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 JUNE 30, 1998
                             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

                 2101 Sixth Avenue North
               Birmingham,
             Alabama 35203
             Telephone Number
             205/326-2700
                 http://www.en
                 ergen.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  the  number of shares outstanding of each of the issuers'
classes  of
common stock, as of August 11, 1998:

            Energen Corporation, $0.01 par value     29,244,719
shares
            Alabama Gas Corporation, $0.01 par value
1,972,052 shares

<PAGE>
     ENERGEN CORPORATION AND ALABAMA GAS CORPORATION
        FORM 10-Q FOR THE QUARTER ENDED JUNE 30, 1998
                                                         Page TABLE OF
                                CONTENTS
             PART I:      FINANCIAL INFORMATION
(Unaudited)
Item 1.   Financial Statements
          (a)  Consolidated Statements of Income of
              Energen Corporation
              3
          (b) Consolidated Balance Sheets of Energen
Corporation 4
          (c) Consolidated Statements of Cash Flows of
Energen Corporation
6
  (d) Statements of Income of Alabama Gas Corporation

                           7

    (e) Balance Sheets of Alabama Gas Corporation

8

      (f) Statements of Cash Flows of Alabama Gas Corporation

                                10

 (g) Notes to Unaudited Financial Statements               11





Item 2.   Management's Discussion and Analysis of Financial
Condition and
         Results of Operations                               15

    Selected Business Segment Data of Energen Corporation    20
                                 
                    PART II: OTHER INFORMATION

Item 5.      Other Information                     21

Item 6.      Exhibits and Reports on Form 8-K      21

SIGNATURES                                         22
<PAGE>

PART I. FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

CONSOLIDATED STATEMENTS OF INCOME
ENERGEN CORPORATION
(Unaudited)
<TABLE>
<CAPTION>

                               Three months ended      Nine
                                    months ended June 30,
                                    June 30,
(in thousands,     1998          1997      1998          1997
except share data)

<S>                <C>     <C>            <C>
<C>
Operating Revenues
Natural gas
distribution     $66,327  $70,147        $323,829
                    $313,603
Oil and gas
 Production
       activities       34,385   20,732
               100,744   57,220
   Total operating
   Revenues       100,712   90,879
424,573 370,823
Operating Expenses
Cost of gas        28,066   30,519
159,112 155,891
Operations and
       Maintenance       36,997   30,814
                105,523  92,917
Depreciation,
 depletion and
       amortization      19,401   14,413
                61,553  37,435
Taxes, other than
income taxes       9,442    6,889       34,011
                    26,783
                       
   Total operating
    Expenses       93,906   82,635      360,199
313,026 Operating Income    6,806    8,244
64,374  57,797 Other Income (Expense)
Interest expense   (7,490)  (5,404)
(22,391) (16,205) Other, net            427
348          1,752   2,678
   Total other income
    (expense)      (7,063)  (5,056)
(20,639) (13,527) Income (Loss) Before
     Income Taxes    (257)   3,188
43,735  44,270 Income tax (benefit)
     Expense         (172)     181
(2,599)                   7,555
Net Income (Loss)   $ (85) $ 3,007     $46,334
$36,715 Basic Earnings Per Avg.
Common Share*        $0.00  $ 0.11      $ 1.60
                    $  1.49
Diluted Earnings Per
 Avg. Common Share* $0.00 $ 0.11     $ 1.58
$ 1.48
Dividends Per
 Common Share*  $0.155    $0.15       $ 0.465
$ 0.45
Basic Avg. Common Shares
 Outstanding*        29,160   26,218   29,024
                    24,655
                       
*Share amounts reflect a 2-for-1 stock split effective
March 2, 1998

The accompanying Notes are an integral part of these
statements </TABLE>
<PAGE>


CONSOLIDATED BALANCE SHEETS
ENERGEN CORPORATION
<TABLE>
<CAPTION>


                          June 30, 1998
September 30,1997 in thousands)           (unaudited)
ASSETS
Current Assets
<S>                           <C>
<C>
Cash and cash equivalents     $  3,420
$105,402 Accounts receivable, net
 of allowance for doubtful
 accounts of $3,854 at
 June 30,1998, and $3,185
      at September 30, 1997        69,887
                    70,676
Inventories, at average cost
 Storage gas                  19,221                 25,367
 Materials and supplies        8,011                  7,281
 Liquified natural gas
  in storage                   3,440                  3,630
Deferred gas cost              2,068                  2,512
Deferred income taxes         12,788                  7,438
Prepayments and other         11,160                 19,859
   Total current assets      129,995
242,165
Property, Plant and Equipment Oil and gas
properties,
successful efforts method    549,191
454,210
Less accumulated
 depreciation, depletion
        and amortization           127,904
                      87,554
 Oil and gas properties,
  Net                        421,287
366,656
Utility plant                615,961
583,630
Less accumulated
 depreciation               301,871
287,749
   Utility plant, net        314,090
295,881
Other property, net            4,157                    4,466
 Total property, plant
  and equipment, net         739,534
667,003

Other Assets
Deferred income taxes         12,624                    1,144
Deferred charges and other     8,827                    9,485

        Total other assets    21,451
10,629
TOTAL ASSETS                $890,980
$919,797

The accompanying Notes are an integral part of
these financial statements.
</TABLE>
<PAGE>

CONSOLIDATED BALANCE SHEETS ENERGEN CORPORATION
<TABLE>
<CAPTION>


                         June 30, 1998
September 30, 1997 (in thousands,
(unaudited)
 except share data)


CAPITAL AND LIABILITIES
Current Liabilities
<S>                                    <C>              <C>
Long-term debt due within one year    $  1,859          $ 1,855
Notes payable to banks                  33,000          202,000
Accounts payable                        36,405           49,196
Accrued taxes                           24,468           18,300
Customers' deposits                     16,932           16,399
Amounts due customers                   11,495            7,347
Accrued wages and benefits              14,347           13,719
Other                                   24,329           21,935
    Total current liabilities          162,835          330,751
Deferred Credits and Other Liabilities
Other                                    8,314            8,301

   Total deferred credits and
    other liabilities                    8,314            8,301
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,
  29,195,502 shares outstanding at
  June 30, 1998, and
  28,796,218 shares outstanding
  at September 30, 1997                    292            288
 Premium on capital stock              193,549        185,841
 Capital surplus                         2,802          2,802
 Retained earnings                     145,042        112,212
   Total common shareholders'
    equity                             341,685        301,143
Long-term debt                         378,146        279,602
   Total capitalization                719,831        580,745
TOTAL CAPITAL AND LIABILITIES         $890,980
$919,797

*Share amounts reflect a 2-for-1 stock split effective March
2, 1998

The accompanying Notes are an integral part of these financial
statements. </TABLE>
<PAGE>


CONSOLIDATED STATEMENTS OF CASH FLOWS
ENERGEN CORPORATION
(Unaudited)
[CAPTION]
<TABLE>

Nine months ended June 30,
 (in thousands)                  1998                1997
Operating Activities
<S>                             <C>                 <C>
Net income                      $46,334             $36,715
Adjustments to reconcile
net income
to net cash
 provided
by (used
in)
 operating
activities:
Depreciatio
n,
depletion
 and amortization                  61,553             37,435
Deferred income taxes, net        (17,189)            (2,313)
 Deferred investment tax
  credits, net                       (351)              (365)
   Net change in:
   Accounts receivable              789                (8,579)
   Inventories                    5,606                 3,130
   Deferred gas cost                444                  (479)
   Accounts payable -
    gas purchases                (3,947)                3,713
    Accounts payable - trade      (8,844)                 945
   Other current assets
    and liabilities              22,570               (11,230)
   Other, net                     3,846                   394
      Net cash provided by
       operating activities      110,811               59,366
Investing Activities
Additions to property, plant
 and equipment                   (134,338)
(171,541) Other, net
2,253   3,061
   Net cash used in
      investing activities         (132,085)
                     (168,480)
Financing Activities
Payment of dividends on
  common stock                    (13,500)            (11,217)
Issuance of common stock            4,121              52,968
Reduction of long-term debt          (870)               (923)
Proceeds from issuance of
  long-term debt                   98,541              84,416
Payment of note payable issued
 to purchase U.S. Treasury
 securities                       (98,636)                  -
Net change in short-term debt     (70,364)            (24,366)
   Net cash provided by (used in)
    financing activities           (80,708)           100,878
Net change in cash and cash
equivalents                      (101,982)             (8,236)
Cash and cash equivalents at
     beginning of period               105,402
                      17,074
Cash and Cash Equivalents at
     end of period                     $ 3,420
                      $ 8,838
                         
The accompanying Notes are an integral part of these financial
statements. </TABLE>
<PAGE>


STATEMENTS OF INCOME
ALABAMA GAS CORPORATION (Unaudited)
<TABLE>
<CAPTION>


                           Three months ended       Nine
months ended
                                June 30,
June 30,
(in thousands)              1998         1997       1998
1997
<S>                        <C>       <C>          <C>
<C>
Operating Revenues         $66,327   $70,147
$323,829   $313,603
Operating Expenses
Cost of gas                 28,496   31,074
160,674   157,667
Operations and
 maintenance                24,737   22,684
73,230    71,477
Depreciation                 6,318    5,906
18,747    17,463
Income taxes
 Current                      108    2,216
21,130    14,498
Deferred, net               (514)  (1,249)
(6,261)      (833)
 Deferred investment
tax credits, net           (117)    (122)           (351)
                          (365)
Taxes, other than
income taxes                5,668    5,356        23,838
                         22,396
  Total operating
   expenses                64,696   65,865
291,007    282,303

Operating Income            1,631    4,282
32,822    31,300

Other Income
Allowance for funds
 used during construction      127       84           311
385
Other, net                      25       38           271
327
  Total other income          152      122            582
712

Interest Charges
Interest on long-term
 debt                        2,210    2,210
6,632     6,632
Other interest expense         159      493
1,230     1,709
 Total interest charges    2,369    2,703           7,862
8,341
Net Income (Loss)           $ (586)  $1,701
$25,542   $23,671

The accompanying Notes are an integral part of these financial
statements. </TABLE>
<PAGE>

BALANCE SHEETS
ALABAMA GAS CORPORATION
<TABLE>
<CAPTION>

                           June 30, 1998
September 30, 1997 (in thousands)      (unaudited)

ASSETS
Property, Plant and Equipment
<S>                            <C>               <C>
Utility plant                  $615,961
$583,630
Less accumulated depreciation   301,871
287,749


   Utility plant, net           314,090
295,881


Other property, net                 346
347

Current Assets
Cash and cash equivalents          2,901
2,580 Accounts receivable
 Gas                              39,402
36,098
 Merchandise                       2,010
2,001
 Other                             1,484
1,442
 Allowance for doubtful accounts  (3,815)
(3,156) Inventories, at average cost
 Storage gas                           19,221
25,367
 Materials and supplies                 5,879
5,391
 Liquified natural gas in storage       3,440
3,630
Deferred gas cost                        2,068
2,512
Deferred income taxes                   10,945
5,675
Prepayments and other                    3,693
6,696


   Total current assets                87,228
88,236
Deferred Charges and Other Assets        4,249
5,917 TOTAL ASSETS                    $405,913
$390,381

The accompanying Notes are an integral part of these
financial statements.
</TABLE>
<PAGE>


BALANCE SHEETS
ALABAMA GAS CORPORATION
<TABLE>
<CAPTION>

                           June 30, 1998
September 30, 1997 (in thousands,     (unaudited)
 except share data)


CAPITAL AND LIABILITIES
<S>                                 <C>
<C>
Capitalization
Common shareholder's equity
 Common stock, $0.01
     par value;
  3,000,000 shares
  authorized,
  1,972,052 shares
  outstanding at June
  30, 1998, and
  September 30, 1997                 $     20
$    20
 Premium on capital stock              31,682
31,682
 Capital surplus                        2,802
2,802
    Retained earnings                 125,160
106,894
 Total common shareholder's
    equity                              159,664
141,398
Cumulative preferred
stock,
 $0.01 par value,
120,000 shares
 authorized, issuable
in series -
 $4.70 Series                                -              -
Long-term debt                         125,000
125,000

    Total capitalization                 284,664
266,398
Current Liabilities
Notes payable to banks                    2,000
11,000
Accounts payable
 Trade                                 22,613
28,923
 Affiliated companies                  2,496
4,984
 Accrued taxes                           28,647
16,745
 Customers' deposits                     16,932
16,399
Other amounts due customers              11,495            7,347
Accrued wages and benefits                4,975            3,879
Other                                     9,265
10,481
     Total current liabilities           98,423
99,758
Deferred Credits and
 Other Liabilities
Deferred income taxes                   16,181
16,739 Accumulated deferred investment
 tax credits                             2,778             3,130
Regulatory liability                     3,062             3,651
Customer advances for
    construction and other                    805
                         705
   Total deferred credits and
      other liabilities                  22,826
24,225
Commitments and Contingencies                 -                -

TOTAL CAPITAL AND LIABILITIES         $405,913
$390,381

The accompanying Notes are an integral part of these
financial statements.
</TABLE>
<PAGE>

STATEMENTS OF CASH FLOWS
ALABAMA GAS CORPORATION
(Unaudited)
<TABLE>
<CAPTION>


Nine months ended June 30,
(in thousands)                          1998
1997 <S>
<C>               <C>
Operating Activities
Net income                            $ 25,542
$23,671 Adjustments to reconcile net
income
to net
 cash

provide
d by
(used
 in) operating activities:
  Depreciation and amortization         18,747
  17,463 Deferred income taxes, net
  (6,261)                                (833)
  Deferred investment tax credits         (351)            (365)
 Net change in:
   Accounts receivable                     (2,696)
(4,924)
   Inventories                             5,848
3,061
   Deferred gas cost                         444           (479)
   Accounts payable - gas purchases        (3,947)
3,713
   Accounts payable - other trade          (2,363)
(3,373)
   Other current assets
    and liabilities                        19,590
(15,630)
   Other, net                                1,176
                        (806)
   Net cash provided by
   operating activities                    55,729
                       21,498
Investing Activities
Additions to property,
 plant and equipment                       (37,130)
(28,663) Net advances from affiliates
(2,488)        6,379 Other, net
486        1,012
   Net cash used in investing
    activities                            (39,132)
(21,272) Financing Activities
Payment of dividends on
 common stock                              (7,276)
(6,720) Net change in short-term debt
(9,000)         8,000
   Net cash provided by
   (used in) financing activities        (16,276)
                        1,280
                          
Net change in cash and
    cash equivalents                          321
                        1,506
Cash and cash equivalents at
    beginning of period                     2,580
                         803
Cash and Cash Equivalents at
End of Period                           $  2,901
$ 2,309

The accompanying Notes are an integral part of these financial
statements. </TABLE>
<PAGE>


NOTES TO UNAUDITED FINANCIAL STATEMENTS
ENERGEN CORPORATION AND ALABAMA GAS CORPORATION


1.  BASIS OF PRESENTATION

All  adjustments to the unaudited financial statements which 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  and
immaterial  adjustments.   The  consolidated   financial statements
and notes thereto should be read in conjunction with
the  financial statements  and  notes for the years ended September
30, 1997, 1996,  and  1995, included in the 1997 Annual Report of
Energen Corporation (the Company) on  Form 10-K. Certain
reclassifications were made to conform prior years' financial
statements  to  the  current quarter presentation.  The Company's
natural  gas distribution business  is  seasonal  in character  and
influenced  by weather conditions.   Results of operations for the
interim periods are not  necessarily indicative of the results which
may be expected for the fiscal year.

2.  REORGANIZATION UNDER THE NAME OF ENERGEN RESOURCES CORPORATION

Following the close of business on September 30, 1998, Taurus
Exploration,  Inc. (Taurus), Energen's wholly owned oil and gas
subsidiary, plans to merge into its wholly owned subsidiary Taurus
Exploration U.S.A., Inc. (Taurus U.S.A.). Taurus U.S.A.  will be the
surviving corporation of the merger and at the time  of  the merger,
Taurus  U.S.A.
will change its name to Energen  Resources Corporation (Energen
Resources). Effective July 22, 1998, Taurus began doing  business
as Energen  Resources. References in this document to Energen
Resources  refer  to Taurus and Taurus U.S.A., collectively.

3.   REGULATORY
As  an  Alabama  utility,  Alabama Gas Corporation (Alagasco)  is
subject to regulation  by  the  Alabama Public Service Commission
(APSC)
which, in 1983, established the Rate Stabilization and Equalization
(RSE) ratesetting  process. RSE  was
extended with modifications in 1985, 1987 and 1990. On October 7,
1996, RSE  was extended,  without change, for a five-year period
through  January 1, 2002. Under  the terms of that extension, RSE
will continue after
January  1, 2002, unless, after notice to the Company and a hearing,
the Commission votes to either modify or discontinue its operation.
Under  RSE as extended, the APSC conducts quarterly reviews to
determine, based on Alagasco's
projections  and  fiscal  year-to-date  performance, whether
Alagasco's return on equity for the fiscal 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
fiscal year, effective December 1, and cannot exceed 4 percent  of
prior-year revenues.  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.  If the change in O&M expense  per customer  falls
within                                                                     1.25
percentage points above or below the Consumer Price Index For  All
Urban Customers (index  range), no adjustment is required.  If,
however, 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. Under
RSE as extended, an $11.8 million annual increase in  revenue became
effective December 1, 1997 and a $2.5 million annual decrease in
revenue became effective July 1, 1998.

Alagasco  calculates a temperature adjustment to customers' bills to
remove  the effect  of  departures from  normal temperature on
Alagasco's  earnings.  The calculation  is performed monthly, and
the adjustments to customers' bills  are made in the same billing
cycle the weather variation occurs.

Alagasco's  rate schedules for natural gas distribution charges
contain  a  Gas Supply  Adjustment  (GSA) rider, established in
1993, which  permits  the passthrough to customers of changes in the
cost of gas supply, including Gas Supply Realignment  (GSR)
surcharges imposed by Alagasco's  suppliers  resulting from changes
in gas supply purchases related to the implementation of  Federal
Energy Regulatory Commission (FERC) Order 636. The APSC on October
7, 1996, issued an order  providing  for  the refund to customers
prior to  January  31, 1997,  of approximately $17 million of
supplier refunds, including interest.
The  Company refunded  these amounts  to customers during January
1997.  The refunds  were collected  from a variety of sources and
most relate to the settlement  of  rate case and FERC Order 636
proceedings of Southern Natural Gas Company.

In  accordance with APSC-directed regulatory accounting procedures,
Alagasco, in 1989  began returning to customers excess utility
deferred taxes which  resulted from a reduction in the federal
statutory tax rate from 46 percent to 34 percent using the average
rate assumption method. This method provides for the return to
ratepayers  of excess deferred taxes over the lives of the related
assets.   In 1993  those excess taxes were reduced as a result of a
federal tax rate increase from  34 percent to 35 percent. Remaining
excess utility deferred taxes of  $2.1 million  are being returned
to ratepayers over approximately 13 years.  At  June 30, 1998, and
September 30, 1997, a regulatory liability related to income taxes
of $3.1 million and $3.7 million, respectively, was included in the
consolidated financial statements.

4.  CAPITAL STOCK

On  January 28, 1998, Energen announced a 2-for-1 split of the
Company's  common stock. The  split  was  in
the form of a 100 percent stock  dividend  and  was payable
on March 2, 1998, to shareholders of record on February 13, 1998.
All pershare  amounts  and the number of shares of capital stock
outstanding  have been
adjusted  to  reflect the stock split.
Effective January  30,  1998,  the Restated  Certificate  of
Incorporation of Energen Corporation  was  amended  to increase
Energen's
authorized common stock, par value $0.01 per  share, from 30,000,000
shares to 75,000,000 shares.

5.  DERIVATIVE COMMODITY INSTRUMENTS

Energen  Resources  enters into derivative commodity instruments  to
hedge  its exposure  to  the impact of price fluctuations on oil and
gas production.  Such instruments include regulated natural gas and
crude oil futures contracts traded on the New York Mercantile
Exchange and overthe-counter swaps and basis hedges with major
energy derivative product specialists. These  transactions  are
accounted  for
under  the hedge method of accounting. Under  this
method,  any unrealized gains and losses are recorded as a current
receivable/payable  and  a deferred
gain/loss.  Realized gains and losses are deferred until the
revenues from  the related hedged volumes are recognized in the
income statement.   These realized deferred  gains  and losses are
reflected in  current liabilities or current assets,  respectively.
Cash flows  from  derivative instruments  are recognized  as
incurred through changes in working capital.   The Company  had
deferred losses of $6.7 million and $12.9 million on the balance
sheet  at  June 30,1998, and September 30, 1997, respectively.

At  June  30, 1998, Energen Resources had entered into contracts and
swaps  for 10.0  Bcf  of its remaining estimated 1998 flowing gas
production at an  average contract  price  of  $2.11 per Mcf and for
183 MBbl of its  remaining  estimated flowing  oil production at an
average contract price of $19.06 per barrel.  The program  has  been
extended into fiscal year 1999 with contracts
and  swaps  in place  for  25.8 Bcf of flowing gas production at an
average contract  price  of $2.32  per Mcf and for 540 MBbl of
flowing oil production at an average contract price  of  $17.31 per
barrel. Realized prices are anticipated to be  lower  than hedged
prices due to basis differences and other factors.  To help mitigate
this variance,  the  Company  has  hedged the basis difference  on
6.4  Bcf  of  its remaining 1998 and 1999 San Juan production.

All  hedge  transactions  are subject to the Company's risk
management  policy, approved by the Board of Directors, which does
not permit speculative positions. To apply the hedge method of
accounting, management must demonstrate that a high correlation
exists between the value of the derivative commodity instrument  and
the value  of  the  item  hedged.  Management uses the historic
relationships between the derivative instruments and the sales
prices of the hedged volumes to ensure that a high level of
correlation exists.

6.  ACCOUNTING FOR LONG-LIVED ASSETS

Statement of Financial Accounting Standards (SFAS) No. 121,
Accounting  for  the Impairment  of  Long-Lived Assets and for Long-
Lived Assets to be
Disposed  Of, requires  that an impairment loss be recognized when
the carrying amount  of  an asset exceeds the sum of the
undiscounted estimated future cash  flows  of  the asset.
Accordingly, during the second fiscal quarter ending  March  31,
1998, Energen Resources recorded a pre-tax writedown of $4.7 million
on  certain  oil and  gas properties, adjusting the carrying amount
of the properties  to  their fair value  based upon expected future
discounted cash flows.  This  writedown primarily  reflects the
impact of the recent decline in crude  oil prices.  The expense was
recorded as additional depreciation, depletion and amortization.
As  of  June 30, 1998, the Company expects to dispose of additional
oil and  gas properties  with  a carrying value of $8.5 million. No
gain or loss  has  been recognized  as the Company estimates that
the fair value of the properties  will exceed their carrying
amount.

7.  RECENT PRONOUNCEMENTS OF THE FASB

In  June  1997,  the  FASB issued SFAS No. 130, Reporting
Comprehensive  Income,
which  requires  the  reporting  and display of  comprehensive
income  and  its components  in an entity's financial statements,
and  SFAS No. 131,  Disclosures about Segments of an Enterprise and
Related Information, which specifies revised guidelines for
determining an entity's operating segments and the type and level of
financial information to be required.  In February 1998, the FASB
issued SFAS No.   132, Employers'  Disclosures
about  Pensions  and  Other  Postretirement Benefits, which revises
employers' disclosures  about  pension  and   other postretirement
benefit plans.  The Company is required to adopt these statements in
fiscal  year  1999.   The impact of these pronouncements  on  the
Company currently is being evaluated and is not expected to be
material.

In  June  1998,  the  FASB  issued  SFAS  No.  133,  Accounting for
Derivative Instruments  and Hedging Activities, which establishes
accounting and  reporting standards  for  derivative instruments.
The Company is required to  adopt  this statement in fiscal year
2000.
The impact of this pronouncement on the  Company is currently being
evaluated.

8.    SUBSEQUENT EVENT

During  August  1998, the Company entered into an agreement  for the
trade  of substantially  all  of  its  Gulf  of
Mexico interests  for  the  Permian  Basin interests of EEX
Corporation (EEX). This transaction is expected to  close  by
September  30, 1998, and has an effective date of January 1, 1998.
The  Company will receive  approximately 58 Bcfe of primarily proved
developed reserves  and EEX  will receive an estimated 38 Bcfe of
proved natural gas reserves along with interest in thirty offshore
blocks and $9 million in cash.

9.  RECONCILIATION OF EARNINGS PER SHARE*
<TABLE>
<CAPTION>
(in thousands, except                  Per Share               Per
Share
   per share amounts)   Income   Shares   Amount    Income
                       Shares  Amount
                         Three months ended          Three
                           months ended June 30, 1998
                           June 30, 1997
<S>                   <C>    <C>      <C>      <C>
<C>    <C> Basic EPS
Income available to
common stockholders   $(85)  29,160   $ 0.00   $ 3,007
26,218 $ 0.11 Effect of Dilutive Securities

Long-range performance
 shares                         155
130
Non-qualified stock
 options                        236
129
Diluted EPS
Income available to
 common stockholders
 plus assumed
   conversions        $ (85)    29,551  $0.00   $ 3,007
                      26,477  $ 0.11
                             
                       Nine months ended         Nine
months ended
                         June 30, 1998             June
30, 1997
Basic EPS
Income available to
   common stockholders $46,334   29,024  $1.60  $36,715
                      24,655   $1.49
Effect of Dilutive Securities
Long-range performance
 shares                           148
119
Non-qualified stock
 options                           203
109
Diluted EPS
Income available to
 common
stockhol
  ders
 plus
assumed
 conversions          $46,334    29,375  $1.58  $36,715  24,883
$1.48
*Share  amounts reflect a 2-for-1 stock split effective March 2,
1998 (see  Note 4)
</TABLE>
<PAGE>


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

Energen's results of operations were a net loss of $85,000 ($0.00
per share) for the  three  months  ended June 30, 1998,
down from net income  of  $3.0  million ($0.11  per
share)  recorded in the same period last year.   Energen
Resources Corporation   (Energen Resources),  Energen's oil  and
gas exploration   and production subsidiary, formerly known as
Taurus Exploration Inc. (see  Note 2), realized  net  income of
$440,000 in the current quarter as compared  with  $1.3 million  in
the same period last year.  Gains resulting from production-related
income  were  more  than  offset by reduced nonconventional  fuels
tax  credit recognition  on  an interim  basis and increased
interest  expense. Alagasco, Energen's  natural gas utility,
reported a net loss of $589,000 in the  current quarter as compared
with net income of $1.7 million in the same period last year
primarily  due  to timing in the recovery of utility rates.  The
utility  earned its  allowed  return on  a higher level of equity
representing  investment
in utility plant. For  the  1998  fiscal year-to-date, Energen's net
income totaled $46.3  million ($1.60  per share) compared with $36.7
million ($1.49 per share) for the  same period  last  year.
Energen Resources' net income totaled $20.6  million  and compared
favorably with $12.7 million of net income in the first nine months
of fiscal  1997.   Gains  resulting  from production  related income
and  higher nonconventional fuels  tax credits were partially
offset
by  a writedown  of certain  oil  and  gas properties in the second
quarter and increased  interest expense. Alagasco's earnings
increased $1.9 million to $25.5 million  as the utility  continued
to  earn its allowed return on  a  higher level  of  equity
representing investment in utility plant.
Natural Gas Distribution
Natural  gas distribution revenues decreased $3.8 million in quarter
comparisons and  increased $10.2 million for the year-to-date.  For
the quarter, a deferral of  revenue  for  future rate reductions was
made to bring Alagasco's  projected return on equity within the RSE
allowed range of    13.15 percent to 13.65 percent. Decreased  gas
purchase volumes resulted in a 8.3 percent decrease  in cost  of
gas.  For  the year-to-date, weather that was 10.8 percent colder
than the  same period  last year contributed to a 11.1 percent
increase in residential sales volumes,  which combined  with
increased contribution  from  commercial and
industrial  customers  for  an increase in total sales volumes  of 9
percent. Partially  offsetting the increase in sales volumes was a
deferral  of revenue under  RSE  requirements.   Increased gas
purchase volumes  were offset  by  a decrease in the commodity cost
of gas, resulting in a relatively stable cost  of gas.

Operations  and  maintenance expenses increased $2.1 million  for
the current quarter  and  $1.8  million  in the year-to-date
primarily  due  to a  one-time reduction  in expense in the prior
year resulting from a change in the  salaried employee vacation
policy and an increase in bad debt expenses.

A  slight  increase  in  depreciation expense for the quarter  and
year-to-date comparisons was due to normal growth of the utility's
distribution system. Taxes other than income primarily reflect
various state and local business  taxes  as well  as  payrollrelated
taxes.
State and local business taxes  are  generally based on gross
receipts and fluctuate accordingly.

As  discussed  more  fully in Note 3, Alagasco is subject to
regulation by  the APSC.   On  October  7,1996, the APSC issued an
order extending
the  Company's current rate-setting mechanism through January 1,
2002.  Under the terms of that extension, RSE will continue after
January 1, 2002, unless, after notice to  the Company and a hearing,
the Commission votes to either modify or discontinue  its operation.
Oil and Gas Exploration and Production
Revenues  from  oil  and gas production activities rose 65.9
percent  to  $34.4 million  for  the  three months ended June 30,
1998, and 76 percent  to  $100.7 million  for the year-to-date,
primarily reflecting Energen Resources' current
and  prior-year property acquisitions.  Natural gas comprised almost
80 percent of  Energen Resources' production for both the current
quarter and the  yeartodate.  For the quarter, natural gas
production increased 52.6 percent  to
11.9 Bcf  and oil  volumes increased 49
percent to 361 MBbl.  For the  year-to-date, natural
gas
production  increased 72.7 percent to 33.2  Bcf  and  oil volumes
increased
68.3  percent  to  981 MBbl.   Energen Resources'  high BTU-content
natural  gas reserves in the San Juan Basin yielded 239 MBbl  in
natural  gas liquids in the current quarter and 609 MBbl for the
yearto-date.

Realized  natural  gas  prices increased over the prior period  but
oil  prices declined  in  period comparisons. For the quarter, gas
sales  prices  increased 12.2 percent to $2.20 per Mcf. Oil prices
decreased    18.4 percent to $14.71 per barrel.  For the year-to-
date,
gas sales prices increased 4.1 percent to  $2.28
while  oil prices decreased 13 percent to $15.98 per barrel. Natural
gas liquids sold  for  an  average price of $8.55 per barrel for the
quarter and  $9.27  per barrel for the year-to-date.

Energen  Resources  enters into derivative commodity instruments  to
hedge  its exposure  to  the impact of price fluctuations on oil and
gas production.   Such instruments include regulated natural gas and
crude oil futures contracts traded on  the New York Mercantile
Exchange and over-the-counter swaps and basis hedges with  major
energy derivative product specialists.  All hedge transactions  are
subject  to  the  Company's risk management policy, approved  by
the  Board  of Directors,  which  does not permit speculative
positions.   At June  30,  1998, Energen Resources  had entered into
contracts and swaps for 10.0  Bcf of  its
remaining estimated 1998 flowing gas production at an average
contract price  of $2.11 per Mcf and for 183 MBbl of its remaining
estimated flowing oil production at  an  average  contract  price of
$19.06 per barrel. The  program  has  been extended into fiscal year
1999 with contracts and swaps in place for 25.8 Bcf of flowing gas
production at an average contract price of
$2.32 per Mcf and for 540 MBbl  of  flowing  oil production at an
average contract price  of  $17.31  per barrel.  Realized prices are
anticipated to be lower than hedged prices due  to
basis differences and other factors. To help mitigate this variance,
the Company has  hedged the basis difference on 6.4 Bcf of its
remaining 1998 and  1999 San Juan production.

O&M  expense  increased $4.1 million for the quarter and $11.4
million  in  the current  year-to-date  primarily due to significant
growth  in  production  and acquisition  activity at Energen
Resources.  Lease operating  expenses  rose  by $5.2  million and
$13.7 million for the quarter and year-to-date, respectively, due to
the acquisition of oil and gas properties. Exploration expense
increased $0.3  million  for  the quarter  but was lower  by  $0.8
million  year-to-date primarily due to reduced drilling activity.

Energen  Resources'  significantly  higher  production volumes
generated  the majority   of   the  $4.6  million  increase  in
depreciation, depletion  and amortization (DD&A) for the quarter and
the $22.8 million increase for the yearto-date.  During  the
previous  fiscal  quarter,  Energen  Resources  recorded additional
DD&A  expense  of  $4.7 million to writedown certain oil  and  gas
properties  under SFAS No. 121, primarily due to lower oil prices.
The  average depletion rate for the quarter decreased to $0.82 as
compared to $0.90  for  the
same  period  last  year, due to accelerated production  of  certain
long-lived properties with decreased depletion rates.  The average
depletion rate was $0.87 in the year-to-date, excluding the effect
of the writedown, compared to $0.85 in the prior-year period.
Energen  Resources'  expense  for  taxes other than income primarily
reflects production-related  taxes which were $2.2 million higher
this quarter  and  $5.8 million higher for the yearto-date as a
result of increased production.
Non-Operating Items
Interest expense for the Company increased  $2.1 million in the
quarter and $6.2 million  in the year-to-date.
To help fund growth at Energen Resources, Energen issued $85 million
of mediumterm notes (MTNs) in July 1997 and $100 million  of MTNs
in  February 1998. The Company had decreased average borrowings
under  its shortterm credit  facilities for  the quarter  which
partially
offset  the increase  in  interest expense on MTNs.  For the year-
todate  the Company  had increased  its average  borrowings under
its short-term  credit  facilities  in connection with the growth at
Energen Resources.

The  Company's  effective tax rates are lower than statutory federal
tax  rates primarily  due to the recognition of nonconventional
fuels tax credits  and the amortization  of investment tax credits.
As nonconventional fuels  tax  credits are  generated each year
through December 31, 2002 and are expected to be fully recognized in
the financial statements, effective tax rates  are  expected  to
continue  to  remain  lower
than statutory federal rates.   Income tax  expense decreased  in
the  current quarter due to lower consolidated  pretax  income,
partially offset by decreased recognition of nonconventional fuels
tax credits. In  year-to-date comparisons, income tax expense
decreased due to both increased production  of nonconventional fuels
and the resulting recognition of such  tax credits on an interim
basis.
FINANCIAL POSITION AND LIQUIDITY


Current year operating cash flow was $110.8 million compared to
$59.4 million in the  prior  year.   The Company benefited from
increased net  income  primarily resulting  from  significantly
higher oil and gas production.   Other  working capital items, which
are highly influenced by throughput and timing of payments, combined
to create the remaining increase.  Negatively affecting cashflow in
the prior  year  was  the utility's payout of $17 million of
supplier  refunds to customers in January 1997.

The  Company invested $132.1 million through the nine months ended
June  30,1998 primarily  in  the addition of property, plant and
equipment. Energen  Resources invested  $97.8 million in capital
expenditures for the year-to-date related  to the  acquisition  and
development of oil and gas properties.   Utility capital
expenditures  totaled  $37.0  million and represented  primarily
normal  system distribution expansion and support facilities.

The  Company used $80.7 million for financing activities through the
nine months ended  June 30,1998.  In February 1998, the Company
issued $100 million of longterm  debt redeemable February 15, 2028.
The 7.125 percent MTNs were priced at   99.416 percent to yield
7.173 percent. The $98.5 million in proceeds were
used to  repay  borrowings under Energen's short-term credit
facilities
incurred to finance
Energen  Resources' growth activity.  For tax  planning purposes,
the Company borrowed $98.6 million in September 1997 to invest in
short-term federal obligations.  The Treasuries matured in early
October and the proceeds were used to repay the debt.
FUTURE CAPITAL RESOURCES AND LIQUIDITY
The Company plans to continue to implement its diversified growth
strategy. Over the  five-year  period ending September 30, 2002,
Energen  Resources     plans to
invest  approximately  $750  million to $800  million
to  acquire and  develop producing  oil and gas properties and to
participate in exploration and related development.  In fiscal 1998,
Energen Resources plans to spend in excess of $120 million,
including $70
million spent on property acquisitions year-to-date.  It should  be
noted that Energen Resources' continued ability to invest in
property acquisitions  will
be significantly  influenced  by industry  trends  as  the producing
property acquisition market historically has been cyclical.  From
time to time, Energen Resources also may be engaged in negotiations
to sell, trade or otherwise dispose of previously acquired or
developed oil and gas properties.

During  the  first quarter of 1998, Energen Resources acquired
approximately  79 Bcfe  of proved oil and natural gas reserves in
the Permian Basin of west  Texas from  B.C. Oil and Gas Ltd. and
certain affiliated companies for $43.3  million. More  than  half
of  the proved reserves are behind-pipe and undeveloped,  and
Energen Resources plans to spend an additional $17 million over the
next two  to three years  to fully  develop the behind-pipe, water
flood and  undeveloped reserve  potential. Oil  accounts for
70  percent  of  the  estimated  proved
reserves.   The properties include approximately 350 producing
wells,  of  which Energen  Resources  will operate  248.  Energen
Resources  also  purchased  an estimated   4.5  Bcfe  of
predominantly  natural  gas reserves  in southwest Mississippi from
Oxy USA Inc. for $7.1 million.  In the second quarter,  Energen
Resources  closed  on a $17 million purchase of Gulf of Mexico
properties  from Chateau  Oil  and  Gas Inc.  In April 1998, Energen
Resources subsequently  sold approximately  20 percent of its share
to a third party who will  serve  as  the operating  partner.
Energen  Resources' retained portion  of  the acquisition includes
an  estimated 9.8 Bcf of natural gas reserves in the Gulf of
Mexico. Approximately 45 percent of the
proved reserves are developed and producing, and Energen Resources
plans to spend another $0.7 million over  the next  several years to
bring on-line the 55 percent of behind-pipe reserves.

To  finance Energen Resources' investment program, the Company will
continue  to utilize its short-term credit facilities to supplement
internally generated cash flow, with long-term debt and equity
providing permanent financing.  In December 1997, Energen filed a
$400 million shelf registration for debt and common stock. Under
that registration, in February 1998 Energen issued $100 million of
Series B  MTNs, the proceeds from which were used to repay shortterm
debt.  During the first quarter, Energen increased its available
short-term credit facilities  to $228  million to accommodate its
growth plans.  Depending on the Company's level of activity in
acquiring oil and gas properties, Energen may issue common equity
during fiscal year 1999.

Utility  capital  expenditures  for  normal
distribution  system renewal  and expansion plus support facilities
could approximate
$60 million in fiscal  1998. Alagasco  also  will maintain an
investment in storage  working  gas  which  is expected to
approximate $24 million at the end of fiscal  1998. The  utility
anticipates  funding  these capital requirements through
internally  generated capital and the utilization of short-term
credit facilities.

Year 2000 Issues
Energen  has  and  continues to evaluate its computer software and
hardware  to assess  modifications needed for the Year 2000.  Over
the past  three  years,  a substantial  investment by the Company
has been made in software  and  computer infrastructure  that either
can be  upgraded  or  complies  with  Year   2000 requirements. A
full time senior management level position was established and a
primary  contractor was selected in 1996 to address the Year  2000
issue.   The plan  of work established involves the following
phases: inventory, assessment, testing,  certification and change
control.  A number of inventory reviews  have been completed and
will continue to be updated in the future. Tools to test, age and
evaluate data software and hardware have been purchased, are
installed  and being utilized  for Year 2000 compliance.  Test plans
for items
identified  as critical  systems  are either being deployed or
currently developed.   A  third party assessment  of Year 2000
readiness is scheduled to be conducted  by  an outside  entity for
both information technology and noninformation  technology systems
at the end of fiscal year 1998.

With respect to material third party relationships, the Company,
in
addition  to responding  to  questions  concerning the Year 2000
issues  from customers  and regulators,  is inquiring  of  certain
vendors  and  partners for information designed  to  determine
their  ability  to continue uninterrupted  supply  of materials
or services to the Company.  This process is scheduled for
completion by the end of fiscal year 1998.

To  date,  the Company has incurred approximately $380,000 of Year
2000  related costs which are being expensed as incurred.  The
Company's Year 2000 remediation is  expected to be completed by the
end of calendar year 1999 with an  estimated total cost of $1.8
million.

Management expects that Year 2000 issues will be addressed on a
schedule and  in a  manner  that  will prevent such issues from
having a material effect  on the Company's  results  of operations,
liquidity or financial condition.  While  the Company has and will
be pursuing Year 2000 compliance, there can be no assurance that
the  Company  and  its  vendors  will be  successful  in identifying
and addressing all material Year 2000 issues.

Specific  Year 2000 contingency plans are scheduled to be
incorporated into  the previously established Energen Business
Resumption Plan during fiscal year 1999. The Company's contingency
plan identifies alternate recovery locations, contact lists, and
other equipment, as well as, special resource requirements.

Forward-Looking Statements and Risks
Certain  statements  in  this  report, including statements  of
future  plans, objectives  and  expected performance of the Company
and its  subsidiaries,  are forward-looking  statements  that are
dependent on certain  events,  risks  and uncertainties that may be
outside the Company's control which 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, Year 2000 issues, 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 reserves and production  estimates.   In the
event Energen Resources is unable to invest fully its planned
acquisition expenditures, future operating revenues and proved
reserves could be negatively affected.   The drilling  of
exploratory wells can involve  significant risk including that
related to timing, success rates and cost overruns.  These  risks
can  be  impacted  by
lease and rig availability, complex  geology  and  other factors.
Results of operations and cash flows also could be affected by
future oil and gas prices. Although Energen Resources makes use of
futures, swaps and fixed  price contracts to mitigate risk,
fluctuations in oil and gas prices  may affect the Company's
financial position and results of operations.

OTHER

Recent Pronouncements of the FASB
In  June  1997,  the  FASB issued SFAS No. 130, Reporting
Comprehensive  Income, which  requires  the reporting  and display
of  comprehensive  income  and its components  in an entity's
financial statements, and SFAS No. 131,  Disclosures about Segments
of an Enterprise and Related Information, which specifies revised
guidelines for determining an entity's operating segments and the
type and level of financial information to be required.  In February
1998, the FASB issued SFAS No.   132,
Employers'  Disclosures  about  Pensions  and  Other Postretirement
Benefits, which  revises  employers' disclosures  about  pension and
other postretirement benefit plans.  The Company is required to
adopt these statements in  fiscal  year  1999.   The  impact of
these  pronouncements  on  the  Company currently is being evaluated
and is not expected to be material.
In  June  1998,  the  FASB  issued  SFAS  No.  133, Accounting  for
Derivative Instruments  and Hedging Activities, which establishes
accounting and  reporting standards  for  derivative instruments.
The Company is required to  adopt  this statement in fiscal year
2000. The impact of this pronouncement on the  Company is currently
being evaluated.
<PAGE>


SELECTED BUSINESS SEGMENT DATA
ENERGEN CORPORATION
(Unaudited)
<TABLE>
<CAPTION>

                     Three months ended    Nine months ended
(in thousands, except      June 30,             June 30,
sales price data)     1998       1997     1998
                     1997
<S>                    <C>        <C>      <C>
<C>
Natural Gas Distribution
Operating revenues
 Residential           $43,683    $42,218   $219,257
                      $210,113
 Commercial and
  industrial - small     16,214    15,769     79,414     75,310
 Transportation           7,894     7,805
27,746               25,648
Other                   (1,464)     4,355
(2,588)               2,532

   Total                $66,327   $70,147
$323,829 $313,603
Gas delivery volumes (MMcf)
  Residential             5,113     4,528
28,969               26,079
 Commercial and
  industrial - small      2,496      2,221
12,172               10,974
  Transportation         17,906     15,432
50,424               46,962
   Total                    25,515    22,181
91,565               84,015
Other data
 Depreciation and
  amortization           $6,318    $ 5,906
$18,747  $17,463
 Capital expenditures       $13,607  $12,098
$36,987  $28,212
  Operating income           $1,108   $ 5,121
$47,340 $44,592
Oil and Gas Exploration
 and Production
Operating revenues
 Natural gas                $26,323  $15,321
$75,764  $42,131
 Oil                          5,314    4,372
15,681               10,703
 Natural gas liquids         2,041         -
5,643                     -
  Other                         707     1,039
3,656   4,386
   Total                    $34,385  $20,732
$100,744 $57,220
Sales volume
 Natural gas (MMcf)         11,948     7,831
33,225  19,240
 Oil (MBbl)                    361       243
981     583
 Natural gas liquids (MBbl)    239         -
609       -
Average sales price
   Natural gas (Mcf)          $ 2.20   $  1.96
$2.28                 $2.19
   Oil (barrel)               $14.71   $ 18.03
$15.98  $18.37
 Natural gas liquids
  (barrel)                  $ 8.55        -    $9.27          -
Other data
 Depreciation, depletion
  and amortization          $13,083  $ 8,505
$42,806  $19,970
 Capital expenditures       $10,300  $39,472
$97,794  $143,003
Exploration expenditures   $1,367   $ 1,716   $2,857
                       $3,662
 Operating income            $5,922   $ 3,356  $17,806  $14,462
</TABLE>
<PAGE>


PART II. OTHER INFORMATION

ITEM 5.  OTHER INFORMATION

Rule 14a-4 Notice.
Pursuant to Rule 14a-4 of the Proxy Rules under the Securities
Exchange  Act  of 1934, if a shareholder fails to notify Energen on
or before November 4, 1998, of a proposal which such shareholder
intends to present at Energen's January  1999
annual meeting other than through inclusion of such proposal in
Energen's  proxy materials for the meeting, then if the proposal is
presented at the January 1999 annual  meeting, management proxies
may use their discretionary voting authority with respect to such
proposal.

ITEM 6.  EXHIBITS AND REPORTS ON FORM 8-K

a.         Exhibits
  27.1    Financial  data  schedule of Energen Corporation  (for
SEC
         purposes only)

 27.2 Financial data schedule of Alabama Gas Corporation(for SEC
        purposes only)
  27.3   Restated  financial data schedule of Energen Corporation
         (for  SEC purposes only)

b. Reports on Form 8-K

   A report on Form 8-K dated June 24, 1998 was filed with the
   Commission to report the adoption of a new Shareholder Rights
   Plan to replace the existing Rights Plan when it expires at the
   close of business on July 27, 1998.
<PAGE>

                        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


August 11, 1998            By/s/ Wm. Michael Warren, Jr.
                                 Wm. Michael Warren, Jr.
                                 Chairman,
                                 President and
                                 Chief Executive
                                 Officer of
                                 Energen,
Chairman and Chief
                                 Executive Officer
of Alagasco August 11, 1998         By/s/ G. C.
Ketcham
                                 G. C. Ketcham
                                 Executive Vice
                                 President, Chief
                                 Financial Officer
                                 and Treasurer of
                                 Energen and
                                 Alagasco
                                 
August 11, 1998            By/s/ Grace B. Carr
                                 Grace B. Carr
                                 Controller of Energen



August 11, 1998            By/s/ Paula H. Rushing
                                 Paula H. Rushing
                                 Vice President -
Finance

                                 of Alagasco