United States Securities and Exchange CommissionWashington, D.C. 20549
Form 10-QQUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the Quarterly Period Ended December 31, 2000
Commission File Number 1-3880
National Fuel Gas Company(Exact name of registrant as specified in its charter)
(Address of principal executive offices)
(716) 857-7000(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 and (2) has been subject to such filing requirements for the past 90 days. YES X NO
Indicate the number shares outstanding of each of the issuer's classes of common stock, as of the latest practicable date:
Common Stock, $1 Par Value, outstanding as of January 31, 2001: 39,488,393 shares.
INDEX
Part I. Financial Information PageItem 1. Financial Statements a. Consolidated Statements of Income and Earnings Reinvested in the Business - Three Months Ended December 31, 2000 and 1999 4 b. Consolidated Balance Sheets - December 31, 2000 and September 30, 2000 5 - 6 c. Consolidated Statement of Cash Flows - Three Months Ended December 31, 2000 and 1999 7 d. Consolidated Statement of Comprehensive Income - Three Months Ended December 31, 2000 and 1999 8 e. Notes to Consolidated Financial Statements 9 - 13 Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations 14 - 30 Item 3. Quantitative and Qualitative Disclosures About Market Risk 30Part II. Other InformationItem 1. Legal Proceedings 30 Item 2. Changes in Securities 30 Item 3. Defaults Upon Senior Securities o Item 4. Submission of Matters to a Vote of Security Holders o Item 5. Other Information o Item 6. Exhibits and Reports on Form 8-K 31 Signature 32
Reference to “the Company” in this report means the Registrant or the Registrant and its subsidiaries collectively, as appropriate in the context of the disclosure. All references to a certain year in this report are to the Company’s fiscal year ended September 30 of that year, unless otherwise noted.
This Form 10-Q contains “forward-looking statements” within the meaning of Section 21E of the Securities Exchange Act of 1934. Forward-looking statements should be read with the cautionary statements and important factors included in this Form 10-Q at Item 2 “Management’s Discussion and Analysis of Financial Condition and Results of Operations” (MD&A), under the heading “Safe Harbor for Forward-Looking Statements.” Forward-looking statements are all statements other than statements of historical fact, including, without limitation, those statements that are designated with a “*” following the statement, as well as those statements that are identified by the use of the words “anticipates,” “estimates,” “expects,” “intends,” “plans,” “predicts,” “projects,” and similar expressions.
National Fuel Gas CompanyConsolidated Statements of Income and EarningsReinvested in the Business(Unaudited)
Three Months Ended December 31, (Thousands of Dollars, Except Per Common Share Amounts) 2000 1999 INCOMEOperating Revenues $559,504 $377,031 Operating ExpensesPurchased Gas 273,080 128,089 Fuel Used in Heat and Electric Generation 16,064 17,780 Operation 96,324 77,524 Maintenance 4,967 5,155 Property, Franchise and Other Taxes 21,453 22,792 Depreciation, Depletion and Amortization 39,136 33,716 Income Taxes 33,359 21,738 484,383 306,794 Operating Income 75,121 70,237Other Income 8,165 1,172 Income Before Interest Charges and Minority Interest in Foreign Subsidiaries 83,286 71,409 Interest ChargesInterest on Long-Term Debt 19,058 16,671 Other Interest 10,329 8,559 29,387 25,230 Minority Interest in Foreign Subsidiaries (915) (1,311) Net Income Available for Common Stock 52,984 44,868 EARNINGS REINVESTED IN THE BUSINESSBalance at October 1 525,847 472,517 578,831 517,385 Dividends on Common Stock (2000 - $0.48; 1999 - $0.465) 18,891 18,084 Balance at December 31 $559,940 $499,301 =================================================================================Earnings Per Common Share:Basic $1.35 $1.15 ================================================================================= Diluted $1.32 $1.14 =================================================================================Weighted Average Common Shares Outstanding:Used in Basic Calculation 39,380,113 38,923,141 ================================================================================= Used in Diluted Calculation 40,173,174 39,413,008 =================================================================================
See Notes to Consolidated Financial Statements
National Fuel Gas CompanyConsolidated Balance Sheets
December 31, 2000 September 30, (Unaudited) 2000 (Thousands of Dollars) ASSETSProperty, Plant and Equipment $3,912,994 $3,829,637 Less - Accumulated Depreciation, Depletion and Amortization 1,188,062 1,146,246 2,724,932 2,683,391 Current AssetsCash and Temporary Cash Investments 36,880 32,125 Receivables - Net 262,071 122,127 Unbilled Utility Revenue 96,833 27,105 Gas Stored Underground 62,175 55,795 Materials and Supplies - at average cost 25,325 25,145 Unrecovered Purchased Gas Costs 49,336 29,681 Prepayments 20,209 32,293 552,829 324,271 Other AssetsRecoverable Future Taxes 84,199 84,199 Unamortized Debt Expense 21,853 19,841 Other Regulatory Assets 14,199 17,518 Deferred Charges 8,719 12,497 Other 98,714 95,171 227,684 229,226 $3,505,445 $3,236,888 =======================================================================================
December 31, 2000 September 30, (Unaudited) 2000 (Thousands of Dollars) CAPITALIZATION AND LIABILITIESCapitalization: Comprehensive Shareholders' EquityCommon Stock, $1 Par Value Authorized - 200,000,000 Shares; Issued and Outstanding - 39,418,824 Shares and 39,329,803 Shares, Respectively $ 39,419 $ 39,330 Paid in Capital 455,795 452,217 Earnings Reinvested in the Business 559,940 525,847 Total Common Shareholder Equity Before Items of Other Comprehensive Loss 1,055,154 1,017,394 Accumulated Other Comprehensive Loss (97,527) (29,957) Total Comprehensive Shareholders' Equity 957,627 987,437Long-Term Debt, Net of Current Portion 1,153,652 953,622 Total Capitalization 2,111,279 1,941,059 Minority Interest in Foreign Subsidiaries 25,681 23,031 Current and Accrued LiabilitiesNotes Payable to Banks and Commercial Paper 480,392 619,502 Current Portion of Long-Term Debt 11,232 11,262 Accounts Payable 167,643 88,853 Amounts Payable to Customers 7,707 9,583 Other Accruals and Current Liabilities 140,861 72,513 807,835 801,713 Deferred CreditsAccumulated Deferred Income Taxes 293,312 326,994 Taxes Refundable to Customers 14,410 14,410 Unamortized Investment Tax Credit 9,777 9,951 Other Deferred Credits 121,935 107,165 Fair Value of Derivative Financial Instruments 121,216 12,565 560,650 471,085 Commitments and Contingencies - - $3,505,445 $3,236,888 ============================================================================================
National Fuel Gas CompanyConsolidated Statement of Cash Flows(Unaudited)
Three Months Ended December 31, (Thousands of Dollars) 2000 1999 OPERATING ACTIVITIESNet Income Available for Common Stock $52,984 $44,868 Adjustments to Reconcile Net Income to Net Cash Provided by Operating Activities: Depreciation, Depletion and Amortization 39,136 33,716 Deferred Income Taxes 12,459 13,996 Minority Interest in Foreign Subsidiaries 915 1,311 Other (26) (838) Change in: Receivables and Unbilled Utility Revenue (208,770) (89,122) Gas Stored Underground and Materials and Supplies (6,206) 12,427 Unrecovered Purchased Gas Costs (19,655) (7,243) Prepayments 12,086 14,797 Accounts Payable 77,845 (14,706) Amounts Payable to Customers (1,876) (145) Other Accruals and Current Liabilities 68,389 16,605 Other Assets 350 4,739 Other Liabilities 252 (16,818) Net Cash Provided by Operating Activities 27,883 13,587 INVESTING ACTIVITIESCapital Expenditures (69,319) (57,817) Investment in Partnerships (30) (950) Other 8,229 436 Net Cash Used in Investing Activities (61,120) (58,331) FINANCING ACTIVITIESChange in Notes Payable to Banks and Commercial Paper (137,938) 65,330 Net Proceeds from Issuance of Long-Term Debt 197,294 - Reduction of Long-Term Debt (3,024) (9,279) Dividends Paid on Common Stock (18,844) (18,015) Proceeds from Issuance of Common Stock 2,310 4,300 Net Cash Provided by Financing Activities 39,798 42,336 Effect of Exchange Rates on Cash (1,806) (736) Net Increase (Decrease) in Cash and Temporary Cash Investments 4,755 (3,144)Cash and Temporary Cash Investments at October 1 32,125 29,222 Cash and Temporary Cash Investments at December 31 $36,880 $26,078 ==================================================================================================
National Fuel Gas CompanyConsolidated Statement of Comprehensive Income(Unaudited)
Three Months Ended December 31, (Thousands of Dollars) 2000 1999 Net Income Available for Common Stock $52,984 $44,868 Other Comprehensive Income (Loss), Before Tax: Foreign Currency Translation Adjustment 8,606 (9,501) Unrealized Gain on Securities Available for Sale 1,565 748 Unrealized Loss on Derivative Financial Instruments (41,658) - Reclassification Adjustment for Realized Losses on Derivative Financial Instruments in Net Income 30,332 - Other Comprehensive Loss, Before Tax (1,155) (8,753) Income Tax Expense Related to Unrealized Gain on Securities Available for Sale Arising During the Period 548 150 Income Tax Benefit Related to Unrealized Loss on Derivative Financial Instruments Arising During the Period (15,495) - Reclassification Adjustment for Income Tax Benefit on Realized Losses from Derivative Financial Instruments in Net Income 11,595 - Income Taxes - Net (3,352) 150 Other Comprehensive Income (Loss), Before Cumulative Effect, Net of Tax 2,197 (8,903) Cumulative Effect of Change in Accounting, Net of Tax (69,767) - Other Comprehensive Loss, After Cumulative Effect, Net of Tax (67,570) (8,903) Comprehensive (Loss) Income $(14,586) $35,965 =======================================================================================================
National Fuel Gas CompanyNotes to Consolidated Financial Statements
The preparation of the consolidated financial statements in conformity with generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Quarterly Earnings.The Company, in its opinion, has included all adjustments that are necessary for a fair statement of the results of operations for the reported periods. The consolidated financial statements and notes thereto, included herein, should be read in conjunction with the financial statements and notes for the years ended September 30, 2000, 1999 and 1998 that are included in the Company’s combined Annual Report to Shareholders/Form 10-K for 2000. The 2001 consolidated financial statements will be examined by the Company’s independent accountants after the end of the fiscal year.
The earnings for the three months ended December 31, 2000 should not be taken as a prediction of earnings for the entire year ending September 30, 2001. Most of the Utility segment’s business is seasonal in nature and is influenced by weather conditions. Because of the seasonal nature of the Utility segment’s heating business, earnings during the winter months normally represent a substantial part of the Utility segment’s earnings for the entire fiscal year. The impact of abnormal weather on earnings during the heating season is partially reduced by the operation of a weather normalization clause (WNC) included in Distribution Corporation’s New York tariff. The WNC is effective for October through May billings. Distribution Corporation’s tariff for its Pennsylvania jurisdiction does not have a WNC. While the Pipeline and Storage segment’s business is influenced by weather conditions, Supply Corporation’s straight fixed-variable rate design, which allows for recovery of substantially all fixed costs in the demand or reservation charge, reduces the earnings impact of weather fluctuations.
Consolidated Statement of Cash Flows. For purposes of the Consolidated Statement of Cash Flows, the Company considers all highly liquid debt instruments purchased with a maturity of generally three months or less to be cash equivalents.
Reclassification.Certain prior year amounts have been reclassified to conform with current year presentation.
Cumulative Effect of Change in Accounting. Effective October 1, 2000, the Company adopted the Financial Accounting Standards Board’s (FASB) Statement of Financial Accounting Standards No. 133, “Accounting for Derivative Instruments and Hedging Activities” (SFAS 133) as amended by SFAS 137, “Accounting for Derivative Instruments and Hedging Activities – Deferral of the Effective Date of FASB Statement No. 133” and by SFAS 138, “Accounting for Certain Derivative Instruments and Certain Hedging Activities, an amendment of Statement 133.” The cumulative effect of this change decreased other comprehensive income by $69.8 million after tax. The cumulative effect of this change did not have a material impact on net income. The derivative financial instruments that comprise the cumulative effect recorded in other comprehensive income have been designated and qualify as cash flow hedges. These instruments hedge the Company’s exposure to variability in expected future cash flows and relate primarily to the Company’s use of derivative financial instruments to manage a portion of the market risk associated with the fluctuations in the price of natural gas and crude oil. The liability for all of the Company’s derivative financial instruments was $121.2 million at December 31, 2000, and is reflected on the Consolidated Balance Sheet as Fair Value of Derivative Financial Instruments. The Consolidated Balance Sheet does not reflect the anticipated physical transactions related to the Company’s cash flow hedges.
Accumulated Other Comprehensive Income (Loss).The components of Accumulated Other Comprehensive Income (Loss)are as follows (in thousands):
At December 31, 2000 At September 30, 2000Cumulative Foreign Currency Translation Adjustment $(23,329) $(31,935) Net Unrealized Loss on Derivative Financial Instruments (77,193) - Net Unrealized Gain on Securities Available for Sale 2,995 1,978 -------- -------- Accumulated Other Comprehensive Loss $(97,527) $(29,957) ======== ========
Earnings Per Common Share. Basic earnings per common share is computed by dividing income available for common stock by the weighted average number of common shares outstanding for the period. Diluted earnings per common share reflects the potential dilution that could occur if securities or other contracts to issue common stock were exercised or converted into common stock. The only potentially dilutive securities the Company has outstanding are stock options. The diluted weighted average shares outstanding shown on the Consolidated Statement of Income reflects the potential dilution as a result of these stock options as determined using the Treasury Stock Method.
The components of federal and state income taxes included in the Consolidated Statement of Income are as follows (in thousands):
Three Months Ended December 31, ---------------------------------------- 2000 1999 ------------------- -------------------- Operating Expenses: Current Income Taxes Federal $13,656 $ 7,709 State 3,835 1,214 Foreign 3,409 (1,177) Deferred Income Taxes Federal 10,844 12,022 State 1,250 429 Foreign 365 1,541 - ------------------------------------------------------------- -------------------- 33,359 21,738 Other Income: Deferred Investment Tax Credit (175) (263) Minority Interest in Foreign Subsidiaries (407) (57) - ------------------------------------------------------------- -------------------- Total Income Taxes $32,777 $21,418 ============================================================= ====================
Three Months Ended December 31, 2000 1999 - ------------------------------------------- ------------------- -------------------- U.S. $76,751 $59,914 Foreign 9,010 6,372 - ------------------------------------------- ------------------- -------------------- $85,761 $66,286 =========================================== =================== ====================
Total income taxes as reported differ from the amounts that were computed by applying the federal income tax rate to income before income taxes. The following is a reconciliation of this difference (in thousands):
Three Months Ended December 31, ---------------------------------------- 2000 1999 ------------------- -------------------- Income tax expense, computed at statutory rate of 35% $30,016 $23,200 Increase (reduction) in taxes resulting from: State income taxes 3,304 1,068 Depreciation 445 476 Foreign tax in excess of (less than) statutory rate 214 (1,924) Miscellaneous (1,202) (1,402) - -------------------------------------------------- ------------------- -------------------- Total Income Taxes $32,777 $21,418 ================================================== =================== ====================
At December 31, 2000 At September 30, 2000 --------------------------------- ---------------------------- Deferred Tax Liabilities: Property, Plant and Equipment $382,907 $375,660 Deferred Gas Costs 17,593 10,454 Other 12,345 13,322 - -------------------------------------- --------------------------------- ---------------------------- Total Deferred Tax Liabilities 412,845 399,436 - -------------------------------------- --------------------------------- ---------------------------- Deferred Tax Assets: Tax Impact in Accumulated Other Comprehensive Loss (45,811) 1,065 Other (73,722) (73,507) - -------------------------------------- --------------------------------- ---------------------------- Total Deferred Assets (119,533) (72,442) - -------------------------------------- --------------------------------- ---------------------------- Total Net Deferred Income Taxes $293,312 $326,994 ====================================== ================================= ============================
Common Stock. During the three months ended December 31, 2000, the Company issued 89,021 shares of common stock under the Company’s stock and benefit plans.
Environmental Matters.The Company is subject to various federal, state and local laws and regulations relating to the protection of the environment. The Company has established procedures for the ongoing evaluation of its operations to identify potential environmental exposures and comply with regulatory policies and procedures. It is the Company’s policy to accrue estimated environmental clean-up costs (investigation and remediation) when such amounts can reasonably be estimated and it is probable that the Company will be required to incur such costs. At December 31, 2000, the Company has estimated its remaining clean-up costs related to former manufactured gas plant sites and third party waste disposal sites will be in the range of $5.7 million to $6.9 million. The minimum liability of $5.7 million has been recorded on the Consolidated Balance Sheet at December 31, 2000. Other than discussed in Note H of the 2000 Form 10-K (referred to below), the Company is currently not aware of any material additional exposure to environmental liabilities. However, adverse changes in environmental regulations or other factors could impact the Company.
For further discussion refer to Note H - Commitments and Contingencies under the heading “Environmental Matters” in Item 8 of the Company’s 2000 Form 10-K.
Other. The Company is involved in litigation arising in the normal course of business. The Company is involved in regulatory matters arising in the normal course of business that involve rate base, cost of service and purchased gas cost issues. While the resolution of such litigation or regulatory matters could have a material effect on earnings and cash flows in the year of resolution, none of this litigation, and none of these regulatory matters, are expected to have a material adverse effect on the financial condition of the Company at this time.
Note 5 – Business Segment Information. The Company has six reportable segments: Utility, Pipeline and Storage, Exploration and Production, International, Energy Marketing and Timber. The breakdown of the Company’s reportable segments is based upon a combination of factors including differences in products and services, regulatory environment and geographic factors.
The data presented in the tables below reflect the reportable segments and reconciliations to consolidated amounts. There have been no changes in the basis of segmentation nor in the basis of measuring segment profit or loss from those used in the 2000 Form 10-K. There have been no material changes in the amount of assets for any operating segment from the amounts disclosed in the 2000 Form 10-K.
Quarter Ended December 31, 2000 (Thousands)
Exploration Total Corporate and Pipeline and Energy Reportable Intersegment Total Utility and Storage Production International Marketing Timber Segments All Other Eliminations Consolidated - -------------------------------------------------------------------------------------------------------------------------------------------- Revenue from External Customers $348,131 $20,432 $101,254 $31,224 $48,186 $10,937 $560,164 $(660) $ - $559,504 Intersegment Revenues 6,037 22,233 - - - - 28,270 1,959 (30,229) - Segment Profit (Loss): Net Income 18,287 6,595 23,001 2,240 1,344 2,396 53,863 (732) (147) 52,984 Quarter Ended December 31, 1999 (Thousands) - -------------------------------------------------------------------------------------------------------------------------------------------- Exploration Total Corporate and Pipeline and Energy Reportable Intersegment Total Utility and Storage Production International Marketing Timber Segments All Other Eliminations Consolidated - -------------------------------------------------------------------------------------------------------------------------------------------- Revenue from External Customers $228,910 $21,071 $49,794 $38,073 $29,175 $8,740 $375,763 $1,268 $ - $377,031 Intersegment Revenues 4,306 22,094 224 - - - 26,624 - (26,624) - Segment Profit (Loss): Net Income 21,753 9,282 8,005 4,683 (17) 931 44,637 (146) 377 44,868
Earnings. The Company’s earnings were $53.0 million, or $1.35 per common share ($1.32 per common share on a diluted basis), for the quarter ended December 31, 2000. This compares to earnings of $44.9 million, or $1.15 per common share ($1.14 per common share on a diluted basis), for the quarter ended December 31, 1999. The increase in earnings of $8.1 million is the result of higher earnings in the Exploration and Production, Timber and Energy Marketing segments. These higher earnings were offset in part by lower earnings in the Utility, Pipeline and Storage and International segments. Additional discussion of earnings in each of the business segments can be found in the business segment information that follows.
Three Months Ended December 31 (Thousands) 2000 1999 - -------------------------------------------- ---------------- ----------------- Utility $18,287 $21,753 Pipeline and Storage 6,595 9,282 Exploration and Production 23,001 8,005 International 2,240 4,683 Energy Marketing 1,344 (17) Timber 2,396 931 - -------------------------------------------- ---------------- ----------------- Total Reportable Segments 53,863 44,637 All Other (732) (146) Corporate (147) 377 - -------------------------------------------- ---------------- ----------------- Total Consolidated $52,984 $44,868 - -------------------------------------------- ---------------- -----------------
Three Months Ended December 31 (Thousands) 2000 1999 - ---------------------------------------------- ---------------- ----------------- Retail Sales Revenues: Residential $252,558 $169,643 Commercial 43,819 27,160 Industrial 11,405 4,491 - ---------------------------------------------- ---------------- ----------------- 307,782 201,294 - ---------------------------------------------- ---------------- ----------------- Off-System Sales 21,987 8,366 Transportation 24,511 23,804 Other (112) (248) - ---------------------------------------------- ---------------- ----------------- $354,168 $233,216 - ---------------------------------------------- ---------------- -----------------
Three Months Ended December 31 (MMcf) 2000 1999 - ------------------------------------------ ---------------- ----------------- Retail Sales: Residential 24,001 20,466 Commercial 4,451 3,678 Industrial 1,674 986 - ------------------------------------------ ---------------- ----------------- 30,126 25,130 - ------------------------------------------ ---------------- ----------------- Off-System Sales 3,181 2,760 Transportation 17,514 16,808 - ------------------------------------------ ---------------- ----------------- 50,821 44,698 - ------------------------------------------ ---------------- -----------------
Operating revenues for the Utility segment increased $121.0 million for the quarter ended December 31, 2000 as compared with the same period a year ago. The increase in retail sales revenues is primarily the result of the recovery of higher gas costs stemming from an increase in retail gas sales volumes, as shown above (6.1 billion cubic feet (Bcf) increase for the quarter ended December 31, 2000), and an increase in the average cost of purchased gas ($7.43 and $4.43 per thousand cubic feet (Mcf) during the quarters ended December 31, 2000 and 1999, respectively). The increase in transportation revenues is a result of higher transportation volumes. Colder weather, as shown below, was the major factor for the increase in retail gas sales volumes and transportation volumes. Off-system sales revenues increased largely due to increased gas prices and slightly higher volumes. However, due to profit sharing with retail customers, the margins resulting from off-system sales are minimal. Partly offsetting these increases to revenue was the impact of a $10.0 million rate decrease for the Utility’s New York customers that went into effect October 1, 2000 in connection with the three year rate settlement reached with the New York State Public Service Commission. This rate decrease is provided in the form of a bill credit included in rates during the November 1 through March 31 heating season.
The Utility segment's first quarter 2001 earnings were $18.3 million, a decrease of $3.5 million when compared with the first quarter 2000 earnings. The most significant reasons for this decrease are the decrease in rates for the Utility's New York customers, mentioned above, as well as an increase in Operating and Maintenance (O&M) expense. The increase in O&M expense resulted from an after tax charge in December 2000 of approximately $0.6 million (after tax) for an early retirement offer accepted by certain employees in Pennsylvania and higher stock appreciation rights (SARs) expense of $2.6 million (after tax) compared to last year’s first quarter. Partly offsetting these decreases was the impact of weather, which in the Pennsylvania jurisdiction was approximately 26% colder than last year's first quarter. The impact of weather variations on earnings in the New York jurisdiction is mitigated by that jurisdiction's weather normalization clause (WNC). The WNC in New York, which covers the eight-month period from October through May, has had a stabilizing effect on earnings for the New York rate jurisdiction. In addition, in periods of colder than normal weather, the WNC benefits Distribution Corporation's New York customers. For the quarter ended December 31, 2000, the WNC resulted in a benefit to customers of $1.1 million (after tax) since it was colder than normal, while for the quarter ended December 31, 1999, the WNC preserved earnings for Distribution Corporation of $2.6 million (after tax) since it was warmer than normal.
Percent (Warmer) Colder Than Three Months Ended -------------------------------- December 31 Normal 2000 1999 Normal Prior Year - ---------------------------------- -------------- -------------- -------------------- ----------------- -------------- Buffalo 2,314 2,488 2,096 7.5% 18.7% Erie 2,030 2,332 1,854 14.9% 25.8% - ---------------------------------- -------------- -------------- -------------------- ----------------- --------------
Three Months Ended December 31 (Thousands) 2000 1999 - --------------------------------------------- ---------------- ----------------- Firm Transportation $22,741 $22,761 Interruptible Transportation 810 60 - --------------------------------------------- ---------------- ----------------- 23,551 22,821 - --------------------------------------------- ---------------- ----------------- Firm Storage Service 15,068 15,984 Interruptible Storage Service 168 122 - --------------------------------------------- ---------------- ----------------- 15,236 16,106 - --------------------------------------------- ---------------- ----------------- Other 3,878 4,238 - --------------------------------------------- ---------------- ----------------- $42,665 $43,165 - --------------------------------------------- ---------------- -----------------
Three Months Ended December 31 (MMcf) 2000 1999 - ----------------------------------------- ---------------- ----------------- Firm Transportation 89,542 82,630 Interruptible Transportation 5,950 241 - ----------------------------------------- ---------------- ----------------- 95,492 82,871 - ----------------------------------------- ---------------- -----------------
Operating revenues for the Pipeline and Storage segment decreased $0.5 million for the quarter ended December 31, 2000 as compared with the same period a year ago. This decrease was due mainly to lower revenues from firm storage service and lower revenues from unbundled pipeline sales and open access transportation offset, in part, by higher interruptible transportation revenues. While transportation volumes increased significantly, volume fluctuations generally do not have a significant impact on revenues as a result of Supply Corporation’s straight fixed-variable rate design. However, higher interruptible transportation volumes did contribute to an increase in interruptible transportation revenues, as shown above.
Earnings in the Pipeline and Storage segment decreased $2.7 million from $9.3 million for the quarter ended December 31, 1999 to $6.6 million for the quarter ended December 31, 2000. Lower operating revenues, as mentioned above, and higher O&M expense, contributed to this decrease. The increase in O&M expense was the result of a $0.6 million after tax charge for an early retirement offer in Pennsylvania in December 2000 and higher SARs expense (an increase of $3.3 million after tax) compared to last year’s first quarter. Partly offsetting these negative impacts to earnings was an increase in other income realized upon the buy-out by a customer of a long-term transportation contract ($2.6 million after tax).
Three Months Ended December 31 (Thousands) 2000 1999 - ---------------------------------------------- ---------------- ----------------- Gas (after Hedging) $32,324 $26,631 Oil (after Hedging) 42,474 17,575 Gas Processing Plant 10,517 4,092 Other 15,939 1,720 - ---------------------------------------------- ---------------- ----------------- $101,254 $50,018 - ---------------------------------------------- ---------------- -----------------
- ------------------------------------------ ---------------- ----------------- Three Months Ended December 31 2000 1999 - ------------------------------------------ ---------------- -----------------Gas Production (million cubic feet)Gulf Coast 6,429 7,946 West Coast 1,044 1,116 Appalachia 1,043 1,107 Canada 122 - - ------------------------------------------ ---------------- ----------------- 8,638 10,169 - ------------------------------------------ ---------------- -----------------Oil Production (thousands of barrels)Gulf Coast 356 322 West Coast 745 686 Appalachia 2 3 Canada 741 - - ------------------------------------------ ---------------- ----------------- 1,844 1,011 - ------------------------------------------ ---------------- -----------------
- --------------------------------------- ---------------- ----------------- Three Months Ended December 31 2000 1999 - --------------------------------------- ---------------- -----------------Average Gas Price/McfGulf Coast $5.91 $2.57 West Coast $9.36 $2.90 Appalachia $4.18 $2.90 Canada $4.75 - Weighted Average $6.10 $2.64 Weighted Average After Hedging $3.74 $2.62Average Oil Price/barrel (bbl)Gulf Coast $31.80 $23.36 West Coast $26.94 $19.97 Appalachia $30.90 $21.67 Canada $28.01 - Weighted Average $28.31 $21.06 Weighted Average After Hedging $23.03 $17.39 - --------------------------------------- ---------------- -----------------
Operating revenues for the Exploration and Production segment increased $51.2 million for the quarter ended December 31, 2000 as compared with the quarter ended December 31, 1999. Oil production revenue after hedging increased $24.9 million from last year’s first quarter as the weighted average price of oil after hedging increased 32% and oil production increased 82%. Oil production from Canadian wells acquired as part of the June 2000 acquisition of Tri Link Resources, Ltd. (Tri Link), now known as National Fuel Exploration Corp. (NFE), added $15.8 million to oil revenues. Gas production revenues after hedging increased $5.7 million principally due to the 43% increase in the weighted average price of gas after hedging. Higher gas prices more than compensated for an overall decrease in gas production. The decrease in production was greatest in the Gulf Coast region as there was a delay in placing new platforms on production and delays in work-over activity. These delays are due to personnel and equipment shortages and a tight rig market. Based on these delays, the Company has lowered its total production estimate for the year to 90–95 Bcfe (see Outlook for 2001 below). Revenue from Seneca’s gas processing plant was up $6.4 million due to higher gas prices. In addition, this segment recognized an increase of $13.6 million in revenues resulting from mark-to-market and other revenue adjustments related to derivative financial instruments. Refer to tables below for production and price information. Refer to further discussion of derivative financial instruments in the “Market Risk Sensitive Instruments” section that follows.
The Exploration and Production segment’s first quarter 2001 earnings were $23.0 million, an increase of $15.0 million when compared with the first quarter 2000 earnings of $8.0 million. As discussed above, significant increases in oil and gas pricing in the current quarter, an 82% increase in oil production, attributable mainly to NFE, and mark-to-market adjustments on derivative financial instruments, contributed to this earnings increase. Partly offsetting higher revenues was an increase in production related expenses, including higher depletion expense, lease operating costs, general and administrative expenses and production taxes, primarily attributable to NFE. Interest expense increased due to higher borrowings related to the acquisition of Tri Link.
Three Months Ended December 31 (Thousands) 2000 1999 - --------------------------------------------- ---------------- ----------------- Heating $21,717 $27,359 Electricity 8,875 9,243 Other 632 1,471 - --------------------------------------------- ---------------- ----------------- $31,224 $38,073 - --------------------------------------------- ---------------- -----------------
Three Months Ended December 31 2000 1999 - ------------------------------------------ ---------------- ----------------- Heating Sales (Gigajoules) (1) 3,365,555 3,967,768 Electricity Sales (megawatt hours) 330,024 317,655 - ------------------------------------------ ---------------- -----------------
(1) Gigajoules = one billion joules. A joule is a unit of energy.
Operating revenues for the International segment decreased $6.8 million for the quarter ended December 31, 2000 as compared to the quarter ended December 31, 1999. The decrease was primarily due to a decrease in heat sales resulting from warmer weather during the quarter ended December 31, 2000 compared to the quarter ended December 31, 1999. Also, the value of the Czech koruna (CZK) compared to the U.S. dollar was significantly lower than the first quarter of last year, further contributing to a decrease in revenues.
The International segment’s first quarter 2001 earnings were $2.2 million, a decrease of $2.4 million when compared with the first quarter 2000 earnings of $4.6 million. This decrease can be attributed to lower margins resulting from warmer weather and a non-recurring income tax adjustment made in the prior year. Also, the exchange rate impact discussed above had a negative impact on earnings. These decreases to earnings were partly offset by lower O&M expense and lower interest expense.
Three Months Ended December 31 (Thousands) 2000 1999 - --------------------------------------------- ------------------ ----------------- Natural Gas (after Hedging) $46,781 $28,627 Electricity 448 360 Other 957 188 - --------------------------------------------- ------------------ ----------------- $48,186 $29,175 - --------------------------------------------- ------------------ -----------------
Three Months Ended December 31 2000 1999 - ---------------------------------------- ------------------ ----------------- Natural Gas - (MMcf) 8,231 9,161 - ---------------------------------------- ------------------ -----------------
Operating revenues for the Energy Marketing segment increased $19.0 million for the quarter ended December 31, 2000 as compared with the quarter ended December 31, 1999. This increase reflects higher gas sales revenue due to the increased price of natural gas and a mark-to-market gain on certain derivative financial instruments.
NFR utilizes exchange-traded futures and exchange-traded options to manage a portion of the market risk associated with fluctuations in the price of natural gas. Refer to the further discussion of these hedging activities in the “Market Risk Sensitive Instruments” section that follows.
The Energy Marketing segment’s first quarter 2001 earnings were $1.3 million compared with a loss of $17,000 during the first quarter of 2000. This increase is a result of higher margins and a mark-to-market gain on certain derivative financial instruments offset, in part, by higher interest and O&M expense.
Three Months Ended December 31 (Thousands) 2000 1999 - ----------------------------------------------- ------------------ ----------------- Log Sales $6,412 $5,479 Green Lumber Sales 1,331 897 Kiln Dry Lumber Sales 3,006 2,190 Other 188 174 - ----------------------------------------------- ------------------ ----------------- Operating Revenues $10,937 $8,740 - ----------------------------------------------- ------------------ -----------------
Three Months Ended December 31 (Thousands) 2000 1999 - ------------------------------------------------- ------------------ ----------------- Log Sales 2,061 2,533 Green Lumber Sales 2,266 1,994 Kiln Dry Lumber Sales 2,068 1,608 - ------------------------------------------------- ------------------ ----------------- 6,395 6,135 - ------------------------------------------------- ------------------ -----------------
Operating revenues for the Timber segment increased $2.2 million for the quarter ended December 31, 2000 as compared with the quarter ended December 31, 1999. This increase is primarily the result of higher revenue from log sales, green lumber sales and kiln dry lumber sales. The increase in log sales revenues is the result of increased sales of higher quality logs at higher average prices which more than compensated for the overall decline in log sales as measured in board feet. The increase in green and kiln dry lumber sales is due to the operation of two more kilns brought on-line in August 2000.
The Timber segment’s first quarter 2001 earnings were $2.4 million, an increase of $1.5 million when compared with the first quarter 2000 earnings of $0.9 million. This increase is primarily the result of a $2.1 million pre tax ($1.3 million after tax) gain on the sale of certain timber properties. Higher revenues from timber sales also contributed to the increase, offset partially by higher O&M expenses.
Although variances in other income items and interest charges are discussed in the earnings discussion by segment above, following is a recap on a consolidated basis:
Other income increased $7.0 million for the quarter ended December 31, 2000 compared with the quarter ended December 31, 1999. This increase was principally due to a buyout of a long-term transportation contract by a customer in the Pipeline and Storage segment as well as a gain realized on the sale of certain timber properties in the Timber segment.
Interest on long-term debt increased $2.4 million for the quarter ended December 31, 2000 as compared with the quarter ended December 31, 1999. This increase can be attributed to a higher average amount of long-term debt outstanding and slightly higher weighted average interest rates.
Other interest charges increased $1.8 million for the quarter ended December 31, 2000. This increase resulted mainly from an increase in the average amount of short-term debt outstanding and higher weighted average interest rates in effect during the current quarter.
This outlook for 2001 section contains forward-looking statements, all of which are based on current expectations. There is no assurance that the Company’s projections will in fact be achieved and these projections do not reflect any acquisitions or divestitures which may occur during the remainder of 2001. Reference should be made to the various important factors listed under the heading “Safe Harbor for Forward-Looking Statements” that could cause actual future results to differ materially.
The Company continues to expect that earnings for 2001 will fall within the range of $168 million to $172 million, or $4.25 per basic common share to $4.35 per basic common share.* The Company further expects that earnings for the second quarter of 2001 will be within the range of $1.90 to $2.00 per basic common share.* Higher earnings in the Exploration and Production segment continue to be the main driver of the expected increase in earnings for 2001 as compared with actual earnings for 2000.* Production estimates for 2001 are in the range of 90 to 95 Bcfe (with oil representing 54% of that production).* Information on the Exploration and Production segment’s hedging program is provided in the “Market Risk Sensitive Instruments” section in Item 7 of the Company’s 2000 Form 10-K.
The Company’s primary sources of cash during the three-month period ended December 31, 2000 consisted of cash provided by operating activities and long-term debt. These sources were supplemented by issuances of common stock under the Company’s stock and benefit plans.
Internally generated cash from operating activities consists of net income available for common stock, adjusted for non-cash expenses, non-cash income and changes in operating assets and liabilities. Non-cash items include depreciation, depletion and amortization, deferred income taxes and minority interest in foreign subsidiaries.
Cash provided by operating activities in the Utility and the Pipeline and Storage segments may vary from period to period because of the impact of rate cases. In the Utility segment, supplier refunds, over- or under-recovered purchased gas costs and weather may also significantly impact cash flow. The impact of weather on cash flow is tempered in the Utility segment’s New York rate jurisdiction by its WNC and in the Pipeline and Storage segment by Supply Corporation’s straight fixed-variable rate design.
Because of the seasonal nature of the heating business in the Utility, Energy Marketing and International segments, revenues in these segments are relatively high during the heating season,
primarily the first and second quarters of the year, and receivables historically increase during these periods from what was receivable at September 30.
The storage gas inventory normally declines during the first and second quarters of the year and is replenished during the third and fourth quarters. For storage gas inventory accounted for under the last-in, first-out (LIFO) method, the current cost of replacing gas withdrawn from storage is recorded in the Consolidated Statements of Income and a reserve for gas replacement is recorded in the Consolidated Balance Sheets and is included under the caption “Other Accruals and Current Liabilities.” Such reserve is reduced as the inventory is replenished.
Net cash provided by operating activities totaled $27.9 million for the three months ended December 31, 2000, an increase of $14.3 million compared with the $13.6 million provided by operating activities for the three months ended December 31, 1999. The increase can be attributed primarily to higher cash receipts from the sale of oil and gas in the Exploration and Production segment. Oil and gas prices were up in this segment and oil production increased significantly due to the acquisition of Tri Link in June 2000. Partly offsetting this increase, higher working capital requirements in the Energy Marketing segment contributed to higher cash outflows in this segment.
Expenditures for long-lived assets include additions to property, plant and equipment (capital expenditures) and investments in corporations (stock acquisitions) or partnerships, net of any cash acquired.
The Company’s expenditures for long-lived assets totaled $69.3 million during the three months ended December 31, 2000. The table below presents these expenditures:
Three Months Ended December 31, 2000(in millions of dollars)------------------------------------------------- ----------------------- Total Expenditures for Long-Lived Assets ------------------------------------------------- ----------------------- Utility $10.1 Pipeline and Storage 6.4 Exploration and Production 42.7 International 9.5 Timber 0.6 Energy Marketing - All Other - ------------------------------------------------- ----------------------- $69.3 ------------------------------------------------- -----------------------
The majority of the Utility capital expenditures were made for replacement of mains and main extensions, as well as for the replacement of service lines.
The majority of the Pipeline and Storage capital expenditures were made for additions, improvements, and replacements to this segment’s transmission and storage systems.
At December 31, 2000, SIP had a $13.7 million investment in Independence Pipeline Company, a Delaware general partnership (Independence). This investment represents a one-third partnership interest. The investment has been financed with short-term borrowings. Independence intends to build a 400 mile natural gas pipeline (the Independence Pipeline) from Defiance, Ohio to Leidy, Pennsylvania at an estimated cost of $680 million.* If the Independence Pipeline project is not constructed, SIP’s share of the development costs (including SIP’s investment in Independence) is estimated not to exceed $15.0 million.*
On July 12, 2000, the Federal Energy Regulatory Commission (FERC) issued a Certificate of Public Convenience and Necessity (the Certificate) authorizing, among other things, the construction and operation of the Independence Pipeline, subject to satisfaction of various conditions spelled out in the Certificate and in previous FERC orders. Among those conditions is the requirement that, before construction may commence, Independence must file at FERC executed, firm transportation agreements with “no out” clauses for at least 68.2% of its capacity. (Independence already filed, on June 26 and July 6, 2000, precedent agreements for firm transportation amounting to about 38% of the capacity of the Independence Pipeline, thereby satisfying a FERC requirement previously imposed as a precondition to FERC’s issuance of the Certificate.) The Independence Pipeline partners are working on obtaining the required customer commitments. The Certificate also requires that the Independence Pipeline be constructed and placed in service by July 12, 2003. Assuming contracts are in place in quantities satisfactory to the partners by July 1, 2001, the Independence Pipeline’s planned in service date is November 1, 2002.*
The Certificate also includes an environmental condition that Independence file an "implementation plan" within 60 days after Independence accepted the Certificate. In October and November 2000, Independence timely filed a preliminary implementation plan which included a request for an extension of time to provide certain technical information, in order to allow the remaining field surveys (for example, for endangered species) to be commenced in spring 2001. This timing would be consistent with Independence's planned in service date of November 1, 2002, and the Certificate's deadline of July 12, 2003 to complete construction. On November 20, 2000, a FERC official issued a letter requiring Independence to file a full implementation plan, including the necessary technical information, by May 1, 2001, and warning that if Independence cannot comply with these terms, its Certificate authority could be in jeopardy. This letter also requires Independence to file monthly status reports on environmental permitting and land acquisition activities. Independence may be unable to file timely an implementation plan which meets the requirements set out in the November 20 letter.* It is therefore possible, but not likely, that Independence's application could be dismissed.* Dismissal of the application would jeopardize the project.* Independence continues to work on the activities which it believes are necessary to keep the Certificate in effect.
The Exploration and Production segment capital expenditures for the three months ended December 31, 2000 included approximately $24.1 million for Seneca’s offshore program in the Gulf of Mexico, including offshore drilling expenditures, offshore construction, lease acquisition costs and geological and geophysical expenditures. The remaining $18.6 million of capital expenditures included onshore drilling, construction and recompletion costs for wells located in Louisiana, Texas, California and Canada as well as onshore geological and geophysical costs, including the purchase of certain three-dimensional seismic data and fixed asset purchases. Of the $18.6 million disclosed above, $10.9 million was spent on the Exploration and Production segment’s Canadian properties.
The majority of the International segment capital expenditures were concentrated on the construction of a boiler at a district heating and power generation plant in the Czech Republic.
The majority of the Timber segment capital expenditures were made for purchases of land and timber for Seneca’s timber operations, as well as equipment for Highland’s sawmill and kiln operations. As discussed under the Timber segment’s results of operations, in November 2000 this segment sold timber properties with a book value of $5.2 million for $7.3 million.
The Company continuously evaluates capital expenditures and investments in corporations and partnerships. The amounts are subject to modification for opportunities such as the acquisition of attractive oil and gas properties, timber or storage facilities and the expansion of transmission line capacities. While the majority of capital expenditures in the Utility segment are necessitated by the continued need for replacement and upgrading of mains and service lines, the magnitude of future capital expenditures or other investments in the Company’s other business segments depends, to a large degree, upon market conditions.*
In November 2000, the Company issued $200.0 million of 7.50% medium-term notes due in November 2010. After deducting underwriting discounts and commissions, the net proceeds to the Company amounted to $197.3 million. The proceeds of this debt issuance were used to reduce short-term debt.
Consolidated short-term debt decreased $139.1 million during the first quarter of 2001. The Company continues to consider short-term debt an important source of cash for temporarily financing capital expenditures and investments in corporations and/or partnerships, gas-in-storage inventory, unrecovered purchased gas costs, exploration and development expenditures and other working capital needs. Fluctuations in these items can have a significant impact on the amount and timing of short-term debt.
In March 1998, the Company obtained authorization from the Securities and Exchange Commission (SEC), under the Public Utility Holding Company Act of 1935, to issue long-term debt securities and equity securities in amounts not exceeding $2.0 billion at any one time outstanding during the order’s authorization period, which extends to December 31, 2002. In August 1999, the Company registered $625 million of debt and equity securities under the Securities Act of 1933. After the November 2000 medium-term note issuance discussed above, the Company currently has $275.0 million of debt and equity securities registered under the Securities Act of 1933.
The Company’s present liquidity position is believed to be adequate to satisfy known demands.* Under the Company’s existing indenture covenants, at December 31, 2000, the Company would have been permitted to issue up to a maximum of $245.0 million in additional long-term unsecured indebtedness at projected market interest rates. Excluding the unrealized loss for derivative financial instruments reflected in Accumulated Other Comprehensive Loss on the Consolidated Balance Sheet, the Company would have been permitted to issue up to a maximum of $361.0 million in additional long-term unsecured indebtedness at projected market interest rates. In addition, at December 31, 2000, the Company had regulatory authorizations and unused short-term credit lines that would have permitted it to borrow an additional $269.6 million of short-term debt.
The amounts and timing of the issuance and sale of debt and/or equity securities will depend on market conditions, regulatory authorizations, and the requirements of the Company.
The Company is involved in litigation arising in the normal course of business. The Company is involved in regulatory matters arising in the normal course of business that involve rate base, cost of service and purchased gas cost issues, among other things. While the resolution of such litigation or regulatory matters could have a material effect on earnings and cash flows in the year of resolution, none of this litigation, and none of these regulatory matters, are expected to change materially the Company’s present liquidity position, nor have a material adverse effect on the financial condition of the Company.*
For a complete discussion of market risk sensitive instruments, refer to “Market Risk Sensitive Instruments” in Item 7 of the Company’s 2000 Form 10-K. There have been no subsequent material changes to the Company’s exposure to market risk sensitive instruments.
On October 11, 2000, the State of New York Public Service Commission (NYPSC) approved a settlement agreement (Agreement) between Distribution Corporation, Staff of the Department of Public Service, the New York State Consumer Protection Board and Multiple Intervenors (an advocate for large commercial and industrial customers) that establishes rates for a three-year period beginning October 1, 2000. The Agreement provides that customers will receive a bill credit of $17.6 million in the first year, of which $7.6 million relates to customers’ share of earnings accumulated under previous settlements. The credit will be reduced to $5.0 million in the second year, and in the third and subsequent years the credit will remain at $5.0 million unless the Company can demonstrate that it is no longer justified. Also, earnings beyond a target level of 11.5% return on equity will be shared equally between shareholders and ratepayers. The Agreement provides further that the Company and interested parties will resume discussions to address the NYPSC’s competition initiatives, including changes to “customer choice” transportation services, among other things. Those discussions are currently under way.
On November 3, 1998, the NYPSC issued its Policy Statement Concerning the Future of the Natural Gas Industry in New York State and Order Terminating Capacity Assignment (Policy Statement). The Policy Statement sets forth the NYPSC’s “vision” on “how best to ensure a competitive market for natural gas in New York.” That vision includes the following goals:
The Policy Statement provides that the most effective way to establish a competitive market in gas supply is “for local distribution companies to cease selling gas.” The NYPSC indicated in its order that it hopes to accomplish that objective over a three-to-seven year transition period from the date the Policy Statement was issued, taking into account “statutory requirements” and the individual needs of each local distribution company (LDC).* The Policy Statement directs Staff to schedule “discussions” with each LDC on an “individualized plan that would effectuate our vision.” In preparation for negotiations, LDCs will be required to address issues such as a strategy to hold new capacity contracts to a minimum, a long-term rate plan with a goal of reducing or freezing rates, and a plan for further unbundling. In addition, Staff was instructed to hold collaborative sessions with multiple parties to discuss generic issues including reliability and market power regulation. Distribution Corporation has participated in the collaborative sessions. These collaborative sessions have not yet produced a consensus document on all issues before the NYPSC. Distribution Corporation will continue to participate in all future collaborative sessions.*
On March 22, 2000, the NYPSC issued an order directing electric and gas utilities to file tariff amendments “to accommodate the wishes of retail access customers who prefer to receive combined, single bills from either their utility company or their [marketer]” (Billing Order). The tariff amendments will provide for marketer single-bill or utility single-bill services, thereby allowing a customer to choose a billing preference through the customer’s choice of suppliers – utility or marketer. Distribution Corporation has permitted marketer single billing since 1996.
On November 1, 2000, Distribution Corporation filed tariff amendments in compliance with the Billing Order (and a subsequent order on rehearing of the Billing Order). Consistent with the provisions of the Billing Order, Distribution Corporation’s filing proposes to maintain its long-standing marketer single-bill model and add a permanent version of a utility-provided competitive single-bill service that has been available since May 2000. In addition, the filing proposes a credit (called a “backout credit”), available to marketers that issue single retail bills, equal to the long-run marginal cost of billing services avoided by Distribution Corporation. Based on the methodology set forth in the Billing Order, Distribution Corporation calculated a backout credit of $0.66 per bill avoided. The charge for Distribution Corporation’s competitive billing service was set at $0.71 (with a backout credit). Distribution Corporation’s filing proposed an effective date of February 1, 2001 and is subject to review and approval by the NYPSC. On January 24, 2001 the NYPSC issued an order postponing the effective date through May 31, 2001. At this time, Distribution Corporation is unable to ascertain the outcome of this proceeding.*
On March 30, 2000, a collaborative was convened to address the NYPSC’s Order Instituting Proceeding in the so-called “Provider of Last Resort” (POLR) case. The collaborative was charged with the task of helping the NYPSC to “refine our concept of the mature competitive retail energy markets (especially the future role of the regulated utilities) and to identify and remove obstacles to its achievement.” The parties in this case are addressing, among other things, issues arising from utilities exiting the merchant function. The proceeding is also focusing on utilities’ responsibility to provide low-income assistance programs. Currently the parties are meeting on a periodic basis and attempting to develop consensus on various end-state models for consideration by the NYPSC. At this time, Distribution Corporation is unable to ascertain the outcome of the POLR proceeding.*
On April 12, 2000, the NYPSC issued an order setting forth procedures for implementation of electronic data interchange (EDI) for electronic exchange of retail access data in New York (EDI Order). As described by the NYPSC, EDI is the computer-to-computer exchange of routine business information in a standard form. The NYPSC believes that EDI is necessary to develop uniform data exchange protocol for the state’s customer choice initiatives. The EDI Order adopts provisions of a report prepared after an EDI collaborative involving utilities, marketers and other interests. Distribution Corporation submitted its EDI implementation plans on May 31, 2000. Initial (test-only) implementation of EDI, expected to begin during the fourth quarter of calendar 2000, has been slightly delayed. At this time, Distribution Corporation is unable to ascertain the outcome of the EDI proceeding.*
The NYPSC continues to address, through various proceedings and “collaboratives,” upstream pipeline capacity issues arising from the restructuring. Currently Distribution Corporation remains authorized to release upstream intermediate capacity to marketers serving former sales customers. Costs relating to retained upstream transmission capacity are recovered through a transition cost surcharge. At this time, Distribution Corporation does not foresee any material changes to upstream capacity requirements in the near term.*
On May 15, 2000, the New York State tax law was amended to phase out the long-running tax on utility gross revenues beginning January 1, 2001. Offsetting the scheduled reductions, however, is the imposition of a net income based tax on the same utilities. In a report issued on October 13, 2000, the New York Department of Public Service (Department) recommended, among other things, that utilities be kept whole for any tax increases resulting from implementation of the changes. Toward that end, the report proposed that the mechanism in rates currently used for recovery of the gross revenue tax would be utilized to collect the new income tax. To the extent a utility’s income tax liability exceeded the amount collectible through the existing gross revenue tax recovery mechanism, deferral accounting would be authorized. On December 18, 2000, Distribution Corporation and other parties submitted comments addressing Staff’s recommendations. Distribution Corporation’s comments expressed concern that the Department’s methodology for calculating amounts subject to deferral was flawed. On December 21, 2000, the NYPSC issued an abbreviated order adopting the Department’s recommendation. Distribution Corporation filed tariff amendments revising its tax recovery mechanism consistent with the order. A comprehensive order, describing the basis for the NYPSC’s decision, is forthcoming. The abbreviated order specified that the time for filing rehearing petitions “will be deemed to run from the date of issuance of the subsequent order.” At this time, Distribution Corporation is evaluating the effect of the abbreviated order and is unable to ascertain the outcome of this proceeding.*
Distribution Corporation currently does not have a rate case on file with the Pennsylvania Public Utility Commission (PaPUC). Management will continue to monitor its financial position in the Pennsylvania jurisdiction to determine the necessity of filing a rate case in the future.
A natural gas restructuring bill was signed into law on June 22, 1999. Entitled the Natural Gas Choice and Competition Act (Act), the new law requires all Pennsylvania LDCs to file tariffs designed to provide retail customers with direct access to competitive gas markets. Distribution Corporation submitted its compliance filing on October 1, 1999 for an effective date on or about July 1, 2000. The filing largely mirrored Distribution Corporation’s System Wide Energy Select program previously in effect, which substantially complied with the Act’s requirements. After negotiations with PaPUC Staff and intervenors, a settlement was reached with all parties except for the Pennsylvania Office of Consumer Advocate (OCA). The settlement parties generally agreed that Distribution Corporation’s proposal needed only modest changes to meet the requirements of the Act. Hearings were held and briefs filed on OCA’s open issues. In a Recommended Decision issued on March 31, 2000, the Administrative Law Judge rejected the OCA’s arguments and recommended approval of the settlement agreement. On June 29, 2000, the PaPUC entered an Opinion and Order adopting the settlement, with immaterial changes. Distribution Corporation’s restructured rates and services became effective on July 1, 2000.
Base rate adjustments in both the New York and Pennsylvania jurisdictions do not reflect the recovery of purchased gas costs. Such costs are recovered through operation of the purchased gas adjustment clauses of the appropriate regulatory authorities.
Supply Corporation currently does not have a rate case on file with the FERC. Management will continue to monitor Supply Corporation’s financial position to determine the necessity of filing a rate case in the future.
Environmental Matters. The Company is subject to various federal, state and local laws and regulations relating to the protection of the environment. The Company has established procedures for the ongoing evaluation of its operations to identify potential environmental exposures and comply with regulatory policies and procedures. It is the Company’s policy to accrue estimated environmental clean-up costs (investigation and remediation) when such amounts can reasonably be estimated and it is probable that the Company will be required to incur such costs. At December 31, 2000, the Company has estimated its remaining clean-up costs related to former manufactured gas plant sites and third party waste disposal sites will be in the range of $5.7 million to $6.9 million.* The minimum liability of $5.7 million has been recorded on the Consolidated Balance Sheet at December 31, 2000. Other than discussed in Note H of the 2000 Form 10-K (referred to below), the Company is currently not aware of any material additional exposure to environmental liabilities. However, adverse changes in environmental regulations or other factors could impact the Company.*
Safe Harbor for Forward-Looking Statements. The Company is including the following cautionary statement in this Form 10-Q to make applicable and take advantage of the safe harbor provisions of the Private Securities Litigation Reform Act of 1995 for any forward-looking statements made by, or on behalf of, the Company. Forward-looking statements include statements concerning plans, objectives, goals, strategies, future events or performance, and underlying assumptions and other statements which are other than statements of historical facts. From time to time, the Company may publish or otherwise make available forward-looking statements of this nature. All such subsequent forward-looking statements, whether written or oral and whether made by or on behalf of the Company, are also expressly qualified by these cautionary statements. Certain statements contained herein, including without limitation those which are designated with a “*", are forward-looking statements and accordingly involve risks and uncertainties which could cause actual results or outcomes to differ materially from those expressed in the forward-looking statements. The forward-looking statements contained herein are based on various assumptions, many of which are based, in turn, upon further assumptions. The Company’s expectations, beliefs and projections are expressed in good faith and are believed by the Company to have a reasonable basis, including, without limitation, management’s examination of historical operating trends, data contained in the Company’s records and other data available from third parties, but there can be no assurance that management’s expectations, beliefs or projections will result or be achieved or accomplished. In addition to other factors and matters discussed elsewhere herein, the following are important factors that, in the view of the Company, could cause actual results to differ materially from those discussed in the forward-looking statements:
The Company disclaims any obligation to update any forward-looking statements to reflect events or circumstances after the date hereof.
Refer to the “Market Risk Sensitive Instruments” section in Item 2 – Management’s Discussion and Analysis of Financial Condition and Results of Operations.
For a discussion of various environmental matters, refer to Part I, Item 1 at Note 4 and Part I, Item 2 – MD&A of this report under the heading “Other Matters.”
On October 2, 2000, the Company issued 840 unregistered shares of Company common stock to the seven non-employee directors of the Company. These shares were issued as partial consideration for the directors’ services during the quarter ended December 31, 2000, pursuant to the Company’s Retainer Policy for Non-Employee Directors. These transactions were exempt from registration by Section 4(2) of the Securities Act of 1933 as transactions not involving a public offering.
(a) Exhibits Exhibit Number Description of Exhibit ------- ---------------------- 3(ii) By-Laws: 3.1 National Fuel Gas Company By-Laws as amended on June 15, 2000. (12) Statements regarding Computation of Ratios: Ratio of Earnings to Fixed Charges for the Twelve Months Ended December 31, 2000 and the Fiscal Years Ended September 30, 1996 through 2000. (99) National Fuel Gas Company Consolidated Statement of Income for the Twelve Months Ended December 31, 2000 and 1999. (b) Reports on Form 8-K On October 17, 2000, the Company filed a Form 8-K under Item 5 regarding the results of a review of its derivative positions. This report did not include any financial statements. On November 2, 2000, the Company filed a Form 8-K under Item 5 regarding press releases issued by the Company and its subsidiary, Seneca Resources Corporation concerning earnings for the fourth quarter and fiscal year ended September 30, 2000. This report included partial financial statements and other financial information.
SIGNATURE
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.
NATIONAL FUEL GAS COMPANY(Registrant)/s/Joseph P. Pawlowski Joseph P. PawlowskiTreasurer andPrincipal Accounting Officer