SECURITIES AND EXCHANGE COMMISSION
                              WASHINGTON, DC 20549

                                    FORM 10-Q


[X]  QUARTERLY  REPORT  PURSUANT  TO  SECTION  13  OR  15(D)  OF  THE SECURITIES
        EXCHANGE  ACT OF 1934 FOR THE QUARTERLY PERIOD ENDED SEPTEMBER 30, 1999.

                                       or

[  ]  TRANSITION  REPORT  PURSUANT  TO  SECTION  13  OR  15(D) OF THE SECURITIES
      EXCHANGE  ACT OF 1934 FOR THE TRANSITION PERIOD FROM ___-____ TO __-_____.


                      Commission file number: 333-29001-01



                          ENERGY CORPORATION OF AMERICA
             (Exact name of registrant as specified in its charter)



                            WEST VIRGINIA  84-1235822
         (State or other jurisdiction of incorporation or organization)
                        (IRS Employer Identification No.)

                      4643 SOUTH ULSTER STREET, SUITE 1100
                             DENVER, COLORADO 80237
              (Address of principal executive offices and zip code)

                                 (303) 694-2667
              (Registrant's telephone number, including area code)



Indicate by check mark whether the registrant (1) has filed all reports required
to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during
    the preceding 12 months (or for such shorter period that the registrant was
      required to file such reports) and (2) has been subject to such filing
                       requirements for the past 90 days.
                                   Yes  x     No ___
                                      -----


    The number of shares of the Registrant's common stock, par value $1.00 per
            share, outstanding at September 30, 1999 was 645,964 shares.

<PAGE>

<TABLE>
<CAPTION>

                          ENERGY CORPORATION OF AMERICA

                                TABLE OF CONTENTS

<S>                                                                      <C>
PAGES
PART I  FINANCIAL INFORMATION

Item 1. Financial Statements

Condensed Consolidated Balance Sheets
   September 30, 1999 (unaudited) and June 30, 1999 . . . . . . . . . .   3

Unaudited Condensed Consolidated Statements of Operations
   For the three months ended September 30, 1999 and 1998 . . . . . . .   5

Unaudited Condensed Consolidated Statements of Cash Flows
   For the three months ended September 30, 1999 and 1998 . . . . . . .   6

Notes to Unaudited Condensed Consolidated Financial Statements. . . . .   7

Item 2. Management's Discussion and Analysis of Financial Condition and
Results of Operation. . . . . . . . . . . . . . . . . . . . . . . . . .  12


PART II  OTHER INFORMATION

Item 1. Legal Proceedings . . . . . . . . . . . . . . . . . . . . . . .  18

Item 2. Changes in Securities . . . . . . . . . . . . . . . . . . . . .  18

Item 3. Defaults Upon Senior Securities . . . . . . . . . . . . . . . .  18

Item 4. Submission of Matters to a Vote of Security Holders . . . . . .  18

Item 5. Other Information . . . . . . . . . . . . . . . . . . . . . . .  18

Item 6. Exhibits and Reports on Form 8-K. . . . . . . . . . . . . . . .  18

Signatures. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .  19

Exhibit Index . . . . . . . . . . . . . . . . . . . . . . . . . . . . .  20
</TABLE>

<PAGE>

PART  I  FINANCIAL  INFORMATION
ITEM  1.  FINANCIAL  STATEMENTS

<TABLE>
<CAPTION>

ENERGY  CORPORATION  OF  AMERICA
CONDENSED  CONSOLIDATED  BALANCE  SHEETS
(AMOUNTS  IN  THOUSANDS)
---------------------------------------------------------------------------------


<S>                                                          <C>         <C>
                                                          SEPTEMBER 30    JUNE 30
                                                                1999       1999
                                                            (UNAUDITED)     *
 ASSETS

 CURRENT ASSETS
    Cash and cash equivalents . . . . . . . . . . . . . . .  $   10,359  $ 13,557
    Accounts receivable, net of allowance for doubtful
       accounts of $1,062 and $1,622. . . . . . . . . . . .      29,910    32,854
    Gas in storage, at average cost . . . . . . . . . . . .         349       357
    Income tax receivable . . . . . . . . . . . . . . . . .       3,180     3,580
    Prepaid winter gas service. . . . . . . . . . . . . . .      38,139    18,474
    Prepaid and other current assets. . . . . . . . . . . .       7,048     7,146
                                                             ----------  --------
       Total current assets . . . . . . . . . . . . . . . .      88,985    75,968
                                                             ----------  --------

 Property, plant and equipment, net of accumulated
    depreciation and depletion of $120,595 and $116,893 . .     328,037   315,316
                                                             ----------  --------

 OTHER ASSETS
    Deferred financing costs, net of accumulated
       amortization of $2,738 and $2,485. . . . . . . . . .       8,319     8,523
    Notes receivable, less allowance for doubtful accounts
       of $440. . . . . . . . . . . . . . . . . . . . . . .       3,596     3,544
    Deferred utility charges. . . . . . . . . . . . . . . .      18,148    18,785
    Other . . . . . . . . . . . . . . . . . . . . . . . . .      14,813    14,806
                                                             ----------  --------
       Total other assets . . . . . . . . . . . . . . . . .      44,876    45,658
                                                             ----------  --------

 TOTAL. . . . . . . . . . . . . . . . . . . . . . . . . . .  $  461,898  $436,942
                                                             ==========  ========
<FN>

 *   Condensed  from  audited  consolidated  financial  statements.
</TABLE>

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

<PAGE>

<TABLE>
<CAPTION>

ENERGY  CORPORATION  OF  AMERICA
CONDENSED  CONSOLIDATED  BALANCE  SHEETS
(AMOUNTS  IN  THOUSANDS)
------------------------------------------------------------------------------------

<S>                                                           <C>          <C>
                                                            SEPTEMBER 30    JUNE 30
                                                                  1999        1999
                                                              (UNAUDITED)      *
 LIABILITIES AND STOCKHOLDERS' EQUITY

 CURRENT LIABILITIES
    Accounts payable . . . . . . . . . . . . . . . . . . . .  $   41,111   $ 40,049
    Current portion of long-term debt. . . . . . . . . . . .       3,590      6,634
    Short-term debt. . . . . . . . . . . . . . . . . . . . .      10,465     16,799
    Funds held for future distribution . . . . . . . . . . .       6,436      5,378
    Accrued taxes, other than income . . . . . . . . . . . .       6,066      7,635
    Overrecovered gas costs. . . . . . . . . . . . . . . . .       2,816      3,927
    Other current liabilities. . . . . . . . . . . . . . . .       8,121      8,465
                                                              -----------  ---------
       Total current liabilities . . . . . . . . . . . . . .      78,605     88,887

 LONG-TERM OBLIGATIONS
    Long-term debt . . . . . . . . . . . . . . . . . . . . .     319,787    280,021
    Gas delivery obligation and deferred trust revenue . . .      13,268     13,839
    Deferred income tax liability. . . . . . . . . . . . . .      27,731     27,868
    Other long-term obligation . . . . . . . . . . . . . . .      11,921     11,850
                                                              -----------  ---------
       Total liabilities . . . . . . . . . . . . . . . . . .     451,312    422,465
                                                              -----------  ---------


 STOCKHOLDERS' EQUITY
    Common stock, par value $1.00; 2,000,000 shares
       authorized; 721,000 shares issued . . . . . . . . . .         721        721
    Class A stock, no par value; 100,000 shares authorized;
       26,000 shares issued. . . . . . . . . . . . . . . . .       2,940      2,940
    Additional paid in capital . . . . . . . . . . . . . . .       4,656      4,656
    Retained earnings. . . . . . . . . . . . . . . . . . . .       9,293     13,598
    Treasury stock and notes receivable arising from the
       issuance of common stock. . . . . . . . . . . . . . .      (7,259)    (7,261)
    Accumulated comprehensive income (loss). . . . . . . . .         235       (177)
                                                              -----------  ---------
       Total Stockholders' equity. . . . . . . . . . . . . .      10,586     14,477
                                                              -----------  ---------

 TOTAL . . . . . . . . . . . . . . . . . . . . . . . . . . .  $  461,898   $436,942
                                                              ===========  =========
<FN>

 *   Condensed  from  audited  consolidated  financial  statements.
</TABLE>

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

<PAGE>

<TABLE>
<CAPTION>

ENERGY  CORPORATION  OF  AMERICA
CONDENSED  CONSOLIDATED  STATEMENTS  OF  OPERATIONS
(UNAUDITED  -  AMOUNTS  IN  THOUSANDS,  EXCEPT  PER  SHARE  DATA)
----------------------------------------------------------------------------------


<S>                                                  <C>             <C>
                                                        FOR THE THREE MONTHS ENDED
                                                               SEPTEMBER 30
                                                              1999       1998
 REVENUES:
    Utility gas sales and transportation. . . . . .  $      16,907   $ 13,863
    Gas marketing and pipeline sales. . . . . . . .         21,906     31,044
    Oil and gas sales . . . . . . . . . . . . . . .          6,971      5,855
    Well operations and service revenues. . . . . .          1,582      1,780
    Other revenue . . . . . . . . . . . . . . . . .            169        358
                                                     --------------  ---------
                                                            47,535     52,900
                                                     --------------  ---------
 COST AND EXPENSES:
    Utility gas purchased . . . . . . . . . . . . .          4,451      7,418
    Gas marketing and pipeline cost . . . . . . . .         21,368     30,104
    Field operating expenses. . . . . . . . . . . .          2,343      2,440
    Utility operations and maintenance. . . . . . .          5,584      5,584
    General and administrative. . . . . . . . . . .          5,165      5,111
    Taxes, other than income. . . . . . . . . . . .          2,291      2,163
    Depletion and depreciation, oil and gas related          2,171      2,175
    Depreciation of pipelines and equipment . . . .          1,989      1,948
    Exploration and impairment. . . . . . . . . . .          1,201      2,085
                                                     --------------  ---------
                                                            46,563     59,028
                                                     --------------  ---------
    Income (loss) from operations . . . . . . . . .            972     (6,128)
                                                     --------------  ---------
 OTHER (INCOME) EXPENSE
    Interest. . . . . . . . . . . . . . . . . . . .          7,102      6,604
    Gain on sale of assets. . . . . . . . . . . . .             (2)      (727)
    Other . . . . . . . . . . . . . . . . . . . . .           (256)      (432)
                                                     --------------  ---------
 Loss before income taxes and
    minority interest . . . . . . . . . . . . . . .         (5,872)   (11,573)
 Benefit from income taxes. . . . . . . . . . . . .         (1,567)    (3,750)
                                                     --------------  ---------
 Loss before minority interest. . . . . . . . . . .         (4,305)    (7,823)
 Minority interest. . . . . . . . . . . . . . . . .              -          7
                                                     --------------  ---------
 NET LOSS . . . . . . . . . . . . . . . . . . . . .  $      (4,305)  $ (7,830)
                                                     ==============  =========

 Net loss per common share,
    Basic . . . . . . . . . . . . . . . . . . . . .  $       (6.45)  $ (11.85)
    Assuming dilution . . . . . . . . . . . . . . .  $       (6.45)  $ (11.85)
</TABLE>

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

<PAGE>

<TABLE>
<CAPTION>

ENERGY  CORPORATION  OF  AMERICA
CONDENSED  CONSOLIDATED  STATEMENTS  OF  CASH  FLOWS
(UNAUDITED  -  AMOUNTS  IN  THOUSANDS)
---------------------------------------------------------------------------------------------

<S>                                                            <C>             <C>
                                                                   FOR THE THREE MONTHS ENDED
                                                                          SEPTEMBER 30
                                                                        1999       1998
 CASH FLOWS FROM OPERATING ACTIVITIES
    Net loss. . . . . . . . . . . . . . . . . . . . . . . . .  $      (4,305)  $ (7,830)
    Adjustment to reconcile net loss to net cash used
    by operating activities:
       Minority interest. . . . . . . . . . . . . . . . . . .                         7
       Depletion, depreciation and amortization . . . . . . .          4,360      4,323
       Gain on sale of assets . . . . . . . . . . . . . . . .             (2)      (727)
       Exploration and impairment . . . . . . . . . . . . . .            960      1,969
       Other, net . . . . . . . . . . . . . . . . . . . . . .           (882)    (1,291)
                                                               --------------  ---------
                                                                         131     (3,549)
    Changes in assets and liabilities
       Accounts receivable. . . . . . . . . . . . . . . . . .          5,529      8,647
       Gas in storage . . . . . . . . . . . . . . . . . . . .              8    (13,082)
       Prepaid and other assets . . . . . . . . . . . . . . .        (19,145)    (1,993)
       Accounts payable . . . . . . . . . . . . . . . . . . .            906     (1,955)
       Funds held for future distributions. . . . . . . . . .          1,058       (898)
       Overrecovered gas costs. . . . . . . . . . . . . . . .         (1,111)      (860)
       Other. . . . . . . . . . . . . . . . . . . . . . . . .           (571)    (2,797)
                                                               --------------  ---------
          Net cash used by operating activities . . . . . . .        (13,195)   (16,487)
                                                               --------------  ---------
 CASH FLOWS FROM INVESTING ACTIVITIES
    Expenditures for property, plant and equipment. . . . . .        (19,087)    (9,355)
    Proceeds from sale of assets. . . . . . . . . . . . . . .             34      1,282
    Notes receivable and other. . . . . . . . . . . . . . . .         (1,341)        13
                                                               --------------  ---------
          Net cash used by investing activities . . . . . . .        (20,394)    (8,060)
                                                               --------------  ---------
 CASH FLOWS FROM FINANCING ACTIVITIES
    Principal payment on long-term debt . . . . . . . . . . .         (3,278)      (145)
    Short-term borrowings, net. . . . . . . . . . . . . . . .         33,667     19,233
    Purchase of treasury stock and other financing activities              2       (389)
    Dividends . . . . . . . . . . . . . . . . . . . . . . . .                      (322)
                                                               --------------   --------
          Net cash provided by financing activities . . . . .         30,391     18,377
                                                               --------------  ---------
          Net decrease in cash and cash equivalents . . . . .         (3,198)    (6,170)
          Cash and cash equivalents, beginning of period. . .         13,557     21,547
                                                               --------------  ---------
 Cash and cash equivalents, end of period . . . . . . . . . .  $      10,359   $ 15,377
                                                               ==============  =========
</TABLE>

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

<PAGE>

                          ENERGY CORPORATION OF AMERICA
         NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
                               SEPTEMBER 30, 1999


1.     Nature  of  Organization

Energy Corporation of America (the "Company") was formed in June 1993 through an
exchange  of  shares  with  the  common  stockholders of Eastern American Energy
Corporation  ("Eastern  American").  The  Company  is  an independent integrated
energy  company.  All  references to the "Company" include Energy Corporation of
America  and  its  consolidated  subsidiaries.

Natural Gas Distribution System - The Company operates, through its wholly owned
-------------------------------
subsidiary  Mountaineer  Gas Company ("Mountaineer"), a natural gas distribution
system in West Virginia.  Mountaineer provides natural gas sales, transportation
and  distribution  service  to residential, commercial, industrial and wholesale
customers.  As  a  public  utility,  Mountaineer is subject to regulation by the
Public  Service  Commission  of  West  Virginia.

Oil  and  Gas  Exploration, Development, Production and Marketing - The Company,
-----------------------------------------------------------------
primarily  through  Eastern American, is engaged in exploration, development and
production,  transportation  and  marketing  of natural gas primarily within the
Appalachian  Basin  states  of  West  Virginia,  Pennsylvania  and  Ohio.

The  Company,  through  its wholly owned subsidiaries Westech Energy Corporation
and  Westech  Energy  New  Zealand,  is  also engaged in the exploration for and
production  of  oil  and  natural  gas  primarily in the Rocky Mountains and New
Zealand.


2.     Accounting  Policies

Reference  is  hereby made to the Company's Annual Report on Form 10-K for 1999,
which contains a summary of major accounting policies followed in preparation of
its  consolidated  financial  statements.  These  policies were also followed in
preparing  the  quarterly  report  included  herein.

Management  of  the  Company  believes  that all adjustments (consisting of only
normal  recurring  accruals) necessary for a fair presentation of the results of
such  interim  periods,  included  herein,  have  been  made.  The  results  of
operations  for  the  three  months ended September 30, l999 are not necessarily
indicative  of  the  results  to  be  expected  for  the  full  year.


3.     Recently  Issued  Accounting  Pronouncements

The  Company  adopted  Statement  of Financial Accounting Standards ("SFAS") No.
130,  "Reporting  Comprehensive  Income",  effective July 1, 1998.  The standard
establishes  rules for the reporting of comprehensive income and its components.
The  Company's  comprehensive  income  (loss)  consists  of  foreign  currency
translation  adjustments.

<PAGE>

In  June  1998, SFAS No. 133, "Accounting for Derivative Instruments and Hedging
Activities" was issued, which is effective for all fiscal quarters of all fiscal
years  beginning  after  June 15, 2000.  SFAS No. 133 establishes accounting and
reporting  standards  for  derivative  instruments, including certain derivative
instruments  embedded  in  other contracts, and hedging activities.  It requires
the  recognition  of  all derivative instruments as assets or liabilities in the
Company's balance sheet and measurement of those instruments at fair value.  The
accounting treatment of changes in fair value is dependent upon whether or not a
derivative  instrument  is  designated  as a hedge and if so, the type of hedge.
The  Company  has  not fully analyzed what impact the provisions of SFAS No. 133
will  have  on  the  Company's  financial  statements.


4.     Earnings  per  Share

A  reconciliation  of  the  components  of basic and diluted net loss per common
share  for  the  three months ended September 30, for the years indicated, is as
follows:

<TABLE>
<CAPTION>

<S>                                         <C>           <C>      <C>
                                                                   Per-Share
                                            Loss          Shares    Amount
                                            ------------  -------  --------
1999
----
  Basic and Diluted Earnings per Share
   Loss available to common shareholders    $(4,305,000)  666,968  $ (6.45)

1998
----
  Basic and Diluted Earnings per Share
   Loss available to common shareholders    $(7,830,000)  660,623  $(11.85)
</TABLE>

The  effect  of  outstanding  stock  options  during  the current period was not
included in the computation of diluted earnings per share because to do so would
have  been  antidilutive.  There  were  no  stock options exercisable during the
prior  period.


5.     The  Company  adopted  SFAS  No.  131,  "Disclosures About Segments of an
Enterprise  and  Related Information," in fiscal 1999.  The Company's reportable
business  segments have been identified based on the differences in products and
service  provided.  Revenues  for  the  exploration  and  production segment are
derived  from  the  production  and  sale  of  natural  gas  and crude oil.  The
regulated  utility segment generates revenue from the transportation and sale of
natural  gas  at  retail.  Revenues for the marketing and pipeline segment arise
from  the marketing of both Company and third party produced natural gas volumes
and  the related transportation.  The Company utilizes earnings before interest,
taxes,  depreciation,  depletion, amortization and exploratory costs ("EBITDAX")
to  evaluate  each  segment's  operations.

Summarized  financial information for the Company's reportable segments is shown
in  the  following  table  (in  thousands):

<PAGE>

<TABLE>
<CAPTION>
<S>                                             <C>            <C>          <C>         <C>       <C>
                                                 Exploration                Marketing
                                                     and        Regulated      and
                                                Production     Utility      Pipeline    Other     Consolidated
                                                -------------  -----------  ----------  --------  --------------
For the three months ended September 30, 1999
 Sales to unaffiliated customers . . . . . . .  $      7,530   $   16,907   $  21,421   $   169   $      46,027
 Intersegment revenues . . . . . . . . . . . .         1,105            -         485       (82)          1,508
 Depreciation, depletion, amortization . . . .         2,560          924         311       365           4,160
 Exploratory costs . . . . . . . . . . . . . .         1,201                                              1,201
 Operating profit (loss) . . . . . . . . . . .           952          945        (584)     (341)            972
 Interest expense. . . . . . . . . . . . . . .            14        1,802                 5,286           7,102
 EBITDAX . . . . . . . . . . . . . . . . . . .         4,867        1,909        (338)      154           6,592
 Total assets. . . . . . . . . . . . . . . . .        88,290      220,654      65,267    87,687         461,898
 Capital expenditures. . . . . . . . . . . . .         3,291       15,683          97        16          19,087
----------------------------------------------  -------------  -----------  ----------  --------  --------------
For the three months ended September 30, 1998
----------------------------------------------
 Sales to unaffiliated customers . . . . . . .         6,729       13,863      24,693       358          45,643
 Intersegment revenues . . . . . . . . . . . .         1,009                    6,351      (103)          7,257
 Depreciation, depletion, amortization . . . .         2,612          802         331       378           4,123
 Exploratory costs . . . . . . . . . . . . . .         2,130                                (45)          2,085
 Operating profit (loss) . . . . . . . . . . .          (926)      (4,935)         31      (298)         (6,128)
 Interest expense. . . . . . . . . . . . . . .            34        1,606                 4,964           6,604
 EBITDAX . . . . . . . . . . . . . . . . . . .         4,813       (3,984)        313        91           1,233
 Total assets. . . . . . . . . . . . . . . . .        98,241      200,111      71,462    74,231         444,045
 Capital expenditures. . . . . . . . . . . . .         6,423        2,671         201        60           9,355
----------------------------------------------  -------------  -----------  ----------  --------  --------------
</TABLE>

Operating  profit  (loss)  represents  revenues  less  costs  which are directly
associated  with  such  operations.  Revenues  are  priced  and  accounted  for
consistently  for  both unaffiliated and intersegment sales.  Intersegment sales
between  the  exploration  and production and the utility segments have not been
eliminated  in  consolidation  because  of  the  regulated  nature  of  the  gas
distribution  segment.  The  'Other'  column  includes  items  related  to
non-reportable  segments,  corporate  and  elimination  items.  Included  in the
regulated  utility  segment's  capital  expenditures  for the three months ended
September  30,  1999  is  $12.6  million  related  to  the  acquisition  cost of
substantially  all  of  the  West  Virginia  assets  of  Shenandoah  Gas Company
("Shenandoah").  Included  in  the  exploration  and  production segment's total
assets  are  net  long-lived  assets  located  in  New  Zealand of $3.0 and $2.0
million,  as  of  September  30,  1999  and  1998,  respectively.

<PAGE>

6.     Debt

A  rollforward  of  the  debt  from  June  30, 1999 to September 30, 1999, is as
follows  (in  thousands):

<TABLE>
<CAPTION>

<S>                                 <C>           <C>             <C>         <C>
                                                    Current
                                    Short Term    Portion Long    Long Term    Total Long
                                      Debt          Term Debt       Debt        Term Debt
                                    ------------  --------------  ----------  -----------
 Balance at June 30, 1999. . . . .  $    16,799   $       6,634   $  280,021  $   286,655
   Short term borrowings, net. . .       33,666
   Issue long term debt, effective                                    40,000       40,000
      November 1, 1999
   Effectively pay down short
      term debt. . . . . . . . . .      (40,000)
   Long term debt payment. . . . .                       (3,278)                   (3,278)
   Reclassify long term debt to
      current portion. . . . . . .                          234        (234)
                                    ------------  --------------
 Balance at September 30, 1999 . .  $    10,465   $       3,590   $  319,787  $   323,377
                                    ============  ==============  ==========  ===========
</TABLE>

The  Company's  scheduled  maturities  of long term debt for each of the periods
indicated  is  as  follows  (in  thousands):

<TABLE>
<CAPTION>

For the Quarter Ending:
<S>                          <C>
  December 31, 1999 . . . .  $    909
  March 31, 2000. . . . . .       910
  June 30, 2000 . . . . . .       905
  September 30, 2000. . . .       866
                             --------
  Total current . . . . . .     3,590

  December 31, 2000 . . . .        32
  March 31, 2001. . . . . .        32
  June 30, 2001 . . . . . .        29

For the Fiscal Year Ending:
  June 30, 2002 . . . . . .    22,462
  June 30, 2003 . . . . . .     3,461
  June 30, 2004 . . . . . .     3,461
  June 30, 2005 . . . . . .     3,461
  Thereafter. . . . . . . .   286,849
                             --------
     Total. . . . . . . . .  $323,377
                             ========
</TABLE>

On  November  1,  1999,  Mountaineer  completed  new  financing arrangement with
several  private  lenders  to  provide  $40.0  million  in  additional unsecured
long-term  financing.  This  commitment  consisted  of  $10.0  million  in 7.83%
unsecured  notes  due  2009 and $30.0 million in 8.09% unsecured notes due 2019,
with  no  required  prepayments.  The  funds  were  used  to  reduce outstanding
borrowings  under  Mountaineer's  short-term  lines  of  credit.

The  Company's  various  debt  agreements  contain  certain  restrictions  and
conditions  among  which  are  limitations  on  indebtedness, funding of certain
subsidiaries, dividends and investments, and certain tangible net worth and debt
and interest coverage ratio requirements.  The agreements require the Company to
maintain  certain  financial  conditions,  including  a  minimum  net  worth,
restriction  on funded debt and restrictions on the amount of dividends that can
be  declared.  Additionally, under its debt covenants, Mountaineer is restricted
in  the  payment  of  dividends  to  the  Company.  As  of  September  30, 1999,
Mountaineer  had  approximately  $5.3  million  available for the declaration of
dividends.


7.     Contingencies

The  Company  is  involved  in  various  legal actions and claims arising in the
ordinary course of business.  Management does not expect these matters to have a
material  adverse  effect  on  the  Company's  financial  position.

<PAGE>

         ITEM 7.     MANAGEMENT'S DISCUSSION AND ANALYSIS OF RESULTS OF
         -------     --------------------------------------------------
                       OPERATIONS AND FINANCIAL CONDITION
                       ----------------------------------

     This  discussion  and  analysis  of  financial  condition  and  results  of
operations,  and  other  sections  of  this  Form  10-Q, contain forward-looking
statements  that  are  based  on  management's  beliefs,  assumptions,  current
expectations,  estimates  and  projections  about  the oil and gas industry, the
economy  and  about the Company itself.  Words such as "anticipates," believes,"
"estimates,"  "expects,"  "forecasts,"  "intends,"  "is  likely,"  "plans,"
"predicts,"  "projects,"  variations  of  such words and similar expressions are
intended  to identify such forward-looking statements.  These statements are not
guarantees  of  future  performance and involve certain risks, uncertainties and
assumptions  that  are  difficult  to  predict  with  regard  to timing, extent,
likelihood and degree of occurrence.  Therefore, actual results and outcomes may
materially  differ  from  what  may  be  expressed  or  forecasted  in  such
forward-looking  statements.  Furthermore,  the Company undertakes no obligation
to  update,  amend or clarify forward-looking statements, whether as a result of
new  information,  future  events  or  otherwise.

     Important factors that could cause actual results to differ materially from
the  forward-looking  statements  include,  but  are  not  limited  to,  weather
conditions, changes in production volumes, worldwide demand and commodity prices
for  petroleum natural resources, the timing and extent of the Company's success
in  discovering,  acquiring,  developing  and  producing  oil  and  natural  gas
reserves,  risks  incident  to the drilling and operation of oil and natural gas
wells,  future  production  and  development  costs,  the effect of existing and
future  laws, governmental regulations and the political and economic climate of
the  United  States  and  New  Zealand,  the  effect  of hedging activities, and
conditions  in  the  capital  markets.

COMPARISON  OF  RESULTS  OF  OPERATIONS FOR THE THREE MONTHS ENDED SEPTEMBER 30,
--------------------------------------------------------------------------------
1999  AND  1998
---------------

The  Company  recorded  a  net  loss  of $4.3 million for the three months ended
September 30, 1999 compared to a net loss of $7.8 million for the same period in
1998.  The increase in income of $3.5 million is attributed to the net of a $5.4
million  decrease in revenue, an $11.6 million decrease in operating expenses, a
$0.9  million  decrease  in  impairment  and  exploratory  costs, a $0.9 million
decrease  in  other  non-operating  income,  a $0.5 million increase in interest
expense  and  a  $2.2  million  decrease  in  income  tax  benefits.

REVENUES.  Total  revenues  decreased $5.4 million or 10.1% between the periods.
--------
The  decrease  was  due to a 29.4% decrease in gas marketing and pipeline sales,
which was offset by a 22.0% increase in utility gas sales and transportation and
a  19.1%  increase in oil and gas sales.  Well and service operating revenue and
other  operating  revenue  remained  relatively  constant  between  the periods.

     Revenues  from gas marketing and pipeline sales decreased $9.1 million from
$31.0 million during the period ended September 30, 1998 to $21.9 million during
the  period  ended  September  30,  1999.  The  decrease in revenue is primarily
attributable to a 45% decline in marketed gas volumes from 12.7 million Mmbtu to
7.0 million Mmbtu, partially offset by a 22% increase in the average sales price
per  Mmbtu  from $2.22 for the quarter ended September 30, 1998 to $2.71 for the
quarter  ended September 30, 1999.  The decline in volumes for the quarter ended
September  30,  1999  was partially attributable to the expiration of contracts,
which  accounted  for  $7.6 million in sales and 3.7 Bcfe.  Also contributing to
the  decreased  revenue is the reduction of trading activity volumes as a result
of  the  marketing  focus  change.  At  the  end of the last fiscal year, it was
decided  that  the  Company would no longer enter into contracts to purchase and
resell  independent producers gas as this business was becoming more competitive
and  less  economical to maintain.  Instead, the Company will focus on marketing
its  production.

<PAGE>

     Revenues  from  oil  and gas sales increased $1.1 million from $5.9 million
for  the  period  ended  September 30, 1998 to $7.0 million for the period ended
September  30, 1999.  The increase in revenue is primarily attributable to a 37%
increase  in  the  average  per barrel oil price from $12.53 to $17.17 and a 22%
increase  in the average per Mcf gas price from $2.21 to $2.70 between September
30,  1998  and  1999.  Mcfe  production volumes were comparable between periods.

     Utility  gas sales and transportation revenues increased approximately $3.0
million  during  the three months ended September 30, 1999 compared to the prior
year.  Of  this  amount,  approximately $2.6 million was the result of increased
tariff sales and $0.4 million resulting from additional transportation revenues.
The  increase  in  tariff  sales  resulted primarily from more favorable weather
conditions  during the current period as system-wide average heating degree days
were 104 compared to 51 in the prior year and additional customers acquired from
Shenandoah.  Tariff  sales  volumes increased approximately 29%, from 1.4 Bcf to
1.8  Bcf during the current period.  Transportation revenues increased despite a
decrease  in  related volumes from 8.1 Bcf to 7.7 Bcf during the current period.
The  decline  in  volumes was primarily the result of reduced throughput for one
particular  customer;  however, this reduction did not have a significant effect
on  revenues  due to the related contract price.  The increase in transportation
revenues  resulted from an increase in Mountaineer's transportation tariff rates
effective  November  1,  1998.

     COSTS  AND  EXPENSES.  The  Company's  costs  and  expenses decreased $11.6
     --------------------
million  or  19.0% during this period primarily as the result of a 40.0% decline
in  the  cost of utility gas purchased and a 29.0% decrease in gas marketing and
pipeline  costs.  Field  and  lease  operating  expenses, utility operations and
maintenance  costs, general and administrative expenses, taxes other than income
and  depreciation, depletion and amortization costs remained relatively constant
between  the  periods.

Utility gas purchase costs decreased approximately $3.0 million during the three
months  ended  September  30,  1999  compared  to the same period in 1998.  This
decrease  was  partially due to a $2.1 million refund from the Company's primary
transmission  service  provider,  which  was  approved  by  the  Federal  Energy
Regulatory  Commission in September 1999.  Also contributing to the decrease was
the  effect  of  the  Company's  gas  supply  management  agreement (the "Supply
Agreement"),  as  discussed in the Company's Form 10-K filed with the Securities
and  Exchange  Commission  on  September  28,  1999,  which  went into effect on
November  1,  1998.  This  agreement results in the demand costs associated with
transmission  services  provided  to the Company being included in a fixed price
per  dekatherm  delivered  either  to its city gate or for winter service rather
than  as  a  fixed monthly charge.  The following table presents a comparison of
the  costs of utility gas purchased for the periods indicated, dollar amounts in
thousands,  except  cost  per  unit  sold:

<TABLE>
<CAPTION>


<S>              <C>         <C>          <C>       <C>
                   September 30, 1999      September 30, 1998
                   ------------------      ------------------
                              Cost Per              Cost Per
                 Cost        Unit Sold    Cost      Unit Sold
                 ----------  -----------  --------  -----------

 Demand costs .  $     178                $ 5,935
 Refund . . . .     (2,100)
                 ----------               --------
 Total demand .     (1,922)  $    (1.04)    5,935   $     4.20
 Commodity. . .      6,849         3.71     2,489         1.76
 Other. . . . .       (476)       (0.26)   (1,006)       (0.71)
                 ----------  -----------  --------  -----------
 Total gas cost  $   4,451   $     2.41   $ 7,418   $     5.25
                 ==========  ===========  ========  ===========

 Mcf sold . . .      1,847                  1,414
</TABLE>

<PAGE>

Prepaid  winter gas service, related to the Supply Agreement, totaled 11,716,997
dth,  6,083,402 dth and 11,704,667 dth (previously classified as gas in storage)
and  account balances of $38.1 million ($3.26 per dth), $18.5 million ($3.04 per
dth)  and $25.9 million ($2.21 per dth) at September 30, 1999, June 30, 1999 and
September  30,  1998,  respectively.

     Assuming  volumes  delivered to the city gate reach a specified level for a
twelve month period, total costs for transmission services included in the fixed
price will approximate the amount previously incurred as a fixed monthly amount.
To  the extent volumes delivered are below the specified level, the Company will
experience  a reduction in such costs.  For the three months ended September 30,
1998,  the  Company  incurred approximately $5.9 million in fixed monthly demand
charges.  During  the  same  period  of 1999, the Company recorded approximately
$1.6  million through purchased gas expense for transmission related costs under
the  Supply  Agreement.  These  decreases  were  partially  offset  by:

a.   Increased  volumes  purchased  resulting  from  higher sales volumes due to
favorable  weather  conditions  and  the  additional  customers  acquired  from
Shenandoah,  which  resulted  in  gas  costs  of  approximately  $1.6  million.

b.   An  increase  in commodity prices (or, in the case of the Supply Agreement,
fixed  price  less the transmission cost component) which increased gas costs by
approximately  $1.1  million.

c.   Reduced amortization of previously overrecovered gas costs of approximately
$.5  million as a result of the Company current rate moratorium, which went into
effect  on  November  1,  1998.

     The  $8.7 million decrease in gas marketing and pipeline costs is primarily
the  result of a 45% decline in purchased gas volumes from 12.9 million Mmbtu to
7.1  million  Mmbtu  from  September  30, 1998 to September 30, 1999.  Partially
offsetting  this  decline  in costs was a 19% increase in the average price paid
for  gas  purchased,  from  $2.20  per Mmbtu to $2.61 per Mmbtu between periods.
Additionally,  approximately  $0.8  million  of purchased gas costs were charged
against  a  reserve  for  losses on future gas purchases during the three months
ended  September  30,  1998.

Impairment  and exploratory expenses decreased $0.9 million primarily due to the
drilling  of  two dry holes in New Zealand during the prior period, resulting in
$1.5  million  of impairment expense compared to none during the current period.
This was partially offset by an increase in domestic impairment expense increase
of  $0.4  million due to the drilling of 3.5 net dry holes in the current period
compared  to  0.8  in  the  prior  period.

     INTEREST  EXPENSE.  Interest  expense  increased between the periods due to
     -----------------
the net addition to long-term debt, including the current portion and short term
debt  of $33.5 million, when comparing September 30, 1999 to September 30, 1998.


     OTHER  (INCOME)  EXPENSE.  Other  income  decreased a total of $0.9 million
     ------------------------
primarily  due to the recognition of gains on the sale of property during fiscal
1999 and none during the current period.  In addition, interest income decreased
$0.1  million  due  to  a  decrease  in  cash  and  cash  equivalents.

     BENEFIT  FOR  INCOME  TAXES.  The  benefit  for  income  taxes changed $2.2
     ---------------------------
million  primarily  because  of  the  decrease  in  pre-tax  loss.

<PAGE>

LIQUIDITY  AND  CAPITAL  RESOURCES
----------------------------------

     The  Company's  primary  sources  of  liquidity  are (1) cash provided from
operating activities (2) short-term debt and credit facilities and (3) long-term
revolving  debt  facilities.  Since  July  1,  1999,  the  Company's  financial
condition  declined  as cash used in operating activities totaled $13.2 million,
cash  on  hand  decreased  $3.2 million, working capital increased $23.3 million
after  reclassification of $40 million of short-term debt to long-term debt (see
Note  6),  debt  to  equity increased from 21 to 1 to 32 to 1, and the Company's
equity  decreased  by  $3.9  million.  Funds available for the Company's utility
operation,  resulting  from  unused  short-term  and revolving credit facilities
totaled  $16.5  million  at September 30, 1999 and $47.8 million at November 12,
1999,  after  reclassification  of  short-term  debt  previously  discussed.  In
addition, on October 12, 1999 Moody's Investors Service downgraded its rating of
the  Company's  $200 million Senior Subordinated Notes due 2007 to Caa1 from B2,
and the Company's secured $22 million Revolving Credit Facility to Ba3 from Ba2.
On  October  18, 1999 Standard and Poor's lowered its corporate credit rating of
the  Company  to  single  'B'  plus from double 'B' minus and lowered its Senior
Subordinated  Notes rating to single 'B' minus from single 'B'.  The agency also
placed  the  ratings  on Credit Watch with negative implications, which indicate
that  ratings  may  be  lowered  again  in  the  future.

The  Company's  cash  balance  decreased  $3.2  million  during the period.  The
decrease  in  cash  during  the  quarter  primarily  resulted  from cash used in
operating  activities  totaling $13.2 million after a non-recurring $2.1 million
cash  refund from an interstate gas transporter.  The Company is generally a net
user  of  funds from operations during this reporting period due to the seasonal
nature  of  its  utility  business  and  its merchant natural gas business.  The
Company's  cash  balance was also impacted by its investments in property, plant
and  equipment,  which  totaled  $19.1  million,  debt principal payment of $3.0
million  required under the Revolving Credit Facility Amended Debt Agreement and
other  uses  totaling  $1.6  million.  Subsequent to the balance sheet date, the
utility  operation  of  the  company  borrowed  $40.0  million, of which all the
proceeds were used to repay short-term indebtedness.  This transaction increased
the  utility's  ability  to  borrow  under  its  short-term credit facilities by
approximately  $40  million.

Prior  to  the  reclassification  of  the  $40  million short-term debt, working
capital  decreased  from  a  negative $12.9 at June 30, 1999 to a negative $29.6
million  at  September  30,  1999.  After  the reclassification, working capital
increased  $23.3 million to a positive $10.4 million, primarily as a result of a
$19.6  million  increase in prepaid winter gas service relating to the Company's
utility  operation  under  the  utility's  Supply  Agreement.

The  Company's  primary  sources  of  liquidity  and capital resources have been
adversely  impacted  by the Company's results of operations, long-term revolving
debt  agreement amendments and external capital market ratings.  The Company has
attempted to mitigate its exposure to gas price risk by hedging 15,000 Mmbtu per
day  of  its  gas  production  under  various  hedging  arrangements  and  has
substantially  reduced its purchased gas price exposure at its utility operation
by  entering  into  the  Supply Agreement.  In addition, the Company has omitted
dividend  payments  and  taken  steps to minimize capital expenditure outlays by
restructuring  certain  opportunities relating to current and future oil and gas
activities.  In  the  remaining  portion of the current fiscal year, the Company
estimates  it  will  invest  an additional $7.8 million in the Company's utility
operation, repay an additional $3.0 million in long-term debt, pay $19.0 million
in  interest payments, and spend approximately $10.5 (including $1.25 million as
other  property  and  equipment)  in  discretionary  oil  &  gas  drilling  and
exploration  activities.  Other than the $3.0 million under the Revolving Credit
Facility  repayment  during  the  twelve  months  ending  September 30, 2000, as
mentioned  above,  no other significant principal payments are due until October
1,  2001  when  the  Company's  utility  commences  principal repayments of $3.3
million  per  year  on  its  $60  million,  7.59% notes due to John Hancock.  In
addition,  the Company's $19.0 million Revolving Credit Facility becomes due May
2002.  In  the  event  that cash from operating activities are not sufficient to
offset  the  cash outflows required above, the Company believes that the capital
expenditures  and  debt  service  obligations, required at the Company's utility
operations,  can  be  funded  through  the  utility's  existing  resources  and
short-term  credit  facilities  in the near term.  The Company believes that the
debt  and interest obligations on its Senior Subordinated Debt and its Revolving
Credit  Facility can be partially funded through dividend and income tax sharing
arrangement  payments from the Company's utility operation and from its existing
oil  and  gas operating activities.  However, the Company's utility operation is
restricted  as  to the amount of dividends it is permitted to pay to the parent,
$5.3  million  is  available  at September 30, 1999 (see Note 6).  Other capital
investments  in  oil  and gas exploration and development drilling opportunities
may  be financed on a cash available basis since the Company's amended Revolving
Debt Agreement, typically used to fund such drilling opportunities, is currently
at  its  maximum  draw  down  capability.

<PAGE>

     The  Company  believes  that its existing capital resources, its mitigating
management  efforts, and its expected fiscal year 2000 results of operations and
cash  flows  from  operating  activities  will  be sufficient for the Company to
remain  in compliance with the requirements of its Senior Subordinated Debt, its
Revolving  Credit  Facility,  and  the  short  and  long-term  debt  and  credit
facilities  at  its  utility  operation,  and  will  be  sufficient  to  fund
non-discretionary capital expenditures.  However, since the expected fiscal year
2000 results of operations and cash flow from operating activities, debt service
capability,  and  levels  and  availability  of capital resources and continuing
liquidity  are  dependent on future weather patterns, maintaining current levels
of  oil  and  gas  commodity sales prices and future exploration and development
drilling  success, the Company can give no assurance that such expectations will
be realized or that debt service or debt covenant violations will not occur.  In
such  instances, the Company may elect to increase debt levels, restructure debt
agreements  (including  debt  agreements with additional lenders), sell core and
non-core  assets  including  a  portion  or  all of its utility subsidiary or it
exploration  and  development  subsidiaries,  defer  discretionary  capital
expenditures, curtail certain domestic and international oil and gas programs or
take  other  actions  necessary  to  mitigate  liquidity  short-falls  and  debt
agreement violations or acquire new or additional capital resources, although no
assurances  can  be  given  that  such  actions  will  be  successful.

YEAR  2000  COMPLIANCE.  The year 2000 issue arose because many computer systems
----------------------
and  software  applications  as well as embedded computer chips currently in use
were  constructed  using an abbreviated date field that eliminates the first two
digits  of  the  year.  On  January  1,  2000,  these  systems, applications and
embedded  computer  chips may incorrectly recognize the date as January 1, 1900.
Accordingly,  many  computer  systems  and  software  applications,  as  well as
embedded  chips,  may  incorrectly process financial or operating information or
fail  to  process  such  information  completely.  The  company  recognized this
problem  and  is  addressing  its  potential  effects  on  its computer systems,
software  applications  and  operating  assets.

The Company began its Year 2000 compliance efforts in 1996 and has completed its
assessment  of its key business information systems to determine what issues, if
any,  exist  regarding  these  systems'  compliance with Year 2000 issues and is
taking  the  necessary steps to ensure its systems will be compliant by the year
2000.  These  steps  include  the  purchase  and implementation of an integrated
application  software  package,  that  together with the associated hardware and
external  consulting  resources,  which  to  date,  has  cost approximately $7.4
million.  In  addition,  the  Company is presently completing of modification of
existing operating and application systems that were not Year 2000 compliant and
anticipates  that  it will be successful in completing such modifications before
the  1999  calendar year end.  With the exception of the new application package
discussed  above,  the  Company  anticipates  that it can complete the necessary
modifications  to  its  information  systems  to  ensure  Year  2000  compliance
utilizing  internal  resources.  The  costs  associated  with  modification  of
existing  information consist primarily of personnel expense for staff dedicated
to the effort.  The Company's policy is to expense these costs as incurred.  The
Company  also has  invested  in  new or upgraded technology, which has definable
value  lasting  beyond  2000.  In these instances, such as the implementation of
the integrated software application discussed above, the Company is capitalizing
and  depreciating  such  costs  over  their  estimated  useful  life.

<PAGE>

     In  addition  to  reviewing  its  own  computer  operating  and application
systems, the Company has communicated with its significant suppliers and vendors
to  determine the extent to which these parties have addressed Year 2000 issues.
To  the  extent  such  vendors  have  not  provided reasonable assurances to the
Company  of  their  readiness to handle Year 2000 issues, contingency plans have
been  developed.  There  is  no  assurance  that  such  parties can complete the
necessary  modifications and conversions in a timely manner.  To the extent such
modifications  and  conversions  are  not completed on a timely basis and issues
outside  of  the  companies  control  arise,  the  Year 2000 issue could have an
adverse  impact  on  the  operations  of  the  Company.

     The costs associated with addressing Year 2000 issues and the date on which
the Company believes it will complete the necessary modifications are based upon
management's  best  estimates.  There  can  be no guarantee that these estimates
will  be  achieved  and  actual  results  could  differ  from those anticipated.

<PAGE>

PART  II.  OTHER  INFORMATION

ITEM  1.  LEGAL  PROCEEDINGS

The Company is not a party to any legal actions that would materially affect the
Company's  operations  or  financial  statements.


ITEM  2.  CHANGES  IN  SECURITIES

None


ITEM  3.  DEFAULTS  UPON  SENIOR  SECURITIES

None


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

None


ITEM  5.  OTHER  INFORMATION

None


ITEM  6.  EXHIBITS  AND  REPORTS  ON  FORM  8-K

(a)     27     Financial  Data  Schedule

(b)     No  reports  on  Form  8-K  have  been  filed  during  the quarter ended
September  30,  1999

<PAGE>

                                   SIGNATURES


     Pursuant  to  the  requirements of the Securities Exchange Act of 1934, the
registrant  has  duly caused this report to be signed on its behalf by the under
signed  thereunto, duly authorized, in the City of Denver, State of Colorado, on
the  15th  day  of  November,  1999.


                                             ENERGY  CORPORATION  OF  AMERICA



                                             By:     /s/John  Mork
                                                     -------------
                                             John  Mork
                                             Chief  Executive  Officer
                                             and  Director



                                             By:     /s/Isobel  Allan
                                                     ----------------
                                             Isobel  Allan
                                             Vice  President  of  Finance


<PAGE>

                                  EXHIBIT INDEX


Exhibit
Number          Description
------          -----------

27     Financial  Data  Schedule