<PAGE> 1
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-KSB
Annual Report under Section 13 or 15(d) of the Securities Exchange Act of 1934
For the fiscal year ended September 30, 1997
Commission File Number: 0-9116
PANHANDLE ROYALTY COMPANY
(Exact name of small business registrant in its charter)
<TABLE>
<S> <C>
OKLAHOMA 73-1055775
(State or other jurisdiction of (I.R.S. Employer
incorporation or organization ) Identification No.)
</TABLE>
<TABLE>
<S> <C>
Grand Centre Suite 210, 5400 N Grand Blvd., Okla. City, OK 73112
(Address of principal executive offices) (zip code)
</TABLE>
Registrant's telephone number (405) 948-1560
Securities registered under Section 12(B) of the Exchange Act: NONE
Securities registered under Section 12(g) of the Exchange Act:
(Title of Class)
CLASS A COMMON STOCK (VOTING) .10 par value
(Title of Class)
CLASS B COMMON STOCK (NON-VOTING) $1.00 par value
Check whether the registrant (1) has filed all reports required to be filed by
Section 13 or 15(d) of the Exchange Act during the past 12 months (or for such
shorter period that the registrant was required to file such reports), and (2)
has been subject to such filing require-ments for the past 90 days.
X Yes No
--- ---
Check if there is no disclosure of delinquent filers in response to Item 405 of
Regulation SB contained in this form, and no disclosure will be contained, to
the best of registrant's knowledge, in the definitive proxy or information
statements incorporated by reference in Part III of this Form 10-KSB or any
amendment to this Form 10-KSB. {X}
Registrant's revenues for fiscal year-end September 30, 1997, were $7,016,478.
The aggregate market value of the voting stock held by non-affiliates of the
registrant, computed by using the closing price of registrant's common stock,
at December 2, 1997, was $20,978,230. As of December 2, 1997, 679,820 class A
common shares were outstanding.
Documents Incorporated By Reference..... NONE
<PAGE> 2
T A B L E O F C O N T E N T S
<TABLE>
<CAPTION>
PART I PAGE
- ------ ----
<S> <C> <C>
Item 1. Description of Business . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-4
Item 2. Description of Properties . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-10
Item 3. Legal Proceedings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10
Item 4. Submission of Matters to a Vote of
Security Holders . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10
PART II
- -------
Item 5. Market for Common Equity and
Related Stockholder Matters . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-11
Item 6. Management's Discussion and Analysis
or Plan of Operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11-14
Item 7. Financial Statements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14-31
Item 8. Changes in and Disagreements with
Accountants on Accounting and
Financial Disclosure . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 32
PART III
- --------
Item 9. Directors, Executive Officers, Promoters
and Control Persons; Compliance with
Section 16(a) of the Exchange Act . . . . . . . . . . . . . . . . . . . . . . . . . 32-34
Item 10. Executive Compensation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 34-35
Item 11. Security Ownership of Certain Beneficial
Owners and Management . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 35-36
Item 12. Certain Relationships and Related
Transactions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 36
Item 13. Exhibits and Reports on Form 8-K . . . . . . . . . . . . . . . . . . . . . . . . . . . . 36-37
Exhibit 22 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 37
Signature Page . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 38
</TABLE>
( i )
<PAGE> 3
PART I
ITEM 1. DESCRIPTION OF BUSINESS
FORWARD-LOOKING STATEMENTS
Forward-looking statements for 1998 and later periods are
made throughout this document. Such statements represent estimates of
management based on the Company's historical operating trends, its proved
reserves and other information currently available to management. The Company
cautions that the forward-looking statements provided herein are subject to all
the risks and uncertainties incident to the acquisition, development and
marketing of, and exploration for oil and gas reserves. These risks include,
but are not limited to oil and natural gas price risk, environmental risk,
drilling risk, reserve quantity risk and operations and production risks. For
all the above reasons, actual results may vary materially from the
forward-looking statements and there is no assurance that the assumptions used
are necessarily the most likely to occur.
BUSINESS DEVELOPMENT
Panhandle Royalty Company ("Panhandle" or the "Company") is
an Oklahoma Corporation, organized in 1926 as Panhandle Cooperative Royalty
Company. In 1979, Panhandle Cooperative Royalty Company was merged into
Panhandle Royalty Company. Panhandle's authorized and registered stock
consisted of 100,000 shares of $1.00 par value class A common stock. In 1982,
the Company split the stock on a 10-for-1 basis and reduced the par value to
$.10, resulting in 1,000,000 shares of authorized class A common stock. Since
its formation, the Company has been involved in the acquisition and management
of mineral interests and the exploration for, and development of, oil and gas
properties, principally involving wells located on the Company's mineral
interests. Panhandle's mineral properties and other oil and gas interests are
located primarily in Oklahoma, New Mexico and Texas. Properties are also
located in twelve other states. The majority of the Company's oil and gas
production is from wells located in the Anadarko Basin of western Oklahoma and
the Dagger Draw Field in Eddy County, New Mexico. In 1988, the Company merged
with New Mexico Osage Royalty Company, thus acquiring most of its New Mexico
mineral interests. The Company's offices are located at Grand Centre Suite
210, 5400 N. Grand Blvd., Oklahoma City, OK 73112 (405)948-1560, FAX
(405)948-2038.
BUSINESS OF ISSUER
The majority of Panhandle's revenues are derived from the
production and sale of oil and natural gas. See "Item 7 - Financial
Statements". The Company's oil and gas holdings, including its mineral
interests and its interests in producing wells, both working interests and
royalty interests, are centered in Oklahoma with increasingly more activity, in
recent years, in New Mexico and Texas. See "Item 2 - Description of
Properties". Exploration and development of the Company's oil and gas
properties is conducted in association with operating oil and gas companies,
including major and independent companies. The Company does not operate any of
its oil and gas
(1)
<PAGE> 4
properties. Drilling operations have been active the last five years with
wells drilled on the Company's mineral properties and on third party drilling
prospects. A large percentage of the Company's recent drilling participations
have been on properties in which the Company has mineral interests and in many
cases already owns an interest in a producing well in the unit. This
"increased density" drilling has accounted for a majority of the successful oil
and gas wells completed in the last five years and has added significant
reserves for the Company. The Company has also been actively acquiring
additional mineral interest properties the last five years. On November 17,
1995 the Company acquired a 50% interest in 65,632 net mineral acres from
Petrocorp, Incorporated. These mineral interests are primarily located in
Oklahoma and Texas and also in eleven other states, and are primarily
non-producing properties. Included however, were small royalty interests in
approximately 170 producing wells and working interests in 5 producing wells.
See "Item 7 - Financial Statements, Note 7". Several of the mineral properties
purchased in the last five years have been in areas where the Company had no
mineral holdings, thus expanding the Company's area of interest.
PRINCIPAL PRODUCTS AND MARKETS
The Company's principal products are crude oil and natural
gas. These products are sold to various purchasers, including pipeline
companies, which are generally located in and service the areas where the
Company's producing wells are located. The Company does not act as operator
for any of the properties in which it owns an interest, thus it relies on the
operating expertise of numerous companies that operate in the area where the
Company owns mineral interests. This expertise includes drilling operations
and completions, producing well operations and, in some cases, the marketing or
purchasing of the well's production. Natural gas sales are contracted by
either the Company or the well operator and are contracted principally on a
monthly basis with third party gas marketers and pipeline companies. Payment
for gas sold is received either from the contracted purchasers or the well
operator. Crude oil sales are generally handled by the well operator and
payment for oil sold is received from the well operator or from the crude oil
purchaser.
COMPETITIVE BUSINESS CONDITIONS
The oil and gas industry is highly competitive, both in the
search for new oil and gas reserves and the marketing of the production from
wells. There are many factors affecting Panhandle's competitive position and
the market for its products which are beyond its control. Some of these
factors are quantity and price of foreign oil imports, changes in prices
received for its oil and gas production, business and consumer demand for
refined oil products and natural gas, and the effects of federal and state
regulation of oil and gas sales. Changes in existing economic conditions,
weather patterns and actions taken by OPEC and other oil-producing countries
have dramatic influence on the price Panhandle receives for its oil and gas
production. The Company relies heavily on companies with greater resources,
staff, equipment, research, and experience for operation of wells and the
development and drilling of subsurface prospects. The Company uses its strong
financial
(2)
<PAGE> 5
base and its mineral property ownership to participate in drilling operations
with these larger companies. This method allows the Company to effectively
compete in drilling operations it could not undertake on its own due to
financial and personnel limits and to maintain low overhead costs.
SOURCES AND AVAILABILITY OF RAW MATERIALS
The existence of commercial oil and gas reserves is essential
to the ultimate realization of value from the Company's mineral properties and
these mineral properties may be considered a raw material to its business. The
production and sale of oil and natural gas from the Company's oil and gas
properties is essential to provide the cash flow necessary to sustain the
ongoing viability of the Company. The Company continues to reinvest a large
portion of its cash flow in the purchase of additional mineral properties to
assure the continued availability of acreage with which to participate in
exploration, drilling, and development operations and subsequently the
production and sale of oil and gas. This participation in exploration and
production and the purchasing of additional mineral interests will continue to
supply the Company with the raw materials with which to generate additional
cash flow. Mineral purchases are made from varied owners, and the Company does
not rely on any particular companies or individuals for these acquisitions.
MAJOR CUSTOMERS
The Company's oil and gas production is sold to many
different purchasers on a well-by-well basis. No one purchaser accounts for a
major percentage of the Company's revenues. Generally, if one purchaser
declines to continue purchasing the Company's oil and/or natural gas, several
other purchasers can be located. Pricing is usually reasonably consistent from
purchaser to purchaser.
PATENTS, TRADEMARKS, LICENSES, FRANCHISES AND
ROYALTY AGREEMENTS
The Company does not own any patents, trademarks, licenses or
franchises. Royalty agreements on producing oil and gas wells stemming from
the Company's ownership of mineral interests generate a substantial portion of
the Company's revenues. These royalties are tied to the ownership of the
mineral interests and this ownership is perpetual, unless sold by the Company.
Royalties are due and payable to the Company whenever oil and/or gas is
produced from wells located on the Company's mineral properties.
GOVERNMENTAL REGULATION
Oil and gas production is subject to various taxes, such as
gross production taxes and, in some cases, ad valorem taxes.
The State of Oklahoma and other states require permits for
drilling operations, drilling bonds and reports concerning operations and
impose other requirements relating to the exploration and production of oil and
gas. Such states also have regulations addressing
(3)
<PAGE> 6
conservation matters, including provisions for the unitization or pooling of
oil and gas properties, the establishment of maximum rates of production from
oil and gas wells and the regulation of spacing, plugging and abandonment of
such wells. These statutes and regulations currently limit the rate at which
oil and gas can be produced from certain of the Company's properties,
especially in the Dagger Draw field of New Mexico.
Federal tax law allows producers of "tight gas" to utilize an
approximate $.52/MMBTU tax credit for gas produced from approved wells. The
credit is a direct reduction of regular federal income tax. Panhandle began
receiving revenues from "tight gas" wells during fiscal 1992. This credit will
be available for all tight gas sold prior to January 1, 2003, and is expected
to substantially reduce the Company's cash outlay for income taxes.
ENVIRONMENTAL MATTERS
As the Company is directly involved in the extraction and use
of natural resources, it is subject to various federal, state and local
provisions regarding environmental and ecological matters. Compliance with
these laws may necessitate significant capital outlays, however, to date the
Company's cost of compliance has been insignificant, and the Company is not
currently aware of any potentially material environmental problems on any of
its properties. The Company does not feel the existence of these environmental
laws will materially hinder or adversely affect the Company's business
operations; however, there can be no assurances of future events. Since the
Company does not operate any wells in which it owns an interest, actual
compliance with environmental laws is controlled by others, with Panhandle
being responsible for its proportionate share of the costs involved. Panhandle
carries liability insurance and to the extent available at reasonable cost,
pollution control coverage. However, all risks are not insured due to
insurance availability and/or cost thereof.
EMPLOYEES
Panhandle employs eight persons on a full-time basis and has
no part-time employees. Three of the employees are executive officers and one
is also a director of the Company.
ITEM 2. DESCRIPTION OF PROPERTIES
As of September 30, 1997, Panhandle's principal properties
consisted of perpetual ownership of 175,596 net mineral acres, held in tracts
in Alabama, Arkansas, Colorado, Idaho, Kansas, Illinois, Indiana, Montana,
Nebraska, New Mexico, North Dakota, Oklahoma, Tennessee and Texas. The Company
also held leases on 5,613 net acres of minerals in Louisiana, Oklahoma and
Texas. At September 30, 1997, Panhandle held royalty and/or working interests
in 1,356 producing oil or gas wells, 27 successfully completed but not yet
producing wells, and 31 wells in the process of being drilled or completed.
(4)
<PAGE> 7
Panhandle does not have current abstracts or title opinions
on all mineral properties owned and, therefore, cannot warrant that it has
unencumbered title to all of its properties. In the period from 1927 through
1937, the Company lost title to a number of its then owned mineral acres
through foreclosures and tax sales of the surface acreage overlying its
minerals. In recent years, few challenges have been made against the Company's
fee title to its properties.
Panhandle pays ad valorem taxes on its minerals owned in
Arkansas, Colorado, Idaho, Indiana, Illinois, Kansas, Tennessee and Texas.
ACREAGE
The following table of mineral interests owned reflects, as
of September 30, 1997, in each respective state, the number of net and gross
acres, net and gross producing acres, net and gross acres leased, and net and
gross acres open (unleased).
MINERAL INTERESTS
<TABLE>
<CAPTION>
Net Gross Net Gross Net Gross
Acres Acres Acres Acres Acres Acres
Net Gross Prod'g Prod'g Leased Leased Open Open
St. Acres Acres (1) (1) (2) (2) (3) (3)
- --- ------- ------- ------ ------ ------ ------ ------- -------
<S> <C> <C> <C> <C> <C> <C> <C>
AL 5 479 5 479
AR 5,890 32,016 64 220 40 80 5,786 31,716
CO 8,161 38,280 8,161 38,280
ID 30 880 30 880
IL 1,018 4,393 1,018 4,393
IN 27 262 27 262
KS 620 5,360 60 480 560 4,880
MT 422 7,960 422 7,960
NE 439 5,960 439 5,960
ND 292 5,036 37 320 255 4,716
NM 53,287 152,343 1,113 4,219 2,639 7,137 49,535 140,987
OK 81,248 630,798 15,821 83,073 1,836 24,359 63,591 523,366
TN 1,543 3,087 1,543 3,087
TX 22,614 212,701 977 33,272 218 3,276 21,419 176,153
------- --------- ------ ------- ------ ------ ------- -------
TOT: 175,596 1,099,555 18,035 121,264 4,770 35,172 152,791 943,119
------- --------- ------ ------- ------ ------ ------- -------
</TABLE>
(1) "Producing" represents the mineral acres in which Panhandle owns a royalty
or working interest in a producing well.
(2) "Leased" represents the mineral acres, owned by Panhandle, that are leased
to third parties but not producing.
(3) "Open" represents mineral acres owned by Panhandle that are not leased or
in production.
This table reflects net mineral acres leased from others,
lease expiration dates, and net leased acres held by production.
LEASES
<TABLE>
<CAPTION>
Net Acres Leases
Expiring Net Acres
Net -------------------- Held By
State Acres 1998 1999 2000 Production
----- ------- ---- ---- ---- ----------
<S> <C> <C> <C> <C> <C>
LA 137 137
OK 5,024 923 422 1,808 1,871
TX 452 323 66 13 50
------- ----- ----- ----- ---------
TOT: 5,613 1,246 488 1,821 2,058
------- ----- ----- ----- ---------
</TABLE>
(5)
<PAGE> 8
PROVED RESERVES
The following table summarizes estimates of the proved
reserves of oil and gas held by Panhandle. All reserves are located within the
United States. Because the Company's nonproducing mineral and leasehold
interests consist of various small interests in numerous tracts located
primarily in Oklahoma, New Mexico and Texas and because the Company is a
non-operator and must rely on third parties to propose and drill wells, it is
not feasible to provide estimates of all proved undeveloped reserves and
associated future net revenues. Prior to fiscal 1995, the Company did not
provide estimates of any proved undeveloped reserves. Since 1995 the Company
has provided estimates of proved undeveloped reserves for certain areas of
western Oklahoma where a large amount of increased density gas drilling had
taken place during the prior few years. In 1996 estimates of certain proved
undeveloped reserves in the Dagger Draw field in southeastern New Mexico were
added. Production in this field has grown rapidly over the last four years and
numerous undrilled well locations are situated on minerals owned by Panhandle.
Due to field production allowable rules in Dagger Draw, only those proved
undeveloped reserves which the Company felt could be drilled, under existing
allowable rules, have been included. Should the allowable rules be amended
and/or production volumes change significantly, additional proved undeveloped
reserves may be added in the future. The Company, in both cases, expects
drilling to continue for the next several years, and thus made the decision to
provide proved undeveloped reserve estimates for these areas. All reserve
estimates were compiled by Campbell & Associates, Inc., an independent
petroleum engineering firm. The Company's reserve estimates were not filed
with any other federal agency.
<TABLE>
<CAPTION>
Proved Developed Reserves Barrels of Oil MCF of Gas
------------------------- -------------- --------------
<S> <C> <C>
September 30, 1993 227,342 7,300,317
September 30, 1994 251,246 7,442,524
September 30, 1995 454,577 7,618,673
September 30, 1996 641,213 8,200,957
September 30, 1997 625,370 9,707,242
</TABLE>
<TABLE>
<CAPTION>
Proved Undeveloped Reserves
---------------------------
<S> <C> <C>
September 30, 1995 10,339 1,570,440
September 30, 1996 297,582 1,638,104
September 30, 1997 278,438 1,559,860
</TABLE>
<TABLE>
<CAPTION>
Total Proved Reserves
---------------------
<S> <C> <C>
September 30, 1995 464,916 9,189,113
September 30, 1996 938,795 9,839,061
September 30, 1997 903,808 11,267,102
</TABLE>
Because the determination of reserves is a function of
testing, evaluating, developing oil and gas reservoirs and establishing a
production decline history, along with product price fluctuations, it would be
expected that estimates will change as future information concerning those
reservoirs is developed and as market conditions change. Estimated reserve
quantities and future net revenues are affected by changes in product prices,
and these prices have varied substantially in recent years. Proved developed
reserves are those
(6)
<PAGE> 9
expected to be recovered through existing well bores under existing economic
and operating conditions. Proved undeveloped reserves are reserves that may be
recovered from undrilled acreage, but are usually limited to those sites
directly offsetting established production units and have sufficient geological
data to indicate a reasonable expectation of commercial success.
ESTIMATED FUTURE NET CASH FLOWS
Set forth below are estimated future net cash flows with
respect to Panhandle's proved reserves (based on the estimated units set forth
in the immediately preceding table) as of year ends, and the present value of
such estimated future net cash flows, computed by applying a ten (10) percent
discount factor as required by the rules and regulations of the Securities and
Exchange Commission. Estimated future net cash flows have been computed by
applying current year-end prices to future production of proved reserves less
estimated future expenditures (based on costs as of year end) to be incurred
with respect to the development and production of such reserves. Such pricing
is based on SEC guidelines. No federal income taxes are included in estimated
costs. However, the amounts are net of production taxes levied by respective
states. Prices used for determining future cash flows from oil and natural gas
for the periods ended September 30, 1997, 1996 and 1995 were as follows: 1997
- - $19.12, $2.48; 1996 - $23.88, $1.84; 1995 - $17.23, $1.56. These future net
cash flows should not be construed as the fair market value of the Company's
reserves. A market value determination would need to include many additional
factors, including anticipated oil and gas price increases or decreases.
Estimated Future Net Cash Flows
<TABLE>
<CAPTION>
9-30-97 9-30-96 9-30-95
----------- ----------- -----------
<S> <C> <C> <C>
Proved Developed $29,186,361 $25,166,810 $16,055,355
Proved Undeveloped $ 7,188,163 $ 8,363,380 $ 1,442,460
----------- ----------- -----------
Total Proved $36,374,530 $33,530,190 $17,497,815
</TABLE>
10% Discounted Present Value of Estimated Future Net Cash Flows
<TABLE>
<CAPTION>
9-30-97 9-30-96 9-30-95
----------- ----------- -----------
<S> <C> <C> <C>
Proved Developed $19,890,600 $17,827,160 $11,126,168
Proved Undeveloped $ 4,430,870 $ 5,328,364 $ 799,923
----------- ----------- -----------
Total Proved (1) $24,321,470 $23,155,524 $11,926,091
</TABLE>
(1) The increase from September 30, 1996 to September 30, 1997 is
attributable to the increase in gas sales prices at September
30, 1997 compared to the sales prices at September 30, 1996,
offset, in large part, by the decline in oil sales prices at
September 30, 1997 compared to the sales price at September
30, 1996.
(7)
<PAGE> 10
OIL AND GAS PRODUCTION
The following table sets forth the Company's net production
of oil and gas for the fiscal periods indicated.
<TABLE>
<CAPTION>
Year Year Year
Ended Ended Ended
9-30-97 9-30-96 9-30-95
----------- ----------- -----------
<S> <C> <C> <C>
Bbls - Oil 147,734 145,301 82,676
MCF - Gas 1,600,247 1,551,147 1,203,623
</TABLE>
Average Sales Prices and Production Costs
The following table sets forth unit price and cost data for
the fiscal periods indicated.
<TABLE>
<CAPTION>
Year Year Year
Ended Ended Ended
Average Sales Price 9-30-97 9-30-96 9-30-95
------------------- ----------- ----------- -----------
<S> <C> <C> <C>
Per Bbl. Oil $ 21.21 $ 19.93 $ 17.26
Per MCF Gas $ 2.39 $ 1.95 $ 1.39
Average Production (Lifting Cost)
Per Equivalent
Bbl. Oil (1)(2) $ 2.54 $ 2.46 $ 2.62
</TABLE>
(1) Gas production is converted to barrel equivalents at the rate
of 6 MCF per barrel, representing the estimated relative
energy content of natural gas and oil.
(2) Includes well operating costs and production taxes.
Average production costs are influenced by the fact that the
Company bears no costs of production on many of its well interests, as a large
part of the Company's producing well interests are royalty interests, which
bear no share of the operating costs.
GROSS AND NET PRODUCTIVE WELLS AND DEVELOPED ACRES
The following table sets forth Panhandle's gross and net
productive oil and gas wells as of September 30, 1997. Panhandle owns
fractional royalty interests or fractional working interests in these wells.
The Company does not operate any wells.
<TABLE>
<CAPTION>
Gross Wells Net Wells
----------- ---------
<S> <C> <C>
Oil 401 13.093635
Gas 955 16.784738
----------- ---------
TOTAL 1,356 29.878373
</TABLE>
Information on multiple completions is not available from
Panhandle's records, but the number of such is insignificant.
(8)
<PAGE> 11
As of September 30, 1997, Panhandle owned 121,264 gross
developed mineral acres and 18,035 net developed mineral acres. Panhandle has
also leased from others 26,521 gross developed acres which contain 2,058 net
developed acres.
UNDEVELOPED ACREAGE
As of September 30, 1997, Panhandle owned 978,291 gross and
157,561 net undeveloped mineral acres, and leases on 22,487 gross and 3,555 net
acres.
DRILLING ACTIVITY
The following net productive development and exploratory
wells and net dry development and exploratory wells, in which the Company had a
fractional royalty or working interest, were drilled and completed during the
fiscal years indicated. Also shown are the net wells purchased during these
periods.
<TABLE>
<CAPTION>
-------------- -------
- ----------------- Net Productive Net Dry
Development Wells Wells Wells
- ----------------- -------------- -------
<S> <C> <C>
Fiscal year ending
September 30, 1995 1.184040 .524182
Fiscal year ending
September 30, 1996 1.614002 .485562
Fiscal year ending
September 30, 1997 2.630851 .659734
Exploratory Wells
- -----------------
Fiscal year ending
September 30, 1995 .255000 .322656
Fiscal year ending
September 30, 1996 .456455 .231341
Fiscal year ending
September 30, 1997 .627670 .477731
Purchased Wells
- ---------------
Fiscal year ending
September 30, 1995 .389869 0
Fiscal year ending
September 30, 1996 1.542173 0
Fiscal year ending
September 30, 1997 .798765 0
</TABLE>
(9)
<PAGE> 12
PRESENT ACTIVITIES
The following table sets forth the gross and net oil and gas
wells drilling or testing as of September 30, 1997, in which Panhandle owns a
royalty or working interest.
<TABLE>
<CAPTION>
Gross Wells Net Wells
----------- ---------
<S> <C> <C>
Oil 5 .334675
Gas 26 .751520
</TABLE>
The Company has very small interests in three waterflood
operations in Oklahoma and Texas which have neglible revenues and expenses to
the Company. No additional purchases or start-ups of waterflood, pressure
maintenance or other related operations are currently planned.
ITEM 3. LEGAL PROCEEDINGS
There were no material legal proceedings involving Panhandle
or its subsidiary, PHC, Inc., as of the date of this report.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
No matters were submitted to a vote of Panhandle's security
holders during the fourth quarter of the fiscal year ended September 30, 1997.
PART II
ITEM 5. MARKET FOR COMMON EQUITY AND RELATED STOCKHOLDER MATTERS
The Company's common stock is listed on the NASDAQ Small-Cap
Market (symbol PANRA). The following table sets forth the high and low trade
prices of the Company's common stock, as reported by NASDAQ System Statistics
furnished by NASD, during the periods indicated:
<TABLE>
<CAPTION>
Quarter Ended HIGH LOW
----------------- ------ ------
<S> <C> <C>
December 31, 1995 18 16
March 31, 1996 18-1/2 15-3/4
June 30, 1996 21-1/2 18-1/2
September 30, 1996 22-1/4 19-1/4
December 31, 1996 37-3/4 20-3/4
March 31, 1997 33 24
June 30, 1997 36 24
September 30, 1997 33 25
</TABLE>
As of November 30, 1997, the approximate number of holders of shares
of Panhandle stock were:
<TABLE>
<CAPTION>
Title of Class Number of Holders
--------------------------- -----------------
<S> <C>
Class A Common (Voting) . . . . . . . . . . . . . 2,300
</TABLE>
(10)
<PAGE> 13
During the past two years, cash dividends have been paid as follows on
the class A common stock:
<TABLE>
<CAPTION>
DATE RATE PER SHARE
-------------- --------------
<S> <C>
December 1995 $ .15
March 1996 $ .15
June 1996 $ .15
September 1996 $ .175
December 1996 $ .20
March 1997 $ .20
June 1997 $ .20
September 1997 $ .20
</TABLE>
The Company's line of credit loan agreement contains a provision
limiting the paying or declaring of a cash dividend to fifty percent of cash
flow, as defined, of the preceding twelve-month period. See Note 3 to the
consolidated financial statements contained herein at "Item 7 - Financial
Statements", for a further discussion of the loan agreement.
ITEM 6. MANAGEMENT'S DISCUSSION AND
ANALYSIS OR PLAN OF OPERATIONS
LIQUIDITY AND CAPITAL RESOURCES
At September 30, 1997, the Company had positive working capital of
$953,528, an increase of $386,106 compared to year-end September 30, 1996.
Cash flow from operating activities increased $854,807 to $4,675,180 for fiscal
1997. The increased cash flow was a result of increased sales volumes and
average sales prices for both oil and natural gas in fiscal 1997 as compared to
fiscal 1996. These increases are discussed in greater detail in "Results of
Operations".
The Company spent $2,644,297 on drilling and equipment costs in fiscal
1997 as compared to $1,747,992 in fiscal 1996. This increased spending is a
continuation of the Company's business strategy established in 1991 to actively
pursue the development of its mineral properties by participating in more
drilling of wells on these properties. Property acquisitions are also a focal
point in the Company's business strategy. In fiscal 1996 the Company spent
$2,318,416 acquiring mineral properties, but was only successful in purchasing
$224,224 of properties in 1997. These acquisitions have been predominately
non-producing mineral properties which did not provide substantial new cash
flow. However, the Company purchases properties which are expected to generate
future drilling opportunities that will potentially increase the Company's oil
and gas reserve base and thereby increase the Company's cash flow as the
properties are developed and begin producing oil and gas. During fiscal 1997
$750,000 of cash was utilized to retire the outstanding amount of the line of
credit used to purchase a 50% interest in 65,632 net mineral acres in November
1995.
The Company expects to continue to increase its expenditues for
exploratory and developmental drilling through fiscal 1998 and for several
additional years. At September 30, 1997 the Company had commitments of
$983,037 for drilling and equipment costs for wells which
(11)
<PAGE> 14
had been proposed or were in the process of being drilled or completed. The
Company expects to spend approximately $2,700,000 for exploration and
development well costs in fiscal 1998. Those expenditures, overhead expenses,
dividend payments and any potential debt service payments are expected to be
funded by cash flow from operating activities and existing working capital.
Should the Company desire to make a large asset purchase in fiscal 1998, it
could access the $2,500,000 cash line of credit.
Panhandle anticipates that continued exploratory and development
drilling will maintain or possibly increase production volumes, and add to the
Company's reserve base. In addition, the Company continues to evaluate and
make purchase offers on both producing and non-producing mineral properties, to
further enhance the Company's future reserve base. The current cash balance,
projected cash flows from existing properties and the Company's line of credit
are adequate to fund anticipated future capital growth and should be adequate
to meet the Company's long-term operation and liquidity requirements.
RESULTS OF OPERATIONS
Oil and gas revenues increased $1,015,171, or 17%, in fiscal
1997 as compared to fiscal 1996. The improvement in revenues is attributable
to larger sales volumes of oil and natural gas and increased average sales
prices for oil and natural gas. The chart below summarizes the Company's
production and average sales prices for oil and natural gas in fiscal 1997 and
1996.
<TABLE>
<CAPTION>
PRODUCTION
------------------------------------------
OIL GAS
------------------ ----------------------
Total Average Total Average
Bbls. Price/Bbl MCF Price/MCF
------ --------- --------- ---------
<S> <C> <C> <C> <C>
Year ended 9/30/97 147,734 $ 21.21 1,600,247 $ 2.39
Year ended 9/30/96 145,301 $ 19.93 1,551,147 $ 1.95
</TABLE>
The slightly increased oil production is principally attributable to
new wells in the Dagger Draw field in southeast New Mexico. The Dagger Draw
field continues to be developed and has added substantially to the Company's
oil production for the last five years. Additional drilling is expected in the
field for at least the next two years, which should replace production lost due
to normal decline in some of the field's older wells. Gas production was up
principally due to increased demand for natural gas during the colder winter
months of fiscal 1997 and production from new gas wells coming on line in 1997.
This increased demand also had the effect of raising average natural gas sales
prices for the entire year as natural gas storage facilities were replenished
during the summer months of fiscal 1997, when natural gas demand is usually
low. In fiscal 1998, management currently expects oil prices to decrease
moderately, compared to fiscal 1997 average prices. Management expects natural
gas prices to stay in the upper $2.00 to low $3.00 range in the winter months
of fiscal 1998 and be in the $2.00 range in the summer months, thus, averaging
out comparable to the 1997 average price of $2.39 per MCF.
(12)
<PAGE> 15
Fiscal 1998 oil and gas production volumes are expected to moderately
increase. Oil production should be positively affected by production allowable
limitations on certain wells in the Dagger Draw field of New Mexico being
overcome as past overproduction will be made up. Further, as natural gas
production volumes are expected to increase slightly, and considering the
expected pricing scenario discussed above, oil and gas revenues should continue
on an upward trend in fiscal 1998. However, these increases could be
dramatically affected should there be product price declines in 1998.
Costs and expenses increased $542,287 or 16% in 1997 as compared to
1996. Lease operating expenses and production taxes (LOE); exploration costs;
and depreciation, depletion and amortization accounted for the majority of the
increase. LOE increased principally due to the increased production taxes paid
on increased oil and gas sales revenues in 1997. In addition, the number of
wells in which the Company owns a working interest continues to increase, thus
increasing LOE expenses. LOE costs are expected to continue to increase as the
Company will continue to participate in additional working interest wells.
Production taxes, which are a percentage of oil and gas sales revenues, will
track future revenues.
Depreciation, depletion and amortization (DD&A) expenses were $102,723
higher (7%) than in fiscal 1996. This increase is attributable to increased
production levels as the Company computes DD&A on the units of production
method, and reduced oil reserves at year end 1997 which was a result of the
lower oil sales price at September 30, 1997 used in the reserve calculations.
In addition, the Company adopted SFAS No. 121 in 1996 (see Note 1., Summary of
Significant Accounting Policies, to the Financial Statements contained herein
at Item 7.) and included $115,734 for 1997 and $105,019 for 1996 impairment
provisions calculated under SFAS 121 in DD&A.
Exploration costs (made up of dry hole costs and seismic costs) were
$294,875 higher in fiscal 1997 than in 1996. These costs will vary from year
to year and are principally dependent upon the Company's participation in
exploratory working interest wells drilled, and the success of those ventures.
The Company utilizes the successful efforts method of accounting for oil and
gas operations, thus exploration costs are a result of drilling unsuccessful
exploratory wells. There is no way to accurately estimate exploration costs
from year to year. The Company will continue exploratory well participations,
and thus future exploration costs can be expected.
General and administrative costs increased 15% in fiscal 1997 to
$1,006,576 The increase was principally the result of increased payroll
expenses. General and administrative costs will continue to moderately
increase as the Company continues to increase its activity level and has the
need to increase staffing levels.
The interest expense reduction of $87,415 resulted from paying off the
outstanding balance of the line of credit of $750,000 at September 30, 1996,
during fiscal 1997. However, the Company could incur additional borrowings and
related interest under the line of credit should another large asset
acquisition be made.
(13)
<PAGE> 16
The provision for income taxes increased in 1997 due to increased
income before taxes. The provision for income taxes was less than 25% of
income before taxes for both 1997 and 1996. Both provisions differ from the
calculated result should the federal statutory rate be applied due to
percentage depletion and due to tight-sands gas production tax credits allowed
on certain of the Company's gas wells.
As discussed above, the increase in net income was a function of
increased oil and gas sales revenues, offset somewhat by increased costs and
expenses. Management intends to continue the proactive approach adopted six
years ago which will include increased drilling costs in 1998. Larger
investments in drilling carry certain risks, principally exploration costs as
discussed above, the results of which can affect Company earnings. In
addition, market prices for oil and gas, over which the Company has no control,
can dramatically impact the Company's earnings, either positively or
negatively. Management feels its increasing oil and gas reserves should
translate into continually improving financial results in the near term,
barring any large increases in exploration costs, or a dramatic downturn in oil
and/or natural gas market prices.
ITEM 7. FINANCIAL STATEMENTS
<TABLE>
<S> <C>
Report of Independent Auditors ........................... 15
Consolidated Balance Sheets
As of September 30, 1997 and 1996 ............... 16
Consolidated Statements of Income For The
Years Ended September 30, 1997 and 1996 ......... 17
Consolidated Statements of Stockholders' Equity For
The Years Ended September 30, 1997 and 1996 ..... 18
Consolidated Statements of Cash Flows For
The Years Ended September 30, 1997 and 1996 ..... 19
Notes To Consolidated Financial Statements .............. 20-31
</TABLE>
(14)
<PAGE> 17
Report of Independent Auditors
Board of Directors and Stockholders
Panhandle Royalty Company
We have audited the accompanying consolidated balance sheets of Panhandle
Royalty Company as of September 30, 1997 and 1996, and the related consolidated
statements of income, stockholders' equity and cash flows for the years then
ended. These financial statements are the responsibility of the Company's
management. Our responsibility is to express an opinion on these financial
statements based on our audits.
We conducted our audits in accordance with generally accepted auditing
standards. Those standards require that we plan and perform the audit to obtain
reasonable assurance about whether the financial statements are free of
material misstatement. An audit includes examining, on a test basis, evidence
supporting the amounts and disclosures in the financial statements. An audit
also includes assessing the accounting principles used and significant
estimates made by management, as well as evaluating the overall financial
statement presentation. We believe that our audits provide a reasonable basis
for our opinion.
In our opinion, the financial statements referred to above present fairly, in
all material respects, the consolidated financial position of Panhandle Royalty
Company at September 30, 1997 and 1996, and the consolidated results of its
operations and its cash flows for the years then ended in conformity with
generally accepted accounting principles.
ERNST & YOUNG LLP
Oklahoma City, Oklahoma
November 21, 1997
(15)
<PAGE> 18
Panhandle Royalty Company
Consolidated Balance Sheets
<TABLE>
<CAPTION>
SEPTEMBER 30,
1997 1996
--------------------------------
<S> <C> <C>
ASSETS
Current assets:
Cash and cash equivalents $ 872,797 $ 399,423
Oil and gas sales and other receivables 893,779 817,258
Prepaid expenses 4,929 4,520
--------------------------------
Total current assets 1,771,505 1,221,201
Property and equipment, at cost, based on successful efforts
accounting:
Producing oil and gas properties 20,063,953 17,594,577
Nonproducing oil and gas properties 5,068,467 5,112,785
Furniture and fixtures 213,474 190,473
--------------------------------
25,345,894 22,897,835
Less accumulated depreciation, depletion and amortization 15,127,925 13,700,007
--------------------------------
Net properties and equipment 10,217,969 9,197,828
Other assets 107,716 107,716
--------------------------------
$ 12,097,190 $ 10,526,745
================================
LIABILITIES AND STOCKHOLDERS' EQUITY
Accounts payable and accrued liabilities $ 351,405 $ 165,900
Gas imbalance liability 44,380 44,380
Dividends payable 29,856 28,656
Income taxes payable 112,336 164,843
Deferred income taxes 280,000 250,000
--------------------------------
Total current liabilities 817,977 653,779
Deferred income taxes 1,247,000 908,000
Long-term debt - 750,000
Stockholders' equity:
Class A voting common stock, $.10 par value;
1,000,000 shares authorized, 679,820 issued
and outstanding (677,846 in 1996) 67,982 67,785
Capital in excess of par value 445,306 383,790
Retained earnings 9,518,925 7,763,391
--------------------------------
Total stockholders' equity 10,032,213 8,214,966
--------------------------------
$ 12,097,190 $ 10,526,745
================================
</TABLE>
See accompanying notes.
(16)
<PAGE> 19
Panhandle Royalty Company
Consolidated Statements of Income
<TABLE>
<CAPTION>
YEAR ENDED SEPTEMBER 30,
1997 1996
--------------------------------
<S> <C> <C>
Revenues:
Oil and gas sales $ 6,959,189 $ 5,944,018
Lease bonuses and rentals 14,469 29,877
Interest 17,372 25,974
Other 25,448 16,299
--------------------------------
7,016,478 6,016,168
Costs and expenses:
Lease operating expenses and production taxes 1,054,036 952,585
Exploration costs 459,861 164,986
Depreciation, depletion, amortization and impairment 1,474,203 1,371,480
General and administrative 1,006,576 875,923
Interest expense 29,960 117,375
--------------------------------
4,024,636 3,482,349
--------------------------------
Income before provision for income taxes 2,991,842 2,533,819
Provision for income taxes 693,000 513,000
--------------------------------
Net income $ 2,298,842 $ 2,020,819
================================
Net income per common share $ 3.39 $ 2.98
================================
Weighted average shares outstanding 677,627 677,586
================================
</TABLE>
See accompanying notes.
(17)
<PAGE> 20
Panhandle Royalty Company
Consolidated Statements of Stockholders' Equity
<TABLE>
<CAPTION>
COMMON STOCK CAPITAL IN
------------------------------- EXCESS OF RETAINED
SHARES AMOUNT PAR VALUE EARNINGS TOTAL
------------------------------------------------------------------------------
<S> <C> <C> <C> <C> <C>
Balances at September 30, 1995 679,642 $67,964 $400,334 $6,166,578 $ 6,634,876
Purchase and cancellation of common
shares (4,712) (471) (77,488) - (77,959)
Issuance of common shares to ESOP 2,916 292 60,944 - 61,236
Dividends declared ($.625 per share) - - - (424,006) (424,006)
Net income - - - 2,020,819 2,020,819
------------------------------------------------------------------------------
Balances at September 30, 1996 677,846 67,785 383,790 7,763,391 8,214,966
Purchase and cancellation of common
shares (446) (45) (10,237) - (10,282)
Issuance of common shares to ESOP 2,420 242 71,753 - 71,995
Dividends declared ($.80 per share) - - - (543,308) (543,308)
Net income - - - 2,298,842 2,298,842
------------------------------------------------------------------------------
Balances at September 30, 1997 679,820 $67,982 $445,306 $9,518,925 $10,032,213
==============================================================================
</TABLE>
See accompanying notes.
(18)
<PAGE> 21
Panhandle Royalty Company
Consolidated Statements of Cash Flows
<TABLE>
<CAPTION>
YEAR ENDED SEPTEMBER 30,
1997 1996
------------------------------
<S> <C> <C>
CASH FLOWS FROM OPERATING ACTIVITIES
Net income $ 2,298,842 $ 2,020,819
Adjustments to reconcile net income to net cash provided by
operating activities:
Depreciation, depletion and amortization 1,474,203 1,371,480
Deferred income taxes 369,000 245,000
Exploration costs, exclusive of seismic 405,072 125,782
Common stock issued to Employee Stock Ownership Plan 71,995 61,236
Cash provided (used) by changes in assets and liabilities:
Oil and gas sales and other receivables (76,521) (287,984)
Income tax refund receivable - 58,637
Prepaid expenses (409) (2,299)
Accounts payable and accrued liabilities 185,505 62,859
Income taxes payable (52,507) 164,843
------------------------------
Total adjustments 2,376,338 1,799,554
------------------------------
Net cash provided by operating activities 4,675,180 3,820,373
CASH FLOWS FROM INVESTING ACTIVITIES OF PROPERTY AND
EQUIPMENT
Capital expenditures, including dry hole costs (2,899,416) (4,079,415)
------------------------------
Net cash used in investing activities (2,899,416) (4,079,415)
CASH FLOWS FROM FINANCING ACTIVITIES
Borrowings under line of credit - 2,100,000
Principal payments on line of credit (750,000) (1,350,000)
Purchase and cancellation of common shares (10,282) (77,959)
Payments of dividends (542,108) (457,438)
------------------------------
Net cash provided (used) in financing activities (1,302,390) 214,603
------------------------------
Increase (decrease) in cash and cash equivalents 473,374 (44,439)
Cash and cash equivalents at beginning of year 399,423 443,862
------------------------------
Cash and cash equivalents at end of year $ 872,797 $ 399,423
==============================
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
Interest paid $ 29,960 $ 117,375
Income taxes paid 376,507 132,650
</TABLE>
See accompanying notes.
(19)
<PAGE> 22
Panhandle Royalty Company
Notes to Consolidated Financial Statements
September 30, 1997 and 1996
1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
PRINCIPLES OF CONSOLIDATION
The consolidated financial statements include the accounts of Panhandle Royalty
Company and its wholly-owned subsidiary, P.H.C., Inc. All material intercompany
transactions have been eliminated in the accompanying consolidated financial
statements.
CASH EQUIVALENTS
All highly liquid short-term investments with original maturities of three
months or less at the date of purchase by the Company are considered to be cash
equivalents. Cash equivalents at September 30, 1997 and 1996 include
certificates of deposit of $200,000 and $99,000, respectively, which are valued
at cost (approximates market) and had original maturities of 90 days or less.
OIL AND GAS SALES RECEIVABLE
The Company sells oil and natural gas to various customers. Substantially all
of the Company's accounts receivable are due from purchasers of oil and natural
gas. Oil and natural gas sales are generally unsecured. The Company has not
experienced significant credit losses in prior years and is not aware of any
significant uncollectible accounts at September 30, 1997.
OIL AND GAS PRODUCING ACTIVITIES
The Company follows the successful efforts method of accounting for oil and gas
producing activities. Intangible drilling and other costs of successful wells
and development dry holes are capitalized and amortized. The costs of
exploratory wells are initially capitalized, but charged against income if and
when the well is determined to be nonproductive. Oil and gas mineral and
leasehold costs are capitalized when incurred. Impairment of unproved
properties is generally assessed on a property-by-property basis.
DEPRECIATION, DEPLETION, AMORTIZATION AND IMPAIRMENT
Depreciation, depletion and amortization of the costs of producing oil and gas
properties are computed using the units of production method primarily on a
separate-property basis using proved reserves as estimated annually by an
independent petroleum engineer. Depreciation of furniture and fixtures is
computed using the straight-line method over estimated productive lives of five
to eight years.
(20)
<PAGE> 23
Panhandle Royalty Company
Notes to Consolidated Financial Statements (continued)
1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (CONTINUED)
The Company has significant royalty interests in wells for which the Company
does not share in the costs associated with the wells. Estimated costs of
future dismantlement, restoration and abandonment of wells in which the Company
owns a working interest are not expected to differ significantly from the
estimated salvage value of equipment from such wells and, accordingly, no
accrual of such costs is included in the accompanying consolidated financial
statements.
Nonproducing oil and gas properties include nonproducing minerals, which have a
net book value of $3,903,228 at September 30, 1997, consisting of perpetual
ownership of mineral interests in several states, including Oklahoma, Texas and
New Mexico. These costs are being amortized over a thirty-three year period
using the straight-line method. An ultimate determination of whether these
properties contain recoverable reserves in economical quantities can generally
be made within this time frame. Impairment of nonproducing oil and gas
properties is recognized based on experience and management judgment.
In the fourth quarter of 1996, the Company adopted the provisions of Financial
Accounting Standards (SFAS) No. 121, "Accounting for the Impairment of
Long-Lived Assets and for Long-Lived Assets to Be Disposed Of." SFAS No. 121
requires impairment losses to be recognized for long-lived assets when
indicators of impairment are present and the undiscounted cash flows are not
sufficient to recover the assets' carrying amount. The impairment loss is
measured by comparing the fair value of the asset to its carrying amount. Fair
values are based on discounted future cash flows or information provided by
sales and purchases of similar assets. The Company's oil and gas properties
were reviewed for indicators of impairment on a field-by-field basis, resulting
in the recognition of impairment provisions of $115,734 and $105,019,
respectively, for 1997 and 1996, which are included in depreciation, depletion,
amortization and impairment expense.
ENVIRONMENTAL COSTS
Environmental liabilities, which historically have not been material, are
recognized when it is probable that a loss has been incurred and the amount of
that loss is reasonably estimable. Environmental liabilities, when accrued, are
based upon estimates of expected future costs without discounting. At September
30, 1997, there are no such costs accrued. The Company's policy is in
compliance with Statement of Position 96-1, Environmental Remediation
Liabilities, issued by the Accounting Standards Executive Committee of the
American Institute of Certified Public Accountants and issuance of this
statement had no impact on the Company's financial position or results of
operations.
(21)
<PAGE> 24
Panhandle Royalty Company
Notes to Consolidated Financial Statements (continued)
1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (CONTINUED)
USE OF ESTIMATES
The preparation of financial statements in conformity with generally accepted
accounting principles requires management to make estimates and assumptions
that affect the amounts reported in the consolidated financial statements and
accompanying notes. Actual results could differ from those estimates.
PRODUCTION IMBALANCES
During the course of normal production operations, joint interest owners will,
from time to time, take more or less than their ownership share of natural gas
volumes from jointly-owned wells. These volumetric imbalances are monitored
over the life of the well to achieve balancing, or to minimize imbalances, by
the time reserves are depleted, with final cash settlements made under a
variety of arrangements at that time. The Company follows the sales method of
accounting for imbalances. A liability is recorded only if takes of natural gas
volumes from jointly-owned wells exceed the Company's interest in the well's
remaining estimated natural gas reserves. At September 30, 1997, the Company's
net liability for production imbalances of approximately 28,000 mcf of natural
gas was $44,380.
EARNINGS PER SHARE OF COMMON STOCK
Earnings per share are computed using the weighted average number of shares
outstanding during the year.
FAIR VALUES OF FINANCIAL INSTRUMENTS
The following information is provided regarding the estimated fair value of the
Company's financial instruments at September 30, 1997 and 1996:
Cash and cash equivalents, receivables, prepaid expenses, accounts
payable and accrued liabilities are each estimated to have a fair
value approximating the carrying amount due to the short maturity of
those instruments.
Long-term debt at September 30, 1996 had a variable interest rate with
a carrying value approximating fair value.
(22)
<PAGE> 25
Panhandle Royalty Company
Notes to Consolidated Financial Statements (continued)
1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (CONTINUED)
RECLASSIFICATIONS
Certain 1996 amounts have been reclassified to conform to the 1997
presentation.
2. INCOME TAXES
The Company's provision for income taxes is detailed as follows:
<TABLE>
<CAPTION>
1997 1996
--------------------------------
<S> <C> <C>
Current:
Federal $ 279,000 $ 206,000
State 45,000 62,000
--------------------------------
324,000 268,000
Deferred:
Federal 316,000 223,000
State 53,000 22,000
--------------------------------
369,000 245,000
--------------------------------
$ 693,000 $ 513,000
================================
</TABLE>
The difference between the provision for income taxes and the amount which
would result from the application of the federal statutory rate to income
before provision for income taxes is analyzed below:
<TABLE>
<CAPTION>
1997 1996
--------------------------------
<S> <C> <C>
Provision for income taxes at statutory rate $ 1,017,226 $ 861,498
Percentage depletion (316,586) (314,979)
Tight-sands gas credits (73,822) (90,412)
State income taxes, net of federal benefit 64,680 55,440
Other 1,502 1,453
--------------------------------
$ 693,000 $ 513,000
================================
</TABLE>
(23)
<PAGE> 26
Panhandle Royalty Company
Notes to Consolidated Financial Statements (continued)
2. INCOME TAXES (CONTINUED)
Deferred tax assets and liabilities, resulting from differences between the
financial statement carrying amounts and the tax bases of assets and
liabilities, consist of the following:
<TABLE>
<CAPTION>
1997 1996
---------------------------------
<S> <C> <C>
Deferred tax liabilities:
Capitalized costs and related depreciation, depletion,
amortization and impairment $ 1,351,000 $ 1,048,000
Cash basis of accounting for income taxes 280,000 250,000
---------------------------------
1,631,000 1,298,000
Deferred tax assets:
Alternative minimum tax credit carryforwards 104,000 140,000
=================================
Net deferred tax liabilities $ 1,527,000 $ 1,158,000
=================================
</TABLE>
3. LONG-TERM DEBT
The Company has a revolving line of credit agreement with a bank, which extends
through January 3, 2001, for borrowings, which bear interest at the bank's base
rate plus .2% (8.70% at September 30, 1997), of up to $2,500,000. Any
outstanding borrowings are unsecured but subject to a negative pledge on all of
the Company's oil and gas properties and are payable in full, with accrued and
unpaid interest, January 3, 2001. The Company is required to pay an annual fee
of .125% for the unused portion of the line of credit. There was no balance
outstanding at September 30, 1997 ($750,000 at September 30, 1996).
The agreement contains various restrictions which, among other things, require
the Company to maintain, at the end of each quarter, positive net income for
the preceding twelve-month period. Additionally, the Company is restricted from
incurring certain indebtedness, selling oil and gas properties for which the
proceeds received exceed $100,000, acquiring treasury stock in any one year in
excess of $150,000 and paying or declaring cash dividends exceeding fifty
percent of the cash flow from operations, as defined, of the preceding
twelve-month period.
(24)
<PAGE> 27
Panhandle Royalty Company
Notes to Consolidated Financial Statements (continued)
4. DIVIDENDS PAYABLE
Dividends payable represent accrued dividends which are due and payable, but
have not been paid for various reasons, including estate problems of deceased
stockholders, lost shareholders or questions of ownership of the underlying
shares.
5. EMPLOYEE STOCK OWNERSHIP PLAN
The Company has an employee stock ownership plan that covers substantially all
employees and is established to provide such employees with a retirement
benefit. These benefits become fully vested after three years of employment.
Contributions to the plan are at the discretion of the Board of Directors and
can be made in cash (none in 1997 or 1996) or the Company's common stock. For
contributions of common stock, the Company records as expense, the fair market
value of the stock at the time of contribution. The 27,249 shares of the
Company's common stock held by the plan are allocated to individual participant
accounts, are included in the weighted average shares outstanding for purposes
of earnings per share computations and receive dividends. Contributions to the
plan consisted of:
<TABLE>
<CAPTION>
YEAR SHARES AMOUNT
------------------------------------------------
<S> <C> <C>
1997 2,420 $72,101
1996 2,916 $61,236
</TABLE>
6. DEFERRED COMPENSATION PLAN FOR DIRECTORS
Effective November 1, 1994, the Company formed the Panhandle Royalty Company
Deferred Compensation Plan for Non-Employee Directors (the "Plan"). The Plan
provides that each eligible director can individually elect to receive shares
of Company stock rather than cash for board meeting fees and board committee
meeting fees. These shares are unissued and vest at the date of grant. The
shares are credited to each director's deferred fee account at the fair market
value of the stock at the date of grant. Upon retirement, termination or death
of the director, or upon change in control of the Company, the shares accrued
under the Plan will be either issued to the director or may be converted to
cash, at the director's discretion, for the fair market value of the shares on
the conversion date as defined by the Plan. As of September 30, 1997, 2,968
shares (1,848 shares at September 30, 1996) are included in the Plan. The
Company has accrued $86,455 at September 30, 1997 ($38,801 at September 30,
1996) in connection with the Plan which is included in accrued liabilities in
the accompanying consolidated balance sheet.
(25)
<PAGE> 28
Panhandle Royalty Company
Notes to Consolidated Financial Statements (continued)
7. INFORMATION ON OIL AND GAS PRODUCING ACTIVITIES
All oil and gas producing activities of the Company are conducted within the
United States (principally Oklahoma and New Mexico) and represent substantially
all of the business activities of the Company.
AGGREGATE CAPITALIZED COSTS
The aggregate amount of capitalized costs of oil and gas properties and related
accumulated depreciation, depletion and amortization is as follows:
<TABLE>
<CAPTION>
SEPTEMBER 30,
1997 1996
----------------------------------
<S> <C> <C>
Producing properties $ 20,063,953 $ 17,594,577
Nonproducing properties 5,068,467 5,112,785
----------------------------------
25,132,420 22,707,362
Accumulated depreciation, depletion and amortization (14,960,593) (13,538,170)
----------------------------------
Net capitalized costs $ 10,171,827 $ 9,169,192
==================================
</TABLE>
COSTS INCURRED
During the reporting period, the Company incurred the following costs in oil
and gas producing activities:
<TABLE>
<CAPTION>
1997 1996
-------------------------------
<S> <C> <C>
Property acquisition costs (principally nonproducing minerals) $ 224,224 $ 2,318,416
Exploration costs 967,456 590,095
Development costs 1,676,841 1,157,897
-------------------------------
$ 2,868,521 $ 4,066,408
===============================
</TABLE>
(26)
<PAGE> 29
Panhandle Royalty Company
Notes to Consolidated Financial Statements (continued)
8. SUPPLEMENTARY INFORMATION ON OIL AND GAS RESERVES (UNAUDITED)
The following unaudited information regarding the Company's oil and natural gas
reserves is presented pursuant to the disclosure requirements promulgated by
the Securities and Exchange Commission ("SEC") and SFAS No. 69, "Disclosures
About Oil and Gas Producing Activities."
Proved reserves are estimated quantities of crude oil and natural gas which
geological and engineering data demonstrate with reasonable certainty to be
recoverable in future years from known reservoirs under existing economic and
operating conditions. Proved developed reserves are those proved reserves that
can be expected to be recovered through existing wells with existing equipment
and operating methods. Because the Company's nonproducing mineral and leasehold
interests consist of various small interests in numerous tracts located
primarily in Oklahoma, New Mexico, Louisiana and Texas, it is not economically
feasible for the Company to provide estimates of all proved undeveloped
reserves. However, in 1995 the Company directed its independent petroleum
engineering firm to include proved undeveloped reserves in certain areas of
Western Oklahoma in the scope of properties which they evaluate for the Company
and, in 1996, the Company included certain proved undeveloped reserves in areas
of New Mexico within the scope of evaluated properties. Due to field production
allowable rules in the Dagger Draw field of New Mexico only those proved
undeveloped reserves which the Company felt could be drilled, under existing
allowable rules, have been included. Should the allowable rules be amended
and/or production volumes change significantly, additional proved undeveloped
reserves in the Dagger Draw field of New Mexico may be added in the future.
The Company's net proved (including certain undeveloped reserves described
above) oil and gas reserves as of September 30, 1997 and 1996 have been
estimated by Campbell & Associates, Inc., an independent petroleum engineering
firm. All studies have been prepared in accordance with regulations prescribed
by the Securities and Exchange Commission. The reserve estimates were based on
economic and operating conditions existing at September 30, 1997 and 1996.
Since the determination and valuation of proved reserves is a function of
testing and estimation, the reserves presented should be expected to change as
future information becomes available.
(27)
<PAGE> 30
Panhandle Royalty Company
Notes to Consolidated Financial Statements (continued)
8. SUPPLEMENTARY INFORMATION ON OIL AND GAS RESERVES (UNAUDITED) (CONTINUED)
ESTIMATED QUANTITIES OF PROVED OIL AND GAS RESERVES
The following table presents the Company's estimate of net proved (including
certain undeveloped reserves described above) oil and gas reserve quantities as
of September 30, 1997 and 1996, and the changes in reserves for the years then
ended:
<TABLE>
<CAPTION>
PROVED RESERVES
--------------------------------------
OIL GAS
(MBARRELS) (MMCF)
--------------------------------------
<S> <C> <C>
September 30, 1995 465 9,189
Revisions of previous estimates:
Initial inclusion of certain New Mexico proved undeveloped reserves 278 294
Other 66 118
Extensions and discoveries 275 1,789
Production (145) (1,551)
--------------------------------------
September 30, 1996 939 9,839
Revisions of previous estimates (1) (243) 956
Purchases of reserves in place 8 64
Extensions and discoveries 348 2,008
Production (148) (1,600)
--------------------------------------
September 30, 1997 904 11,267
======================================
</TABLE>
(1) Oil revisions are primarily related to those reserves which were
economically recoverable at the higher prices which existed at
September 30, 1996 which are not economically recoverable at prices
existing at September 30, 1997.
(28)
<PAGE> 31
Panhandle Royalty Company
Notes to Consolidated Financial Statements (continued)
8. SUPPLEMENTARY INFORMATION ON OIL AND GAS RESERVES (UNAUDITED) (CONTINUED)
<TABLE>
<CAPTION>
PROVED DEVELOPED RESERVES PROVED UNDEVELOPED RESERVES
----------------------------------- ---------------------------------------
OIL GAS OIL GAS
(MBARRELS) (MMCF) (MBARRELS) (MMCF)
-------------------------------------------------------------------------------
<S> <C> <C> <C> <C>
September 30, 1995 455 7,619 10 1,570
===============================================================================
September 30, 1996 641 8,201 298 1,638
===============================================================================
September 30, 1997 625 9,707 279 1,560
===============================================================================
</TABLE>
STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS
Estimates of future cash flows from proved oil and gas reserves, based on
current prices and costs, are shown in the following table. Estimated income
taxes are calculated by (i) applying the appropriate year-end tax rates to the
estimated future pretax net cash flows less depreciation of the tax basis of
properties and statutory depletion allowances and (ii) reducing the amount in
(i) for estimated tax credits to be realized in the future for gas produced
from "tight-sands."
<TABLE>
<CAPTION>
SEPTEMBER 30,
1997 1996
----------------------------------------
<S> <C> <C>
Future cash inflows $ 45,015,420 $ 40,244,270
Future production costs 7,481,181 5,628,840
Future development costs 1,159,709 1,085,240
----------------------------------------
Future net cash inflows before future income tax expenses 36,374,530 33,530,190
Future income tax expense 8,971,733 9,778,912
----------------------------------------
Future net cash flows 27,402,797 23,751,278
10% annual discount 8,660,434 7,463,967
----------------------------------------
Standardized measure of discounted future net cash flows $ 18,742,363 $ 16,287,311
========================================
</TABLE>
(29)
<PAGE> 32
Panhandle Royalty Company
Notes to Consolidated Financial Statements (continued)
8. SUPPLEMENTARY INFORMATION ON OIL AND GAS RESERVES (UNAUDITED) (CONTINUED)
Changes in the standardized measure of discounted future net cash flows are as
follows:
<TABLE>
<CAPTION>
1997 1996
----------------------------------------
<S> <C> <C>
Beginning of year $ 16,287,311 $ 8,685,589
Changes resulting from:
Sales of oil and gas, net of production costs (5,850,364) (4,952,229)
Net change in sales prices and production costs 387,598 5,938,650
Future development costs (49,806) 43,184
Extensions and discoveries 6,163,526 5,317,949
Revisions of quantity estimates:
Initial inclusion of New Mexico proved undeveloped
reserves in 1996
- 2,783,712
Other (780,082) 795,609
Purchases of minerals-in-place 157,667 -
Accretion of discount 2,315,552 1,188,289
Net change in income taxes 521,575 (3,670,908)
Other, net (410,614) 157,466
----------------------------------------
End of year $ 18,742,363 $ 16,287,311
========================================
</TABLE>
9. QUARTERLY RESULTS OF OPERATIONS (UNAUDITED)
The following is a summary of the Company's unaudited quarterly results of
operations:
<TABLE>
<CAPTION>
FISCAL 1997
-------------------------------------------------------------------------
QUARTER ENDED
-------------------------------------------------------------------------
DECEMBER 31 MARCH 31 JUNE 30 SEPTEMBER 30
-------------------------------------------------------------------------
<S> <C> <C> <C> <C>
Revenues $1,557,539 $2,511,315 $1,475,773 $1,471,851
Income before provision for
income taxes (A) 582,102 1,407,716 648,708 353,316
Net income (B) 476,102 1,082,716 513,708 226,316
Earnings per share $.70 $1.60 $.76 $.33
</TABLE>
(30)
<PAGE> 33
Panhandle Royalty Company
Notes to Consolidated Financial Statements (continued)
9. QUARTERLY RESULTS OF OPERATIONS (UNAUDITED) (CONTINUED)
<TABLE>
<CAPTION>
FISCAL 1996
-------------------------------------------------------------------------
QUARTER ENDED
-------------------------------------------------------------------------
DECEMBER 31 MARCH 31 JUNE 30 SEPTEMBER 30
-------------------------------------------------------------------------
<S> <C> <C> <C> <C>
Revenues $1,187,449 $1,533,007 $1,663,949 $1,631,763
Income before provision for
income taxes (A) 416,584 635,681 750,201 731,353
Net income (B) 352,084 505,681 530,201 632,853
Earnings per share $.52 $.74 $.78 $.94
</TABLE>
(A) Fourth quarter income before provision for income taxes includes
an SFAS 121 charge of $115,734 and $105,019 for 1997 and 1996,
respectively.
(B) Year-end adjustments to the Company's provision for income taxes
caused the effective rate for 1997 to be more than (less than in 1996)
that estimated during the previous three quarters. The effect of this
difference is reflected in the fourth quarter net income above.
(31)
<PAGE> 34
ITEM 8. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON
ACCOUNTING AND FINANCIAL DISCLOSURE
N O N E
PART III
ITEM 9. DIRECTORS, EXECUTIVE OFFICERS, PROMOTERS AND
CONTROL PERSONS; COMPLIANCE WITH SECTION 16(a)
OF THE EXCHANGE ACT
Listed below are the names, ages and positions, as of December
1, 1997, of the directors and executive officers of the Company. The Company's
bylaws provide for seven directors who are elected for staggered three-year
terms. Executive officers are appointed by the board of directors to serve in
their respective capacities until their successors are duly appointed by the
directors.
DIRECTORS
<TABLE>
<CAPTION>
A Served As
g Term Director
Name e Position & Offices Expires Since
- ----------------------- -- ------------------ ------- ---------
<S> <C> <C> <C>
Michael A. Cawley (b) 50 Director 1998 1991
Sam J. Cerny (a) 65 Director 2000 1993
E. Chris Kauffman (b)(c) 57 Director 2000 1991
H W Peace II (b) 62 Director, Chief 1999 1991
Executive Officer,
President
Ray H. Potts 65 Director 1998 1997
Robert A. Reece (a)(c) 53 Director 1999 1986
Jerry L. Smith (a) 57 Director, Chairman 1999 1987
of the Board
</TABLE>
(a) Member of Audit Committee
(b) Member of Compensation Committee
(c) Member of Retirement Committee
(32)
<PAGE> 35
EXECUTIVE OFFICERS
<TABLE>
<CAPTION>
Held Office
Name Age Position & Offices Since
- ------------------ --- -------------------- -----------
<S> <C> <C> <C>
Jerry L. Smith 57 Chairman of the 1997
Board, Director
H W Peace II 62 Director, Chief 1991
Executive Officer,
President
Michael C. Coffman 44 Vice President, 1990
Chief Financial Officer,
Secretary/Treasurer
Wanda C. Tucker 60 Vice President of 1990
Land
</TABLE>
BUSINESS EXPERIENCE
Michael A. Cawley is an attorney and is the president and chief
executive officer of the Samuel Roberts Noble Foundation, Inc. He has been
employed by the Noble Foundation for the last six years. Prior to joining the
Noble Foundation, he was engaged in the practice of law in Ardmore, Oklahoma
with the firm of Thompson & Cawley. He is also a director of Noble Drilling
Corporation and Noble Affiliates Inc.
Sam J. Cerny is a geological engineer and has been employed by Shell
Oil Company, Cleary Petroleum Corporation and its successor company, Grace
Petroleum Corporation, where he served as President/CEO from 1976 to 1991. He
is a past president of the Oklahoma Independent Petroleum Association and for
the last five years has been active as a petroleum management consultant.
E. Chris Kauffman is a vice-president of Campbell-Kauffman, Inc., an
independent insurance agency in Oklahoma City. He has been involved with the
agency since it was formed in 1981. In addition, he is the chief financial
officer and treasurer of The Insurance Center Agency, Inc. He is also a
director of First State Bank in Oklahoma City and a trustee of the Central
Oklahoma Transportation & Parking Authority.
Robert A. Reece is an attorney, and for the last five years has been
of counsel with the firm of Crowe & Dunlevy. He is also active in the
management of his family's investments.
H W Peace II holds bachelors and masters degrees in geology. For
thirty-three years he has been employed as a geologist, in management or as an
officer and/or director in the petroleum industry. He has been employed by
Union Oil Company of California, Cotton Petroleum and Hadson Petroleum
Corporation. He has been president of the Company since 1991.
(33)
<PAGE> 36
Ray H. Potts holds a master's degree in geology from the University of
Missouri. He was employed for six years as an exploration geologist for the
Pure Oil Company and in 1967 formed Potts-Stephenson Exploration Company, later
changed to PSEC, Inc. In 1997 PSEC, Inc. was sold to ONEOK Resources Company.
Mr. Potts is currently active in the oil and gas industry and has been involved
in several national and state trade associations, geological societies and
numerous civic activities.
Jerry L. Smith for the last seven years has been the owner of Smith
Capital Corporation in Dallas. This corporation is a private investment firm
focusing on commercial real estate and securities. Mr. Smith also serves as
Treasurer and as a Director of the Association of Graduates of the United
States Air Force Academy.
Michael C. Coffman is a certified public accountant. Since 1975, he
has worked in public accounting and as a financial officer of three publicly
owned companies involved in the oil and gas industry. He has been employed by
the Company for the last seven years.
Wanda C. Tucker has been a full-time employee of the Company since
1978, has served in various positions with the Company and is currently vice
president of land.
None of the organizations described in the business experiences of
company directors and officers are parents, subsidiaries or affiliates of
Panhandle Royalty Company.
ITEM 10. EXECUTIVE COMPENSATION
Summary Compensation Table
<TABLE>
<CAPTION>
Name and
Principal All Other
Position Year Salary Bonus Compensation
- ------------ ----- --------- -------- ----------------
<S> <C> <C> <C> <C>
H W Peace II 1997 $113,750 $25,600 $20,903 (1)
President & 1996 $108,750 $15,600 $18,653 (1)
Chief Exec. 1995 $103,750 $15,600 $17,880 (1)
Officer
</TABLE>
(1) Represents the value of 702 shares for 1997, 888 shares for 1996, and
1,052 shares for 1995 of Company stock contributed to the Panhandle
Employee Stock Ownership Plan (ESOP) on Mr. Peace's behalf. The ESOP
is a defined contribution plan, non-voluntary and non-contributory and
serves as the retirement plan for the Company's employees.
Contributions are at the discretion of the board of directors and, to
date, all contributions have been made in shares of Company stock.
Contributions are allocated to all participants in proportion to their
salaries for the plan year and 100% vesting occurs after three years'
of service.
(34)
<PAGE> 37
DIRECTORS FEES
Outside directors of the Company are paid $1,000 plus travel expenses
for attending each meeting of the board of directors and $200 for attending
each committee meeting of the board. Any director who travels in excess of 50
miles to attend a meeting receives an additional $100 for each meeting.
Outside directors can elect to be included in the Panhandle Royalty Company
Deferred Compensation Plan For Non-Employee Directors (the "Plan"). The Plan
provides that each eligible director can individually elect to receive shares
of Company stock rather than cash for board meeting fees and board committee
meeting fees. These unissued shares are credited to each director's deferred
fee account at the fair market value of the shares on the date of the meeting.
Upon retirement, termination or death of the director, or upon a change in
control of the Company, the shares accrued under the Plan will be either issued
to the director or may be converted to cash, at the directors' discretion, at
the fair market value of the shares on the conversion date, as defined. All
outside directors are participating in this Plan.
In addition to the above, Jerry Smith, chairman of the board of
directors, who is not an employee of the Company, is entitled to receive a $100
per hour fee for time spent, other than board or committee meetings, on Company
business. During fiscal 1997 and 1996, no payments were made to Mr. Smith, or
the prior chairman Dean Brown, under this arrangement.
ITEM 11. SECURITY OWNERSHIP OF CERTAIN
BENEFICIAL OWNERS AND MANAGEMENT
SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS
As of December 4, 1997, no person or "group" as that term is
used in Section 13(d)(3) of the Securities Exchange Act of 1934, was known to
Panhandle to be the beneficial owner of more than five percent of the
outstanding shares of Panhandle's class A common stock.
SECURITY OWNERSHIP OF MANAGEMENT
The following table sets forth, as of September 30, 1997, all
shares of class A common stock held beneficially, directly or indirectly by
each director and by all directors and officers as a group.
<TABLE>
<CAPTION>
Amount And Nature Of Percent Of
Name Beneficial Ownership Class
- --------------------- ------------------------- ----------
<S> <C> <C>
Michael A. Cawley (A) 100 shares, sole voting *
and investment powers
Sam J. Cerny (B) 100 shares, sole voting *
and investment powers
E. Chris Kauffman (C) 3,100 shares, shared voting *
and investment powers
</TABLE>
(35)
<PAGE> 38
<TABLE>
<S> <C> <C>
H W Peace II (D) 7,225 shares, shared voting 1.1%
and investment powers
Ray H. Potts (E) 160 shares, sole voting *
and investment powers
Robert A. Reece (F) 5,848 shares, sole voting *
and investment powers
Jerry L. Smith (G) 7,024 shares, sole voting 1.0%
and investment powers
All directors and 9,246 shares, shared 1.4%
officers as a voting and investment
group (9 persons) powers
25,090 shares, sole voting 3.7%
and investment powers
34,336 shares total 5.1%
</TABLE>
* less than 1.0%
(A) P.O. Box 2180, Ardmore, OK 73402
(B) 3330 Liberty Twr, 100 N. Broadway, Okla. City, OK 73102
(C) 701 N.W. 63rd Street - Suite #200, Okla. City, OK 73116
(D) 5400 N.W. Grand Blvd - Suite #210, Okla. City, OK 73112
(E) 100 N. Broadway - Suite #3200, Okla. City, OK 73102
(F) 6403 N. Grand Blvd. - Suite #204, Okla. City, OK 73116
(G) 5944 Luther Lane - Suite #401, Dallas, TX 75225
ITEM 12. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
N O N E
ITEM 13. EXHIBITS AND REPORTS ON FORM 8-K
( 3) Articles of Incorporation (Incorporated by reference to
Exhibit attached to Form 10 filed January 27, 1980, and to
Forms 8-K dated June 1, 1982 and December 3, 1982)
By-Laws as amended (Incorporated by reference to Form 8-K
dated October 31, 1994)
( 4) Instruments defining the rights of security holders
(Incorporated by reference to Articles of Incorporation and
By-Laws listed above)
(36)
<PAGE> 39
(10) Agreement indemnifying directors and officers (Incorporated by
reference to Form 10-K dated September 30, 1989)
(22) Subsidiaries of the Registrant
(27) Financial Data Schedule
REPORTS ON FORM 8-K
No reports on Form 8-K were filed during the quarter ended September
30, 1997.
(37)
<PAGE> 40
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the
Exchange Act, the registrant caused this report to be signed on its
behalf by the undersigned, thereunto duly authorized.
PANHANDLE ROYALTY COMPANY
By: /s/ H W Peace II
-----------------------
H W Peace II, Chief
Executive Officer,
President, Director
Date: December 16, 1997
------------------
In accordance with the Exchange Act, this report has been
signed below by the following persons on behalf of the registrant and in
the capacities and on the dates indicated.
/s/ Jerry L. Smith /s/ E. Chris Kauffman
- ----------------------------- -----------------------------
Jerry L. Smith, Chairman of Board E. Chris Kauffman, Director
Date December 16, 1997 Date December 16, 1997
------------------------ ------------------------
/s/ Robert A. Reece /s/ Ray H. Potts
- ----------------------------- -----------------------------
Robert A. Reece, Director Ray H. Potts, Director
Date December 16, 1997 Date December 16, 1997
------------------------ ------------------------
/s/ Sam J. Cerny /s/ Michael A. Cawley
- ----------------------------- -----------------------------
Sam J. Cerny, Director Michael A. Cawley, Director
Date December 16, 1997 Date December 16, 1997
------------------------ ------------------------
/s/ Michael C. Coffman
- -----------------------------------
Michael C. Coffman, Vice President
Treasurer and Secretary
(Principal Financial and Accounting
Officer)
Date December 16, 1997
------------------------------
(38)
<PAGE> 41
INDEX TO EXHIBITS
<TABLE>
EXHIBIT
NO. DESCRIPTION
------- -----------
<S> <C>
( 3) Articles of Incorporation (Incorporated by reference to
Exhibit attached to Form 10 filed January 27, 1980, and to
Forms 8-K dated June 1, 1982 and December 3, 1982)
By-Laws as amended (Incorporated by reference to Form 8-K
dated October 31, 1994)
( 4) Instruments defining the rights of security holders
(Incorporated by reference to Articles of Incorporation and
By-Laws listed above)
(10) Agreement indemnifying directors and officers (Incorporated by
reference to Form 10-K dated September 30, 1989)
(22) Subsidiaries of the Registrant
(27) Financial Data Schedule
</TABLE>
<PAGE> 1
EXHIBIT 22
SUBSIDIARIES OF PANHANDLE ROYALTY COMPANY
AT SEPTEMBER 30, 1997
The following table sets forth certain information with respect to
Panhandle's subsidiary:
Corporation
PHC, Inc.
PHC, Inc. was incorporated in Oklahoma and is included in Panhandle's
consolidated financial statements. PHC, Inc. is inactive, and has never done
any business.
<TABLE> <S> <C>
<ARTICLE> 5
<S> <C>
<PERIOD-TYPE> YEAR
<FISCAL-YEAR-END> SEP-30-1997
<PERIOD-START> OCT-01-1996
<PERIOD-END> SEP-30-1997
<CASH> 872,797
<SECURITIES> 0
<RECEIVABLES> 893,779
<ALLOWANCES> 0
<INVENTORY> 0
<CURRENT-ASSETS> 1,771,505
<PP&E> 25,345,894
<DEPRECIATION> 15,127,925
<TOTAL-ASSETS> 12,097,190
<CURRENT-LIABILITIES> 817,977
<BONDS> 0
0
0
<COMMON> 67,982
<OTHER-SE> 9,964,231
<TOTAL-LIABILITY-AND-EQUITY> 12,097,190
<SALES> 6,959,189
<TOTAL-REVENUES> 7,016,478
<CGS> 1,054,036
<TOTAL-COSTS> 3,994,676
<OTHER-EXPENSES> 0
<LOSS-PROVISION> 0
<INTEREST-EXPENSE> 29,960
<INCOME-PRETAX> 2,991,842
<INCOME-TAX> 693,000
<INCOME-CONTINUING> 2,298,842
<DISCONTINUED> 0
<EXTRAORDINARY> 0
<CHANGES> 0
<NET-INCOME> 2,298,842
<EPS-PRIMARY> 3.39
<EPS-DILUTED> 3.39
</TABLE>
