<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, 1996
Commission File Number: 0-9116
PANHANDLE ROYALTY COMPANY
(Exact name of small business registrant in its charter)
OKLAHOMA 73-1055775
(State or other jurisdiction of (I.R.S. Employer
incorporation or organization ) Identification No.)
Grand Centre Suite 210, 5400 NW Grand Blvd., Okla. City, OK 73112
(Address of principal executive offices) (zip code)
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 requirements 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, 1996, were $6,016,168.
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 4, 1996, was $22,199,457. As of December 4, 1996, 677,846 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 1997 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.W. 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 four 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 gas
wells completed in the last four years and has added significant gas 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 the
last four 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 and
actions taken by OPEC and other oil-producing countries have dramatic influence
on the price Panhandle receives for its oil and, to some extent, 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 AND ENVIRONMENTAL MATTERS
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 conserva-
(3)
<PAGE> 6
tion 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 limit the rate at which oil and gas can
be produced from certain of the Company's properties.
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.
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, 1996, Panhandle's principal properties
consisted of perpetual ownership of 173,108 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 4,117 net acres of minerals in Louisiana, Oklahoma and
Texas. At September 30, 1996, Panhandle held royalty and/or working interests
in 1,124 producing oil or gas wells, 21 successfully completed but not yet
producing wells, and 37 wells in the process of being drilled or completed.
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
(4)
<PAGE> 7
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, Kansas and Texas.
ACREAGE
The following table of mineral interests owned reflects, as of
September 30, 1996, 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).
<TABLE>
<CAPTION>
MINERAL INTERESTS
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> <C>
AL 5 479 5 479
AR 5,890 32,016 20 40 44 160 5,826 31,816
CO 8,156 37,960 8,156 37,960
OK 79,451 603,102 15,051 71,332 1,754 24,801 62,646 506,969
ID 30 880 30 880
IL 1,018 4,393 1,018 4,393
IN 27 262 27 262
KS 620 5,360 620 5,360
MT 422 7,960 422 7,960
NE 439 5,960 439 5,960
ND 292 5,036 37 320 255 4,716
NM 53,285 151,933 1,089 3,749 2,063 5,602 50,133 142,582
TN 1,544 3,087 1,544 3,087
TX 21,929 204,672 1,020 33,992 291 2,502 20,618 168,179
------- --------- ------ ------- ----- ------ ------- -------
TOT: 173,108 1,063,100 17,180 109,113 4,189 33,385 151,739 920,603
------- --------- ------ ------- ----- ------ ------- -------
</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 1997 1998 1999 Production
----- ------ ---- ---- ---- ----------
<S> <C> <C> <C> <C> <C>
LA 137 137
OK 2,885 666 349 218 1,652
TX 1,095 352 675 68
----- ----- ----- --- -----
TOT: 4,117 1,018 1,024 218 1,857
----- ----- ----- --- -----
</TABLE>
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
(5)
<PAGE> 8
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, 1992 183,968 7,068,028
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
Proved Undeveloped Reserves
---------------------------
September 30, 1995 10,339 1,570,440
September 30, 1996 297,582 1,638,104
Total Proved Reserves
---------------------
September 30, 1995 464,916 9,189,113
September 30, 1996 938,795 9,839,061
</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
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.
(6)
<PAGE> 9
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, 1996, 1995 and 1994 were as follows: 1996
- - $23.88, $1.84; 1995 - $17.23, $1.56; 1994 - $17.79, $1.55. 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>
9-30-96 9-30-95 9-30-94
----------- ----------- -----------
<S> <C> <C> <C>
Proved Developed $25,166,810 $16,055,355 $12,778,920
Proved Undeveloped $ 8,363,380 $ 1,442,460 NA
----------- ----------- -----------
Total Proved $33,530,190 $17,497,815 $12,778,920
</TABLE>
10% Discounted Present Value of Estimated Future Net Cash Flows
<TABLE>
<CAPTION>
9-30-96 9-30-95 9-30-94
----------- ----------- -----------
<S> <C> <C> <C>
Proved Developed $17,827,160 $11,126,168 $ 8,690,835
Proved Undeveloped $ 5,328,364 $ 799,923 $ NA
----------- ----------- -----------
Total Proved (1) $23,155,524 $11,926,091 $ 8,690,835
</TABLE>
(1) Approximately 53% of the increase from September 30, 1995 to September
30, 1996 is attributable to the increase in oil and gas sales prices at
September 30, 1996 compared to the sales prices at September 30, 1995.
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
9-30-96 9-30-95 9-30-94
--------- --------- ---------
<S> <C> <C> <C>
Bbls - Oil 145,301 82,676 77,720
MCF - Gas 1,551,147 1,203,623 1,339,545
</TABLE>
(7)
<PAGE> 10
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 9-30-96 9-30-95 9-30-94
------------------- --------- --------- ---------
<S> <C> <C> <C>
Per Bbl. Oil $ 19.93 $ 17.26 $ 16.13
Per MCF Gas $ 1.95 $ 1.39 $ 1.91
</TABLE>
<TABLE>
<CAPTION>
Average Production (Lifting Cost)
---------------------------------
Per Equivalent
<S> <C> <C> <C>
Bbl. Oil (1)(2) $ 2.46 $ 2.62 $ 2.46
</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, 1996. 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 263 10.930683
Gas 861 15.101761
----- ---------
TOTAL 1,124 26.032444
</TABLE>
Information on multiple completions is not available from
Panhandle's records, but the number of such is insignificant.
As of September 30, 1996, Panhandle owned 109,113 gross
developed mineral acres and 17,180 net developed mineral acres. Panhandle has
also leased from others 23,079 gross developed acres which contain 1,857 net
developed acres.
UNDEVELOPED ACREAGE
As of September 30, 1996, Panhandle owned 953,988 gross and
155,928 net undeveloped mineral acres, and leases on 28,572 gross and 2,260 net
acres.
(8)
<PAGE> 11
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, 1994 .948187 .267869
Fiscal year ending
September 30, 1995 1.184040 .524182
Fiscal year ending
September 30, 1996 1.6140027 .485562
- -----------------
Exploratory Wells
- -----------------
Fiscal year ending .103746 .300875
September 30, 1994
Fiscal year ending
September 30, 1995 .255000 .322656
Fiscal year ending
September 30, 1996 .456455 .231341
- ---------------
Purchased Wells
- ---------------
Fiscal year ending
September 30, 1994 .078540 0
Fiscal year ending
September 30, 1995 .389869 0
Fiscal year ending
September 30, 1996 1.542173 0
</TABLE>
PRESENT ACTIVITIES
The following table sets forth the gross and net oil and gas
wells drilling or testing as of September 30, 1996, in which Panhandle owns a
royalty or working interest.
<TABLE>
<CAPTION>
Gross Wells Net Wells
----------- ---------
<S> <C> <C>
Oil 8 .493600
Gas 29 1.192700
</TABLE>
(9)
<PAGE> 12
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, 1996.
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, 1994 16-3/4 15-1/2
March 31, 1995 16-1/2 15-1/4
June 30, 1995 17-1/2 15-1/2
September 30, 1995 18 16-1/2
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
</TABLE>
As of November 30, 1996, 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>
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 1994 $ .15
March 1995 $ .15
June 1995 $ .15
September 1995 $ .15
December 1995 $ .15
March 1996 $ .15
June 1996 $ .15
September 1996 $ .175
</TABLE>
(10)
<PAGE> 13
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 year end September 30, 1996 the Company had working capital
of $567,422, a decrease of $54,063 compared to year end September 30, 1995.
Cash flow from operating activities increased substantially from $1,535,334 for
fiscal 1995 to $3,820,373 for fiscal 1996. The increased cash flow was a
result of increased sales volumes and sales prices for both oil and natural gas
in fiscal 1996 as compared to fiscal 1995. These increases are discussed in
greater detail in "Results of Operations".
The Company spent $1,747,992 on exploratory and developmental
drilling and equipment costs in fiscal 1996 as compared to $1,323,950 in fiscal
1995. 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 those properties. In
addition, the Company continues to pursue outside generated drilling prospects
which present good potential economic returns. 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, as compared to $379,164 in
fiscal 1995. These acquisitions were predominately non-producing mineral
properties and did not provide substantial new cash flow. However, these
properties are expected to generate future drilling opportunities and will
eventually increase the Company's oil and gas reserve base and thereby increase
the Company's cash flow as the properties are developed or begin producing oil
and gas.
The majority of the purchased properties were acquired in
November 1995 when the Company purchased a 50% interest in 65,632 net mineral
acres located primarily in Oklahoma and Texas. The purchase price for these
properties was $2,071,557 net of post closing adjustments. Financing was
provided by accessing the Company's bank line of credit for $2,100,000. During
fiscal 1996 $1,350,000 of cash was utilized to reduce the outstanding amount of
the line of credit to $750,000 at September 30, 1996.
The Company expects to continue to increase its expenditures for
exploratory and developmental drilling through 1997 and for several additional
years. At September 30, 1996 the Company had commitments of $990,000 for
drilling and equipment costs for wells which had been proposed or were in the
process of being drilled or completed. The Company expects to commit a total
of approximately $2,200,000 for well costs in fiscal 1997. These commitments
and any additional drilling and development costs, overhead expenses, dividend
payments and debt service
(11)
<PAGE> 14
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 1997, it could access the available portion of the bank line
of credit.
The continuing positive results of the last five years drilling
operations have added significantly to the Company's reserve base and have
significantly contributed to the increased cash flow in fiscal 1996. These new
reserves should continue to provide increasing cash flow to the Company for the
next several years. However, should natural gas and or oil sales prices
decline dramatically from current levels, cash flow would be adversely
affected. Currently, management does not anticipate such declines and has
based 1997 capital expenditure levels on continuing strong cash flow levels.
As stated earlier, the line of credit is available should cash flow decline to
a level which would not support anticipated capital expenditures.
RESULTS OF OPERATIONS
Oil and gas revenues increased $2,843,730, or 92%, in fiscal
1996 as compared to fiscal 1995 oil and gas revenues. 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 1995 and 1996.
<TABLE>
<CAPTION>
PRODUCTION
---------------------------------------------------
OIL GAS
--------------------- --------------------------
Total Average Total Average
Bbls. Price/Bbl MCF Price/MCF
------ --------- --------- ---------
<S> <C> <C> <C> <C>
Year ended 9/30/96 145,301 $ 19.93 1,551,147 $1.95
Year ended 9/30/95 82,676 $ 17.26 1,203,623 $1.39
</TABLE>
The increased oil production is principally attributable to new
wells in the Dagger Draw field in southeast New Mexico, and to a lesser extent
increased production from wells in Louisiana and West Texas. The Dagger Draw
field continues to be developed and has added substantially to the Company's
oil production for the last three years. Additional drilling is expected in
the field for at least the next two to three 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 1995 and 1996 and production from new gas
wells coming on line in 1996. 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 1996,
when natural gas demand is usually low. In fiscal 1997 management currently
expects oil prices to remain relatively stable, to slightly up, compared to
fiscal 1996 average prices. Natural gas prices are expected to rise above the
current mid $2.00 range in the winter months of fiscal 1997 and thus should
average out somewhat higher than the 1996 average price of $1.95 per MCF.
(12)
<PAGE> 15
Fiscal 1997 oil production volumes are expected to be relatively
stable while gas production volumes are expected to increase slightly.
However, oil production could be adversely affected by production allowable
limitations on certain wells in the Dagger Draw field of New Mexico.
Management currently feels the reduced production due to the allowable limits
will be replaced by production from wells, in New Mexico, which will begin
production in fiscal 1997. 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 1997. However, this trend is not expected to be as dramatic as the
increase from fiscal 1995 to 1996.
Costs and expenses increased $983,939 or 39% in 1996 as compared
to 1995. Lease operating expenses, production taxes and seismic costs (LOE)
along with depreciation, depletion and amortization accounted for $249,949 and
$664,331, respectively, of the increase. LOE increased principally due to the
increased production taxes paid on increased oil and gas sales revenues in
1996. 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 revenue increases and/or
decreases.
Depreciation, depletion and amortization (DD&A) expenses were
$664,331 higher (94%) than in fiscal 1995. This increase is again principally
attributable to increased production levels as the Company computes DD&A on the
units of production method. In addition, the Company adopted SFAS No. 121 (see
Note 1., Summary of Significant Accounting Policies, to the Financial
Statements contained herein at Item 7.) and included the $105,019 impairment
provision calculated under SFAS 121 in DD&A during fiscal 1996.
Dry hole costs were $138,270 lower in fiscal 1996 than in 1995.
These costs will vary from year to year and are 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 dry hole costs are a result of
drilling unsuccessful exploratory wells. There is no way to accurately
estimate dry hole costs from year to year. The Company will continue
exploratory well participation, and thus future dry hole costs can be expected.
General and administrative costs increased 11.5% in fiscal 1996
to $875,923. The increase was the result of increased salary expenses,
increased legal expenses for several administrative matters, increased
engineering expenses for the Company's reserve report, and increased insurance
costs. General and administrative costs will continue to moderately increase
as the Company continues to increase its activity level.
(13)
<PAGE> 16
The $117,375 of interest expense was incurred on the $2,100,000
borrowed in November 1995 to purchase the Petrocorp minerals discussed in
"Liquidity and Capital Resources". Interest expense should be substantially
reduced in fiscal 1997 as the Company has paid down the outstanding balance of
the line of credit to $750,000 at September 30, 1996, and expects to have the
current borrowings paid off prior to fiscal year end 1997. However, the
Company could incur additional borrowings and related interest under the line
of credit should an additional acquisition be made.
The provision for income taxes increased in 1996 due to
substantially increased income before taxes in 1996. The provision for income
taxes was approximately 20% of income before taxes for both 1996 and 1995.
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. Current production levels and sales prices are expected to continue
into fiscal 1997. Management intends to continue the proactive approach
adopted five years ago which includes increased drilling costs in 1997. Larger
investments in drilling carry certain risks, principally dry hole 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 dry hole costs related to exploratory drilling
ventures, or a dramatic downturn in oil and or natural gas market prices.
ITEM 7. FINANCIAL STATEMENTS
<TABLE>
<CAPTION>
<S> <C>
Report of Independent Auditors ............................ 15
Consolidated Balance Sheets
As of September 30, 1996 and 1995 ................ 16
Consolidated Statements of Income For The
Years Ended September 30, 1996 and 1995 .......... 17
Consolidated Statements of Stockholders' Equity For
The Years Ended September 30, 1996 and 1995 ...... 18
Consolidated Statements of Cash Flows For
The Years Ended September 30, 1996 and 1995 ...... 19
Notes To Consolidated Financial Statements ................ 20
</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, 1996 and 1995, 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, 1996 and 1995, and the consolidated results of its
operations and its cash flows for the years then ended in conformity with
generally accepted accounting principles.
As discussed in Note 1 to the accompanying consolidated financial statements,
in fiscal year 1996, Panhandle Royalty Company changed its method of accounting
for impairment of long-lived assets by adopting Statement of Financial
Accounting Standards No. 121, "Accounting for the Impairment of Long-Lived
Assets and for Long-Lived Assets to Be Disposed Of."
/s/ ERNST & YOUNG LLP
ERNST & YOUNG LLP
Oklahoma City, Oklahoma
November 22, 1996
(15)
<PAGE> 18
Panhandle Royalty Company
Consolidated Balance Sheets
<TABLE>
<CAPTION>
SEPTEMBER 30,
1996 1995
--------------------------------------
<S> <C> <C>
ASSETS
Current assets:
Cash and cash equivalents $ 399,423 $ 443,862
Oil and gas sales and other receivables 817,258 529,274
Income tax refund receivable - 58,637
Prepaid expenses 4,520 2,221
--------------------------------------
Total current assets 1,221,201 1,033,994
Property and equipment, at cost, based on successful efforts
accounting (Notes 3 and 7):
Producing oil and gas properties 17,594,577 15,285,738
Nonproducing oil and gas properties 5,112,785 3,480,998
Furniture and fixtures 190,473 177,466
--------------------------------------
22,897,835 18,944,202
Less accumulated depreciation, depletion and amortization 13,700,007 12,328,527
--------------------------------------
Net properties and equipment 9,197,828 6,615,675
Other assets 107,716 107,716
--------------------------------------
$ 10,526,745 $ 7,757,385
======================================
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities:
Accounts payable and accrued liabilities (Note 6) $ 165,900 $ 103,041
Gas imbalance liability 44,380 44,380
Dividends payable (Note 4) 28,656 62,088
Income taxes payable (Note 2) 164,843 -
Deferred income taxes (Note 2) 250,000 203,000
--------------------------------------
Total current liabilities 653,779 412,509
Deferred income taxes (Note 2) 908,000 710,000
Long-term debt (Note 3) 750,000 -
Stockholders' equity (Notes 3, 5 and 6):
Class A voting common stock, $.10 par value;
1,000,000 shares authorized, 677,846 issued
and outstanding (679,642 in 1995) 67,785 67,964
Capital in excess of par value 383,790 400,334
Retained earnings 7,763,391 6,166,578
--------------------------------------
Total stockholders' equity 8,214,966 6,634,876
--------------------------------------
$ 10,526,745 $ 7,757,385
======================================
</TABLE>
See accompanying notes.
(16)
<PAGE> 19
Panhandle Royalty Company
Consolidated Statements of Income
<TABLE>
<CAPTION>
YEAR ENDED SEPTEMBER 30,
1996 1995
---------------------------
<S> <C> <C>
Revenues:
Oil and gas sales $5,944,018 $3,100,288
Lease bonuses and rentals 29,877 14,453
Interest 25,974 46,203
Other 16,299 57,495
---------------------------
6,016,168 3,218,439
Costs and expenses:
Lease operating expenses, production taxes and seismic costs 991,789 741,840
Dry hole costs 125,782 264,052
Depreciation, depletion and amortization (Note 1) 1,371,480 707,149
General and administrative 875,923 785,369
Interest expense 117,375 -
---------------------------
3,482,349 2,498,410
---------------------------
Income before provision for income taxes 2,533,819 720,029
Provision for income taxes (Note 2) 513,000 146,000
---------------------------
Net income $2,020,819 $ 574,029
===========================
Net income per common share $ 2.98 $ .85
===========================
Weighted average shares outstanding 677,586 676,914
===========================
</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
------------------------------------------------------------
<S> <C> <C> <C> <C>
Balances at September 30, 1994 678,136 $67,814 $370,904 $5,999,535
Purchase and cancellation of common
shares (1,988) (199) (29,594) -
Issuance of common shares to ESOP (Note
5) 3,494 349 59,024 -
Dividends declared ($.60 per
share) - - - (406,986)
Net income - - - 574,029
------------------------------------------------------------
Balances at September 30, 1995 679,642 67,964 400,334 6,166,578
Purchase and cancellation of common
shares (4,712) (471) (77,488) -
Issuance of common shares to ESOP (Note
5) 2,916 292 60,944 -
Dividends declared ($.625 per
share) - - - (424,006)
Net income - - - 2,020,819
------------------------------------------------------------
Balances at September 30, 1996 677,846 $67,785 $383,790 $7,763,391
============================================================
</TABLE>
See accompanying notes.
(18)
<PAGE> 21
Panhandle Royalty Company
Consolidated Statements of Cash Flows
<TABLE>
<CAPTION>
YEAR ENDED SEPTEMBER 30,
1996 1995
----------------------------
<S> <C>
CASH FLOWS FROM OPERATING ACTIVITIES
Net income $2,020,819 $ 574,029
Adjustments to reconcile net income to net cash provided by operating
activities:
Depreciation, depletion and amortization 1,371,480 707,149
Deferred income taxes 245,000 139,000
Dry hole costs 125,782 264,052
Common stock issued to Employee Stock Ownership Plan 61,236 59,373
Cash provided (used) by changes in assets and liabilities:
Oil and gas sales and other receivables (287,984) (106,268)
Income tax refund receivable 58,637 (58,637)
Prepaid expenses (2,299) 1,242
Accounts payable and accrued liabilities 62,859 (20,527)
Gas imbalance liability - 44,380
Income taxes payable 164,843 (68,449)
----------------------------
Total adjustments 1,799,554 961,315
----------------------------
Net cash provided by operating activities 3,820,373 1,535,344
CASH FLOWS FROM INVESTING ACTIVITIES OF PROPERTY AND EQUIPMENT
Purchases (4,079,415) (1,711,894)
Purchases of other assets - (45,553)
----------------------------
Net cash used in investing activities (4,079,415) (1,757,447)
CASH FLOWS FROM FINANCING ACTIVITIES
Borrowings under line of credit 2,100,000 -
Principal payments on line of credit (1,350,000) -
Purchase and cancellation of common shares (77,959) (29,793)
Payments of dividends (457,438) (403,910)
----------------------------
Net cash provided (used) in financing activities 214,603 (433,703)
----------------------------
Decrease in cash and cash equivalents (44,439) (655,806)
Cash and cash equivalents at beginning of year 443,862 1,099,668
----------------------------
Cash and cash equivalents at end of year $ 399,423 $ 443,862
============================
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
Interest paid $ 117,375 $ -
Income taxes paid 132,650 84,086
</TABLE>
See accompanying notes.
(19)
<PAGE> 22
Panhandle Royalty Company
Notes to Consolidated Financial Statements
September 30, 1996 and 1995
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 from the date of purchase by the Company are considered to be
cash equivalents. Cash equivalents at September 30, 1996 and 1995 include
certificates of deposit of $99,000 and $299,000, 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, 1996.
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.
(20)
<PAGE> 23
Panhandle Royalty Company
Notes to Consolidated Financial Statements (continued)
1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (CONTINUED)
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 a $105,019 impairment provision in the fourth quarter of
1996 which is included in depreciation, depletion and amortization expense.
DEPRECIATION, DEPLETION AND AMORTIZATION
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.
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 $4,070,610 at September 30, 1996, 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.
Depreciation of furniture and fixtures is computed using the straight-line
method over estimated productive lives of five to eight years.
(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, 1996, 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, 1996 and 1995:
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 has a variable interest rate with a
carrying value approximating fair value.
(22)
<PAGE> 25
Panhandle Royalty Company
Notes to Consolidated Financial Statements (continued)
2. INCOME TAXES
The Company's provision for income taxes is detailed as follows:
<TABLE>
<CAPTION>
1996 1995
-------------------
<S> <C> <C>
Current:
Federal $206,000 $ -
State 62,000 7,000
-------------------
268,000 7,000
Deferred:
Federal 223,000 126,000
State 22,000 13,000
-------------------
245,000 139,000
-------------------
$513,000 $146,000
===================
</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>
1996 1995
---------------------
<S> <C> <C>
Provision for income taxes at statutory rate $ 861,498 $244,810
Percentage depletion (314,979) (97,708)
Tight-sands gas credits (90,412) (68,854)
State income taxes, net of federal benefit 55,440 13,200
Reduction in alternative minimum tax credit carryforward - 54,000
Other 1,453 552
--------------------
$ 513,000 $146,000
====================
</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>
1996 1995
-----------------------
<S> <C> <C>
Deferred tax liabilities:
Capitalized costs and related depreciation, depletion
and amortization $1,048,000 $ 952,000
Cash basis of accounting for income taxes 250,000 203,000
-----------------------
1,298,000 1,155,000
Deferred tax assets:
Alternative minimum tax credit carryforwards 140,000 242,000
Valuation allowance - -
-----------------------
Net deferred tax liabilities $1,158,000 $ 913,000
=======================
</TABLE>
3. LONG-TERM DEBT
The Company has a revolving line of credit agreement with a bank, which extends
through January 3, 1998, for borrowings, which bear interest at the bank's base
rate plus .2% (8.45% at September 30, 1996), of up to $2,500,000. The
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, 1998. The Company is required to pay an annual fee
of .125% for the unused portion of the line of credit. The outstanding balance
at September 30, 1996 was $750,000 (none at September 30, 1995).
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 1996 or 1995) 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 21,288 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>
1996 2,916 $61,236
1995 3,494 59,373
</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, 1996, 1,848
shares (760 shares at September 30, 1995) are included in the Plan. The Company
has accrued $38,801 at September 30, 1996 ($11,900 at September 30, 1995) 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,
1996 1995
--------------------------
<S> <C> <C>
Producing properties $ 17,594,577 $ 15,285,738
Nonproducing properties 5,112,785 3,480,998
--------------------------
22,707,362 18,766,736
Accumulated depreciation, depletion
and amortization (13,538,170) (12,175,056)
--------------------------
Net capitalized costs $ 9,169,192 $ 6,591,680
==========================
</TABLE>
COSTS INCURRED
During the reporting period, the Company incurred the following costs in oil
and gas producing activities:
<TABLE>
SEPTEMBER 30,
1996 1995
------------------------
<S> <C> <C>
Property acquisition costs
(principally nonproducing minerals) $ 2,318,416 $ 379,164
Exploration costs 590,095 798,259
Development costs 1,157,897 525,691
------------------------
$ 4,066,408 $1,703,114
========================
</TABLE>
(26)
<PAGE> 29
Panhandle Royalty Company
Notes to Consolidated Financial Statements (continued)
7. INFORMATION ON OIL AND GAS PRODUCING ACTIVITIES (CONTINUED)
In November 1995, the Company closed the acquisition of a fifty percent
interest in 65,632 net mineral acres (primarily located in Oklahoma) from
Petrocorp, Inc. for a total acquisition price of $2.1 million. The Company
allocated $1.4 million of the purchase price to nonproducing minerals with the
remainder being attributed to producing minerals and working interests
acquired.
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 has not been
economically feasible for the Company to provide estimates of all proved
undeveloped reserves. Beginning 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. Beginning 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.
(27)
<PAGE> 30
Panhandle Royalty Company
Notes to Consolidated Financial Statements (continued)
8. SUPPLEMENTARY INFORMATION ON OIL AND GAS RESERVES (UNAUDITED) (CONTINUED)
The Company's net proved (including undeveloped reserves in New Mexico in 1996
and Western Oklahoma in 1995) oil and gas reserves as of September 30, 1996 and
1995 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, 1996 and 1995. 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.
ESTIMATED QUANTITIES OF PROVED OIL AND GAS RESERVES
The following table presents the Company's estimate of net proved (including
undeveloped reserves in New Mexico in 1996 and Western Oklahoma in 1995) oil
and gas reserve quantities as of September 30, 1996 and 1995, and the changes
in reserves for the years then ended:
<TABLE>
PROVED RESERVES OIL (BARRELS) GAS (MMCF)
- ------------------------------------------------------------------------------
<S> <C> <C>
September 30, 1994 251,246 7,442
Revisions of previous estimates:
Initial inclusion of Western Oklahoma
proved undeveloped reserves 10,339 1,570
Other 54,127 (178)
Extensions and discoveries 231,880 1,558
Production (82,676) (1,203)
-----------------------
September 30, 1995 464,916 9,189
Revisions of previous estimates:
Initial inclusion of certain New Mexico
proved undeveloped reserves 277,642 294
Other 66,172 118
Extensions and discoveries 275,366 1,789
Production (145,301) (1,551)
-----------------------
September 30, 1996 938,795 9,839
=======================
</TABLE>
(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 OIL (BARRELS) GAS (MMCF)
- ------------------------------------------------------------------------------
<S> <C> <C>
September 30, 1994 251,246 7,442
========================
September 30, 1995 454,577 7,619
========================
September 30, 1996 641,213 8,201
========================
</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>
SEPTEMBER 30,
1996 1995
---------------------------
<S> <C> <C>
Future cash inflows $40,244,270 $22,316,615
Future production costs 5,628,840 4,030,951
Future development costs 1,085,240 787,849
---------------------------
Future net cash inflows before future income tax expenses 33,530,190 17,497,815
Future income tax expense 9,778,912 4,667,898
---------------------------
Future net cash flows 23,751,278 12,829,917
10% annual discount 7,463,967 4,144,328
---------------------------
Standardized measure of discounted future net cash flows $16,287,311 $ 8,685,589
===========================
</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>
1996 1995
-------------------------------
<S> <C> <C>
Beginning of year $ 8,685,589 $ 6,467,751
Changes resulting from:
Sales of oil and gas, net of production costs (4,952,229) (2,358,448)
Net change in sales prices and production costs 5,938,650 486,028
Future development costs 43,184 (3,453)
Extensions and discoveries 5,317,949 3,052,621
Revisions of quantity estimates:
Initial inclusion of New Mexico proved undeveloped
reserves in 1996 and Western Oklahoma proved
undeveloped reserves in 1995 2,783,712 996,260
Other 795,609 154,356
Accretion of discount 1,188,289 869,094
Net change in income taxes (3,670,908) (974,217)
Other, net 157,466 (4,403)
-------------------------------
End of year $ 16,287,311 $ 8,685,589
===============================
</TABLE>
(30)
<PAGE> 33
Panhandle Royalty Company
Notes to Consolidated Financial Statements (continued)
9. QUARTERLY RESULTS OF OPERATIONS (UNAUDITED)
The following is a summary of the Company's unaudited quarterly results of
operations:
<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>
<TABLE>
FISCAL 1995
-------------------------------------------------
QUARTER ENDED
-------------------------------------------------
DECEMBER 31 MARCH 31 JUNE 30 SEPTEMBER 30
-------------------------------------------------
<S> <C> <C> <C> <C>
Revenues $ 699,214 $ 705,681 $ 843,751 $ 969,793
Income before provision for
income taxes 116,442 16,203 281,833 305,551
Net income (B) 116,442 16,203 281,833 159,551
Earnings per share $ .17 $ .02 $ .42 $ .24
</TABLE>
(A) Fourth quarter income before provision for income taxes in 1996 includes
a $105,019 charge related to the initial adoption of Financial Accounting
Standards No. 121.
(B) Year-end adjustments to the Company's provision for income taxes caused
the effective rate for 1996 to be less than (more than in 1995) 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, 1996, 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> <C>
Dean Brown (c) 69 Director, Chairman 1998 1983
of the Board
Michael A. Cawley (b) 49 Director 1998 1991
E. Chris Kauffman (b)(c) 56 Director 1997 1991
Sam J. Cerny (a) 64 Director 1997 1993
H W Peace II (b) 61 Director, Chief 1999 1991
Executive Officer,
President
Robert A. Reece (a)(c) 52 Director 1999 1986
Jerry L. Smith (a) 56 Director 1999 1987
(a) Member of Audit Committee
(b) Member of Compensation Committee
(c) Member of Retirement Committee
</TABLE>
(32)
<PAGE> 35
EXECUTIVE OFFICERS
<TABLE>
<CAPTION>
Held Office
Name Age Position & Offices Since
- ------------------ --- ------------------- -----------
<S> <C> <C> <C>
Dean Brown 69 Chairman of the 1991
Board, Director
H W Peace II 61 Director, Chief 1991
Executive Officer,
President
Michael C. Coffman 43 Vice President, 1990
Secretary/Treasurer
Wanda C. Tucker 59 Vice President of 1990
Land
</TABLE>
BUSINESS EXPERIENCE
Dean Brown is an attorney and certified public accountant. He
has been engaged in the practice of law since 1957, and is a member of the law
firm of Green, Brown and Stark, in Oklahoma City.
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 five 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. He is also an advisory director
of Memorial Bank of Oklahoma City and 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-two 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
Jerry L. Smith for the last six 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 six 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> <C>
H W Peace II 1996 $108,750 $15,600 $18,653 (1)
President & 1995 $103,750 $15,600 $17,880 (1)
Chief Exec. 1994 $ 98,750 $15,500 $17,146 (1)
Officer
</TABLE>
(1) Represents the value of 888 shares for 1996, 1,052
shares for 1995 and 1,079 shares for 1994 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 $750 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.
In addition to the above, Dean Brown, 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 1996 and 1995, no payments were made to Mr. Brown
under this arrangement.
ITEM 11. SECURITY OWNERSHIP OF CERTAIN
BENEFICIAL OWNERS AND MANAGEMENT
SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS
As of December 4, 1996, 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, 1996, 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>
Dean Brown (A) 1,250 shares, sole voting *
and investment powers
Michael A. Cawley (B) 100 shares, sole voting *
and investment powers
Sam J. Cerny (C) 100 shares, sole voting *
and investment powers
</TABLE>
(35)
<PAGE> 38
<TABLE>
<S> <C>
E. Chris Kauffman (D) 3,100 shares, shared voting *
and investment powers
H W Peace II (E) 6,523 shares, shared 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 8,544 shares, shared 1.3%
officers as a voting and investment
group (9 persons) powers
24,325 shares, sole voting 3.6%
and investment powers
32,869 shares total 4.8%
* less than 1.0%
</TABLE>
(A) 5550 N. Francis, Oklahoma City, OK 73118
(B) P.O. Box 2180, Ardmore, OK 73402
(C) 3330 Liberty Twr, 100 N. Broadway, Okla. City, OK 73102
(D) 701 N.W. 63rd Street - Suite #200, Okla. City, OK 73116
(E) 5400 N.W. Grand Blvd - Suite #210, Okla. City, OK 73112
(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, 1996.
(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 17, 1996
-------------------
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.
<TABLE>
<S> <C>
/s/ Dean Brown /s/ E. Chris Kauffman
- ----------------------------- -----------------------------
Dean Brown, Chairman of Board E. Chris Kauffman, Director
Date December 17, 1996 Date December 17, 1996
------------------------ ------------------------
/s/ Robert A. Reece /s/ Jerry L. Smith
- ----------------------------- -----------------------------
Robert A. Reece, Director Jerry L. Smith, Director
Date December 17, 1996 Date December 17, 1996
------------------------ ------------------------
/s/ Sam J. Cerny /s/ Michael A. Cawley
- ----------------------------- -----------------------------
Sam J. Cerny, Director Michael A. Cawley, Director
Date December 17, 1996 Date December 17, 1996
------------------------ ------------------------
/s/ Michael C. Coffman
- -----------------------------------
Michael C. Coffman, Vice President
Treasurer and Secretary
(Principal Financial and Accounting
Officer)
Date December 17, 1996
------------------------------
</TABLE>
(38)
<PAGE> 41
Exhibit Index
Description
-----------
Exhibit No.
-----------
( 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
<PAGE> 1
EXHIBIT 22
SUBSIDIARIES OF PANHANDLE ROYALTY COMPANY
AT SEPTEMBER 30, 1996
The following table sets forth certain information with respect to
Panhandle's subisdiary:
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-30-1996
<PERIOD-START> OCT-1-1996
<PERIOD-END> SEP-30-1996
<CASH> 399,423
<SECURITIES> 0
<RECEIVABLES> 817,258
<ALLOWANCES> 0
<INVENTORY> 0
<CURRENT-ASSETS> 1,221,201
<PP&E> 22,897,835
<DEPRECIATION> 13,700,007
<TOTAL-ASSETS> 10,526,745
<CURRENT-LIABILITIES> 653,779
<BONDS> 0
0
0
<COMMON> 67,785
<OTHER-SE> 8,147,181
<TOTAL-LIABILITY-AND-EQUITY> 10,526,745
<SALES> 5,944,018
<TOTAL-REVENUES> 6,016,168
<CGS> 991,789
<TOTAL-COSTS> 2,373,185
<OTHER-EXPENSES> 0
<LOSS-PROVISION> 0
<INTEREST-EXPENSE> 117,375
<INCOME-PRETAX> 2,533,819
<INCOME-TAX> 513,000
<INCOME-CONTINUING> 2,020,819
<DISCONTINUED> 0
<EXTRAORDINARY> 0
<CHANGES> 0
<NET-INCOME> 2,020,819
<EPS-PRIMARY> 2.98
<EPS-DILUTED> 2.98
</TABLE>
