UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
Quarterly Report Pursuant to Section 13 or 15(d) of the
Securities Exchange Act of 1934
For the quarterly period ended June 30, 2000
Commission File Number 333-42641
RAM Energy, Inc.
(Exact name of registrant as specified in its charter.)
Delaware 52-1535102
(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification No.)
5100 East Skelly Drive, Suite 650
Tulsa, Oklahoma 74135
(Address of principal executive offices) (Zip Code)
Registrant's telephone number, including area code:
(918) 632-0620
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 the number of shares outstanding of each of the
issuer's classes of common stock, as of the latest practical
date:
2,727,000 shares of common stock issued and outstanding
<PAGE>
RAM ENERGY, INC.
FORM 10-Q
TABLE OF CONTENTS
Page
PART I. FINANCIAL INFORMATION
Item 1. Financial Statements
Consolidated Balance Sheets - December 31, 1999 and June
30, 2000 (unaudited)
Consolidated Statements of Operations - Three months and
six months ended June 30, 1999 and 2000 (unaudited)
Consolidated Statements of Cash Flows - Three months and
six months ended June 30, 1999 and 2000 (unaudited)
Notes to Consolidated Financial Statements (unaudited)
Item 2. Management's Discussion and Analysis of Financial
Condition and Results of Operations
Item 3. Quantitative and Qualitative Disclosures about Market Risk
PART II. OTHER INFORMATION
Item 1. Legal Proceedings
Item 2. Changes in Securities
Item 3. Defaults Upon Senior Securities
Item 4. Submission of Matters to a Vote of Security Holders
Item 5. Other Information
Item 6. Exhibits and Reports on Form 8-K
Exhibits and Reports on Form 8-K
SIGNATURES
<PAGE>
PART I. FINANCIAL INFORMATION
Item 1. Financial Statements
<TABLE>
RAM Energy, Inc.
Consolidated Balance Sheets
(Dollars in Thousands)
<CAPTION>
December 31 June 30,
1999 2000
---- ----
(Unaudited)
<S> <C> <C>
Assets
Current assets:
Cash and cash equivalents $ 1,875 $ 4,385
Accounts receivable:
Oil and gas sales 3,587 3,049
Joint interest operations, net of allowance
for doubtful accounts of $459 in 1999 and
$471 in 2000 1,164 956
Related parties 219 234
Other 16 528
Prepaid expenses and deposits 361 219
-------- --------
Total current assets 7,222 9,371
Properties and equipment, at cost:
Oil and gas properties and equipment, based on
full cost accounting 119,227 122,245
Gathering and disposal systems 39,623 39,636
Other property and equipment 3,940 4,024
-------- --------
162,790 165,905
Less accumulated amortization and depreciation 40,103 45,273
-------- --------
Net properties and equipment 122,687 120,632
Other assets:
Deferred loan costs, net of accumulated
amortization of $1,042 in 1999 and $1,312 in
2000 1,578 1,355
Deferred offering costs, net of accumulated
amortization of $865 in 1999 and $1,100 in
2000 3,837 3,602
Other 473 341
-------- --------
Total assets $135,797 $135,301
======== ========
Liabilities and stockholders' deficiency
Current liabilities:
Accounts payable:
Trade $ 1,372 $ 2,247
Oil and gas proceeds due others 4,539 5,795
Related party 217 -
Accrued liabilities:
Compensation 122 99
Interest 4,707 5,096
Gas balancing liability and other 639 847
Long-term debt due within one year 103 86
-------- --------
Total current liabilities 11,699 14,170
Gas balancing liability not expected to be
to be settled within one year 2,509 1,896
Long-term debt due after one year 129,253 130,033
Other noncurrent liabilities - 1,580
Deferred income taxes 11,406 9,615
Commitments and contingencies 600 600
Stockholders' deficiency:
Preferred stock, $.01 par value; authorized -
5,000,000 shares; none issued - -
Common stock, $.01 par value; authorized -
15,000,000 shares; issued and outstanding -
2,727,000 shares 27 27
Paid-in capital 16 16
Accumulated deficit (19,713) (22,636)
-------- --------
Stockholders' deficiency (19,670) (22,593)
-------- --------
Total liabilities and stockholders' deficiency $135,797 $135,301
======== ========
</TABLE>
See accompanying notes.
<TABLE>
RAM Energy, Inc.
Consolidated Statements of Operations
(Unaudited)
(Dollars in Thousands, Except for Per Share Amounts)
<CAPTION>
Three months ended Six months ended
June 30, June 30,
1999 2000 1999 2000
---------------- ----------------
<S> <C> <C> <C> <C>
Operating revenues:
Oil and gas sales $ 5,325 $ 6,712 $ 11,438 $ 12,861
Gathering systems 2,299 2,671 3,969 5,372
Other 203 53 390 217
--------- --------- --------- ---------
Total operating revenues 7,827 9,436 15,797 18,450
Operating expenses:
Oil and gas production expenses 1,947 1,946 3,814 3,594
Gathering system purchases 1,657 2,050 2,816 4,104
Gathering system operations 117 105 214 212
Amortization and depreciation 3,369 2,719 6,653 5,675
General and administrative,
overhead and other expenses,
net of operator's overhead fees
to unrelated interests 1,172 778 2,285 2,081
--------- --------- --------- ---------
Total operating expenses 8,262 7,598 15,782 15,666
--------- --------- --------- ---------
Operating income (loss) (435) 1,838 15 2,784
Other income (expense):
Interest expense (3,650) (3,765) (7,291) (7,570)
Interest income 21 37 99 72
Equity in loss of RVC
Energy, Inc. (404) - (780) -
--------- --------- --------- ---------
Loss before income taxes (4,468) (1,890) (7,957) (4,714)
Income taxes (1,415) (720) (2,715) (1,791)
--------- --------- --------- ---------
Net loss $ (3,053) $ (1,170) $ (5,242) $ (2,923)
========= ========= ========= =========
Net loss per share - basic and
diluted $ (1.12) $ (.43) $ (1.92) $ (1.07)
========= ========= ========= =========
Weighted average shares
outstanding 2,727,000 2,727,000 2,727,000 2,727,000
========= ========= ========= =========
</TABLE>
See accompanying notes.
<TABLE>
RAM Energy, Inc.
Consolidated Statements of Cash Flows
(Unaudited)
(Dollars in Thousands)
<CAPTION>
Three months ended Six months ended
June 30, June 30,
1999 2000 1999 2000
---- ---- ---- ----
<S> <C> <C> <C> <C>
Cash flows from operating
activities
Net loss $ (3,053) $ (1,170) $ (5,242) $ (2,923)
Adjustments to reconcile net
loss to net cash provided
(used) by operating activities:
Equity in net loss of RVC
Energy, Inc. 404 - 780 -
Provision for doubtful
accounts receivable and other - 12 8 12
Amortization of Senior Notes
discount included in interest
expense 31 39 70 78
Amortization and depreciation:
Oil and gas properties and
equipment 2,634 1,946 5,186 4,075
Gathering and disposal systems 487 487 975 975
Senior Notes fees 117 117 235 235
Credit facility fees 82 105 164 270
Other property and equipment 49 64 93 120
Deferred income taxes (1,415) (720) (2,715) (1,791)
Cash provided (used) by
changes in operating assets
and liabilities:
Prepaid expenses and deposits 29 79 (24) 142
Accounts receivable 166 178 904 207
Accounts payable (66) (279) (4,565) 1,914
Accrued liabilities and other 3,109 3,147 (191) 484
Gas balancing liability (131) (204) (131) (613)
--------- --------- --------- ---------
Total adjustments 5,496 4,971 789 6,108
--------- --------- --------- ---------
Net cash provided (used) by
operating activities 2,443 3,801 (4,453) 3,185
Cash flows from investing activities
Payments for oil and gas
properties and equipment (677) (1,755) (1,055) (3,097)
Proceeds from sales of oil and
gas properties and equipment 1,611 79 1,641 1,749
Payments for other property
and equipment (103) (69) (114) (84)
Proceeds from sales of other
property and equipment - - 18 -
Payments for gathering and
disposal systems (179) (8) (398) (13)
Payments for other assets (30) - (30) -
Proceeds from sales of other assets 198 68 198 132
--------- --------- --------- ---------
Net cash provided (used) by
investing activities 820 (1,685) 260 (1,313)
Cash flows from financing activities
Principal payments on long-term debt (26) (104) (80) (1,831)
Proceeds from borrowings on
long-term debt 58 22 58 2,516
Payments for loan origination fees - - - (47)
--------- --------- --------- ---------
Net cash provided (used) by
financing activities 32 (82) (22) 638
--------- --------- --------- ---------
Increase (decrease) in cash
and cash equivalents 3,295 2,034 (4,215) 2,510
Cash and cash equivalents at
beginning of period 1,093 2,351 8,603 1,875
--------- --------- --------- ---------
Cash and cash equivalents at
end of period $ 4,388 $ 4,385 $ 4,388 $ 4,385
========= ========= ========= =========
Disclosures of noncash investing activities
Accounts receivable for proceeds
from the sale of oil and gas
properties $ 1,047 $ - $ 1,047 $ -
========= ========= ========= =========
</TABLE>
See accompanying notes.
RAM Energy, Inc.
Notes to Unaudited Consolidated Financial Statements
1. Summary of Significant Accounting Policies, Organization, and
Basis of Financial Statements
The accompanying unaudited consolidated financial statements
present the results of operations and cash flows of RAM Energy,
Inc. (the "Company") for the three- and six-month periods ended
June 30, 1999 and 2000. These financial statements include all
adjustments, consisting of normal and recurring adjustments,
which, in the opinion of management, were necessary for a fair
presentation of the financial position and the results of
operations for the indicated periods. The results of operations
for the three and six months ended June 30, 2000, are not
necessarily indicative of the results to be expected for the full
year ending December 31, 2000. Certain reclassifications have
been made to the prior period statements to conform with the
current year presentation. Reference is made to the Company's
Annual Report on Form 10-K for the year ended December 31, 1999,
for an expanded discussion of the Company's financial disclosures
and accounting policies.
Nature of Operations and Organization
RAM Energy, Inc. operates exclusively in the upstream segment of
the oil and natural gas industry with activities including the
drilling, completion, and operation of oil and natural gas wells,
and operation of gathering and disposal systems. The Company
conducts the majority of its operations in the states of
Oklahoma, Texas, and New Mexico. Additionally, the Company owns
and operates an oil and gas gathering system and a saltwater
disposal operation in north central Oklahoma (the "Gathering
System"). The Gathering System purchases, transports, and markets
oil and gas production and disposes of salt water from properties
owned by the Company and other oil and gas companies.
Principles of Consolidation
The consolidated financial statements include the accounts of its
majority or wholly owned subsidiaries. All significant
intercompany transactions have been eliminated.
2. Financial Instruments
The carrying amounts reported in the balance sheets for cash and
cash equivalents, trade receivables and payables, installment
notes and capital leases, and variable rate long-term debt
approximate their fair values. The carrying value of the Senior
Notes exceeded the fair value at December 31, 1999 and June 30,
2000, by approximately $62.1 million and $55.1 million,
respectively, based on quoted market prices.
3. Contingencies
In 1996, the Company's predecessor sold an oil and gas property
located in Louisiana state waters in Plaquemines Parish. The
property included several uneconomical wells for which the
Company estimated the plugging and abandonment ("P&A") obligation
to be approximately $1,020,000. The purchaser provided a letter
of credit and a bond totaling $420,000 to ensure funding of a
portion of the P&A obligation. The P&A obligation would revert to
the Company in the event the purchaser does not complete the
required P&A activities. As a result, in connection with the
sale, the Company recorded a contingent liability of $600,000,
which is included in the accompanying consolidated balance
sheets.
4. Subsequent Event
In July 2000, the Company sold certain oil and gas properties
with proceeds from such sale of $1.1 million.
Item 2. Management's Discussion and Analysis of Financial Condition
and Results of Operations
General
We are an independent oil and gas company engaged in the
acquisition and development of oil and gas properties, and
production of oil and gas. Our oil and gas properties are
located primarily in the Mid-Continent Area and the Permian
Basin. We also own and operate gathering and disposal systems in
Oklahoma.
Historically, we have added reserves primarily through acquisitions
and development. We intend to continue to pursue attractive oil
and gas acquisitions and drilling opportunities. Any future
acquisitions or major development will require additional
financing which will depend upon financing arrangements, if any,
available to us at the time.
Our revenue, profitability and cash flow are directly impacted
by prevailing prices for oil and gas and the volumes of oil and
gas we produce. In addition, our proved reserves and the rates
of our oil and gas production will decline as oil and gas are
produced unless we are successful in acquiring producing
properties or conducting successful exploration and development
drilling activities.
We have entered into hedging arrangements for natural gas
production from July through October 2000 on 2,310,000 Mmbtu
that provide an average floor price of $2.915 per Mmbtu.
We use the full cost method of accounting for our investment
in oil and gas properties. Under the full cost method of
accounting, all of our costs of acquisition, exploration and
development of oil and gas reserves are capitalized into a "full
cost pool" as incurred, and costs included in the pool are
amortized and charged to operations using the future recoverable
units of production method based on the ratio of current
production to total proved reserves, computed based on current
prices and costs. Significant downward revisions of quantity
estimates or declines in oil and gas prices that are not offset
by other factors could result in a writedown of the carrying
value of our oil and gas properties. Once incurred, a writedown
of oil and gas properties is not reversible at a later date, even
if our quantity estimates or oil or gas prices subsequently
increase.
Results of Operations
Three Months Ended June 30, 2000 Compared to Three Months Ended
June 30, 1999
Operating Revenues. Our operating revenues increased by $1.6
million, or 21% for the three months ended June 30, 2000,
compared to the year earlier period. The following table
summarizes our oil and gas production volumes, average sales
prices and period to period comparisons, including the effect on
our operating revenues, for the periods indicated:
<TABLE>
<CAPTION>
Three Months 2000 Compared to 1999
Ended June 30, ---------------------
-------------- % Increase Operating Revenue
1999 2000 (Decrease) Increase (Decrease)
---- ---- ---------- -------------------
(Dollars in thousands)
<S> <C> <C> <C> <C>
Production volumes:
Natural gas (Mmcf) 2,153 1,869 (13.2) $(512)
Oil (Mmbls) 98 81 (17.6) (253)
Average sale prices:
Natural gas (per Mcf) $1.80 $2.48 37.9 1,275
Oil (per Bbl) 14.70 25.66 74.5 886
</TABLE>
Our oil and gas revenues were higher in the second quarter of
2000 as compared to the second quarter of 1999 with a 47%
increase in realized prices, and 14% decrease in production, both
on an Mcfe basis. Average daily production was 26 million cubic
feet of natural gas equivalent in the second quarter of 2000
compared to 30 million cubic feet of natural gas equivalent
during the second quarter of 1999, a decrease of 14%. For the
second quarter of 2000, our natural gas production decreased by
13% and our oil production decreased 18% compared to the second
quarter of 1999. Approximately 72% of the decrease in natural
gas production was due to a production payment entered into at
the beginning of the fourth quarter of 1999. The balance of the
decrease in natural gas production and the decrease in oil
production was due to sales of oil and gas properties effective
at the beginning of the second half of 1999 which were completed
in June. The average realized sales price for natural gas
was $2.48 per Mcf for the quarter ended June 30, 2000, an
increase of 38% compared to $1.80 per Mcf for the same quarter in
1999. The average realized oil price for the quarter ended June
30, 2000 was $25.66 per Bbl, a 75% increase compared to $14.70
per Bbl for the quarter ended June 30, 1999.
Oil and Gas Production Expense. Our oil and gas production
expense was unchanged for the three months ended June 30, 2000,
compared to the same period in 1999. Oil and gas production
expense was $0.83 per Mcfe for the second quarter of 2000, of
which $0.53 per Mcfe was attributable to lease operations and
$.30 per Mcfe was attributable to production taxes.
Gathering System. Our gathering system revenues were $2.7
million for the three months ended June 2000 compared to $2.3
million for the three months ended June 30, 1999. We are
obligated to deliver 10,000 Mmbtu's per day at the tailgate of
the system, and we purchase natural gas to satisfy that
obligation. Third party purchases of natural gas were $2.1
million for the second quarter of 2000 and system operating costs
were $105,000. For the three months ended June 30, 1999 the
purchases from third parties totaled $1.7 million and system
operating costs were $117,000.
Depreciation and Amortization ("D&A") Expense. Our
depreciation and amortization expenses decreased $650,000, or 19%
for the second quarter of 2000 compared to the same period in
1999. Our D&A Expense was $1.15 per Mcfe for the 2000 quarter,
a decrease of 7% compared to the $1.23 per Mcfe for the 1999
quarter. This decrease is due primarily to the sales of
certain of our properties in the second half of 1999 as well as
increased reserves in the 2000 period.
G & A Expense. Our general and administrative expense
decreased $394,000, or 34%, in the three months ended June 30,
2000 as compared with the 1999 period. In the 2000 period we
benefited fully from the closing of our Oklahoma City and Midland
offices at the end of the first quarter.
Interest Expense. Our interest expense increased by
$115,000 to $3.77 million for the three months ended June 30,
2000 compared to $3.65 million for the comparable period of 1999.
This increase was attributable to higher effective interest rates
on larger average outstanding balances during the 2000 period.
Income Taxes. In connection with an acquisition in 1998, we
recorded deferred income taxes related to the excess of financial
bases of net assets acquired (principally properties and
equipment) over their respective bases for income tax purposes.
This net liability results in our providing for income taxes or
credits after the date of the acquisition.
Net Loss. Due to the factors described above, we realized
a net loss of $1.2 million for the second quarter of 2000
compared to a net loss of $3.1 million for the second quarter of
1999.
Six Months Ended June 30, 2000 Compared to Six Months Ended
June 30, 1999
Operating Revenues. Our operating revenues increased by $2.7
million, or 17% for the six months ended June 30, 2000,
compared to the year earlier period. The following table
summarizes our oil and gas production volumes, average sales
prices and period to period comparisons, including the effect on
our operating revenues, for the periods indicated:
<TABLE>
<CAPTION>
Six Months Ended 2000 Compared to 1999
June 30, ---------------------
-------- % Increase Operating Revenue
1999 2000 (Decrease) Increase(Decrease)
---- ---- ---------- ------------------
(Dollars in thousands)
<S> <C> <C> <C> <C>
Production volumes:
Natural gas (Mmcf) 4,240 3,656 (13.8) $(1,224)
Oil (Mmbls) 204 169 (17.2) (439)
Average sale prices:
Natural gas (per Mcf) $2.10 $2.36 12.8 980
Oil (per Bbl) 12.52 25.03 99.7 2,107
</TABLE>
Our oil and gas revenues were higher in the first six months of
2000 as compared to the same period of 1999 with a 32% increase
in realized prices offset by a 15% decrease in production, both
on an Mcfe basis. Average daily production was 26 million cubic
feet of natural gas equivalent in the first six months of 2000
compared to 30 million cubic feet of natural gas equivalent
during the same period of 1999, a decrease of 15%. For the first
half of 2000, our natural gas production decreased by 14% and our
oil production decreased 18% compared to the first half of 1999.
Approximately 68% of the decrease in our natural gas production
was due to a production payment arrangement we entered into at
the beginning of the fourth quarter of 1999 and our oil
production decreased due to property sales effective at the
beginning of the second half of 1999. The average realized sales
price for our natural gas was $2.36 per Mcf for the first half of
2000, compared to $2.10 per Mcf for the same period in 1999, an
increase of 13%. Our average realized oil price for the six
months ended June 30, 2000 was $25.03 per Bbl, and for the six
months ended June 30, 1999 was $12.52 per Bbl, a 100% increase.
Oil and Gas Production Expense. Our oil and gas production
expense decreased by $220,000, or 6%, for the six months ended
June 30, 2000, compared to the same period in 1999. Of the oil
and gas production expense of $0.77 per Mcfe for the first half
of 2000, $0.54 per Mcfe was attributable to lease operations and
$0.23 per Mcfe was attributable to production taxes. The net
decrease in our oil and gas production expense was due primarily
to the sales of properties in the second half of 1999 and the
second quarter of 2000.
Gathering System. Our gathering system revenues were $5.4
million for the six months ended June 2000 and $4.0 million for
the six months ended June 30, 1999. We are obligated to deliver
10,000 Mmbtu's daily at the tailgate of the system, and we
purchase natural gas from third parties to satisfy that
obligation. Our purchases from third parties were $4.1 million
for the first half of 2000 and our system operating costs were
$212,000. For the six months ended June 30, 1999, our purchases
of natural gas from third parties totaled $2.8 million and our
system operating costs were $214,000.
Depreciation and Amortization ("D&A") Expense. Our
depreciation and amortization expenses decreased $978,000, or
15% for the first half of 2000 over the same period in 1999, and
was $1.22 per Mcfe for the six months ended June 30, 2000 and
June 30, 1999.
G & A Expense. Our general and administrative expense
decreased $204,000, or 9%, in the six months ended June 30, 2000
as compared with the 1999 period. During the first half of 2000
we recorded a $308,000 provision for closing our Oklahoma City
and Midland offices.
Interest Expense. Our interest expense increased by
$279,000 to $7.6 million for the six months ended June 30, 2000
compared to $7.3 million for the comparable period of 1999. This
increase during the 2000 period was attributable to higher
average outstanding indebtedness and higher effective interest
rates.
Income Taxes. In connection with an acquisition in 1998, we
recorded deferred income taxes related to the excess of financial
bases of net assets acquired (principally properties and
equipment) over their respective bases for income tax purposes.
This net liability results in our providing for income taxes or
credits after the date of the acquisition.
Net Loss. Due to the factors described above, we realized
a net loss of $2.9 million for the six months ended June 30,
2000, representing a decrease of $2.3 million or 44%, from a net
loss of $5.2 million in the first half of 1999.
Liquidity and Capital Resources
As of June 30, 2000 we had cash and cash equivalents of $4.4
million, and $2.9 million available under our credit facility
discussed below.
As of June 30, 2000 we had $130 million ($131.2 million
excluding original issue discount) of indebtedness outstanding.
This included $108 million of Senior Notes due 2008 issued in
late February 1998, and $23.2 million of advances under our
credit facility discussed below. Under the terms of the indenture
governing its outstanding senior notes, we may incur up to $30.0
million in permitted indebtedness (as defined in the indenture).
Subject to certain limitations in the indenture, we may also
incur additional indebtedness, including indebtedness under its
credit facility. See "-- Credit Facility."
Funding for our business activities has historically been
provided by operating cash flow and reserve-based bank
borrowings. We regularly engage in discussions relating to
potential acquisitions of oil and gas properties or companies
engaged in the oil and gas business. We have no present
agreement, commitment or understanding with respect to any such
acquisitions. Any future acquisitions may require that we obtain
additional financing which will depend upon financing
arrangements, if any, available at the time.
Credit Facility. On December 27, 1999 we completed the
refinancing of our senior secured credit facility with Foothill
Capital Corporation, a Wells Fargo company. The refinancing was
effected by Foothill purchasing from Union Bank of California,
N.A. and Den norske Bank, ASA, our prior lenders, the outstanding
$25.0 million balance indebtedness, together with all rights
under the mortgages, security agreements and other loan documents
previously executed in connection therewith.
Foothill and we entered into an Amended and Restated Loan and
Security Agreement (the "credit facility") which provides for up
to $30.0 million of revolving credit, subject to borrowing base
restrictions and applicable limitations under the indenture
governing our senior notes. The initial maturity date of our
credit facility will expire in December 2002 and the interest
rate is prime plus 2%. Indebtedness under our credit facility is
secured by liens on substantially all our oil and gas properties
and other assets.
The amount of credit available at any time under our credit
facility may not exceed the borrowing base which is subject to
redetermination at least semi-annually. The borrowing base at
June 30, 2000 was $26.1 million. The credit facility contains
customary covenants which, among other things, require periodic
financial and reserve reporting and limit our incurrence of
indebtedness, liens, dividends, loans, mergers, transactions with
affiliates, investments and sales of assets.
Net Cash Provided by or Used in Operating Activities. For
the three months ended June 30, 2000 net cash provided by our
operating activities was $3.8 million compared to $2.4 million
provided by operations during the comparable period in 1999. For
the six months ended June 30, 2000 net cash provided by our operating
activities was $3.2 million compared to $4.5 million used by
operations during the comparable period in 1999. The primary use
of cash for the six months ended June 30, 1999 was the reduction
of accounts payable.
Net Cash Provided by or Used in Investing Activities.
For the three months ended June 30, 2000, net cash used by us
in our investing activities was $1.7 million primarily
representing $1.9 million of capital expenditures. This compares
with $0.8 million provided in 1999, involving our sales of oil
and gas properties for $1.6 million, offset by $0.7 million of
capital expenditures. At current prices and without additional
financing, we have budgeted approximately $5.5 million for
capital expenditures in 2000. We expect to use cash flow from
our operations, cash balances and property sales to fund these
expenditures.
Item 3. Quantitative and Qualitative Disclosure about Market
Risk
The carrying amounts reported in the balance sheets for cash
and cash equivalents, trade receivables and payable, installment
notes and capital leases, and variable rate long-term debt
approximate their fair values The carrying value of our senior
notes exceeded their fair value at December 31, 1999 by
approximately $61.2 million and at June 30, 2000 by approximately
$55.1 million based on quoted market prices.
This document contains forward-looking statements within the
meaning of Section 27A of the Securities Act of 1933, as amended,
and Section 21E of the Securities Exchange Act of 1934, as
amended. The forward-looking statements contained in this
release are statements that involve risks and uncertainties
including, but not limited to, market demand, the effect of
economic conditions, the result of financing efforts and risks
detailed in our filings with the Securities and Exchange
Commission.
PART II. OTHER INFORMATION
Item 1. Legal Proceedings
Not applicable
Item 2. Changes in Securities
Not applicable
Item 3. Defaults Upon Senior Securities
Not applicable
Item 4. Submission of Matters to a Vote of Security Holders
Not applicable
Item 5. Other Information
Not applicable
Item 6. Exhibits and Reports on Form 8-K
(a) Exhibits
The following exhibits are filed as a part of this report:
Exhibit
Number Description
---------- -------------------------------------------------
21 Subsidiaries of the Company (2) [21]
27 Financial Data Schedule (1)
_______________
(1) Filed herewith.
(2) Filed as an exhibit to the Company's 1999 Annual Report on
Form 10-K which was filed with the Securities and Exchange
Commission. The exhibit number is indicated in brackets and
incorporated by reference herein.
(b) Reports on Form 8-K
Not applicable
<PAGE>
SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of
1934, the registrant has duly caused this report to be signed on
its behalf by the undersigned thereunto duly authorized.
RAM ENERGY, INC.
(Registrant)
Date: August 14, 2000
By: LARRY E. LEE
Larry E. Lee
President and Chief Executive
Officer
By: JOHN M. LONGMIRE
John M. Longmire
Senior Vice President and
Treasurer and Chief Financial
Officer
EXHIBIT INDEX
<TABLE>
<CAPTION>
Exhibit
No. Description Method of Filing
------- ----------- ----------------
<S> <C> <C>
21 Subsidiaries of the Company Incorporated herein by reference
27 Financial Data Schedule Filed herewith electronically
</TABLE>
