UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D. C. 20549
FORM 10-Q
X QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE
- ----- SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended March 31, 1997
----------------------
OR
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE SECURITIES
- ----- EXCHANGE ACT OF 1934
For the transition period from to
-------------- ------------------
Commission File Number 1-7796
TIPPERARY CORPORATION
(Exact name of registrant as specified in its charter)
Texas 75-1236955
(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification No.)
633 Seventeenth Street, Suite 1550
Denver, Colorado 80202
(Address of principal executive offices) (Zip Code)
Registrant's telephone number, including area code (303) 293-9379
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 practicable date.
Class Outstanding May 14, 1997
- ---------------------------- ------------------------
Common Stock, $.02 par value 13,050,271 shares
/page
TIPPERARY CORPORATION AND SUBSIDIARIES
Index to Form 10-Q
Page No.
PART I. FINANCIAL INFORMATION (UNAUDITED)
Item 1. Financial Statements
Consolidated Balance Sheet
March 31, 1997 and September 30, 1996 1
Consolidated Statement of Operations
Three months and six months ended
March 31, 1997 and 1996 2
Consolidated Statement of Cash Flows
Six months ended March 31, 1997 and 1996 3
Notes to Consolidated Financial Statements 4
Item 2. Management's Discussion and Analysis of
Financial Condition and Results of Operations 5-10
PART II. OTHER INFORMATION
Item 1. Legal Proceedings 11
Item 2. Changes in Securities 11
Item 3. Defaults Upon Senior Securities 11
Item 4. Submission of Matters to a Vote of Security Holders 11
Item 5. Other Information 11
Item 6. Exhibits and Reports on Form 8-K 11
SIGNATURES 12
/page
PART I - FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
TIPPERARY CORPORATION AND SUBSIDIARIES
Consolidated Balance Sheet
(in thousands)
(unaudited)
March 31, September 30,
1997 1996
------------- -------------
ASSETS
Current assets:
Cash and cash equivalents $ 2,753 $ 3,575
Receivables 2,071 2,154
Inventory 196 190
Current portion of deferred income
taxes, net 34 57
Other current assets 172 123
------------- -------------
Total current assets 5,226 6,099
------------- -------------
Property, plant and equipment, at cost:
Oil and gas properties, full cost method 127,821 122,360
Other property and equipment 2,391 2,336
------------- -------------
130,212 124,696
Less accumulated depreciation, depletion and
amortization (86,898) (85,215)
------------- -------------
Property, plant and equipment, net 43,314 39,481
------------- -------------
Noncurrent portion of deferred income taxes,
net 3,157 3,134
Investment in NGL fractionating plant 2,303 2,474
Investment in stock 897 707
Other noncurrent assets 12 203
------------- -------------
$ 54,909 $ 52,098
============= =============
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities:
Current portion of long-term debt $ - $ -
Note payable - related party 2,300 -
Accounts payable 1,075 1,539
Accrued liabilities 176 215
Production and income taxes payable 190 186
Royalties payable 145 148
------------- -------------
Total current liabilities 3,886 2,088
------------- -------------
Long-term debt 13,844 13,994
Commitments and contingencies (Note 3)
Stockholders' equity
Common stock; par value $.02; 20,000,000
shares authorized; 13,078,071 issued
and 13,050,271 outstanding 262 262
Capital in excess of par value 105,375 105,375
Accumulated deficit (68,387) (69,550)
Treasury stock, at cost; 27,800 shares (71) (71)
------------- -------------
Total stockholders' equity 37,179 36,016
------------- -------------
$ 54,909 $ 52,098
============= =============
See accompanying notes to consolidated financial statements.
1
/page
TIPPERARY CORPORATION AND SUBSIDIARIES
Consolidated Statement of Operations
(in thousands, except per share data)
(unaudited)
Three months ended Six months ended
March 31, March 31,
------------------ ------------------
1997 1996 1997 1996
-------- -------- -------- --------
Revenues $ 3,064 $ 2,686 $ 7,176 $ 5,317
Costs and expenses:
Operating 1,446 1,400 2,916 2,698
General and administrative 382 342 819 691
Depreciation, depletion and
amortization 749 978 1,684 2,006
-------- -------- -------- --------
Total costs and expenses 2,577 2,720 5,419 5,395
Operating income (loss) 487 (34) 1,757 (78)
Other income (expense):
Interest income 30 43 59 111
Dividend income - 22 - 44
Interest expense (210) (249) (455) (505)
Research and development
expense - (17) - (17)
-------- -------- -------- --------
Total other expense (180) (201) (396) (367)
-------- -------- -------- --------
Income (loss) before
income tax 307 (235) 1,361 (445)
Income tax benefit (expense) 18 (1) (5) (4)
-------- -------- -------- --------
Income (loss) before equity in
earnings (loss) of NGL
fractionating plant 325 (236) 1,356 (449)
Equity in earnings (loss) of NGL
fractionating plant (140) 65 (193) 37
-------- -------- -------- --------
Net income (loss) $ 185 $ (171) $ 1,163 $ (412)
======== ======== ======== ========
Net income (loss) per share $ .01 $ (.02) $ .09 $ (.04)
======== ======== ======== ========
Weighted average shares
outstanding 13,050 11,210 13,050 11,210
======== ======== ======== ========
See accompanying notes to consolidated financial statements.
2
/page
TIPPERARY CORPORATION AND SUBSIDIARIES
Consolidated Statement of Cash Flows
(in thousands)
(unaudited)
Six months ended
March 31,
------------------
1997 1996
-------- --------
Cash flows from operating activities:
Net income (loss) $ 1,163 $ (412)
Adjustments to reconcile net income (loss) to net cash
provided by operating activities:
Depreciation, depletion and amortization 1,684 2,006
Equity in (earnings) loss of NGL fractionating plant 193 (37)
Change in assets and liabilities:
Decrease in receivables 83 253
Increase in inventory (6) -
Increase in other current assets (49) (11)
Decrease in accounts payable, accrued liabilities,
and production and income taxes payable (499) (185)
Decrease in royalties payable (3) (26)
Other (1) (61)
-------- --------
Net cash provided by operating activities 2,565 1,527
-------- --------
Cash flows from investing activities:
Proceeds from asset sales 29 234
Investment in NGL fractionating plant (21) (985)
Capital expenditures (5,545) (2,173)
-------- --------
Net cash used in investing activities (5,537) (2,924)
-------- --------
Cash flows from financing activities:
Proceeds from borrowing 2,300 -
Principal repayments (150) -
-------- --------
Net cash from financing activities 2,150 -
-------- --------
Net decrease in cash and cash equivalents (822) (1,397)
Cash and cash equivalents at beginning of period 3,575 4,193
-------- --------
Cash and cash equivalents at end of period $ 2,753 $ 2,796
Supplemental disclosure of cash flow information:
Cash paid during the period for:
Interest $ 449 $ 511
Income taxes $ 1 $ 4
See accompanying notes to consolidated financial statements.
3
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TIPPERARY CORPORATION AND SUBSIDIARIES
Notes to Consolidated Financial Statements
(Unaudited)
NOTE 1 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Basis of Presentation
- ---------------------
In the opinion of management, the accompanying unaudited financial statements
reflect all adjustments, consisting only of normal recurring adjustments, which
are necessary for a fair presentation of the consolidated financial position of
Tipperary Corporation and its subsidiaries (the "Company") at March 31, 1997,
and the results of its operations for the three-month and six-month periods
ended March 31, 1997, and 1996. The consolidated financial statements include
the accounts of the Company and its share of assets, liabilities, revenues and
expenses of unincorporated joint ventures and partnerships. The accounting
policies followed by the Company are included in Note 1 to the Consolidated
Financial Statements in the Annual Report on Form 10-K for the year ended
September 30, 1996. These financial statements should be read in conjunction
with the Form 10-K.
Reclassification
- ----------------
Certain prior period amounts reported herein have been reclassified to
correspond to the presentation used for the six months ended March 31, 1997.
NOTE 2 - NOTE PAYABLE - RELATED PARTY
In January 1997, the Company obtained a bridge loan of $2,300,000 from Slough
Parks Incorporated, an affiliate of the Company's largest shareholder. The note
is due in January 1998 and bears interest at 8.5% per annum payable in calendar
quarter installments. The note is secured by a 10% interest in the rights under
the Joint Operating Agreement covering the Comet Ridge project in Queensland,
Australia, and is subject to the terms and provisions of a subordination
agreement with the Company's bank. During the quarter ended March 31, 1997, the
Company incurred interest expense of approximately $36,000 on this note.
NOTE 3 - COMMITMENTS AND CONTINGENCIES
The Company was a defendant in a lawsuit filed on September 20, 1991 styled
VALERO TRANSMISSION, L.P. v. J. L. DAVIS v. TIPPERARY CORPORATION, Cause No. 91-
09-00357-CVF, in the 81st Judicial District, Frio County, Texas. The case
involved gas purchase contracts between Valero and Davis. The Company
previously owned 50% of Davis' interest in the contracts. Valero claimed it had
overpaid Davis under the contracts and requested damages for breach of contract
from Davis. Davis thereafter filed a third-party petition against the Company
requesting that the Company reimburse Davis for 50% of any amounts paid to
Valero on account of the claims made by Valero in its original petition. The
Company answered the lawsuit, denying the claims of Davis. After Valero and
Davis settled the claims between themselves, Davis requested that the Company
reimburse Davis for 50% of such settlement to the extent that the settlement
covered time periods in which Davis and the Company each owned a 50% interest in
the contracts. On March 27, 1997, the Company entered into a settlement
agreement with Davis pursuant to which the Company paid Davis $90,000 and Davis
agreed to dismiss all claims against the Company. The case was dismissed by
order of the court on April 23, 1997. The $90,000 settlement payment is
included in these financial statements as an operating expense.
On March 14, 1997, the Company filed a complaint along with several other
plaintiffs in BTA OIL PRODUCERS, ET AL. v. MDU RESOURCES GROUP, INC., ET AL. in
Stark County Court in the Southwest Judicial District of North Dakota. The
plaintiffs are suing the defendants for breach of gas sales contracts, unjust
enrichment, implied trust, and related business torts. The case concerns the
sale by plaintiffs and certain predecessors of natural gas processed at the
McKenzie Gas Processing Plant in North Dakota to Koch Hydrocarbons Company. It
also concerns the contracts for resale of that gas to MDU Resources Group, Inc.,
and Williston Basin Interstate Pipeline Company. The defendants have answered
the complaint denying the claims, and discovery is expected to begin in the near
term.
4
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ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATIONS
FINANCIAL CONDITION
During the six months ended March 31, 1997, the Company continued its production
and development efforts in the Comet Ridge coalbed methane project in
Queensland, Australia and its exploration efforts in the Missouri River project
in Montana and the Divide project in North Dakota. The Company also continued
development drilling on its existing properties. During this period, the
Company incurred capital expenditures of $5,545,000, received proceeds of
$29,000 from miscellaneous oil and gas property sales and invested an additional
$21,000 in the Alabama natural gas liquids ("NGL") fractionating plant,
resulting in net cash used in investing activities of $5,537,000. The capital
expenditures included an investment of $4,042,000 in the Comet Ridge project,
$997,000 in domestic development drilling costs and $506,000 in other capital
expenditures, of which $300,000 was for domestic leasehold acquisitions. The
investment in the Comet Ridge project included approximately $2,300,000 for the
purchase price of an additional 5% interest in the project. The balance of
$1,742,000 was expended primarily for the Company's share of costs to drill and
complete three new wells, for continued de-watering of the Fairview area wells
and, to a lesser extent, to advance funds for the purchase of gas gathering and
compression equipment. During the six months ended March 31, 1996, the Company
incurred $2,173,000 in capital expenditures, invested $985,000 in the
construction of the NGL fractionating plant and received proceeds of $234,000
from the sale of producing oil and gas properties, resulting in net cash used in
investing activities of $2,924,000. The capital expenditures of $2,173,000
included $574,000 expended on the Missouri River project, $357,000 on the Divide
project and other Williston Basin leasehold costs and $344,000 on the Comet
Ridge project. The balance was expended primarily in other domestic drilling
activities.
The Company held cash and temporary investments of $2,753,000 as of March 31,
1997, versus $3,575,000 as of September 30, 1996. Net cash provided by
operating activities was $2,565,000 and $1,527,000 for the six month periods
ended March 31, 1997, and 1996, respectively. In January 1997, the Company
obtained a bridge loan of $2,300,000 from an affiliate of the Company's largest
shareholder and used the proceeds to acquire the additional 5% interest in the
Comet Ridge project. This loan bears interest at 8.5% per annum payable in
calendar quarter installments. The unpaid principal balance, together with
accrued and unpaid interest, is due in January 1998. During the three months
ended March 31, 1997, the Company made principal payments of $150,000 on its
long term debt, all of which was owed to the Company's commercial bank lender.
No principal payments were made during the prior year quarter.
While the Company's cash flows are directly affected by oil and gas prices, the
Company's existing hedge positions partially mitigate the effects of lower
prices. The Company presently has hedged, under "swap" agreements, 20,000
barrels of oil per month, or approximately 55%, of its estimated remaining
fiscal 1997 oil production subsequent to March 31, 1997. These swaps provide a
weighted average New York Mercantile Exchange ("NYMEX") floor price of $19.44
per barrel. The swap agreements provide the Company with 50% participation in
NYMEX prices in excess of the floor level. The Company's actual price received
for oil at the wellhead during the first half of fiscal 1997 averaged $2.25 per
barrel below the average NYMEX oil price. This difference varies based on
location and quality of oil sold. Subsequent to March 31, 1997, the Company
closed out a hedge position covering 70,000 MMBtu of its natural gas production
through a put option with a strike price of $2.10 per MMBTU. Notwithstanding
the Company's hedging activities, decreases in oil and gas prices subsequent to
March 31, 1997, could cause a significant reduction in cash flows available for
the funding of capital projects and reduction of bank debt, and could negatively
impact the Company's efforts to secure new financing.
The Company's bank credit agreement (the "Agreement") provides a maximum loan
facility of $40,000,000 subject to borrowing base limitations described below.
The Agreement contains provisions for both fixed rate and variable rate
borrowings. At the Company's option, interest on the revolver is payable at
either the London Interbank Offered Rate ("LIBOR") plus 1.5% or the bank's Base
Rate. The LIBOR-based option may be selected for periods not exceeding 90 days.
At March 31, 1997, the Company's outstanding debt of $13,844,000 carried a
weighted average interest rate of 7.22%. Upon expiration of the revolver (the
"Conversion Date"), the principal balance will convert to a four-year term loan.
During the second quarter of fiscal 1997, the Conversion Date was extended by
the bank from October 5, 1997, to October 5, 1998.
Certain of the Company's domestic oil and gas properties have been pledged as
security for the bank loan, and the bank has the option to place additional
liens on other unencumbered properties. The maximum borrowing base is
determined solely by the bank and is based upon its assessment of the value of
the Company's properties. This bank valuation is based upon the bank's
assumptions about reserve quantities, oil and gas prices, operating expenses and
other
5
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assumptions, all of which may change from time to time and which may differ from
the Company's assumptions. The borrowing base is currently set at $14,500,000.
Should the outstanding loan balance ever exceed the borrowing base, the Company
is required to either make a cash payment to the bank equal to or greater than
such excess or provide additional collateral to the bank to increase the
borrowing base by the amount of the deficit. In the event oil prices and/or
natural gas prices decline by a significant amount, the Company's borrowing base
could be reduced to an amount less than the loan balance, resulting in the
Company having to fulfill the foregoing requirements. The Company is obligated
to pay a commitment fee of 3/8% per annum on the difference between the average
outstanding loan balance and the borrowing base. The agreement provides that
the Company may not pay dividends or incur additional debt without prior
approval from the bank.
The Company has minimal remaining unused borrowing capacity and is therefore
attempting to establish additional oil and gas reserves through its exploitation
and exploration projects, which if successful, could increase its borrowing base
with the bank. The Company anticipates that in order to complete its capital
projects and sustain growth, internal cash flow and bank financing will have to
be supplemented with project financing and/or additional corporate debt or
equity offerings. The Company presently anticipates using cash on hand,
existing cash flows, additional bank financing and any additional external
financing to pay its bridge loan of $2,300,000 due January 1998, and to continue
to pursue both its domestic and international projects.
The Company's capital investment was directed primarily to the following
projects for the three months and six months ended March 31, 1997:
International Exploration and Development
- -----------------------------------------
In April 1992, the Company acquired a non-operating interest in the Comet Ridge
coalbed methane project in the Bowen Basin located in Queensland, Australia. As
of September 30, 1996, the co-venturers conducting the project (the "Group")
held an Authority to Prospect ("ATP") granted by the Queensland government
covering approximately 1,365,000 acres. The holder of an ATP may be granted
petroleum leases upon establishing to the satisfaction of the Queensland
government that commercial deposits of petroleum have been discovered. During
fiscal 1996, the Group was granted petroleum leases covering approximately
167,000 acres in the area known as "Fairview," which is in the southern portion
of the ATP. During the first quarter of fiscal 1997, the Group received a four-
year renewal of its ATP after relinquishing 20% of the acreage along the western
border of the ATP. The renewed ATP contains approximately 1,088,000 acres, of
which 167,000 acres are covered by petroleum leases. The new ATP requires
certain minimum expenditures, based on current exchange rates, of approximately
$240,000 in year one, $435,000 in years two and three, and $780,000 in year
four. The Company will be responsible for its pro rata share of these
expenditures.
As of March 31, 1997, the Group had drilled 19 wells on its ATP acreage, of
which 18 are in the Fairview area and one well is awaiting completion in the
Dawson area in the northern portion of the ATP. Fifteen of the wells are in a
core area where significant de-watering and production testing has been done,
with the natural gas production being flared. Based upon past production
testing, continued de-watering is expected to further increase gas production
rates.
During fiscal 1996, the Group began negotiations regarding a gas contract with a
Brisbane-based gas utility, which would call for the delivery of approximately
57 petajoules, or roughly 57 billion cubic feet, of gas over 15 years.
Negotiations are continuing and the parties are reviewing a draft agreement
which would take effect upon completion of a connecting pipeline and gathering
facilities. The Group has recently entered into gas contract negotiations with
two other companies interested in purchasing gas from the property. PGT
Australia ("PGT"), a subsidiary of Pacific Gas Transmission, a Portland, Oregon-
based transmission company, has applied for a pipeline license to construct a
17-mile spur line which will connect the core Fairview area wells to the
existing PGT Queensland Gas pipeline. This pipeline was acquired by PGT during
fiscal 1996 from the State of Queensland. The Company has been notified by PGT
that it has received certain of the necessary government approvals and has
ordered pipe for the project. It plans to operate the line as a part of its
existing pipeline system. PGT also informed the Company that construction of
the pipeline is expected to take approximately three months and that PGT will
begin construction after clearance is received from the Queensland Department of
Mines and Energy, which is projected by mid-1997. The Group has ordered
compression and gathering equipment to be used in the construction of a
gathering system which will transport the gas from the individual wells to the
PGT connecting pipeline. PGT has recently announced its plans to build a new
478 km pipeline from an area near the Group's ATP to the Brisbane area.
Assuming completion of the new pipeline, the Group's gas could be transported to
both the Gladstone and Brisbane market areas on the PGT system.
6
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Effective January 1, 1997, the Company increased its ownership in the rights
under the Joint Operating Agreement covering the Comet Ridge project from 45.75%
to 50.75% with the acquisition of an additional 5% capital-bearing interest from
an unaffiliated interest holder for approximately $2,300,000. The purchase of
the additional interest was financed through the bridge loan from an affiliate
of the Company's largest shareholder. The Company's interest bears 50.75% of
capital costs and 47.58% of operating expenses and its net revenue interest is
42.35% prior to project payout. Subsequent to project payout, the Company's
interest bears 40.60% of capital and operating expenses and its net revenue
interest is 36.14%.
The Company expects to incur approximately $750,000 in equipment and
construction costs for the gas gathering system during the third fiscal quarter.
Although the Company cannot predict capital requirements beyond the installation
of this system, it has retained an international investment banking firm to
serve as the Company's agent in seeking equity and debt financing for the Comet
Ridge project, with proceeds to be used to develop the project and repay the
bridge loan. The Company has recently received indications of interest in
providing capital for the project from several different parties. There can be
no assurance, however, that sufficient capital will be obtained or, if obtained,
that it will be on terms acceptable to the Company or on a basis that meets the
Company's objectives.
Domestic Exploration
- --------------------
MISSOURI RIVER PROJECT. The Company owns an 87.5% undivided interest in
approximately 45,000 acres in its Missouri River project area in the Williston
Basin of Montana. During fiscal 1995, a three-dimensional ("3-D") seismic
survey was conducted over approximately 30% of the project area, resulting in
the identification of several prospects. The Company drilled a dry hole on the
first prospect tested in February 1996. As of September 30, 1996, the Company's
investment in the project totaled approximately $2,420,000. An additional
$35,000 was incurred during the first six months of fiscal 1997, bringing the
total investment to $2,455,000 as of March 31, 1997. On January 29, 1997, the
Company entered into an agreement with another oil and gas company covering
30,000 acres in the project. The other company agreed to spend $150,000 in
acquiring two-dimensional seismic data, and will then have an option to acquire
an undivided 50% interest in the acreage for an additional $390,000 cash
payment. The Company has also entered into a joint seismic program with a
different oil and gas company covering an additional 4,000 acres in the Missouri
River project area.
DIVIDE PROJECT. During fiscal 1996, the Company assembled a 30,000 acre
leasehold position in Divide County, North Dakota, and subsequently entered into
exploration agreements with two industry partners. The agreements included the
sale of a total of 75% of the Company's working interest for $975,000 in cash
and $256,000 in "carried" capital costs and provide for the three parties to
jointly pursue exploration activities on the acreage, including the acquisition
of 3-D seismic data and exploratory drilling. The parties have identified
numerous prospects in the Divide Project area, which is located in a multi-pay
area of the Williston Basin. Seismic data acquisition commenced in November
1996 and initial drilling is expected to begin in the third quarter of fiscal
1997. During the six months ended March 31, 1997, the Company incurred
approximately $261,000 to acquire additional acreage in Divide County.
OTHER WILLISTON BASIN PROJECTS. In March 1997, the Company entered into an
agreement to participate with an industry partner in a three-well drilling
program with an option to participate in up to five additional wells. Each
well will be drilled to test a structural anomaly defined by 3-D seismic data.
Drilling of the first well commenced in March 1997 and the two additional wells
in the initial three-well program are expected to be drilled within the next few
months. The Company's share of estimated costs for the three-well program is
$480,000.
Other Activities
- ----------------
The Company and joint venture partners constructed an NGL fractionating plant in
Alabama during fiscal 1994 and 1995. The results of the plant operations have
been disappointing due to both mechanical inefficiencies and changing market
conditions for NGL products. A new plant operator was appointed by the co-
owners of the plant in November 1996 and certain mechanical modifications were
made. In January 1997, the Company engaged a consulting engineering firm to
further investigate and analyze the operations of the plant and the marketing
and transportation of the plant products. The Company is currently evaluating
the findings of the study and, together with the co-owners, may seek to
restructure the terms under which it provides fractionating services in an
effort to improve the plant's profitability. The Company is also considering
other alternatives, including possible new markets, that could improve operating
results. The Company has an interest in plant profits of 55% prior to payout
and 47% thereafter. As of March 31, 1997, the Company had invested $2,303,000,
which is net of a distribution of $77,000 and a net loss of $75,000 during
fiscal 1996 and a net loss of $193,000 during the first half of fiscal 1997.
The combined net loss of $268,000 represents the Company's share
7
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of the net loss from the Plant's operations from start-up in late November 1995
through March 31, 1997. The loss during the first six months of fiscal 1997 is
due to a lower profit margin on the products, maintenance to improve the plant's
efficiency and to a decrease in inlet volumes of raw NGLs.
RESULTS OF OPERATIONS - COMPARISON OF THE THREE MONTHS ENDED MARCH 31, 1997, AND
1996
The Company reported net income of $185,000 for the three months ended March 31,
1997, compared to a net loss of $171,000 for the three months ended March 31,
1996. Operating income increased $521,000 to $487,000 in the fiscal 1997
quarter from an operating loss of $34,000 in the corresponding quarter of fiscal
1996. The increase in operating income is due to higher oil and gas prices and
to lower depreciation, depletion and amortization ("DD&A") during the three
months ended March 31, 1997, as compared to the prior year quarter. Following
are detailed comparisons of the components of the respective periods.
Operating revenues for the three months ended March 31, 1997, increased
$378,000, or 14%, to $3,064,000 from $2,686,000 in the corresponding fiscal 1996
quarter. Oil volumes decreased 12,000 barrels, or 10%, to 107,000 barrels
versus 119,000 barrels in the prior year quarter, decreasing revenue by
$204,000. Gas volumes decreased 57,000 Mcf, or 15%, to 324,000 Mcf in the
current quarter compared to 381,000 Mcf in the three months ended March 31,
1996, resulting in a $97,000 decrease in revenues. These volume decreases are
attributable to sales of producing properties during the prior year period and
to natural declines in production rates. Average oil prices increased 13% to
$19.16 per barrel for the three months ended March 31, 1997, from $16.96 per
barrel for the corresponding prior year quarter, resulting in a $235,000
increase in revenue. Gas prices increased 80% to $3.06 per Mcf in the current
year quarter versus $1.70 in the prior year quarter, resulting in a $441,000
revenue increase. Saltwater disposal and other income increased $3,000 from the
corresponding fiscal 1996 quarter.
Operating expenses increased $46,000, or 3%, to $1,446,000 from $1,400,000
reported in fiscal 1996. The Company's average lifting cost per equivalent
barrel increased 14% to $8.21 in the three month period of fiscal 1997 from
$7.19 in the prior year period. These increases were primarily attributable to
increased production taxes resulting from higher oil and gas prices and to
remedial work on mature properties. The increase in operating expenses is also
due to a payment in March 1997 of $90,000 in settlement of litigation. (See
Note 3 to the Consolidated Financial Statements.)
General and administrative expenses increased by $40,000, or 12%, to $382,000
during the three months ended March 31, 1997, compared to $342,000 for the prior
year period. The increase was primarily due to increased payroll costs
resulting from an increase in the size of the Company's staff and to an increase
in legal fees.
DD&A expense for the three months ended March 31, 1997, decreased by $229,000,
or 23%, to $749,000 from $978,000 reported for the comparable fiscal 1996
period. The decrease is attributable to a lower DD&A rate per equivalent barrel
resulting from an increase in oil and gas reserve volumes as of March 31, 1997,
compared to March 31, 1996.
Interest income decreased $13,000, or 30%, to $30,000 in the quarter ended March
31, 1997, from $43,000 in the corresponding prior year quarter. This decrease
is due to a decrease in the average balance of cash and cash equivalents.
Dividend income decreased to $0 during the quarter ended March 31, 1997 from
$22,000 in the quarter ended March 31, 1996. Dividend income was accrued during
fiscal 1996 on 354,000 shares of convertible preferred stock in United States
Exploration, Inc. ("USXP"). The convertible preferred stock was exchanged for
common stock of USXP on September 30, 1996.
Interest expense for the three months ended March 31, 1997, decreased $39,000,
or 16%, to $210,000 from $249,000 for the three months ended March 31, 1996.
When capitalized interest is included, interest expense increased by $24,000.
Such increase is attributable to an increase in debt and to higher interest
rates.
Research and development expense decreased to $0 in the three months ended March
31, 1997, from $17,000 in the three months ended March 31, 1996. The Company
met its contractual funding commitment in the fourth quarter of fiscal 1994, but
has made voluntary payments from time to time for third party consulting
services.
Income tax expense decreased $19,000 to a benefit of $18,000 for the second
quarter of fiscal 1997 from an expense of $1,000 in the prior year quarter. The
tax benefit during the fiscal 1997 quarter resulted from adjustments to the
expected income tax liability.
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The equity in earnings of the NGL fractionator decreased $205,000 to a loss of
$140,000 in the quarter ended March 31, 1997 from income of $65,000 in the prior
year quarter. The loss in the fiscal 1997 quarter is attributable to a lower
profit margin on NGL products and to a decrease in inlet volumes.
RESULTS OF OPERATIONS - COMPARISON OF THE SIX MONTHS ENDED MARCH 31, 1997, AND
1996
The Company reported net income of $1,163,000 for the six months ended March 31,
1997, versus a net loss of $412,000 for the six months ended March 31, 1996.
Operating income increased $1,835,000 to $1,757,000 in the first six months of
fiscal 1997 from a loss of $78,000 in the prior year period. This increase was
primarily attributable to higher oil and gas prices. Following are detailed
comparisons of the components of the respective periods.
Operating revenues for the six months ended March 31, 1997, increased
$1,859,000, or 35%, to $7,176,000 from $5,317,000 in the corresponding fiscal
1996 period. Oil volumes increased 11,000 barrels, or 5%, to 253,000 barrels
versus 242,000 barrels in the prior year period, increasing revenue by $181,000.
Gas volumes decreased 27,000 Mcf, or 3%, to 761,000 Mcf in the current period
compared to 788,000 Mcf in the six months ended March 31, 1996, resulting in a
$43,000 decrease in revenues. Gas volumes decreased due to the sale of
producing properties and to declining production rates. Oil volume increases
are largely attributable to new production during the first fiscal quarter
resulting from exploitation and development drilling projects completed in the
fourth quarter of fiscal 1996. Average oil prices increased 25% to $20.57 per
barrel for the six months ended March 31, 1997, from $16.41 per barrel for the
corresponding prior year period, resulting in a $1,052,000 increase in revenue.
Gas prices increased 56% to $2.48 per Mcf in the current period versus $1.59 in
the prior year period, resulting in a $677,000 revenue increase. Saltwater
disposal and other income decreased $8,000 from the corresponding fiscal 1996
period.
Operating expenses increased $218,000, or 8%, to $2,916,000 from $2,698,000
reported in fiscal 1996. The Company's average lifting cost per equivalent
barrel increased 9% to $7.32 in the first six months of fiscal 1997 from $6.73
in the prior year period. These increases were primarily attributable to higher
production taxes resulting from higher oil and gas prices and to remedial work
on mature properties. The increase in operating expenses is also due to a
payment in March 1997 of $90,000 in settlement of litigation. (See Note 3 to
the Consolidated Financial Statements.)
General and administrative expenses increased by $128,000, or 19%, to $819,000
during the six months ended March 31, 1997, compared to $691,000 for the prior
year period. The increase was primarily due to increased payroll costs
resulting from an increase in the size of the Company's staff and to an increase
in legal fees.
DD&A expense for the six months ended March 31, 1997, decreased by $322,000, or
16%, to $1,684,000 from $2,006,000 reported for the comparable fiscal 1996
period. The decrease is attributable to a lower DD&A rate per equivalent barrel
resulting from an increase in oil and gas reserve volumes as of March 31, 1997,
compared to March 31, 1996.
Interest income decreased $52,000, or 47%, to $59,000 in the six months ended
March 31, 1997, from $111,000 in the corresponding prior year period. This
decrease is due to a decrease in the average balance of cash and cash
equivalents.
Dividend income decreased to $0 during the six months ended March 31, 1997 from
$44,000 in the six months ended March 31, 1996. Dividend income was accrued
during fiscal 1996 on 354,000 shares of convertible preferred stock in United
States Exploration, Inc. ("USXP"). The convertible preferred stock was
exchanged for common stock of USXP on September 30, 1996.
Interest expense for the six months ended March 31, 1997, decreased $50,000, or
10%, to $455,000 from $505,000 for the six months ended March 31, 1996. When
capitalized interest is included, interest expense increased by $11,000. Such
increase is attributable to an increase in debt and to higher interest rates.
Research and development expense decreased to $0 in the six months ended March
31, 1997, from $17,000 in the six months ended March 31, 1996. The Company met
its contractual funding commitment in the fourth quarter of fiscal 1994, but has
made voluntary payments for third party consulting services.
Current income tax expense increased to $5,000 in the six months ended March 31,
1997, from $4,000 in the first six months of fiscal 1996. The expense reflects
an effective federal tax rate of 2%, rather than 35%, because the Company
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has utilized a portion of its net operating loss carryover. The Company,
however, must pay the alternative minimum tax at an effective rate of 2%.
The equity in earnings of the NGL fractionator decreased $230,000 to a loss of
$193,000 in the six months ended March 31, 1997, from income of $37,000 during
the corresponding prior year period. The loss in fiscal 1997 is attributable to
a lower profit margin on NGL products, a decrease in inlet volumes and to
maintenance on the plant.
Information herein contains forward-looking statements within the meaning of the
Private Securities Litigation Reform Act of 1995, which can be identified by
words such as "may," "will," "expect," "anticipate," "estimate" or "continue,"
or comparable words. In addition, all statements other than statements of
historical facts that address activities that Tipperary expects or anticipates
will or may occur in the future are forward-looking statements. Readers are
encouraged to read the SEC reports of Tipperary, particularly its Form 10-K for
the Fiscal Year Ended September 30, 1996, for meaningful cautionary language
disclosing why actual results may vary materially from those anticipated by
management.
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PART II - OTHER INFORMATION
Item 1. Legal Proceedings
- ------
See Note 2 to the consolidated financial statements under Part I - Item 1.
Item 2. Changes in Securities
- ------
See Note 3 to the consolidated financial statements under Part I - Item 1.
Item 3. Defaults Upon Senior Securities
- ------
None
Item 4. Submission of Matters to a Vote of Security Holders
- ------
The Company held its Annual Meeting of Shareholders on January 28, 1997,
and proxies for such meeting were solicited pursuant to Regulation 14A
adopted under the Securities Exchange Act of 1934. There was no
solicitation in opposition to management's nominees for directors as listed
in the proxy statement and all such nominees were elected. The table below
summarizes voting results:
Votes For Votes Withheld
---------- --------------
Kenneth L. Ancell 10,074,957 31,390
David L. Bradshaw 10,085,957 20,390
Eugene I. Davis 10,074,917 31,430
Douglas Kramer 10,085,958 20,389
Marshall D. Lees 9,820,452 285,895
In addition, the shareholders voted on and approved two other proposals as
listed in the proxy statement and summarized below.
1. The shareholders approved the Company's 1997 Long-Term Incentive Plan,
which reserves 250,000 shares of common stock for issuance under
options which may be granted under the Plan. The vote was 9,898,575
for, 126,318 against and 81,454 abstained.
2. The shareholders ratified the selection of Price Waterhouse LLP as
independent auditors. The vote was 10,062,788 for, 18,233 against and
25,326 abstained.
Item 5. Other Information
- ------
None
Item 6. Exhibits and Reports on Form 8-K
- ------
(a) Exhibits:
--------
Filed in Part I
11. Computation of per share earnings
Filed in Part II
4.50 Fifth Amendment of Revolving Credit and Term Loan Agreement
dated March 3, 1997, by and among Tipperary Corporation, and
Tipperary Oil & Gas Corporation, and Colorado National Bank,
a national banking association.
(b) Reports on Form 8-K:
-------------------
None
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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.
Tipperary Corporation
----------------------------------------------
Registrant
Date: May 15, 1997 By: /s/ David L. Bradshaw
----------------------------------------------
David L. Bradshaw, President, Chief Executive
Officer and Chairman of the Board of Directors
Date: May 15, 1997 By: /s/ Paul C. Slevin
----------------------------------------------
Paul C. Slevin, Chief Financial Officer
Date: May 15, 1997 By: /s/ Wayne W. Kahmeyer
----------------------------------------------
Wayne W. Kahmeyer, Controller and Principal
Accounting Officer
12