UNITED STATES OF AMERICA
                       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, 2002.

                                       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, 2002 was 623,773 shares.

<PAGE>
                          ENERGY CORPORATION OF AMERICA

                                TABLE OF CONTENTS


                                                                          PAGES
PART  I  FINANCIAL  INFORMATION

<TABLE>
<CAPTION>

Item  1.  Financial  Statements
<S>                                                                       <C>
        Condensed  Consolidated  Balance  Sheets
          September  30,  2002  (unaudited)  and June 30, 2002. . . . . . . . . . 3

        Unaudited Condensed Consolidated Statements of Operations
          For the three months ended September 30, 2002 and 2001. . . . . . . .   5

        Unaudited Condensed Consolidated Statements of Cash Flows
          For the three months ended September 30, 2002 and 2001. . . . . . . .   6

        Unaudited Condensed Consolidated Statements of Comprehensive Income
          For the three months ended September 30, 2002 and 2001. . . . . . . .   7

        Notes to Unaudited Condensed Consolidated Financial Statements . . . . .  8

Item 2. Management's Discussion and Analysis of Results of Operation and
        Financial Condition. . . . . . . . . . . . . . . . . . . . . . . .  . .  10

Item 3. Quantitative and Qualitative Disclosures About Market Risk . . . . .  .  14

Item 4. Controls and Procedures. . . .  . .  . . . . . . . . . . . . . . . .  .  15


PART II  OTHER INFORMATION

Item 1. Legal Proceedings. . . . . . . . . . . . . . .  . . . . . . . . . . . .  15

Item 2. Changes in Securities. . . . . . . . . . . . . . . . . . . . . .  . .  . 16

Item 3. Defaults Upon Senior Securities. . . . . . . . . . . . . . .  . . . . .  16

Item 4. Submission of Matters to a Vote of Security Holders. . . . . . . . . . . 16

Item 5. Other Information. . . . . . . . . . . . . . . . . . . . . . .  . . . .. 16

Item 6. Exhibits and Reports on Form 8-K . . . . . . . . . . . . . . . . . . . . 16

Signatures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .  . .. . . 17
</TABLE>

                                     -2-
<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
                                                                     2002         2002
                                                                 (UNAUDITED)        *
 ASSETS

 CURRENT ASSETS
    Cash and cash equivalents . . . . . . . . . . . . . . . . .  $      20,667  $ 17,775
    Accounts receivable, net of allowance for doubtful
       accounts of $1,344 and $1,366. . . . . . . . . . . . . .         16,745    18,165
    Gas inventory . . . . . . . . . . . . . . . . . . . . . . .            117       199
    Deferred income tax asset . . . . . . . . . . . . . . . . .          2,237     2,237
    Prepaid and other current assets. . . . . . . . . . . . . .          3,649     6,085
                                                                 -------------  --------
       Total current assets . . . . . . . . . . . . . . . . . .         43,415    44,461
                                                                 -------------  --------

 Property, plant and equipment, net of accumulated
    depreciation and depletion of $117,924 and $116,294 . . . .        242,852   244,155
                                                                 -------------  --------

 OTHER ASSETS
    Deferred financing costs, net of accumulated
       amortization of $4,043 and $3,722. . . . . . . . . . . .          4,587     3,617
    Notes receivable. . . . . . . . . . . . . . . . . . . . . .          1,735     1,756
    Other . . . . . . . . . . . . . . . . . . . . . . . . . . .         10,806    10,747
                                                                 -------------  --------
       Total other assets . . . . . . . . . . . . . . . . . . .         17,128    16,120
                                                                 -------------  --------

 TOTAL. . . . . . . . . . . . . . . . . . . . . . . . . . . . .  $     303,395  $304,736
                                                                 =============  ========

 *   Condensed from audited consolidated financial statements.
<FN>

 The  accompanying  notes are an integral part of these condensed consolidated financial
statements.
</TABLE>

                                     -3-
<PAGE>

<TABLE>
<CAPTION>

 ENERGY  CORPORATION  OF  AMERICA
 CONDENSED  CONSOLIDATED  BALANCE  SHEETS
 (AMOUNTS  IN  THOUSANDS,  EXCEPT  SHARE  DATA)
------------------------------------------------------------------------------------------

<S>                                                              <C>             <C>
                                                                 SEPTEMBER 30      JUNE 30
                                                                     2002           2002
                                                                 (UNAUDITED)         *
 LIABILITIES AND STOCKHOLDERS' EQUITY

 CURRENT LIABILITIES
    Accounts payable and accrued expenses . . . . . . . . . . .  $      16,634   $ 15,683
    Current portion of long-term debt . . . . . . . . . . . . .            124        121
    Funds held for future distribution. . . . . . . . . . . . .         11,545     11,414
    Taxes payable . . . . . . . . . . . . . . . . . . . . . . .          5,743      8,221
    Other current liabilities . . . . . . . . . . . . . . . . .          7,634      7,258
                                                                 --------------  ---------
       Total current liabilities. . . . . . . . . . . . . . . .         41,680     42,697

 LONG-TERM OBLIGATIONS
    Long-term debt. . . . . . . . . . . . . . . . . . . . . . .        202,977    198,701
    Gas delivery obligation and deferred revenue. . . . . . . .          4,322      5,886
    Deferred income tax liability . . . . . . . . . . . . . . .          9,887      9,887
    Other long-term obligation. . . . . . . . . . . . . . . . .          8,408      8,689
                                                                 --------------  ---------
       Total liabilities. . . . . . . . . . . . . . . . . . . .        267,274    265,860
                                                                 --------------  ---------
 Minority Interest. . . . . . . . . . . . . . . . . . . . . . .          1,678      1,732
                                                                 --------------  ---------

 STOCKHOLDERS' EQUITY
    Common stock, par value $1.00; 2,000,000 shares
       authorized; 730,039 shares issued. . . . . . . . . . . .            730        730
    Class A stock, no par value; 100,000 shares authorized;
       45,582 shares issued . . . . . . . . . . . . . . . . . .          5,092      5,092
    Additional paid in capital. . . . . . . . . . . . . . . . .          5,503      5,503
    Retained earnings . . . . . . . . . . . . . . . . . . . . .         34,599     36,422
    Treasury stock and notes receivable arising from the
       issuance of common stock . . . . . . . . . . . . . . . .        (10,606)   (10,426)
    Accumulated comprehensive income (loss) . . . . . . . . . .           (875)      (177)
                                                                 --------------  ---------
       Total stockholders' equity . . . . . . . . . . . . . . .         34,443     37,144
                                                                 --------------  ---------

 TOTAL. . . . . . . . . . . . . . . . . . . . . . . . . . . . .  $     303,395   $304,736
                                                                 ==============  =========

 *   Condensed from audited consolidated financial statements.
<FN>

 The  accompanying  notes  are  an integral part of these condensed consolidated financial
statements.
</TABLE>

                                     -4-
<PAGE>

<TABLE>
<CAPTION>

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


                                                              THREE MONTHS ENDED
                                                                 SEPTEMBER 30
<S>                                                  <C>             <C>
                                                              2002         2001
 REVENUES:
    Oil and gas sales . . . . . . . . . . . . . . .  $       9,164   $   11,510
    Gas marketing and pipeline sales. . . . . . . .         11,922       10,479
    Well operations and service revenues. . . . . .          1,467        1,405
    Other revenue . . . . . . . . . . . . . . . . .             36            -
                                                     --------------  -----------
                                                            22,589       23,394
                                                     --------------  -----------
 COST AND EXPENSES:
    Field operating expenses. . . . . . . . . . . .          2,485        2,509
    Gas marketing and pipeline cost . . . . . . . .         10,755       10,040
    General and administrative. . . . . . . . . . .          3,560        3,524
    Taxes, other than income. . . . . . . . . . . .            632          522
    Depletion and depreciation, oil and gas related          3,052        3,331
    Depreciation of pipelines and equipment . . . .            856          745
    Exploration and impairment. . . . . . . . . . .            572          779
                                                     --------------  -----------
                                                            21,912       21,450
                                                     --------------  -----------
    Income from operations. . . . . . . . . . . . .            677        1,944
 OTHER (INCOME) EXPENSE
    Interest expense. . . . . . . . . . . . . . . .          4,881        4,895
    Interest income and other . . . . . . . . . . .         (1,756)        (687)
                                                     --------------  -----------
 Loss from operations before income taxes . . . . .         (2,448)      (2,264)
 Income tax benefit . . . . . . . . . . . . . . . .           (824)        (747)
                                                     --------------  -----------
 Loss from operations before minority interest. . .         (1,624)      (1,517)
 Minority interest. . . . . . . . . . . . . . . . .            (62)           -
                                                     --------------  -----------
 NET LOSS . . . . . . . . . . . . . . . . . . . . .  $      (1,562)  $   (1,517)
                                                     ==============  ===========

 Basic and diluted earnings per common share:
    Net loss. . . . . . . . . . . . . . . . . . . .  $       (2.38)  $    (2.30)
                                                     ==============  ===========
<FN>

 The  accompanying  notes  are  an integral part of these condensed consolidated
financial  statements.
</TABLE>

                                     -5-
<PAGE>

<TABLE>
<CAPTION>

 ENERGY  CORPORATION  OF  AMERICA
 CONDENSED  CONSOLIDATED  STATEMENTS  OF  CASH  FLOWS
 (UNAUDITED  -  AMOUNTS  IN  THOUSANDS)
----------------------------------------------------------------------------------------------------
                                                                                 THREE MONTHS ENDED
                                                                                    SEPTEMBER 30
<S>                                                                              <C>       <C>
                                                                                    2002       2001
 CASH FLOWS FROM OPERATING ACTIVITIES
    Net loss from operations. . . . . . . . . . . . . . . . . . . . . . . . . .  $(1,562)  $ (1,517)
    Adjustments to reconcile net loss to net cash used by operating activities:
       Depletion, depreciation and amortization . . . . . . . . . . . . . . . .    4,088      4,260
       Impairment and exploratory expense . . . . . . . . . . . . . . . . . . .      487        614
       Other, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .   (2,002)    (1,037)
                                                                                 --------  ---------
                                                                                   1,011      2,320
    Changes in assets and liabilities:
       Accounts receivable. . . . . . . . . . . . . . . . . . . . . . . . . . .    1,425      3,099
       Gas inventory. . . . . . . . . . . . . . . . . . . . . . . . . . . . . .       82        682
       Prepaid and other assets . . . . . . . . . . . . . . . . . . . . . . . .   (2,492)    (1,052)
       Accounts payable . . . . . . . . . . . . . . . . . . . . . . . . . . . .      697        396
       Funds held for future distributions. . . . . . . . . . . . . . . . . . .      132     (3,656)
       Other. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .   (1,069)   (16,358)
                                                                                 --------  ---------
       Net cash used by operating activities. . . . . . . . . . . . . . . . . .     (214)   (14,569)
                                                                                 --------  ---------
 CASH FLOWS FROM INVESTING ACTIVITIES
    Expenditures for property, plant and equipment. . . . . . . . . . . . . . .   (4,802)    (5,549)
    Proceeds from sale of assets. . . . . . . . . . . . . . . . . . . . . . . .    2,422        116
    Notes receivable and other. . . . . . . . . . . . . . . . . . . . . . . . .     (152)      (751)
                                                                                 --------  ---------
       Net cash used by investing activities. . . . . . . . . . . . . . . . . .   (2,532)    (6,184)
                                                                                 --------  ---------
 CASH FLOWS FROM FINANCING ACTIVITIES
    Proceeds from long-term debt. . . . . . . . . . . . . . . . . . . . . . . .   10,000
    Principal payment on long-term debt . . . . . . . . . . . . . . . . . . . .   (3,892)       (37)
    Purchase of treasury stock and other financing activities . . . . . . . . .     (207)      (210)
    Dividends paid. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .     (263)      (265)
                                                                                 --------  ---------
       Net cash provided (used) by financing activities . . . . . . . . . . . .    5,638       (512)
                                                                                 --------  ---------
       Net increase (decrease) in cash and cash equivalents . . . . . . . . . .    2,892    (21,265)
       Cash and cash equivalents, beginning of period . . . . . . . . . . . . .   17,775     80,336
                                                                                 --------  ---------
 Cash and cash equivalents, end of period . . . . . . . . . . . . . . . . . . .  $20,667   $ 59,071
                                                                                 ========  =========
<FN>

 The  accompanying  notes are an integral part of these condensed consolidated financial statements.
</TABLE>

                                     -6-
<PAGE>

<TABLE>
<CAPTION>

 ENERGY  CORPORATION  OF  AMERICA
 CONDENSED  CONSOLIDATED  STATEMENTS  OF  COMPREHENSIVE  INCOME
 (UNAUDITED  -  AMOUNTS  IN  THOUSANDS)
-------------------------------------------------------------------

                                                 THREE MONTHS ENDED
                                                    SEPTEMBER 30
<S>                                              <C>       <C>
                                                    2002      2001

 Net loss . . . . . . . . . . . . . . . . . . .  $(1,562)  $(1,517)
                                                 --------  --------
 Other comprehensive income (loss), net of tax:
    Foreign currency translation adjustment:
       Current period change. . . . . . . . . .     (323)     (722)
    Marketable securities:
       Current period change. . . . . . . . . .       (6)      (61)
       Reclassification to earnings . . . . . .      (16)
    Oil and Gas derivatives:
       Current period transactions. . . . . . .     (428)    1,590
       Reclassification to earnings . . . . . .       75    (1,934)
                                                 --------  --------
 Other comprehensive loss, net of tax . . . . .     (698)   (1,127)
                                                 --------  --------
 Comprehensive loss . . . . . . . . . . . . . .  $(2,260)  $(2,644)
                                                 ========  ========

<FN>

The  accompanying  notes  are  an  integral part of these condensed consolidated
financial  statements.
</TABLE>

                                     -7-

<PAGE>
                          ENERGY CORPORATION OF AMERICA
         NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
                               SEPTEMBER 30, 2002


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 energy company.
All  references  to  the "Company" include Energy Corporation of America and its
consolidated  subsidiaries.

The Company, through its wholly owned subsidiary 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,  Kentucky,  Virginia  and  Ohio.

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


2.     Accounting  Policies

Reference  is  hereby  made  to the Company's Annual Report on Form 10-K for the
fiscal  year  ended  June 30, 2002, 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 have been made.  The results of operations for the periods
ended  September  30,  2002  are not necessarily indicative of the results to be
expected  for  the  full  year.

Subsequent  to September 30, 2002, the Company has redeemed $42.5 million of its
9 1/2%  senior  subordinated  debt  in  privately  negotiated  transactions.

Certain  amounts  in  the  financial  statements  of  prior  periods  have  been
reclassified  to  conform  to  the  current  period  presentation.


3.     Earnings  per  Share

A  reconciliation  of  the  components  of basic and diluted net loss per common
share  is as follows for the loss from continuing operations available to common
shareholders:

<TABLE>
<CAPTION>
<S>                                    <C>           <C>      <C>
                                            Loss      Shares   Per Share
                                       ------------  -------  ----------
Three months ended September 30, 2002  $(1,562,000)  655,643      (2.38)
                                       ------------
Three months ended September 30, 2001   (1,517,000)  660,438      (2.30)
                                       ------------
</TABLE>

The  effect  of outstanding stock options was not included in the computation of
diluted  earnings  per  share  because  to  do  so would have been antidilutive.

                                     -8-
<PAGE>

4.     Industry  Segments

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.  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  exploration  and  impairment costs
("EBITDAX")  to  evaluate  the  operations  of  each  segment.

Summarized  financial  information  for  the  Company's  reportable segments for
continuing  operations  is  as  follows  (in  thousands):

<TABLE>
<CAPTION>
<S>                                             <C>             <C>            <C>        <C>
                                                Exploration &   Marketing &
                                                  Production      Pipeline       Other     Consolidated
                                                --------------  -------------  ---------  -------------
 For the three months ended September 30, 2002
 ---------------------------------------------
   Revenue to unaffiliated customers . . . . .  $       10,632  $     11,922   $     35   $      22,589
   Depreciation, depletion, amortization . . .           3,355           203        350           3,908
   Exploration and impairment costs. . . . . .             572                                      572
   Income (loss) from operations . . . . . . .             567           454       (344)            677
   Interest expense. . . . . . . . . . . . . .           3,752            43      1,086           4,881
   EBITDAX . . . . . . . . . . . . . . . . . .           5,003           622      1,350           6,975
   Total assets. . . . . . . . . . . . . . . .         184,781        76,284     42,330         303,395
   Capital expenditures. . . . . . . . . . . .           4,593            36        173           4,802
-------------------------------------------------------------------------------------------------------

 For the three months ended September 30, 2001
----------------------------------------------
   Revenue to unaffiliated customers . . . . .  $       12,915  $     10,479                   $ 23,394
   Depreciation, depletion, amortization . . .           3,716           228        133           4,077
   Exploration and impairment costs. . . . . .             779                                      779
   Income (loss) from operations . . . . . . .           2,304          (332)       (29)          1,943
   Interest expense. . . . . . . . . . . . . .           3,313            30      1,552           4,895
   EBITDAX . . . . . . . . . . . . . . . . . .           7,296           (98)       288           7,486
   Total assets. . . . . . . . . . . . . . . .         151,874        74,165    130,757         356,796
   Capital expenditures. . . . . . . . . . . .           5,260            44        245           5,549
</TABLE>

Income  (loss) from operations represents revenues less costs which are directly
associated  with  such  operations.  Revenues  are  priced  and  accounted  for
consistently  for  both unaffiliated and intersegment sales.  The 'Other' column
includes  corporate-related  items,  including corporate debt and non-reportable
segments.  Included  in  the  total  assets  of  the  exploration and production
segment  are  net  long-lived  assets located in New Zealand of $3.3 million and
$3.2  million  as  of  September  30,  2002  and  2001.


5.     Derivative  Instruments  and  Hedging  Activities

The  Company periodically hedges a portion of its gas production through futures
and  swap  agreements.  The  purpose  of  the  hedges is to provide a measure of
stability  in  the  volatile environment of oil and gas prices and to manage its
exposure  to  commodity price risk under existing sales commitments.  All of the
Company's price swap agreements in place are designated as cash flow hedges.  At
September  30,  2002,  the  Company had recorded a $0.07 million OCI loss, $0.03
million  long  term  derivative  asset,  $0.04 million short term derivative tax
asset  and  $0.14  million  short  term derivative liability.  The estimated net
amount  of  the  existing  losses  within  other  comprehensive  income that are
expected  to  be  reclassified  into  earnings  within  the  next  12  months is
approximately  $0.05  million.  The Company has partially hedged its exposure to
the  variability  in  future  cash  flows  through  June  2004.

                                     -9-
<PAGE>

6.     Contingencies

In  addition  to  the matters discussed in Legal Proceedings at Part II, Item 1,
the Company is involved in various other legal actions and claims arising in the
ordinary  course  of  business.  While  the  outcome of the lawsuits against the
Company  cannot  be  predicted  with certainty, management does not expect these
matters  to  have  a  material  adverse  effect  on  the Company's operations or
financial  position.


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

SAFE HARBOR STATEMENT UNDER THE PRIVATE SECURITIES LITIGATION REFORM ACT OF 1995
--------------------------------------------------------------------------------

     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,  intentions  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 under the
Private  Securities  Litigation  Reform  Act of 1995.  The Company cautions that
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, foreign currency exchange rates,
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.

     The  following  should  be read in conjunction with the Company's Financial
Statements  and  Notes  (including  the  segment information) at Part I, Item 1.

COMPARISON  OF  RESULTS  OF  OPERATIONS FOR THE THREE MONTHS ENDED SEPTEMBER 30,
--------------------------------------------------------------------------------
2002  AND  2001
---------------

     The  Company  recorded  a  net loss from operations of $1.6 million for the
quarter ended September 30, 2002 compared to a net loss of $1.5 million in 2001.
The  increase  in  net  loss  of $0.1 million is attributed to the net of a $0.8
million  decrease  in  revenue, a $0.5 million increase in operating expenses, a
$1.1  million  increase in interest income and other non-operating income, and a
$0.1  million  increase  in  minority  interest  and  income  tax  benefits.

                                     -10-
<PAGE>
     Production,  marketing  and  pipeline  volumes,  revenue  and average sales
prices  for  the  quarters ended September 30 and their related variances are as
follows:

<TABLE>
<CAPTION>

                                                                                   Variance
                                                                            --------------------
<S>                                                  <C>         <C>        <C>         <C>
                                                          2002        2001     Amount    Percent
                                                     ----------  ---------  ----------  --------
 Natural Gas
   Production (Mmcf). . . . . . . . . . . . . . . .    2,530.6     2,566.5      (35.9)     -1.4%
   Average sales price received ($per Mcf). . . . .       3.33        2.88       0.45      15.6%
                                                     ----------  ---------  ----------  --------
   Sales ($in thousands). . . . . . . . . . . . . .    8,435.8     7,391.7    1,044.1      14.1%
 Oil
   Production (Mbbl). . . . . . . . . . . . . . . .       29.6        39.3       (9.7)    -24.7%
   Average sales price received ($per Bbl). . . . .      23.47       22.86       0.61       2.7%
                                                     ----------  ---------  ----------  --------
   Sales ($in thousands). . . . . . . . . . . . . .      695.0       897.2     (202.2)    -22.5%
 Hedging. . . . . . . . . . . . . . . . . . . . . .      (62.5)    3,123.3   (3,185.8)   -102.0%
 Other. . . . . . . . . . . . . . . . . . . . . . .       96.1        97.5       (1.4)     -1.4%
                                                     ----------  ---------  ----------  --------
 Total oil and gas sales ($in thousands). . . . . .  $ 9,164.4   $11,509.7  $(2,345.3)    -20.4%
                                                     ==========  =========  ==========  ========
 Marketing Revenue
   Volume (Mdth). . . . . . . . . . . . . . . . . .    2,431.6     2,443.0      (11.4)     -0.5%
   Average sales price received ($per Dth). . . . .       3.70        3.25       0.45      13.8%
                                                     ----------  ---------  ----------  --------
   Sales ($in thousands). . . . . . . . . . . . . .    9,001.8     7,934.0    1,067.8      13.5%
 Pipeline Revenue
   Volume (Mdth). . . . . . . . . . . . . . . . . .    1,478.6     1,464.3       14.3       1.0%
   Average sales price received ($per Dth). . . . .       1.97        1.74       0.23      13.2%
                                                     ----------  ---------  ----------  --------
   ($in thousands). . . . . . . . . . . . . . . . .    2,919.9     2,545.0      374.9      14.7%
                                                                                        --------
 Total marketing and pipeline sales ($in thousands)  $11,921.7   $10,479.0  $ 1,442.7      13.8%
                                                     ==========  =========  ==========  ========
 Marketing Cost
   Volume (Mdth). . . . . . . . . . . . . . . . . .    2,431.6     2,442.5      (10.9)     -0.4%
   Average price paid ($per Dth). . . . . . . . . .       3.46        3.24       0.22       6.8%
                                                     ----------  ---------  ----------  --------
   Cost ($in thousands) . . . . . . . . . . . . . .    8,416.9     7,905.2      511.7       6.5%
 Pipeline Cost
   Volume (Mdth). . . . . . . . . . . . . . . . . .    1,183.7     1,230.7      (47.0)     -3.8%
   Average price paid ($per Dth). . . . . . . . . .       1.98        1.73       0.25      14.5%
                                                     ----------  ---------  ----------  --------
   Cost ($in thousands) . . . . . . . . . . . . . .    2,338.5     2,135.0      203.5       9.5%
                                                     ----------  ---------  ----------  --------
 Total marketing and pipeline cost ($in thousands).  $10,755.4   $10,040.2  $   715.2       7.1%
                                                     ==========  =========  ==========  ========
</TABLE>

     REVENUES.  Total  revenues  decreased  $0.8  million  or  3.4%  between the
     --------
quarters.  The  net  decrease  was  due to a 13.8% increase in gas marketing and
pipeline  sales  and a 20.4% decrease in oil and gas sales.  Well operations and
service  revenues  and  other  operating  revenue  remained relatively constant.

     Revenues  from gas marketing and pipeline sales increased $1.4 million from
$10.5 million during the period ended September 30, 2001 to $11.9 million in the
period  ended  September 30, 2002. Gas marketing revenue increased $1.1 million.
The price increase corresponds with related gas indexes. Pipeline revenue, which
has  a  sale  and  transportation  component,  increased  $0.3  million. The gas
marketing  and  pipeline  volumes  remained  relatively  constant.

                                     -11-
<PAGE>
     Revenues  from oil and gas sales decreased a net of $2.3 million from $11.5
million for the quarter ended September 30, 2001 to $9.2 million for the quarter
ended  September  30,  2002.  Natural  gas  sales increased $1.0 million and oil
sales  declined  $0.2  million.  The  net  increase  for  production  revenue is
attributed  to  the  following  variances;  gas price increase $1.1 million, gas
production  decrease $0.1 million and oil production decrease $0.2 million.  The
price  increase  corresponds  with  related  indexes.  The  increased production
revenue  was  offset by recognized losses on related hedging transactions, which
totaled a loss of $0.1 million for the quarter ended September 30, 2002 compared
to a gain of $3.1 million for the quarter ended September 30, 2001.  The average
price  per  Mcfe,  after  hedging,  was  $3.38  and $4.11 for the quarters ended
September  30,  2002  and  2001.

     COSTS AND EXPENSES. The Company's costs and expenses increased $0.5 million
     -------------------
or 2.2% between the  periods primarily as a net result of a 7.1% increase in gas
marketing  and  pipeline  costs,  a 21.1% increase in taxes other than income, a
4.1%  decrease  in depreciation, depletion and amortization expenses and a 26.6%
decrease  in  exploration  and  impairment  costs.  Field  and  lease  operating
expenses  and  general and administrative expenses remained relatively constant.

     Gas marketing and pipeline costs increased $0.7 million. Gas marketing cost
increased  $0.5  million.  The  price increase corresponds with related indexes.
Pipeline  costs  increased  $0.2  million.

     Taxes other than income increased $0.1 million due to increased oil and gas
prices.  Production  taxes  are based on wellhead prices and are not affected by
hedging  activity.

     Depreciation,  depletion  and amortization expenses decreased $0.2 million.
The  decrease  is  primarily  related to decreased production volumes, no longer
depleting  a fully depleted well and reduced property costs in Texas due to year
end  impairment.

     Exploration and impairment expenses decreased $0.2 million. The decrease is
primarily  due  to  reduced seismic and delay rental payments during the current
quarter.

     OTHER  NON-OPERATING  INCOME.  Other  non-operating  income  increased $1.1
     ----------------------------
million  when  comparing  the periods. This is primarily the result of a gain of
$1.8  million  recognized  on  the  early  retirement  of  the  Company's Senior
Subordinated  Notes. The gain was partially offset by losses related to the sale
of  property of approximately $0.2 million and $0.5 million less interest income
due  to  decreased  cash  balances.


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

     The  Company's  financial condition has continued to decline since June 30,
2002.  Stockholders' equity has decreased from $37.1 million at June 30, 2002 to
$34.4  million  at  September  30,  2002.  The Company's working capital of $1.8
million  at  June  30, 2002 remained at $1.7 million at September 30, 2002.  The
Company's cash increased from $17.8 million at June 30, 2002 to $20.7 million at
September  30,  2002.  The Company's cash at November 12, 2002 was $2.4 million.
The  change  in  cash  during the quarter of approximately $2.9 million resulted
from  various  financing,  operating  and  capital expenditure activities of the
Company.  The  activities  were  primarily  comprised  of:  the  borrowing  of
approximately  $10.0  million  under  the Company's $50 million revolving Credit
Agreement  (the  "Agreement"); proceeds from the sale of assets of approximately
$2.4  million;  the  net  investment  of approximately $4.8 million in property,
plant  and equipment; payments of approximately $3.9 million for the purchase of
certain  of  the  Company's  outstanding  Notes;  payments of approximately $0.5
million  for  the  acquisition  of  treasury stock and dividends; and the use of
approximately  $0.2  million  of  cash  by  operations  during  the  quarter.

                                     -12-
<PAGE>
     On  June  21,  2002  Moody's  Investors  Service ("Moody's") downgraded the
Company's debt rating.  With a negative outlook, Moody's downgraded to Caa3 from
Caa1  the  Company's 9.5% Senior Subordinated Notes ("Notes") due 2007.  Moody's
stated  that;  "Further ratings actions are possible upon review of ECA's fiscal
year-end  June 30, 2002 reserve replacements after a year of heavy reinvestment,
funded with cash-on-hand, and depending on whether ECA incurs additional secured
debt  to  fund its drilling program."  Moody's also stated that; "The downgrades
reflect insufficient cash flow to cover interest expense and reserve replacement
capital  expenditures;  asset coverage that is below the par value of the bonds;
and declining production in spite of heavy FYE 2001 and FYE 2002 reinvestment in
reserve  acquisitions  and  development  and  exploration drilling."  This could
negatively  impact  the  Company's  ability  to  raise  capital in the future or
increase  the  cost  of  such  capital.  The  Company's  total  proved  reserves
decreased  by  9.5%  in  the  fiscal year ended June 30, 2002.  At July 1, 2002,
total  proved  reserves  were 201,051 Mmcfe compared to total proved reserves at
July  1,  2001  of  222,254  Mmcfe.

     At  September  30,  2002,  the  Company's  principal  source  of  liquidity
consisted  of  $20.7 million of cash, plus amounts available under the Agreement
and $2 million available under an unsecured short-term credit facility currently
in place. At September 30, 2002, $10 million was outstanding under the Agreement
and  no  amounts  were  outstanding  or  committed  under  the short-term credit
facility.

     On  July  10,  2002,  the  Company entered into the Agreement with Foothill
Capital  Corporation ("Foothill"). Depending on its level of borrowing under the
Agreement,  the  applicable interest rates are based on Wells Fargo's prime rate
plus  0.50%  to  2.50%. The Agreement expires on July 10, 2005. The Agreement is
secured by approximately 80% of the existing proved producing oil and gas assets
of  the Company. The Agreement, among other things, restricts the ability of the
Company  and  its  subsidiaries  to  incur  new  debt, grant additional security
interests  in  its  collateral,  engage  in  certain  merger  or  reorganization
activities,  or  dispose  of  certain assets. Upon the occurrence of an event of
default,  the  lenders  may  terminate the Agreement and declare all obligations
thereunder immediately due and payable. As of November 12, 2002, there are $24.6
million  in  outstanding borrowings under the Agreement. Under the Indenture for
the Company's Notes, the Company is restricted from incurring additional debt in
excess  of  the  $50  million available under the Agreement unless the Company's
fixed  charge coverage ratio, as defined in the Indenture, is at least 2.5 to 1.
Currently,  the  Company's  fixed  charge  coverage ratio is less than 2.5 to 1.

     The  Company's net cash requirements will fluctuate based on timing and the
extent  of  the  interplay of capital expenditures, cash generated by continuing
operations,  cash  generated  by  the  sale  of  assets  and  interest  expense.
Management anticipates that EBITDAX, before inclusion of anticipated gain on the
sale  of  assets  and  anticipated gain on the early retirement of the Company's
Notes,  for fiscal year 2003 will approximate $33 million; however, such results
will not be sufficient to fully fund fiscal year 2003 projected interest charges
of  over $18 million and fund the Company's anticipated fiscal year 2003 capital
expenditures  program  of  $39  million.  The  Company's  ability to achieve the
projected  results for fiscal year 2003 is highly dependant on product price and
drilling success. The Company's price assumption is approximately $4 per Mcf for
the  sale  of  natural  gas  and  the Company's assumption for gas production is
approximately  12.8  Bcf,  which  is  an  increase  of  20%  over  production of
approximately 10.6 Bcf in fiscal year 2002. There can be no assurance given that
the  Company will be able to achieve these goals. EBITDAX for fiscal years 2002,
2001  and  2000 was $19.7 million, $33.7 million and $4.1 million, respectively.
Although  cash  provided  from  oil and gas operations will not be sufficient to
fully  fund  the  Company's fiscal year 2003 projected interest charges, capital
expenditures  program,  and  other uses, management believes that cash generated
from  continuing oil and gas operations, together with the liquidity provided by
existing  cash  balances  and working capital, permitted borrowings and the cash
proceeds  resulting  from  the  sale  of certain operating assets as well as the
divestment of certain non-core assets, will be sufficient to satisfy commitments
for  capital  expenditures,  debt service obligations, working capital needs and
other  cash  requirements  for  the  next  year.

                                     -13-
<PAGE>

     In order to reduce future cash interest payments, as well as future amounts
due at maturity or upon redemption, the Company may, from time to time, purchase
its  outstanding  debt  securities  in  open  market  purchases and/or privately
negotiated  transactions.  The  Company  will  evaluate any such transactions in
light  of  then  existing  market conditions, taking into account its liquidity,
uses  of  capital  and  prospects  for  future  access  to capital.  The amounts
involved  in  any  such  transaction,  individually  or in the aggregate, may be
material.  Since  September  30,  2002,  the  Company  has continued to purchase
certain of its outstanding debt securities in privately negotiated transactions.

     The  Company  believes that its existing capital resources and its expected
fiscal  year 2003 results of operations and cash flows from operating activities
will be sufficient for the Company to remain in compliance with the requirements
of  its  Notes.  However,  since  future  results  of operations, cash flow from
operating  activities,  debt  service  capability,  levels  and  availability of
capital  resources  and  continuing  liquidity  are  dependent on future weather
patterns,  oil  and  gas  commodity  prices and production volume levels, future
exploration  and  development  drilling  success  and  successful  acquisition
transactions,  no  assurance  can  be  given  that  the  Company  will remain in
compliance  with  the  requirements  of  its  Notes.  See  Part II Item 1 "Legal
Proceedings"  for  a  discussion  related  to the Company's receipt of Notice of
Default  from  certain  holders  of  the  Notes.


              ITEM 3.      QUANTITATIVE AND QUALITATIVE DISCLOSURES
              -----------------------------------------------------
                                ABOUT MARKET RISK
                                -----------------

COMMODITY  RISK
---------------

     The  Company's  operations  consist  primarily of exploring for, producing,
aggregating  and  selling  natural  gas  and  oil.  Contracts  to deliver gas at
pre-established prices mitigate the risk to the Company of falling prices but at
the  same time limit the Company's ability to benefit from the effects of rising
prices.  The  Company  occasionally  uses  derivative  instruments  to hedge its
commodity  price risk. The Company hedges a portion of its projected natural gas
production  through a variety of financial and physical arrangements intended to
support  natural  gas  prices  at  targeted levels and to manage its exposure to
price  fluctuations.  The  Company may use futures contracts, swaps, options and
fixed price physical contracts to hedge its commodity prices. Realized gains and
losses from the Company's price risk management activities are recognized in oil
and  gas  sales  when  the  associated production occurs. Unrecognized gains and
losses  are  included  as a component of other comprehensive income. The Company
does  not hold or issue derivative instruments for trading purposes. The Company
has  elected  to  enter into hedge transactions, covering approximately 21.7% of
its  natural  gas  production  through  June  2004.

     Notwithstanding the above, the Company's future cash flows from gas and oil
production  are  exposed  to  significant volatility as commodity prices change.
Assuming  total  oil  and  gas  production  and the percentage of gas production
hedged  under physical delivery contracts remain at September 2002 levels, a 10%
change  in the average unhedged prices realized during the year would change the
Company's  gas and  oil  revenues  by approximately $0.75 million on a quarterly
basis.

INTEREST  RATE  RISK
--------------------

     Interest  rate  risk  is  attributable  to the Company's debt.  The Company
utilizes United States dollar denominated borrowings to fund working capital and
investment  needs.  As  of  September  30,  2002,  all  but  $10  million of the
Company's  debt  has  fixed interest rates.  There is inherent rollover risk for
borrowings  as  they mature and are renewed at current market rates.  The extent
of  this  risk  is not predictable because of the variability of future interest
rates  and the Company's future financing needs.  Assuming the variable interest
debt  remained at the September 30, 2002 level, a 10% change in rates would have
a  negligible  affect  on interest expense for the quarter.  The Company has not
attempted  to  hedge  the  interest  rate  risk  associated  with  its  debt.

                                     -14-
<PAGE>

FOREIGN  CURRENCY  EXCHANGE  RISK
---------------------------------

Some  of the Company's transactions are denominated in New Zealand dollars.  For
foreign  operations  with  the local currency as the functional currency, assets
and  liabilities are translated at the period end exchange rates, and statements
of income are translated at the average exchange rates during the period.  Gains
and  losses  resulting  from  foreign  currency  translation  are  included as a
component  of  other  comprehensive  income.


                         ITEM 4. CONTROLS AND PROCEDURES
                         -------------------------------

     Under  the  supervision  and  with  the  participation  of  our management,
including  our  principal executive officer and principal financial officer, the
Company  has  evaluated  the  effectiveness  of  the design and operation of our
disclosure  controls  and  procedures  within 90 days of the filing date of this
quarterly report and, based on their evaluation, our principal executive officer
and  principal  financial  officer  have  concluded  that  these  controls  and
procedures  are  effective.  There  were  no significant changes in our internal
controls  or  in  other  factors  that could significantly affect these controls
subsequent  to the date of their evaluation.  Disclosure controls and procedures
are  our  controls  and  other  procedures  that  are  designed  to  ensure that
information required to be disclosed by us in the reports that we file or submit
under  the  Securities Exchange Act of 1934, as amended, is recorded, processed,
summarized and reported, within the time periods specified in the Securities and
Exchange  Commission's  rules  and  forms.  Disclosure  controls  and procedures
include,  without  limitation,  controls  and procedures designed to ensure that
information required to be disclosed by us in the reports that we file under the
Securities  Exchange  Act  is  accumulated  and  communicated to our management,
including  our  principal  executive officer and principal financial officer, as
appropriate  to  allow  timely  decisions  regarding  required  disclosure.


PART  II.  OTHER  INFORMATION

ITEM  1.  LEGAL  PROCEEDINGS

     As  previously disclosed, in June 2001, the Company filed a lawsuit against
Oracle  Corporation  for  breach  of contract, breach of warranty and rescission
with  respect  to  a  software  package  purchased  from  Oracle  and the failed
implementation  thereof. Oracle answered the complaint substantially denying all
of  the  Company's  allegations  and  filed  a  counterclaim against the Company
alleging  that  it  is  owed  approximately  $1.2 million for prior services. In
November  2001,  the Company amended its Complaint against Oracle to add a count
for  fraud.  Extensive  discovery has been conducted by the parties. The Company
intends  to  aggressively  prosecute  its  case against Oracle as well as defend
against  the counterclaim of Oracle. This case is scheduled for trial in January
2003.

     As  previously  disclosed,  on  December  27,  2001, the Company received a
Notice  of  Default  from  certain  holders  of  its  $200 million 9-1/2% Senior
Subordinate Notes due 2007 (the "Notes") alleging a default under Section 4.9 of
the  Indenture  pursuant  to  which  the  Notes were issued. The alleged default
related to the proper calculation of Net Proceeds of an Asset Sale, particularly
with  respect  to  the  deduction  for taxes paid or payable as a result of such
sale.  On  December 28, 2001, the Company filed a declaratory judgment action in
the  United  States  District  Court  for the Southern District of West Virginia

                                     -15-
<PAGE>

(the  "Court") against the holders of the Notes who issued the Notice of Default
(the  "Noteholders"),  asking the Court to confirm the proper calculation of Net
Proceeds  of  an  Asset Sale under the Indenture. On January 25, 2002, the Court
entered  an  order  denying  the Noteholders' Motion to Dismiss and granting the
Company's  Motion  for  Partial  Summary  Judgment,  which  order  approved  the
Company's methodology in calculating taxes paid or payable in connection with an
Asset  Sale.  On  February  28,  2002,  the  Noteholders  filed  an  answer  and
counterclaim  in  the declaratory judgment action. The counterclaim alleges that
the  Company's  sale  of  Mountaineer  in  August  of 2000 constituted a sale of
substantially  all  assets  of  the  Company,  as  opposed to an Asset Sale, and
invoked  certain  obligations  under the Indenture to repurchase the outstanding
Notes.  On  March  25,  2002,  the  Company  filed its Second Motion for Partial
Summary  Judgment, asserting that the Noteholders were barred from asserting the
counterclaim. On June 3, 2002, the United States District Court for the Southern
District  of West Virginia entered an order granting the Company's Second Motion
for  Partial  Summary  Judgment, which order dismissed the Noteholders' claim on
the  basis  of  judicial admissions and equitable estoppel. On May 22, 2002, the
Noteholders  filed a "Motion for Reconsideration of the Court's January 25, 2002
Order  and  Permission  to  Take  Limited  Discovery  in Order to Supplement the
Record".  The  Court  entered  an  Order  dated  July  19,  2002,  denying  the
Noteholders' Motion for Reconsideration. On July 27, 2002, the Noteholders filed
a Notice of Appeal in the United States Court of Appeals for the Fourth Circuit.
The  Noteholders  subsequently  filed  a  motion  to dismiss the appeal with the
Fourth  Circuit.  This motion was granted and the matter is still pending before
the  District  Court.

     The  Company  is involved in various other legal actions and claims arising
in  the  ordinary  course of business. While the outcome of these other lawsuits
against  the  Company  cannot  be  predicted with certainty, management does not
expect  these  matters  to  have  a  material  adverse  effect  on the Company's
operations  or  financial  position.

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)     None

          b)     None

                                     -16-
<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  14th  day  of  November  2002.



                                        ENERGY  CORPORATION  OF  AMERICA




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




                                        By:     /s/Michael  S.  Fletcher
                                           -----------------------------------
                                        Michael  S.  Fletcher
                                        Chief  Financial  Officer

                                     -17-
<PAGE>



CERTIFICATION  PURSUANT  TO  SECTION  302  UNDER  THE  SECURITIES  ACT  OF  1934
FORM  OF  302  CERTIFICATION  (10-Q)


I,  John  Mork,  certify  that:

1.     I  have reviewed this quarterly report on Form 10-Q of Energy Corporation
of  America;

2.     Based  on my knowledge, this quarterly report does not contain any untrue
statement  of a material fact or omit to state a material fact necessary to make
the  statements  made, in light of the circumstances under which such statements
were  made,  not misleading with respect to the period covered by this quarterly
report;

3.     Based  on  my  knowledge,  the  financial statements, and other financial
information  included  in  this quarterly report, fairly present in all material
respects  the  financial  condition, results of operations and cash flows of the
registrant  as  of,  and  for,  the  periods presented in this quarterly report;

4.     The  registrant's  other  certifying  officer  and  I are responsible for
establishing  and  maintaining disclosure controls and procedures (as defined in
Exchange  Act  Rules  13a-14  and  15d-14)  for  the  registrant  and  we  have:

     a. designed such disclosure controls and procedures to ensure that material
information relating to the registrant, including its consolidated subsidiaries,
is  made  known  to  us by others within those entities, particularly during the
period  in  which  this  quarterly  report  is  being  prepared;

     b.  evaluated the effectiveness of the registrant's disclosure controls and
procedures  as  of  a  date  within  90  days  prior  to the filing date of this
quarterly  report  (the  "Evaluation  Date");  and

     c.  presented  in  this  quarterly  report  our  conclusions  about  the
effectiveness  of the disclosure controls and procedures based on our evaluation
as  of  the  Evaluation  Date;

5.     The  registrant's other certifying officer and I have disclosed, based on
our most recent evaluation, to the registrant's auditors and the audit committee
of  registrant's  board  of  directors  (or  persons  performing  the equivalent
function):

     a.  all  significant  deficiencies  in  the design or operation of internal
controls  which  could  adversely  affect  the  registrant's  ability to record,
process,  summarize  and  report  financial  data  and  have  identified for the
registrant's  auditors  any  material  weaknesses  in  internal  controls;  and

     b.  any  fraud,  whether or not material, that involves management or other
employees who have a significant role in the registrant's internal controls; and

6.     The  registrant's  other  certifying officer and I have indicated in this
quarterly  report  whether  or  not  there  were significant changes in internal
controls  or  in other factors that could significantly affect internal controls
subsequent  to  the date of our most recent evaluation, including any corrective
actions  with  regard  to  significant  deficiencies  and  material  weaknesses.


Dated:  November 14, 2002                      /s/ John Mork
                                          -----------------------------------
                                           John  Mork
                                           Chief  Executive  Officer

<PAGE>

CERTIFICATION  PURSUANT  TO  SECTION  302  UNDER  THE  SECURITIES  ACT  OF  1934
FORM  OF  302  CERTIFICATION  (10-Q)


I,  Michael  S.  Fletcher,  certify  that:

1.     I  have reviewed this quarterly report on Form 10-Q of Energy Corporation
of  America;

2.     Based  on my knowledge, this quarterly report does not contain any untrue
statement  of a material fact or omit to state a material fact necessary to make
the  statements  made, in light of the circumstances under which such statements
were  made,  not misleading with respect to the period covered by this quarterly
report;

3.     Based  on  my  knowledge,  the  financial statements, and other financial
information  included  in  this quarterly report, fairly present in all material
respects  the  financial  condition, results of operations and cash flows of the
registrant  as  of,  and  for,  the  periods presented in this quarterly report;

4.     The  registrant's  other  certifying  officer  and  I are responsible for
establishing  and  maintaining disclosure controls and procedures (as defined in
Exchange  Act  Rules  13a-14  and  15d-14)  for  the  registrant  and  we  have:

     a. designed such disclosure controls and procedures to ensure that material
information relating to the registrant, including its consolidated subsidiaries,
is  made  known  to  us by others within those entities, particularly during the
period  in  which  this  quarterly  report  is  being  prepared;

     b.  evaluated the effectiveness of the registrant's disclosure controls and
procedures  as  of  a  date  within  90  days  prior  to the filing date of this
quarterly  report  (the  "Evaluation  Date");  and

     c.  presented  in  this  quarterly  report  our  conclusions  about  the
effectiveness  of the disclosure controls and procedures based on our evaluation
as  of  the  Evaluation  Date;

5.     The  registrant's other certifying officer and I have disclosed, based on
our most recent evaluation, to the registrant's auditors and the audit committee
of  registrant's  board  of  directors  (or  persons  performing  the equivalent
function):

     a.  all  significant  deficiencies  in  the design or operation of internal
controls  which  could  adversely  affect  the  registrant's  ability to record,
process,  summarize  and  report  financial  data  and  have  identified for the
registrant's  auditors  any  material  weaknesses  in  internal  controls;  and

     b.  any  fraud,  whether or not material, that involves management or other
employees who have a significant role in the registrant's internal controls; and

6.     The  registrant's  other  certifying officer and I have indicated in this
quarterly  report  whether  or  not  there  were significant changes in internal
controls  or  in other factors that could significantly affect internal controls
subsequent  to  the date of our most recent evaluation, including any corrective
actions  with  regard  to  significant  deficiencies  and  material  weaknesses.


Dated:  November 14, 2002                      /s/ Michael S. Fletcher
                                          -----------------------------------
                                                Michael  S.  Fletcher
                                                Chief  Financial  Officer

<PAGE>

CERTIFICATION  PURSUANT  TO  SECTION  906  OF  THE  SARBANES-OXLEY  ACT  OF 2002
(SUBSECTIONS  (A) AND (B) OF SECTION 1350, CHAPTER 63 OF TITLE 18, UNITED STATES
CODE)

Pursuant  to  section 906 of the Sarbanes-Oxley Act of 2002 (subsections (a) and
(b)  of  section  1350,  chapter  63  of  title  18,  United  States  Code), the
undersigned  officer  of  Energy  Corporation  of  America,  a  West  Virginia
corporation  (the  "Company"),  hereby  certifies,  to such officer's knowledge,
that:

The  Quarterly Report on Form 10-Q for the quarter ended September 30, 2002 (the
"Report")  of  the Company fully complies with the requirements of section 13(a)
or 15(d) of the Securities Exchange Act of 1934 and information contained in the
Report  fairly  presents,  in all material respects, the financial condition and
results  of  operations  of  the  Company.


Dated: November 14, 2002                       /s/ John Mork
                                          -----------------------------------
                                                John  Mork
                                                Chief  Executive  Officer


The foregoing certification is being furnished solely pursuant to section 906 of
the Sarbanes-Oxley Act of 2002 (subsections (a) and (b) of section 1350, chapter
63 of title 18, United States Code) and is not being filed as part of the Report
or  as  a  separate  disclosure  document.

<PAGE>
CERTIFICATION  PURSUANT  TO  SECTION  906  OF  THE  SARBANES-OXLEY  ACT  OF 2002
(SUBSECTIONS  (A) AND (B) OF SECTION 1350, CHAPTER 63 OF TITLE 18, UNITED STATES
CODE)

Pursuant  to  section 906 of the Sarbanes-Oxley Act of 2002 (subsections (a) and
(b)  of  section  1350,  chapter  63  of  title  18,  United  States  Code), the
undersigned  officer  of  Energy  Corporation  of  America,  a  West  Virginia
corporation  (the  "Company"),  hereby  certifies,  to such officer's knowledge,
that:

The  Quarterly Report on Form 10-Q for the quarter ended September 30, 2002 (the
"Report")  of  the Company fully complies with the requirements of section 13(a)
or 15(d) of the Securities Exchange Act of 1934 and information contained in the
Report  fairly  presents,  in all material respects, the financial condition and
results  of  operations  of  the  Company.


Dated:  November 14, 2002                       /s/ Michael S. Fletcher
                                          -----------------------------------
                                                Michael  S.  Fletcher
                                                Chief  Financial  Officer

The foregoing certification is being furnished solely pursuant to section 906 of
the Sarbanes-Oxley Act of 2002 (subsections (a) and (b) of section 1350, chapter
63 of title 18, United States Code) and is not being filed as part of the Report
or  as  a  separate  disclosure  document.

<PAGE>