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 DECEMBER 31, 2001.

                                       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
December  31,  2001  was  630,118  shares.

<PAGE>
<TABLE>
<CAPTION>

                          ENERGY CORPORATION OF AMERICA

                                TABLE OF CONTENTS

                                                                         PAGES
PART  I  FINANCIAL  INFORMATION

<S>                                                                       <C>
Item 1. Financial Statements

Condensed Consolidated Balance Sheets
   December 31, 2001 (unaudited) and June 30, 2001 . . . . . . . . . . .   3

Unaudited Condensed Consolidated Statements of Operations
   For the three and six months ended December 31, 2001 and 2000 . . . .   5

Unaudited Condensed Consolidated Statements of Cash Flows
   For the six months ended December 31, 2001 and 2000 . . . . . . . . .   6

Unaudited Condensed Consolidated Statements of Comprehensive Income
   For the three and six months ended December 31, 2001 and 2000 . . . .   7

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

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

Financial Condition. . . . . . . . . . . . . . . . . . . . . . . . . . .  12

Item 3. Quantitative and Qualitative Disclosures About Market Risk . . .  17


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. . . . . . .  19

Item 5. Other Information. . . . . . . . . . . . . . . . . . . . . . . .  19

Item 6. Exhibits and Reports on Form 8-K . . . . . . . . . . . . . . . .  19

Signatures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .  20
</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>
                                                                 DECEMBER 31   JUNE 30
                                                                     2001        2001
                                                                 (UNAUDITED)      *
 ASSETS

 CURRENT ASSETS
    Cash and cash equivalents . . . . . . . . . . . . . . . . .  $     42,032  $ 80,336
    Accounts receivable, net of allowance for doubtful
       accounts of $442 and $457. . . . . . . . . . . . . . . .        19,209    23,388
    Gas in storage, at average cost . . . . . . . . . . . . . .           271     1,069
    Deferred income tax asset . . . . . . . . . . . . . . . . .         7,467     7,467
    Prepaid and other current assets. . . . . . . . . . . . . .         4,249     6,369
                                                                 ------------  --------
       Total current assets . . . . . . . . . . . . . . . . . .        73,228   118,629
                                                                 ------------  --------

 Property, plant and equipment, net of accumulated
    depreciation and depletion of $109,388 and $102,223 . . . .       255,815   248,659
                                                                 ------------  --------

 OTHER ASSETS
    Deferred financing costs, net of accumulated
       amortization of $3,355 and $2,987. . . . . . . . . . . .         3,985     4,353
    Notes receivable. . . . . . . . . . . . . . . . . . . . . .         1,845     1,867
    Other . . . . . . . . . . . . . . . . . . . . . . . . . . .         7,018     7,024
                                                                 ------------  --------
       Total other assets . . . . . . . . . . . . . . . . . . .        12,848    13,244
                                                                 ------------  --------

 TOTAL. . . . . . . . . . . . . . . . . . . . . . . . . . . . .  $    341,891  $380,532
                                                                 ============  ========

 *   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>
                                                                 DECEMBER 31     JUNE 30
                                                                    2001          2001
                                                                 (UNAUDITED)       *
 LIABILITIES AND STOCKHOLDERS' EQUITY

 CURRENT LIABILITIES
    Accounts payable. . . . . . . . . . . . . . . . . . . . . .  $     13,705   $ 18,979
    Current portion of long-term debt . . . . . . . . . . . . .           153        151
    Funds held for future distribution. . . . . . . . . . . . .         9,184     14,666
    Other taxes payable . . . . . . . . . . . . . . . . . . . .         7,460      7,860
    Other current liabilities . . . . . . . . . . . . . . . . .         6,552     23,932
                                                                 -------------  ---------
       Total current liabilities. . . . . . . . . . . . . . . .        37,054     65,588

 LONG-TERM OBLIGATIONS
    Long-term debt. . . . . . . . . . . . . . . . . . . . . . .       198,826    198,902
    Gas delivery obligation and deferred revenue. . . . . . . .         9,115     11,321
    Deferred income tax liability . . . . . . . . . . . . . . .        29,888     29,888
    Other long-term obligation. . . . . . . . . . . . . . . . .         9,314     10,007
                                                                 -------------  ---------
       Total liabilities. . . . . . . . . . . . . . . . . . . .       284,197    315,706
                                                                 -------------  ---------


 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;
       39,469 and 36,067 shares issued. . . . . . . . . . . . .         4,218      3,732
    Additional paid in capital. . . . . . . . . . . . . . . . .         5,503      5,503
    Retained earnings . . . . . . . . . . . . . . . . . . . . .        59,523     63,653
    Treasury stock and notes receivable arising from the
       issuance of common stock . . . . . . . . . . . . . . . .        (9,985)    (9,293)
    Accumulated comprehensive income (loss) . . . . . . . . . .        (2,295)       501
                                                                 -------------  ---------
       Total stockholders' equity . . . . . . . . . . . . . . .        57,694     64,826
                                                                 -------------  ---------

 TOTAL. . . . . . . . . . . . . . . . . . . . . . . . . . . . .  $    341,891   $380,532
                                                                 =============  =========

 *   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)
--------------------------------------------------------------------------------------------------

                                                              FOR THE THREE        FOR THE SIX
                                                               MONTHS ENDED         MONTHS ENDED
                                                               DECEMBER 31          DECEMBER 31
<S>                                                         <C>       <C>       <C>       <C>
                                                               2001      2000      2001      2000
 REVENUES:
    Gas marketing and pipeline sales . . . . . . . . . . .  $10,051   $21,581   $20,530   $39,188
    Oil and gas sales. . . . . . . . . . . . . . . . . . .    9,788     8,488    21,298    16,207
    Well operations and service revenues . . . . . . . . .    1,318     1,282     2,723     2,664
    Other revenue. . . . . . . . . . . . . . . . . . . . .                547                 921
                                                            --------  --------  --------  --------
                                                             21,157    31,898    44,551    58,980
                                                            --------  --------  --------  --------
 COST AND EXPENSES:
    Gas marketing and pipeline cost. . . . . . . . . . . .    9,107    20,185    19,148    37,071
    Field operating expenses . . . . . . . . . . . . . . .    2,616     1,963     5,124     3,966
    General and administrative . . . . . . . . . . . . . .    3,503     3,131     7,027     5,659
    Taxes, other than income . . . . . . . . . . . . . . .      380       821       902     1,428
    Depletion and depreciation, oil and gas related. . . .    3,148     1,965     6,479     4,037
    Depreciation of pipelines and equipment. . . . . . . .      673       685     1,419     1,346
    Exploration and impairment . . . . . . . . . . . . . .      611     1,785     1,389     2,637
                                                            --------  --------  --------  --------
                                                             20,038    30,535    41,488    56,144
                                                            --------  --------  --------  --------
    Income from operations . . . . . . . . . . . . . . . .    1,119     1,363     3,063     2,836
 OTHER (INCOME) EXPENSE
    Interest expense . . . . . . . . . . . . . . . . . . .    4,940     4,951     9,927    10,324
    Interest income and other. . . . . . . . . . . . . . .     (658)   (3,405)   (1,437)   (4,402)
                                                            --------  --------  --------  --------
 Loss from continuing operations before income taxes . . .   (3,163)     (183)   (5,427)   (3,086)
 Income tax expense (benefit). . . . . . . . . . . . . . .   (1,077)       67    (1,824)     (988)
                                                            --------  --------  --------  --------
 Loss from continuing operations . . . . . . . . . . . . .   (2,086)     (250)   (3,603)   (2,098)
                                                            --------  --------  --------  --------
 Disposal of utility operations:
    Loss from utility operations, net of income tax. . . .             (1,067)             (1,949)
    Gain on sale of utility operations, net of income tax.                                 85,390
                                                            --------  --------  --------  --------
    Net income from disposal of utility operations . . . .        -    (1,067)        -    83,441
 Extraordinary gain on extinguishment of debt, net of tax.        -       378         -       378
                                                            --------  --------  --------  --------
 NET INCOME (LOSS) . . . . . . . . . . . . . . . . . . . .  $(2,086)  $  (939)  $(3,603)  $81,721
                                                            ========  ========  ========  ========

 Basic and diluted earnings per common share:
    Loss from continuing operations. . . . . . . . . . . .  $ (3.16)  $ (0.38)  $ (5.46)  $ (3.15)
    Income from disposed utility operations. . . . . . . .              (1.60)             125.26
    Extraordinary gain on extinguishment of debt . . . . .               0.57                0.57
                                                            --------  --------  --------  --------
    Net income (loss). . . . . . . . . . . . . . . . . . .  $ (3.16)  $ (1.41)  $ (5.46)  $122.68
                                                            ========  ========  ========  ========
<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)
-----------------------------------------------------------------------------------------------------

                                                                                   FOR THE SIX MONTHS
                                                                                    ENDED DECEMBER 31
<S>                                                                              <C>        <C>
                                                                                     2001       2000
 CASH FLOWS FROM OPERATING ACTIVITIES
    Net loss from continuing operations . . . . . . . . . . . . . . . . . . . .  $ (3,603)  $ (2,098)
    Adjustments to reconcile net loss to net cash used by operating activities:
       Depletion, depreciation and amortization . . . . . . . . . . . . . . . .     8,266      5,873
       Impairment expense . . . . . . . . . . . . . . . . . . . . . . . . . . .     1,003      2,394
       Other, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .      (884)      (461)
                                                                                 ---------  ---------
                                                                                    4,782      5,708
    Changes in assets and liabilities:
       Accounts receivable. . . . . . . . . . . . . . . . . . . . . . . . . . .     4,194     (5,703)
       Gas in storage . . . . . . . . . . . . . . . . . . . . . . . . . . . . .       702       (114)
       Prepaid and other assets . . . . . . . . . . . . . . . . . . . . . . . .      (786)      (825)
       Accounts payable . . . . . . . . . . . . . . . . . . . . . . . . . . . .    (5,669)       418
       Income taxes payable . . . . . . . . . . . . . . . . . . . . . . . . . .    (1,822)    (4,668)
       Funds held for future distributions. . . . . . . . . . . . . . . . . . .    (5,482)     1,425
       Other. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .   (17,134)    (2,526)
                                                                                 ---------  ---------
       Net cash used by operating activities from continuing operations . . . .   (21,215)    (6,285)
       Net cash used by operating activities from disposed operations . .            . . .   (25,751)
                                                                                 ---------  ---------
       Net cash used by operating activities. . . . . . . . . . . . . . . . . .   (21,215)   (32,036)
                                                                                 ---------  ---------
 CASH FLOWS FROM INVESTING ACTIVITIES
    Expenditures for property, plant and equipment. . . . . . . . . . . . . . .   (15,961)   (71,694)
    Proceeds from sale of assets. . . . . . . . . . . . . . . . . . . . . . . .       307        680
    Notes receivable and other. . . . . . . . . . . . . . . . . . . . . . . . .      (150)    (4,351)
                                                                                 ---------  ---------
       Net cash used by investing activities from continuing operations . . . .   (15,804)   (75,365)
       Net cash provided by investing activities from disposed operations . . .              224,765
                                                                                 ---------  ---------
       Net cash provided (used) by investing activities . . . . . . . . . . . .   (15,804)   149,400
                                                                                 ---------  ---------
 CASH FLOWS FROM FINANCING ACTIVITIES
    Proceeds from long-term debt. . . . . . . . . . . . . . . . . . . . . . . .                7,825
    Principal payment on long-term debt . . . . . . . . . . . . . . . . . . . .       (75)   (21,776)
    Principal payment on short-term borrowing . . . . . . . . . . . . . . . . .               (2,000)
    Purchase of treasury stock and other financing activities . . . . . . . . .      (682)       (86)
    Dividends paid. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .      (528)    (3,340)
                                                                                 ---------  ---------
       Net cash used by financing activities from continuing operations . . . .    (1,285)   (19,377)
       Net cash provided by financing activities from disposed operations . . .                6,539
                                                                                 ---------  ---------
       Net cash used by financing activities. . . . . . . . . . . . . . . . . .    (1,285)   (12,838)
                                                                                 ---------  ---------
       Net increase (decrease) in cash and cash equivalents . . . . . . . . . .   (38,304)   104,526
       Cash and cash equivalents, beginning of period . . . . . . . . . . . . .    80,336      3,310
                                                                                 ---------  ---------
 Cash and cash equivalents, end of period . . . . . . . . . . . . . . . . . . .  $ 42,032   $107,836
                                                                                 =========  =========
<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    SIX MONTHS ENDED
                                                     DECEMBER 31          DECEMBER 31
                                                      2001     2000       2001     2000
<S>                                               <C>       <C>       <C>       <C>
 Net income (loss) . . . . . . . . . . . . . . .  $(2,086)  $  (939)  $(3,603)  $81,721
                                                  --------  --------  --------  --------
 Other comprehensive income (loss), net of tax:
    Foreign currency translation adjustment:
       Current period change . . . . . . . . . .     (219)    1,135      (941)    1,579
    Marketable securities:
       Current period change . . . . . . . . . .       59         3        (2)       91
    Oil and Gas derivatives:
       Net cumulative effect adjustment. . . . .                                 (2,153)
       Current period transactions . . . . . . .       32    (8,099)    1,622    (9,562)
       Reclassification to earnings. . . . . . .   (1,541)    1,189    (3,475)    1,749
                                                  --------  --------  --------  --------
 Other comprehensive loss, net of tax. . . . . .   (1,669)   (5,772)   (2,796)   (8,296)
                                                  --------  --------  --------  --------
 Comprehensive income (loss) . . . . . . . . . .  $(3,755)  $(6,711)  $(6,399)  $73,425
                                                  ========  ========  ========  ========

<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
                                DECEMBER 31, 2001


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  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 the Rocky Mountains, Texas and New Zealand.

In  August  2000,  the  Company sold its wholly owned regulated gas distribution
utility,  Mountaineer  Gas  Company.  The  financial  statements  exclude  the
operating  results of this segment from continuing operations and for accounting
purposes  classify  such  as  discontinued  operations.


2.     Accounting  Policies

Reference  is  hereby  made  to the Company's Annual Report on Form 10-K for the
fiscal  year  ended  June 30, 2001, 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  December  31,  2001  are  not necessarily indicative of the results to be
expected  for  the  full  year.

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

                                       -8-
<PAGE>

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 December 31, 2001
------------------------------------
   Basic and Diluted . . . . . . . .  $(2,086,000)  659,615  $    (3.16)
Six months ended December 31, 2001
------------------------------------
   Basic and Diluted . . . . . . . .  $(3,603,000)  659,682  $    (5.46)
Three months ended December 31, 2000
------------------------------------
   Basic and Diluted . . . . . . . .  $  (250,000)  665,424  $    (0.38)
Six months ended December 31, 2000
------------------------------------
   Basic and Diluted . . . . . . . .  $(2,098,000)  666,164  $    (3.15)
</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.


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

                                       -9-
<PAGE>
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
                                                 and           and
                                              Production    Pipeline     Other      Consolidated
                                              ------------  -----------  ---------  -------------
 For the six months ended December 31, 2001
--------------------------------------------
   Sales to unaffiliated customers . . . . .  $     24,021  $   20,530                   $ 44,551
   Depreciation, depletion, amortization . .         7,183         442        273           7,898
   Impairment and exploratory costs. . . . .         1,389                                  1,389
   Operating profit (loss) . . . . . . . . .         3,259        (170)       (26)          3,063
   Interest expense. . . . . . . . . . . . .        11,303      (3,675)     2,299           9,927
   EBITDAX . . . . . . . . . . . . . . . . .        12,891         324        572          13,787
   Total assets. . . . . . . . . . . . . . .       154,545      74,652    112,694         341,891
   Capital expenditures. . . . . . . . . . .        15,439          51        471          15,961
-------------------------------------------------------------------------------------------------
 For the six months ended December 31, 2000
--------------------------------------------
   Sales to unaffiliated customers . . . . .  $     18,872  $   39,188   $    920   $      58,980
   Depreciation, depletion, amortization . .         4,690         487        206           5,383
   Impairment and exploratory costs. . . . .         2,637                                  2,637
   Operating profit (loss) . . . . . . . . .         3,420         755     (1,339)          2,836
   Interest expense. . . . . . . . . . . . .            41           1     10,282          10,324
   EBITDAX . . . . . . . . . . . . . . . . .        10,945         758      3,555          15,258
   Total assets. . . . . . . . . . . . . . .       127,087      76,722    181,426         385,235
   Capital expenditures. . . . . . . . . . .        68,868         625      2,201          71,694
</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.  The 'Other' column
includes  corporate-related  items,  including  corporate  debt,  non-reportable
segments and elimination items.  Included in the total assets of the exploration
and  production segment are net long-lived assets located in New Zealand of $5.2
million  as  of December 31, 2001 and 2000.  Effective July 1, 2000, the Company
initiated  a  new  policy,  which  reallocates certain costs, including interest
expense,  to  the  operating  segments  based  on  resource  utilization.


5.     Derivative  Instruments  and  Hedging  Activities

The  Company periodically hedges a portion of its oil and 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
December 31, 2001, the Company recorded a $0.6 million gain in accumulated other
comprehensive  income,  $1.4  million  short term derivative asset, $0.4 million
short  term  derivative  liability and $0.4 million deferred tax liability.  The
estimated  net  amount  of  the existing gains within other comprehensive income
that  are expected to be reclassified into earnings within the next 12 months is
approximately  $0.6  million.  The  Company has partially hedged its exposure to
the  variability  in  future  cash  flows  through  April  2002.

The  Company  entered  into  a  natural  gas sales contract with Allegheny Power
Company  to  supply  5,500  Mmbtu per day beginning December 2001 and continuing
through  October  2004.  The  Company  will receive a Henry Hub NYMEX base price
plus  an  Appalachian Basis adjustment with a collar between $2.75 and $4.85 per
Mmbtu.

                                       -10-
<PAGE>

6.     Contingencies

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.     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  Item  1.


COMPARISON OF RESULTS OF OPERATIONS FOR THE THREE MONTHS ENDED DECEMBER 31, 2001
--------------------------------------------------------------------------------
AND  2000
---------

     The  Company recorded a net loss from continuing operations of $2.1 million
for  the  quarter ended December 31, 2001 compared to a net loss of $0.3 million
for  the  same  period  in  2000.  The  decrease  in  income  of $1.8 million is
attributed  to  the  net of a $10.7 million decrease in revenue, a $10.5 million
decrease  in  operating expenses, a $2.7 million decrease in other non-operating
income  and  a  $1.1  million  increase  in  income  tax  benefits.

                                       -11-
<PAGE>

REVENUES. Total revenues decreased $10.7  million or 33.7% between the quarters.
--------
The  net  decrease  was  due  to  a 53.4% decrease in gas marketing and pipeline
sales,  a  15.3%  increase  in  oil  and  gas sales and a 100% decrease in other
operating  revenue.  Well  operations  and  service revenues remained relatively
constant.

     Revenues from gas marketing and pipeline sales decreased $11.5 million from
$21.6  million during the period ended December 31, 2000 to $10.1 million in the
period  ended  December  31, 2001.  Gas marketing revenue decreased $9.8 million
primarily  due to a 52% decrease in the average sales price per Mmbtu from $5.85
for  the  prior  period  to  $2.82  for  the  current period.  An 8% decrease in
marketed  gas  volumes  from 2.9 million Mmbtu to 2.7 million Mmbtu for the same
period  also  contributed  to  the decline.  For the total gas marketing revenue
decline,  $9.1  million  is attributed to the price decrease and $0.7 million to
the volume decrease.  Pipeline revenue decreased $1.7 million primarily due to a
41%  decrease  in  the  average sales price per Mmbtu from $4.91 for the quarter
ended  December  31,  2000  to  $2.92  for  the quarter ended December 31, 2001,
attributing  $1.6  million  to the total decrease.  A 7% decrease in gas volumes
from 0.8 million Mmbtu to 0.7 million Mmbtu for the same period also contributed
to  the  decline.

     Revenues  from  oil  and gas sales increased $1.3 million from $8.5 million
for  the  quarter  ended December 31, 2000 to $9.8 million for the quarter ended
December  31,  2001.  The  average  Mcf  price declined from $5.17 for the prior
period  to  $2.50  for  the  current  period.  The  Company's net Mcf production
increased  608.3  Mmcf,  31.7%  between  the  periods,  which  was attributed to
drilling  and  acquisitions.  The average Bbl price declined from $26.62 for the
prior  quarter to $18.70 for the current quarter. This price decrease was offset
by a 1,842 Bbl, 6.45%, increase in production for the quarter. The net effect of
the  decrease  in  prices  and  increase in production between the periods was a
decrease  of  $3.6  million  to  oil  and gas sales. This decrease was offset by
recognized  gains  on related hedging transactions, which totaled a gain of $2.7
million  for  the  quarter  ended  December  31, 2001 compared to a loss of $2.2
million  for  the  quarter  ended December 31, 2000. The average price per Mcfe,
after  hedging, was $3.58 and $4.02 for the quarters ended December 31, 2001 and
2000.

     Other  operating  revenue decreased from $0.5 million for the quarter ended
December  31,  2000  to  zero  for the current quarter. The revenue in the prior
quarter  was  attributed  to  a management contract whereby the Company provided
certain  services,  which  terminated  March  31,  2001.

COSTS AND EXPENSES.  The Company's costs and expenses decreased $10.5 million or
------------------
34.4%  between the quarters primarily as a net result of a 54.9% decrease in gas
marketing  and  pipeline  costs,  a  33.3% increase in field and lease operating
expenses,  a  60.2%  increase in oil and gas related depreciation, depletion and
amortization expenses and a 65.8% decreased in exploration and impairment costs.
Taxes  other  than  income  and  general  and  administrative  expenses remained
relatively  constant  between  the  periods.

   Gas marketing and pipeline costs decreased $11.1 million.  Gas marketing cost
decreased $9.1 million primarily due to a 52% decrease in the average price paid
per  Mmbtu  from  $5.49 for the quarter ended December 31, 2000 to $2.66 for the
quarter  ended  December  31,  2001.  Also contributing to the decrease was a 7%
decline in purchased gas volumes from 2.9 million Mmbtu to 2.7 million Mmbtu for
the  same  period.  Pipeline costs decreased $2.0 million primarily due to a 47%
decrease  in  the  average price paid for gas purchased from $4.65 per Mmbtu for
the  prior  period  to $2.66 for the current period.  Purchased gas volumes also
decreased  0.07  Mmbtu,  9%,  for  the  same  period.

     Field and lease operating expenses increased  $0.7 million primarily as the
result  of an acquisition that occurred during the second quarter of fiscal year
2001,  an  increase  in  Texas  activity  and  increased  payroll  expenses.

                                       -12-
<PAGE>

 Oil and gas related depreciation, depletion and amortization expenses increased
$1.2  million  as  a  result  of  the increased production volumes and increased
depletion  rates.

 Exploration and impairment expenses decreased $1.2 million primarily due to dry
hole  costs  incurred  during  the  prior  quarter.

     INCOME TAX.  The benefit for income taxes increased $1.1 million due to the
     ----------
$3.0  million  increased  loss  from  continuing  operation.


COMPARISON  OF  RESULTS OF OPERATIONS FOR THE SIX MONTHS ENDED DECEMBER 31, 2001
--------------------------------------------------------------------------------
AND  2000
---------

     The  Company recorded a net loss from continuing operations of $3.6 million
for  the six month period ended December 31, 2001 compared to a net loss of $2.1
million  for the same period in 2000.  The decrease in income of $1.5 million is
attributed  to  the  net of a $14.4 million decrease in revenue, a $14.7 million
decrease  in  operating expenses, a $0.4 million decrease to interest expense, a
$3.0  million decrease in other non-operating income and a $0.8 million increase
in  income  tax  benefits.

REVENUES.  Total  revenues decreased $14.4 million or 24.5% between the periods.
--------
The  net  decrease  was  due  to  a 47.6% decrease in gas marketing and pipeline
sales,  a  31.4%  increase  in  oil  and  gas sales and a 100% decrease in other
operating  revenue.  Well  operations  and  service revenues remained relatively
constant.

     Revenues from gas marketing and pipeline sales decreased $18.7 million from
$39.2  million during the period ended December 31, 2000 to $20.5 million in the
period  ended  December 31, 2001.  Gas marketing revenue decreased $16.0 million
primarily  due to a 42% decrease in the average sales price per Mmbtu from $5.18
for  the  prior  period  to  $3.02  for  the  current period.  A 15% decrease in
marketed  gas  volumes  from 6.1 million Mmbtu to 5.2 million Mmbtu for the same
period  also  contributed  to  the decline.  For the total gas marketing revenue
decline,  $13.2  million is attributed to the price decrease and $2.8 million to
the volume decrease.  Pipeline revenue decreased $2.7 million primarily due to a
31%  decrease  in  the  average  sales price per Mmbtu from $4.45 for the period
ended  December 31, 2000 to $3.08 for the period ended December 31, 2001.  An 8%
decrease in gas volumes from 1.6 million Mmbtu to 1.5 million Mmbtu for the same
period  also  contributed  to  the  decline.

   Revenues from oil and gas sales increased $5.1 million from $16.2 million for
the  period  ended  December  31,  2000  to  $21.3  million for the period ended
December  31,  2001.  The  average  Mcf  price declined from $4.61 for the prior
period  to  $2.69  for  the  current  period.  The  Company's net Mcf production
increased  1,209.7  Mmcf,  31.0%  between  the  periods, which was attributed to
drilling  and  acquisitions.  The average Bbl price declined from $26.87 for the
prior  period  to $21.04 for the current period.  This price decrease was offset
by  a  14,621 Bbl, 26.6%, increase in production for the period.  The net effect
of  the  decrease in prices and increase in production between the periods was a
decrease  of  $4.0  million  to  oil and gas sales.  This decrease was offset by
recognized  gains  on related hedging transactions, which totaled a gain of $5.8
million  for  the  period  ended  December  31,  2001 compared to a loss of $3.3
million  for  the  period  ended December 31, 2000.  The average price per Mcfe,
after  hedging,  was $4.90 and $3.05 for the periods ended December 31, 2001 and
2000.

     Other operating revenue decreased from $0.9  million  for  the period ended
December  31,  2000  to  zero  for the current period.  The revenue in the prior
period  was  attributed  to  a  management contract whereby the Company provided
certain  services,  which  terminated  March  31,  2001.

                                       -13-
<PAGE>

COSTS AND EXPENSES.  The Company's costs and expenses decreased $14.7 million or
------------------
26.1%  between  the periods primarily as a net result of a 48.4% decrease in gas
marketing  and  pipeline  costs,  a  29.2% increase in field and lease operating
expenses,  a  24.2%  increase  in  general  and administrative expenses, a 36.8%
decrease  in  taxes  other  than income, a 60.5% increase in oil and gas related
depreciation,  depletion  and  amortization  expenses  and  a  47.3% decrease in
exploration  and  impairment  costs.

   Gas marketing and pipeline costs decreased $17.9 million.  Gas marketing cost
decreased  $15.1  million  primarily  due to a 41% decrease in the average price
paid  per  Mmbtu  from $4.95 for the period ended December 31, 2000 to $2.93 for
the period ended December 31, 2001.  Also contributing to the decrease was a 15%
decline in purchased gas volumes from 6.1 million Mmbtu to 5.2 million Mmbtu for
the  same  period.  Pipeline costs decreased $2.8 million primarily due to a 35%
decrease  in  the  average price paid for gas purchased from $4.05 per Mmbtu for
the  prior  period  to $2.62 for the current period.  Purchased gas volumes also
decreased  0.1  million  Mmbtu,  9%,  for  the  same  period.

     Field and lease operating expenses increased  $1.2 million primarily as the
result  of an acquisition that occurred during the second quarter of fiscal year
2001,  increased  Texas  activity  and other increased expenses, such as payroll
costs  and  flood  damages.

   General and administrative  expenses increased $1.4 million because of higher
costs,  primarily related to payroll and employee benefits, outside professional
fees,  information  technology  costs  and  increased  Texas  activity.

   Taxes other than income decreased $0.5 million primarily due to decreased oil
and  gas  prices.  Production  taxes  are  based  on wellhead prices and are not
affected  by  hedging  activity.

 Oil and gas related depreciation, depletion and amortization expenses increased
$2.4  million  as  a  result  of  the increased production volumes and increased
depletion  rates.

     INTEREST  EXPENSE. Interest expense  decreased $0.4  million or 3.9%,  when
     -----------------
comparing  the  periods.  This is primarily due to eliminating the $19.8 million
revolving  line  of  credit and the related fees and deferred financing costs on
August  18,  2000.

     INCOME TAX.  The benefit for income taxes increased $0.8 million due to the
     ----------
$2.3  million  increased  loss  from  continuing  operation.


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

     During  the  quarter ended December 31, 2001, the Company's working capital
decreased  from  $48.1  million  at  September  30,  2001 to $36.2 million.  The
Company's  cash  decreased  from  $59.1  million  at September 30, 2001 to $42.0
million  at  December  31,  2001.  The decrease in cash during the quarter was a
result  of  the  net  use  of  approximately  $17.1  million of cash for various
operating  and  capital  expenditure  activities of the Company.  The activities
were  primarily  comprised of: the net investment of approximately $10.4 million
in property, plant and equipment; payments of approximately $0.7 million for the
acquisition  of  treasury stock and dividends; and the use of approximately $6.0
million  of  cash  by  operations during the quarter.  Cash used for the various
operating  and  capital  expenditures of the Company was offset by approximately
$6.2  million of income before interest charges, taxes, depreciation, depletion,
amortization  and  impairment  and  exploratory  costs  ("EBITDAX")  during  the
quarter.

  At December 31, 2001, the Company's principal source of liquidity consisted of
$42.0  million of cash.  The $2 million potentially available under an unsecured
short-term  credit facility currently in place could not be utilized at December
31, 2001 due to the Notice of Default discussed below.  At December 31, 2001, no
amounts  were  outstanding  or  committed  under the short-term credit facility.

                                       -14-
<PAGE>

    During the quarter, certain bondholders of the Company's Senior Subordinated
Notes  ("Notes")  made  inquiries regarding the Company's calculation of the Net
Proceeds  from  the  sale  of  Mountaineer  Gas  Company  ("Mountaineer").
Specifically,  these inquiries were directed to the Company's calculation of the
"taxes  paid or payable as a result [of the sale] (after taking into account any
available  tax  credits  or  deductions  and any tax sharing arrangements)".  In
response  to  these inquiries, the Company stated that the taxes paid or payable
as a result of the sale are $83.8 million and that such tax calculation does not
include  any  credits,  deductions  or  operating  losses unrelated to the sale.
Certain bondholders questioned the Company's interpretation and asserted that in
calculating  Net  Proceeds  all  tax  credits available to the Company are to be
utilized  in  determining the taxes paid or payable as a result of the sale.  It
is  the  Company's position that tax credits or losses that are unrelated to the
sale of Mountaineer are to be excluded in the calculation of the Net Proceeds of
such  sale.

     On December 27, 2001, the Company received a Notice of Default from certain
bondholders,  who  state  that  they  represented  more  than  50% of the Notes,
alleging  that  the Company had failed to make an Asset Sale Offer for the Notes
consistent with the terms of the Indenture.  The bondholders advised the Company
that  an  Event  of  Default  would  arise  under  the  Indenture if the alleged
non-compliance  was  not  remedied within 30 days of the Notice of Default.  The
bondholders  expressly  cited  and  reserved their rights under the Indenture to
accelerate  immediately payment of all principal and other amounts due under the
Notes  if  the  alleged  failure  to  comply with the Indenture was not remedied
within  the  30 days.  The Company believes it has fully complied with the terms
of  the  Indenture.

     On  December  28,  2001, the Company filed a declaratory judgment action in
the  United  States  District  Court  of  the Southern District of West Virginia
against  the  holders  of the Notes who issued the Notice of Default, asking the
Court  to  confirm the proper calculation of Net Proceeds of an Asset Sale under
the  Indenture.  On  January  25,  2002,  the Court issued an order granting the
Company's  motion  for  partial  summary  judgment.  The  Court  agreed with the
Company's  position  that  in  the  calculation  of  taxes  paid or payable as a
component  of  Net  Proceeds  from  an  Asset Sale, only credits, deductions and
arrangements  resulting  from that asset sale need to be considered.  The matter
remains  pending.

     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  and  interest  expense.  Management  anticipates  that  in  light of
continued  lower  product  prices,  EBITDAX  for  fiscal  year  2002  will  be
approximately  $30  million.  EBITDAX  for  fiscal years 2001, 2000 and 1999 was
$33.2 million, $3.6 million and $10.4 million respectively.  However, management
estimates  that  capital  expenditures  for  fiscal  year  2002  will  total
approximately  $35  million  and interest expense will total approximately $19.2
million.  Although  cash  provided  from  oil  and  gas  operations  will not be
sufficient  to  fully  fund  the  Company's  fiscal year 2002 projected interest
charges  and  capital  expenditures  program,  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 divestment of 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.

     The Company  believes that its existing capital  resources,  its mitigating
management  efforts  and its expected fiscal year 2002 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.

                                       -15-
<PAGE>

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

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.  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.  All of the Company's debt has fixed interest
rates.  The Company has not attempted to hedge the interest rate risk associated
with  its  debt.

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

     The  Company's  operations  consist  primarily of exploring for, producing,
aggregating  and  selling natural gas and oil.  The Company attempts to mitigate
its  commodity  price risk by entering into a mix of short, medium and long-term
supply  contracts.  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.
Notwithstanding  the  above,  the  Company's  future cash flows from gas and oil
production  are  exposed  to  significant volatility as commodity prices change.

     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 swap transactions, covering approximately 18.3% of its
natural  gas  production  through  April  2002.

FOREIGN  CURRENCY  TRANSLATION
------------------------------

     Some  of  the  Company's  transactions  are  denominated  in New Zealand or
Australian  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.

                                       -16-
<PAGE>

PART  II.  OTHER  INFORMATION

ITEM  1.  LEGAL  PROCEEDINGS

     As previously disclosed the Company has  filed  a  lawsuit  against  Oracle
Corporation  seeking  judgment  for  approximately  $5.4  million  together with
prejudgment  interest  and  costs.  Oracle  has  answered  the complaint and has
substantially  denied  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.  The  case  is  in  its early stages and the Company intends to
aggressively  prosecute  its  case  against Oracle as well as defend against the
counterclaims  of  Oracle.

    The Company, along with various other Appalachian Basin producers have filed
suit  against  MarkWest  Hydrocarbon,  Inc.  seeking  a  preliminary injunction,
permanent  injunction,  declaratory judgment and damages.  MarkWest has answered
and denied substantially all of the allegations of the producers and has filed a
counterclaim against the producers alleging various causes of action.  On August
13,  2001  the  Court  in  its  Opinion  Order,  stated  in part "The Plaintiffs
(including the Company) are likely to prevail on the merits of their claim for a
breach  of  contract".  The  Company  and  the  producers intend to aggressively
prosecute  its case against MarkWest as well as defend against the counterclaims
of  MarkWest.

   As previously disclosed in the Company's Form 8-K filed on December 31, 2001,
certain  holders  of  the Company's $200 million 9-1/2% Senior Subordinate Notes
due  2007  (the  "Notes")  gave  a  Notice of Default on December 27, 2001.  The
Company  fully believed that it had complied with the terms of the Indenture and
filed  a declaratory judgment action in the United States District Court for the
Southern  District  of  West  Virginia  (Civil  Action No.3:01-1317) against the
holders  of  the  Notes who issued the Notice of Default.  The Company asked the
Court  to  confirm  the proper calculation of the Net Proceeds for an Asset Sale
under  the  Indenture.  The  Company filed a Motion for Partial Summary Judgment
and  the  bondholders  filed  a  Motion  to  Dismiss.  The  Court established an
expedited  schedule  and  heard  oral  argument from both parties on January 23,
2002.  On  January  25,  2002,  the Court issued an Order granting the Company's
Motion  for  Partial  Summary  Judgment  and  denying the bondholder's Motion to
Dismiss.  The  Court  approved  the  Company's  methodology  in  calculating Net
Proceeds  under  the  terms  of  the  Indenture.  The  matter  remains  pending.

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

                                       -17-
<PAGE>

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)     Reports  on  Form  8-K

The  Company  filed  a  report  on  Form  8-K,  Item  5, filed December 31, 2001
reporting  the Notice of Default that the Company received on December 27, 2001.

                                       -18-
<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  February,  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


                                       -19-
<PAGE>