<PAGE> 1
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, 1998 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 Identification
incorporation or organization) Number)
One Marienfeld Place, Suite 465,
Midland, Texas 79701
(Address of principal executive offices) (Zip Code)
(915) 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
The number of outstanding shares of the issuer's common stock, $.01
par value, was 18,120,608 shares as of May 1, 1998.
===============================================================================
<PAGE> 2
PART I. - FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
Reference is made to the succeeding pages for the following financial
statements:
- Balance Sheets as of December 31, 1997 and March 31, 1998
- Statements of Operations for the three months ended March 31, 1997
and 1998
- Statements of Cash Flows for the three months ended March 31, 1997
and 1998
- Notes to Financial Statements
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS.
PART II. - OTHER INFORMATION
ITEM 2. CHANGES IN SECURITIES
ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K
/a/ Exhibits
27. Financial Data Schedule
/b/ Reports on Form 8-K
No reports were filed on Form 8-K during the quarterly period
ended March 31, 1998.
<PAGE> 3
PARALLEL PETROLEUM CORPORATION
BALANCE SHEETS
<TABLE>
December 31, March 31, 1998
ASSETS 1997* (Unaudited)
- ------------- ------------ ------------
<S> <C> <C>
Current assets:
Cash and cash equivalents $ 597,149 $ 289,149
Accounts receivable:
Oil & gas 1,649,350 1,795,975
Others, net of allowance for doubtful accounts
of $28,130 in 1997 and 1998 915,358 1,131,830
Affiliate 9,506 13,537
Subscription receivable -- 6,000,000
------------ ------------
2,574,214 8,941,342
Other assets 37,183 44,162
------------ ------------
Total current assets 3,208,546 9,274,653
------------ ------------
Property and equipment, at cost:
Oil and gas properties, full cost method 62,659,570 67,554,864
Other 433,922 454,743
------------ ------------
63,093,492 68,009,607
Less accumulated depreciation and depletion 16,514,102 17,444,918
------------ ------------
Net property and equipment 46,579,390 50,564,689
------------ ------------
Other assets, net of accumulated amortization of
$59,085 in 1997 and $65,612 in 1998 67,596 61,070
------------ ------------
$ 49,855,532 $ 59,900,412
============ ============
</TABLE>
<PAGE> 4
<TABLE>
December 31, March 31, 1998
1997* (Unaudited)
------------ --------------
<S> <C> <C>
LIABILITIES AND STOCKHOLDERS' EQUITY
- ------------------------------------
Current liabilities:
Accounts payable and accrued liabilities:
Trade $ 5,313,439 $ 4,880,398
Affiliate 14,660 1,581
Income taxes payable 42,586 --
------------ ------------
Total current liabilities 5,370,685 4,881,979
------------ ------------
Long-term debt 12,182,610 16,632,610
Deferred income taxes 3,183,484 3,219,353
Stockholders' equity:
$.60 Cumulative convertible preferred
stock subscribed - par value $.10 per share
(aggregate liquidation preference of $10),
authorized, issued and outstanding 600,000
shares -- 60,000
Preferred stock - par value of $.10 per share,
authorized 40,000,000 shares, none issued -- --
Common stock - par value of $.01 per share,
authorized 100,000,000 shares, issued and
outstanding 18,114,358 in 1997 and 18,120,608
in 1998 181,144 181,207
Additional paid-in surplus 22,839,049 28,753,877
Retained earnings 6,098,560 6,171,386
------------ ------------
Total stockholders' equity 29,118,753 35,166,470
Contingencies
------------ ------------
$ 49,855,532 $ 59,900,412
============ ============
</TABLE>
The balance sheet as of December 31, 1997 has been derived from the Company's
audited financial statements. The accompanying notes are an integral part of
these financial statements.
<PAGE> 5
PARALLEL PETROLEUM CORPORATION
STATEMENTS OF OPERATIONS
Three Months Ended March 31, 1997 and 1998
(Unaudited)
<TABLE>
1997 1998
------------ -----------
<S> <C> <C>
Oil and gas revenues $ 4,040,647 $ 2,112,563
----------- -----------
Cost and expenses:
Lease operating expense 893,251 557,638
General and administrative 141,209 220,389
Depreciation, depletion and amortization 961,246 930,816
----------- -----------
1,995,706 1,708,843
----------- -----------
Operating income 2,044,941 403,720
----------- -----------
Other income (expense), net:
Interest income 1,661 76
Other income 8,482 13,559
Interest expense (166,106) (304,278)
Other expense (1,296) (4,382)
----------- -----------
Total other expense, net (157,259) (295,025)
----------- -----------
Income before income taxes 1,887,682 108,695
Income tax expense - deferred 622,935 35,869
----------- -----------
Net income $ 1,264,747 $ 72,826
=========== ===========
Net income per common share
Basic $.070 $.004
----- -----
Diluted $.070 $.004
----- -----
Weighted average common shares outstanding 18,254,575 18,779,453
=========== ===========
</TABLE>
The accompanying notes are an integral part of these financial statements
<PAGE> 6
PARALLEL PETROLEUM CORPORATION
STATEMENTS OF CASH FLOWS
Three Months Ended March 31, 1997 and 1998
(Unaudited)
<TABLE>
1997 1998
---------- ----------
<S> <C> <C>
Cash flows from operating activities:
Net income $1,264,747 $ 72,826
Adjustments to reconcile net income to
net cash provided by (used in) operating
activities:
Depreciation, depletion and amortization 961,246 930,816
Incomes taxes 622,935 35,869
Other (increase) decrease, net (11,171) 6,526
Changes in assets and liabilities:
Decrease (increase) in trade receivables 543,268 (367,128)
Increase in subscription receivable -- (6,000,000)
(Increase)in prepaid expenses
and other (2,700) (6,979)
Decrease in accounts payable
and accrued liabilities (962,855) (488,706)
----------- -----------
Net cash provided by (used in)operating
activities 2,415,470 (5,816,776)
----------- -----------
Cash flows from investing activities:
Additions to property and equipment (4,072,611) (4,916,115)
----------- -----------
Net cash used in investing
activities (4,072,611) (4,916,115)
----------- -----------
Cash flows from financing activities:
Proceeds from the issuance of long-term debt 3,645,000 4,450,000
Payments of long-term debt (3,533,781) --
Stock offering costs (10,535) (58,859)
Proceeds from common stock issuance 1,483,324 6,000,000
Proceeds from exercise of options and warrants 36,688 33,750
----------- -----------
Net cash provided by financing
activities 1,620,696 10,424,891
----------- -----------
Net decrease in cash and cash equivalents (36,445) (308,000)
Beginning cash and cash equivalents 41,569 597,149
----------- -----------
Ending cash and cash equivalents $ 5,124 $ 289,149
=========== ===========
</TABLE>
The accompanying notes are an integral part of these financials.
<PAGE> 7
PARALLEL PETROLEUM CORPORATION
NOTES TO FINANCIAL STATEMENTS
NOTE 1. OPINION OF MANAGEMENT
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.
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 pursuant to the
rules and regulations of the Securities and Exchange Commission. These
financial statements should be read in connection with the financial
statements and notes thereto included in the Company's 1997 Annual Report
and Form 10-K.
NOTE 2. LONG TERM DEBT
The Company and its bank lender are parties to a loan agreement
providing for a line of credit to the Company in the principal amount of up
to $19,600,000, the "borrowing base" determined by the bank as of April 1,
1998. The $19,600,000 borrowing base includes (i) a $17,600,000 revolving
credit facility (the "Revolving Facility") and (ii) a $2,000,000 "overline",
non-revolving line of credit (the "Development Facility"). Loans are made
to the Company under a promissory note secured by substantially all of the
Company's oil and gas properties. All indebtedness under the Revolving
Facility matures on July 1, 2001 and all indebtedness under the Development
Facility is due and payable on December 31, 1998. Loans made to the Company
under the Revolving Facility bear interest at the election of the Company at
a rate equal to (i) the bank's base lending rate less .25% or (ii) the
bank's Eurodollar rate plus a margin of 2.50%. Loans made under the
Development Facility bear interest at the bank's base lending rate plus 5.50%.
Interest only is payable monthly until maturity. On March 31, 1998, the
interest rate in effect was the bank's base lending rate less .25%, or 8.5%.
Commitment fees of .25% per annum on the difference between the borrowing
base and the average daily amount outstanding are due quarterly. Under terms
of the loan facility, the principal amount outstanding at any one time may
never exceed the borrowing base established by the bank which, at April 1,
1998, was $19,600,000. The borrowing base reduces automatically each month
at a rate of $300,000 (the "monthly reduction amount"). The borrowing base
and the monthly reduction amount are redetermined by the bank on or about
April 1 and October 1 of each year or at such other times as the bank may
elect. At March 31, 1998, the principal amount outstanding under the
Revolving Facility was $16,632,610 and no amounts were outstanding under the
Development Facility.
The loan agreement requires the Company to comply with certain
covenants including limits on additional debt, maintenance of minimum levels
of financial ratios and dividend payment restrictions.
NOTE 3. CUMULATIVE CONVERTIBLE PREFERRED STOCK
On April 8, 1998, the Company completed a private placement of
600,000 shares of its $.60 Cumulative Convertible Preferred Stock, $.10 par
value per share (the "Preferred Stock"). Cumulative dividends of $.60 per
share are payable semi-annually. Each share of the Preferred Stock may be
converted, at the option of the holder, into 1.5625 shares of common stock
at an initial conversion price of $6.40 per share, subject to adjustment in
certain events.
The Company may redeem the Preferred Stock, in whole or in part,
after April 1, 1999, for $10 per share plus accrued dividends.
Proceeds received, net of related expenses, were approximately
$5,941,000. The net proceeds from the sale of Preferred Stock were used to
reduce the indebtedness outstanding under the Company's loan agreement.
A certain director of the Company purchased 100,000 shares of the
Preferred Stock for $1,000,000.
<PAGE> 8
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 the Company's Financial Statements and the related notes thereto.
OVERVIEW
The Company's long term business strategy is to increase its reserve
base by (i) utilizing 3-D seismic technology in the targeted exploration,
development and production of its leasehold inventory; (ii) exploiting
existing producing properties; (iii) acquiring additional producing
properties that it believes can be exploited by developing reserves not
previously produced; and (iv) maintaining a low overhead cost structure.
As part of this business strategy, the Company has discovered oil
and gas reserves through the use of 3-D seismic technology in the Horseshoe
Atoll Reef Trend of west Texas and the Yegua/Frio/Wilcox Gas Trend onshore
gulf coast of Texas and has acquired oil and gas producing properties in the
Permian Basin of west Texas.
The Company's operating performance is influenced by several factors,
the most significant of which is the prices received for its oil and gas and
its production volumes. The world price for oil has an overall influence on
the prices that the Company receives for its 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
the Company receives are primarily influenced by seasonal demand, weather,
hurricane conditions in the Gulf of Mexico, availability of pipeline
transportation to end users, the proximity of the Company's wells to major
transportation pipeline infrastructure and, to a lesser extent, world oil
prices. Additional factors influencing operating performance include
production expenses, overhead requirements, and cost of capital.
The Company's oil and gas producing activities are accounted for
using the full cost method of accounting. Accordingly, the Company capitalizes
all costs incurred in connection with the exploration for and development of
oil and gas reserves and the acquisition of oil and gas properties. 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 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 such 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.
The Company's quarterly production and results of operations vary
from quarter to quarter. Based on its scheduled drilling activities, the
Company does not currently anticipate that its production volumes in the
second quarter of 1998 will decrease significantly compared to its production
volumes in the prior year, however normal operating considerations and other
factors could result in decreased production volumes in subsequent quarters.
<PAGE> 9
RESULTS OF OPERATIONS
Because of the Company's ever-changing reserve base and sources of
production, year-to-year or quarter-to-quarter comparisons of the Company's
results of operations can be difficult. This situation is further complicated
by significant changes in the Company's product mix (oil vs. gas volumes) and
related price fluctuations for oil and gas. The table below compares the
Results of Operations on the basis of EBOs for the period indicated. An EBO
means one barrel of oil equivalent using the ratio of six Mcf of gas to one
barrel of oil.
<TABLE>
THREE MONTHS ENDED THREE MONTHS ENDED
---------------------------- --------------------
9-30-97 12-31-97 3-31-98 3-31-97 3-31-98
-------- -------- -------- --------- ---------
<S> <C> <C> <C> <C> <C>
Production and prices:
Oil (Bbls) 35,217 41,321 43,375 50,554 43,375
Natural gas (Mcf) 793,660 750,730 719,905 976,555 719,905
Equivalent barrels of oil(EBO) 167,494 166,443 163,359 213,313 163,359
Oil price (per Bbl) $21.57 $18.03 $14.08 $21.01 $14.08
Gas price (per Mcf) $2.67 $3.06 $2.09 $3.05 $2.09
Price per EBO $17.18 $18.27 $12.93 $18.94 $12.93
Results of operations per EBO
Oil and gas revenues $17.18 $18.27 $12.93 $18.94 $12.93
Costs and expenses:
Lease operating expense 4.26 5.52 3.41 4.19 3.41
General and administrative .73 2.50 1.35 .66 1.35
Depreciation and depletion 4.74 8.12 5.70 4.50 5.70
------ ------ ------ ------ ------
Total costs and expenses 9.73 16.14 10.46 9.35 10.46
------ ------ ------ ------ ------
Operating income 7.45 2.13 2.47 9.59 2.47
Interest expense, net (1.27) (1.32) (1.86) (.77) (1.86)
Other income, net .04 .04 .06 .03 .06
------ ------ ------ ------ ------
Pretax income 6.22 .85 .67 8.85 .67
Income tax expense - deferred (2.05) .64 (.22) (2.92) (.22)
------ ------ ------ ------ ------
Net income 4.17 1.49 .45 5.93 .45
------ ------ ------ ------ ------
Income before working
capital adjustments $10.96 $ 8.97 $ 6.37 $13.35 $ 6.37
====== ====== ====== ====== ======
</TABLE>
<PAGE> 10
The following table sets forth for the periods indicated the
percentage of total revenues represented by each item reflected on the
Company's statements of operations.
<TABLE>
THREE MONTHS ENDED THREE MONTHS ENDED
---------------------------- --------------------
9-30-97 12-31-97 3-31-98 3-31-97 3-31-98
-------- -------- -------- -------- --------
<S> <C> <C> <C> <C> <C>
Oil and gas revenues 100.0% 100.0% 100.0% 100.0% 100.0%
Costs and expenses:
Production costs 24.8 30.2 26.4 22.1 26.4
General and administrative 4.3 13.7 10.4 3.5 10.4
Depreciation, depletion and
amortization 27.6 44.4 44.1 23.8 44.1
------ ------ ------ ------ ------
Total costs and expense 56.7 88.3 80.9 49.4 80.9
------ ------ ------ ------ ------
Operating income 43.3 11.7 19.1 50.6 19.1
------ ------ ------ ------ ------
Interest expense, net (7.4) (7.2) (14.4) (4.1) (14.4)
Other income, net .3 .2 .5 .2 .5
------ ------ ------ ------ ------
Pretax income 36.2 4.7 5.2 46.7 5.2
Income tax expense (11.9) 3.5 (1.7) (15.4) (1.7)
------ ------ ------ ------ ------
Net income 24.3% 8.2% 3.5% 31.3% 3.5%
====== ====== ====== ====== ======
</TABLE>
THREE MONTHS ENDED MARCH 31, 1998 AND MARCH 31, 1997:
Oil and Gas Revenues. Oil and gas revenues decreased $1,928,084, or
48%, to $2,112,563 for the three months ended March 31, 1998. This compares
with oil and gas revenues of $4,040,647 for the same period in 1997. The
decrease in revenues was primarily the result of a 23% decrease in oil and
gas production volumes and a 32% decrease in the average sales price per
equivalent barrel of oil ("EBO") received by the Company in the first quarter
of 1998. Contributing to the decrease in production volumes was a third
quarter 1997 property sale that represented approximately 10%, or 180 EBO
per day, of the Company's aggregate daily production at the time of sale.
The Company produced 163,359 EBOs in first quarter 1998 compared with 213,313
EBOs in first quarter 1997, a decrease of 49,954 EBOs. The average sales
price per EBO received by the Company was $12.93 for the three months ended
March 31, 1998 compared with $18.94 for the same prior year period.
Approximately 42% of the decrease in revenues was attributable to decreased
oil and gas production volumes and approximately 58% was attributable to the
decrease in the average sales price.
Production Costs. Production costs decreased $335,613, or 38%, to
$557,638 for the first three months of 1998 compared with $893,251 for the
same period in 1997, primarily a result of the decrease in production volumes
of 49,954 EBOs. Production costs as a percentage of revenues increased
primarily because of the 32% decrease in the average sales price per EBO
received by the Company in first quarter 1998. Average production costs per
EBO decreased by $0.78, or 18%, to $3.41 per EBO for the first three months
in 1998 compared with $4.19 for the same period in 1997, primarily a result
of the addition of lower cost oil and gas production during the first
quarter of 1998.
General and Administrative Expenses. General and administrative
costs increased by $79,180, or 56%, to $220,389 for the first three months of
1998 compared with $141,209 for the same period of 1997. The increase was
primarily due to an increase in the state of Delaware franchise taxes and by
the Company capitalizing less of its general and administrative expenses.
General and administrative costs are expected to remain fairly stable with
no material increases expected in any particular category.
<PAGE> 11
Depreciation, Depletion and Amortization Expense. Depreciation,
depletion and amortization expense ("DD&A") decreased by $30,430, or 3%, to
$930,816 for the first three months of 1998 compared with $961,246 for the
same period of 1997. As a percentage of revenues, the DD&A rate increased by
85% when compared with the prior year first quarter, primarily a result of
the decrease in the average sales price per EBO received by the Company and
an increase in the DD&A rate per EBO. The DD&A rate per EBO increased to
$5.70 for first quarter 1998 compared with $4.50 per EBO for the first
quarter of 1997. The increase in the DD&A rate per EBO is attributable to a
revision in the Company's current reserve estimates, primarily a result of
lower oil and gas prices in effect at March 31, 1998 compared with prices in
effect at December 31, 1997, and the effect of limited reserve additions
for new wells brought on production by the Company in the first quarter of
1998. Until production histories are established for new wells, the
quantities of estimated reserves to be added are limited. Generally, after
production histories are established, additional quantities of reserves can
be booked, thereby increasing the quantities of reserves used in calculating
the DD&A rate.
Historically, the Company has reviewed its estimates of reserve
quantities on an annual basis. However, due to current oil and gas prices,
the Company's current level of drilling activity and the potential that new
discoveries could significantly impact its operations, the Company intends
to conduct internal reviews of its estimated reserves on a more frequent
basis and make necessary adjustments to its DD&A rate accordingly. The
Company believes this periodic review and adjustments will result in a more
accurate reflection of its DD&A rate during the year and minimize possible
year-end adjustments.
Net Interest Expense. Interest expense increased $139,757, or 85%,
to $304,202 for the three months ended March 31, 1998 compared with $164,445
for the same period of 1997, due principally to increased borrowings against
the Company's revolving line of credit associated with an increased level of
3-D seismic acquisition and drilling activities.
Income Tax Expense. The Company had an effective tax rate of 33%
for the three months ended March 31, 1998 and 1997.
Net Income and Operating Cash Flow. Net income decreased by
$1,191,921, or 94%, to $72,826 for the first three months of 1998 compared
with $1,264,747 for the same three month period in 1997. Operating cash flow
decreased by $1,809,417, or 64%, to $1,039,511 for the three months ended
March 31, 1998 compared with $2,848,928 for the same period in 1997. The
decreases in net income and operating cash flow resulted from a 48% decrease
in oil and gas revenues, a 56% increase in general and administrative costs,
and a 85% increase in net interest expense.
LIQUIDITY AND CAPITAL RESOURCES
Working capital increased $6,554,813 as of March 31, 1998 compared
to December 31, 1997. Current assets exceeded current liabilities by
$4,392,674 at March 31, 1998 while current liabilities exceeded current
assets by $2,162,139 at December 31, 1997. Current assets increased
primarily due to (i) an increase of $367,128 in accounts receivable, (ii) a
$6,000,000 subscription receivable from a private placement of 600,000
shares of its $.60 Cumulative Convertible Preferred Stock, which closed on
April 8, 1998, (iii) an increase of $6,979 in prepaid expense which was
offset by a decrease in cash of $308,000. The decrease in cash was
primarily due to the Company's investments in oil and gas drilling
activities, payment of trade payables accrued as of December 31, 1997 and
the Company's cash management system, whereby it maintains minimum cash
balances with any excess cash applied against its bank line of credit.
The Company incurred net costs of $4,916,115 in its oil and gas
property acquisition, development, and enhancement activities for the three
months ended March 31, 1998. Such costs were financed by the utilization of
the Company's cash position and funds provided from its line of credit.
Based on the Company's projected oil and gas revenues and related
expenses, management believes that its internally generated cash flow,
coupled with borrowings under the Company's lending facility, and proceeds
from the recent private placement will be sufficient to fund its current
operations. The Company continually reviews and considers alternative
methods of financing.
<PAGE> 12
TREND AND PRICES
The Company's revenues, cash flows and borrowing capacity are
affected by changes in oil and gas prices. The 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
the control of the Company. The Company is unable to accurately predict
domestic or worldwide political events or the effects of such other factors
on the prices received by the Company for its oil and gas. The Company
historically has not entered into transactions to hedge against changes in
oil and gas prices but may elect to enter into hedging transactions in the
future to protect against fluctuations in oil and gas prices.
During 1997, the average sales price received by the Company for
its oil was approximately $19.88 per barrel ("Bbl") compared with $21.83 in
1996, while the average sales prices for the Company's gas was approximately
$2.70 per thousand cubic feet ("Mcf") in 1997, compared with $2.55 per Mcf
in 1996. At March 31, 1998, the average price received by the Company for
its oil production was approximately $14.08 per Bbl, while the average price
received by the Company, at that same date, for its gas production was
approximately $2.09 per Mcf.
INFORMATION SYSTEMS FOR THE YEAR 2000
The Company will be required to modify its information systems in
order to accurately process data referencing the year 2000. Because of the
importance of occurrence dates in the oil and gas industry, the consequences
of not pursuing these modifications could significantly affect the Company's
ability to manage and report operating activities. Currently, the Company
plans to purchase software modifications from third parties in order to
correct any existing deficiencies. The total cost will be approximately
$10,000 and the information systems are anticipated to be updated by the end
of 1998. Year 2000 issues as they relate to field operation programs,
suppliers and contractors remain to be evaluated by the Company. However,
based on current available information, the Company does not anticipate that
the costs associated with any necessary modifications will be material to
the Company's operations or financial condition.
PART II - OTHER INFORMATION
ITEM 2. CHANGES IN SECURITIES
On April 8, 1998, the Company completed a private placement of
600,000 shares of its $.60 Cumulative Convertible Preferred Stock, $.10 par
value per share (the "Preferred Stock"). Gross proceeds from the sale of
the Preferred Stock were $6,000,000. The net proceeds from the sale of the
Preferred Stock, approximately $5,941,000, were used to reduce the
Company's outstanding bank indebtedness which, after giving effect to the
application of the net proceeds from the sale of the Preferred Stock, was
approximately $10,647,610 at April 13, 1998. The Preferred Stock was
placed directly by the Company, without discount or commissions, to eight
accredited investors in reliance on the exemption from registration under
the Securities Act of 1933, as amended (the "Act"), pursuant to Rule 506 of
Regulation D under the Act.
The Preferred Stock is convertible at the holder's option at any
time after October 9, 1998, unless previously redeemed, into Common Stock at
an initial conversion price of $6.40 per share (equivalent to a conversion
rate of 1.5625 shares of Common Stock for each share of Preferred Stock,
subject to adjustment in certain events).
Holders of Preferred Stock are entitled to receive cumulative cash
dividends at the annual rate of $.60 per share, payable semi-annually on
June 15 and December 15 in each year, commencing June 15, 1998.
The Preferred Stock is senior to the Common Stock with respect to
dividends and on liquidation, dissolution or winding up of the Company.
Upon any liquidation, dissolution or winding up of the Company, whether
voluntary or involuntary, the holders of Preferred Stock have preference and
priority over the Common Stock and any other class or series of stock
ranking junior to the Preferred Stock upon liquidation, dissolution or
winding up, for payment out of the assets of the Company or proceeds thereof
available for distribution to stockholders of $10.00 per share plus all
dividends accrued and unpaid thereon.
The Preferred Stock is redeemable after April 1, 1999, in whole or
in part, at the option of the Company, upon not less than 30 days' notice at
$10.00 per share plus an amount equal to all accrued and unpaid dividends.
<PAGE> 12
The Preferred Stock does not have any voting rights, except as
required by applicable law and except that as long as any shares of
Preferred Stock remain outstanding, the holders of a majority of the
outstanding share of the Preferred Stock may vote on any proposal to change
any provision of the Preferred Stock which materially and adversely affects
the rights, preferences or privileges of the Preferred Stock.
ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K
(a) Exhibits
27. Financial Data Schedule
(b) Reports on Form 8-K
No reports were filed on Form 8-K during the quarter ended
March 31, 1998.
<PAGE> 14
SIGNATURES
PURSUANT TO THE REQUIREMENTS OF THE SECURITIES AND 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/ THOMAS R. CAMBRIDGE
Date: May 15, 1998 ----------------------------------
THOMAS R. CAMBRIDGE,
CHAIRMAN OF THE BOARD OF DIRECTORS
AND CHIEF EXECUTIVE OFFICER
Date: May 15, 1998 BY: /s/ LARRY C. OLDHAM
----------------------------------
LARRY C. OLDHAM,
PRESIDENT AND
PRINCIPAL FINANCIAL OFFICER
(1stqtr98.10q.msworks)
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<ARTICLE> 5
<S> <C>
<PERIOD-TYPE> 3-MOS
<FISCAL-YEAR-END> DEC-31-1998
<PERIOD-END> MAR-31-1998
<CASH> 289,149
<SECURITIES> 0
<RECEIVABLES> 8,969,472
<ALLOWANCES> 28,130
<INVENTORY> 0
<CURRENT-ASSETS> 9,274,653
<PP&E> 68,009,607
<DEPRECIATION> 17,444,918
<TOTAL-ASSETS> 59,900,412
<CURRENT-LIABILITIES> 4,881,979
<BONDS> 16,632,610
<COMMON> 181,207
0
60,000
<OTHER-SE> 34,925,263
<TOTAL-LIABILITY-AND-EQUITY> 59,900,412
<SALES> 0
<TOTAL-REVENUES> 2,112,563
<CGS> 0
<TOTAL-COSTS> 1,708,843
<OTHER-EXPENSES> (9,177)
<LOSS-PROVISION> 0
<INTEREST-EXPENSE> 304,202
<INCOME-PRETAX> 108,695
<INCOME-TAX> 35,869
<INCOME-CONTINUING> 72,826
<DISCONTINUED> 0
<EXTRAORDINARY> 0
<CHANGES> 0
<NET-INCOME> 72,826
<EPS-PRIMARY> .004
<EPS-DILUTED> .004
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