<PAGE> 1
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 June 30, 1996
OR
[ ] TRANSITION REPORT UNDER SECTION 13 OR 15(d) OF THE
EXCHANGE ACT
For the transition period from ______ to _______
Commission File No. 0-21702
MIDDLE BAY OIL COMPANY, INC.
(Exact name of small business issuer as specified in its charter)
Alabama 63-1081013
(State or other jurisdiction (I.R.S. Employer
of incorporation or organization) Identification No.)
115 SOUTH DEARBORN STREET
MOBILE, ALABAMA 36602
(Address of principal executive offices)
(334) 432-7540
(Issuer's telephone number)
N/A
(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 Exchange Act 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 [ ]
Number of shares outstanding of each of the Registrant's classes of common
stock, as of the latest practicable date:
Common stock, $.02 par value
1,318,917 shares as of July 31, 1996
Transitional Small Business Disclosure Format (check one)
Yes [ ] No [X]
<PAGE> 2
MIDDLE BAY OIL COMPANY, INC.
INDEX
Part I. Financial Information
Item 1. Financial Statements
Balance Sheets-
June 30, 1996 and December 31, 1995 ...............
Statements of Operations-
Six months ended June 30, 1996 and 1995 ...........
Statements of Cash Flows-
Six months ended June 30, 1996 and 1995 ...........
Notes to Financial Statements ........................
Item 2. Management's Discussion and Analysis
or Plan of Operation ......................
Part II. Other Information
Item 4. Submission of Matters to a Vote of
Security Holders ...........................
Item 6. Exhibits and Reports on Form 8k ...............
<PAGE> 3
PART I- FINANCIAL INFORMATION
Item 1. Financial Statements
MIDDLE BAY OIL COMPANY, INC.
BALANCE SHEETS
<TABLE>
<CAPTION>
(UNAUDITED) (AUDITED)
JUNE 30, DECEMBER 31,
1996 1995
-------- --------
<S> <C> <C>
ASSETS
CURRENT ASSETS
CASH $493,22 $80,791
NOTES AND ACCOUNTS RECEIVABLE-TRADE 783,25 880,715
OTHER CURRENT ASSETS 6,452 52,785
--------- ---------
TOTAL CURRENT ASSETS 1,282,932 1,014,291
NON-CURRENT ASSETS
NOTES RECEIVABLE- STOCKHOLDER (NOTE 2) 135,861 132,547
--------- ---------
135,861 132,547
PROPERTY (AT COST) (NOTE 1)
OIL AND GAS (SUCCESSFUL EFFORTS METHOD) 11,973,46 11,400,288
REAL ESTATE-UNDEVELOPED 0 54,414
FURNITURE, FIXTURES AND OTHER (NOTE 2) 355,738 350,676
ACCUMULATED DEPRECIATION AND DEPLETION (4,412,648) (3,976,923)
--------- ---------
7,916,550 7,828,455
OTHER ASSETS 4,304 9,459
--------- ---------
TOTAL ASSETS $9,339,647 $8,984,752
========= =========
LIABILITIES AND STOCKHOLDERS' EQUITY
CURRENT LIABILITIES
CURRENT MATURITY OF LONG-TERM DEBT (NOTE 3) $221,400 $810,861
ACCOUNTS PAYABLE AND ACCRUED EXPENSES 299,059 624,144
-------- --------
TOTAL CURRENT LIABILITIES 520,459 1,435,005
LONG-TERM DEBT 5,064,226 4,195,391
DEFERRED INCOME TAXES (NOTE 5) 495 495
REDEEMABLE COMMON STOCK (NOTE 4) 677,965 852,642
COMMITMENTS AND CONTINGENCIES (NOTE 6)
STOCKHOLDERS' EQUITY (NOTE 4)
COMMON STOCK, $.02 PAR VALUE, 5,000,000
AUTHORIZED, 1,318,917 ISSUED AND
OUTSTANDING AT JUNE 30, 1996 AND
DECEMBER 31, 1995 26,378 26,378
PAID-IN-CAPITAL 3,415,717 3,241,040
RETAINED EARNINGS (DEFICIT) (297,553) (766,199)
LESS COST OF TREASURY STOCK;
21,773 SHARES AT JUNE 30, 1996 (68,040) -
--------- ---------
TOTAL STOCKHOLDERS' EQUITY 3,076,502 2,501,219
TOTAL LIABILITIES AND EQUITY $9,339,647 $8,984,752
========= =========
</TABLE>
See accompanying notes.
<PAGE> 4
MIDDLE BAY OIL COMPANY, INC.
STATEMENTS OF OPERATIONS
UNAUDITED
<TABLE>
<CAPTION>
THREE MONTHS ENDED SIX MONTHS ENDED
------------------------ ----------------------
JUNE 30, JUNE 30, JUNE 30, JUNE 30,
1996 1995 1996 1995
-------- -------- -------- --------
<S> <C> <C> <C> <C>
REVENUE
OIL AND GAS PRODUCTION $1,066,862 $935,151 $2,083,138 $1,648,622
INTEREST 2,769 2,561 6,190 5,877
OTHER 305,215 34,905 332,117 65,902
GAIN ON SALE OF PROPERTY 34,783 65,171 37,814 74,252
--------- --------- --------- ---------
TOTAL REVENUE 1,409,629 1,037,788 2,459,259 1,794,653
--------- --------- --------- ---------
COSTS AND EXPENSES
WELL OPERATING $367,772 $418,602 $771,570 $682,236
DEPRECIATION, DEPLETION AND
AMORTIZATION 269,815 321,116 539,630 564,959
ABANDONMENT 91,535 - 91,535 -
INTEREST 126,816 147,793 246,990 251,498
GENERAL AND ADMINISTRATIVE 169,616 188,454 340,887 363,360
--------- --------- --------- ---------
TOTAL EXPENSES 1,025,554 1,075,965 1,990,612 1,862,053
INCOME (LOSS) BEFORE INCOME
TAXES 384,075 (38,177) 468,647 (67,400)
INCOME TAXES - - - -
--------- --------- --------- ---------
NET INCOME (LOSS) $384,075 ($38,177) $468,647 ($67,400)
========= ========= ========= =========
AVERAGE COMMON SHARES
OUTSTANDING 1,318,917 1,318,917 1,318,917 1,318,917
NET INCOME (LOSS) PER
COMMON SHARE $0.29 ($0.03) $0.36 ($0.05)
</TABLE>
See accompanying notes.
<PAGE> 5
MIDDLE BAY OIL COMPANY, INC.
STATEMENTS OF CASH FLOWS
SIX MONTHS ENDED
UNAUDITED
<TABLE>
<CAPTION>
JUNE 30, JUNE 30,
1996 1995
-------- --------
<S> <C> <C>
OPERATING ACTIVITIES
NET INCOME (LOSS) $468,647 ($67,400)
ADJUSTMENTS TO RECONCILE NET INCOME (LOSS)
TO NET CASH PROVIDED BY OPERATING ACTIVITIES
DEPLETION, DEPRECIATION AND AMORTIZATION 539,630 564,959
CHANGES IN CURRENT ASSETS AND LIABILITIES:
ACCOUNTS RECEIVABLE 381,788 (465,783)
ACCOUNTS PAYABLE AND ACCRUED EXPENSES (565,311) (20,096)
GAIN ON SALE OF PROPERTIES (37,814) (74,252)
OTHER CHARGES (CREDITS) (507) 2,245
------- -------
NET CASH PROVIDED (USED) BY OPERATING ACTIVITIES 786,433 (60,327)
INVESTING ACTIVITIES
PROCEEDS FROM SALES OF PROPERTIES 40,000 485,728
ADDITIONS TO OIL AND GAS PROPERTIES (690,687) (2,965,548)
PURCHASE OF EQUIPMENT (1,827) (4,802)
FURNITURE, FIXTURES AND OTHER ASSETS (4,507) (13,072)
PROCEEDS FROM SALE OF REAL ESTATE 75,000 -
RECEIPTS FROM (ADVANCES TO) STOCKHOLDER (3,314) (22,160)
------- ---------
NET CASH USED BY INVESTING ACTIVITIES (585,335) (2,519,854)
FINANCING ACTIVITIES
PROCEEDS FROM DEBT ISSUED 483,766 5,628,000
PRINCIPAL PAYMENTS ON DEBT (204,393) (2,942,007)
PURCHASE OF STOCK FOR TREASURY (68,040) -
------- ---------
NET CASH PROVIDED BY FINANCING ACTIVITIES 211,333 2,685,993
NET INCREASE IN CASH 412,431 105,812
CASH - BEGINNING 80,791 183,516
------- ---------
CASH - ENDING $493,222 $289,328
SUPPLEMENTAL CASH FLOW INFORMATION:
INTEREST PAID IN CASH $246,990 $251,498
======== ========
</TABLE>
See accompanying notes.
<PAGE> 6
MIDDLE BAY OIL COMPANY, INC.
Notes to Financial Statements
June 30, 1996 and 1995
(1) ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Organization
Middle Bay Oil Company, Inc. (the Company), an Alabama corporation, was
formed in connection with a transaction (the Transaction) approved by the
unitholders on December 22, 1992 to reorganize the business of Bay City
Consolidated Partners, Ltd. (the Partnership) into the Company. The
Partnership was formed in 1988 to succeed to the business of 10 affiliated oil
and gas limited partnerships. The partnership was owned 95% by the limited
partners and 5% by the general partner.
Pursuant to the Transaction, the Partnership transferred substantially
all its assets and liabilities to the Company on December 31, 1992 in exchange
for subscribing to all the outstanding shares of the Company's common stock.
The Partnership allocated 7.0 shares of the Company's common stock for each
common unit. Concurrently, the Partnership distributed to its former
unitholders, including the general partner, 7.0 shares of common stock for
each common unit.
Basis of Presentation
In management's opinion, the accompanying financial statements contain
all adjustments (consisting solely of normal recurring adjustments) necessary
to present fairly the financial position of the Company as of June 30, 1996
and the results of operations and cash flows for the six months ended June 30,
1996 and 1995.
The accompanying financial statements have not been audited by an
inde-pendent accountant. Certain information and disclosures normally
included in annual audited financial statements prepared in accordance with
generally accepted accounting principles have been omitted, although the
Company believes that the disclosures made are adequate to make the
information presented not misleading. These financial statements should be
read in conjunction with the Company's financial statements and notes thereto
included in the Company's Annual Report on Form 10-KSB for the year ended
December 31, 1995.
Principles of Consolidation
The Transaction has been reflected in the accounts of the Company as a
reorganization of entities under common control whereby the historical bases
of the assets and liabilities of the Partnership are carried forward as the
recorded bases for the Company.
Statements of Cash Flows
For purposes of the statements of cash flows, the Company classifies all
cash investments with original maturities of three months or less as cash.
Marketable Securities
Marketable securities held by the Company are categorized as
available-for-sale in accordance with the provisions of SFAS No. 115.
Available-for-sale securities are carried at fair value, with the unrealized
gains and losses, net of tax, reported as a separate component of
stockholders' equity. Realized gains and losses and declines in value judged
to be other-than-temporary are included in investment income.
Properties
The Company follows the "successful efforts" method of accounting for its oil
an 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. Costs of drilling and equipping productive wells, including
developmental dry holes and related production facilities are capitalized.
Depletion, depreciation and amortization of capitalized costs are
computed separately for each property based on the unit-of-production method
using only proved oil and gas reserves. In arriving at such rates,
commercially recoverable reserves have been estimated by an independent
petroleum engineering firm. If the capitalized costs of total proved
properties exceed the sum of undiscounted estimated future net revenues before
income taxes from total proved reserves (determined on a field-by-field
basis), such excess is charged to expense in the period in which it occurs and
is not reinstated.
With respect to normal dispositions, the cost of properties retired or
otherwise disposed of, and the applicable accumulated depreciation, depletion
and amortization are removed from the accounts, and the resulting profit or
loss, if any, is reflected in current operations.
Site Restoration, Dismantlement & Abandonment Costs
Site restoration, dismantlement and abandonment costs (P&A costs) include
costs associated with dismantling and disposing of the facilities and
equipment required to operate a well and restoring the well site to specified
conditions. The Company develops specific estimates of its P&A costs based on
consultations with its engineers and reevaluates such estimates annually.
Estimated future P&A costs are accrued on a unit-of-production method based on
proved reserves. As of June 30, 1996 and December 31, 1995, the P&A costs
accrued were immaterial.
Impairment of Long-Lived Assets
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 #121) was issued in March 1995 and was adopted by the Company in the
fourth quarter of 1995. This statement requires that long-lived assets be
reviewed for impairment when events or changes in circumstances indicate that
the carrying value of such assets may not be recoverable. This review consists
of a comparison of the carrying value of the asset with the asset's expected
future undiscounted cash flows without interest costs.
Estimates of expected future cash flows are to represent management's best
estimate based on reasonable and supportable assumptions and projections. If
the expected future cash flows exceed the carrying value of the asset, no
impairment is recognized. If the carrying value of the asset exceeds the
expected future cash flows, an impairment exists and is measured by the excess
of the carrying value over the estimated fair value of the asset. Any
impairment provisions recognized in accordance with SFAS #121 are permanent
and may not be restored in the future
Property and Equipment
Property and equipment are stated at cost and depreciated on the accelerated
method over the appropriate life of the property.
Income Taxes
The Company provides for income taxes using the asset and liability method
under which deferred income taxes are recognized for the tax consequences of
"temporary differences" by applying enacted statutory tax rates applicable to
future years to differences between the financial statement carrying amounts
and the tax bases of existing assets and liabilities. The effect on deferred
taxes of a change in tax laws or tax rates is recognized in income in the
period that includes the enactment date.
Stock-based Compensation
In October 1995, the Financial Accounting Standards Board issued SFAS No.
123, "Accounting for Stock-Based Compensation," which establishes financial
accounting and reporting standards for stock-based compensation plans.
Effective for fiscal years beginning after December 15, 1995, the statement
provides the option to continue under the accounting provisions of APB Opinion
25, while requiring pro forma footnote disclosures of the effects on net
income and earnings per share, calculated as if the new method had been
implemented. The Company has adopted the financial reporting provisions of
SFAS No. 123 for 1996, but will continue under the accounting provisions of
APB Opinion 25.
(2) RELATED PARTY TRANSACTIONS
The Company has a receivable, including accrued interest, from Bay City
Energy Group, Inc. (BCEG), a significant stockholder, as of June 30, 1996 and
December 31, 1995 in the amount of $135,861 and $132,547, respectively. The
note is secured by 75,000 shares of Company common stock with principal and
accrued interest at 5% per annum due in full on January 1, 2001.
In January, 1993, BCEG contributed computer equipment and software,
office furnishings and equipment, maps, logs and other geological and
engineering data to the Company in partial payment of the amount owed. In
December, 1993, the Company purchased from BCEG land valued at $125,000 and
fee minerals valued at $150,000. The land was sold in April, 1995.
On December 31, 1995, BCEG contributed proved oil and gas reserves valued
at $186,938 to the Company as partial payment on the amount owed. The
reserves were evaluated on a basis similar to the evaluation of the Company's
reserves as detailed in the Company's 1995 10-KSB Footnote 9.
During the six months ended June 30, 1996 and 1995, BCEG did not make any
payments and was not advanced any funds. Interest of $17,612 was accrued on
the note at June 30, 1996.
(3) LONG-TERM DEBT
<TABLE>
<CAPTION>
June 30, December 31,
1996 1995
-------- ------------
<S> <C> <C>
Convertible Loan of $6,000,000 due
March 31, 1997, secured by oil and
gas properties, monthly payments of
interest only at 1.5% over prime,
convertible into a 72 month term
note on March 31, 1997 $5,140,766 --
Term note of $5,628,000, due February 1,
2002, secured by oil and gas properties,
repayable in monthly installments of
$67,000 plus interest at 1.5% over
prime -- 4,858,000
Note, due 1/1/99, secured by office
building, repayable in monthly
installments of $1,511 including
interest at 7 3/4% 144,860 148,252
--------- ---------
Total $5,285,626 $5,006,252
Less current maturities 221,440 810,861
--------- ---------
Long-term debt excluding current
maturities $5,064,226 $4,195,391
========= =========
</TABLE>
The $6,000,000 convertible loan contains certain restrictive provisions,
the most significant of which restricts additional borrowings, either directly
or indirectly, and payment of dividends. At June 30, 1996, the Company was in
compliance with all covenants specified in the convertible loan agreement.
(4) STOCKHOLDERS' EQUITY
On May 31, 1996, the Board of Directors granted options to acquire
125,000 shares of Company common stock under the 1995 Stock Option and Stock
Appreciation Rights Plan to key employees and non-employee directors. All of
the options vested on the grant date of May 31, 1996 with an exercise price of
$2.50 per share, which was equal to the fair market value of common stock on
the date of grant. The options expire ten years from the date of grant if not
exercised.
On April 1, 1996, the Board of Directors authorized the repurchase of up
to $100,000 of Company common stock at a price per share not to exceed $3.25,
exclusive of brokerage costs. As of June 30, 1996 the Company had purchased
21,772.75 shares of common stock at a cost of $68,040.
On March 21, 1995 Middle Bay Oil Company, Inc. effected a one-for-two
reverse stock split (share consolidation) of its capital stock, thereby
changing the authorized shares of common stock from 10,000,000 shares of $.01
par value to 5,000,000 shares of $.02 par value. The issued and outstanding
shares of common stock were reduced from 2,637,257 to 1,318,629 shares.
Fractional shares resulting from the reverse split, 288 shares, were rounded
up to whole shares and issued. The Company's authorized preferred shares were
reduced from 5,000,000 shares of $.01 par value to 2,500,000 shares of $.02
par value. No preferred shares have been issued by the Company. All
previous per share data have been restated to account for the reverse stock
split. The reverse split was authorized by the shareholders of the Company at
a special meeting held March 14, 1995.
The Company has a contingent obligation to repurchase the 142,107 common
shares of the Company issued in 1993 in connection with an asset acquisition
(the "Janex Acquisition"), upon written notice delivered to the Company,
beginning five years after the closing date and continuing for thirty days
thereafter, at a price of $6.00 per share. This obligation shall terminate if
the Company's stock trades at a share price of $8.00 or greater for twenty
consecutive days during the thirty-six month period immediately preceding the
first day of the fifth year after the closing date. The closing date of the
Janex Acquisition was November 1, 1993. The value of the redeemable common
stock at the $6.00 redemption price is shown in the balance sheet as
Redeemable Common Stock. As of June 30, 1996, 29,112.75 shares of Company
common stock subject to the repurchase obligation have been sold, of which
21,772.75 shares were purchased by the Company.
(5) INCOME TAXES
The Company's income tax expense (benefit) for continuing operations
consists of the following:
<TABLE>
<CAPTION>
Six Months Ended
June 30, June 30,
1996 1995
------- -------
<S> <C> <C>
Current $ - $ -
Deferred - -
------- -------
Total $ - $ -
======= =======
</TABLE>
The Company's net deferred tax liability at June 30, 1996 and December
31, 1995 are as follows:
<TABLE>
<CAPTION>
June 30, December 31,
1996 1995
------- -----------
<S> <C> <C>
Deferred tax liability
Oil and gas properties $ 495 $ 90,648
Deferred tax asset - -
Valuation allowance - -
------- -------
Net deferred tax liability $ 495 $ 90,648
======= =======
</TABLE>
As of June 30, 1996, the Company had approximately $850,000 of operating
loss carryforwards, with $432,000 expiring in 2009 and $418,000 expiring in
2010. As of December 31, 1995 the Company had $36,482 of AMT credit
carryforwards and $22,000 of Section 29 tax credit carryforwards.
(6) COMMITMENTS AND CONTINGENCIES
The Company is obligated under the terms of certain operating leases for
office equipment through December, 1997. Future minimum rental payments are
approximately $9,774 in 1996 and $3,775 in 1997.
On April 3, 1996, the Company entered into a Joint Expense and
Participa-tion Agreement with Brigham Oil and Gas, L.P. which allows the
Company to participate in the drilling of eighty-seven (87) onshore wells in
Texas and Oklahoma over the twelve month period beginning April 1, 1996. The
Company is committed to fund $1,500,000 in drilling costs over this twelve
month period. As of June 30, 1996, the Company had advanced $492,150 in
drilling and completion costs to Brigham Oil and Gas, L.P. The amount
required to be deposited into the escrow account at July 1, 1996 is $400,217
which covers estimated drilling and completion costs for the period July 1 to
September 30. At June 30, 1996, $320,000 of cash on hand consists of cash
that has been escrowed for the July 1 to September 30 drilling and completion
costs.
The Company is a defendant in various legal proceedings which are
considered routine litigation incidental to the Company's business, the
disposition of which management believes will not have a material effect on
the financial position or results of operations of the Company.
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OR PLAN OF OPERATIONS
Liquidity and Capital Resources
Cash flow from operating activities for the six months ended June 30, 1996
of $786,433 increased $846,760 over the comparable 1995 period. The increase
was due primarily to higher oil and gas prices, working capital changes and
cash from the settlement of a gas contract. Oil and gas prices increased 11%
and 41%, respectively, while oil production increased only 2% and gas
production decreased 2%. The change in working capital increased cash flow by
$299,604 over the comparable 1995 period. The change in working capital was
caused principally by timing differences in the payment of expenses and
receipt of revenues. In June, the Company received $262,525, which represents
the Company's share of a partial distribution from a gas contract settlement
with Columbia Gas Transmission Corporation. Cash flow from operations before
working capital changes of $970,463 increased $547,156 over the comparable
1995 period. Additions to oil and gas properties were lower than the
comparable period in 1995 due to only minimal acquisitions and drilling in
1996 compared to the P&P Acquisition which closed in February 1995. The
decrease in the proceeds from debt issued was due to only an advance for
drilling in 1996 compared to the amendment to the Company's term note which
allowed for the P&P Acquisition and the payoff of the remaining principal
balance on the $3.8 million term note of $2,545,759, in the comparable
period. The decrease in the amount of cash used for debt payments was due
principally to only regular principal payments through March 31, 1996 and no
principal payments from April 1 to June 30, 1996 compared to the payoff of the
remaining principal balance on the $3.8 million term note of $2,545,759 in the
comparable period.
The Company's operating activities provided net cash of $786,433 for the
six month period ended June 30, 1996. Sales of minor oil and gas properties
in March and June provided cash of $40,000. The sale in June of real estate
located on Bayou Coden provided cash of $75,000. During this period, net cash
from operations and cash from property sales were used principally for
exploratory and developmental drilling of $609,000 and workovers of $81,000.
Approximately $401,000 of the $609,000 spent on exploratory and developmental
drilling was for completed wells and wells in progress through the
participation agreement with Brigham Oil and Gas, L.P. (the "Brigham
Agreement"). The Company incurred an additional $91,000 in dry hole costs
attributable to wells in the Brigham Agreement. The majority of the
remaining funds were spent on four projects, all of which were completed as
of June 30; developmental drilling on one well in the Campbell Field in Major
County, Oklahoma, one developmental well in Rocky Mount Field in Louisiana,
one developmental well in Lake Trammel Field and a workover on one well in the
Lea Field in Lea County, New Mexico. Lake Trammel and Lea Field are major
properties of the Company. Of the $81,000 spent on workovers, approximately
$40,000 was spent on purchasing and installing downhole pumps on two wells in
the Tulk Field in Lea County, New Mexico. The remaining $41,000 was spent on
several different properties. Amounts spent on debt retirement represent
three months of principal payments on the $5.6 million term note. The
principal payments on the $5.6 million term note were suspended when the
Company converted the term note to a revolving line-of-credit on April 3,
1996.
The monthly principal payment on the Company's $3.8 million term note was
amended on January 1, 1995 to reduce the monthly principal payment to $42,833
from $79,167. On February 23, 1995, the Bank issued $5,628,000 under a new
term note to refinance the $3.8 million term note and to finance the P&P
Acquisition. The new term note matured in seven years and required monthly
principal payments of $67,000 plus interest at prime plus 1.5%. On April 3,
1996, the Bank converted the new term note into a $6.0 million, one-year,
revolving line-of-credit (the "Revolver"), effective April 1, 1996. The
Revolver requires monthly payments of interest only at prime plus 1.5% and
converts into a term note payable in seventy-one consecutive equal monthly
principal and interest payments at prime plus 1.5%, with the remaining
principal and interest payment due on March 31, 2003.
At the time of the conversion, the principal balance of the $5.628
million term note was $4.657 million. The Bank advanced the Company $483,766
on April 3, which resulted in a Revolver principal balance of $5.14 million.
The Company can be advanced a maximum of $6.0 million on the Revolver, based
on the Bank's engineer's or any other independent engineer's redetermination
of the Borrowing Base, using the Bank's pricing and discount factors and the
future net revenue expected to be produced from the Company's oil and gas
reserves.
The Company had current assets of $1,282,932 and current liabilities of
$520,459 which resulted in working capital of $762,473 as of June 30, 1996.
This was an increase of $1,183,187 from the working capital deficit of
$420,714 as of December 31, 1995. Working capital increased primarily due to
cash proceeds from the gas contract settlement, increased cash flow from oil
and gas production and suspension of monthly principal payments on the Term
Note offset partially by amounts spent on exploratory and developmental
drilling. The Company's current ratio of 4.29, calculated under the terms of
the Credit Agreement which excludes stockholder receivables and debt due under
the Credit Agreement, was in excess of the 0.90 to 1.00 required.
At June 30, 1996 seventeen wells had been spudded under the Brigham
Agreement. Of these seventeen wells, four were completed, seven were dry
holes and six were drilling. Oil and gas sales and lease operating expenses
on the four completed wells for the six months ended June 30, 1996 was
immaterial. At August 5, 1996, of these seventeen wells, six were completed,
ten were dry holes and one was drilling. The amount to be escrowed for
drilling under the Brigham Agreement for the period July 1 to September 30 is
$400,217. The advances to Brigham for the actual July and August drilling was
$204,511 and $73,003, respectively.
In general, because the Company's principal natural gas and oil reserves
are depleted by production, its success is dependent upon the results of its
development, acquisition and exploration activities. The Company's strategy
is to enhance and exploit its existing properties for reserves, to invest in
exploratory and developmental drilling prospects and to acquire reserves. The
Company expects to incur a total of approximately $600,000 in capital
expenditures over the next three months; $100,000 to invest in development
projects on certain of its existing wells and $500,000 in exploration projects
in the Brigham Agreement. These projects will be funded by
internally-generated cash flows, proceeds from property sales and bank
debt.
In connection with the issuance of 142,107 shares of common stock in the
Janex Acquisition, the Company has a contingent obligation to repurchase the
shares, upon written notice delivered to the Company, beginning five years
after the Closing Date and continuing for thirty days thereafter, at a price
of $6.00 per share. This contingent obligation shall terminate if the
Company's stock trades at a share price of $8.00 or greater for twenty
consecutive days during the thirty-six month period immediately preceding the
first day of the fifth year after the Closing Date. The closing date of the
Janex Acquisition was November 1, 1993. The redemption value is shown in the
Balance sheet as Redeemable Common Stock. If the trading market for the
Company's stock does not meet the trading limits stated above over the three
year period beginning November 1, 1995 through October 31, 1998, the Company
will have to redeem the shares of stock from the original owners upon written
request at $6.00 per share beginning November 1, 1998 and ending November 30,
1998. The Company is unable to determine at this time if it will have to
redeem any or all of the shares issued. Depending on the number of shares the
Company may have to redeem, the redemption will be financed through internal
cash flow or by debt financing. The redemption, if any, is not expected to
have a material adverse affect on the operations of the Company. If the
Company has to redeem the entire amount, the redemption could have an adverse
affect on the financial position of the Company. Over the period November 1,
1995 to June 30, 1996, the trading range of the Company's common stock has
been $4.125 to $2.50. During the second quarter of 1996, the Company
purchased 21,772.75 shares and the original owners sold 7,340 shares of
Company common stock subject to the repurchase obligation. The Company may
purchase additional shares subject to the repurchase obligation in the future.
The Company's liquidity position and current and anticipated cash flows
from operations remain adequate for its general requirements. However,
because future cash flows and the availability of financing are subject to a
number of variables, such as the level of production and prices received for
gas and oil, there can be no assurance that the Company's capital resources
will be sufficient to maintain planned levels of capital expenditures.
Current Activities
As of August 5, 1996 there were five exploratory wells drilling under the
Brigham Agreement.
Results of Operations
Three Months Ended June 30, 1996 and 1995
Total revenues for the three months ended June 30, 1996 of $1,409,629 were
$371,841 higher than the same period in 1995. The increase in total revenues
was due primarily to higher oil and gas revenues of $131,711 and a gas
contract settlement of $263,000. The increase in oil and gas revenues
consisted primarily of a $2,312 increase in oil revenues and a $127,819
increase in gas revenues. The increase in oil and gas revenues was the result
of higher oil and gas prices. Production of oil and gas decreased 14% and
11%, respectively, over the comparable 1995 period. The primary reason for the
production decrease was the previous year's minor property sale which was
effective June 1995. During the three month period ended June 30, 1996, the
Company sold 29,492 barrels of oil and 231,463 Mcf of gas, as compared to
34,312 barrels and 259,793 Mcf for the comparable 1995 period. The price
received on the gas sold in 1996 of $2.12 per Mcf was higher than the $1.39
per Mcf received in the comparable 1995 period. Oil prices in 1996 of $19.58
per barrel were higher than the $16.66 per barrel received in 1995.
Total expenses decreased by $50,411 over the comparable 1995 period.
Decreases in interest expense, lease operating expense, general and
administrative expense and depreciation and depletion expense were experienced
in 1996 as compared to 1995. The increase in dry hole costs of $91,535 is due
to dry hole costs associated with the Brigham Agreement in 1996 versus no dry
hole costs in the comparable 1995 period. Interest expense was $20,977 lower
due primarily to lower principal balances and lower rates. Lease operating
expenses decreased by $50,830 due principally to lower expenses on existing
properties and sold properties. A one-time credit on a major property resulted
in a $58,000 decrease in lease operating expenses over the comparable period.
Depletion expense decreased by $51,301 while depreciation expense decreased by
$4,726. Depletion was lower due to sold properties and lower depletion on
existing properties. Depreciation was lower due to minimal asset additions and
lower depreciation on lease and well equipment and corporate office furniture
and fixtures which are depreciated on the accelerated method which declines
over the useful life of the asset. General and administrative expenses
decreased by $18,838, due primarily to lower SEP contribution of $25,000 and
lower miscellaneous expenses of $9,700 offset partially by higher travel
expenses of $9,400.
The Company reported operating income of $384,075 for the three months ended
June 30, 1996 versus an operating loss of $38,177 for the comparable period.
If the income from the gas contract settlement is excluded, operating income
would have been $121,075.
The Company reported net income of $384,075 for the three months ended
June 30, 1996 versus a net loss of $38,177 for the comparable 1995 period.
Six Months Ended June 30, 1996 and 1995
Total revenues for the six months ended June 30, 1996 of $2,459,259 were
$664,606 higher than the same period in 1995. The increase in total revenues
was due primarily to higher oil and gas revenues of $434,516 and a gas
contract settlement of $263,000. The increase in oil and gas revenues
consisted primarily of a $121,293 increase in oil revenues and a $283,669
increase in gas revenues. The increase in oil and gas revenues was the result
of higher oil and gas prices. Production of oil increased 2% and production
of gas decreased 2%, over the comparable 1995 period. The primary reason for
the production decrease was the minor property sale which was effective June
1995; production on existing properties increased over the comparable 1995
period. During the six month period ended June 30, 1996, the Company sold
57,226 barrels of oil and 472,960 Mcf of gas, as compared to 56,320 barrels
and 481,912 Mcf for the comparable 1995 period. The price received on the gas
sold in 1996 of $2.12 per Mcf was higher than the $1.50 per Mcf received in
the comparable 1995 period. Oil prices in 1996 of $18.27 per barrel were
higher than the $16.41 per barrel received in 1995.
Total expenses increased by $128,559 over the comparable 1995 period.
Higher lease operating and dry hole expenses offset lower depletion,
depreciation, interest and general and administrative expenses. Lease
operating expenses increased by $89,334 due principally to higher expenses on
existing properties offset partially by sold properties. Dry hole costs
increased by $91,535 due to dry holes associated with the Brigham Agreement
versus no dry hole costs in the comparable 1995 period. Depletion expense
decreased by $16,550 while depreciation expense decreased by $8,779. Depletion
was lower due to sold properties and lower depletion on existing properties.
Depreciation was lower due to minimal asset additions and lower depreciation
on lease and well equipment and corporate office furniture and fixtures which
are depreciated on the accelerated method which declines over the useful life
of the asset. Interest expense was $4,508 lower due primarily to lower
principal balances and lower rates. General and administrative expenses
decreased by $22,473, due primarily to lower SEP contribution of $25,000 and
lower miscellaneous expenses of $25,000 offset partially by higher travel
expenses of $20,800 and higher stock exchange related expenses of $11,200.
The Company reported operating income of $468,647 for the six months ended
June 30, 1996 versus an operating loss of $67,400 for the comparable period.
If the income from the gas contract settlement is excluded, operating income
would have been $205,647.
The Company reported net income of $468,647 for the six months ended June
30, 1996 versus a net loss of $67,400 for the comparable 1995 period.
<PAGE> 7
PART II. OTHER INFORMATION
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
On May 10, 1996 a proxy was mailed to shareholders of record on May 1,
1996 soliciting their vote at the Annual Meeting of Shareholders of the
Company on May 31, 1996. The following matters were submitted to a vote of
shareholders (Shares Eligible to Vote: 1,318,917; Shares Voted 839,740):
1. Election of Directors
Messrs. Edward P. Turner, Jr., John J. Bassett, Frank C. Turner II, Frank
E. Bolling, Jr. and C. Noell Rather were elected to serve on the Board of
Directors until the next Annual Meeting of Shareholders.
For Without Authority
All Nominees 835,599 4,141
2. Ratification of Auditors
Schultz Watkins & Company was approved as the Company's independent
accountant for 1996.
For Against Abstain
825,648 0 14,092
ITEM 6. EXHIBITS AND REPORTS ON FORM 8K
(a) Exhibits - None
(b) Reports on Form 8-K - None
<PAGE> 8
SIGNATURES
In accordance with the requirements of the Securities Exchange Act of
1934, the registrant caused this report to be signed on its behalf by the
undersigned, thereunto duly authorized.
MIDDLE BAY OIL COMPANY, INC.
(Registrant)
Date: August 7, 1996 By: /s/ John J. Bassett
---------------------------------
John J. Bassett
President and
Chief Executive Officer
Date: August 7, 1996 By: /s/ Frank C. Turner, II
--------------------------------
Frank C. Turner II
Vice-President and
Chief Financial Officer
