot
market. Spot market prices for electricity and, to a lesser extent, monthly
market-based contracts can be volatile, especially during periods of high
demand. Because Electric Utility's generation rates are capped through
approximately December 2002 under its Restructuring Order, any increases in the
cost of electricity will negatively impact Electric Utility's results.
We have market risk exposure from changes in interest rates on floating rate
borrowings under the Operating Partnership's Bank Credit Agreement, UGI
Utilities' revolving credit agreements and substantially all of FLAGA's debt.
These debt agreements have interest rates that are generally indexed to
short-term market interest rates. At December 31, 2000, combined borrowings
under these facilities totaled $302 million. Based upon average borrowings under
these agreements during fiscal 2000, an increase in short-term interest rates of
100 basis points (1%) would have increased interest expense on an annual basis
by $2.5 million. We also use fixed-rate long-term debt as a source of capital.
As these fixed-rate long-term debt issues mature, we intend to 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. On occasion, we enter into interest rate protection agreements
to reduce interest rate risk associated with a forecasted issuance of debt.
We do not currently use derivative instruments to hedge foreign currency
exposure associated with our current investments in international propane
operations, principally FLAGA. As a result, the U.S. dollar value of our foreign
denominated assets and liabilities will fluctuate with changes in the associated
foreign currency exchange rates. Our exposure to changes in foreign currency
exchange rates has been significantly limited, however, because our net
investment in FLAGA, our principal international propane operation, was financed
with EURO denominated debt. On occasion we may enter into foreign currency
exchange contracts associated with anticipated investments in foreign ventures.
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UGI CORPORATION AND SUBSIDIARIES
The following table summarizes the fair values of unsettled market risk
sensitive derivative instruments held at December 31, 2000. It also includes the
changes in fair value that would result if there were an adverse change in (1)
the market price of propane of 10 cents a gallon; (2) the market price of
natural gas of 50 cents a dekatherm; (3) interest rates on ten-year U.S.
treasury notes of 100 basis points; and (4) EURO conversion rates of 10%.
- --------------------------------------------------------------------------------
Fair Change in
Value Fair Value
- --------------------------------------------------------------------------------
(Millions of dollars)
December 31, 2000:
Propane commodity price risk $18.4 $(7.5)
Natural gas commodity price risk 13.9 (2.4)
Interest rate risk (0.5) (6.2)
Exchange rate risk - EURO 0.2 (1.0)
- --------------------------------------------------------------------------------
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UGI CORPORATION AND SUBSIDIARIES
PART II OTHER INFORMATION
ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K
(a) List of Exhibits:
10.1 Service Agreement by and among UGI Development Company and
Hunlock Creek Energy Ventures dated December 9, 2000,
incorporated by reference to Exhibit 10.1 to UGI Utilities,
Inc. Quarterly Report on Form 10-Q for the quarter ended
December 31, 2000
10.2 Service Agreement by and among Allegheny Energy Supply
Company, LLC and Hunlock Creek Energy Ventures dated December
9, 2000, incorporated by reference to Exhibit 10.2 to UGI
Utilities, Inc. Quarterly Report on Form 10-Q for the quarter
ended December 31, 2000
18 Letter re: change in accounting principles
27 Financial Data Schedule
(b) The Company filed a Current Report on Form 8-K dated November 10,
2000 to give advance notice of the webcast of its regular earnings
conference call under Item 5 of the Report.
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SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the
registrant has duly caused this report to be signed on its behalf by the
undersigned thereunto duly authorized.
UGI Corporation
------------------------------------
(Registrant)
Date: February 12, 2001 By: /s/ A.J. Mendicino
- ------------------------ -----------------------------------------
A. J. Mendicino, Vice President - Finance
and Chief Financial Officer
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EXHIBIT INDEX
EXHIBIT NO. Description
----------- -----------
18 Letter re: change in accounting principles
27 Financial data schedule