UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D. C. 20549
FORM 10-Q/A
Amendment No. 1
----------------------------
(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, 2003 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 0-13305
--------------------------
PARALLEL PETROLEUM CORPORATION
(Exact name of registrant as specified in its charter)
DELAWARE 75-1971716
(State of other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification Number)
1004 N. Big Spring, Suite 400,
Midland, Texas 79701
(Address of principal executive offices) (Zip Code)
(432) 684-3727 (Registrant's telephone number,
including area code)
NOT APPLICABLE (Former name, former address and
former fiscal year,
if changed since last report)
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
---
Indicate by check mark whether the registrant is an accelerated filer (as
defined in Rule 12b-2 of the Exchange Act).
Yes No X
---
At May 6, 2003, there were 21,143,406 shares of the Registrant's Common
Stock, $0.01 par value, outstanding.
Explanatory Note
On May 14, 2003, we filed with the Securities and Exchange Commission
our Quarterly Report on Form 10-Q for the fiscal quarter ended March 31, 2003
(the "Original Quarterly Report"). After filing the Original Quarterly Report,
KPMG LLP determined it had reviewed the Original Quarterly Report at a time when
it was not independent. As reported in our Current Report on Form 8-K, dated
December 2, 2003 and filed with the Securities and Exchange Commission on
December 9, 2003, KPMG resigned on December 2, 2003. We are filing this
Amendment No. 1 to our Original Quarterly Report because the Original Quarterly
Report has been reviewed by our new independent accountants, BDO Seidman, LLP.
Unless otherwise stated, all information contained in this amendment is as of
May 14, 2003, the filing date of our Original Quarterly Report.
INDEX
PART I. - FINANCIAL INFORMATION
Page
No.
----
ITEM 1. FINANCIAL STATEMENTS
Reference is made to the succeeding pages for the following financial
statements:
- Consolidated Balance Sheets as of December 31, 2002
and March 31, 2003(unaudited) 1
- Unaudited Consolidated Statements of Operations
for the three months ended March 31, 2002 and 2003 2
- Unaudited Consolidated Statements of Cash Flows
for the three months ended March 31, 2002 and 2003 3
- Unaudited Consolidated Statements of Comprehensive Income (Loss) 4
- Notes to Consolidated Financial Statements 5
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS 13
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT
MARKET RISK 19
ITEM 4. CONTROLS AND PROCEDURES 20
PART II. - OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS 21
ITEM 6. EXHIBIT AND REPORTS ON FORM 8-K 21
SIGNATURES
PARALLEL PETROLEUM CORPORATION
CONSOLIDATED BALANCE SHEETS
<table>
(unaudited)
December 31, March 31,
ASSETS 2002 2003
------------- --------------
<s> <c> <c>
Current assets:
Cash and cash equivalents $ 11,811,704 $ 3,834,101
Accounts receivable:
Oil and gas 3,071,315 5,045,575
Others, net of allowance for doubtful account of $12,681 in 2002 and 2003 236,443 229,540
Affiliate 2,084 -
------------- ------------
3,309,842 5,275,115
Income tax receivable 832,590 832,590
Other assets 78,675 55,125
Fair value of derivative instruments 21,884 2,784
------------- ------------
Total current assets 16,054,695 9,999,715
------------- ------------
Property and equipment, at cost:
Oil and gas properties, full cost method (Note 5) 146,679,503 152,274,021
Other 1,083,282 1,246,674
------------- ------------
147,762,785 153,520,695
Less accumulated depreciation and depletion (62,074,559) (63,746,018)
------------- ------------
Net property and equipment (Note 8) 85,688,226 89,774,677
------------- ------------
Other assets, net of accumulated amortization of $78,520 in 2002 and $43,996 in 2003 608,410 585,626
------------- ------------
$102,351,331 $100,360,018
============= ============
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities:
Accounts payable and accrued liabilities $ 3,033,650 $ 2,866,239
Current maturities of long-term debt (Note 2) 4,145,833 5,700,000
Current maturity of derivative obligations 335,829 1,286,654
------------- ------------
7,515,312 9,852,893
------------- ------------
Long-term debt, excluding current maturities (Note 2) 45,604,167 37,050,000
Long-term asset retirement obligation (Note 8) - 1,727,165
Long-term maturity of derivative obligations (Note 6) 103,745 1,188,086
Deferred tax liability 3,627,963 4,158,344
Stockholders' equity:
Series A preferred stock -- par value $.10 per share (aggregate liquidation
preference of $26)
authorized 50,000 shares - -
Preferred stock -- $.60 cumulative convertible preferred
stock -- par value of $.10 per share (aggregate liquidation
preference of $10) authorized 10,000,000 shares, issued
and outstanding 974,500 in 2002 and 2003 97,450 97,450
Common stock -- par value $.01 per share, authorized 60,000,000
shares, issued and outstanding 21,143,406 in 2002 and 2003 211,434 211,434
Additional paid-in capital 34,567,866 34,421,691
Retained earnings 10,623,394 12,875,148
Other comprehensive income (loss) net of tax (Note 6) - (1,222,193)
------------- ------------
Total stockholders' equity 45,500,144 46,383,530
Commitments and contingencies (Note 11)
------------- ------------
$102,351,331 $100,360,018
============= ============
</Table>
*The balance sheet as of December 31, 2002 has been derived from Parallel's
audited financial statements. The accompanying notes are an integral part of
these financials.
1
PARALLEL PETROLEUM CORPORATION
CONSOLIDATED STATEMENTS OF OPERATIONS
(Unaudited)
<table>
Three Months Ended March 31,
------------------------------
2002 2003
------------ -----------
<s> <c> <c>
Oil and gas revenues $ 1,971,191 $ 8,492,792
------------ -----------
Cost and expenses:
Lease operating expense (Note 8) 549,376 1,455,660
General and administrative 349,764 801,768
Depreciation, depletion and amortization 1,354,630 2,065,691
----------- -----------
Total costs and expenses 2,253,770 4,323,119
----------- -----------
Operating income (loss) (282,579) 4,169,673
----------- -----------
Other income (expense), net:
Equity in loss of First Permian, L.P. (316,293) -
Change in fair market value of derivatives (Note 6) (339,858) (202,457)
Interest and other income 16,375 44,656
Interest expense (153,057) (486,464)
Other expense (172,066) (20,544)
----------- -----------
Total other expense, net (964,899) (664,809)
----------- -----------
Income (loss) before income taxes (1,247,478) 3,504,864
Income tax (expense) benefit, net 478,727 (1,191,654)
----------- -----------
Net income (loss) before cumulative effect of change in accounting principle (768,751) 2,313,210
Cumulative effect on prior years of a change in accounting principle, less
applicable income taxes of $31,659 (Note 8) - (61,456)
----------- -----------
Net income (loss) (768,751) 2,251,754
Cumulative preferred stock dividend (146,175) (146,175)
----------- -----------
Net income (loss) available to common stockholders $ (914,926) $ 2,105,579
=========== ===========
Net income (loss) per common share:
Basic - before cumulative effect of a change in accounting principal $ (0.04) $ 0.10
Cumulative effect of a change in accounting principle, net of tax - -
----------- -----------
Basic - after cumulative effect of a change in acocounting principle $ (0.04) $ 0.10
=========== ===========
Diluted - before cumulative effect of a change in accounting principle $ (0.04) $ 0.09
Cumulative effect of a change in accounting principle, net of tax - -
----------- -----------
Diluted - after cumulative effect of a change in accounting principle $ (0.04) $ 0.09
=========== ===========
Weighted average common share outstanding:
Basic 20,663,861 21,143,406
=========== ===========
Diluted 20,663,861 24,038,049
=========== ===========
</table>
The accompanying notes are an integral part of these financials.
2
PARALLEL PETROLEUM CORPORATION
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
<table>
Three Months Ended March 31,
------------------------------
2002 2003
---------- -----------
<s> <c> <c>
Cash flows from operating activities:
Net income (loss) $ (768,751) $ 2,251,754
Adjustments to reconcile net income (loss) to net cash provided by operating
activities:
Depreciation and depletion 1,354,630 2,065,691
Accretion expense - 33,835
Equity in loss from investments in First Permian, L.P. 316,293 -
Change in fair value of derivative instruments 339,859 202,457
Deferred income taxes (478,727) 1,191,654
Cumulative effect on prior years of a change in accounting principle, net of tax - 61,456
Changes in assets and liabilties:
Other, net (11,865) 22,784
Decrease (increase) in accounts receivables 161,584 (1,965,273)
Decrease in prepaid expenses and other 95,571 23,550
Decrease in accounts payable and accrued liabilities (864,538) (313,586)
Purchase of derivative instruments (391,105) -
---------- ------------
Net cash provided by (used in) operating activities (247,049) 3,574,322
---------- ------------
Cash flows from investing activities:
Additions to property and equipment (2,785,855) (4,572,325)
Proceeds from disposition of property and equipment 365,380 20,400
---------- ------------
Net cash used in investing activities (2,420,475) (4,551,925)
---------- ------------
Cash flows from financing activities:
Borrowings from bank line of credit 565,589 3,173,625
Payments on bank line of credit - (10,173,625)
---------- ------------
Net cash provided by (used in) financing activities 565,589 (7,000,000)
---------- ------------
Net increase (decrease) in cash and cash equivalents (2,101,935) (7,977,603)
Beginning cash and cash equivalents 3,351,044 11,811,704
---------- ------------
Ending cash and cash equivalents $1,249,109 $ 3,834,101
========== ============
Non-cash financing and investing activities:
Oil and gas properties - FASB 143 - $ 1,205,985
Accrued preferred stock dividend $ 146,175 $ 146,175
</table>
The accompany notes are an integral part of these financials.
3
PARALLEL PETROLEUM CORPORATION
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
(unaudited)
<table>
THREE MONTHS ENDED MARCH 31,
----------------------------------
2002 2003
------------ -----------
<s> <c> <c>
Net income (loss) $ (768,751) $ 2,251,754
Oil and natural gas derivatives adjustments, net of tax - (1,222,193)
----------- -----------
Comprehensive income (loss), net of tax $ (768,751) $ 1,029,561
=========== ===========
</table>
The accompanying notes are an integral part of these financials.
4
PARALLEL PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NOTE 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Basis of Presentation
The financial information included herein is unaudited. However, such
information includes all adjustments (consisting solely of normal recurring
adjustments), which are, in the opinion of management, necessary for a fair
statement of the results of operations for the interim periods. The results of
operations for the interim period are not necessarily indicative of the results
to be expected for an entire year.
Certain information and footnote disclosures normally included in financial
statements prepared in accordance with generally accepted accounting principles
have been condensed or omitted in this Form 10-Q/A Report pursuant to certain
rules and regulations of the Securities and Exchange Commission. These financial
statements should be read with the financial statements and notes included in
Parallel's 2002 Form 10-K Report.
Parallel accounts for stock-based compensation utilizing the intrinsic
value method prescribed by Accounting Principles Board Opinion No. 25
"Accounting for Stock Issued to Employees" ("APB 25") and related
interpretations. The following pro forma information, as required by Statement
of Financial Accounting Standards No. 123 "Accounting for Stock-Based
Compensation" (SFAS 123") as amended by Statement of Financial Accounting
Standards No. 148 ("SFAS 148"), presents net income and earnings per share
information as if the stock options issued since May 2, 2002 were accounted for
using the fair value method. The fair value of stock options issued for each
year was estimated at the date of grant using the Black-Scholes option pricing
model. No options were granted during quarter ending March 31, 2003.
The SFAS 123 pro forma information for the three months ended March 31,
2002 and 2003 is as follows:
<table>
Three Months Ended
March 31,
--------------------------
2002 2003
----------- ----------
<s> <c> <c>
Net income (loss), as reported $ (768,751) $ 2,251,754
Add: Stock-based employee compensation expense
included in net income (loss), net of tax - -
Deduct: Stock-based employee compensation expense
determined under fair value based method (SFAS 123),
net of tax (376,700) (47,658)
----------- -----------
Net income (loss), pro forma $(1,145,451) $ 2,204,096
=========== ===========
Basic:
Net income (loss) per common share, as reported $ (0.04) $ 0.10
=========== ===========
Net income (loss) per common share, pro forma $ (0.06) $ 0.10
=========== ===========
Diluted:
Net income (loss) per common share, as reported $ (0.04) $ 0.09
=========== ===========
Net income (loss) per common share, pro forma $ (0.06) $ 0.09
=========== ===========
</table>
5
NOTE 2. LONG TERM DEBT
Long-term debt consists of the following at March 31, 2003:
<table>
<s> <c>
Revolving Facility note payable to bank, at bank's base lending rate
(4.5% at March 31, 2003)
$42,750,000
Less: current maturities 5,700,000
-----------
$37,050,000
===========
</table>
Scheduled maturities of long-term debt at March 31, 2003 are as follows:
<table>
<s> <c>
2003 $ 3,562,500
2004 8,550,000
2005 8,550,000
2006 8,550,000
2007 8,550,000
2008 4,987,500
-----------
$42,750,000
===========
</table>
Revolving Credit Facility. On July 19, 2002, Parallel entered into a loan
agreement with First American Bank SSB to refinance its outstanding
indebtedness. Under the facility, Parallel may borrow the lesser of $100,000,000
or the "borrowing base" then in effect. The loan agreement was amended and
restated on December 20, 2002. The facility became syndicated with First
American Bank SSB as the Joint Lead Arranger and Administrative Agent, BNP
Paribas as Joint Lead Arranger and Syndication Agent, and Western National Bank
as a Lender. The borrowing base at March 31, 2003, was $43,000,000 which at that
date was collateralized with Parallel's oil and gas reserves. The total
outstanding principal amount of Parallel's bank indebtedness at March 31, 2003
was $42,750,000, including $250,000 reserved for our Letters of Credit thus
fully utilizing our borrowing base. Borrowings attributable to the oil and gas
reserves are subject to redetermination semi-annually, on or about May 1 and
November 1 of each year, beginning May 1, 2003. The bank may require a
redetermination of the borrowing base and monthly commitment reduction at any
time in its sole discretion. Monthly Commitment Reductions begin August 31, 2003
in an amount equal to the amount of the borrowing base on the day immediately
preceeding the date of each such Monthly Commitment Reduction divided by the
number of months then remaining prior to July 31, 2008. All indebtedness under
the new Revolving Facility matures December 20, 2006.
The unpaid principal balance for the Revolving Facility bears interest at
the election of Parallel at a rate equal to (i) the bank's base lending rate, or
(ii) the libor rate plus a libor margin of
2.75% per annum whenever the Borrowing Base Usage is equal to or
greater than 75%;
2.50% per annum whenever the Borrowing Base Usage is equal to or
greater than 50% but less than 75%;
2.25% per annum whenever the Borrowing Base Usage is less than 50%.
6
However, the interest rate may never be less than 4.50%. Interest is due
and payable on the day which the related libor interest period ends.
Parallel is required to pay a commitment fee of one-quarter of one percent
times the daily average of the unadvanced amount of the commitment. The
commitment fee is payable quarterly in arrears on the last day of each calendar
quarter beginning March 31, 2003.
In addition to customary affirmative covenants, the loan agreement contains
various restrictive covenants and compliance requirements, including:
. Maintaining certain financial requirements;
. Limitation on additional indebtedness;
. Prohibiting the payment of dividends on our common stock;
. Limitations on the disposition of assets;
. Prohibiting liens (other than in favor of the bank) to exist on any of
our properties;
. Limitations on investments, mergers, forming subsidiaries, affiliate
transactions, changes in accounting methods, rental and lease payments
and derivative transactions
. Limitations on the purchase, redemption or retirement of stock; and
. Limitations on hedging activities.
NOTE 3. PREFERRED STOCK
We have outstanding 974,500 shares of 6% Convertible Preferred Stock, $0.10
par value per share. Cumulative annual dividends of $0.60 per share are payable
semi-annually on June 15 and December 15 of each year. Each share of Convertible
Preferred Stock may be converted, at the option of the holder, into 2.8571
shares of common stock at an initial conversion price of $3.50 per share,
subject to adjustment in certain events. The Convertible Preferred Stock has a
liquidation preference of $10 per share and has no voting rights, except as
required by law. We may redeem the preferred stock, in whole or part, for $10
per share plus accrued and unpaid dividends.
NOTE 4. INCOME TAX LIABILITY
For the three months ended March 31, 2003, we recorded income tax expense
of $1,191,654 resulting in a net deferred tax liability of $4,158,344. The
income tax expense was largely due to Parallel generating taxable income in the
current period.
NOTE 5. FULL COST CEILING TEST
We use the full cost method to account for our oil and gas producing
activities. Under the full cost method of accounting, the net book value of oil
and gas properties, less related deferred income taxes, may not exceed a
calculated "ceiling". The ceiling limitation is the discounted estimated
after-tax future net revenues from proved oil and gas properties. In calculating
future net revenues, current prices and costs are generally held constant
indefinitely. The net book value, less related deferred income taxes, is
compared to the ceiling on a quarterly and annual basis. Any excess of the net
book value, less related deferred income taxes, is generally written off as an
expense. Under rules and regulations of the SEC, the excess above the ceiling is
not written off if, subsequent to the end of the quarter or year but prior to
the release of the financial results, prices increased sufficiently such that an
excess above the ceiling would not have existed if the increased prices were
used in the calculations.
7
At March 31, 2003 our net book value of oil and gas properties, less
related deferred income taxes, was below the calculated ceiling. As a result, we
were not required to record a reduction of our oil and gas properties under the
full cost method of accounting at that time.
Under the full cost accounting method, all costs incurred in the
acquisition, exploration and development of oil and natural gas properties,
including a portion of our overhead, are capitalized. In the three month period
ended March 31, 2003 overhead costs capitalized were $263,607.
NOTE 6. DERIVATIVE INSTRUMENTS
On May 24, 2002 we purchased put floors on volumes of 100,000 Mcf gas per
month for a total of 700,000 Mcf during the seven month period from April 2003
through October 2003 at a floor price of $3.00 per Mcf for a total consideration
of approximately $139,500. These derivatives are not held for trading purposes.
A decrease in fair value of the put floors of $19,100 was recognized for
the three months ended March 31, 2003 in the Consolidated Statements of
Operations.
The following table illustrates our put options.
<table>
Fair Value
Floor at
Period Commodity Mcf Volume Price Cost of Floor March 31, 2003
- --------------------------------- ------------- -------------- -------- ----------------- --------------------
<s> <c> <c> <c> <c> <c>
April 2003 thru October 2003 natural gas 700,000 $ 3.00 $ 139,500 $ 2,784
</table>
For the year ended December 31, 2002, we used mark-to-market accounting for
our hedge contracts. As of January 1, 2003 Parallel adopted hedge accounting for
the costless collars, oil and gas swaps, and interest note swaps described
below. The purpose of the hedge is to provide a measure of stability in our oil
and gas prices and interest rate payments and to manage exposure to commodity
price risk under existing sales contracts. Parallel's objective is to lock in a
range of oil and gas prices and a fixed interest rate for certain notional
amounts. This allows Parallel to forecast cash flows within a predictable range.
During the terms of the hedge, the quarterly change in the fair value of
the derivatives will be recorded in stockholders' equity as other comprehensive
income (loss) and then reclassified to earnings when the production is sold.
Ineffective portions of such hedges (changes in realized prices that do not
match the changes in the hedge price) are recognized in earnings as they occur.
While the hedge contract is open, the ineffective gain or loss may increase or
reverse until settlement of the contract. As of March 31, 2003 there was no
ineffective portion of the natural gas and interest rate hedges. On March 31,
2003 we recorded a charge of $183,357 to Other Income (expense) for the
ineffective portion of the crude oil hedges.
As of the quarter ended March 31, 2003, Parallel has reversed $1,061,925
from other compensation income (loss) and charged to earnings. During the twelve
month period ended March 31, 2004, Parallel expects approximately $717,622 to be
reversed out of other comprehensive income (loss) and recorded to earnings.
8
We are exposed to credit risk in the event of nonperformance by BNP Paribas
in its derivative instruments. However, we periodically assess its credit
worthiness to mitigate this credit risk.
Costless Collar
Collars are created by purchasing puts to establish a floor price and then
selling a call which establishes a maximum amount the producer will receive for
the oil or gas hedged. Calls are sold to offset or reduce the premium paid for
buying the put. In January, 2003, we entered into a costless, seven-month
Houston ship channel gas collar. Under terms of the gas collar, we will receive
no less than $4.25 per MMBtu and no greater than $5.30 per MMBtu for the
seven-month period of April, 2003 through October, 2003. A majority of our
natural gas production is sold based on Houston ship channel prices. A recap for
the period of time, number of MMBtu's and average gas prices is as follows:
<table>
Houston Ship Channel
gas prices
----------------------------
MMBtu of
Period of Time Natural Gas Floor Cap
- ------------------------------------- --------------- ------------- --------------
<s> <c> <c> <c>
April 1, 2003 thru October 31, 2003 642,000 $ 4.25 $ 5.30
</table>
Swaps
Generally, swaps are an agreement to buy or sell a specified commodity for
delivery in the future, but at an agreed fixed price. Swap transactions convert
a floating price into a fixed price. For any particular swap transaction, the
counterparty is required to make a payment to the hedge party if the reference
price for any settlement period is less than the swap price for such hedge, and
the hedge party is required to make a payment to the counterparty if the
reference price for any settlement period is greater than the swap price for
such hedge.
In January and February, 2003, we entered into additional oil and gas swap
contracts with BNP Paribas. A recap for the period of time, number of MMBtu's,
number of barrels, and swap prices are as follows:
<table>
Houston Ship
Barrels of Nymex Oil MMBtu of Channel
Period of Time Oil Swap Prices Natural Gas Gas Swap Price
- -------------------------------------------- ------------ --------------- ------------- -----------------
<s> <c> <c> <c> <c>
February 1, 2003 thru March 31, 2003 88,500 $ 33.00 - $ -
March 1, 2003 thru March 31, 2003 - $ - 279,000 $ 5.45
April 1, 2003 thru October 31, 2003 - $ - 214,000 $ 4.87
April 1, 2003 thru October 31, 2003 - $ - 428,000 $ 4.83
April 1, 2003 thru December 31, 2003 275,000 $ 24.58 - $ -
January 1, 2004 thru December 31, 2004 329,400 $ 23.19 - $ -
January 1, 2005 thru December 31, 2005 292,000 $ 22.77 - $ -
January 1, 2006 thru December 20, 2006 265,500 $ 23.04 - $ -
</table>
9
Interest Rate Swaps
In January, 2003, we entered into a 45-month libor fixed interest rate swap
contract with BNP Paribas. We will receive a fixed interest rate, as noted on
the table below, for the 45-month period beginning March 31, 2003 through
December 20, 2006.
Under our credit facility, we may elect an interest rate based upon the
agent lender's base lending rate, or the libor rate, plus a margin ranging from
2.25% to 2.75% per annum, depending on our borrowing base usage. The interest
rate we are required to pay, including the applicable margin, may never be less
than 4.50%.
A recap for the period of time, notional amounts, libor fixed interest
rates, expected margin rates and expected fixed interest rates for the contract
are as follows:
<table>
Libor Expected Expected
Notional Fixed Margin Fixed
Period of Time Amounts (1) Interest Rates (2) Rates (3) Interest Rates (4)
- ----------------------------------------------- ----------------- ------------------- ----------- ------------------
<s> <c> <c> <c> <c>
March 31, 2003 thru December 31, 2003 $ 35,000,000 1.675% 2.750% 4.425%
December 31, 2003 thru December 31, 2004 $ 30,000,000 2.660% 2.500% 5.160%
December 31, 2004 thru December 31, 2005 $ 20,000,000 4.050% 2.250% 6.300%
December 31, 2005 thru December 20, 2006 $ 10,000,000 4.050% 2.250% 6.300%
</table>
(1) Based on the anticipated principal reductions under our credit
facility.
(2) Parallel's swap contract with BNP Paribas.
(3) Based on the anticipated borrowing base usage under our credit
facility.
(4) Total of the libor fixed interest rate plus the expected margin rate
under our credit facility. Our loan agreement requires the interest
rate to not be below 4.50%.
10
NOTE 7. NET INCOME PER COMMON SHARE
Basic income per share is computed by dividing income available to common
stockholders by the weighted average number of common shares outstanding for the
period. Diluted income per share reflects the assumed conversion of all
potentially dilutive securities.
<table>
Three Months Ended
March 31,
-------------------------------
2002 2003
------------- --------------
<s> <c> <c>
Basic EPS Computation:
Numerator-
Net income (loss) before cumulative effect of a change
in accounting principle $ (768,751) $ 2,313,210
Cumulative effect of a change in accounting principle, net of tax - (61,456)
------------ -------------
(768,751) 2,251,754
Preferred stock dividend (146,175) (146,175)
------------ -------------
Net income (loss) available to common stockholders $(914,926) $ 2,105,579
============ =============
Denominator-
Weighted average common shares outstanding 20,663,861 21,143,406
============ =============
Basic EPS:
Net income (loss) before cumulative effect of a change $ (0.04) $ 0.10
in accounting principle
Cumulative effect of a change in accounting principle, net of tax - -
------------ -------------
Net income (loss) $ (0.04) $ 0.10
============ =============
Diluted EPS Computation:
Numerator-
Net income (loss) before cumulative effect of a change $ (768,751) $ 2,313,210
in accounting principle
Cumulative effect of a change in accounting principle, net of tax - (61,456)
------------ -------------
(768,751) 2,251,754
Preferred stock dividend (146,175) -
------------ -------------
Net income available to common stockholders $ (914,926) $ 2,251,754
============ =============
Weighted average common shares outstanding 20,663,861 21,143,406
Employee stock options - 110,399
Preferred stock - 2,784,244
------------ -------------
Weighted average common shares for diluted earnings (loss)
per share assuming conversion 20,663,861 24,038,049
============ =============
Diluted EPS:
Net income (loss) before cumulative effect of a change $ (0.04) $ 0.09
in accounting principle
Cumulative effect of a change in accounting principle, net of tax - -
------------ -------------
Net income (loss) $ (0.04) $ 0.09
============ =============
</table>
11
Convertible preferred stock equivalent shares for the three-month period
ended March 31, 2002 that could potentially dilute basic earnings per share in
the future were not included in the computation of diluted earnings per share
because to do so would have been anti-dilutive.
NOTE 8: ASSET RETIREMENT OBLIGATIONS
On January 1, 2003 Parallel adopted Statement of Financial Accounting
Standards No. 143, Accounting for Asset Retirement Obligations "SFAS 143".
Adoption of SFAS 143 is required for all companies with fiscal years beginning
after June 15, 2002. The new standard requires Parallel to recognize a liability
for the present value of all legal obligations associated with the retirement of
tangible long-lived assets and capitalize an equal amount as a cost of the asset
depreciating the additional cost through the unit-of-production method on the
life of the asset. Parallel recorded additional oil and gas property costs of
approximately $1,205,985, a reduction in accumulated depletion of $394,230, a
non current liability of $1,693,330 and an after tax charge of approximately
$61,456 for the cumulative effect on prior years for depreciation and accretion
expense on the liability related to expected abandonment costs of its oil and
natural gas properties. The accretion expense for the current quarter is
approximately $33,835 and recorded as a charge to lease operating expense with a
corresponding additional long-term liability.
The following table summarizes Parallel's asset retirement obligation
transactions during the three months ended March 31, 2003.
<table>
Three Months Ended
March 31, 2003
-------------------
<s> <c>
Asset retirement obligation January 1, 2003 $ 1,693,330
Accretion expense 33,835
-------------------
Ending asset retirement obligation $ 1,727,165
===================
</table>
Prior years pro forma were not shown since the change was not significant.
NOTE 9: RECENTLY ANNOUNCED ACCOUNTING PRONOUNCEMENTS
SFAS No. 148, Accounting for Stock-Based Compensation-Transition and
Disclosure, which amends SFAS No. 123, Accounting for Stock-Based Compensation.
SFAS No. 148 provides alternative methods of transition for a voluntary change
to the fair value based method of accounting for stock-based employee
compensation. The statement also amends the disclosure requirements of SFAS No.
123 to require prominent disclosures in both annual and interim financial
statements about the method of accounting for stock-based employee compensation
and the effect of the method used on reported results. The statement is required
to be adopted for fiscal years ending after December 15, 2002.
Parallel currently accounts for stock-based compensation in accordance with
APB Opinion No. 25 which allows Parallel to recognize compensation expense only
to the extent that the fair market value is greater than the option price.
12
On April 22, 2003, the FASB announced its decision to require all companies
to expense the value of employee stock options. Companies will be required to
measure the cost according to the fair value of the options. The new guidelines
have not been released to measure the cost according to the fair value of the
options. Although the new guidelines have not been released, it is expected that
they will be finalized and become effective in 2004. When final rules are
announced, Parallel will assess the impact to our financial statements.
FIN No. 45, Guarantor's Accounting and Disclosure Requirements for
Guarantees, Including Indirect Guarantees of Indebtedness of Others, FIN No. 45
requires that a liability be recorded in the guarantor's balance sheet upon
issuance of certain guarantees. Initial recognition and measurement of the
liability will be applied on a prospective basis to guarantees issued or
modified after December 31, 2002. FIN No. 45 also requires disclosures about
guarantees in financial statements for interim or annual periods ending after
December 15, 2002. Parallel does not expect the adoption of FIN No. 45 to have a
material impact on our consolidated financial statements.
FIN No. 46, Consolidation of Variable Interest Entities, an Interpretation
of Accounting Research Bulletin No. 51. FIN No. 46 requires certain variable
interest entities to be consolidated by the primary beneficiary of the entity if
the equity investors in the entity do not have the characteristics of a
controlling financial interest or do not have sufficient equity at risk for the
entity to finance its activities without financial support from other parties.
Parallel does not expect the adoption of FIN No. 46 to have a material impact on
our consolidated financial statements.
A reporting issue has arisen regarding the application of certain
provisions of SFAS No. 141 and SFAS No. 142 to companies in the extractive
industries, including oil and gas companies. The issue is whether SFAS No. 142
requires registrants to classify the costs of mineral rights held under lease or
other contractual arrangements associated with extracting oil and gas as
intangible assets in the balance sheet, apart from other capitalized oil and gas
property costs, and provide specific footnote disclosures. Historically,
Parallel has included the costs of such mineral rights associated with
extracting oil and gas as a component of oil and gas properties. If it is
ultimately determined that SFAS No. 142 requires oil and gas companies to
classify costs of mineral rights held under lease or other contractual
arrangement associated with extracting oil and gas as a separate intangible
assets line item on the balance sheet, Parallel would be required to reclassify
approximately $16.0 million at March 31, 2003 and $13.5 million at December 31,
2002 out of Oil and Gas Properties and into a separate intangible assets line
item. Parallel's cash flows and results of operations would not be affected
since such intangible assets would continue to be depleted and assessed for
impairment in accordance with full-cost accounting rules.
NOTE 10. COMMITMENTS AND CONTINGENCIES
At March 31, 2003, we were involved in one lawsuit incidental to our
business. In the opinion of management, the ultimate outcome of this lawsuit
will not have a material adverse effect on Parallel's financial position or
results of operations. We are not aware of any other threatened litigation. We
have not been a party to any bankruptcy, receivership, reorganization,
adjustment or similar proceeding.
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS.
The following discussion and analysis should be read in conjunction with
our Financial Statements and the related notes.
13
OVERVIEW
Strategy
Parallel's primary objective will be to increase the shareholder value of
its common stock through increasing reserves, production, cash flow and
earnings. Parallel is shifting the balance of its investments from properties
having high rates of production in early years to properties with more
consistent production over a longer term. Parallel is reducing its drilling
risks by dedicating a smaller portion of its capital to high risk projects,
while reserving the majority of its available capital for exploitation and
development drilling opportunities. Obtaining positions in long-lived oil and
gas reserves will be given priority over properties that might provide more cash
flow in the early years of production, but which have shorter reserve lives.
Parallel will also reduce risk by emphasizing acquisition possibilities over
high risk exploration projects.
During the latter part of 2002, we reduced the emphasis on high risk
exploration efforts and started focusing on established geologic trends where we
can utilize the engineering, operational, financial and technical expertise of
our entire staff. Although we anticipate participating in exploratory drilling
activities in the future, reducing financial, reservoir, drilling and geological
risks and diversifying our property portfolio are important criteria in the
execution of our business plan. In summary, Parallel's new business plan will:
. focus on projects having less geological risk;
. entails less exploratory activity in the down dip Wilcox trend of our
south Texas properties;
. emphasize exploitation and enhancement activities;
. focus on acquiring producing properties; and
. expand the scope of our operations by diversifying our exploratory and
development efforts, both in and outside of our current areas of
operation.
Although the direction of Parallel's exploration and development activities
has shifted from high risk exploratory activities to lower risk development
opportunities, Parallel will continue its efforts, as it has in the past, to
maintain low general and administrative expenses relative to the size of its
overall operations, utilize advanced technologies, serve as operator in
appropriate circumstances, and reduce operating costs.
The extent to which Parallel is able to implement and follow through with
its business plan will be influenced by:
. the prices it receives for the oil and gas it produces;
. the results of reprocessing and reinterpreting its 3-D seismic data;
. the results of its drilling activities;
. the costs of obtaining high quality field services;
. its ability to find and consummate acquisition opportunities; and
. its ability to negotiate and enter into work to earn arrangements,
joint venture or other similar agreements on terms acceptable to
Parallel.
Significant changes in the prices Parallel receives for its oil and gas,
drilling results, or the occurrence of unanticipated events beyond Parallel's
control may cause it to defer or deviate from its business plan, including the
amounts it has budgeted for its activities.
Operating Performance. Our operating performance is influenced by several
factors, the most significant of which are the prices we receive for our oil and
gas and production volumes. The world
14
price for oil has overall influence on the prices we receive for our oil
production. The prices received for different grades of oil are based upon the
world price for oil, which is then adjusted based upon the particular grade.
Typically, light oil is sold at a premium, while heavy grades of crude are
discounted. Gas prices we receive are primarily influenced by seasonal demand,
weather, hurricane conditions in the Gulf of Mexico, availability of pipeline
transportation to end users and proximity of our wells to major transportation
pipeline infrastructure and, to a lesser extent, world oil prices. Additional
factors influencing our operating performance include production expenses,
overhead requirements, and cost of capital.
Our oil and gas exploration, development and acquisition activities require
substantial and continuing capital expenditures. Historically, the sources of
financing to fund our capital expenditures have included:
. cash flow from operations,
. sales of our equity securities,
. bank borrowings, and
. industry joint ventures
For the three months ended March 31, 2003, the sales price we received for
our crude oil production (excluding hedges) averaged $32.60 per barrel compared
with $26.66 per barrel for the three months ended December 31, 2002 and $21.20
per barrel for the three months ended March 31, 2002. The average sales price we
received for natural gas for the three months ended March 31, 2003 (excluding
hedges), was $5.82 per mcf compared with $4.17 per mcf for the three months
ended December 31, 2002 and $2.25 per mcf for the three months ended March 31,
2002.
Our oil and gas producing activities are accounted for using the full cost
method of accounting. Under this method, we capitalize all costs incurred in
connection with the acquisition of oil and gas properties and the exploration
for and development of oil and gas reserves. See Note 5 to Financial Statements.
These costs include lease acquisition costs, geological and geophysical
expenditures, costs of drilling both productive and non-productive wells, and
overhead expenses directly related to land and property acquisition and
exploration and development activities. Proceeds from the disposition of oil and
gas properties are accounted for as a reduction in capitalized costs, with no
gain or loss recognized unless the disposition involves a material change in
reserves, in which case the gain or loss is recognized.
Depletion of the capitalized costs of oil and gas properties, including
estimated future development costs, is provided using the equivalent
unit-of-production method based upon estimates of proved oil and gas reserves
and production, which are converted to a common unit of measure based upon their
relative energy content. Unproved oil and gas properties are not amortized, but
are individually assessed for impairment. The cost of any impaired property is
transferred to the balance of oil and gas properties being depleted.
RESULTS OF OPERATIONS
Our business activities are characterized by frequent, and sometimes
significant, changes in our:
. sources of production;
. product mix (oil vs. gas volumes); and
. the prices we receive for our oil and gas production.
15
Year-to-year or other periodic comparisons of the results of our operations
can be difficult and may not accurately describe our condition. A BOE means one
barrel of oil equivalent using the ratio of six Mcf of gas to one barrel of oil.
<table>
---------------------------------------------
12/31/2002 3/31/2002 3/31/2003
-------------- ------------- --------------
<s> <c> <c> <c>
Production and prices:
Oil (Bbls) 39,071 30,161 153,578
Natural gas (Mcf) 853,074 590,650 781,751
Equivalent barrels of oil (BOE) 181,250 128,603 283,870
Equivalent barrels of oil (BOE) per day 2,014 1,429 3,154
Prices:
Bbls (unhedged) $ 26.66 $ 21.20 $ 32.60
Bbls (hedged) $ 31.80
Mcf (unhedged) $ 4.17 $ 2.25 $ 5.82
Mcf (hedged) $ 4.62
BOE (unhedged) $ 25.47 $ 15.33 $ 33.66
BOE (hedged) $ 29.92
</table>
CRITICAL ACCOUNTING POLICIES AND PRACTICES
Full Cost. Parallel accounts for its oil and natural gas exploration and
development activities using the full cost method of accounting. Under this
method, all costs incurred in the acquisition, exploration and development of
oil and natural gas properties are capitalized. Costs of nonproducing
properties, wells in process of being drilled and significant development
projects are excluded from depletion until such time as the related project is
developed and proved reserves are established or impairment is determined. At
the end of each quarter, the net capitalized costs of our oil and natural gas
properties is limited to the lower of unamortized cost or a ceiling.
Provision for depletion of oil and gas properties, under the full cost
method, is calculated using the unit of production method based upon estimates
of proved oil and gas reserves with oil and gas production being converted to a
common unit of measure based upon their relative energy content. Investments in
unproved properties and major development projects are not amortized until
proved reserves associated with the projects can be determined or until
impairment occurs. The cost of any impaired property is transferred to the
balance of oil and gas properties being depleted.
Our discounted present value of proved oil and natural gas reserves is a
major component of the ceiling calculation, and represents the component that
requires the most subjective judgments. Estimates of reserves are forecasts
based on engineering data, projected future rates of production and the timing
of future expenditures. The process of estimating oil and natural gas reserves
requires substantial judgment, resulting in imprecise determinations,
particularly for new discoveries. Different reserve engineers may make different
estimates of reserve quantities based on the same data. Our reserve estimates
are prepared by outside consultants.
The passage of time provides more qualitative information regarding
estimates of reserves, and revisions are made to prior estimates to reflect
updated information. However, there can be
16
no assurance that more significant revisions will not be necessary in the
future. If future significant revisions are necessary that reduce previously
estimated reserve quantities, it could result in a full cost property
write-down. In addition to the impact of these estimates of proved reserves on
calculation of the ceiling, estimates of proved reserves are also a significant
component of the calculation of depreciation, depletion and amortization.
While the quantities of proved reserves require substantial judgment, the
associated prices of oil and natural gas reserves that are included in the
discounted present value of the reserves do not require judgment. The ceiling
calculation dictates that prices and costs in effect as of the last day of the
period are held constant indefinitely. Because the ceiling calculation dictates
that we use prices in effect as of the last day of the applicable quarter, the
resulting value is not indicative of the true fair value of the reserves. Oil
and natural gas prices have historically been cyclical and, on any particular
day at the end of a quarter, can be either substantially higher or lower than
prices we actually receive in the long-term, which are a barometer for true fair
value.
Impairment of Assets. Under the full cost accounting rules, the capitalized
costs of oil and gas properties may not exceed a "ceiling limit", which is based
on the present value of estimated future net revenues, net of income tax
effects, from proved reserves, discounted at 10%, plus the lower of cost or fair
market value of unproved properties. If the net capitalized costs of our oil and
natural gas properties exceed the ceiling, we are subject to a ceiling test
write-down to the extent of such excess. A ceiling test write-down is a non-cash
charge to earnings. It reduces earnings and impacts stockholders' equity in the
period of occurrence and results in lower depreciation, depletion and
amortization expense in future periods.
The risk that we will be required to write down the carrying value of oil
and gas properties increases when oil and gas prices decline. If commodity
prices deteriorate, it is possible that we could incur an impairment in 2003.
RESULTS OF OPERATIONS FOR THE THREE MONTHS ENDED MARCH 31, 2003 AND 2002:
Oil and Gas Revenues. Oil and gas revenues increased $6,521,601 or 331%, to
$8,492,792 for the three months ended March 31, 2003, from $1,971,191 for the
same period of 2002. The increase was primarily the result of a 121% increase in
oil and gas production due to the Fullerton acquisition on December 20, 2002 and
increased gas production at Cook Mountain and a 95% increase in the average
sales price per BOE including hedges.
Lease Operating Costs. Lease operating costs increased $906,284 or 165%, to
$1,455,660 during the three months ended March 31, 2003, compared with $549,376
for the same period of 2002. The increase was primarily attributable to higher
lease operating costs associated with the Fullerton acquisition and Diamond M
operations.
General and Administrative Expenses. General and administrative expenses
increased by $452,004, or 129%, to $801,768 for the three months ended March 31,
2003 from $349,764 for the same period of 2002. The increase was primarily due
to costs associated with additional personnel hired to implement the business
plan.
Depreciation, Depletion and Amortization Expense. Depreciation, depletion
and amortization expense ("DD&A") increased by $711,061, or 52%, to $2,065,691
for the three months ended March 31, 2003 compared with $1,354,630 for the same
period of 2002 primarily because of a 121% increase in production volumes offset
by a reduced depletion rate. The decrease in depletion rate
17
when compared with the same quarter a year ago is attributable to an increase in
net depletable property basis offset by an increase in reserves due to the
Fullerton acquisition.
Interest Expense. Interest expense increased $333,407, or 218%, to $486,464
for the three months ended March 31, 2003 compared with $153,057 for the same
period of 2002 due to an increase in the bank borrowings associated with our
property acquisitions.
Interest and Other Income. Interest and other income increased $28,281, or
173% to $44,656 for the three month period ended March 31, 2003 compared to
$16,375 for the same period of 2002 due to increased cash balances associated
with the sale of Energen stock and increased cash flow.
Income Tax Expense. Our effective tax rate for the three months ended March
31, 2003 is 34%. For further discussion see Note 4.
Net Income (Loss). We reported net income of $2,251,754 for the three
months ended March 31, 2003 compared to a loss of $768,751 for the same period
in 2002. The increase of $3,020,505 or 393% is primarily due to higher product
prices and increased production volumes due to the Fullerton acquisition and
Cook Mountain discoveries.
Cash flow from operations for the three months ended March 31, 2003
increased $3,821,371 to $3,574,322 compared with a net cash flow deficiency of
$247,049 for the three months ended March 31, 2002.
LIQUIDITY AND CAPITAL RESOURCES
Our capital resources consist primarily of cash flows from our oil and gas
properties and bank borrowings supported by our oil and gas reserves. Our level
of earnings and cash flows depends on many factors, including the prices we
receive for oil and natural gas we produce.
Working capital decreased $8,392,561 as of March 31, 2003 compared with
December 31, 2002. Current assets exceeded current liabilities by $146,822 at
March 31, 2003 compared with $8,539,383 at December 31, 2002. Working capital
decreased primarily due to the payment of $7,000,000 on our bank debt
requirements, current derivative obligations and current maturities of long-term
debt.
We incurred net property costs of $4,572,325 for the three months ended
March 31, 2003, primarily for our oil and gas property acquisition, development,
and enhancement activities. Also added to our property basis were asset
retirement costs of $1,205,985 for the adoption of SFAS 143 (see Note 8). The
property acquisition, development and enhancement activities were financed by
the utilization of cash flows provided by operations.
Based on our projected oil and gas revenues and related expenses and
available bank borrowings, we believe that we will have sufficient capital
resources to fund normal operations, interest expense and principal reduction
payments on bank debt, if required, and preferred stock dividends. We
continually review and consider alternative methods of financing.
The following table is a summary of significant contractual cash
obligations:
<table>
Obligation Due in Period
-------------------------------------------------------------------------
Contractual Cash Obligations 2003 2004 2005 2006 2007 2008 Total
- ------------------------------------------------ ---------- --------- --------- ---------- --------- --------- ----------
(000)
<s> <c> <c> <c> <c> <c> <c> <c>
Revolving Credit Facility (Secured) $ 3,563 $ 8,550 $ 8,550 $ 8,550 $ 8,550 $ 4,987 $ 42,750
Office Lease (One Marienfeld Place) $ 54 $ 22 $ - $ - $ - $ - $ 76
Office Lease (Dinero Plaza) $ 102 $ 102 $ 102 $ 68 $ - $ - $ 374
</table>
18
TRENDS AND PRICES
Changes in oil and gas prices significantly affect our revenues, cash flows
and borrowing capacity. Markets for oil and gas have historically been, and will
continue to be, volatile. Prices for oil and gas typically fluctuate in response
to relatively minor changes in supply and demand, market uncertainty, seasonal,
political and other factors beyond our control. We are unable to accurately
predict domestic or worldwide political events or the effects of other such
factors on the prices we receive for our oil and gas. Please refer to Note 6
Derivative Instruments.
Our capital expenditure budgets are highly dependent on future oil and gas
prices and will be consistent with internally generated cash flows.
During fiscal year 2002 the average sales price we received for our oil was
approximately $24.59 per barrel while the average sales prices we received for
natural gas was approximately $3.33 per thousand cubic feet ("Mcf"). For the
three months ended March 31, 2003, the average price we received for our oil
production was approximately $32.60 (unhedged) per Bbl, while the average price
received at that same date for our natural gas production was approximately
$5.82 per Mcf (unhedged).
FORWARD-LOOKING STATEMENTS
In addition to historical information contained herein, this Form 10-Q/A
Report contains forward-looking statements subject to various risks and
uncertainties that could cause Parallel's actual results to differ materially
from those in the forward-looking statements. Forward-looking statements can be
identified by the use of forward-looking terminology such as "may", "will",
"expect," "intend," "anticipate, "estimate," "continue," "present value,"
"future," "reserves" or other variations thereof or comparable terminology.
Factors that could cause or contribute to such differences could include, but
are not limited to, those relating to the results of exploratory drilling
activity, changes in oil and natural gas prices, operating risks, availability
of drilling equipment, outstanding indebtedness, changes in interest rates,
dependence on weather conditions, seasonality, expansion and other activities of
competitors, changes in federal or state environmental laws and the
administration of such laws, and the general condition of the economy and our
effect on the securities market. While we believe our forward-looking statements
are based upon reasonable assumptions, these are factors that are difficult to
predict and that are influenced by economic and other conditions beyond our
control. Investors are directed to consider such risks and other uncertainties
discussed in documents filed by Parallel with the Securities and Exchange
Commission.
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Our only financial instrument sensitive to changes in interest rates is our
bank debt. Our annual interest costs in 2003 could fluctuate based on short-term
interest rates. As the interest rate is variable and reflects current market
conditions, the carrying value approximates the fair value. The table below
shows principal cash flows and related weighted average interest rates by
expected maturity dates. Weighted average interest rates were determined using
weighted average interest paid and accrued in March, 2003.
<table>
July July July July July July
2003 2004 2005 2006 2007 2008 Total
------------ ------------ ------------ ------------- ------------ -------------- -------------
(In 000's, except interest rates)
<s> <c> <c> <c> <c> <c> <c>
Variable rate debt:
Revolving facility (secured) $ 3,563 $ 8,550 $ 8,550 $ 8,550 $ 8,550 $ 4,987 $ 42,750
Average interest rate 4.50% 4.50% 4.50% 4.50% 4.50% 4.50%
</table>
19
At March 31, 2003, we had bank loans in the amount of $42,750,000
outstanding at an average interest rate of 4.50%. Borrowings under our new
credit facility bear interest, at our election, at (i) the bank's base rate or
(ii) the Eurodollar rate, plus 2.75%, but in no event less than 4.50%. As a
result, our annual interest costs in 2003 could fluctuate based on short-term
interest rates. Assuming no change in the amount outstanding during 2003, the
impact on interest expense of a one-half of one percent change in the average
interest rate above the 4.50% floor would be approximately $160,313 for the
remainder of the year. As the interest rate is variable and is reflective of
current market conditions, the carrying value approximates the fair value.
Our major market risk exposure is in the pricing applicable to our oil and
natural gas production. Market risk refers to the risk of loss from adverse
changes in oil and natural gas prices. Realized pricing is primarily driven by
the prevailing domestic price for crude oil and spot prices applicable to the
region in which we produce natural gas. Historically, prices received for oil
and gas production have been volatile and unpredictable. Pricing volatility is
expected to continue. Oil prices ranged from a low of $14.26 per barrel to a
high of $29.57 per barrel during 2002. Natural gas prices we received during
2002 ranged from a low of $1.05 per Mcf to a high of $4.94 per Mcf. During the
first quarter 2003 oil prices ranged from a low of $22.78 to a high of $35.95.
Natural gas prices we received during 2003 ranged from a low of $1.98 per Mcf to
a high of $7.92 per Mcf. A significant decline in the prices of natural gas or
oil could have a material adverse effect on our financial condition and results
of operations.
Parallel periodically hedges a portion of its oil and natural gas and
interest rate payments to manage exposure to commodity price risk under existing
sales contracts. Our objective is to lock in a range of oil and gas prices and a
fixed interest rate for certain notional amounts. This allows us to forecast
cash flow within a predictable range. Parallel meets the objective by entering
into costless collars and swap hedge contracts. For the remainder of fiscal 2003
hedged oil and natural gas volumes represent approximately 50% and 30%
respectively of expected production from April thru December 2003.
Additional information about Parallel's hedging activities can be found in
Note 6 on page 8 of this report.
ITEM 4. CONTROLS AND PROCEDURES
As of the end of the period covered by this Quarterly Report on Form
10-Q/A, the effectiveness of our disclosure controls and procedures (as defined
in Rules 13a-15(e) and 15d-15(e)) promulgated under the Securities Exchange Act
of 1934, was evaluated by our management, with the participation of our Chief
Executive Officer, Larry C. Oldham (principal executive officer), and our Chief
Financial Officer, Steven D. Foster (principal financial officer). Mr. Oldham
and Mr. Foster have concluded that our disclosure controls and procedures are
effective, as of the end of the period covered by this Quarterly Report on Form
10-Q/A, to help ensure that information we are required to disclose in reports
that we file with the SEC is accumulated and communicated to management and
recorded, processed, summarized and reported within the time periods prescribed
by the SEC.
There were no changes in our internal control over financial reporting that
occurred during the fiscal quarter ended March 31, 2003 that have materially
affected, or are reasonably likely to materially affect our internal control
over financial reporting.
20
PART II - OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS
At March 31, 2003, we were involved in one lawsuit incidental to our
business. In the opinion of management, the ultimate outcome of this lawsuit
will not have a material adverse effect on Parallel's financial position or
results of operations. We are not aware of any other threatened litigation. We
have not been a party to any bankruptcy, receivership, reorganization,
adjustment or similar proceeding.
ITEM 6. EXHIBIT AND REPORTS ON FORM 8-K
(a) Exhibits
Exhibit
No. Description of Exhibit
------- ----------------------
3.1 Certificate of Incorporation of Registrant (incorporated by
reference to Exhibit 3.1 to Form 10-K of the Registrant for the
fiscal year ended December 31, 1998.)
3.2 Bylaws of Registrant (Incorporated by reference to Exhibit 3 to
the Registrant's Form 8-K, dated October 9, 2000, as filed with
the Securities and Exchange Commission on October 10, 2000.)
4.1 Certificate of Designations, Preferences and Rights of Serial
Preferred Stock - 6% Convertible Preferred Stock (Incorporated
by reference to Exhibit 4.1 to Form 10-Q of the Registrant for
the fiscal quarter ended September 30, 1998.)
4.2 Certificate of Designation, Preferences and Rights of Series A
Preferred Stock. (Incorporated by reference to Exhibit 4.2 of
Form 10-K for the fiscal year ended December 31, 2000.)
4.3 Rights Agreement, dated as of October 5, 2000, between the
Registrant and Computershare Trust Company, Inc., as Rights
Agent. (Incorporated by reference to Exhibit 4.3 of Form 10-K
for the fiscal year ended December 31, 2000.)
Executive Compensation Plans and Arrangements (Exhibit No.'s
10.1 through 10.10):
10.1 1983 Incentive Stock Option Plan (Incorporated by reference to
Exhibit 10.2 to Form S-l of the Registrant (File No. 2-92397) as
filed with the Securities and Exchange Commission on July 26,
1984, as amended by Amendments No. 1 and 2 on October 5, 1984,
and October 25, 1984, respectively.)
10.2 1992 Stock Option Plan (Incorporated by reference to Exhibit
28.1 to Form S-8 of the Registrant (File No. 33-57348) as filed
with the Securities and Exchange Commission on January 25,
1993.)
21
10.3 Stock Option Agreement between the Registrant and Thomas R.
Cambridge dated December 11, 1991 (Incorporated by reference to
Exhibit 10.4 of Form 10-K of the Registrant for the fiscal year
ended December 31, 1992.)
10.4 Stock Option Agreement between the Registrant and Thomas R.
Cambridge dated October 18, 1993 (Incorporated by reference to
Exhibit 10.4(e) of Form 10-K of the Registrant for the fiscal
year ended December 31, 1993.)
10.5 Merrill Lynch, Pierce, Fenner & Smith Incorporated Prototype
Simplified Employee Pension Plan (Incorporated by reference to
Exhibit 10.6 of the Registrant's Form 10-K for the fiscal year
ended December 31, 1995.)
10.6 Non-Employee Directors Stock Option Plan (Incorporated by
reference to Exhibit 10.6 of the Registrant's Form 10-K Report
for the fiscal year ended December 31, 1997).
10.7 1998 Stock Option Plan (Incorporated by reference to Exhibit
10.7 of Form 10-K of the Registrant for the fiscal year ended
December 31, 1998.)
10.8 Form of Incentive Award Agreements, dated December 12, 2001,
between the Registrant and Thomas R. Cambridge, Larry C. Oldham,
Eric A. Bayley and John S. Rutherford granting 2,394 Unit
Equivalent Rights to Mr. Cambridge; 9,564 Unit Equivalent Rights
to Mr. Oldham; 2,869 Unit Equivalent Rights to Mr. Bayley; and
7,173 Unit Equivalent Rights to Mr. Rutherford. (Incorporated by
reference to Exhibit 10.8 of the Registrant's Form 10-K Report
for the fiscal year ended December 31, 2001).
10.9 Form of Change of Control Agreements, dated June 1, 2001,
between the Registrant and Thomas R. Cambridge, Larry C. Oldham,
Eric A. Bayley and John S. Rutherford. (Incorporated by
reference to Exhibit 10.9 of the Registrant's Form 10-K Report
for the fiscal year ended December 31, 2001).
10.10 Restated Loan Agreement, dated December 27, 1999, between the
Registrant and Bank One, Texas, N.A. (Incorporated by reference
to Exhibit 10.8 of Form 10-K of the Registrant for the fiscal
year ended December 31, 1999).
10.11 Loan Agreement dated December 18, 2000, between the Registrant
and Bank One, Texas, N.A. (Incorporated by reference to Exhibit
10.8 of Form 10-K of the Registrant for the fiscal year ended
December 31, 2000.)
10.12 Letter agreement, dated March 24, 1999, between the Registrant
and Bank One, Texas, N.A. (Incorporated by reference to Exhibit
10.9 of Form 10-K of the Registrant for the fiscal year ended
December 31, 1998.)
10.13 Certificate of Formation of First Permian, L.L.C. (Incorporated
by reference to Exhibit 10.1 of the Registrant's Form 8-K report
dated June 30, 1999.)
10.14 Limited Liability Company Agreement of First Permian, L.L.C.
(Incorporated by reference to Exhibit 10.2 of the Registrant's
Form 8-K report dated June 30, 1999.)
22
10.15 Merger Agreement dated June 25, 1999. (Incorporated by reference
to Exhibit 10.3 of the Registrant's Form 8-K report dated June
30, 1999.)
10.16 Agreement and Plan of Merger of First Permian, L.L.C. and Nash
Oil Company, L.L.C. (Incorporated by reference to Exhibit 10.4
of the Registrant's Form 8-K report dated June 30, 1999.)
10.17 Certificate of Merger of First Permian, L.L.C. and Nash Oil
Company, L.L.C (Incorporated by reference to Exhibit 10.5 of the
Registrant's Form 8-K Report dated June 30, 1999.)
10.18 Amended and Restated Limited Liability Company Agreement of
First Permian, L.L.C. dated as of May 31, 2000. (Incorporated by
reference to Exhibit 10.16 of Form 10-K for the fiscal year
ended December 31, 2000.)
10.19 Credit Agreement dated June 30, 1999, by and among First
Permian, L.L.C., Parallel Petroleum Corporation, Baytech, Inc.,
and Bank One, Texas, N.A. (Incorporated by reference to Exhibit
10.6 of the Registrant's Form 8-K report dated June 30, 1999.)
10.20 Limited Guaranty, dated June 30, 1999, by and among First
Permian, L.L.C., Parallel Petroleum Corporation, and Bank One,
Texas, N.A. (Incorporated by reference to Exhibit 10.7 of the
Registrant's Form 8-K report dated June 30, 1999.)
10.21 Intercreditor Agreement, dated as of June 30, 1999, by and among
First Permian, L.L.C., Bank One, Texas, N.A., Tejon Exploration
Company, and Mansefeldt Investment Corporation (Incorporated by
reference to Exhibit 10.8 of the Registrant's Form 8-K report
dated June 30, 1999.)
10.22 Subordinated Promissory Note, dated June 30, 1999, in the
original principal amount of $8.0 million made by First Permian,
L.L.C. payable to the order of Tejon Exploration Company
(Incorporated by reference to Exhibit 10.9 of the Registrant's
Form 8-K report dated June 30, 1999.)
10.23 Subordinated Promissory Note, dated June 30, 1999, in the
original principal amount of $8.0 million made by First Permian,
L.L.C. payable to the order of Mansefeldt Investment Corporation
(Incorporated by reference to Exhibit 10.10 of the Registrant's
Form 8-K report dated June 30, 1999.)
10.24 Second Restated Credit Agreement, dated October 25, 2000, among
First Permian, L.L.C., Bank One, Texas, N.A., and Bank One
Capital Markets, Inc. (Incorporated by reference to Exhibit
10.22 of Form 10-K for the fiscal year ended December 31, 2000.)
10.25 Loan Agreement, dated January 25, 2002, between the Registrant
and First American Bank, SSB (Incorporated by reference to
Exhibit 10.25 of Form 10-K for the fiscal year ended December
31, 2001.)
10.26 Purchase and Sale Agreement, dated as of November 27, 2002,
among JMC Exploration, Inc., Arkoma Star L.L.C., Parallel, L.P.
and Texland Petroleum, Inc. (Incorporated by reference to
Exhibit 10.1 of Form 8-K of the Registrant, dated December 20,
2002)
23
10.27 First Amended and Restated Credit Agreement, dated December 20,
2002, by and among Parallel Petroleum Corporation, Parallel,
L.P. Parallel, L.L.C., First American Bank, SSB, Western
National Bank and BNP Paribas (Incorporated by reference to
Exhibit 10.2 of Form 8-K of the Registrant, dated December 20,
2002)
10.28 Guaranty dated December 20, 2002, between Parallel, L.L.C. and
First American Bank, SSB, as Agent (Incorporated by reference to
Exhibit 10.3 of Form 8-K of the Registrant, dated December 20,
2002)
21 Subsidiaries (Incorporated by reference to Exhibit 21 of Form
10-K of the Registrant for the fiscal year ended December 31,
2002)
*31.1 Certification of Principal Executive Officer pursuant to 18
U.S.C. Section 1350, as adopted pursuant to Section 302 of the
Sarbanes - Oxley Act of 2002
*31.2 Certification of Principal Financial Officer pursuant to 18
U.S.C. Section 1350, as adopted pursuant to Section 906 of the
Sarbanes - Oxley Act. of 2002
*32.1 Certification of Chief Executive Officer pursuant to 18 U.S.C.
Section 1350, as adopted pursuant to Section 906 of the Sarbanes
- Oxley Act of 2002.
*32.2 Certification of Chief Financial Officer pursuant to 18 U.S.C.
Section 1350, as adopted pursuant to Section 906 of the Sarbanes
- Oxley Act of 2002.
- ----------------
* Filed herewith.
(b) Reports on Form 8-K
During the fiscal quarter ended March 31, 2003, we filed two reports on
Form 8-K.
In Form 8-K/A, Amendment No. 1, filed with the SEC on March 7, 2003, we
reported the acquisition of oil and gas properties located in Andrews County,
Texas in the Permian Basin of west Texas, which included statement of revenues
and direct expense of the Fullerton Properties for the years ended December 31,
2000, 2001 and 2002. This Form 8-K/A Report amended our Form 8-K Report, dated
December 20, 2002, and filed with the SEC on December 23, 2002. This initial
report on Form 8-K also reported the acquisition of oil and gas properties
located in Andrews County, Texas.
On March 27, 2003, we filed Form 8-K, dated March 26, 2003, reporting
matters under Item 9 - Regulation FD Disclosure, and Item 12 - Disclosure of
Results of Operations and Financial Condition. This report included our March
26, 2003 press release announcing 2002 year-end financial results, fourth
quarter results, capital investments, proved reserves and capital investment
budget for the periods specified.
24
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.
PARALLEL PETROLEUM CORPORATION
BY: /s/ Larry C. Oldham
Date: February 4, 2004 -----------------------------------
Larry C. Oldham, President and
Chief Executive Officer
Date: February 4, 2004 BY: /s/ Steven D. Foster
-----------------------------------
Steven D. Foster
Chief Financial Officer
25
INDEX TO EXHIBITS
(a) Exhibits
Exhibit
No. Description of Exhibit
-------- ----------------------
3.1 Certificate of Incorporation of Registrant (incorporated by
reference to Exhibit 3.1 to Form 10-K of the Registrant for the
fiscal year ended December 31, 1998.)
3.2 Bylaws of Registrant (Incorporated by reference to Exhibit 3 to
the Registrant's Form 8-K, dated October 9, 2000, as filed with
the Securities and Exchange Commission on October 10, 2000.)
4.1 Certificate of Designations, Preferences and Rights of Serial
Preferred Stock - 6% Convertible Preferred Stock (Incorporated
by reference to Exhibit 4.1 to Form 10-Q of the Registrant for
the fiscal quarter ended September 30, 1998.)
4.2 Certificate of Designation, Preferences and Rights of Series A
Preferred Stock. (Incorporated by reference to Exhibit 4.2 of
Form 10-K for the fiscal year ended December 31, 2000.)
4.3 Rights Agreement, dated as of October 5, 2000, between the
Registrant and Computershare Trust Company, Inc., as Rights
Agent. (Incorporated by reference to Exhibit 4.3 of Form 10-K
for the fiscal year ended December 31, 2000.)
Executive Compensation Plans and Arrangements (Exhibit No.'s
10.1 through 10.10):
10.1 1983 Incentive Stock Option Plan (Incorporated by reference to
Exhibit 10.2 to Form S-l of the Registrant (File No. 2-92397) as
filed with the Securities and Exchange Commission on July 26,
1984, as amended by Amendments No. 1 and 2 on October 5, 1984,
and October 25, 1984, respectively.)
10.2 1992 Stock Option Plan (Incorporated by reference to Exhibit
28.1 to Form S-8 of the Registrant (File No. 33-57348) as filed
with the Securities and Exchange Commission on January 25,
1993.)
10.3 Stock Option Agreement between the Registrant and Thomas R.
Cambridge dated December 11, 1991 (Incorporated by reference to
Exhibit 10.4 of Form 10-K of the Registrant for the fiscal year
ended December 31, 1992.)
10.4 Stock Option Agreement between the Registrant and Thomas R.
Cambridge dated October 18, 1993 (Incorporated by reference to
Exhibit 10.4(e) of Form 10-K of the Registrant for the fiscal
year ended December 31, 1993.)
10.5 Merrill Lynch, Pierce, Fenner & Smith Incorporated Prototype
Simplified Employee Pension Plan (Incorporated by reference to
Exhibit 10.6 of the Registrant's Form 10-K for the fiscal year
ended December 31, 1995.)
10.6 Non-Employee Directors Stock Option Plan (Incorporated by
reference to Exhibit 10.6 of the Registrant's Form 10-K Report
for the fiscal year ended December 31, 1997).
10.7 1998 Stock Option Plan (Incorporated by reference to Exhibit
10.7 of Form 10-K of the Registrant for the fiscal year ended
December 31, 1998.)
10.8 Form of Incentive Award Agreements, dated December 12, 2001,
between the Registrant and Thomas R. Cambridge, Larry C. Oldham,
Eric A. Bayley and John S. Rutherford granting 2,394 Unit
Equivalent Rights to Mr. Cambridge; 9,564 Unit Equivalent Rights
to Mr. Oldham; 2,869 Unit Equivalent Rights to Mr. Bayley; and
7,173 Unit Equivalent Rights to Mr. Rutherford. (Incorporated by
reference to Exhibit 10.8 of the Registrant's Form 10-K Report
for the fiscal year ended December 31, 2001).
10.9 Form of Change of Control Agreements, dated June 1, 2001,
between the Registrant and Thomas R. Cambridge, Larry C. Oldham,
Eric A. Bayley and John S. Rutherford. (Incorporated by
reference to Exhibit 10.9 of the Registrant's Form 10-K Report
for the fiscal year ended December 31, 2001).
10.10 Restated Loan Agreement, dated December 27, 1999, between the
Registrant and Bank One, Texas, N.A. (Incorporated by reference
to Exhibit 10.8 of Form 10-K of the Registrant for the fiscal
year ended December 31, 1999).
10.11 Loan Agreement dated December 18, 2000, between the Registrant
and Bank One, Texas, N.A. (Incorporated by reference to Exhibit
10.8 of Form 10-K of the Registrant for the fiscal year ended
December 31, 2000.)
10.12 Letter agreement, dated March 24, 1999, between the Registrant
and Bank One, Texas, N.A. (Incorporated by reference to Exhibit
10.9 of Form 10-K of the Registrant for the fiscal year ended
December 31, 1998.)
10.13 Certificate of Formation of First Permian, L.L.C. (Incorporated
by reference to Exhibit 10.1 of the Registrant's Form 8-K report
dated June 30, 1999.)
10.14 Limited Liability Company Agreement of First Permian, L.L.C.
(Incorporated by reference to Exhibit 10.2 of the Registrant's
Form 8-K report dated June 30, 1999.)
10.15 Merger Agreement dated June 25, 1999. (Incorporated by reference
to Exhibit 10.3 of the Registrant's Form 8-K report dated June
30, 1999.)
10.16 Agreement and Plan of Merger of First Permian, L.L.C. and Nash
Oil Company, L.L.C. (Incorporated by reference to Exhibit 10.4
of the Registrant's Form 8-K report dated June 30, 1999.)
10.17 Certificate of Merger of First Permian, L.L.C. and Nash Oil
Company, L.L.C (Incorporated by reference to Exhibit 10.5 of the
Registrant's Form 8-K Report dated June 30, 1999.)
10.18 Amended and Restated Limited Liability Company Agreement of
First Permian, L.L.C. dated as of May 31, 2000. (Incorporated by
reference to Exhibit 10.16 of Form 10-K for the fiscal year
ended December 31, 2000.)
10.19 Credit Agreement dated June 30, 1999, by and among First
Permian, L.L.C., Parallel Petroleum Corporation, Baytech, Inc.,
and Bank One, Texas, N.A. (Incorporated by reference to Exhibit
10.6 of the Registrant's Form 8-K report dated June 30, 1999.)
10.20 Limited Guaranty, dated June 30, 1999, by and among First
Permian, L.L.C., Parallel Petroleum Corporation, and Bank One,
Texas, N.A. (Incorporated by reference to Exhibit 10.7 of the
Registrant's Form 8-K report dated June 30, 1999.)
10.21 Intercreditor Agreement, dated as of June 30, 1999, by and among
First Permian, L.L.C., Bank One, Texas, N.A., Tejon Exploration
Company, and Mansefeldt Investment Corporation (Incorporated by
reference to Exhibit 10.8 of the Registrant's Form 8-K report
dated June 30, 1999.)
10.22 Subordinated Promissory Note, dated June 30, 1999, in the
original principal amount of $8.0 million made by First Permian,
L.L.C. payable to the order of Tejon Exploration Company
(Incorporated by reference to Exhibit 10.9 of the Registrant's
Form 8-K report dated June 30, 1999.)
10.23 Subordinated Promissory Note, dated June 30, 1999, in the
original principal amount of $8.0 million made by First Permian,
L.L.C. payable to the order of Mansefeldt Investment Corporation
(Incorporated by reference to Exhibit 10.10 of the Registrant's
Form 8-K report dated June 30, 1999.)
10.24 Second Restated Credit Agreement, dated October 25, 2000, among
First Permian, L.L.C., Bank One, Texas, N.A., and Bank One
Capital Markets, Inc. (Incorporated by reference to Exhibit
10.22 of Form 10-K for the fiscal year ended December 31, 2000.)
10.25 Loan Agreement, dated January 25, 2002, between the Registrant
and First American Bank, SSB (Incorporated by reference to
Exhibit 10.25 of Form 10-K for the fiscal year ended December
31, 2001.)
10.26 Purchase and Sale Agreement, dated as of November 27, 2002,
among JMC Exploration, Inc., Arkoma Star L.L.C., Parallel, L.P.
and Texland Petroleum, Inc. (Incorporated by reference to
Exhibit 10.1 of Form 8-K of the Registrant, dated December 20,
2002)
10.27 First Amended and Restated Credit Agreement, dated December 20,
2002, by and among Parallel Petroleum Corporation, Parallel,
L.P. Parallel, L.L.C., First American Bank, SSB, Western
National Bank and BNP Paribas (Incorporated by reference to
Exhibit 10.2 of Form 8-K of the Registrant, dated December 20,
2002)
10.28 Guaranty dated December 20, 2002, between Parallel, L.L.C. and
First American Bank, SSB, as Agent (Incorporated by reference to
Exhibit 10.3 of Form 8-K of the Registrant, dated December 20,
2002)
21 Subsidiaries (Incorporated by reference to Exhibit 21 of Form
10-K of the Registrant for the fiscal year ended December 31,
2002)
<page>
*31.1 Certification of Principal Executive Officer pursuant to 18
U.S.C. Section 1350, as adopted pursuant to Section 302 of the
Sarbanes - Oxley Act of 2002
*31.2 Certification of Principal Financial Officer pursuant to 18
U.S.C. Section 1350, as adopted pursuant to Section 906 of the
Sarbanes - Oxley Act. of 2002
*32.1 Certification of Chief Executive Officer pursuant to 18 U.S.C.
Section 1350, as adopted pursuant to Section 906 of the Sarbanes
- Oxley Act of 2002.
*32.2 Certification of Chief Financial Officer pursuant to 18 U.S.C.
Section 1350, as adopted pursuant to Section 906 of the Sarbanes
- Oxley Act of 2002.
- ------------------
*Filed herewith
EXHIBIT 31.1
CERTIFICATIONS
I, Larry C. Oldham, certify that:
1. I have reviewed this quarterly report on Form 10-Q/A of Parallel Petroleum
Corporation;
2. Based on my knowledge, this report does not contain any untrue statement of a
material fact or omit to state a material fact necessary to make the statements
made, in light of the circumstances under which such statements were made, not
misleading with respect to the period covered by this report;
3. Based on my knowledge, the financial statements, and other financial
information included in this quarterly report, fairly present in all material
respects the financial condition, results of operations and cash flows of the
registrant as of, and for, the periods presented in this quarterly report;
4. The registrant's other certifying officers and I are responsible for
establishing and maintaining disclosure controls and procedures (as defined in
Exchange Act Rules 13a-15(e) and 15d-15(e)) for the registrant and have:
a) Designed such disclosure controls and procedures, or caused such
disclosure controls and procedures to be designed under our supervision,
to ensure that material information relating to the registrant,
including its consolidated subsidiaries, is made known to us by others
within those entities, particularly during the period in which this
quarterly report is being prepared;
b) Evaluated the effectiveness of the registrant's disclosure controls
and procedures and presented in this report our conclusions about the
effectiveness of the disclosure controls and procedures, as of the end
of the period covered by this report based on such evaluation; and
c) Disclosed in this report any change in the registrant's internal
control over financial reporting that occurred during the registrant's
most recent fiscal quarter (the registrant's fourth fiscal quarter in
the case of an annual report) that has materially affected, or is
reasonably likely to materially affect, the registrant's internal
control over financial reporting; and
5. The registrant's other certifying officers and I have disclosed, based on our
most recent evaluation of internal control over financial reporting, to the
registrant's auditors and the audit committee of the registrant's board of
directors (or persons performing the equivalent functions):
a) All significant deficiencies and material weaknesses in the design or
operation of internal control over financial reporting which are
reasonably likely to adversely affect the registrant's ability to
record, process, summarize and report financial information; and
b) Any fraud, whether or not material, that involves management or other
employees who have a significant role in the registrant's internal
control over financial reporting; and
6. The registrant's other certifying officers and I have indicated in this
quarterly report whether or not there were significant changes in internal
controls or in other factors that could significantly affect internal controls
subsequent to the date of our most recent evaluation, including any corrective
actions with regard to significant deficiencies and material weaknesses.
Date: February 4, 2004
/s/ Larry C. Oldham
------------------------------
Larry C. Oldham, President
and Chief Executive Officer
(principal executive officer)
EXHIBIT 31.2
CERTIFICATIONS
I, Steven D. Foster, certify that:
1. I have reviewed this quarterly report on Form 10-Q/A of Parallel Petroleum
Corporation;
2. Based on my knowledge, this report does not contain any untrue statement of a
material fact or omit to state a material fact necessary to make the statements
made, in light of the circumstances under which such statements were made, not
misleading with respect to the period covered by this report;
3. Based on my knowledge, the financial statements, and other financial
information included in this quarterly report, fairly present in all material
respects the financial condition, results of operations and cash flows of the
registrant as of, and for, the periods presented in this quarterly report;
4. The registrant's other certifying officers and I are responsible for
establishing and maintaining disclosure controls and procedures (as defined in
Exchange Act Rules 13a-15(e) and 15d-15(e)) for the registrant and have:
a) Designed such disclosure controls and procedures, or caused such
disclosure controls and procedures to be designed under our supervision,
to ensure that material information relating to the registrant,
including its consolidated subsidiaries, is made known to us by others
within those entities, particularly during the period in which this
quarterly report is being prepared;
b) Evaluated the effectiveness of the registrant's disclosure controls
and procedures and presented in this report our conclusions about the
effectiveness of the disclosure controls and procedures, as of the end
of the period covered by this report based on such evaluation; and
c) Disclosed in this report any change in the registrant's internal
control over financial reporting that occurred during the registrant's
most recent fiscal quarter (the registrant's fourth fiscal quarter in
the case of an annual report) that has materially affected, or is
reasonably likely to materially affect, the registrant's internal
control over financial reporting; and
5. The registrant's other certifying officers and I have disclosed, based on our
most recent evaluation of internal control over financial reporting, to the
registrant's auditors and the audit committee of the registrant's board of
directors (or persons performing the equivalent functions):
a) All significant deficiencies and material weaknesses in the design or
operation of internal control over financial reporting which are
reasonably likely to adversely affect the registrant's ability to
record, process, summarize and report financial information; and
b) Any fraud, whether or not material, that involves management or other
employees who have a significant role in the registrant's internal
control over financial reporting; and
6. The registrant's other certifying officers and I have indicated in this
quarterly report whether or not there were significant changes in internal
controls or in other factors that could significantly affect internal controls
subsequent to the date of our most recent evaluation, including any corrective
actions with regard to significant deficiencies and material weaknesses.
Date: February 4, 2004
/s/ Steven D. Foster
-----------------------
Steven D. Foster
Chief Financial Officer
(principal financial officer)
EXHIBIT 32.1
CERTIFICATION
(Not filed pursuant to the Securities Exchange Act of 1934)
Pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906
of the Sarbanes - Oxley Act of 2002, the undersigned, Larry C. Oldham, the
President and Chief Executive Officer of Parallel Petroleum Corporation
("Parallel"), hereby certifies that the Quarterly Report on Form 10Q/A of
Parallel for the quarter ended March 31, 2003 fully complies with the periodic
reporting requirements of the Securities Exchange Act of 1934, as amended, and
the information contained in that Form 10Q/A Report fairly presents, in all
material respects, the financial condition and results of operations of
Parallel.
Dated: February 4, 2004
/s/ Larry C. Oldham
-------------------------------------
Larry C. Oldham,
President and Chief Executive Officer
A signed original of this written statement required by Section 906 has been
provided to Parallel Petroleum Corporation and will be retained by Parallel
Petroleum Corporation and furnished to the Securities and Exchange Commission or
its staff upon request.
EXHIBIT 32.2
CERTIFICATION
(Not filed pursuant to the Securities Exchange Act of 1934)
Pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906
of the Sarbanes - Oxley Act of 2002, the undersigned, Steven D. Foster, the
Chief Financial Officer of Parallel Petroleum Corporation ("Parallel"), hereby
certifies that the Quarterly Report on Form 10Q/A of Parallel for the quarter
ended March 31, 2003 fully complies with the periodic reporting requirements of
the Securities Exchange Act of 1934, as amended, and the information contained
in that Form 10Q/A Report fairly presents, in all material respects, the
financial condition and results of operations of Parallel.
Dated: February 4, 2004
/s/ Steven D. Foster
-----------------------------------------
Steven D. Foster, Chief Financial Officer
A signed original of this written statement required by Section 906 has been
provided to Parallel Petroleum Corporation and will be retained by Parallel
Petroleum Corporation and furnished to the Securities and Exchange Commission or
its staff upon request.