U.S. SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
________________________________
FORM 10-QSB
/X/ Quarterly Report Under Section 13 or 15(d) of the Securities
Exchange Act of 1934
For the Quarterly Period Ended March 31, 1997
or
/ / Transition Report Under Section 13 or 15(d) of the Securities
Exchange Act of 1934
For the Transition Period From __________ to ___________
______________________
Commission File Number 0-7406
______________________
PrimeEnergy Corporation
(Exact name of registrant as specified in its charter)
Delaware
(State or other jurisdiction of incorporation or organization)
84-0637348
(IRS employer identification number)
One Landmark Square, Stamford, Connecticut 06901
(Address of principal executive offices)
(203) 358-5700
(Registrant's telephone number, including area code)
(Former name, former address and former fiscal year, if changed since
last report)
Check whether the issuer (1) filed all reports required to be filed by
Section 13 or 15 (d) of the Securities Exchange Act of 1934 during the
past 12 months (or for such shorter period that the Registrant was
required to file such reports), and (2) has been subject to such
filing requirements for the past 90 days. Yes /X/ No / /
The number of shares outstanding of each class of the Registrant's
Common Stock as of May 9, 1997 was: Common Stock, $0.10 par value,
4,684,649 shares.
PrimeEnergy Corporation
Index to Form 10-QSB
March 31, 1997
Part I - Financial Information
Consolidated Balance Sheets - March 31, 1997 and
December 31, 1996 3-4
Consolidated Statements of Operations for the three months
ended March 31, 1997 and 1996 5
Consolidated Statement of Stockholders' Equity for the
three months ended March 31, 1997 6
Consolidated Statements of Cash Flows for the three months
ended March 31, 1997 and 1996 7
Notes to Consolidated Financial Statements 9-17
Management's Discussion and Analysis of Financial Condition
and Results of Operations 18-23
Part II - Other Information 24
Signatures 25
PrimeEnergy Corporation
Consolidated Balance Sheets
March 31, 1997 and December 31, 1996
March 31, December 31,
1997 1996
(Unaudited) (Audited)
Current assets:
Cash and cash equivalents $ 2,779,000 $ 3,316,000
Restricted cash and cash
equivalents (Note 2) 623,000 663,000
Accounts receivable (Note 3) 4,362,000 5,052,000
Due from related parties (Note 10) 1,479,000 2,184,000
Other current assets 267,000 266,000
Prepaid expenses 108,000 150,000
Deferred income taxes 119,000 119,000
---------- ----------
Total current assets 9,737,000 11,750,000
---------- ----------
Property and equipment, at cost(Notes 1 and 4):
Oil and gas properties (successful
efforts method)
Proved 37,744,000 36,645,000
Unproved 262,000 179,000
Furniture, fixtures and equipment
including leasehold improvements 5,380,000 5,269,000
---------- ----------
43,386,000 42,093,000
Accumulated depreciation and depletion (23,343,000) (21,860,000)
---------- ----------
Net property and equipment 20,043,000 20,233,000
---------- ----------
Other assets 607,000 607,000
Due from affiliates 325,000 325,000
---------- ----------
Total assets $ 30,712,000 $32,915,000
========== ==========
See accompanying notes to the consolidated financial statements.
PrimeEnergy Corporation
Consolidated Balance Sheets
March 31, 1997 and December 31, 1996
March 31, December 31,
1997 1996
(Unaudited) (Audited)
Current liabilities:
Current portion of other long-term
obligations (Note 6) $ 69,000 $ 73,000
Accounts payable 6,074,000 5,297,000
Accrued liabilities:
Payroll, Benefits and Related Items 785,000 494,000
Taxes (Note 1) 51,000 11,000
Interest and other 602,000 774,000
Due to related parties (Note 10) 1,111,000 1,298,000
---------- ----------
Total current liabilities 8,692,000 7,947,000
---------- ----------
Long-term bank debt (Note 5) 14,325,000 17,400,000
Other long-term obligations (Note 6) 231,000 243,000
Deferred income taxes (Note 1) 240,000 240,000
Payable for encumbered treasury
stock (Note 7) 392,000 621,000
Stockholder's equity:
Preferred stock, $.10 par, authorized
10,000 shares; none issued -- --
Common stock, $.10 par value, authorized
15,000,000 shares; issued 7,597,970
in 1996 and 1995 760,000 760,000
Paid in capital 10,888,000 10,888,000
Retained earnings(accumulated deficit) 531,000 (53,000)
Encumbered treasury stock (Note 7) (392,000) (621,000)
---------- ----------
11,787,000 10,974,000
Treasury stock, at cost, 2,913,321
common shares in 1997 and 2,867,349
common shares in 1996 (4,955,000) (4,510,000)
---------- ----------
Total stockholders' equity 6,832,000 6,464,000
---------- ----------
Total liabilities and equity $30,712,000 $32,915,000
========== ===========
See accompanying notes to the consolidated financial statements.
PrimeEnergy Corporation
Consolidated Statements of Operations
Three Months Ended March 31, 1997 and 1996
(Unaudited)
1997 1996
Revenue:
Oil and gas sales $ 4,277,000 $ 1,621,000
District operating income 2,653,000 2,294,000
Administrative revenue (Note 10) 363,000 386,000
Reporting and management fees (Note 10) 82,000 87,000
Interest and other income 33,000 58,000
---------- ----------
Total revenue 7,408,000 4,446,000
---------- ----------
Costs and expenses:
Lease operating expense 1,650,000 1,037,000
District operating expense 2,116,000 1,765,000
Depreciation and depletion of
oil and gas properties 1,290,000 624,000
General and administrative expense 806,000 688,000
Exploration costs 643,000 184,000
Interest expense (Notes 5 and 6) 276,000 138,000
---------- ----------
Total costs and expenses 6,781,000 4,436,000
---------- ----------
Income from operations 627,000 10,000
Gain on sale and exchange of assets 22,000 45,000
---------- ----------
Net income before income taxes 649,000 55,000
Provision for income taxes 65,000 19,000
---------- ----------
Net income $ 584,000 $ 36,000
========== ==========
Primary income per common share (Note 11) $0.11 $0.01
==== ====
Fully diluted income per common share (Note 11) $0.11 $0.01
==== ====
See accompanying notes to consolidated financial statements.
PrimeEnergy Corporation
Consolidated Statement of Stockholder's Equity
Three Months Ended March 31, 1997
<TABLE>
<CAPTION>
Retained
Add'l Earnings Encumbered
Common Stock paid in (Accumulated Treasury Treasury
Shares Amount Capital Deficit) Stock Stock Total
-------- -------- -------- -------- --------- --------- --------
<S> <C> <C> <C> <C> <C> <C> <C>
Balance at December 31, 1996 $7,597,970 $760,000 $10,888,000 ($53,000) ($4,510,000) ($621,000) $6,464,000
Purchased 45,972 shares of -- -- -- -- -- -- --
common stock (216,000) (216,000)
Amortization of (229,000) 229,000 --
Encumbered Treasury Stock
(Note 7)
Net income 584,000 -- -- 584,000
----------- -------- ------------ ---------- ----------- ---------- ----------
Balance at March 31, 1997 $7,597,970 $760,000 $10,888,000 $531,000 ($4,955,000) $392,000 $6,832,000
=========== ========= ============ ========= ============ ========= ===========
</TABLE>
See accompanying notes to consolidated financial statements.
PrimeEnergy Corporation
Consolidated Statements of Cash Flows
Three Months Ended March 31, 1997 and 1996
(Unaudited)
March 31, March 31,
1997 1996
Net cash provided by operating activities $ 4,261,000 $ 1,722,000
---------- ----------
Cash flows from investing activities:
Additions to property and equipment (1,306,000) (490,000)
Proceeds from sale of property
and equipment 24,000 54,000
Proceeds from payment on notes receivable 20,000 --
---------- ----------
Net cash used in investing activities (1,262,000) (436,000)
---------- ----------
Cash flows from financing activities:
Purchase of treasury stock (445,000) (26,000)
Increase in long-term bank debt and
other long-term obligations 7,405,000 2,707,000
Repayment of long-term bank debt and
other long-term obligations (10,496,000) (4,133,000)
---------- ----------
Net cash used in financing activities (3,536,000) (1,452,000)
---------- ----------
Net increase (decrease) in cash and
cash equivalents (537,000) (166,000)
Cash and cash equivalents at the
beginning of the period 3,316,000 1,009,000
---------- ----------
Cash and cash equivalents at the
end of the period $ 2,779,000 $ 843,000
========== ==========
See accompanying notes to consolidated financial statements.
PrimeEnergy Corporation
Notes to Consolidated Financial Statements
March 31, 1997
(1) Description of Operations and Significant Accounting Policies:
Nature of Operations-
The Company is engaged in the development, acquisition and production of oil
and natural gas properties. The Company owns leasehold, mineral and royalty
interests in producing and non- producing oil and gas properties across the
continental United States, including Colorado, Kansas, Louisiana,
Mississippi, Montana, Nebraska, Nevada, New Mexico, North Dakota,
Oklahoma, Texas, Utah, West Virginia and Wyoming. The Company operates
approximately 1,762 wells and owns non-operating interests in
approximately 1,052 additional wells. Additionally, the Company provides
well-servicing support operations, site preparation and construction services
for oil and gas drilling and rework operations, both in connection with the
Company's activities and in providing contract services for third parties.
The Company is publicly traded on NASDAQ under the symbol "PNRG".
The markets for the Company's products are highly competitive, as oil and gas
are commodity products and prices depend upon numerous factors beyond the
control of the Company, such as economic, political and regulatory
developments and competition from alternative energy sources.
Principles of Consolidation-
The consolidated financial statements include the accounts of
PrimeEnergy Corporation and its wholly-owned subsidiaries. All
material inter-company accounts and transactions between these entities
have been eliminated. Oil and gas properties include ownership interests
in the Partnerhips. The statement of operations includes the Company's
proportionate share of revenue and expenses related to oil and gas
interests.
Use of Estimates-
The preparation of financial statements in conformity with generally
accepted accounting principles requires management to make estimates
and assumptions that affect the reported amounts of assets and liabilities
and disclosure of contingent assets and liabilities at the date of the
financial statements and the reported amounts of revenues and expenses
during the reporting period. Actual results could differ from those
estimates.
Estimates of oil and gas reserves, as determined by independent petroleum
engineers, are continually subject to revision based on price, production
history and other factors. Depletion expense, which is computed based on
the units of production method, could be significantly impacted by changes
in such estimates. Additionally, FAS 121 requires that, if the expected
future cash flow from an asset is less than its carrying cost, that asset
must be written down to its fair market value. As the fair market value of a
property is generally substantially less than the total future cash flow
expected from the asset, small changes in the estimated future net revenue
from an asset could lead to the necessity of recording a significant
impairment.
The Company has significant deferred tax assets which have been fully
reserved against based upon the assumption that at current and expected
future levels of taxable income, and considering the Section 29 credits the
Company expects to generate, the availability of these carryforwards will
not lead to significant reductions in the Company's tax liability as
compared to what it would pay if such carryforwards did not exist.
Increases in estimates of future taxable income could lead to significant
reductions in the amount of this reserve, which could have a material
effect on the net income of the Company.
Property and Equipment-
The Company follows the "successful efforts" method of accounting for
its oil and gas properties. Under the successful efforts method,
costs of acquiring undeveloped oil and gas leasehold acreage, including
lease bonuses, brokers' fees and other related costs are capitalized.
Provisions for impairment of undeveloped oil and gas leases are based on
periodic evaluations. Annual lease rentals and exploration expenses,
including geological and geophysical expenses and exploratory dry hole
costs, are charged against income as incurred.
All other property and equipment are carried at cost. Depreciation
and depletion of oil and gas production equipment and properties are
determined under the unit-of-production method based on estimated proved
recoverable oil and gas reserves. Depreciation of all other equipment is
determined under the straight-line method using various rates based on
useful lives. The cost of assets and related accumulated depreciation is
removed from the accounts when such assets are disposed of, and any related
gains or losses are reflected in current earnings.
Effective January 1, 1996, the Company adopted the provisions of
Statement of Financial Accounting Standards No. 121, "Accounting for
the Impairment of Long-Lived Assets and for Long Lived Assets to Be
Disposed Of" ("SFAS No. 121"). Prior to the adoption of SFAS No. 121,
the total amount of unamortized capitalized cost was limited to the
aggregated undiscounted value of future net revenues, based on current
prices and cost. SFAS No. 121 requires that long-lived assets held and
used by a company, including oil and gas properties accounted for under
the successful efforts method of accounting, be reviewed for impairment
whenever events or changes in circumstances indicate that the carrying
amount of an asset may not be recoverable. The Company determines whether
an impairment has occurred by estimating the undiscounted expected future
net cash flows of its oil and gas properties at a field level and compares
such cash flows to the carrying amount of the oil and gas properties to
determine if the carrying amount is recoverable. For those oil and gas
properties for which the carrying amount exceeds the undiscounted
estimated future cash flows, an impairment is determined to exist.
The carrying amount of such properties is adjusted to their estimated net
fair value based on discounted cash flows. The Company recognized a
non-cash charge of $184,000 related to the impairment oil and gas
properties during 1996, which was included in depreciation, depletion
and amortization expense.
Income Taxes-
The Company records income taxes in accordance with Statement of Financial
Accounting Standards ("SFAS") No. 109, "Accounting for Income Taxes". SFAS
No. 109 is an asset and liability approach to accounting for income taxes,
which requires the recognition of deferred tax assets and liabilities
for the expected future consequences of events that have been recognized
in the company's financial statements or tax returns.
Deferred tax liabilities or assets are established for temporary differences
between financial and tax reporting bases and are subsequently adjusted to
reflect changes in the rates expected to be in effect when the temporary
differences reverse. A valuation allowance is established for any deferred
tax asset for which realization is not likely.
General and Administrative Expenses-
General and administrative expenses represent costs and expenses associated
with the operation of the Company. Certain partnerships and trusts
sponsored by the Company reimburse general and administrative expenses
incurred on their behalf.
Income per share-
Income per share of common stock has been computed based on the weighted
average number of common shares and common stock equivalents outstanding
during the respective periods.
Statements of cash flows-
For purposes of the consolidated statements of cash flows, the Company
considers short-term, highly liquid investments with original maturities
of less than ninety days to be cash equivalents.
Concentration of Credit Risk-
The Company maintains significant banking relationships with financial
institutions in the State of Texas. The Company limits its risk by
periodically evaluating the relative credit standing of these financial
institutions. The Company's oil and gas production purchasers consist
primarily of independent marketers and major gas pipeline companies.
Hedging-
From time to time, the Company may enter into futures contracts in order to
reduce its exposure related to changes in oil and gas prices. In
accordance with Statement of Financial Accounting Standards No. 80, any
gain or loss on such contracts is treated as an adjustment to oil and gas
revenue.
Recently Issued Accounting Standards-
In October 1995, FAS Statement No. 123, "Accounting for Stock-Based
Compensation", was issued, effective January 1, 1996. The Company will
continue to measure compensation costs for its employee stock compensation
as prescribed by APB Opinion No. 25, "Accounting for Stock Issued to
Employees", and comply with the disclosure requirements of FAS Statement
No. 123 rather than record compensation expense in accordance with the new
standard. Recording compensation expense in accordance with the standard
would not have a significant effect on the Company's results of
operations.
In October 1996, the American Institute of Certified Public Accountants
issued Statement of Position (SOP) 96-1, "Environmental Remediation
liabilities". SOP 96-1 was adopted by the Company on January 1, 1997.
It requires, among other things, that environmental remediation liabilities
be accrued when the criteria of SFAS No. 5, "Accounting for Contingencies",
have been met. SOP 96-1 also provides guidance with respect to the
measurement of the remediation liabilities. Such accounting is consistent
with the company's current method of accounting for environmental
remediation costs. Therefore adoption of SOP 96-1 will not have a
material impact on the company's financial position or results of
operations.
(2) Restricted Cash and Cash Equivalents:
Restricted cash and cash equivalents includes $623,000 and
$663,000 at March 31, 1997 and December 31, 1996, respectively,
of cash primarily pertaining to unclaimed royalty payments. There
were corresponding accounts payable recorded at March 31, 1997
and December 31, 1996 for these liabilities.
(3) Accounts Receivable
Accounts receivable at March 31, 1997 and December 31, 1996
consisted of the following:
March 31, December 31,
1997 1996
Joint Interest Billing $ 1,294,000 $ 1,533,000
Trade Receivables 117,000 126,000
Oil and Gas Sales 2,913,000 3,337,000
Other 75,000 99,000
--------- ---------
4,399,000 5,095,000
Less, Allowance for doubtful
accounts (37,000) ( 43,000)
--------- ---------
$ 4,362,000 $ 5,052,000
========= =========
(4) Property and equipment
Property and equipment at March 31, 1997 and December 31, 1996
consisted of the following:
March 31, December 31,
1997 1996
Developed oil and gas
properties at cost $37,013,000 $35,952,000
Undeveloped oil and gas
properties at cost 993,000 872,000
Less, accumulated depletion
and depreciation (19,951,000) (18,661,000)
------------ ------------
18,055,000 18,163,000
------------ ------------
Furniture, fixtures and
and equipment 5,380,000 5,269,000
Less, accum. depreciation (3,392,000) (3,199,000)
---------- ----------
1,988,000 2,070,000
---------- ----------
Total net property and
equipment $20,043,000 $20,233,000
========== ==========
(5) Long-Term Bank Debt
At December 31, 1996, the Company was party to a line of credit
agreement with a bank with a non-reducing borrowing base of $19
million. Twenty-five percent of the borrowing is syndicated to a
second bank. During 1996, the agreement provided for interest at
1/2% over the bank's base rate as defined, or 2-3/4% over the
London Inter-Bank Offered Rate (LIBO) rate for the interest
period in question, payable at the end of the interest period.
On February 6, 1997, the bank extended the borrowing base to $21
million. The credit agreement was also amended to provide for
interest on outstanding borrowings at the bank's base rate, as
defined, or 2 1/4% over the LIBO rate.
Advances pursuant to the agreement are limited to the borrowing
base as defined in the agreement. Most of the Company's oil and
gas properties as well as certain receivables and equipment were
pledged as security under this agreement. Under the Company's
credit agreement, the Company is required to maintain, as
defined, a minimum current ratio, tangible net worth, debt
coverage ratio and interest coverage ratio.
(6) Other Long-Term Obligations:
Other long-term obligations at March 31, 1997 and December 31,
1996 consisted of the following:
March 31, December 31,
1997 1996
Subordinated debentures due
December 31, 1998 $ 225,000 $ 225,000
Capital lease obligations 75,000 91,000
--------- ---------
300,000 316,000
Less, current portion (69,000) (73,000)
--------- ---------
$ 231,000 $ 243,000
========= =========
The secured subordinated debentures are held by affiliated
Partnerships in which PEMC is a general partner. Interest was
payable at 9.25% through 1995, 6.5% through 1996 and 1% above
year end money market rates thereafter.
(7) In June of 1996, the Company entered into an agreement to purchase
400,000 shares of the Company's common stock from McJunkin
Corporation. The Company agreed to make 15 monthly payments of
$80,000 beginning on June 1, 1996, with the shares held in escrow
until such payments have been made. The shares are classified as
encumbered treasury stock on the balance sheet, and will be un-
encumbered in proportion to the payments made under the
agreement. The liability for future payments under the note, less
imputed interest, is shown as "Payable for Encumbered Treasury
Stock" on the balance sheet.
(8) Contingent Liabilities:
PEMC, as managing general partner of the affiliated Partnerships,
is responsible for all Partnership activities, including the
review and analysis of oil and gas properties for acquisition,
the drilling of development wells and the production and sale of
oil and gas from productive wells. PEMC also provides the
administration, accounting and tax preparation work for the
Partnerships. PEMC is liable for all debts and liabilities of
the affiliated Partnerships, to the extent that the assets of a
given limited Partnership are not sufficient to satisfy its
obligations.
As a general partner, PEMC is committed to offer to purchase the
limited partners' interests in certain of its managed Partnerships
at various annual intervals. Under the terms of a partnership
agreement, PEMC is not obligated to purchase an amount greater
than 10% of the total partnership interest outstanding. In
addition, PEMC will be obligated to purchase interests tendered
by the limited partners only to the extent of one-hundred fifty
(150) percent of the revenues received by it from such
partnership in the previous year. Purchase prices are based upon
annual reserve reports of independent petroleum engineering firms
discounted by a risk factor. Based upon historical production
rates and prices, management estimates that if all such offers
were to be accepted, the maximum annual future purchase
commitment would be approximately $500,000.
(9) Stock Options and Other Compensation:
In May 1989, non-statutory stock options were granted by the
Company to four key executive officers for the purchase of shares
of common stock. In each case such options are for a term of ten
years ending May 15, 1999, and are exercisable, on a cumulative
basis, as to twenty percent of the shares subject to option in
each year, beginning one year after the granting of the option.
At March 31, 1995, options on 802,500 shares were outstanding and
exercisable at prices ranging from $1.00 to $1.25.
On January 27, 1983, the Company adopted the 1983 Incentive Stock
Option Plan. At March 31, 1997 and 1996, options on 124,000 and
134,000 shares were exercisable at $1.50 per share, respectively,
and no additional shares were available for granting.
(10) Related Party Transactions:
PEMC is a general partner in several oil and gas Partnerships in which
certain directors have limited and general partnership interests.
A substantial portion of the assets and revenues of PEMC are derived from its
sponsorship of the Partnerships and the interests of PEMC in the oil and
gas properties acquired by the Partnerships. As the managing general
partner in each of the Partnerships, PEMC receives approximately 5% to 12%
of the net revenues of each Partnership as a carried interest in the
Partnerships' properties.
The Partnership agreements allow PEMC to receive management fees for
various services to the Partnerships as well as reimbursement for
property acquisition and development costs incurred on behalf of the
Partnerships and general and administrative overhead, which is reported in
the statements of operations as administrative revenue.
In 1991, the Company loaned approximately $325,000 at 12% interest to a
real estate limited partnership of which a Company Officer and Director
is a general partner. This loan is secured by a mortgage on the underlying
real estate in the partnership and the Company received a 23% equity
participation in the partnership. The loan agreement provides for
interest payments on a quarterly basis provided the cash flow from
operations of the limited partnership are sufficient to pay interest for
the quarter. If cash flows are not sufficient, the accrued interest is added
to the principal. This loan is included in other non-current assets on the
balance sheet.
Due to related parties at March 31, 1997 and December 31, 1996 primarily
represent receipts collected by the Company, as agent, from oil and gas
sales net of expenses. Receivables from affiliates consist of
reimbursable general and administrative costs, lease operating expenses
and reimbursements for property acquisitions and related costs.
11) Income per share:
The weighted average number of common shares and common stock equivalents
outstanding used in the income per share calculation are as follows:
Three Months Ended
March 31,
1997 1996
Primary 5,407,036 5,745,674
========= =========
Fully diluted 5,416,754 5,747,695
========= =========
12) Subsequent events:
During the second quarter of 1997 the Company sold, in separate transactions,
two properties located in New Mexico for a total consideration of $847,000.
A net gain of approximately $102,000 was realized on these sales.
Item 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS
This discussion should be read in conjunction with the financial statements
of the Company and notes thereto. The Company's subsidiaries are defined
in Note 1 of the financial statements. PEMC is the managing general partner
or managing trustee in several Limited Partnerships and Trusts
(collectively, the "Partnerships").
LIQUIDITY AND CAPITAL RESOURCES
The Company feels that it has the ability to generate sufficient amounts
of cash to meet long-term liquidity needs, as well as debt service.
The Company expects to generate increased cash flows by increasing its
reserve base through continued acquisitions and development. By increasing
its reserve base, the Company's borrowing ability is increased due to
additional properties available as collateral.
On April 26, 1995, the Company entered into a revised credit agreement
with Bank One, Texas NA providing for a $12.5 million revolving line
of credit on a $50 million master promissory note. This new agreement
introduced Den norske Bank, AS as a 25% syndication partner in the
line, once the Company reaches borrowings of $12.5 million for over
one month. The agreement also provides for a lower floating rate
compared to previous agreements as well as the ability to borrow based
upon the London Inter-Bank Offered Rate (LIBO). The borrowing base is
non-reducing and is revised every six months by the banks.
During 1996, the interest rate on this line of credit was 1/2% over the
bank's base rate, as defined, monthly, or 2 3/4% over the published LIBO
rate, payable at the end of the applicable interest period. Effective
February 6, 1997, the agreement was amended, lowering the interest rate to
the banks base rate, as defined, monthly, or 2 1/4% over the published LIBO
rate. Pursuant to the semi-annual redetermination of the borrowing base,
the Company's line of credit was increased to $21,000,000. This amount
reflects the increase in the companies reserve and borrowing base due to the
purchase and development of properties acquired in Saratoga acquisition, and
the success of the company's 3D drilling program, both of which are
described below.
Most of the Company's oil and gas properties as well as certain
receivables and equipment are pledged as security under the agreement.
The Company is required to maintain, as defined, a minimum current
ratio, tangible net worth, and debt and interest coverage ratios, and
restrictions are placed on the Company's ability to pay dividends and
purchase treasury stock.
During 1996, the Company entered into an agreement to purchase 400,000
shares of its common stock for total consideration of $1,144,000. Of this
amount, $523,000 was paid in 1996, $229,000 was paid in the first quarter
of 1997, and $392,000 will be paid during the remainder of 1997. The
Company also spent $216,000 during the first quarter of 1997 to acquire
treasury stock in open market transactions.
The Company's primary source of working capital during the first three
months of 1997 was through internally generated funds coupled with cash
balances at the prior year-end. Net cash provided by operations was used
primarily to repay bank debt and continue property development.
During the second quarter of 1997 the Company sold a group of outside
operated wells located in New Mexico for $680,000. A group of operated
properties located in New Mexico were sold in the second quarter for
$167,000. The Company will report a net gain from the sale these properties
of approximately $102,000. These net cash flow received from these
properties in the first quarter of 1997 was $105,000.
In May of 1996, the Company purchased from Internationale Nederlanden (U.S.)
Capital Corporation properties formerly owned by Saratoga Resources Inc.
(the Saratoga Properties) for $7,180,000. The addition of these properties
has significantly increased the Company's cash flow.
From the inception of the program through March 31, 1997, the Company had
spent $4,563,000 on its 3D seismic exploration and development program
(3D Drilling Program). It is anticipated that the Company will spend
several million dollars more on this program during the remainder of 1997.
The Company has, to date, drilled eight wells as part of this program,
seven of which have been completed as commercial gas wells. The Company is
currently receiving significant cash flow from these wells.
During the first quarter, the Company spent approximately $1,824,000 on the
acquisition and development of its oil and gas interests. This amount
includes $643,000 of exploration costs related to an area in which the
Company intends to drill two wells during the second quarter of the year,
and $422,000 spent to buy back interests in partnerships in which the
Company is a general partner. Additionally, the Company spent approximately
$73,000 on trucks, automobiles and equipment used in connection with field
service operations, and an additional $49,000 on computer and related
equipment and software.
RESULTS OF OPERATIONS
Net income increased to $584,000 in the first quarter of 1997 as compared
to $36,000 in the first quarter of 1996. The primary factors causing this
large increase were the contributions to income made by the Saratoga and
the 3D Drilling Program properties, as well as sharply higher prices
received for oil and gas production.
As a result of the Saratoga acquisition and the success of the Company's
recent drilling, oil and gas revenue accounted for 58% of total revenue in
the first quarter of 1997 as compared to 36% in the comparable period in
1996. As oil and gas prices can be highly volatile, this may lead to
greater variability in the Company's profitability and cash flow in the
future. In addition, the Company has greatly increased its drilling and
exploration activities. The risk inherent in these activities, coupled
with the requirement that certain costs incurred in these activities
must be expensed as incurred, can be expected to lead to greater
volatility in earnings in the future.
Oil and gas sales of $4,278,000 represent an increase of $2,657,000 over
1996 first quarter sales of $1,621,000. Production from directly owned
properties, expressed in barrel of oil equivalents (BOE's), more than
doubled between the two periods. These increases are primarily attributable
to the contributions of the Saratoga properties and 3D drilling program
wells, which contributed $1,075,000 and $799,000, respectively, in the
first quarter of 1997. Sharply higher oil and gas prices also contributed
to this rise. The average price received per barrel increased to $21.49 in
the first quarter 1997 as compared to $18.14 in the first quarter 1996, and
the average price received for an MCF of gas rose to $2.92 in 1997 as compared
to $2.15 in 1996.
District operating income increased 16% in the first quarter of 1997 as
compared to the comparable period in 1996, primarily due to income from
the operation of the Saratoga properties.
Administrative revenue for the first quarter of 1997 decreased about 6%
from the comparable period in 1996. Amounts received in both years from
certain partnerships are substantially less than the amounts allocable to
those Partnerships under the Partnership agreements. The lower amounts
reflect PEMC's efforts to limit costs incurred and those allocated to
the Partnerships.
Lease operating expense of $1,650,000 in the first quarter of 1997
represents a 59% increase over the $1,037,000 incurred in the first quarter
of 1996. The newly acquired Saratoga and 3D Drilling Program wells
contributed $346,000 and $100,000 respectively to this increase. Lease
operating expense relating to the Company's interest in partnerships
increased by $61,000, due primarily to additional interests in these
partnerships purchased during the year.
Average lifting costs on directly owned properties declined from $9.85 per
barrel of oil equivalent (BOE) in the first quarter of 1996 to $6.96 in 1997.
This decrease is largely due to the fact that the wells drilled as part of the
Company's 3D Drilling Program produced 48,000 BOE's in 1997, while contributing
only $100,000 to lease operating expense, an average cost of $2.06 per BOE.
Average lifting costs on the Saratoga properties were $6.41 per BOE, also
helping to lower the overall average.
The Company receives reimbursement for costs incurred related to the
evaluation, acquisition and development of properties on behalf of its
related partnerships, trusts, and other joint venture partners. To the
extent that these costs are expended at the district level, the
reimbursements reduce total district operating expenses. Alternatively,
if the expenses are incurred by PEMC, such reimbursements reduce total
general and administrative expenses. Property acquisition cost
reimbursement remained relatively constant at approxiametly $300,000 in
both the first quarter of 1997 and the first quarter of 1996.
General and administrative expenses of $808,000 in the first quarter of
1997, equaled about 11% of total revenue in that period. In the first
quarter of 1996, general and administrative expenses were approximately
15% of total revenue. This decline is largely attributable to the fact
that the Saratoga acquisition greatly expanded the scope of the Company's
operations without requiring a proportionate increase in office personnel
and related costs.
Depreciation, depletion and amortization (DD&A) of oil and gas properties
of $1,290,000 represents a $667,000 increase over the $623,000 expense
recorded in the first quarter of 1996. This increase is attributable to
the Saratoga and 3D Drilling Program properties, which contributed
$421,000 and $359,000, respectively, to DD&A expense in the first
quarter of 1997.
First quarter 1997 exploration costs of $643,000 consist primarily of the
cost of a 3D seismic shoot made in an attempt to identify locations for
exploratory drilling. The Company plans to drill two wells on the
acreage covered by this seismic shoot during the second quarter of 1997.
The Company spent $575,000 on 3D seismic in April of 1997, which will
be charged to expense in the second quarter.
Interest expense doubled to $276,000 in the first quarter of 1997 from
$138,000 in the first quarter of 1996, due to higher debt levels associated
with the Saratoga acquisition.
Item 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
The Annual Meeting of Stockholders of the Registrant will be held on
Wednesday, June 18, 1997 to elect a Board of Directors and to transact
such other procedural business as may properly be brought before the
meeting.
Item 6.
No reports on form 8K were filed by the Company during the three months ended
March 31, 1997.
Exhibit 27 - Financial Data Schedule is attached to the electronic filing of
this report only.
SIGNATURES
Pursuant to the requirements of the Securities and Exchange Act of 1934,
Registrant has duly caused this report to be signed on its behalf by the
undersigned thereunto duly authorized.
PrimeEnergy Corporation
(Registrant)
May 14, 1997 /s/ Charles E. Drimal, Jr.
(Date) --------------------------
Charles E. Drimal, Jr.
President
Principal Executive Officer
May 14, 1997 /s/ Beverly A. Cummings
(Date) --------------------------
Beverly A. Cummings
Executive Vice President
Principal Financial and
Accounting Officer
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This schedule contains summary financial information extracted from
PrimeEnergy Corporation's form 10QSB and is qualified in its entirety by
reference to such financial statements.
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<PERIOD-END> MAR-31-1997
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