Back to GetFilings.com
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-Q
(Mark One)
[X] QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(D) OF THE SECURITIES
EXCHANGE ACT OF 1934
For the quarterly period ended March 31, 2004
OR
[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(D) OF THE SECURITIES
EXCHANGE ACT OF 1934
For the transition period from _________ to __________
Commission file number: 333-112653
ATLAS AMERICA, INC.
-------------------
(Exact name of registrant as specified in its charter)
Delaware 51-0404430
-------- ----------
(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification No.)
311 Rouser Road
Moon Township, PA 15108
- ---------------------------------------- ---------
(Address of principal executive offices) (Zip code)
Registrant's telephone number, including area code: (412) 262-2830
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 [ ] No [ X ]
Indicate by check mark whether the registrant is an accelerated filer (as
defined in Rule 12b-2 of the Exchange Act).
Yes [ ] No [ X ]
APPLICABLE ONLY TO CORPORATE ISSUERS
Indicate the number of shares outstanding of each of the issuer's
classes of common stock, as of the latest practicable date:
13,333,333 Shares June 11, 2004
ATLAS AMERICA, INC.
(A Wholly-Owned Subsidiary of Atlas Energy Holdings, Inc.)
INDEX TO QUARTERLY REPORT
ON FORM 10-Q
PAGE
----
PART I. FINANCIAL INFORMATION
Item 1. Financial Statements
Consolidated Balance Sheets as of March 31, 2004 (Unaudited) and
September 30, 2003.............................................................. 3
Consolidated Statements of Income for the Three and Six Months Ended
March 31, 2004 and 2003 (Unaudited)............................................. 4
Consolidated Statement of Changes in Stockholder's Equity for the Six
Months Ended March 31, 2004 (Unaudited)......................................... 5
Consolidated Statements of Cash Flows for the Six Months Ended
March 31, 2004 and 2003 (Unaudited)............................................. 6
Notes to Consolidated Financial Statements - March 31, 2004 (Unaudited)............. 7 - 19
Item 2. Management's Discussion and Analysis of Financial Condition and Results
of Operations................................................................... 20 - 30
Item 3. Quantitative and Qualitative Disclosures About Market Risk.......................... 31 - 32
Item 4. Controls and Procedures............................................................. 32
PART II. OTHER INFORMATION
Item 4. Submission of Matters to a Vote of Security Holders................................. 33
Item 6. Exhibits and Reports on Form 8-K.................................................... 33
SIGNATURES .......................................................................................... 34
2
ATLAS AMERICA, INC.
(A WHOLLY-OWNED SUBSIDIARY OF ATLAS ENERGY HOLDINGS, INC.)
CONSOLIDATED BALANCE SHEETS
(in thousands, except share data)
MARCH 31, SEPTEMBER 30,
2004 2003
----------------- ------------------
(Unaudited) (Audited)
ASSETS
Current assets:
Cash and cash equivalents........................................... $ 11,908 $ 25,372
Accounts receivable................................................. 8,620 12,362
Prepaid expenses.................................................... 1,237 1,131
----------- -----------
Total current assets............................................ 21,765 38,865
Property and equipment, net.............................................. 153,686 142,260
Goodwill 37,470 37,470
Intangible assets........................................................ 7,720 8,239
Other assets............................................................. 6,890 5,554
----------- -----------
$ 227,531 $ 232,388
=========== ===========
LIABILITIES AND STOCKHOLDER'S EQUITY
Current liabilities:
Current portion of long-term debt................................... $ 56 $ 56
Accounts payable.................................................... 14,487 14,663
Liabilities associated with drilling contracts...................... 15,465 22,157
Accrued liabilities................................................. 3,126 4,151
----------- ------------
Total current liabilities....................................... 33,134 41,027
Long-term debt........................................................... 40,610 31,138
Advance from parent...................................................... 2,453 4,498
Deferred tax liability................................................... 22,364 21,031
Asset retirement obligation.............................................. 3,371 3,207
Minority interest ....................................................... 43,163 43,976
Commitments and contingencies............................................ - -
Stockholder's equity:
Preferred stock, $0.01 par value: 1,000,000 authorized shares........ - -
Common stock, $0.01 par value: 49,000,000 authorized shares ........ 107 107
Additional paid-in capital........................................... 38,619 38,619
Retained earnings.................................................... 43,710 48,785
----------- ------------
Total stockholder's equity...................................... 82,436 87,511
----------- ------------
$ 227,531 $ 232,388
=========== ============
See accompanying notes to consolidated financial statements
3
ATLAS AMERICA, INC.
(A WHOLLY-OWNED SUBSIDIARY OF ATLAS ENERGY HOLDINGS, INC.)
CONSOLIDATED STATEMENTS OF INCOME
(Unaudited)
(in thousands, except per share data)
THREE MONTHS ENDED SIX MONTHS ENDED
MARCH 31, MARCH 31,
------------------------------ -----------------------------
2004 2003 2004 2003
------------- ------------- ------------- ------------
REVENUES
Well drilling..................................... $ 26,248 $ 23,366 $ 48,207 $ 29,949
Gas and oil production............................ 11,799 9,416 21,995 17,485
Well services..................................... 2,123 2,152 4,060 4,052
Transportation.................................... 1,579 1,403 3,178 2,810
Other............................................. 331 137 499 313
----------- ---------- ---------- ---------
42,080 36,474 77,939 54,609
COSTS AND EXPENSES
Well drilling..................................... 22,824 20,318 41,919 26,043
Gas and oil production and exploration............ 3,323 2,602 5,008 4,188
Well services..................................... 1,021 1,085 2,062 1,940
Transportation.................................... 620 613 1,216 1,203
General and administrative........................ 1,248 1,211 2,159 3,441
Depreciation, depletion and amortization.......... 3,534 2,983 6,779 5,855
Interest.......................................... 473 430 960 1,059
Minority interest in Atlas Pipeline Partners, L.P. 1,324 884 2,595 1,529
---------- ---------- ---------- ---------
34,367 30,126 62,698 45,258
---------- ---------- ---------- ---------
Income from operations before income taxes........ 7,713 6,348 15,241 9,351
Provision for income taxes........................ 2,547 2,094 5,182 3,085
---------- ---------- ---------- ---------
Net income........................................ $ 5,166 $ 4,254 $ 10,059 $ 6,266
========== ========== ========== =========
NET INCOME PER COMMON SHARE -
BASIC AND DILUTED............................... $ .48 $ .40 $ .94 $ .59
========== ========== ========== =========
WEIGHTED AVERAGE COMMON SHARES
OUTSTANDING.................................... 10,688 10,688 10,688 10,688
========== ========== ========== =========
See accompanying notes to consolidated financial statements
4
ATLAS AMERICA, INC.
(A WHOLLY-OWNED SUBSIDIARY OF ATLAS ENERGY HOLDINGS, INC.)
CONSOLIDATED STATEMENT OF CHANGES IN STOCKHOLDER'S EQUITY
SIX MONTHS ENDED MARCH 31, 2004
(Unaudited)
(in thousands, except share data)
COMMON STOCK ADDITIONAL TOTAL
--------------------------------- PAID-IN RETAINED STOCKHOLDER'S
SHARES AMOUNT CAPITAL EARNINGS EQUITY
---------------------------------------------------------------------------------
Balance, October 1, 2003.................. 10,688,333 $ 107 $ 38,619 $ 48,785 $ 87,511
Dividend to parent........................ - - - (15,134) (15,134)
Net income................................ - - - 10,059 10,059
---------- ----------- ----------- --------- -----------
Balance, March 31, 2004................... 10,688,333 $ 107 $ 38,619 $ 43,710 $ 82,436
========== =========== =========== ========= ===========
See accompanying notes to consolidated financial statements
5
ATLAS AMERICA, INC.
(A WHOLLY-OWNED SUBSIDIARY OF ATLAS ENERGY HOLDINGS, INC.)
CONSOLIDATED STATEMENTS OF CASH FLOWS
SIX MONTHS ENDED MARCH 31, 2004 AND 2003
(Unaudited)
(in thousands)
2004 2003
---------------- ---------------
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income...................................................................... $ 10,059 $ 6,266
Adjustments to reconcile net income to net cash provided by operating
activities:
Depreciation, depletion and amortization................................... 6,779 5,855
Amortization of deferred finance costs..................................... 320 281
Minority interest in Atlas Pipeline Partners, L.P.......................... 2,595 1,529
Loss on asset dispositions................................................. (49) (55)
Property impairments and abandonments...................................... 599 12
Deferred income taxes...................................................... 5,182 3,085
Changes in operating assets and liabilities..................................... (2,972) 7,188
----------- ----------
Net cash provided by operating activities....................................... 22,513 24,161
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures............................................................ (17,546) (12,660)
Proceeds from sale of assets.................................................... 159 119
Decrease (increase) in other assets............................................. (826) 286
----------- -----------
Net cash used in investing activities........................................... (18,213) (12,255)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings...................................................................... 48,000 53,383
Principal payments on debt...................................................... (38,528) (55,167)
Payments to parent.............................................................. (7,866) -
Dividends paid to parent........................................................ (15,134) -
Distributions paid to minority interests of Atlas Pipeline Partners, L.P........ (3,379) (1,751)
Increase in other assets........................................................ (857) (592)
----------- -----------
Net cash used in financing activities........................................... (17,764) (4,127)
Increase (decrease) in cash and cash equivalents................................ (13,464) 7,779
Cash and cash equivalents at beginning of period................................ 25,372 8,922
----------- -----------
Cash and cash equivalents at end of period...................................... $ 11,908 $ 16,701
=========== ===========
See accompanying notes to consolidated financial statements
6
ATLAS AMERICA, INC.
(A Wholly-Owned Subsidiary of Atlas Energy Holdings, Inc.)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NOTE 1 - MANAGEMENT'S OPINION REGARDING INTERIM FINANCIAL STATEMENTS
The consolidated financial statements include the accounts of the
Company and its subsidiaries, all of which are wholly-owned except for Atlas
Pipeline Partners, L.P. ("Atlas Pipeline").
The consolidated financial statements and the information and tables
contained in the notes to the consolidated financial statements as of March 31,
2004 and for the three and six months ended March 31, 2004 and 2003 are
unaudited. Certain information and footnote disclosures normally included in
financial statements prepared in accordance with accounting principles generally
accepted in the United States of America have been condensed or omitted in these
statements pursuant to the rules and regulations of the Securities and Exchange
Commission. However, in the opinion of management, these interim financial
statements include all the necessary adjustments to fairly present the results
of the interim periods presented. The results of operations for the six months
ended March 31, 2004 may not necessarily be indicative of the results of
operations for the full fiscal year ending September 30, 2004.
Certain reclassifications have been made to the consolidated financial
statements as of September 30, 2003 to conform to the presentation as of and for
the three months and six months ended March 31, 2004.
NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
FAIR VALUE OF FINANCIAL INSTRUMENTS
The Company uses the following methods and assumptions in estimating
the fair value of each class of financial instruments for which it is
practicable to estimate fair value.
For cash and cash equivalents, receivables, payables and debt, the
carrying amounts approximate fair value because of the short maturity of these
instruments.
For secured revolving credit facilities and all other debt, the
carrying value approximates fair value because of the short term maturity of
these instruments and the variable interest rates in the debt agreements.
7
ATLAS AMERICA, INC.
(A Wholly-Owned Subsidiary of Atlas Energy Holdings, Inc.)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - (CONTINUED)
STOCK-BASED COMPENSATION
The Company accounts for its employees' participation in the stock
option plans of its parent, Resource America, Inc. ("RAI"), in accordance with
the provisions of Accounting Principles Board Opinion No. 25, "Accounting for
Stock Issued to Employees ("APB 25"), and related interpretations. Compensation
expense is recorded on the date of grant only if the current market price of the
underlying stock exceeded the exercise price. The Company adopted the disclosure
requirement of Statement of Financial Accounting Standards ("SFAS") No. 123,
"Accounting for Stock-Based Compensation, as amended by the required disclosures
SFAS No. 148, "Accounting for Stock-Based Compensation-Transition and
Disclosure." No stock-based employee compensation cost is reflected in net
income of the Company, as all options granted under those plans had an exercise
price equal to the market value of the underlying RAI common stock on the date
of grant. The following table illustrates the effect on net income if the
Company had applied the fair value recognition provisions of SFAS 123 to
stock-based employee compensation.
Three Months Ended Six Months Ended
March 31, March 31,
------------------ ------------------
2004 2003 2004 2003
------ ------ ------ ------
(in thousands, except per share data)
Net income, as reported........................................ $ 5,166 $ 4,254 $ 10,059 $ 6,266
Stock-based employee compensation expense
reported in net income, net of tax......................... - - - -
Less total stock-based employee compensation
expense determined under the fair
value-based method for all awards, net of income
taxes...................................................... (82) (115) (162) (231)
--------- --------- --------- --------
Pro forma net income........................................... $ 5,084 $ 4,139 $ 9,897 $ 6,035
========= ========= ========= ========
Net income per share:
Basic and diluted - as reported............................... $ .48 $ .40 $ .94 $ .59
Basic and diluted - pro forma................................. $ .48 $ .39 $ .93 $ .56
8
ATLAS AMERICA, INC.
(A Wholly-Owned Subsidiary of Atlas Energy Holdings, Inc.)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - (CONTINUED)
COMPREHENSIVE INCOME
Comprehensive income includes net income and all other changes in the
equity of a business during a period from transactions and other events and
circumstances from non-owner sources. These changes, other than net income, are
referred to as "other comprehensive income" and for the Company include only
changes in the fair value, net of taxes, of unrealized hedging gains and losses.
Three Months Ended Six Months Ended
March 31, March 31,
-------------------- --------------------
2004 2003 2004 2003
--------- -------- ------- --------
(in thousands)
Net income.................................................... $ 5,166 $ 4,254 $ 10,059 $ 6,266
Other comprehensive loss:
Unrealized loss on natural gas futures and
options contracts, net of taxes of $50 and $145.......... - (106) - (318)
--------- -------- --------- ---------
Comprehensive income.......................................... $ 5,166 $ 4,148 $ 10,059 $ 5,948
========= ======== ========= =========
EARNINGS PER SHARE
There is no difference between basic and diluted net income per share
since there are no potentially dilutive shares outstanding. Earnings per share
is determined by dividing net income by the weighted average number of
outstanding common shares during the three months ended March 31, 2004 and 2003.
DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES
The Company from time to time enters into natural gas futures and
option contracts to hedge its exposure to changes in natural gas prices. At any
point in time, such contracts may include regulated New York Mercantile Exchange
("NYMEX") futures and options contracts and non-regulated over-the-counter
futures contracts with qualified counterparties. NYMEX contracts are generally
settled with offsetting positions, but may be settled by the delivery of natural
gas.
9
ATLAS AMERICA, INC.
(A Wholly-Owned Subsidiary of Atlas Energy Holdings, Inc.)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - (CONTINUED)
At March 31, 2004, the Company had no open natural gas futures
contracts related to natural gas sales. Gains or losses on futures contracts are
determined as the difference between the contract price and a reference price,
generally prices on NYMEX. The Company did not settle any contracts during the
six months ended March 31, 2004. The Company recognized losses of $448,000 and
$544,000 on settled contracts for the three months and six months ended March
31, 2003, respectively. The Company recognized no gains or losses during the six
months ended March 31, 2004 and 2003 for hedge ineffectiveness or as a result of
the discontinuance of cash flow hedges.
Although hedging provides the Company some protection against falling
prices, these activities could also reduce the potential benefits of price
increases, depending upon the instrument.
PROPERTY AND EQUIPMENT
Property and equipment consists of the following:
March 31, September 30,
2004 2003
--------- -------------
(in thousands)
Mineral interests in properties:
Proved properties.............................................. $ 844 $ 844
Unproved properties............................................ 983 563
Wells and related equipment........................................ 201,411 184,226
Support equipment.................................................. 2,336 2,189
Other.............................................................. 7,427 7,299
----------- ----------
213,001 195,121
Accumulated depreciation, depletion, amortization and
valuation allowances:
Oil and gas properties......................................... (56,275) (50,170)
Other (3,040) (2,691)
----------- ----------
(59,315) (52,861)
----------- ----------
$ 153,686 $ 142,260
=========== ==========
ASSET RETIREMENT OBLIGATIONS
The Company accounts for its estimated plugging and abandonment of its
oil and gas properties in accordance with SFAS 143, "Accounting for Asset
Retirement Obligations."
10
ATLAS AMERICA, INC.
(A Wholly-Owned Subsidiary of Atlas Energy Holdings, Inc.)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - (CONTINUED)
A reconciliation of the Company's liability for well plugging and
abandonment costs for the periods indicated follows:
Three Months Ended Six Months Ended
March 31, March 31,
------------------- -------------------
2004 2003 2004 2003
------ ------ ------ ------
(in thousands)
Asset retirement obligations, beginning
of period................................................. $ 3,180 $ 3,380 $ 3,131 $ -
Liabilities incurred......................................... 71 - 101 -
Adoption of SFAS 143......................................... - - - 3,380
Liabilities settled.......................................... (15) - (43) -
Revisions in estimates....................................... 83 - 83 -
Accretion expense............................................ 52 101 99 101
--------- --------- --------- ---------
Asset retirement obligations, end of period.................. $ 3,371 $ 3,481 $ 3,371 $ 3,481
========= ========= ========= =========
The above accretion expense is included in depreciation, depletion and
amortization in the Company's consolidated statements of income.
SUPPLEMENTAL CASH FLOW INFORMATION
The Company considers temporary investments with maturity at the date
of acquisition of 90 days or less to be cash equivalents.
Supplemental disclosure of cash flow information:
Six Months Ended
March 31,
--------------------------
2004 2003
-------- --------
(in thousands)
CASH PAID DURING THE PERIOD FOR:
Interest.................................................................... $ 579 $ 636
Income taxes................................................................ $ - $ 82
NON-CASH ACTIVITIES INCLUDE THE FOLLOWING:
Asset retirement obligation................................................. $ 101 $ 3,380
11
ATLAS AMERICA, INC.
(A Wholly-Owned Subsidiary of Atlas Energy Holdings, Inc.)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - (CONTINUED)
RECENTLY ISSUED FINANCIAL ACCOUNTING STANDARDS
In December 2003, the Financial Accounting Standards Board ("FASB")
revised SFAS No. 132, "Employers' Disclosures about Pensions and other
Postretirement Benefits," establishing additional annual disclosures about plan
assets, investment strategy, measurement date, plan obligations and cash flows.
In addition, the revised standard established interim disclosure requirements
related to the net periodic benefit cost recognized and contributions paid or
expected to be paid during the current fiscal year. The new annual disclosures
are effective for financial statements with fiscal years ending after December
15, 2003 and the interim-period disclosures are effective for interim periods
beginning after December 15, 2003. The adoption of the revised SFAS No. 132 had
no impact on the Company's results of operations or financial position.
In April 2003, the FASB issued SFAS No. 149 ("SFAS 149"), "Amendment of
Statement 133 on Derivative Instruments and Hedging Activities." SFAS 149 is
effective for contracts entered into or modified after December 31, 2003 and
amends and clarifies financial accounting and reporting for derivative
instruments. The adoption of SFAS 149 had no impact on the Company's financial
position or results of operations.
In January 2003, FASB issued Interpretation No. 46, "Consolidation of
Variable Interest Entities, an Interpretation of ARB No. 51" ("FIN 46"). In
December 2003, FASB issued a revised interpretation of FIN 46 ("FIN 46-R"),
which supersedes FIN 46 and clarifies and expands current accounting guidance
for variable interest entities ("VIE's"). FIN 46 clarifies when a company should
consolidate in its financial statements the assets, liabilities and activities
of a VIE. FIN 46 provides general guidance as to the definition of a VIE and
requires it to be consolidated if a party with an ownership, contractual or
other financial interest absorbs the majority of the VIE's expected losses, or
is entitled to receive a majority of the residual returns, or both. A variable
interest holder that is such a primary beneficiary of the VIE is required to
consolidate the VIE's assets, liabilities and non-controlling interests at fair
value at the date the interest holder first becomes the primary beneficiary of
the VIE. FIN 46 and FIN 46-R are effective immediately for all VIEs created
after January 31, 2003 and for VIEs created prior to February 1, 2003, no later
than the end of the first reporting period after March 15, 2004. The adoption of
FIN 46 on July 1, 2003 had no impact on the Company's financial position or
results of operations.
12
ATLAS AMERICA, INC.
(A Wholly-Owned Subsidiary of Atlas Energy Holdings, Inc.)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
NOTE 3 - OTHER ASSETS, INTANGIBLE ASSETS AND GOODWILL
OTHER ASSETS
The following table provides information about other assets at the
dates indicated:
March 31, September 30,
2004 2003
---------- -------------
(in thousands)
Deferred financing costs, net of accumulated amortization of
$1,411 and $1,091.............................................. $ 2,085 $ 1,548
Investments.............................................................. 2,908 2,974
Other.................................................................... 1,897 1,032
---------- -----------
$ 6,890 $ 5,554
========== ===========
Deferred financing costs are amortized over the terms of the related
loans.
INTANGIBLE ASSETS
Intangible assets consist of partnership management and operating
contracts acquired through acquisitions and recorded at fair value on their
acquisition dates. The Company amortizes contracts acquired on a declining
balance method over their respective estimated lives, ranging from five to
thirteen years. Amortization expense for the six months ended March 31, 2004 and
2003 was $519,000 and $635,000, respectively. The aggregate estimated annual
amortization expense is approximately $1.1 million for each of the succeeding
five year periods.
The following table provides information about intangible assets at the
dates indicated:
March 31, September 30,
2004 2003
----------- -------------
(in thousands)
Partnership management and operating contracts........................... $ 14,343 $ 14,343
Accumulated amortization................................................. (6,623) (6,104)
---------- ----------
Intangible assets, net................................................... $ 7,720 $ 8,239
=========== ==========
GOODWILL
The Company accounts for its goodwill in accordance with SFAS 142,
"Goodwill and Other Intangible Assets." The Company evaluates its goodwill at
least annually as of the last day of the fiscal year and will reflect the
impairment of goodwill, if any, in operating income in the statement of income
in the period in which the impairment is indicated. At March 31, 2004 and
September 30, 2003, the Company had goodwill of $37.5 million, net of
accumulated amortization of $4.2 million.
13
ATLAS AMERICA, INC.
(A Wholly-Owned Subsidiary of Atlas Energy Holdings, Inc.)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
NOTE 4 - DEBT
Total debt consists of the following:
March 31, September 30,
2004 2003
--------- -------------
(in thousands)
Revolving credit facilities.......................................... $ 40,500 $ 31,000
Other debt........................................................... 166 194
---------- -----------
40,666 31,194
Less current maturities.............................................. (56) (56)
---------- -----------
$ 40,610 $ 31,138
========== ===========
At March 31, 2004, the Company has complied with all covenants in its
debt agreements.
NOTE 5 - PENDING ACQUISITION
In September 2003, Atlas Pipeline entered into a purchase and sale
agreement with SEMCO Energy, Inc. ("SEMCO") pursuant to which Atlas Pipeline or
its designee will purchase substantially all of the stock of SEMCO's
wholly-owned subsidiary, Alaska Pipeline Company ("Alaska Pipeline"), which owns
an intrastate natural gas transmission pipeline that delivers gas to
metropolitan Anchorage (the "Acquisition"). The total consideration, payable in
cash at closing, will be approximately $95.0 million, subject to an adjustment
based on the amount of working capital that Alaska Pipeline has at closing.
As part of the Acquisition, at closing, Alaska Pipeline and ENSTAR
Natural Gas Company ("ENSTAR"), a division of SEMCO which conducts its gas
distribution business in Alaska, will enter into a Special Contract for Gas
Transportation pursuant to which ENSTAR will pay a reservation fee of $943,000
per month for the use of all of the pipeline's transportation capacity plus
$.075 per thousand cubic feet, or mcf, of gas transported, for 10 years. During
2003, total gas volumes delivered through the Alaska Pipeline system averaged
approximately 147.0 million cubic feet per day. SEMCO will execute a gas
transmission agreement with Alaska Pipeline pursuant to which SEMCO will be
obligated to make up any difference if the Regulatory Commission of Alaska
reduces the transportation rates payable by ENSTAR pursuant to the Special
Contract.
Further, Alaska Pipeline will enter into an Operation and Maintenance
and Administrative Services Agreement with ENSTAR under which ENSTAR will
continue to operate and maintain the pipeline for at least 5 years for a fee of
$334,000 per month for the first three years. Thereafter, ENSTAR's fee will be
adjusted for inflation.
14
ATLAS AMERICA, INC.
(A Wholly-Owned Subsidiary of Atlas Energy Holdings, Inc.)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
NOTE 5 - PENDING ACQUISITION - (CONTINUED)
Consummation of the Acquisition is subject to a number of conditions,
including receipt of governmental and non-governmental consents and approvals
and the absence of a material adverse change in Alaska Pipeline's business. The
purchase and sale agreement may be terminated by either SEMCO or Atlas Pipeline
if the transaction is not completed by June 16, 2004, unless the party seeking
the termination caused the delay by failing to fulfill its obligations under the
agreement. Among the required governmental authorizations are approval of the
Regulatory Commission of Alaska and expiration of the waiting period under the
Hart-Scott-Rodino Antitrust Improvements Act. Atlas Pipeline received an early
termination of the Hart-Scott-Rodino waiting period in January 2004. On April
20, 2004, the Regulatory Commission issued an order finding that approval of the
transaction is in the public interest and consistent with controlling law.
Thereafter, SEMCO filed a "Petition for Clarification or Alternatively
Reconsideration" with the Regulatory Commission seeking clarification or
amendment of the order that SEMCO believed would make the order comply with the
regulatory approval requirements of the purchase agreement. On June 4, 2004, the
Regulatory Commission issued an order granting SEMCO's motion for
reconsideration, vacating its prior order and approving the transfer of control
of Alaska Pipeline. In its order, the Regulatory Commission stated that it could
not grant the regulatory approvals required by the purchase agreement on the
record before it and permitted the parties to request further proceedings. Atlas
Pipeline notified SEMCO on June 15, 2004 that it believes SEMCO has breached its
obligations under the purchase and has requested that SEMCO participate in the
dispute resolution procedures prescribed by the purchase agreement. The
acquisition could be delayed or prevented if the dispute is not resolved in a
timely manner.
NOTE 6 - COMMON STOCK SPLIT
On February 10, 2004, the Company filed a registration statement on
Form S-1 with respect to a proposed public offering of up to 19.8% of its common
stock. On February 27, 2004 the Company effectuated a 106,833 for 1 stock split.
Income per share reflecting the retroactive effect of the stock split is
presented on the face of the consolidated statements of income for the three
months and six months ended March 31, 2004 and 2003. (See Note 8)
15
ATLAS AMERICA, INC.
(A Wholly-Owned Subsidiary of Atlas Energy Holdings, Inc.)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
NOTE 7 - OPERATING SEGMENT INFORMATION AND MAJOR CUSTOMERS
The Company's operations include two reportable operating segments. In
addition to the reportable operating segments, certain other activities are
reported in the "Other energy" category. These operating segments reflect the
way the Company manages its operations and makes business decisions. The Company
does not allocate income taxes to its operating segments.
Operating segment data for the periods indicated are as follows:
THREE MONTHS ENDED MARCH 31, 2004 (in thousands):
Production
Well and Other
Drilling Exploration Energy (a) Total
--------- ----------- ---------- -----------
Revenues from external customers...................... $ 26,248 $ 11,799 $ 4,033 $ 42,080
Interest income....................................... - - 20 20
Interest expense...................................... - - 473 473
Depreciation, depletion and amortization.............. - 2,513 1,021 3,534
Segment profit (loss)................................. 3,007 5,847 (1,141) 7,713
Other significant items:
Segment assets.................................... 7,725 150,683 69,123 227,531
- --------------
(a) Revenues and expenses from segments below the quantitative thresholds are
attributable to two operating segments of the Company. Those segments
include well services and transportation. These segments have never met
any of the quantitative thresholds for determining reportable segments.
THREE MONTHS ENDED MARCH 31, 2003 (in thousands):
Production
Well and Other
Drilling Exploration Energy (a) Total
----------- ----------- ---------- ---------
Revenues from external customers.................... $ 23,366 $ 9,416 $ 3,692 $ 36,474
Interest income..................................... - - 47 47
Interest expense.................................... - - 430 430
Depreciation, depletion and amortization........... - 2,034 949 2,983
Segment profit ..................................... 1,521 4,206 621 6,348
Other significant items:
Segment assets.................................. 7,332 132,034 56,318 195,684
- --------------
(a) Revenues and expenses from segments below the quantitative thresholds are
attributable to two operating segments of the Company. Those segments
include well services and transportation. These segments have never met any
of the quantitative thresholds for determining reportable segments.
16
ATLAS AMERICA, INC.
(A Wholly-Owned Subsidiary of Atlas Energy Holdings, Inc.)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
NOTE 7 - OPERATING SEGMENT INFORMATION AND MAJOR CUSTOMERS - (CONTINUED)
SIX MONTHS ENDED MARCH 31, 2004 (in thousands):
Production
Well and Other
Drilling Exploration Energy (a) Total
---------- ------------ ----------- -----------
Revenues from external customers.................... $ 48,207 $ 21,995 $ 7,737 $ 77,939
Interest income..................................... - - 59 59
Interest expense.................................... - - 960 960
Depreciation, depletion and amortization............ - 4,722 2,057 6,779
Segment profit (loss)............................... 5,505 12,031 (2,295) 15,241
Other significant items:
Segment assets.................................. 7,725 150,683 69,123 227,531
- --------------
(a) Revenues and expenses from segments below the quantitative thresholds are
attributable to two operating segments of the Company. Those segments
include well services and transportation. These segments have never met any
of the quantitative thresholds for determining reportable segments.
SIX MONTHS ENDED MARCH 31, 2003 (in thousands):
Production
Well and Other
Drilling Exploration Energy (a) Total
---------- ----------- ----------- ---------
Revenues from external customers.................... $ 29,949 $ 17,485 $ 7,175 $ 54,609
Interest income..................................... - - 138 138
Interest expense.................................... - - 1,059 1,059
Depreciation, depletion and amortization........... - 3,966 1,889 5,855
Segment profit ..................................... 1,394 7,826 131 9,351
Other significant items:
Segment assets.................................. 7,332 132,034 56,318 195,684
- --------------
(a) Revenues and expenses from segments below the quantitative thresholds are
attributable to two operating segments of the Company. Those segments
include well services and transportation. These segments have never met any
of the quantitative thresholds for determining reportable segments.
17
ATLAS AMERICA, INC.
(A Wholly-Owned Subsidiary of Atlas Energy Holdings, Inc.)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
NOTE 7 - OPERATING SEGMENT INFORMATION AND MAJOR CUSTOMERS - (CONTINUED)
Operating profit (loss) per segment represents total revenues less
costs and expenses attributable thereto, including interest, provision for
possible losses and depreciation, depletion and amortization.
The Company markets its gas and oil production on a competitive basis.
Gas is sold under various types of contracts ranging from life-of-the-well to
short-term contracts. The Company is party to a ten-year agreement which expires
in March 2009 to sell the majority of its existing and future production to an
affiliate of FirstEnergy Corp., a publicly-traded company (NYSE:FE). Pricing
under the contract is tied to index-based formulas which the Company negotiates
annually. In order to hedge its gas prices over a longer period of time, the
Company recently agreed upon prices under this contract that will be effective
through March 2005. Approximately 55% of the Company's current production was
dedicated to the performance of this agreement for the six months ended March
31, 2004. Payments to the Company under the agreement are guaranteed by FEC.
The Company anticipates that it will negotiate mutually agreeable
pricing terms for subsequent 12-month periods pursuant to the aforementioned
agreement. Management believes that the loss of any one customer would not have
a material adverse effect as it believes that, under current market conditions,
the Company's production could readily be absorbed by other purchasers.
NOTE 8 - SUBSEQUENT EVENTS
On June 10, 2004, Atlas Pipeline Partners entered into a definitive
agreement to acquire Spectrum Field Services, Inc. ("Spectrum"), whose principal
assets comprise 1,900 miles of natural gas pipelines and a natural gas
processing facility in Velma, Oklahoma. The total consideration will be
approximately $140 million, including the payment of anticipated taxes due as a
result of the transaction. The transaction is expected to close in July 2004,
subject to receipt of various approvals and other customary closing conditions.
Wachovia Bank, National Association has committed to provide financing for the
acquisition of Spectrum. In addition, the Company and RAI have committed to the
purchase of up to 35.0 million in preferred units upon the closing of the
transaction.
Spectrum is a privately owned natural gas gathering and processing
company headquartered in Tulsa, Oklahoma. During 2003, Spectrum processed an
average of 48 million cubic feet per day of natural gas and produced an average
of 5,100 barrels per day of NGLs. Spectrum currently processes approximately 56
million cubic feet per day of natural gas and produces approximately 5,600
barrels per day of NGLs. The majority of Spectrum's natural gas supply is from
long-lived, mid-continent casinghead gas production.
Approximately 20% of Spectrum's revenues are generated under fee-based
arrangements whereby Spectrum receives a fee or fees for gathering, compressing,
treating or processing natural gas. The revenue it earns from these arrangements
is related to the volume of natural gas that flows through its systems and is
not dependent on commodity prices. Approximately 80% of Spectrum's revenues are
generated under percentage-of-proceeds, or POP, arrangements. Under POP
arrangements, Spectrum generally gathers and processes natural gas on behalf of
producers, sells the resulting residue gas and NGL volumes at market prices and
remits to producers an agreed upon percentage of the proceeds based on index
prices.
18
ATLAS AMERICA, INC.
(A Wholly-Owned Subsidiary of Atlas Energy Holdings, Inc.)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
NOTE 8 - SUBSEQUENT EVENTS - (CONTINUED)
On May 10, 2004, the Company completed an initial public offering of
2,300,000 shares of its common stock at a price of $15.50 per common share. The
net proceeds of the offering of $33.2 million, after deducting underwriting
discounts, was distributed to the parent in the form of a repayment of
inter-company debt and a non-taxable dividend. On June 1, 2004, the Company sold
an additional 345,000 shares, generating an additional $5.0 million of net
proceeds, pursuant to the underwriters' exercise of their over allotment option.
Following the offering, the parent continues to own approximately 80.2% of the
Company's common stock.
In April 2004, Atlas Pipeline completed a public offering of 750,000
common units of limited partner interest. The net proceeds after underwriting
discounts, commissions and estimated costs were approximately $25.0 million.
Atlas Pipeline intends to use these proceeds for the acquisition of Alaska
Pipeline. To the extent that Atlas Pipeline does not apply the proceeds to the
purchase of Alaska Pipeline, it intends to use them as working capital.
19
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS (UNAUDITED)
WHEN USED IN THIS FORM 10-Q, THE WORDS "BELIEVES" "ANTICIPATES,"
"EXPECTS" AND SIMILAR EXPRESSIONS ARE INTENDED TO IDENTIFY FORWARD-LOOKING
STATEMENTS. SUCH STATEMENTS ARE SUBJECT TO CERTAIN RISKS AND UNCERTAINTIES
INCLUDING THE FOLLOWING:
o VOLATILITY IN THE PRICE WE RECEIVE FOR NATURAL GAS WE PRODUCE;
o THE SPECULATIVE NATURE OF DRILLING NATURAL GAS WELLS;
o COMPETITION IN OBTAINING SUITABLE PROPERTIES ON WHICH TO DRILL;
o INHERENT UNCERTAINTY IN OUR ESTIMATES OF PROVED RESERVES;
o OUR NEED TO REPLENISH RESERVES TO AVOID PRODUCTION DECLINES;
o OUR ABILITY TO RAISE CAPITAL FOR OUR DRILLING PROGRAMS THROUGH
SPONSORED DRILLING INVESTMENT PARTNERSHIPS;
o POTENTIAL LOSSES FROM OUR TRANSPORTATION ARRANGEMENTS WITH ATLAS
PIPELINE PARTNERS, L.P.; AND
o ENVIRONMENTAL AND OTHER LIABILITIES THAT WE MAY INCUR AS A RESULT OF
OUR DRILLING AND TRANSPORTATION.
THESE RISKS AND UNCERTAINTIES COULD CAUSE ACTUAL RESULTS TO DIFFER
MATERIALLY. READERS ARE CAUTIONED NOT TO PLACE UNDUE RELIANCE ON THESE
FORWARD-LOOKING STATEMENTS, WHICH SPEAK ONLY AS OF THE DATE HEREOF. WE UNDERTAKE
NO OBLIGATION TO PUBLICLY RELEASE THE RESULTS OF ANY REVISIONS TO
FORWARD-LOOKING STATEMENTS WHICH WE MAY MAKE TO REFLECT EVENTS OR CIRCUMSTANCES
AFTER THE DATE OF THIS FORM 10-Q OR TO REFLECT THE OCCURRENCE OF UNANTICIPATED
EVENTS.
OVERVIEW OF THREE MONTHS AND SIX MONTHS ENDED MARCH 31, 2004 AND 2003
During the six months ended March 31, 2004 our energy operations
continued to grow as we increased our gross revenues, number of wells drilled,
number of wells operated and total reserves.
We finance our drilling operations principally through funds raised
from investors in our public and private drilling investment partnerships. The
funds we raised in the first three months of fiscal 2004 grew substantially from
those we raised in fiscal 2003. The $40.2 million raised in the first three
months of fiscal 2004 represented a 70% increase over the $23.7 million raised
in first three months of fiscal 2003.
Our gross revenues depend, to a significant extent, on the price of
natural gas which can fluctuate significantly. We seek to balance this
volatility with the more stable net income from our well drilling and well
servicing operations which are principally fee-based. Our well drilling
operations' gross margin was $3.4 million and $6.3 million for three months and
six months ended March 31, 2004, respectively.
20
Our business strategy for increasing our reserve base includes
acquisitions of undeveloped properties or companies with significant amounts of
undeveloped property. At March 31, 2004 we had $22.8 million available under our
credit facility, which could be employed to finance such acquisitions. However,
as a result of our agreements with Resource America, Inc., our ultimate parent,
relating to its proposed tax-free distribution to its stockholders of the stock
it owns in us, described below under "-Recent Developments," we will be limited
in our ability to issue voting securities, non-voting securities or convertible
debt and in making acquisitions or entering into mergers or other business
combinations that would jeopardize the tax-free status of the distribution until
such time that Resource America informs us that it will not complete the
distribution.
RECENT DEVELOPMENTS
Public Offerings
On May 10, 2004, we completed an initial public offering of 2,300,000
shares of our common stock at a price of $15.50 per common share. The net
proceeds of the offering of $33.2 million, after deducting underwriting
discounts, were distributed to our parent in the form of a repayment of
inter-company debt and a non-taxable dividend. On June 1, 2004, we sold an
additional 345,000 shares, realizing net proceeds of $5.0 million, pursuant to
the underwriters' exercise of their over-allotment option. These proceeds were
also distributed to our parent as a special dividend.
Following the offering, our parent continues to own approximately 80.2%
of our common stock. Resource America has advised us that it intends to spin-off
its remaining ownership interest in us to its common stockholders by means of a
special dividend of all of our common stock owned by Resource America. Resource
America has sole discretion if and when to complete the distribution and its
terms, and does not intend to complete the distribution unless it receives a
ruling from the Internal Revenue Service and/or an opinion from its tax counsel
as to the tax-free nature of the distribution to Resource America and its
stockholders for U.S. federal income tax purposes. The Internal Revenue Service
requirements for tax-free distributions of this nature are complex and the
Internal Revenue Service has broad discretion, so there is significant
uncertainty as to whether Resource America will be able to obtain such a ruling.
Because of this uncertainty and the fact that the timing and completion of the
distribution is in Resource America's sole discretion, we cannot assure you that
the distribution will occur by the contemplated time or at all.
For the proposed distribution of Resource America's common stock in us
to its stockholders to be tax-free to them, Resource America must, among other
things, own at least 80% of all of our voting power at the time of the
distribution. Therefore, until such time that Resource America informs us that
it will not complete the distribution, we will be limited in our ability to
issue voting securities, non-voting stock or convertible debt without Resource
America's prior consent, and Resource America may be unwilling to give that
consent. In addition, agreements that we entered into with Resource America upon
the closing of our initial public offering prohibit us from making acquisitions
or entering into mergers or other business combinations that would jeopardize
the tax-free status of the distribution.
In April 2004, our subsidiary, Atlas Pipeline Partners, L.P., completed
a public offering of 750,000 common units of limited partner interest. The net
proceeds after underwriting discounts, commissions and estimated costs were
approximately $25.0 million. Atlas Pipeline Partners intends to use these
proceeds for the acquisition of Alaska Pipeline Company from SEMCO Energy, Inc.
described under "-Pending Acquisition." To the extent that Atlas Pipeline does
not apply the proceeds to the purchase of Alaska Pipeline, it intends to use
them as working capital. As a result of this offering, our ownership interest in
Atlas Pipeline Partners was reduced to 32%.
21
Spectrum Acquisition
On June 10, 2004, Atlas Pipeline Partners entered into a definitive
agreement to acquire Spectrum Field Services, Inc. ("Spectrum"), whose principal
assets comprise 1,900 miles of natural gas pipelines and a natural gas
processing facility in Velma, Oklahoma. The total consideration will be
approximately $140 million, including the payment of anticipated taxes due as a
result of the transaction. The transaction is expected to close in July 2004,
subject to receipt of various approvals and other customary closing conditions.
Wachovia Bank, National Association has committed to provide financing for the
acquisition of Spectrum.
Spectrum is a privately owned natural gas gathering and processing
company headquartered in Tulsa, Oklahoma. During 2003, Spectrum processed an
average of 48 million cubic feet per day of natural gas and produced an average
of 5,100 barrels per day of NGLs. Spectrum currently processes approximately 56
million cubic feet per day of natural gas and produces approximately 5,600
barrels per day of NGLs. The majority of Spectrum's natural gas supply is from
long-lived, mid-continent casinghead gas production.
Approximately 20% of Spectrum's revenues are generated under fee-based
arrangements whereby Spectrum receives a fee or fees for gathering, compressing,
treating or processing natural gas. The revenue it earns from these arrangements
is related to the volume of natural gas that flows through its systems and is
not dependent on commodity prices. Approximately 80% of Spectrum's revenues are
generated under percentage-of-proceeds, or POP, arrangements. Under POP
arrangements, Spectrum generally gathers and processes natural gas on behalf of
producers, sells the resulting residue gas and NGL volumes at market prices and
remits to producers an agreed upon percentage of the proceeds based on index
prices.
22
RESULTS OF OPERATIONS: ENERGY
The following tables set forth information relating to production
revenues, daily production volumes, average sales prices, production costs as a
percentage of natural gas and oil revenues and depletion per mcfe (2) for our
energy operations during the periods indicated:
Three Months Ended Six Months Ended
March 31, March 31,
------------------------- -----------------------
2004 2003 2004 2003
------ ------ ------ ------
(in thousands, except production volume,
average sales prices, production costs and depletion
per equivalent mcfe (2))
Production revenues:
Gas (1)................................................ $ 10,116 $ 8,231 $ 19,182 $ 15,281
Oil.................................................... $ 1,666 $ 1,187 $ 2,789 $ 2,203
Production volume:
Gas (mcf/day) (1) (2).................................. 18,265 17,933 18,875 18,648
Oil (bbls/day) (2)..................................... 576 410 514 429
Total (mcfe/day) (2)................................... 21,721 20,393 21,959 21,222
Average sales prices:
Gas (per mcf).......................................... $ 6.09 $ 5.10 $ 5.55 $ 4.50
Oil (per bbl).......................................... $ 31.81 $ 32.17 $ 29.65 $ 28.24
Production costs (3):
As a percent of production revenues.................... 15% 17% 16% 18%
Per mcf equivalent unit................................ $ .91 $ .90 $ .85 $ .82
Depletion per equivalent mcfe.............................. $ 1.24 $ 1.05 $ 1.15 $ 1.00
- -----------------
(1) Excludes sales of residual gas and sales to landowners.
(2) As used in this discussion, "mcf" and mmcf" means thousand cubic feet
and million cubic feet; "mcfe" and "mmcfe" means thousand cubic feet
equivalent and million cubic feet equivalent, and "bbls" means barrels.
Bbls are converted to mcfe equivalent using the ratio of six mcfs to
one bbl.
(3) Production costs include labor to operate the wells and related
equipment, repairs and maintenance, materials and supplies, property
taxes, severance taxes, insurance, gathering charges and production
overhead.
23
Our well drilling revenues and costs and expenses incurred represent
the billings and costs associated with the completion of 157 and 123 net wells
for partnerships we sponsored in the three months ended March 31, 2004 and 2003,
respectively, and 268 and 160 net wells in the six months ended March 31, 2004
and 2003, respectively. The following table sets forth information relating to
these revenues and costs during the periods indicated:
Three Months Ended Six Months Ended
March 31, March 31,
--------------------- ---------------------
2004 2003 2004 2003
-------- --------- ------- -------
(dollars in thousands)
Average drilling revenue per well......................... $ 167 $ 190 $ 180 $ 187
Average drilling cost per well (1)........................ 145 165 157 163
--------- -------- -------- --------
Average drilling gross profit per well.................... $ 22 $ 25 $ 23 $ 24
========= ======== ======== ========
Gross profit margin....................................... $ 3,424 $ 3,048 $ 6,288 $ 3,906
========= ======== ======== ========
Gross margin percent...................................... 13% 13% 13% 13%
========= ======== ======== ========
Net wells drilled......................................... 157 123 268 160
========= ======== ======== ========
- -------------
(1) The amounts shown do not reflect the total cost of a well. The drilling
revenue and associated drilling cost reflect that portion of the total well
cost that is attributable to our investor partners in each investment
drilling program as specified in the relevant drilling contracts.
Our natural gas revenues were $10.1 million and $19.2 million in the
three months and six months ended March 31, 2004, an increase of $1.9 million
(23%) and $3.9 million (26%) from $8.2 million and $15.3 million in the three
months and six months ended March 31, 2003, respectively. The increases were due
to increases in the average sales price of natural gas of 19% and 23% for the
three months and six months ended March 31, 2004 and increases of 2% and 1% in
the volume of natural gas we produced in the three months and six months ended
March 31, 2004, respectively. The $1.9 million increase in gas revenues in the
three months ended March 31, 2004 as compared to the prior year period consisted
of a $1.6 million increase attributable to increases in natural gas sales
prices, and a $293,000 increase attributable to increased production volumes.
The $3.9 million increase in natural gas revenues in the six months ended March
31, 2004 as compared to the prior period consisted of a $3.6 million increase
attributable to an increase in natural gas sales prices, and a $335,000 increase
attributable to increased production volumes.
Our oil revenues were $1.7 million and $2.8 million in the three months
and six month periods ended March 31, 2003, an increase of $479,000 (40%) and
$586,000 (27%) from $1.2 million and $2.2 million in the three months and six
months ended March 31, 2003, primarily due to increases in oil production
volumes of 40% and 20% for the respective periods. Oil prices decreased 1%
during the three months and increased 5% during the six months ended March 31,
2004 and 2003, respectively. The $479,000 increase in oil revenues in the three
months ended March 31, 2004 as compared to the prior period consisted of
increases of $493,000 attributable to increases in oil production volumes offset
by $14,000 attributable to decreased sale prices. The $586,000 increase in oil
revenues for the six months ended March 31, 2004 as compared to the prior period
consisted of increases of $476,000 attributable to increases in production
volumes and $110,000 attributable to increased sales prices.
24
Our well drilling gross margin was $3.4 million and $6.3 million in the
three months and six months ended March 31, 2004, an increase of $376,000 and
$2.4 million from $3.0 million and $3.9 million in the three months and six
months ended March 31, 2003, respectively. In the three month ended March 31,
2004, the increase of $376,000 was attributable to an increase in the number of
wells drilled ($741,000) offset by a decrease in the gross margin per well
($365,000). In the six months ended March 31, 2004, the increase of $2.4 million
was attributable to an increase in the number of wells drilled ($2.5 million)
offset by a decrease in the gross margin per well ($152,000).
Our gross profit per well decreased as a result of a decrease in our
average cost per well which, because our drilling contracts are on a "cost plus"
basis (typically cost plus 15%), determines our average revenue per well. The
decrease in our average cost per well in the three month and six months ended
March 31, 2004 resulted from a decrease in the cost of tangible equipment used
in the wells because a portion of the wells we drilled targeted shallower
formations and required less equipment. In addition, it should be noted that
"Liabilities associated with drilling contracts" on our balance sheet represents
funds raised in our drilling investment program in the first three months of
fiscal 2004 that had not been applied to drill wells as of March 31, 2004 due to
the timing of drilling operations, and thus had not been recognized as well
drilling revenue. We expect to recognize this amount as revenue in the remainder
of fiscal 2004. Because we raised $40.2 million in the first quarter of fiscal
2004 alone, we anticipate drilling revenues and related costs to be
substantially higher than in fiscal 2003.
Our transportation revenues increased 13% in the three months and six
months ended March 31, 2004 as compared to the prior year periods. This increase
resulted from higher gross volumes transported due to the additional volumes
associated with new partnership wells drilled by us and connected to our
gathering system and an increase in the average prices received for the natural
gas transported, upon which the fees chargeable under a portion of our
transportation arrangements are based.
Our production costs were $1.8 million and $3.4 million in the three
months and six months ended March 31, 2004, an increase of $151,000 (9%) and
$253,000 (8%), respectively. These increases were attributable to increases in
repairs and maintenance due to discretionary workovers on marginal wells, and
increased transportation expenses associated with increased volumes and the
average price received for natural gas transported as a portion of our wells pay
transportation fees based on the sales price of the gas transported.
Our exploration costs were $1.5 million and $1.6 million in the three
months and six months ended March 31, 2004, an increase of $570,000 and $567,000
from the three months and six months ended March 31, 2003, respectively. These
increases were attributable to expenditures for dry hole costs of $587,000 in
the three months ended March 31, 2004 which were charged to operations upon our
decision that a well drilled in an exploratory area of our operations was not
capable of economic production.
Our depletion, depreciation and amortization costs consist mainly of
depletion of oil and gas properties and amortization of contracts acquired. Our
depletion as a percentage of oil and gas production revenues was 21% in the
three and six months ended March 31, 2004 compared to 21% and 22% in the three
and six months ended March 31, 2003. The variance from period to period is
directly attributable to changes in our oil and gas reserve quantities, product
prices, and fluctuations in the depletable cost basis of oil and gas properties.
25
Our interest expense was $473,000 and $960,000 in the three months and
six months ended March 31, 2004, an increase of $43,000 and a decrease of
$99,000 from $430,000 and $1.1 million in the three and six months ended March
31, 2003, respectively. The increase in the three months ended March 31, 2004
was primarily a result of a write-off of unamortized deferred finance costs upon
the amendment of our credit facility with Wachovia Bank. The decrease in the six
months ended March 31, 2004 was primarily a result of lower funds borrowed.
Our general and administrative expenses were $1.2 million and $2.2
million in the three months and six months ended March 31, 2004, a decrease of
$14,000 (1%) and $1.4 million (39%), respectively. The decreases were
attributable to reimbursements we received for costs we incurred in our
partnership management and drilling activities resulting from an increase in the
number of wells we drilled and managed compared to the prior year period, which
was partially offset by increases in the cost of running our energy corporate
office as a result of continued growth in our energy operations.
At March 31, 2004, we owned 39% of Atlas Pipeline Partners through both
our general partner interest and our subordinated limited partner units. As
general partner, we control Atlas Pipeline Partners; therefore we include it in
our consolidated financial statements and show the ownership by the public as a
minority interest. The minority interest in Atlas Pipeline Partners earnings was
$1.3 million and $2.6 million in the three months and six months ended March 31,
2004, as compared to $884,000 and $1.5 million in the three months and six
months ended March 31, 2003, an increase of $438,000 (50%) and $1.1 million
(70%), respectively. These increases were the result of an increase in Atlas
Pipeline Partners' net income principally caused by increases in transportation
fees received and an increase in the amount of Atlas Pipeline Partners' earnings
attributable to minority interests as a result of its May 2003 public offering.
LIQUIDITY AND CAPITAL RESOURCES
General. We fund our exploration and production operations from a
combination of cash generated by operations, capital raised through drilling
investment partnerships and, if required, use of our credit facility. We fund
our transportation operations, which are conducted through Atlas Pipeline
Partners, through a combination of cash generated by operations, Atlas Pipeline
Partners' credit facility and, in fiscal 2003, the sale of Atlas Pipeline
Partners' common units.
Six Months Ended
March 31
------------------------------
2004 2003
------------ ------------
(in thousands)
Provided by operations............................................. $ 22,513 $ 24,161
Used in investing activities....................................... (18,213) (12,255)
Used in financing activities....................................... (17,764) (4,127)
----------- -----------
$ (13,464) $ 7,779
=========== ===========
26
We had $11.9 million in cash and cash equivalents on hand at March 31,
2004, as compared to $25.4 million at September 30, 2003. Our ratio of earnings
from continuing operations before income taxes, minority interest and interest
expense to fixed charges was 19.6 to 1.0 in the six months ended March 21, 2004
as compared to 11.3 to 1.0 in the six months ended March 31, 2003. We had a
working capital deficit of $11.4 million and $2.2 million at March 31, 2004 and
September 30, 2003, respectively. The increase in our working capital deficit
was primarily due to a decrease in cash and cash equivalents at March 31, 2004
as a result of the payment of a dividend to our parent of $15.1 million in the
six months ended March 31, 2004. Our long-term debt (including current
maturities) to total capital was 49% at March 31, 2004 and 36% at September 30,
2003.
In March 2004, our available borrowings under our energy credit
facility were increased to $65.0 million from $54.2 million. At March 31, 2004,
we had $22.8 million and $20.0 million available on this energy credit facility
and Atlas Pipeline's credit facility, respectively.
Cash flows from operating activities. Cash provided by operations is an
important source of short-term liquidity for us. It is directly affected by
changes in the price of natural gas and oil, interest rates and our ability to
raise funds for our drilling investment partnerships. Net cash provided by
operating activities decreased $1.6 million in the six months ended March 31,
2004 to $22.5 million from $24.1 million in the six months ended March 31, 2003,
substantially as a result of the following:
o Changes in operating assets and liabilities decreased operating cash
flow by $10.2 million in the six months ended March 31, 2004,
compared to the six months ended March 31, 2003, primarily due to
payments during the six months ended March 31, 2004 of accounts
payable and accrued liabilities. The level of liabilities is
dependent upon the remaining amount of our drilling obligations at
any balance sheet date, which is dependent upon the timing of funds
raised through our investment partnerships.
o An increase in cash flow before depreciation and amortization of
$4.8 million in the six months ended March 31, 2004 as compared to
the prior year period principally as a result of higher gas prices.
o An increase in our deferred tax liability increased cash flow by
$2.1 million.
o An increase in minority interest of $1.1 million due to an increase
in Atlas Pipeline Partners' earnings and common units outstanding.
Cash flows from investing activities. Net cash used in our investing
activities increased $6.0 million in the six months ended March 31, 2004 to
$18.2 million from $12.2 million in the six months ended March 31, 2003 as a
result of the following:
o Capital expenditures increased $4.9 million due to an increase in
the number of wells we drilled
o Cash used on other assets decreased cash flows by $1.1 million due
to costs associated with Atlas Pipeline Partners' pending
acquisition.
Cash flows from financing activities. Net cash used in our financing
activities increased $13.6 million in the six months ended March 31, 2004 to
$17.8 million from $4.2 million in the six months ended March 31, 2003, as a
result of the following:
o We made payments to our parent of $15.1 million in the form of a
dividend and $7.9 million for the repayment of debt in the six
months ended March 31, 2004, no such payments were made in the prior
year similar period.
o Net borrowings increased cash flows by $11.3 million in the six
months ended March 31, 2004, as compared to the prior year similar
period which reflected a pay down of debt.
27
o Dividends paid to minority interests increased $1.6 million as a
result of higher earnings and more common units outstanding for
Atlas Pipeline.
Capital Requirements
During the six months ended March 31, 2004 and 2003, our capital
expenditures related primarily to investments in our drilling partnerships and
pipeline expansions, in which we invested $17.3 million and $11.7 million,
respectively. For the six months ended March 31, 2004 and the remaining quarters
of fiscal 2004, we funded and expect to continue to fund these capital
expenditures through cash on hand, borrowings under our credit facilities, and
from operations. We have established two credit facilities to facilitate the
funding of our capital expenditures. In March 2004, we obtained an increase in
our borrowing base on our credit facility administered by Wachovia Bank to $65.0
million from $54.2 million. In addition, Atlas Pipeline Partners replaced its
$15.0 million credit facility with a new $20.0 million credit facility with
Wachovia Bank.
The level of capital expenditures we must devote to our exploration and
production operations depends upon the level of funds raised through our
drilling investment partnerships. We have budgeted to raise up to $90.0 million
in fiscal 2004 through drilling partnerships. Through the six months ended March
31, 2004 we had raised $40.2 million. We believe cash flow from operations and
amounts available under our credit facility will be adequate to fund our
contributions to these partnerships. However, the amount of funds we raise and
the level of our capital expenditures will vary in the future depending on
market conditions for natural gas and other factors.
We continuously evaluate acquisitions of gas and oil and pipeline
assets. In order to make any acquisition, we believe we will be required to
access outside capital either through debt or equity placements or through joint
venture operations with other energy companies. There can be no assurance that
we will be successful in our efforts to obtain outside capital. For a discussion
of limitations on our ability to issue equity or make certain acquisitions or
business combinations, see "-Overview of Three and Six Months Ended March 31,
2004 and 2003."
CONTRACTUAL OBLIGATIONS AND COMMERCIAL COMMITMENTS
The following table summarizes our contractual obligations at March 31,
2004.
PAYMENTS DUE BY PERIOD
(IN THOUSANDS)
------------------------------------------------------------------
CONTRACTUAL CASH OBLIGATIONS: LESS THAN 1 - 3 4 - 5 AFTER 5
TOTAL 1 YEAR YEARS YEARS YEARS
-------------- ------------- --------------- ------------- --------------
Long-term debt........................... $ 40,666 $ 56 $ 40,610 $ - $ -
Secured revolving credit facilities...... - - - - -
Operating lease obligations.............. 978 539 429 10 -
Capital lease obligation................. - - - - -
Unconditional purchase obligations....... - - - - -
Other long-term obligations.............. - - - - -
----------- ----------- ----------- ----------- ---------
Total contractual cash obligations....... $ 41,644 $ 595 $ 40,659 $ 10 $ -
=========== =========== =========== =========== =========
28
AMOUNT OF COMMITMENT EXPIRATION PER PERIOD
(IN THOUSANDS)
---------------------------------------------------------------
OTHER COMMERCIAL COMMITMENTS: LESS THAN 1 - 3 4 - 5 AFTER 5
TOTAL 1 YEAR YEARS YEARS YEARS
------------ ------------- -------------- ----------- -------------
Standby letters of credit................ $ 1,695 $ 1,695 $ - $ - $ -
Guarantees............................... - - - - -
Standby replacement commitments.......... - - - - -
Other commercial commitments............. 1,414 1,414 - - -
--------- -------- ---------- --------- ----------
Total commercial commitments............. $ 3,109 $ 3,109 $ - $ - $ -
========= ======== ========== ========= ==========
CRITICAL ACCOUNTING POLICIES
The discussion and analysis of our financial condition and results of
operations are based upon our consolidated financial statements, which have been
prepared in accordance with accounting principles generally accepted in the
United States of America. The preparation of these financial statements requires
us to make estimates and judgments that affect the reported amounts of our
assets, liabilities, revenues and cost and expenses, and related disclosure of
contingent assets and liabilities. On an on-going basis, we evaluate our
estimates, including those related to provision for possible losses, deferred
tax assets and liabilities, goodwill and identifiable intangible assets, and
certain accrued liabilities. We base our estimates on historical experience and
on various other assumptions that we believe reasonable under the circumstances,
the results of which form the basis for making judgments about the carrying
values of assets and liabilities that are not readily apparent from other
sources. Actual results may differ from these estimates under different
assumptions or conditions.
For a detailed discussion on the application of policies critical to
our business operations and other accounting policies, see Note 2 of the "Notes
to Consolidated Financial Statements" included in this report.
PENDING ACQUISITION
In September 2003, Atlas Pipeline Partners entered into a purchase and
sale agreement with SEMCO Energy, Inc. pursuant to which Atlas Pipeline Partners
or its designee will purchase substantially all of the stock of SEMCO Energy's
wholly-owned subsidiary, Alaska Pipeline Company, which owns an intrastate
natural gas transmission pipeline that delivers gas to metropolitan Anchorage.
The total consideration, payable in cash at closing, will be approximately $95.0
million, subject to an adjustment based on the amount of working capital that
Alaska Pipeline has at closing.
If, as we believe will be the case, Atlas Pipeline Partners consummated
the transaction, it intends to fund the acquisition price and expenses as
follows:
o Atlas Pipeline Partners will invest $49.4 million in common equity
of the SPV. It will fund this investment with the proceeds of its
recent public offering, by borrowing all of the $20 million
available under its existing credit facility and through $4.4
million of advances from us.
o The SPV has received a commitment for a $50 million credit facility
to be administered by Wachovia Bank, National Association. It will
borrow $50 million under this facility.
29
As part of the acquisition, at closing, Alaska Pipeline and ENSTAR
Natural Gas Company, a division of SEMCO Energy which conducts its gas
distribution business in Alaska, will enter into a Special Contract for Gas
Transportation pursuant to which ENSTAR will pay a reservation fee of $943,000
per month for the use of all of the pipeline's transportation capacity plus
$.075 per thousand cubic feet, or mcf, of gas transported, for 10 years. During
2003, total gas volumes delivered through the Alaska Pipeline system averaged
approximately 147.0 million cubic feet per day. SEMCO Energy will execute a gas
transmission agreement with Alaska Pipeline pursuant to which SEMCO Energy will
be obligated to make up any difference if the Regulatory Commission of Alaska
reduces the transportation rates payable by ENSTAR pursuant to the Special
Contract.
Further, Alaska Pipeline will enter into an Operation and Maintenance
and Administrative Services Agreement with ENSTAR under which ENSTAR will
continue to operate and maintain the pipeline for at least 5 years for a fee of
$334,000 per month for the first three years. Thereafter, ENSTAR's fee will be
adjusted for inflation.
Consummation of the acquisition is subject to a number of conditions,
including receipt of governmental and non-governmental consents and approvals
and the absence of a material adverse change in Alaska Pipeline's business. The
purchase and sale agreement may be terminated by either SEMCO Energy or Atlas
Pipeline Partners if the transaction is not completed by June 16, 2004, unless
the party seeking the termination caused the delay by failing to fulfill its
obligations under the agreement. Among the required governmental authorizations
are approval of the Regulatory Commission of Alaska and expiration of the
waiting period under the Hart-Scott-Rodino Antitrust Improvements Act. Atlas
Pipeline received an early termination of the Hart-Scott-Rodino waiting period
in January 2004. On April 20, 2004, the Regulatory Commission issued an order
finding that approval of the transaction is in the public interest and
consistent with controlling law. Thereafter, SEMCO filed a "Petition for
Clarification or Alternatively Reconsideration" with the Regulatory Commission
seeking clarification or amendment of the order that SEMCO believed would make
the order comply with the regulatory approval requirements of the purchase
agreement. On June 4, 2004, the Regulatory Commission issued an order granting
SEMCO's motion for reconsideration, vacating its prior order and approving the
transfer of control of Alaska Pipeline. In its order, the Regulatory Commission
stated that it could not grant the regulatory approvals required by the purchase
agreement on the record before it and permitted the parties to request further
proceedings. Atlas Pipeline Partners notified SEMCO Energy on June 15, 2004 that
it believes SEMCO Energy has breached its obligations under the purchase
agreement and has requested that SEMCO Energy participate in the dispute
resolution procedures prescribed by the purchase agreement. The acquisition
could be delayed or prevented if the dispute is not resolved in a timely manner.
30
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
The primary objective of the following information is to provide
forward-looking quantitative and qualitative information about our potential
exposure to market risks. The term "market risk" refers to the risk of loss
arising from adverse changes in interest rates and oil and gas prices. The
disclosures are not meant to be precise indicators of expected future losses,
but rather indicators of reasonable possible losses. This forward-looking
information provides indicators of how we view and manage our ongoing market
risk exposures. All of our market risk sensitive instruments were entered into
for purposes other than trading.
GENERAL
We are exposed to various market risks, principally fluctuating
interest rates and changes in commodity prices. These risks can impact our
results of operations, cash flows and financial position. We manage these risks
through regular operating and financing activities and periodically use
derivative financial instruments.
The following analysis presents the effect on our earnings, cash flows
and financial position as if the hypothetical changes in market risk factors
occurred on March 31, 2004. Only the potential impacts of hypothetical
assumptions are analyzed. The analysis does not consider other possible effects
that could impact our business.
Interest Rate Risk. At March 31, 2004, the amount outstanding under our
credit facility had increased to $40.5 million from $31.0 million at September
30, 2003. The weighted average interest rate for this facility increased from
2.9% at September 30, 2003 to 3.3% at March 31, 2004 due to a larger portion of
our borrowings being at the bank's prime rate. Holding all other variables
constant, if interest rates hypothetically increased or decreased by 10%, our
net annual income would change by approximately $87,000.
Atlas Pipeline Partners has a $20.0 million revolving credit facility
to fund the expansion of its existing gathering systems and the acquisitions of
other gas gathering systems. In the six months ended March 31, 2004, it had no
borrowings under this facility.
Commodity Price Risk. Our major market risk exposure in commodities is
fluctuations in the pricing of our gas and oil production. Realized pricing is
primarily driven by the prevailing worldwide prices for crude oil and spot
market prices applicable to United States natural gas production. Pricing for
gas and oil production has been volatile and unpredictable for many years. To
limit our exposure to changing natural gas prices, we use hedges. Through our
hedges, we seek to provide a measure of stability in the volatile environment of
natural gas prices. Our risk management objective is to lock in a range of
pricing for expected production volumes.
We do not hold or issue derivative instruments for trading purposes.
Historically, we have entered into financial hedging activities for a portion of
our projected natural gas production. We recognize gains and losses from the
settlement of these hedges in gas revenues when the associated production
occurs. The gains and losses realized as a result of hedging are substantially
offset in the market when we deliver the associated natural gas. We determine
gains or losses on open and closed hedging transactions as the difference
between the contract price and a reference price, generally closing prices on
NYMEX. We did not settle any contracts during the six months ended March 31,
2004. We recognized losses of $544,000 on settled contracts during the six
months ended March 31, 2003. We had no open hedge transactions in place as of
March 31, 2004.
31
In addition, FirstEnergy Solutions and other third party marketers to
which we sell gas, also use financial hedges to hedge their pricing exposure and
make price hedging opportunities available to us. These transactions are similar
to NYMEX-based futures contracts, swaps and options, but also required firm
delivery of the hedged quantity. Thus, we limit these arrangements to much
smaller quantities than those projected to be available at any delivery point.
For the fiscal year ending September 30, 2004, we estimate in excess of 50% of
our produced natural gas volumes will be sold in this manner, leaving our
remaining production to be sold at contract prices in the month produced or at
spot market prices. We also negotiate with certain purchasers for delivery of a
portion of natural gas we will produce for the upcoming twelve months. The
prices under most of our gas sales contracts are negotiated on an annual basis
and are index-based. Considering those volumes already designated for the fiscal
year ending September 30, 2004, and current indices, a theoretical 10% upward or
downward change in the price of a natural gas would result in approximately a 5%
change in our projected natural gas revenues.
ITEM 4. CONTROLS AND PROCEDURES
We maintain disclosure controls and procedures that are designed to
ensure that information required to be disclosed in our Securities Exchange Act
of 1934 reports is recorded, processed, summarized and reported within the time
periods specified in the SEC's rules and forms, and that such information is
accumulated and communicated to our management, including our Chief Executive
Officer and our Chief Financial Officer, as appropriate, to allow timely
decisions regarding required disclosure. In designing and evaluating the
disclosure controls and procedures, our management recognized that any controls
and procedures, no matter how well designed and operated, can provide only
reasonable assurance of achieving the desired control objectives, and our
management necessarily was required to apply its judgment in evaluating the
cost-benefit relationship of possible controls and procedures.
Under the supervision of our Chief Executive Officer and Chief
Financial Officer and with the participation of the disclosure committee of our
parent, we have carried out an evaluation of the effectiveness of our disclosure
controls and procedures as of the end of the period covered by this report.
Based upon that evaluation, our Chief Executive Officer and Chief Financial
Officer concluded that our disclosure controls and procedures are effective.
There have been no significant changes in our internal controls over
financial reporting that has partially affected, or is reasonably likely to
materially affect, our internal control over financial reporting during our most
recent fiscal quarter.
32
PART II. OTHER INFORMATION
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
No matter was submitted to a vote of security holders during the three
months ended March 31, 2004.
ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K
(A) EXHIBITS:
Exhibit No. Description
----------- -----------
3.1 Amended and Restated Certificate of Incorporation.
3.2 Amended and Restated Bylaws.
31.1 Rule 13a-14(a)/15d-14(a) Certifications
31.2 Rule 13a-14(a)/15d-14(a) Certifications
32.1 Section 1350 Certifications
32.2 Section 1350 Certifications
(B) REPORTS ON FORM 8-K
None
33
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
undersigned, thereunto duly authorized.
ATLAS AMERICA, INC.
(REGISTRANT)
Date: June 17, 2004 By: /s/ Freddie M. Kotek
------------------------------
Freddie M. Kotek
Executive Vice President and
Chief Financial Officer
Date: June 17, 2004 By: /s/ Nancy J. McGurk
-----------------------------
Nancy J. McGurk
Senior Vice President and
Chief Accounting Officer
34