10-Q 1 tenq304filingcopy.htm ENERGEN CORPORATION 3/31/04 10Q UNITED STATES

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D. C. 20549


FORM 10-Q


|X|

QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES

 

 

EXCHANGE ACT OF 1934 FOR THE QUARTER ENDED MARCH 31, 2004

 

OR

|  | 

TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES

 

 

EXCHANGE ACT OF 1934 FOR THE TRANSITION PERIOD FROM ___ TO ___

 

 

Commission

 

 

IRS Employer

 

 

File

 

State of

Identification

 

Number

Registrant

Incorporation

Number

 

1-7810

Energen Corporation

Alabama

63-0757759

 

 

2-38960

Alabama Gas Corporation

Alabama

63-0022000

 


605 Richard Arrington Jr. Boulevard North
Birmingham, Alabama 35203-2707
Telephone Number 205/326-2700
http://www.energen.com

Alabama Gas Corporation, a wholly owned subsidiary of Energen Corporation, meets the conditions set forth in General Instruction H(1)(a) and (b) of Form 10-Q and is therefore filing this Form with reduced disclosure format pursuant to General Instruction H(2).


Indicate by a check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities and Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrants were required to file such reports), and (2) have been subject to such filing requirements for the past 90 days. YES X NO ____

Indicate by check mark whether the registrant is an accelerated filer (as defined in Rule 12b-2 of the Exchange Act). YES X NO ____


Indicate the number of shares outstanding of each of the issuers' classes of common stock, as of May 5, 2004

 

Energen Corporation

$0.01 par value

36,342,788 shares

 

 

Alabama Gas Corporation

$0.01 par value

  1,972,052 shares

 

 

 

 

 

 

ENERGEN CORPORATION AND ALABAMA GAS CORPORATION

FORM 10-Q FOR THE QUARTER ENDED MARCH 31, 2004

 

 

 

TABLE OF CONTENTS

 

 

 

 

 

Page

 

PART I: FINANCIAL INFORMATION

 

 

 

 

 

 

Item 1.

Financial Statements

(a) Consolidated Condensed Statements of Income of Energen Corporation

 3

(b) Consolidated Condensed Balance Sheets of Energen Corporation

 4

(c) Consolidated Condensed Statements of Cash Flows of Energen Corporation

 6

(d) Condensed Statements of Income of Alabama Gas Corporation

 7

(e) Condensed Balance Sheets of Alabama Gas Corporation

 8

(f) Condensed Statements of Cash Flows of Alabama Gas Corporation

10

(g) Notes to Unaudited Condensed Financial Statements

11

Item 2.

Management's Discussion and Analysis of Financial Condition and
Results of Operations


20

Selected Business Segment Data of Energen Corporation

25

Item 3.

Quantitative and Qualitative Disclosures about Market Risk

26

Item 4.

Controls and Procedures

27

PART II: OTHER INFORMATION

Item 2.

Changes in Securities, Use of Proceeds and Issuer Purchases of Equity Securities

28

Item 4.

Submission of Matters to a Vote of Security Holders

28

Item 6.

Exhibits and Reports on Form 8-K

28

SIGNATURES

29

 

 

 

PART I. FINANCIAL INFORMATION

 

ITEM 1. FINANCIAL STATEMENTS

 

 

 

CONSOLIDATED CONDENSED STATEMENTS OF INCOME

ENERGEN CORPORATION

 

(Unaudited)

 

 

Three months ended

 

March 31,

(in thousands, except per share data)

2004

2003

 

 

 

Operating Revenues

 

 

Oil and gas operations

$    96,227

$   88,519

Natural gas distribution

255,202

221,139

     Total operating revenues

351,429

309,658

 

 

 

Operating Expenses

 

 

Cost of gas

138,738

111,972

Operations and maintenance

53,147

50,817

Depreciation, depletion and amortization

28,736

28,735

Taxes, other than income taxes

24,278

21,520

Accretion expense

490

494

     Total operating expenses

245,389

213,538

Operating Income

106,040

96,120

 

 

 

Other Income (Expense)

 

 

Interest expense

(10,318)

(10,822)

Other income

862

3,120

Other expense

(1,025)

(3,089)

     Total other expense

(10,481)

(10,791)

 

 

 

Income From Continuing Operations Before Income Taxes

95,559

85,329

Income tax expense

35,362

32,006

Income From Continuing Operations

60,197

53,323

 

 

 

Discontinued Operations, net of taxes

 

 

Income from discontinued operations

1

673

Gain (loss) on disposal

(13)

585

Income (Loss) From Discontinued Operations

(12)

1,258

 

 

 

Net Income

$     60,185

$      54,581

 

 

 

Diluted Earnings Per Average Common Share

 

 

Continuing operations

$     1.65

$      1.52

Discontinued operations

-

0.04

Net Income

$        1.65

$       1.56

Basic Earnings Per Average Common Share

 

 

Continuing operations

$     1.66

$       1.54

Discontinued operations

-

0.03

Net Income

$      1.66

$        1.57

Dividends Per Common Share

$       0.185

$       0.18

Diluted Average Common Shares Outstanding

36,566

35,034

Basic Average Common Shares Outstanding

36,173

34,729

The accompanying Notes are an integral part of these condensed financial statements.

 

 

 

CONSOLIDATED CONDENSED BALANCE SHEETS

 

 

ENERGEN CORPORATION

 

 

(Unaudited)

 

 

 

 

 

(in thousands)

March 31, 2004

December 31, 2003

 

 

 

ASSETS

 

 

Current Assets

 

 

Cash and cash equivalents

$      88,198

$       2,127

Accounts receivable, net of allowance for doubtful
    accounts of $10,353 at March 31, 2004, and
    $9,852 at December 31, 2003



147,827



172,915

Inventories, at average cost

 

 

    Storage gas inventory

17,046

40,654

    Materials and supplies

7,919

7,677

    Liquified natural gas in storage

3,266

3,475

Deferred income taxes

46,927

38,145

Prepayments and other

36,925

25,073

 

 

 

    Total current assets

348,108

290,066

 

 

 

Property, Plant and Equipment

 

 

Oil and gas properties, successful efforts method

1,215,490

1,197,340

Less accumulated depreciation, depletion and amortization

326,071

310,368

    Oil and gas properties, net

889,419

886,972

Utility plant

896,989

883,225

Less accumulated depreciation

349,483

341,787

    Utility plant, net

547,506

541,438

Other property, net

4,962

5,041

    Total property, plant and equipment, net

1,441,887

1,433,451

 

 

 

Other Assets

 

 

Regulatory asset

18,082

18,082

Deferred charges and other

31,933 

39,833

 

 

 

    Total other assets

50,015 

57,915

 

 

 

TOTAL ASSETS

$   1,840,010 

$   1,781,432



The accompanying Notes are an integral part of these condensed financial statements.

 

CONSOLIDATED CONDENSED BALANCE SHEETS

 

 

ENERGEN CORPORATION

 

 

(Unaudited)

 

 

 

 

 

(in thousands, except share data)

March 31, 2004

December 31, 2003

 

 

 

CAPITAL AND LIABILITIES

 

 

Current Liabilities

 

 

Long-term debt due within one year

$      10,000

$      10,000

Notes payable to banks

-

11,000

Accounts payable

141,860

135,319

Accrued taxes

48,312

28,551

Customers' deposits

18,710

17,884

Amounts due customers

-

8,571

Accrued wages and benefits

19,913

24,957

Regulatory liability

48,915

54,146

Other

44,899

37,303

 

 

 

    Total current liabilities

332,609

327,731

 

 

 

Deferred Credits and Other Liabilities

 

 

Asset retirement obligation

26,885

26,515

Minimum pension liability

19,571

17,911

Regulatory liability

106,705

113,427

Deferred income taxes

46,939

33,200

Other

12,071

10,774

 

 

 

    Total deferred credits and other liabilities

212,171

201,827

Commitments and Contingencies

 

 

 

 

 

Capitalization

 

 

Preferred stock, cumulative $0.01 par value, 5,000,000
    shares authorized



-

Common shareholders' equity

 

 

    Common stock, $0.01 par value; 75,000,000 shares authorized, 36,344,722 shares outstanding at March 31, 2004, and 36,223,531 shares outstanding at December 31, 2003



363



362

    Premium on capital stock

374,440

367,765

    Capital surplus

2,802

2,802

    Retained earnings

413,467

360,001

    Accumulated other comprehensive loss, net of tax

 

 

Unrealized loss on hedges

(35,533)

(21,714)

Minimum pension liability

(8,881)

(8,881)

Deferred compensation on restricted stock

(3,431)

(1,258)

Deferred compensation plan

18,300

17,063

Treasury stock, at cost (446,731 shares at March 31, 2004,
    and 415,869 shares at December 31, 2003)


(19,171)


(17,108)

    Total common shareholders' equity

742,356

699,032

Long-term debt

552,874

552,842

    Total capitalization

1,295,230

1,251,874

 

 

 

TOTAL CAPITAL AND LIABILITIES

$   1,840,010

$   1,781,432



The accompanying Notes are an integral part of these condensed financial statements.

CONSOLIDATED CONDENSED STATEMENTS OF CASH FLOWS

 

ENERGEN CORPORATION

 

 

(Unaudited)

 

 

 

 

 

Three months ended March 31, (in thousands)

2004

2003

 

 

 

Operating Activities

 

 

Net income

$     60,185

$     54,581

Adjustments to reconcile net income to net cash

 

 

provided by (used in) operating activities:

 

 

    Depreciation, depletion and amortization

28,736

29,437

    Deferred income taxes

12,777

8,982

    Deferred investment tax credits

(112)

(112)

    Change in derivative fair value

2,532

1,620

    (Gain) loss on sale of assets

78

(9,167)

    Loss on properties held-for-sale

-

8,247

Net change in:

 

 

     Accounts receivable

11,336

(46,200)

     Inventories

23,575

13,041

     Accounts payable

(15,804)

26,687

     Amounts due customers

(11,360)

(3,103)

     Other current assets and liabilities

21,781

23,789

Other, net

1,859

(2,671)

 

 

 

    Net cash provided by operating activities

135,583 

105,131 

 

 

 

Investing Activities

 

 

Additions to property, plant and equipment

(34,934)

(68,444)

Proceeds from sale of assets

-

15,460

Other, net

(81)

74

 

 

 

    Net cash used in investing activities

(35,015)

(52,910)

 

 

 

Financing Activities

 

 

Payment of dividends on common stock

(6,719)

(6,275)

Issuance of common stock

3,522

4,319

Purchase of treasury stock

(300)

(294)

Net change in short-term debt

(11,000)

(48,000)

 

 

 

    Net cash used in financing activities

(14,497) 

(50,250) 

 

 

 

Net change in cash and cash equivalents

86,071

1,971 

Cash and cash equivalents at beginning of period

2,127

4,804 

 

 

 

Cash and Cash Equivalents at End of Period

$      88,198

$      6,775 



The accompanying Notes are an integral part of these condensed financial statements.

 

CONDENSED STATEMENTS OF INCOME

 

 

ALABAMA GAS CORPORATION

 

 

(Unaudited)

 

 

 

Three months ended

 

March 31,

(in thousands)

2004

2003

Operating Revenues

$ 255,202

$   221,139

 

 

 

Operating Expenses

 

 

Cost of gas

139,206

112,564

Operations and maintenance

28,597

28,448

Depreciation

9,610

8,925

Income taxes

 

 

    Current

20,802

19,503

    Deferred, net

1,458

1,043

    Deferred investment tax credits, net

(112)

(112)

Taxes, other than income taxes

15,775

14,002

 

 

 

     Total operating expenses

215,336

184,373

 

 

 

Operating Income

39,866

36,766

 

 

 

Other Income (Expense)

 

 

Allowance for funds used during construction

300

323

Other income

704

1,241

Other expense

(1,016)

(1,323)

     Total other income (expense)

(12)

241

 

 

 

Interest Charges

 

 

Interest on long-term debt

2,987

3,237

Other interest expense

548

323

 

 

 

    Total interest charges

3,535

3,560

 

 

 

Net Income

$ 36,319

$    33,447


The accompanying Notes are an integral part of these condensed financial statements.

CONDENSED BALANCE SHEETS

 

 

ALABAMA GAS CORPORATION

 

 

(Unaudited)

 

 

(in thousands)

March 31, 2004

December 31, 2003

 

 

 

ASSETS

 

 

Property, Plant and Equipment

 

 

Utility plant

$   896,989

$   883,225

Less accumulated depreciation

349,483

341,787

 

 

 

    Utility plant, net

547,506

541,438

 

 

 

Other property, net

329

331

 

 

 

Current Assets

 

 

Cash and cash equivalents

5,922

1,440

Accounts receivable

 

 

    Gas

112,265

134,376

    Merchandise

1,559

1,210

    Other

1,513

1,018

    Affiliated companies

18,923

-

    Allowance for doubtful accounts

(9,400)

(9,100)

Inventories, at average cost

 

 

    Storage gas inventory

17,046

40,654

    Materials and supplies

4,852

5,527

    Liquified natural gas in storage

3,266

3,475

Deferred income taxes

18,301

17,650

Regulatory asset

-

251

Prepayments and other

34,316

22,056

 

 

 

    Total current assets

208,563

218,557

 

 

 

Other Assets

 

 

Regulatory asset

18,082

18,082

Deferred charges and other

10,876

19,285

 

 

 

    Total other assets

28,958

37,367

 

 

 

TOTAL ASSETS

$   785,356

$   797,693



The accompanying Notes are an integral part of these condensed financial statements.

 

CONDENSED BALANCE SHEETS

 

 

ALABAMA GAS CORPORATION

 

 

(Unaudited)

 

 

 

 

 

(in thousands, except share data)

March 31, 2004

December 31, 2003

 

 

 

CAPITAL AND LIABILITIES

 

 

Capitalization

 

 

Preferred stock, cumulative $0.01 par value, 120,000 shares
    authorized, issuable in series-$4.70 Series


$              -


$           -

Common shareholder's equity

 

 

    Common stock, $0.01 par value; 3,000,000 shares
       authorized, 1,972,052 shares outstanding at
       March 31, 2004, and December 31, 2003



           20



         20

    Premium on capital stock

31,682

31,682

    Capital surplus

2,802

2,802

    Retained earnings

245,487

215,869

 

 

 

    Total common shareholder's equity

279,991

250,373

Long-term debt

169,533

169,533

 

 

 

    Total capitalization

449,524

419,906

 

 

 

Current Liabilities

 

 

Notes payable to banks

-

11,000

Accounts payable

56,079

56,020

Amounts due to affiliates

-

37,290

Accrued taxes

43,513

22,145

Customers' deposits

18,710

17,884

Amounts due customers

-

8,571

Accrued wages and benefits

5,528

6,247

Regulatory liability

48,915

54,146

Other

10,825

9,039

 

 

 

    Total current liabilities

183,570

222,342

 

 

 

Deferred Credits and Other Liabilities

 

 

Deferred income taxes

34,362

32,178

Minimum pension liability

8,285

6,988

Regulatory liability

106,705

113,427

Other

2,910

2,852

 

 

 

     Total deferred credits and other liabilities

152,262

155,445

 

 

 

Commitments and Contingencies

-

-

 

 

 

TOTAL CAPITAL AND LIABILITIES

$   785,356

$   797,693



The accompanying Notes are an integral part of these condensed financial statements.

 

CONDENSED STATEMENTS OF CASH FLOWS

 

 

ALABAMA GAS CORPORATION

 

 

(Unaudited)

 

 

 

 

 

Three months ended March 31, (in thousands)

2004

2003

 

 

 

Operating Activities

 

 

Net income

$     36,319

$     33,447

Adjustments to reconcile net income to net cash

 

 

provided by (used in) operating activities:

 

 

    Depreciation and amortization

9,610

8,925

    Deferred income taxes, net

1,458

1,043

    Deferred investment tax credits

(112)

(112)

Net change in:

 

 

    Accounts receivable

7,815

(24,393)

    Inventories

24,492

13,530

    Accounts payable

310

31,735

    Amounts due customers

(11,360)

(3,103)

    Other current assets and liabilities

22,137

17,204

Other, net

1,200

(143)

 

 

 

    Net cash provided by operating activities

91,869

78,133

 

 

 

Investing Activities

 

 

Additions to property, plant and equipment

(13,490)

(14,613)

Other, net

17

26

 

 

 

    Net cash used in investing activities

(13,473)

(14,587)

 

 

 

Financing Activities

 

 

Dividends

(6,701)

-

Net advances from (to) affiliates

(56,213)

(50,194)

Net change in short-term debt

(11,000)

(13,000)

 

 

 

    Net cash used in financing activities

(73,914)

(63,194)

 

 

 

Net change in cash and cash equivalents

4,482

352

Cash and cash equivalents at beginning of period

1,440

2,818

 

 

 

Cash and Cash Equivalents at End of Period

$        5,922

$        3,170



The accompanying Notes are an integral part of these condensed financial statements.

 

NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS
ENERGEN CORPORATION AND ALABAMA GAS CORPORATION

1. BASIS OF PRESENTATION


The unaudited financial statements and notes should be read in conjunction with the financial statements and notes thereto for the years ended December 31, 2003 and 2002, the three months ended December 31, 2001, and the year ended September 30, 2001, included in the 2003 Annual Report of Energen Corporation (the Company) and Alabama Gas Corporation (Alagasco) on Form 10-K. On December 5, 2001, the Board of Directors of the Company approved a change in the Company's fiscal year end from September 30 to December 31, effective January 1, 2002. A transition report was filed on Form 10-Q for the period October 1, 2001, to December 31, 2001. Alagasco is on a September 30 fiscal year for rate-setting purposes (rate year) and reports on a calendar year for the Securities and Exchange Commission and all other financial accounting reporting purposes. The accompanying unaudited condensed financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America for interim financial information and with the instructions to Form 10-Q and Rule 10-01 of Regulation S-X. Accordingly, they do not include all of the disclosures required for complete financial statements. The year-end consolidated condensed balance sheet data was derived from audited financial statements, but does not include all disclosures required by accounting principles generally accepted in the United States of America. The Company's natural gas distribution business is seasonal in character and influenced by weather conditions. Results of operations for interim periods are not necessarily indicative of the results that may be expected for the year.

The quarterly information reflects the application of Statement of Financial Accounting Standard (SFAS) No. 144, "Accounting for Impairment or Disposal of Long-Lived Assets". SFAS No. 144 requires that gains and losses from the sale of certain oil and gas properties and write-downs of certain properties held-for-sale be reported as discontinued operations, with income or loss from operations of the associated properties reported as income or loss from discontinued operations in the current and prior periods. All other adjustments to the unaudited financial statements that are, in the opinion of management, necessary for a fair statement of the results of operations for the interim periods have been recorded. Such adjustments consisted of normal recurring items. Certain reclassifications were made to conform prior years' financial statements to the current-quarter presentation.

  1. STOCK-BASED COMPENSATION

The Company adopted the fair value recognition provisions of SFAS No. 123 (as amended), "Accounting for Stock-Based Compensation," prospectively for all stock-based employee compensation effective as of January 1, 2003. Awards under the Company's plan vest over periods ranging from one to four years; therefore, the cost related to stock-based employee compensation included in the determination of net income for the three months ended March 31, 2004 and 2003, approximates that which would have been recognized if the fair value method had been applied to all awards since the original effective date of SFAS No. 123. The following table illustrates the effect on net income and diluted and basic earnings per share as if the fair value based method had been applied to all outstanding and unvested awards in each period:

 

 

Three months ended

March 31,

(in thousands)

2004

2003

Net income

 

 

As reported

$ 60,185

$ 54,581

Stock-based compensation expense included in reported net income, net of tax

1,043

682

Stock-based compensation expense determined under fair value based method, net of tax

(916)

(833)

Pro forma

$ 60,312

$ 54,430

Diluted earnings per average common share

 

 

As reported

$ 1.65

$ 1.56

Pro forma

$ 1.65

$ 1.55

Basic earnings per average common share

 

 

As reported

$ 1.66

$ 1.57

Pro forma

$ 1.67

$ 1.57

3. REGULATORY

All of Alagasco's utility operations are conducted in the state of Alabama. Alagasco is subject to regulation by the APSC which established the Rate Stabilization and Equalization (RSE) rate-setting process in 1983. RSE was extended with modifications in 2002, 1996, 1990, 1987 and 1985. On June 10, 2002, the APSC extended Alagasco's rate-setting methodology, RSE, without change, for a six-year period through January 1, 2008. Under the terms of that extension, RSE will continue after January 1, 2008, unless, after notice to the Company and a hearing, the Commission votes to either modify or discontinue its operation. Alagasco's allowed range of return on average equity remains 13.15 percent to 13.65 percent throughout the term of the order, subject to change in the event that the Commission, following a generic rate of return hearing, adjusts the equity returns of all major energy utilities operating under a similar methodology. Under RSE as extended, the APSC conducts quarterly reviews to determine, based on Alagasco's projections and year-to-date performance, whether Alagasco's return on average equity at the end of the rate year will be within the allowed range of 13.15 percent to 13.65 percent. Reductions in rates can be made quarterly to bring the projected return within the allowed range; increases, however, are allowed only once each rate year, effective December 1, and cannot exceed 4 percent of prior-year revenues. As of September 30, 2003, Alagasco had a $3 million reduction in revenues to bring the return on average equity within the allowed range of return. RSE limits the utility's equity upon which a return is permitted to 60 percent of total capitalization and provides for certain cost control measures designed to monitor Alagasco's operations and maintenance (O&M) expense. Under the inflation-based cost control measurement established by the APSC, if the percentage change in O&M expense per customer falls within a range of 1.25 points above or below the percentage change in the Consumer Price Index For All Urban Consumers (index range), no adjustment is required. If the change in O&M expense per customer exceeds the index range, three-quarters of the difference is returned to customers. To the extent the change is less than the index range, the utility benefits by one-half of the difference through future rate adjustments. The increase in O&M expense per customer was slightly above the index range for the rate year ended September 30, 2003; as a result, the utility returned to customers $0.1 million pre-tax through rate adjustments under the provisions of RSE. An $11.2 million and a $12.7 million annual increase in revenues became effective December 1, 2003 and 2002, respectively, under RSE.

Alagasco calculates a temperature adjustment to customers' monthly bills to substantially remove the effect of departures from normal temperatures on Alagasco's earnings. Adjustments to customers' bills are made in the same billing cycle in which the weather variation occurs. The temperature adjustment applies primarily to residential, small commercial and small industrial customers. Alagasco's rate schedules for natural gas distribution charges contain a Gas Supply Adjustment (GSA) rider, established in 1993, which permits the pass-through to customers of changes in the cost of gas supply.

4. DERIVATIVE COMMODITY INSTRUMENTS

The Company applies SFAS No. 133 (as amended), "Accounting for Derivative Instruments and Hedging Activities," which requires all derivatives to be recognized on the balance sheet and measured at fair value. If a derivative is designated as a cash flow hedge, the Company is required to measure the effectiveness of the hedge, or the degree that the gain (loss) for the hedging instrument offsets the loss (gain) on the hedged item, at each reporting period. The effective portion of the gain or loss on the derivative instrument is recognized in other comprehensive income (OCI) as a component of equity and subsequently reclassified into earnings as operating revenues when the forecasted transaction affects earnings. The ineffective portion of a derivative's change in fair value is required to be recognized in earnings immediately. Derivatives that do not qualify for hedge treatment under SFAS No. 133 must be recorded at fair value with gains or losses recognized in earnings in the period of change.

 

Energen Resources Corporation, Energen's oil and gas subsidiary, periodically enters into derivative commodity instruments that qualify as cash flow hedges under SFAS No. 133 to hedge its exposure to price fluctuations on oil, natural gas and natural gas liquids production. In addition, Alagasco periodically enters into cash flow derivative commodity instruments to hedge its exposure to price fluctuations on its gas supply. Such instruments include regulated natural gas and crude oil futures contracts traded on the New York Mercantile Exchange (NYMEX) and over-the-counter swaps, collars and basis hedges with major energy derivative product specialists. The counterparties to the commodity instruments are investment banks and energy-trading firms. In some contracts, the amount of credit allowed before Energen Resources or Alagasco must post collateral for out-of-the-money hedges varies depending on the credit rating of the Company's debt. In cases where this arrangement exists, generally the Company's credit ratings must be maintained at investment grade status to have available counterparty credit.

As of March 31, 2004, $32.7 million, net of tax, of deferred net losses on derivative instruments recorded in accumulated other comprehensive income are expected to be reclassified to operating revenues in earnings during the next 12-month period. The actual amounts that will be reclassified to earnings over the next year could vary materially from this amount due to changes in market conditions. Gains and losses on derivative instruments that are not accounted for as cash flow hedges as well as the ineffective portion of the change in fair value of derivatives accounted for as cash flow hedges, are included in operating revenues in the consolidated financial statements. For the ineffective portion of the change in fair value of derivatives accounted for as cash flow hedges, the Company recorded a $148,000 after-tax gain for the three months ended March 31, 2004. Also, Energen Resources recorded an after-tax loss of $1.4 million for the quarter on contracts which did not meet the definition of cash flow hedges under SFAS No. 133. As of March 31, 2004, the Company had 4.91 billion cubic feet (Bcf) of gas hedges and 270,000 barrels (Bbl) of oil hedges which expire by year-end that did not meet the definition of a cash flow hedge but are considered by the Company to be viable economic hedges. As of March 31, 2004, and December 31, 2003, the Company had $21.8 million and $13.9 million, respectively, included in current and noncurrent deferred income taxes on the consolidated balance sheets related to OCI.

Energen Resources has entered into the following transactions for the remainder of 2004 and subsequent years:

Production Period

Total Hedged Volumes

Average Contract

Price

Description

Natural Gas

2004

12.7 Bcf

$4.77 Mcf

NYMEX Swaps

 

18.8 Bcf

$4.30 Mcf

Basin Specific Swaps

 

1.8 Bcf

$4.05 - $4.44 Mcf

NYMEX Collars

2005

1.2 Bcf

$3.75 Mcf

NYMEX Swaps

 

10.2 Bcf

$4.26 Mcf

Basin Specific Swaps

Oil

2004

1,268 MBbl

$28.39 Bbl

NYMEX Swaps

 

916 MBbl

$27.68 Bbl

West Texas Sour (WTS) Swaps

2005

660 MBbl

$30.79 Bbl

NYMEX Swaps

Oil Basis Differential

2004

315 MBbl

*

Basis Swaps

2005

180 MBbl

*

Basis Swaps

Natural Gas Liquids

2004

27.9 MMGal

$0.41 Gal

Liquids Swaps

2005

30.2 MMGal

$0.49 Gal

Liquids Swaps

* Average contract prices not meaningful due to the varying nature of each contract.

All hedge transactions are subject to the Company's risk management policy, approved by the Board of Directors, which does not permit speculative positions. The Company formally documents all relationships between hedging instruments and hedged items, as well as its risk management objective and strategy for undertaking the hedge. This process includes specific identification of the hedging instrument and the hedge transaction, the nature of the risk being hedged and how the hedging instrument's effectiveness in hedging the exposure to the hedged transaction's variability in cash flows attributable to the hedged risk will be assessed. Both at the inception of the hedge and on an ongoing basis, the Company assesses whether the derivatives that are used in hedging transactions are highly effective in offsetting changes in cash flows of hedged items. The Company discontinues hedge accounting if a derivative has ceased to be a highly effective hedge. The maximum term over which Energen Resources has hedged exposures to the variability of cash flows is through December 31, 2005.

On December 4, 2000, the APSC authorized Alagasco to engage in energy risk-management activities to manage the utility's cost of gas supply. As required by SFAS No. 133, Alagasco recognizes all derivatives as either assets or liabilities on the balance sheet. Any gains or losses are passed through to customers using the mechanisms of the GSA in compliance with Alagasco's APSC-approved tariff. In accordance with SFAS No. 71, Alagasco had recorded a current regulatory liability of $28.3 million representing the fair value of derivatives as of March 31, 2004. As of December 31, 2003, Alagasco had recorded a current regulatory asset of $0.3 million, a current regulatory liability of $17 million and a noncurrent regulatory liability of $8.7 million representing the fair value of derivatives.

5. RECONCILIATION OF EARNINGS PER SHARE

 

Three months ended

Three months ended

(in thousands, except per share amounts)

March 31, 2004

March 31, 2003

 

 

 

Per Share

 

 

Per Share

 

Income

Shares

Amount

Income

Shares

Amount

 

 

 

 

 

 

 

Basic EPS

$   60,185

36,173

$   1.66

$ 54,581

34,729

$ 1.57 

Effect of Dilutive Securities

 

 

 

 

 

 

Long-range performance shares

 

132

 

 

105

 

Stock options

247

193

Restricted stock

 

14

 

 

7

 

 

 

 

 

 

 

 

Diluted EPS

$   60,185

36,566

$   1.65

$ 54,581

35,034

$ 1.56 

For the three months ended March 31, 2004 and 2003, the Company had no options or shares of non-vested restricted stock that were excluded from the computation of diluted EPS.

6. SEGMENT INFORMATION

The Company principally is engaged in two business segments: the purchase, distribution and sale of natural gas in central and north Alabama (natural gas distribution) and the acquisition, development, exploration and production of oil and gas in the continental United States (oil and gas operations).

 

Three months ended

March 31,

(in thousands)

2004

2003

Operating revenues from continuing operations

 

 

    Oil and gas operations

$ 96,227

$ 88,519

    Natural gas distribution

255,202

221,139

        Total

$ 351,429

$ 309,658

Operating income (loss) from continuing operations

 

 

    Oil and gas operations

$ 44,133

$ 39,175

    Natural gas distribution

62,014

57,200

     Subtotal

106,147

96,375

    Eliminations and corporate expenses

(107)

(255)

        Total

$ 106,040

$ 96,120

Other income (expense)

 

 

    Oil and gas operations

$ (6,930)

$ (7,283)

    Natural gas distribution

(3,547)

(3,319)

     Subtotal

(10,477)

(10,602)

    Eliminations and other

(4)

(189)

        Total

$ (10,481)

$ (10,791)

Income from continuing operations before income taxes

$ 95,559

$ 85,329

 

(in thousands)

March 31, 2004

December 31, 2003

Identifiable assets

 

 

    Oil and gas operations

$     967,052

$     959,815

    Natural gas distribution

766,433

797,693

     Subtotal

1,733,485

1,757,508

    Eliminations and other

106,525

23,924

        Total

$ 1,840,010

$  1,781,432

7. COMPREHENSIVE INCOME (LOSS)

Comprehensive income (loss) consisted of the following:

 

Three months ended

Three months ended

(in thousands)

March 31, 2004

March 31, 2003

 

 

 

Net Income

$    60,185

$    54,581

Other comprehensive income (loss)

             

             

   Current period change in fair value of derivative instruments,       net of tax of ($12.2) million and ($14.5) million

(20,920)

(22,806)

   Reclassification adjustment, net of tax of $4.4 million and
      $10 million


7,101


15,690

Comprehensive Income

$   46,366

$     47,465

Accumulated other comprehensive loss consisted of the following:

(in thousands)

March 31, 2004

December 31, 2003

 

 

 

Unrealized loss on hedges, net of tax of ($21.8) million and ($13.9) million


$
    (35,533)


$    (21,714)

Minimum pension liability, net of tax of ($4.8) million and ($4.8) million

(8,881)

(8,881)

 

 

 

Accumulated Other Comprehensive Loss

$    (44,414)

$    (30,595)

 

 

 

8. LONG-LIVED ASSETS AND DISCONTINUED OPERATIONS

On January 1, 2002, the Company adopted SFAS No. 144, which retains the previous asset impairment requirements of SFAS No. 121, "Accounting for the Impairment of Long-Lived Assets and for Long-Lived Assets to be Disposed Of," for loss recognition when the carrying value of an asset exceeds the sum of the undiscounted estimated future cash flows of the asset. In addition, SFAS No. 144 requires that gains and losses on the sale of certain oil and gas properties and write-downs of certain properties held-for-sale be reported as discontinued operations, with income or loss from operations of the associated properties reported as income or loss from discontinued operations. The results of operations for held-for-sale properties are reclassified and reported as discontinued operations for prior periods in accordance with SFAS No. 144. Energen Resources may, in the ordinary course of business, be involved in the sale of developed or undeveloped properties. All assets held-for-sale must be reported at the lower of the carrying amount or fair value. Energen Resources had no property sales during the first quarter of 2004. During the three months ended March 31, 2003, Energen Resources recorded a

 

 

pre-tax writedown to fair value based upon expected market value of $8.2 million on certain non-strategic gas properties located in the Gulf Coast region. These properties were subsequently sold during 2003, for a pre-tax gain of $0.4 million. The pre-tax gain on disposals for the three months ended March 31, 2003, was $9.2 million largely due to sales of properties located in the San Juan Basin.

The following are the results of operations from discontinued operations:

 

Three months ended

 

March 31,

(in thousands, except per share data)

2004

2003

 

 

 

Oil and gas revenues

$ -

$ 2,721

 

 

 

Pretax income (loss) from discontinued operations

$ 1

$ 1,103

Income tax expense (benefit)

-

430

Income (Loss) From Discontinued Operations

1

673

 

 

 

Impairment charge on held-for-sale property

-

(8,247)

Gain (loss) on disposal

(21)

9,206

Income tax expense (benefit)

(8)

374

Gain (Loss) on Disposal

(13)

585

Total Income (Loss) From Discontinued Operations

$ (12)

$ 1,258

 

 

 

Diluted Earnings Per Average Common Share

 

 

Income from Discontinued Operations

$ -

$ 0.02

Gain (Loss) on Disposal

-

0.02

Total Income from Discontinued Operations

$ -

$ 0.04

 

 

 

Basic Earnings Per Average Common Share

 

 

Income from Discontinued Operations

$ -

$ 0.02

Gain (Loss) on Disposal

-

0.01

Total Income from Discontinued Operations

$ -

$ 0.03

9. EMPLOYEE BENEFIT PLANS

The components of net pension expense were:

(in thousands)

Plan A

Plan B

 

Three Months Ended

March 31,

Three Months Ended

March 31,

 

2004

2003

2004

2003

Components of net periodic benefit cost:

 

 

 

 

Service cost

$ 1,356

$ 989

$ 146

$ 123

Interest cost

1,664

1,660

346

354

Expected long-term return on assets

(1,950)

(1,714)

(522)

(390)

Actuarial loss (gain)

433

157

27

-

Prior service cost amortization

58

58

88

88

Net periodic expense

$ 1,561

$ 1,150

$ 85

$ 175

The Company contributed $773,000 to Plan A assets and $46,000 to Plan B assets through the three months ended March 31, 2004. The Company does not expect to make additional contributions to Plan A or Plan B assets during 2004.

 

Net periodic post-retirement benefit expense included the following:

(in thousands)

Salaried Employees

Union Employees

 

Three Months Ended

March 31,

Three Months Ended

March 31,

 

2004

2003

2004

2003

Components of net periodic benefit cost:

 

 

 

 

Service cost

$ 320

$ 206

$ 119

$ 103

Interest cost

580

511

494

503

Expected long-term return on assets

(380)

(325)

(615)

(525)

Actuarial loss (gain)

-

-

(73)

(71)

Prior service cost amortization

-

-

1

4

Transition amortization

171

171

321

321

Net periodic expense

$ 691

$ 563

$ 247

$ 335

10. COMMITMENTS AND CONTINGENCIES

Commitments and Agreements: Certain of Alagasco's long-term contracts for the supply, storage and delivery of natural gas include fixed charges that amount to approximately $215 million through May 2013. The Company also is committed to purchase minimum quantities of gas at market-related prices or to pay certain costs in the event the minimum quantities are not taken. These purchase commitments are approximately 65.7 billion cubic feet through June 2007.

Legal Matters: Energen and its affiliates are, from time to time, parties to various pending or threatened legal
proceedings. Certain of these lawsuits include claims for punitive damages in addition to other specified relief. Based upon information presently available, and in light of available legal and other defenses, contingent liabilities arising from threatened and pending litigation are not considered material in relation to the respective financial positions of Energen and its affiliates. It should be noted, however, that Energen and its affiliates conduct business in Alabama and other jurisdictions in which the magnitude and frequency of punitive damage awards may bear little or no relation to culpability or actual damages, thus making it increasingly difficult to predict litigation results.

Various pending or threatened legal proceedings arising in the normal course of business are in progress currently, and the Company has accrued a provision for estimated costs.

Environmental Matters: Various environmental laws and regulations apply to the operations of Energen Resources and Alagasco. Historically, the cost of environmental compliance has not materially affected the Company's financial position and results of operations and is not expected to do so in the future.  However, new regulations, enforcement policies, claims for damages or other events could result in significant unanticipated costs. 

Alagasco is in the chain of title of eight former manufactured gas plant sites, of which it still owns four, and five manufactured gas distribution sites, of which it still owns one. An investigation of the sites does not indicate the present need for remediation activities. Management expects that, should remediation of any such sites be required in the future, Alagasco's share, if any, of such costs will not materially affect the results of operations or financial condition of Alagasco.

 

11. REGULATORY ASSETS AND LIABILITIES

The following table details regulatory assets and liabilities on the balance sheets:

(in thousands)

March 31, 2004

December 31, 2003

 

Current

Noncurrent

Current

Noncurrent

Regulatory assets:

Pension asset

$       -

$    18,082

$     -

$     18,082

Risk management activities

   -

     -

      251

      -

Total regulatory assets

$   -

$    18,082

$     251

$    18,082

 

 

 

 

 

Regulatory liabilities:

 

 

 

 

Enhanced stability reserve

$    3,760

$     -

$    3,481

$       -

Gas supply adjustment

     3,485

      -

     4,903

       -

Risk management activities

      28,335

      -

     17,025

       8,650

RSE adjustment

969

      -

2,619

       -

Unbilled service margin

     12,366

       -

     26,118

       -

Asset removal costs, net

      -

      105,743

     -

       103,727

Other

       -

962

       -

       1,050

Total regulatory liabilities

$     48,915

$  106,705

$    54,146

$   113,427

12. LONG-TERM DEBT

In March 2004, Alagasco elected to call a total of $30 million of Medium-term Notes maturing January 16, 2006 to December 15, 2023. The call date for the above-referenced notes was April 26, 2004. During the three-months ended June 30, 2004, the Company will record a pre-tax loss on debt extinguishment of $0.9 million for the call premiums and unamortized debt discount.

13. RECENT PRONOUNCEMENTS OF THE FINANCIAL ACCOUNTING STANDARDS BOARD (FASB)

SFAS No. 141,"Business Combinations," requires all business combinations initiated after June 30, 2001, to be accounted for using the purchase method and SFAS No. 142,"Goodwill and Other Intangible Assets," establishes guidelines in accounting for goodwill and other intangible assets. The appropriate application of SFAS No. 141 and SFAS No. 142 is being considered to determine whether oil and gas mineral rights should be classified separately as intangible assets on the balance sheet, rather than as a part of oil and gas properties as currently recorded. Although formal guidance for oil and gas companies has not been issued, at the March 2004 Emerging Issues Task Force (EITF) meeting, a consensus was reached that mineral rights related to the mining industry should be accounted for as tangible assets (EITF 04-2). The Board subsequently ratified the consensus and a FASB Staff Position (FSP) was issued in April 2004 to amend SFAS No. 141 and SFAS No. 142 accordingly. The Company will continue to evaluate the impact of the application of these standards as further guidance is provided.

In December 2003, the FASB revised SFAS No. 132, "Employers' Disclosures about Pensions and Other Postretirement Benefits - an amendment of FASB Statements No. 87, 88 and 106." The revised Statement added additional interim disclosures relating to the net periodic benefit cost of defined benefit pension plans and other postretirement plans effective for interim periods ending after December 15, 2003. The Company has incorporated within this report the additional required disclosures (See Note 9).

On December 8, 2003, President Bush signed into law a bill that expands Medicare, adding a prescription drug benefit for Medicare-eligible retirees starting in 2006. Although the company anticipates that the benefits it pays after 2006 will be lower as a result of the new Medicare provisions, the retiree medical obligations and costs reported do not reflect the impact of this legislation. Deferring the recognition of the new Medicare provisions' impact is permitted by FSP FAS 106-1, "Accounting and Disclosure Requirements Related to the Medicare Prescription Drug, Improvement and Modernization Act of 2003," due to open issues related to the new Medicare provisions and a lack of authoritative accounting guidance about certain matters. In March 2004, the FASB proposed FSP FAS 106-b, "Accounting and Disclosure Requirements Related to the Medicare Prescription Drug, Improvement and Modernization Act of 2003," which provides more specific authoritative guidance on the accounting for this federal subsidy and that guidance, when finalized, is anticipated to supersede FSP FAS 106-1. The FSP could require changes to previously reported information.

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

Energen's net income totaled $60.2 million ($1.65 per diluted share) for the three months ended March 31, 2004, and compared favorably to net income of $54.6 million ($1.56 per diluted share) recorded in the same period in the prior year. In the first quarter of 2004, Energen's income from continuing operations totaled $60.2 million ($1.65 per diluted share) and compared with income from continuing operations of $53.3 million ($1.52 per diluted share) in the same period a year ago. Energen Resources Corporation, Energen's oil and gas subsidiary, had net income for the three months ended March 31, 2004, of $23.2 million as compared with $20.9 million in the previous period. Energen Resources generated net income from continuing operations of $23.2 million in the current quarter as compared with $19.7 million in the same quarter last year primarily as a result of significantly increased commodity prices for oil and natural gas as well as the impact of higher oil and gas production volumes. Energen's natural gas utility, Alagasco, reported net income of $36.3 million in the first quarter of 2004 as compared to net income of $33.4 million in the same period last year primarily due to increased earnings on a higher level of equity.

Oil and Gas Operations

Revenues from oil and gas operations rose 8.7 percent to $96.2 million for the three months ended March 31, 2004, largely as a result of significantly increased commodity prices and increased gas and oil production volumes. In the current quarter, average gas prices increased 8.9 percent to $4.77 per thousand cubic feet (Mcf), while average oil prices rose 4.4 percent to $27.12 per barrel. Natural gas liquids prices declined 7.2 percent to an average price of $16.55 per barrel. Natural gas production from continuing operations in the first quarter increased 3.5 percent to 13.7 billion cubic feet (Bcf), oil volumes rose 2.7 percent to 874 thousand barrels (MBbl) and natural gas liquids production declined 2.9 percent to 364 MBbl. Natural gas comprised approximately 65 percent of Energen Resources' production for the current quarter.

Energen Resources periodically enters into derivative commodity instruments that qualify as cash flow hedges under Statement of Financial Accounting Standard (SFAS) No. 133, "Accounting for Derivative Instruments and Hedging Activities," to hedge its exposure to price fluctuations on oil, natural gas and natural gas liquids production. Such instruments include regulated natural gas and crude oil futures contracts traded on the New York Mercantile Exchange (NYMEX) and over-the-counter swaps, collars and basis hedges with major energy derivative product specialists. The counterparties to the commodity instruments are investment banks and energy-trading firms. In some contracts, the amount of credit allowed before Energen Resources must post collateral for out-of-the-money hedges varies depending on the credit rating of the Company's debt. In cases where this arrangement exists, generally the Company's credit ratings must be maintained at investment grade status to have available counterparty credit. All hedge transactions are subject to the Company's risk management policy, approved by the Board of Directors, which does not permit speculative positions.

Energen Resources has entered into the following transactions for the remainder of 2004 and subsequent years:

Production Period

Total Hedged Volumes

Average Contract

Price

Description

Natural Gas

2004

12.7 Bcf

$4.77 Mcf

NYMEX Swaps

 

18.8 Bcf

$4.30 Mcf

Basin Specific Swaps

 

1.8 Bcf

$4.05 - $4.44 Mcf

NYMEX Collars

2005

1.2 Bcf

$3.75 Mcf

NYMEX Swaps

 

10.2 Bcf

$4.26 Mcf

Basin Specific Swaps

 

** 5.9 Bcf

$5.03 Mcf

Basin Specific Swaps

Oil

2004

1,268 MBbl

$28.39 Bbl

NYMEX Swaps

 

916 MBbl

$27.68 Bbl

West Texas Sour (WTS) Swaps

2005

660 MBbl

$30.79 Bbl

NYMEX Swaps

 

** 240 MBbl

$32.95 Bbl

NYMEX Swaps

 

** 240 MBbl

$30.27 Bbl

WTS Swaps

Oil Basis Differential

2004

315 MBbl

*

Basis Swaps

2005

180 MBbl

*

Basis Swaps

 

**240 MBbl

*

Basis Swaps

Natural Gas Liquids

2004

27.9 MMGal

$0.41 Gal

Liquids Swaps

2005

30.2 MMGal

$0.49 Gal

Liquids Swaps

* Average contract prices not meaningful due to the varying nature of each contract.

** Contracts entered into subsequent to March 31, 2004.

Realized prices are anticipated to be lower than NYMEX prices due to basis differences and other factors. Production from continuing operations in 2004 is expected to approximate 85.6 Bcfe. The estimated amount of production in 2004 from proved reserves owned at December 31, 2003 is 81.6 Bcfe.

Operations and maintenance (O&M) expense increased $2.3 million for the quarter. Lease operating expenses (excluding production taxes) increased by $1 million for the quarter primarily due to increased drilling activity. Administrative expense rose $1.4 million for the three months in the current quarter largely due to labor related costs. Exploration expense remained stable in quarter comparisons.

Energen Resources' depreciation, depletion and amortization (DD&A) expense for the quarter decreased $0.7 million. The average depletion rate for the three-months ended March 31, 2004, was $0.88 as compared to $0.91 in the same period a year ago largely due to current production in basins with lower DD&A rates.


Energen Resources' expense for taxes other than income taxes primarily reflected production-related taxes that were $1 million higher in the first quarter of 2004 as compared to the same period last year largely due to increased production.


Energen Resources may, in the ordinary course of business, be involved in the sale of developed or undeveloped properties. With respect to developed properties, sales may occur as a result of, but not limited to, disposing of non-strategic or marginal assets and accepting offers where the buyer gives greater value to a property than does Energen Resources. The Company is required to reflect gains and losses on the dispositions of these assets, the writedown of certain properties held-for-sale, and income or loss from the operations of the associated held-for-sale properties as discontinued operations under the provisions of SFAS No. 144, "Accounting for Impairment or Disposal of Long-Lived Assets," which was adopted as of January 1, 2002. Energen Resources had no property sales during the first quarter of 2004. In the prior year quarter, Energen Resources recorded a pre-tax gain of $9.2 million from the sale of properties located in the San Juan Basin and a pre-tax writedown of $8.2 million on certain non-strategic gas properties located in the Gulf Coast region, which were subsequently sold in August 2003.

Natural Gas Distribution

Natural gas distribution revenues increased $34.1 million for the quarter largely due to an increase in the commodity cost of gas partially offset by a decrease in weather related sales volumes. For the quarter, weather that was 5 percent warmer than in the same period last year contributed to a 5.9 percent decline in residential sales volumes and a 3.1 percent decrease in small commercial and industrial customer sales volumes. Transportation volumes increased 1.4 percent in period comparisons. Higher commodity gas prices partially offset by decreased gas purchase volumes contributed to a 23.7 percent increase in cost of gas for the quarter. The GSA rider in Alagasco's rate schedule provides for a pass-through of gas price fluctuations to customers without markup. Alagasco's tariff provides a temperature adjustment to certain customers' bills designed to substantially remove the effect of departures from normal temperatures. The temperature adjustment applies primarily to residential, small commercial and small industrial customers.


As discussed more fully in Note 3, Alagasco is subject to regulation by the Alabama Public Service Commission (APSC). On June 10, 2002, the APSC issued an order to extend the Company's rate-setting mechanism. Under the terms of that extension, RSE will continue after January 1, 2008, unless, after notice to the Company and a hearing, the Commission votes to either modify or discontinue its operation.

O&M expense remained stable in the current quarter as increased labor related costs were offset by lower bad debt expense. A 7.7 percent increase in depreciation expense in the current quarter was due to normal growth of the utility's distribution and support systems. Taxes other than income taxes primarily reflected various state and local business taxes as well as payroll-related taxes. State and local business taxes generally are based on gross receipts and fluctuate accordingly.

Non-Operating Items

Interest expense for the Company decreased $0.5 million in the first quarter due to a $32.1 million equity issuance completed in July 2003 which reduced short-term debt, the payment of current maturities of long-term debt of $23 million and reduced short-term borrowings. These reductions in borrowings were partially offset by $50 million of long-term debt issued by Energen in October 2003. In quarter comparisons, income tax expense increased $3.4 million primarily due to higher consolidated pre-tax income.

FINANCIAL POSITION AND LIQUIDITY

Cash flows from operations for the year-to-date were $135.6 million as compared to $105.1 million in the same period last year. Increased net income during the period was augmented by changes in working capital items, which are highly influenced by throughput, changes in weather, and timing of payments. Working capital needs at Alagasco were primarily affected by storage gas inventory and increased gas costs compared to the prior period.

The Company had a net outflow of cash from investing activities of $35 million through the three months ended March 31, 2004, primarily due to additions of property, plant and equipment. Energen Resources invested $21.4 million in capital expenditures primarily related to the development of oil and gas properties. Utility capital expenditures totaled $13.5 million in the year-to-date and primarily represented system distribution expansion and support facilities.


The Company used $14.5 million for financing activities in the year-to-date primarily due to the repayment of borrowings and dividends paid to common stockholders partially offset by proceeds from the issuance of common stock.

A portion of available cash was used on April 26, 2004 to call $30 million of Medium-term Notes maturing January 16, 2006 to December 15, 2023. The Company expects to use the remaining available cash to finance the acquisition of oil and gas properties as discussed below.

FUTURE CAPITAL RESOURCES AND LIQUIDITY

The Company plans to continue to implement its diversified growth strategy that focuses on expanding Energen Resources' oil and gas operations through the acquisition of producing properties with developmental potential while maintaining the strength of the Company's utility foundation. For the five years ended December 31, 2003, Energen's diluted EPS grew at an average compound rate of 21.9 percent a year. Over the next five years, Energen is targeting an average EPS growth rate over each rolling five-year period of approximately 7 to 8 percent a year.


To finance Energen Resources' investment program, the Company expects to utilize short-term credit facilities to supplement internally generated cash flow. The Company may periodically issue long-term debt and equity to replace short-term obligations providing permanent financing. Energen currently has available short-term credit facilities aggregating $267 million to help finance its growth plans and operating needs. As an acquisition company, access to capital is an integral part of the Company's business plan. The Company regularly provides information to corporate rating agencies related to current business activities and future performance expectations. In April 2004, Moody's Investors Service confirmed Energen's debt rating as Baa1 and Alagasco's debt rating as A1. Standard and Poor's last update in October 2003, confirmed Energen's and Alagasco's rating as A- with a stable outlook. While the Company expects to have ongoing access to its short-term credit facilities and the broader long-term markets, continued accessibility could be affected by future economic and business conditions. Energen's management plans to utilize increases in cash flows to help finance Energen Resources' acquisition strategy. In July 2003, the Company completed the issuance of 1,000,000 shares of common stock through the periodic draw-down of shares in a shelf registration. In October 2003, the Company issued $50 million of long-term debt. These proceeds were used for general corporate purposes and to repay a portion of short-term debt incurred to finance the oil and gas property acquisition program of Energen Resources.

In 2004, Energen Resources plans to invest approximately $310 million, including $200 million in property acquisitions, $2 million in related acquisition development, $103 million in other development and approximately $5 million in exploratory activities. As of December 31, 2003, the estimated amount of development of previously identified proved undeveloped reserves was approximately $77 million. Capital investment at Energen Resources in 2005 is expected to approximate $200 million for property acquisitions, $20 million for related acquisition development and $52 million for other development and exploration. Of this $52 million, development of previously identified proved undeveloped reserves is estimated to be $35 million and exploratory exposure is estimated to be $3 million. Energen Resources' capital investment for oil and gas activities over the five-year period ending December 31, 2008 is estimated to be approximately $1.4 billion, with $1 billion for property acquisitions, $200 million for related acquisition development, $200 million for other development and $25 million for exploratory and other activities. During the five year period, Energen Resources anticipates spending approximately $137 million on development of previously identified proved undeveloped reserves and incurring approximately $16 million in exploratory exposure. Energen Resources' continued ability to invest in property acquisitions will be influenced significantly by industry trends, as the producing property acquisition market historically has been cyclical. Notwithstanding the estimated expenditures mentioned above, as an acquisition oriented company, Energen Resources continually evaluates acquisition opportunities which arise in the marketplace and from time to time may pursue acquisitions that meet Energen's acquisition criteria which could result in capital expenditures different than those outlined above. These acquisitions or negotiations to sell, trade or otherwise dispose of properties may alter the aforementioned financing requirements.

Alagasco maintains an investment in storage gas that is expected to average approximately $40 million in 2004 but may vary depending upon the price of natural gas. In March 2004, Alagasco elected to call $30 million of Medium-term Notes maturing January 16, 2006 to December 15, 2023. During 2004 and 2005, Alagasco plans to invest approximately $60 million and $53 million, respectively, in utility capital expenditures for normal distribution and support systems. Over the Company's five-year planning period ending December 31, 2008, Alagasco anticipates capital investments of approximately $275 million. The utility anticipates funding these capital requirements through internally generated capital and the utilization of short-term credit facilities. As a result of drawing on the short-term credit facilities for capital expenditures and the anticipated refinancing of the $30 million recalled debt discussed above, Alagasco may issue up to $80 million in long-term debt during the planning period.

Certain of the Company's long-term contracts for the supply, storage and delivery of natural gas include fixed charges that amount to approximately $215 million through May 2013. The Company also is committed to purchase minimum quantities of gas at market-related prices or to pay certain costs in the event the minimum quantities are not taken. These purchase commitments are approximately 65.7 billion cubic feet through June 2007.


Energen Resources periodically enters into derivative commodity instruments that qualify as cash flow hedges under SFAS No. 133 to hedge its exposure to price fluctuations on oil, natural gas and natural gas liquids production. In addition, Alagasco periodically enters into cash flow derivative commodity instruments to hedge its exposure to price fluctuations on its gas supply. Such instruments include regulated natural gas and crude oil futures contracts traded on the NYMEX and over-the-counter swaps, collars and basis hedges with major energy derivative product specialists. The counterparties to the commodity instruments are investment banks and energy-trading firms. In some contracts, the amount of credit allowed before Energen Resources or Alagasco must post collateral for out-of-the-money hedges varies depending on the credit rating of the Company's debt. In cases where this arrangement exists, generally the Company's credit ratings must be maintained at investment grade status to have available counterparty credit.


Recent Pronouncements of the Financial Accounting Standards Board (FASB)

SFAS No. 141,"Business Combinations," requires all business combinations initiated after June 30, 2001, to be accounted for using the purchase method and SFAS No. 142,"Goodwill and Other Intangible Assets," establishes guidelines in accounting for goodwill and other intangible assets. The appropriate application of SFAS No. 141 and SFAS No. 142 is being considered to determine whether oil and gas mineral rights should be classified separately as intangible assets on the balance sheet, rather than as a part of oil and gas properties as currently recorded. Although formal guidance for oil and gas companies has not been issued, at the March 2004 Emerging Issues Task Force (EITF) meeting, a consensus was reached that certain mineral rights related to the mining industry should be accounted for as tangible assets (EITF 04-2). The Board subsequently ratified the consensus and a FASB Staff Position (FSP) was issued in April 2004 to amend SFAS No. 141 and SFAS No. 142 accordingly. The Company will continue to evaluate the impact of the application of these standards as further guidance is provided.

In December 2003, the FASB revised SFAS No. 132, "Employers' Disclosures about Pensions and Other Postretirement Benefits - an amendment of FASB Statements No. 87, 88 and 106." The revised Statement added additional interim disclosures relating to the net periodic benefit cost of defined benefit pension plans and other postretirement plans effective for interim periods ending after December 15, 2003. The Company has incorporated within this report the additional required disclosures (See Note 9).

On December 8, 2003, President Bush signed into law a bill that expands Medicare, adding a prescription drug benefit for Medicare-eligible retirees starting in 2006. Although the company anticipates that the benefits it pays after 2006 will be lower as a result of the new Medicare provisions, the retiree medical obligations and costs reported do not reflect the impact of this legislation. Deferring the recognition of the new Medicare provisions' impact is permitted by FSP FAS 106-1, "Accounting and Disclosure Requirements Related to the Medicare Prescription Drug, Improvement and Modernization Act of 2003," due to open issues related to the new Medicare provisions and a lack of authoritative accounting guidance about certain matters. In March 2004, the FASB proposed FSP FAS 106-b, "Accounting and Disclosure Requirements Related to the Medicare Prescription Drug, Improvement and Modernization Act of 2003," which provides more specific authoritative guidance on the accounting for this federal subsidy and that guidance, when finalized, is anticipated to supersede FSP FAS 106-1. The FSP could require changes to previously reported information.

Forward-Looking Statements and Risk Factors

Certain statements in this report express expectations of future plans, objectives and performance of the Company and its subsidiaries and constitute forward-looking statements made pursuant to the Safe Harbor provision of the Private Securities Litigation Reform Act of 1995. Except as otherwise disclosed, the Company's forward-looking statements do not reflect the impact of possible or pending acquisitions, divestitures or restructurings. The Company cannot guarantee the absence of errors in input data, calculations and formulas used in its estimates, assumptions and forecasts. The Company undertakes no obligation to correct or update any forward-looking statements whether as a result of new information, future events or otherwise.

All statements based on future expectations rather than on historical facts are forward-looking statements that are dependent on certain events, risks and uncertainties that could cause actual results to differ materially from those anticipated. Some of these include, but are not limited to, economic and competitive conditions, inflation rates, legislative and regulatory changes, financial market conditions, future business decisions, and other uncertainties, all of which are difficult to predict.

There are numerous uncertainties inherent in estimating quantities of proved oil and gas reserves and in projecting future rates of production and timing of development expenditures. The total amount or timing of actual future production may vary significantly from reserve and production estimates. In the event Energen Resources is unable to fully invest its planned acquisition, development and exploratory expenditures, future operating revenues, production, and proved reserves could be negatively affected. The drilling of development and exploratory wells can involve significant risks, including those related to timing, success rates and cost overruns and these risks can be affected by lease and rig availability, complex geology and other factors.

Although Energen Resources makes use of futures, swaps and fixed-price contracts to mitigate risk, fluctuations in future oil and gas prices could materially affect the Company's financial position, results of operation and cash flows; furthermore, such risk mitigation activities may cause the Company's financial position and results of operations to be materially different from results that would have been obtained had such risk mitigation activities not occurred. The effectiveness of such risk-mitigation assumes that counterparties maintain satisfactory credit quality.

SELECTED BUSINESS SEGMENT DATA

 

ENERGEN CORPORATION

 

(Unaudited)

 

 

Three months ended

 

March 31,

(in thousands, except sales price data)

2004

2003

 

 

 

Oil and Gas Operations

 

 

Operating revenues from continuing operations

 

 

    Natural gas

$   65,476

$ 58,096

    Oil

23,687

22,103

    Natural gas liquids

6,020

6,676

    Other

1,044

1,644

        Total

$   96,227

$ 88,519

Production volumes from continuing operations

 

 

    Natural gas (MMcf)

13,737

13,267

    Oil (MBbl)

874

851

    Natural gas liquids (MBbl)

364

375

Production volumes from continuing operations (MMcfe)

21,161

20,620

Total production volumes (MMcfe)

21,161

21,195

Average sales price including effects of hedging

 

 

    Natural gas (Mcf)

$       4.77

$ 4.38

    Oil (barrel)

$     27.12

$ 25.97

    Natural gas liquids (barrel)

$     16.55

$ 17.83

Average sales price excluding effects of hedging

 

 

    Natural gas (Mcf)

$       5.30

$ 5.81

    Oil (barrel)

$     32.74

$ 31.99

    Natural gas liquids (barrel)

$     20.79

$ 21.83

Other data from continuing operations

 

 

    Lease operating expense (LOE)

 

 

     LOE and other

$   17,830

$ 16,813

     Production taxes

    8,248

7,247

        Total

$   26,078

$ 24,060

    Depreciation, depletion and amortization

$   19,126

$ 19,810

    Capital expenditures

$   21,444

$ 53,821

    Exploration expenditures

$         48

$ 140

    Operating income

$   44,133

$ 39,175

Natural Gas Distribution

Operating revenues

 

 

    Residential

$   176,660

$ 153,939

    Commercial and industrial - small

64,601

54,939

    Transportation

11,376

11,131

    Other

2,565

1,130

        Total

$   255,202

$ 221,139

Gas delivery volumes (MMcf)

 

 

    Residential

15,109

16,060

    Commercial and industrial - small

6,049

6,244

    Transportation

14,598

14,393

        Total

35,756

36,697

Other data

 

 

    Depreciation and amortization

$     9,610

$ 8,925

    Capital expenditures

$    13,811

$ 14,959

    Operating income

$     62,014

$ 57,200

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Energen Resources' major market risk exposure is in the pricing applicable to its oil and gas production. Historically, prices received for oil and gas production have been volatile because of seasonal weather patterns, world and national supply-and-demand factors and general economic conditions. Crude oil prices also are affected by quality differentials, by worldwide political developments and by actions of the Organization of Petroleum Exporting Countries. Basis differentials, like the underlying commodity prices, can be volatile because of regional supply-and-demand factors, including seasonal factors and the availability and price of transportation to consuming areas.

Energen Resources periodically enters into derivative commodity instruments that qualify as cash flow hedges under Statement of Financial Accounting Standard (SFAS) No. 133, "Accounting for Derivative Instruments and Hedging Activities," to hedge its exposure to price fluctuations on oil, natural gas and natural gas liquids production. In addition, Alagasco periodically enters into cash flow derivative commodity instruments to hedge its exposure to price fluctuations on its gas supply. Such instruments include regulated natural gas and crude oil futures contracts traded on the New York Mercantile Exchange and over-the-counter swaps, collars and basis hedges with major energy derivative product specialists. The counterparties to the commodity instruments are investment banks and energy-trading firms. These counterparties have been deemed creditworthy by the Company and have agreed in certain instances to post collateral with the Company when unrealized gains on hedges exceed certain specified contractual amounts. Notwithstanding these agreements, the Company is at risk for economic loss based upon the credit worthiness of its counterparties. In some contracts, the amount of credit allowed before Energen Resources or Alagasco must post collateral for out-of-the-money hedges varies depending on the credit rating of the Company's debt. In cases where this arrangement exists, generally the Company's credit ratings must be maintained at investment grade to have available counterparty credit. All hedge transactions are subject to the Company's risk management policy, approved by the Board of Directors, which does not permit speculative positions. The Company formally documents all relationships between hedging instruments and hedged items, as well as its risk management objective and strategy for undertaking the hedge. The maximum term over which Energen Resources is hedging exposures to the variability of cash flows is through December 31, 2005.

See Note 4 for details related to the Company's hedging activities.

 

 

 

ITEM 4. CONTROLS AND PROCEDURES

 

(a)

Our chief executive officer and chief financial officer have evaluated the effectiveness of our disclosure controls and procedures as of the end of the period covered by this report. Based on that evaluation they have concluded that our disclosure controls and procedures are effective at a reasonable assurance level.

 

 

(b)

Our chief executive officer and chief financial officer have concluded that during the period covered by this report there were no changes in our internal controls that materially affected or are reasonably likely to materially affect our internal control over financial reporting.

 

 

 

 

 

PART II. OTHER INFORMATION

 

ITEM 2. CHANGES IN SECURITIES, USE OF PROCEEDS AND ISSUER PURCHASES OF EQUITY SECURITIES

 

 

 

 

Period

 

Total Number of Shares Purchased*

 

Average Price Paid per Share

Total Number of Shares Purchased as Part of Publicly Announced Plans

Maximum Number of Shares that May Yet Be Purchased Under the Plans**

 

 

 

 

 

January 1, 2004 through January 31, 2004

-

-

-

-

February 1, 2004 through February 29, 2004

-

-

-

-

March 1, 2004 through March 31, 2004

1,959

$ 41.52

-

1,075,350

Total

1,959

$ 41.52

-

1,075,350

 

 

 

 

 

* Acquired in connection with tax withholdings on stock compensation plans.

** By resolution adopted May 24, 1994, and supplemented by a resolution adopted April 26, 2000, the Board of Directors authorized the Company to repurchase up to 1,782,200 shares of the Company's common stock. The resolutions do not have an expiration date.

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

 

a.

At the annual meeting of shareholders held on April 28, 2004, Energen shareholders elected the following Director to serve for a one-year term expiring in 2005:

Director

Votes cast for

Votes withheld

David W. Wilson

28,737,617

654,681

At the annual meeting of shareholders held on April 28, 2004, Energen shareholders elected the following Directors to serve for three-year terms expiring in 2007:

Director

Votes cast for

Votes withheld

Stephen D. Ban

28,861,609

530,689

Julian W. Banton

28,730,076

662,222

T. Michael Goodrich

28,718,502

673,796

Wm. Michael Warren, Jr.

28,856,123

536,175

ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K

 

 

a.

Exhibits

 

 

 

31(a) - Certification pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

 

31(b) - Certification pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

 

32 - Certification pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes- Oxley Act of 2002

 

 

b.

Reports on Form 8-K

 

 

 

Form 8-K dated January 28, 2004, reporting Energen and Alagasco issued a press release announcing financial results for the fourth quarter of 2003

SIGNATURES

 

Pursuant to the requirements of the Securities and Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

 

 

 

 

ENERGEN CORPORATION

 

 

ALABAMA GAS CORPORATION

 

 

 

           May 7, 2004

 

By   /s/ Wm. Michael Warren, Jr.        

 

 

Wm. Michael Warren, Jr.

 

 

Chairman, President and Chief Executive

 

 

Officer of Energen Corporation, Chairman

 

 

and Chief Executive Officer of Alabama

 

 

Gas Corporation

 

 

 

 

 

 

           May 7, 2004

 

By   /s/ G. C. Ketcham                       

 

 

G. C. Ketcham

 

 

Executive Vice President, Chief

 

 

Financial Officer and Treasurer of

 

 

Energen Corporation and Alabama Gas

 

 

Corporation

 

 

 

 

 

 

           May 7, 2004

 

By   /s/ Grace B. Carr                         

 

 

Grace B. Carr

 

 

Vice President and Controller of Energen

 

 

Corporation

 

 

 

 

 

 

           May 7, 2004

 

By   /s/ Paula H. Rushing                     

 

 

Paula H. Rushing

 

 

Vice President-Finance of Alabama Gas

 

 

Corporation

 

 

 

 

 

 

 

 

 

 

 







 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

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