<PAGE> 1
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-K
(Mark One)
X ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT
- -- OF 1934 for the fiscal year ended August 31, 1995
OR
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
- -- EXCHANGE ACT OF 1934 for the transition period from _______ to _______
Commission file number 1-2572
ONEOK INC.
(Exact name of registrant as specified in its charter)
DELAWARE 73-0383100
(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification No.)
100 WEST FIFTH STREET, TULSA, OK 74103
(Address of principal executive offices) (Zip Code)
Registrant's telephone number, including area code (918) 588-7000
Securities registered pursuant to Section 12(b) of the Act:
TITLE OF EACH CLASS NAME OF EACH EXCHANGE ON WHICH REGISTERED
- ------------------- -----------------------------------------
Common stock, without par value New York Stock Exchange
Securities registered pursuant to Section 12(g) of the Act:
TITLE OF EACH CLASS
- -------------------
Preferred stock, $50 par value, Series A, 4 3/4% cumulative
Indicate by check mark whether the registrant (1) has filed all reports
required to be filed by Section 13 or 15(d) of the Securities Exchange Act of
1934 during the preceding 12 months (or for such shorter period that the
registrant was required to file such reports) and (2) has been subject to such
filing requirements for the past 90 days. Yes X No
---- ----
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405
of Regulation S-K is not contained herein, and will not be contained, to the
best of registrant's knowledge, in definitive proxy or information statements
incorporated by reference in Part III of this Form 10-K or any amendment to
this Form 10-K. _____
Aggregate market value of registrant's voting stock held by nonaffiliates as of
September 29, 1995, was: Common stock $615.7 million; Preferred stock $5.1
million.
On October 1, 1995, the Company had 27,020,004 shares of common stock
outstanding.
DOCUMENTS INCORPORATED BY REFERENCE:
DOCUMENTS PART OF FORM 10-K
Definitive Proxy Statement dated December 11, 1995. Part III
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ONEOK INC.
1995 ANNUAL REPORT ON FORM 10-K
<TABLE>
<CAPTION>
PART I PAGE NO.
<S> <C> <C>
Item 1. Business 3 - 13
Item 2. Properties 13 - 16
Item 3. Legal Proceedings 17 - 18
Item 4. Results of Votes of Security Holders 18 - 19
PART II
Item 5. Market Price and Dividends on the Registrant's
Common Stock and Related Shareholder Matters 20
Item 6. Selected Financial Data 21
Item 7. Management's Discussion and Analysis of Financial
Condition and Results of Operations 22 - 29
Item 8. Financial Statements and Supplementary Data 29 - 47
Item 9. Changes in and Disagreements with Accountants
on Accounting and Financial Disclosure 48
PART III
Item 10. Directors, Executive Officers, Promoters, and
Control Persons of the Registrant 48
Item 11. Executive Compensation 48
Item 12. Security Ownership of Certain Beneficial Owners and Management 48
Item 13. Certain Relationships and Related Transactions 48
PART IV
Item 14. Exhibits, Financial Statement Schedules, and Reports on Form 8-K. 49 - 64
</TABLE>
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PART I.
ITEM 1. BUSINESS
ONEOK Inc. and its divisions and subsidiaries, hereinafter referred to as the
Company, engage in natural gas distribution, transmission, gathering, and
storage operations; oil and gas energy operations; and certain other operations
as described below. The operations of its principal division and subsidiaries
are as follows:
Oklahoma Natural Gas Company purchases, distributes, and sells natural gas and
leases pipeline capacity. Oklahoma Natural and ONG Sayre Storage Company own
and operate gas storage facilities.
ONG Transmission Company and ONG Gas Gathering Company compress and transport
natural gas within Oklahoma and transport gas in interstate commerce. Through a
subsidiary, TransTex Pipeline Company, the Company owns an interest in a
partnership that operates a natural gas transmission system. OkTex Pipeline
Company transports gas in interstate commerce.
ONEOK Exploration Company and ONEOK Resources Company primarily explore for and
produce natural gas and oil.
ONEOK Products Company extracts and sells natural gas liquids and buys and
sells natural gas.
ONEOK Gas Marketing Company markets natural gas.
ONEOK Leasing Company and ONEOK Parking Company operate the headquarters office
building and a parking garage.
The business was founded on October 12, 1906.
Following are ONEOK Inc.'s wholly owned subsidiaries and corporate division:
<TABLE>
<CAPTION>
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YEAR OF
STATE OF ESTABLISHMENT OR
INCORPORATION INCORPORATION
- ------------------------------------------------------------------------------------------------------------
<S> <C> <C>
DISTRIBUTION AND TRANSMISSION
Oklahoma Natural Gas Company (Division) -- 1980
ONEOK Technology Company Delaware 1992
The Tri-Fuels Company Delaware 1995
ONG Transmission Company Delaware 1968
ONG Sayre Storage Company Delaware 1964
TransTex Pipeline Company Delaware 1981
OkTex Pipeline Company Delaware 1990
ONG Gas Gathering Company Delaware 1995
EXPLORATION AND PRODUCTION
ONEOK Resources Company Delaware 1970
ONEOK Exploration Company Delaware 1972
GAS PROCESSING
ONEOK Products Company Delaware 1983
OTHER
Fifth Street Investment Corporation Oklahoma 1995
ONEOK Gas Marketing Company Delaware 1992
ONEOK Leasing Company Delaware 1983
ONEOK Parking Company Delaware 1983
- ------------------------------------------------------------------------------------------------------------
</TABLE>
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(A) GENERAL DEVELOPMENT OF BUSINESS
(1) DISTRIBUTION AND TRANSMISSION
The Company's activities include those in its historic merchant role,
purchasing and selling natural gas, and those in its newer role,
transporting natural gas and leasing pipeline capacity.
Gathering activities were transferred to a new subsidiary, ONG Gas
Gathering Company, in 1995, and transmission activities were
consolidated into a new subsidiary, ONG Transmission Company.
A substantial portion of the gas delivered through the Company's
pipeline system goes to industrial customers, in particular, several
large fertilizer plants which use the gas as feed stock. Most industrial
customers purchase gas in the spot market. The Company's pipeline
capacity lease (PCL) program allows the transportation of the gas
purchased by the customers to their facilities. In order to meet
competitive pressures, the Company provided PCL service at discounted
rates substantially below the Company's mark-up on its industrial tariff
rates. The Company also has a Special Industrial Sales Program (SISP)
which allocates lower cost supplies to these customers.
Through the SISP, PCL, and payment-in-kind (PIK) programs, the Company
continued to remain competitive for industrial load. Under the PIK
program, the Company accepts gas in lieu of cash for PCL payments and
for payment for exchanges of gas between intrastate pipelines. Prior to
a June 1995 rate order, some of the PCL contracts included price caps,
which reduced the volume of gas delivered to the Company as the price of
gas purchased by the customer escalated.
In 1995, in recognition of the highly competitive conditions in
industrial gas marketing, the Oklahoma Corporation Commission (OCC)
allowed rates for large industrial customers to be restructured and
reduced. In addition, the price of PIK gas was reduced to the cost of
SISP gas. Revenue losses associated with these reductions were shifted
to the general system core customers (residential and commercial). The
OCC also allowed a limited (up to ten percent) recovery of any revenue
lost as a result of renegotiating contracts with industrial customers.
The primary effect of these changes was to allow the Company to remain
competitive for industrial customers while stabilizing the Company's
revenues.
In the past, certain interstate and intrastate pipeline companies have
been very aggressive in attempting to capture industrial load within the
Company's service area, a phenomenon generally referred to as "bypass"
in the gas industry. The Company has protected its load through its PCL
and other special sales programs and, now, through competitive rates
established by the June 1995 rate restructuring.
The Company's transmission system serves much of the State of Oklahoma,
including all of the major gas producing areas. The system, which
intersects with ten interstate pipelines, allows natural gas to be moved
to locations throughout the nation. In 1991, the Company purchased Lone
Star Gas Company's Oklahoma properties which provide access to the Texas
market through the Lone Star intrastate system in Texas. In 1993, the
Company acquired two pipelines in western Oklahoma. One provides access
to a pipeline owned by Northern Natural Gas Company. The other provides
access to Red River Pipeline in Texas.
In April 1992, the Federal Energy Regulatory Commission (FERC) approved
Order 636. The Company has complied with the Order for its FERC
regulated properties It is difficult to assess what long-term impact, if
any, the Order will have on the Company.
The Company is interested in acquiring gas distribution and transmission
facilities which will enhance its operations. The Lone Star Gas Company
acquisition in 1991 added 36,000 customers, 700 miles of distribution
line, and 1,000 miles of transportation pipeline. The Company continues
to pursue other opportunities for acquisitions as they occur.
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In the past, the Company experienced claims and potential liabilities
arising out of long-term gas supply contracts containing "take-or-pay"
provisions which purported to require the Company to pay for volumes of
natural gas contracted for but not taken. There are no significant
potential claims or cases pending against the Company under remaining
gas purchase contracts. The Company currently has approximately $106.1
million of deferred take-or-pay and other settlement costs, of which the
OCC has authorized an annual recovery of $6.7 million by a combination
of a surcharge from customers and revenue from transportation under
Section 311 (a) of the NGPA and other intrastate transportation
revenues.
On June 19, 1995, the OCC approved a settlement of all issues in the
Company's rate proceeding. Under the settlement, the Company received a
$13.8 million permanent increase in base rates and an additional $1.15
million increase for two years. Rates for large industrial customers
were restructured and reduced with the revenue reduction shifted to the
general system customers (residential and commercial). The Company
anticipates a net annual reduction of $6.7 million for general system
customers resulting from changes in purchasing and pricing practices.
The order also included a temperature adjustment clause, agreement by
the Company not to file for a general rate increase for two years, and
amortization of the Company's additional deferred pension costs, not
covered by prior orders.
Gas volumes sold or transported are as follows:
<TABLE>
<CAPTION>
- --------------------------------------------------------------------------------------------------------------
VOLUMES (MMCF) 1995 1994 1993 1992 1991
- --------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C> <C>
Sales:
Residential 52,804 58,587 60,459 51,557 49,937
Commercial 25,289 27,343 27,989 24,350 25,462
Industrial
Fertilizer plants 15,763 27,078 34,350 17,487 57,380
Other 21,624 21,907 20,855 21,707 30,859
- --------------------------------------------------------------------------------------------------------------
Total industrial 37,387 48,985 55,205 39,194 88,239
Wholesale 1,196 1,797 2,253 2,830 2,836
- --------------------------------------------------------------------------------------------------------------
Total intrastate sales 116,676 136,712 145,906 117,931 166,474
- --------------------------------------------------------------------------------------------------------------
Pipeline Capacity Leases:
Fertilizer plants 80,232 66,284 55,252 75,925 34,346
Other 53,898 54,335 53,732 49,680 37,208
- --------------------------------------------------------------------------------------------------------------
Total PCL volumes 134,130 120,619 108,984 125,605 71,554
- --------------------------------------------------------------------------------------------------------------
Transportation:
Sec. 311(a) interstate 50,135 56,779 54,515 42,061 46,081
Other 2,914 3,029 3,349 3,201 -
- --------------------------------------------------------------------------------------------------------------
Total transportation 53,049 59,808 57,864 45,262 46,081
- --------------------------------------------------------------------------------------------------------------
Total PCL and transportation 187,179 180,427 166,848 170,867 117,635
- --------------------------------------------------------------------------------------------------------------
Total volumes 303,855 317,139 312,754 288,798 284,109
==============================================================================================================
</TABLE>
Through a subsidiary, the Company is a 25 percent partner in a natural
gas transmission system, Red River Pipeline (Red River). Red River
operates in Texas and is regulated by the Texas Railroad Commission. It
is the Company's intent to withdraw from the partnership during the next
year. The Company sold its 25 percent partnership in the Ozark Gas
Transmission System for its net book value of approximately $11 million.
OkTex Pipeline Company owns short transmission pipelines between
Oklahoma and Texas which connect the Company's intrastate systems to the
intrastate systems of Lone Star Gas Company, a division of ENSERCH
Corporation, and Red River.
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ONEOK Technology Company is a partner in a company which has developed a
device that allows quick meter change- out without interruption of
service to customers. The partnership contracts out fabrication of the
devices which are sold through an exclusive representative in the United
States. The same party manufactures and markets the devices in Europe
under license from the partnership.
The Company's long-standing commitment to the development of natural gas
vehicles (NGV) has helped Oklahoma become the leading state in the
nation regarding the number of NGV vehicles. The Company expects NGV
vehicles to be a growing future market for natural gas in Oklahoma.
During 1995, ONEOK acquired the remaining interest in the Tri-Fuels
Company, which operates a manufacturing plant to supply conversion kits
and fueling stations for natural gas vehicles. It is currently being
reorganized for eventual sale.
(2) EXPLORATION AND PRODUCTION
The Company explores for and produces oil and natural gas, and, from
time to time, engages in certain transactions to hedge crude oil and
natural gas prices. At times, the Company curtails production due to
depressed prices for natural gas.
The Company is currently evaluating its exploration and production
properties to determine its future direction for this segment.
Crude oil and natural gas production sales and natural gas liquids sales
are as follows:
<TABLE>
<CAPTION>
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SALES 1995 1994 1993 1992 1991
- ------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C> <C>
Oil (Bbls) 466,105 515,195 442,931 375,506 294,025
Oil (000) $7,563 $7,628 $8,192 $7,535 $7,081
Average Price (per Bbl) $16.23 $14.81 $18.50 $20.07 $24.08
Gas (MMcf) 8,775 8,043 8,401 7,349 6,952
Gas (000) $13,236 $16,036 $16,905 $10,793 $10,228
Average Price (per Mcf) $1.51 $1.99 $2.01 $1.47 $1.47
Gas Liquids (Mgal.) 9,154 2,391 - - -
Gas Liquids (000) $2,491 $487 $- $- $-
Average Price (per gal.) $.27 $.20 $- $- $-
- ------------------------------------------------------------------------------------------------------------
</TABLE>
(3) GAS PROCESSING
The Company extracts and sells natural gas liquids and buys and sells
natural gas, and, from time to time, engages in certain transactions to
hedge shrinkage and fuel costs in its gas processing operation and
natural gas prices in its gas sales activities.
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The Company's share of gas processing plant capacity, natural gas
liquids sales, residue gas sales, and other gas sales, including
intercompany transactions, are as follows:
<TABLE>
<CAPTION>
- ------------------------------------------------------------------------------------------------------------
1995 1994 1993 1992 1991
- ------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C> <C>
Interest in Gas Processing
Plant Capacity (MMcf per day) 326 327 327 327 327
SALES
Gas Liquids (Mgal.) 205,464 194,378 195,067 180,956 173,974
Gas Liquids (000) $53,638 $48,838 $59,569 $52,080 $56,468
Average Price (per gal.) $.26 $.25 $.31 $.29 $.32
Average Production Cost
(per gal.) $.22 $.24 $.26 $.22 $.21
Residue Gas (MMcf) 7,560 7,180 7,328 8,500 9,186
Residue Gas (000) $11,088 $14,266 $14,805 $13,259 $14,663
Average Price (per Mcf) $1.47 $1.99 $2.02 $1.56 $1.60
Other Gas Sales (MMcf) 19,641 18,551 40,436 48,311 65,288
Other Gas Sales (000) $39,165 $41,853 $83,578 $77,610 $98,215
Average Price (per Mcf) $1.99 $2.26 $2.07 $1.61 $1.50
- ------------------------------------------------------------------------------------------------------------
</TABLE>
The Company aggressively pursues gas supplies for processing in an
effort to increase throughput and liquid recoveries.
(4) OTHER OPERATIONS
(a) Gas Marketing
ONEOK Gas Marketing Company was formed in 1992 to pursue natural gas
marketing opportunities. ONEOK Gas Marketing Company and Ward Gas
Marketing, Inc. (Ward), organized a partnership to market natural gas.
On February 23, 1995, the Company acquired the remaining partnership
interest through merger of Ward into ONEOK Gas Marketing Company.
Gas marketing sales are as follows:
<TABLE>
<CAPTION>
- ------------------------------------------------------------------------------------------------------------
SALES 1995 1994 1993 1992 1991
- ------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C> <C>
Volumes (MMcf) 201,920 64,990 4,360 - -
Amount (000) $289,725 $126,995 $8,102 $- $-
Average Price (per Mcf) $1.43 $1.95 $1.86 $- $-
- ------------------------------------------------------------------------------------------------------------
</TABLE>
(b) Buildings
The Company, through two subsidiaries, owns a parking garage and leases
an office building in downtown Tulsa, Oklahoma. The parking garage is
owned and operated by ONEOK Parking Company. The office building (ONEOK
Plaza) is leased by ONEOK Leasing Company.
On August 18, 1995, the Company, through a subsidiary, Fifth Street
Investment Corporation, submitted a written offer to Midtown Associates,
the general partner of Southwestern Associates (the "Partnership") the
owner of the office building, to pay the Partnership $5,200,000 to
acquire the Partnership's equity in the building, subject to existing
indebtedness. The offer was rejected. On October 7, 1995, offers were
made to purchase the interests of limited partners in the Partnership at
a price of $102,000 per unit for up to 33 aggregate units. In addition,
an offer was made to the limited partners guaranteeing at least $92,000
per unit when the building sells or the Partnership dissolves in return
for proxies to vote the interests of the limited partners in the
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Partnership. The proxy offer is open to holders of the first 45
aggregate units (including up to 33 aggregate units for which the offers
to purchase are accepted). The offers expire November 17, 1995. The
limited partners in the Partnership consist of approximately 100
investors who own a total of 70 units. If the offer is accepted by
sufficient limited partners, the Company intends to vote the purchased
units and the proxies to dissolve the Partnership and force the sale of
the office building. The Company has a right of first refusal to
purchase the office building from the Partnership. The Company cannot
determine at this time whether it will be successful in securing
sufficient limited partnership interests and proxies to force
dissolution of the Partnership. However, if such dissolution occurs, the
Company intends to acquire the office building under its right of first
refusal unless for any reason it should elect otherwise.
(B) FINANCIAL INFORMATION ABOUT INDUSTRY SEGMENTS
See Note I of the Notes to Consolidated Financial Statements on pages 42
and 43.
(C) NARRATIVE DESCRIPTION OF THE BUSINESS
(1) PRINCIPAL PRODUCTS PRODUCED AND SERVICES RENDERED
(a) Distribution and Transmission
One operating division, Oklahoma Natural Gas Company, along with three
subsidiaries, ONG Transmission Company, ONG Sayre Storage Company, and
ONG Gas Gathering Company, (collectively, ONG), constitute a fully
integrated intrastate natural gas distribution and transmission
business, which purchases, stores, transports, and distributes natural
gas for sale to wholesale and retail customers primarily in the State of
Oklahoma, and leases pipeline capacity to customers for their use in
transporting natural gas to their facilities. ONG Transmission Company
transports gas for others under Section 311(a) of the Natural Gas Policy
Act of 1978 (NGPA).
Oklahoma Natural Gas Company and the three subsidiaries are consolidated
for ratemaking purposes by the Oklahoma Corporation Commission. ONG
purchases natural gas from gas processing plants, producing gas wells,
and pipeline suppliers, and utilizes five underground storages as
necessary to deliver natural gas to 717,084 customers in 294 communities
in Oklahoma. The Company's largest markets are in the Oklahoma City and
Tulsa metropolitan areas. ONG also sells natural gas at wholesale to
other distributors serving 44 Oklahoma communities. ONG serves an
estimated population of over 2 million. The all-time peak gas deliveries
during a single day was 2.02 billion cubic feet of gas delivered on
February 10, 1981. The peak for the most recent fiscal year was 1.63
billion cubic feet delivered on March 7, 1995.
The Company leases space in its pipeline system under its PCL program to
third party end users to allow them to buy gas in the field and
transport it to their facilities. ONG Sayre Storage Company leases
excess capacity in its underground storage facility to Natural Gas
Pipeline Company of America on a long-term basis. The Company, at times,
has leased part of its gas storage to third parties on a temporary
basis, allowing them to store gas in the Company's other gas storage
facilities.
Gas reserves committed to ONG's system are not subject to priority
allocations nor are they dedicated to certain classes of customers,
except for certain low priced gas under the SISP Program, which is
allocated to certain commercial and industrial customers.
ONG's rate schedules contain an "Order of Curtailment" that provides for
first reducing or totally discontinuing gas service to the very large
industrial users, who are required to have standby fuel-burning
equipment, and graduating down to requesting residential and commercial
customers to reduce their gas requirements to an amount essential for
public health and safety.
TransTex Pipeline Company has a 25 percent limited partnership interest
in Red River Pipeline (Red River), a limited partnership, which owns a
transmission pipeline system and related facilities. Red River
originates in Hemphill County, Texas, and terminates in Pecos County,
Texas, where it connects with Oasis Pipeline. The system is regulated by
the Texas Railroad Commission.
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OkTex Pipeline Company transports gas in interstate commerce under
Section 311(a) of the NGPA and is treated as a separate entity by the
FERC. The Company has the capacity to move up to 200 million cubic feet
of gas per day into Lone Star Gas Company's system in Texas and Red
River Pipeline.
ONEOK Technology Company has a 50 percent interest in Natural Energy
Products Company, a partnership, which was formed in 1992 to develop and
market a meter-setting device that allows gas utilities to change meters
without shutting off the flow of gas to the customer. The devices are
sold through an exclusive representative in the United States which also
manufactures and markets the devices in Europe under a license from
Natural Energy.
The Tri-Fuels Company operates a manufacturing plant to supply
conversion kits and fueling stations for natural gas vehicles. The
business is currently for sale.
(b) Exploration and Production
As of August 31, 1995, ONEOK Exploration Company and ONEOK Resources
Company (the Subsidiaries) had working interests in 379 gas wells and
112 oil wells located in Alabama, Louisiana, Mississippi, Oklahoma, and
Texas. A number of these wells are multiple completions.
The Subsidiaries participated in the drilling of 41 and 37 working
interest wells during 1995 and 1994 respectively, 76 percent of which
were completed as commercial producers in 1995, compared with 62 percent
completed in 1994.
The following table summarizes drilling activity during those years:
<TABLE>
<CAPTION>
- -------------------------------
1995 1994
- -------------------------------
<S> <C> <C>
Oil 9 6
Gas 22 17
Dry 10 14
- -------------------------------
41 37
===============================
</TABLE>
The Subsidiaries farmed out an additional three well prospects, which
were completed -- two as oil wells and one as a gas well.
Exploration activities are concentrated in Oklahoma and Texas, and, for
the present, the Subsidiaries are pursuing a relatively conservative
drilling and leasehold acquisition program due to uncertainty about gas
price trends.
The Company acquired reserves in Alabama in 1993 and Louisiana in 1994.
(c) Gas Processing
ONEOK Products Company owns varying interests in 15 plants which extract
liquids from natural gas and is participating with other plant owners in
programs to acquire more gas volumes for processing through the plants
to increase liquid recoveries. Products also buys and sells natural gas.
(d) Other
(i) Gas Marketing
ONEOK Gas Marketing Company purchases and markets natural gas, primarily
outside of Oklahoma. From time to time, the Company engages in certain
transactions to hedge natural gas prices in its gas marketing
activities.
(ii) Buildings
ONEOK Parking Company operates a parking garage, and ONEOK Leasing
Company operates an office building in which the Company's headquarters
is located and leases excess space to others.
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(2) STATUS OF NEW PRODUCTS OR SEGMENTS
None
(3) SOURCE AND AVAILABILITY OF RAW MATERIAL
ONG's gas supply comes from 38 gas processing plants and 914 gas
purchase connections (in 129 producing fields in Oklahoma).
<TABLE>
<CAPTION>
- ---------------------------------------------------
(MILLION CUBIC FEET)
- ---------------------------------------------------
<S> <C>
Gas Purchases 92,699
Payment in Kind 24,753
Gas Storage Withdrawals 25,261
Less: Gas Storage Injections (23,417)
- ---------------------------------------------------
Total Sources of Gas Supply 119,296
===================================================
</TABLE>
(4) PATENTS, TRADEMARKS, AND FRANCHISES HELD
Natural Energy Products Company, a partnership in which ONEOK Technology
Company has a 50 percent interest, has an exclusive license to develop
and market meter setting devices for which a patent is in effect.
The Company has one corporate division, which engages in distribution
operations in Oklahoma and operates under the trade name Oklahoma
Natural Gas Company.
Oklahoma Natural Gas Company holds franchises, all of which are for an
initial period of 25 years, in major towns in which it operates. In the
state of Oklahoma, a franchise is a right to use the municipal streets,
alleys, and other public ways for utility facilities for a defined
period of time for a fee. Although the laws of the state of Oklahoma
prohibit exclusive utility franchises, the Company nevertheless believes
there are advantages to having franchises in the larger towns in which
it operates.
Below is a list of the municipalities having a population of over 10,000
which have granted franchises to Oklahoma Natural Gas Company.
<TABLE>
<CAPTION>
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POPULATION
GRANTOR 1990 CENSUS EXPIRATION DATE
- --------------------------------------------------------------------
<S> <C> <C>
Ardmore* 23,015 July 16, 2012
Claremore 13,225 December 29, 2003
Del City 23,758 August 24, 1998
Durant 12,767 August 1, 1997
Elk City 10,419 November 21, 1998
El Reno* 15,382 December 6, 2015
Enid 45,175 January 16, 2015
Midwest City 52,037 July 14, 2019
Muskogee* 37,440 July 30, 2015
Norman* 79,579 November 15, 1998
Oklahoma City* 441,154 April 24, 2010
Ponca City* 26,328 August 16, 2007
Sand Springs 14,943 August 28, 2015
Shawnee 26,175 October 14, 2020
Stillwater 36,543 April 19, 2015
Tulsa* 364,572 August 29, 2011
Woodward* 12,287 September 7, 2019
- --------------------------------------------------------------------
</TABLE>
* Grantor has an option to purchase property within the corporate limits
at such terms and conditions as are provided in the franchise at a price
to be agreed upon or determined by arbitration.
The Company has franchises in 42 other municipalities in which there is
an aggregate population of approximately 102,000. Of the remaining towns
served in which ONG has no franchises, Bethany, Broken Arrow, Edmond,
Guthrie, Moore, Mustang, Okmulgee, Owasso, Sapulpa, The Village, and
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Yukon, with a combined population of approximately 263,000, are the
largest. In the Company's opinion, its franchises contain no unduly
burdensome restrictions and are sufficient for the transaction of its
business in the manner in which it is now conducted.
(5) SEASONAL VARIATIONS OF BUSINESS
Because residential and commercial customers use natural gas principally
for space heating, the volume of ONG's gas sales is consistently higher
during the heating season (November through May) than in other months of
the year. However, the Company's rates include a temperature
normalization adjustment clause for its natural gas distribution
operations. Industrial sales, rentals for PCLs, and other energy-related
operations tend to remain relatively constant throughout the year, while
interstate transportation volumes fluctuate based on market demand.
(6) SPECIAL INVENTORY PRACTICES, BILL PAYMENT TERMS, AND AVERAGE
PAYMENT PLANS
ONG stores gas during the summer months in underground storages for
delivery to customers during the periods of higher demand. Typically,
inventories of stored gas are near maximum levels immediately prior to
the winter months and are reduced to much lower levels by the end of the
winter heating season.
ONG has a bill payment extension program which allows its customers with
temporary financial hardships to spread the payments of their bills over
an extended period of time. In addition, the Company has an average
monthly payment plan that allows customers to spread the payments of
their average utility bills over a 12-month period.
(7) DEPENDENCE UPON A LIMITED NUMBER OF CUSTOMERS
A material part of the combined gas sales and revenues from PCLs
consists of revenues from fertilizer plant customers, including
Agricultural Minerals Limited Partnership, Wil-Gro Fertilizer, Inc.,
Farmland Industries, Inc., and Terra International, Inc. In 1995,
operating revenues from these customers amounted to $23.4 million in gas
sales and $49.4 million in rentals under PCLs. Revenues from no single
customer accounted for more than 10 percent of the Company's total
operating revenues.
Currently, all the plants are operating at or near full capacity. For
the effect of reduced fertilizer plant and other industrial sales, see
Management's Discussion and Analysis of Financial Condition and Results
of Operations, Liquidity, on page 28.
(8) BACKLOG OF ORDERS
None
(9) GOVERNMENT CONTRACTS
None
(10) COMPETITIVE CONDITIONS AND IDENTITY OF MARKETS
(a) Distribution and Transmission
Of ONEOK's consolidated revenues, revenue from the distribution and
transmission segment represented approximately 63, 78, and 79 percent
for 1995, 1994, and 1993, respectively.
ONG provides natural gas service to its customers primarily for heating
and cooking, industrial processes, and feedstock for the production of
fertilizer. ONG has experienced competition from electric utilities,
offering electricity as a rival energy source, competing for the space
heating, water heating, and cooking markets. The principal means to
compete against alternative fuels is lower
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prices, and natural gas continues to maintain its price advantage in the
residential, commercial, and both small and large industrial markets.
In the last few years, the Company has experienced competition from
other pipelines for its existing industrial load. The Company offers its
PCL program, Special Industrial Sales Program (SISP), and PIK program as
a response to such competitive pressure. Utilizing the Company's PCL
program, customers may transport gas they purchased from sources other
than the Company to their facilities. The Company's SISP program
allocates lower cost supplies to these customers, allowing the company
to compete with other sellers. Under the PIK program, the Company
accepts gas in lieu of cash for PCL payments and for transportation
charges.
In 1995, rates for industrial customers were restructured and reduced
and revenues shifted to the general system core customers (residential
and commercial). In addition, up to ten percent of revenues lost as a
result of renegotiating contracts can also be recovered from the general
system core customers. The effect of these changes is to stabilize the
Company's utility revenues and allow the Company to remain competitive
for industrial customers.
ONG's gas sales rate schedules filed with and approved by the Oklahoma
Corporation Commission allow ONG to pass on to its customers changes in
the field cost of gas by means of a purchased gas adjustment clause.
The Company had a surplus of natural gas available to its utility system
and ceased contracting for new gas reserves between 1982 and 1992. The
Company does not anticipate any problem with securing sufficient gas
supply for its customers for the foreseeable future.
In April 1992, the Federal Energy Regulatory Commission (FERC) approved
Order 636. The Company has complied with the Order for its interstate
pipeline, OkTex Pipeline Company. It is difficult to assess what long
term impact, if any, the Order will have on the Company.
(b) Exploration and Production
In the area of exploration and production operations, the Company
competes for leaseholds and drilling prospects with many large
integrated oil and gas companies and numerous independent oil and gas
companies of various sizes. The Company continues to be able to sell
its crude oil production at current market prices and anticipates
continuing to be able to sell such production in the future. However,
the Company, like the rest of the industry, has occasionally curtailed
some of its natural gas production because of low prices. A small amount
of production is still sold under long-term contracts. In certain
instances, the Company has agreed to lower prices in order to continue
sales. Most production is sold to brokers at spot-market prices.
(c) Gas Processing
Of ONEOK's consolidated revenues, revenue from the gas processing
segment represented approximately 10, 13, and 16 percent for 1995, 1994,
and 1993, respectively.
The Company owns varying interests in plants which separate such
hydrocarbon products as propane, ethane, and butane out of the gas
stream to be sold in other markets. Such liquids are used as a
petrochemical feedstock, for residential heating and cooking in rural
areas, and for producing motor fuels. The industry as a whole operates
substantial numbers of such plants, many owned by large integrated oil
and gas companies and independents. The production costs of such liquids
generally depend on the cost of the natural gas being processed and the
underlying agreements. Because of the generally favorable location of
the plants and terms of the Company's processing and operating
agreements, the Company anticipates continuing to have favorable product
costs and anticipates that its currently competitive position in
marketing will remain so for the near future.
12
<PAGE> 13
(d) Other
(i) Gas Marketing
Of ONEOK's consolidated revenues, revenue from the gas marketing
business represented approximately 24, 5, and .2 percent for 1995, 1994,
and 1993, respectively.
The Company competes with numerous other gas marketers, which vary in
size and affiliation. The gas marketing business is very competitive and
is going through a period of consolidation and reduced margins as the
industry is maturing. The business is expected to remain very
competitive during this period of change.
(ii) Buildings
The downtown Tulsa office leasing market continues to have excess
capacity. Rates remain relatively flat while the excess capacity is
being absorbed by the market.
(11) RESEARCH AND DEVELOPMENT COSTS
None.
(12) MATERIAL EFFECTS OF ENVIRONMENTAL CONTROL COMPLIANCE.
There have been no material effects upon capital expenditures, earnings,
or the Company's competitive position during the 1995 fiscal year
related to compliance with federal, state, or local regulations relating
to the discharge of materials into the environment or the protection of
the environment. No material effects of this nature are anticipated
during the 1996 fiscal year.
(13) NUMBER OF PERSONS EMPLOYED
The Company employed 2,003 persons at August 31, 1995, and is currently
not a party to any collective bargaining agreements with such employees.
ITEM 2. PROPERTIES
(A) DESCRIPTION OF PROPERTY
(1) DISTRIBUTION AND TRANSMISSION
(a) Distribution
The Company had 13,958 miles of pipeline and other distribution
facilities at August 31, 1995. Oklahoma Natural Gas Company owns a
five-story office building in Oklahoma City, Oklahoma, as well as a
number of warehouses, garages, meter and regulator houses, service
buildings, and other buildings throughout the state. The Company also
owns a fleet of vehicles and maintains an inventory of spare parts,
equipment, and supplies. In addition, the Company owns five underground
storages located throughout the state. Four of the storages operated by
the Company are located next to its large market areas. These four
storages have a combined storage capacity of 124.5 billion cubic feet.
The other storage is located in western Oklahoma and is leased to and
operated by another company. However, 25 billion cubic feet of storage
capacity in this reservoir has been retained for use by the Company.
13
<PAGE> 14
(b) Transmission
The Company had a combined total of 4,810 miles of transmission and
gathering pipeline on August 31, 1995. Compression and dehydration
facilities are located at various points throughout the pipeline system.
Through a subsidiary, the Company is a 25 percent partner in Red River
Pipeline, a transmission pipeline system consisting of approximately 361
miles of 24-inch diameter pipeline and related facilities. The system
originates in Hemphill County, Texas, and terminates in Pecos County,
Texas, where it connects with Oasis Pipeline. It is the Company's intent
to exit from the partnership during the coming year.
(2) EXPLORATION AND PRODUCTION
The Company owns varying economic interests, including overrides, in 472
gas wells and 122 oil wells, some of which are multiple completions.
Such interests are in wells located in Alabama, Louisiana, Mississippi,
Oklahoma, and Texas. The Company owns 44,622 net onshore developed
leasehold acres and 21,256 net onshore undeveloped acres, located in
Alabama, Arkansas, Colorado, Louisiana, Mississippi, Oklahoma, and
Texas. The Company owns no offshore acreage.
Lease acreage in producing units is held by production. Leases not being
held by production are generally for a term of three years and require
payments of rentals annually.
(3) GAS PROCESSING
The Company owns interests in 15 gas processing plants, which extract
liquid hydrocarbons from natural gas. All are located in Oklahoma. The
Company's share of the capacity of the plants is 326 million cubic feet
per day.
(4) OTHER
(a) Gas Marketing
The Company markets natural gas, and, from time to time, owns or has the
contractual right to supplies of natural gas.
(b) Buildings
The Company owns a parking garage with 1,179 parking spaces and land,
subject to a long-term ground lease, upon which has been constructed a
seventeen-story office building with approximately 517,000 square feet
of net rentable space. The office building is being leased to the
Company at a lease term of 25 years with six five-year renewal options.
After any renewal period, the Company can purchase the property at its
fair market value. The Company has occupied and reserved approximately
260,000 square feet of space for its own use and leases the remaining
space to others.
(B) OTHER INFORMATION
Production figures are defined by the SEC to include natural gas liquids
from Company-owned leases. The Company produces a substantial amount of
natural gas liquids as a result of ownership in several gas processing
plants, but the Company does not own the reserves attributable to the
leases producing the gas processed by these plants. As a result of this
exclusion by the SEC, information concerning these natural gas liquids
is not included in any of the tables in this section but is included
under GAS PROCESSING on pages 6 and 7.
14
<PAGE> 15
(1) OIL AND GAS RESERVES
All of the Company's oil and gas reserves are located in the United
States.
(a) Quantities of Oil and Gas Reserves
See Note L of Notes to Consolidated Financial Statements on page 45.
(b) Present Value of Estimated Future Net Revenues
See Note M of Notes to Consolidated Financial Statements on page 46.
(2) RESERVE ESTIMATES FILED WITH OTHERS
None.
(3) QUANTITIES OF OIL AND GAS PRODUCED
The net quantities of oil and natural gas produced and sold, including
intercompany transactions, were as follows:
<TABLE>
<CAPTION>
- ---------------------------------------------------------------------------------------
SALES 1995 1994 1993 1992 1991
- ---------------------------------------------------------------------------------------
<S> <C> <C> <C> <C> <C>
Oil (Bbls) 466,105 515,195 442,931 375,506 294,025
Gas (MMcf) 8,775 8,043 8,401 7,349 6,952
- ---------------------------------------------------------------------------------------
</TABLE>
(4) AVERAGE SALES PRICE AND PRODUCTION (LIFTING) COSTS
Average sales prices and lifting costs are as follows:
<TABLE>
<CAPTION>
- ------------------------------------------------------------------------
1995 1994 1993
- ------------------------------------------------------------------------
<S> <C> <C> <C>
Average Sales Price (a)
Per Bbl of oil $16.23 $14.81 $18.50
Per Mcf of gas $1.51 $1.99 $2.01
Average Lifting Costs
Per equivalent barrel
of oil & gas (b) $2.37 $2.57 $2.65
- ------------------------------------------------------------------------
</TABLE>
(a) In determining the average sales prices of oil and gas, sales to
affiliated companies were recorded on the same basis as sales to
unaffiliated customers.
(b) For the purpose of calculating the average lifting cost per
equivalent barrel of production, natural gas was converted to a liquid
equivalent using six (6) Mcf of natural gas to one barrel of oil.
Lifting costs do not include depreciation or depletion.
(5) WELLS AND DEVELOPED ACREAGE
The table below shows gross and net wells in which the Company has a
working interest at August 31, 1995 and does not include wells in which
the Company has royalty or overriding royalty interests.
<TABLE>
<CAPTION>
- ---------------------------
Oil Gas
- ---------------------------
<S> <C> <C>
Gross wells 112 379
Net wells 25 155
- ---------------------------
</TABLE>
Gross developed acres and net developed acres by well classification are
not available from the Company's records. Net developed acres for both
oil and gas is 44,622 acres.
15
<PAGE> 16
(6) UNDEVELOPED ACREAGE
The gross and net undeveloped leasehold acreage held by the Company at
the end of the fiscal year was as follows:
<TABLE>
<CAPTION>
- ----------------------------------------
GROSS NET
- ----------------------------------------
<S> <C> <C>
Alabama 1,903 226
Arkansas 5,460 1,815
Colorado 80 1
Louisiana 1,225 228
Mississippi 4,050 130
Oklahoma 43,261 12,786
Texas 19,961 6,070
- ----------------------------------------
Total 75,940 21,256
- ----------------------------------------
</TABLE>
Of the Company's net onshore undeveloped acres, approximately eight
percent lies in the Ardmore Basin area, 28 percent in the Anadarko Basin
area in Oklahoma, 30 percent in the Oklahoma portion of the Arkoma
Basin, and ten percent in the Texas Gulf Coast area.
(7) NET EXPLORATORY AND DEVELOPMENT WELLS DRILLED
The Company's net interest in total wells drilled, by well
classification, are as follows:
<TABLE>
<CAPTION>
- ------------------------------------------------
EXPLORATORY DEVELOPMENT
- ------------------------------------------------
<S> <C> <C>
1995
Productive 2.4166 6.3342
Dry 1.7463 1.8469
Total 4.1629 8.1811
================================================
1994
Productive 0.8500 5.5760
Dry 3.5075 1.8866
Total 4.3575 7.4626
================================================
1993
Productive 0.4840 5.4701
Dry 1.8487 2.3540
Total 2.3327 7.8241
================================================
</TABLE>
(8) PRESENT DRILLING ACTIVITIES
On August 31, 1995, the Company was participating in the drilling of
five wells. The Company's average net interest in these drilling
activities amounts to .605 wells.
(9) FUTURE OBLIGATIONS TO PROVIDE OIL AND GAS
None.
16
<PAGE> 17
ITEM 3. LEGAL PROCEEDINGS
FENT, ET UX V. OKLAHOMA NATURAL GAS COMPANY, A DIVISION OF ONEOK INC., ET AL.,
No. CJ-88-10148, District Court, Oklahoma County ("Fent I case"). On October 6,
1988, the Plaintiffs filed a petition for reimbursement for the cost of
replacement of a yard line and for repairing the gap in piping caused by the
relocation of the meter to the property line and as a class action for
similarly situated customers. The Company moved to dismiss the action on the
grounds the District Court did not have subject matter jurisdiction and a
failure to state a cause of action for which relief could be granted. The
District Court granted the motion to dismiss and the Plaintiffs appealed the
decision. On August 14, 1991, the Court of Appeals reversed the trial court's
decision and remanded the case for further proceedings. The appellate court
held that the trial court had erred in ruling both that it was without
jurisdiction and that the Plaintiffs had failed to state a cause of action,
instead finding that under Commission Rule 6(a) the Company could be
responsible for maintenance of the gas line up to the outflow side of the
meter. As a result, the Company could have a duty to repair the gap caused by
removal of the meter and to maintain and repair the yard line. The case was
remanded to the District Court, the Company filed a related proceeding with the
Oklahoma Corporation Commission seeking an interpretation of the applicable
Commission rules, and although the Plaintiffs filed a motion in district court
to certify the class, further proceedings in the case were stayed pending
resolution of the appeal of the decision in the related Corporation Commission
proceeding. The Corporation Commission proceeding has now been resolved and it
is anticipated that the Plaintiffs will now go forward with efforts to obtain
certification of a class.
LARUE V. ONEOK INC., No. CJ-95-6324, District Court, Oklahoma County, now Case
No. CIV-95-1556C, U.S. District Court for the Western District of Oklahoma. On
September 15, 1995, the Plaintiff filed this action alleging wrongful
termination of his employment, seeking compensatory and punitive damages, each
in an amount in excess of $10,000. This action arises out of the termination of
the employment of the Plaintiff for his refusal either to acknowledge the
Company's ownership of photographs taken by him with a company camera, while on
duty, during the aftermath of the April 19 Murrah Building bombing, or to agree
with the Company to donate all proceeds derived from such photographs to
disaster victim relief. On October 5, the Company removed the action to Federal
District Court and filed its answer denying liability, concurrently with the
filing by the Company of an action in Federal District Court to establish the
Company's ownership of the copyright to such photographs. (ONEOK INC. V. LARUE,
Case No. CIV-95-1557M, U.S. District Court for the Western District of
Oklahoma.)
NATURAL GAS OPERATIONS COMPANY V. ASSOCIATED NATURAL GAS, INC., ET AL.
(INCLUDING ONEOK INC. D/B/A OKLAHOMA NATURAL GAS COMPANY), No. CJ-94-383-E,
District Court, Stephens County. The Plaintiff commenced this action on
November 9, 1994, against Associated Natural Gas, Inc. ("ANGI"), ONEOK Inc.
d/b/a Oklahoma Natural Gas Company, and Buffum Oil & Gas, Inc.("Buffum"),
seeking to recover damages for breach of a Gas Purchase Contract dated October
24, 1988, originally entered into by Plaintiff and Lone Star Gas Company, and
on tort claims for the breach and/or tortious interference by ANGI with the
Plaintiff's gas contract with Buffum. Lone Star assigned its contract to the
Company on June 30, 1991, which the Company assigned to ANGI on October 29,
1992. The actions upon which the Plaintiff bases its claims extend from July,
1992, to the present date. Under the assignment of the gas purchase contract by
the Company to ANGI, ANGI agreed to perform all of the obligations of the buyer
required under the contract. ANGI has agreed to undertake the defense of the
Company in the action and to indemnify the Company against any damages that may
ultimately be required to be paid. The Plaintiff seeks to recover breach of
contract damages in excess of $10,000, damages for conversion of the gas in
excess of $10,000, exemplary damages in excess of $2,000,000, costs, and
attorneys' fees. This case is presently in the discovery stage.
IN THE MATTER OF THE APPLICATION OF OKLAHOMA NATURAL GAS COMPANY, A DIVISION OF
ONEOK INC. FOR EXAMINATION OF STANDBY SERVICE, Cause CD No. 598, Oklahoma
Corporation Commission. This is a request filed on September 6, 1988, by the
Company to determine if standby and/or partial service shall be offered by the
Company and if offered what rates should apply, what the priority for such
service should be, what class of customers should be able to utilize such
service, and remaining terms and conditions applicable to such service. The
Company's brief argued that the Commission had no
17
<PAGE> 18
jurisdiction to require standby service, or alternatively, if jurisdiction does
exist, no standby service should be required. On December 11, 1990, an
Administrative Law Judge recommended that the Commission assert jurisdiction to
determine the issue of standby service. The Company appealed the recommendation
to the full Commission and the Commission voted to accept the recommendation.
The matter was appealed to the Oklahoma Supreme Court. On October 20, 1992, the
Supreme Court decided the Commission is empowered to determine whether standby
service is in the public interest and what rates to apply, and the matter has
been returned to the Commission for further proceedings. Pursuant to a
scheduling order entered by an administrative law judge (and agreed to by the
parties) on December 9, 1994, a hearing on the merits was originally scheduled
for September 13, 1995, but has been rescheduled for January 17, 1996. The
Company filed its testimony and proposed tariffs on April 14, 1995.
APPLICATION OF OKLAHOMA NATURAL GAS COMPANY, A DIVISION OF ONEOK INC., FOR A
DETERMINATION THAT UNDER THE COMMISSION'S EXISTING NATURAL GAS UTILITY RULES
AND REGULATIONS, AND OKLAHOMA NATURAL'S EXISTING SERVICE RULES AND REGULATIONS,
THE GAS UTILITY CUSTOMERS OF OKLAHOMA NATURAL GAS COMPANY, EXCEPT JERRY R. FENT
AND MARGARET B. FENT, ARE RESPONSIBLE FOR INSTALLING AND MAINTAINING ALL PIPING
BETWEEN THE CUSTOMERS' PROPERTY OR CURB LINES, AND SUCH CUSTOMERS' POINTS OF
CONSUMPTION OF GAS, Cause PUD No. 95-000223, Oklahoma Corporation Commission.
On February 24, 1992, in Cause PUD No. 001123 (hereinafter referred to as the
"Fent II" case), the Commission issued Order No. 363449, holding that under the
Commission Gas Rules and ONG Rules, a gas utility customer is financially
responsible for the installation, maintenance, repair or replacement of the
customer's yard line, being the line lying between the gas utility's main
located at the property or curb line, or easement, and the premises being
served, and lying outside of any easement, regardless of where the gas meter is
located. The Commission's Order in FENT II was subsequently appealed to the
Oklahoma Supreme Court, which issued an opinion in FENT V. OKLAHOMA NATURAL GAS
CO., 898 P.2d 126 (1994), resulting in a reversal of the Commission's Order. In
its opinion the Supreme Court stated that its pronouncement did not question
the general power of the Commission to regulate utilities by rulemaking and to
interpret its own rules; it was addressed narrowly to the agency's attempt to
affect the Fent's pending district court claim. However, the Court reversed the
Commission's Order in its entirety. The Company has therefore filed this new
proceeding requesting that the Commission reaffirm its order in Fent II as it
applies to ratepayers other than the Fents, for application in the Fent I case
if it should be certified as a class action.
ITEM 4. RESULTS OF VOTES OF SECURITY HOLDERS
(A) MATTERS SUBMITTED TO A VOTE OF SECURITY HOLDERS
None
18
<PAGE> 19
(B) EXECUTIVE OFFICERS OF THE REGISTRANT
All executive officers are elected at the annual meeting of directors
held in January and serve for a period of one year or until their
successors are duly elected.
<TABLE>
<CAPTION>
- -------------------------------------------------------------------------------------------------------------
PERIOD SERVED BUSINESS EXPERIENCE
NAME AND POSITION AGE IN SUCH CAPACITY IN PAST FIVE YEARS
- -------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C>
LARRY W. BRUMMETT 45 1994 to present Chairman of the Board
Chairman of the Board of of Directors,
Directors, President, and President, and CEO
CEO 1993 to 1994 Executive VP of ONEOK
1990 to 1993 Executive VP of
Oklahoma Natural Gas
Company (ONG)
- -------------------------------------------------------------------------------------------------------------
DAVID L. KYLE 43 1995 to present Member of the Board
President and Chief of Directors
Operating Officer of 1994 to present President and Chief
Oklahoma Natural Gas Operating Officer of
Company and ONG Oklahoma Natural Gas
Transmission Company Company and ONG
Transmission Company
1990 to 1994 Executive VP of ONG
- -------------------------------------------------------------------------------------------------------------
BILL M. VAN METER 62 1986 to present President of Energy
President of Energy Companies of ONEOK
Companies of ONEOK
- -------------------------------------------------------------------------------------------------------------
JERRY D. NEAL 56 1992 to present VP, CFO, and Treasurer
VP, CFO, and Treasurer 1990 to 1992 VP of Finance
- -------------------------------------------------------------------------------------------------------------
LAVON W. NEAL 63 1991 to present VP, Secretary, and
VP, Secretary, and Assistant Treasurer
Assistant Treasurer 1976 to 1991 VP of Corporate
Responsibilities and Services
- -------------------------------------------------------------------------------------------------------------
EDMUND J. FARRELL 52 1995 to present VP of Corporate
VP of Corporate Communications and
Communications Strategic Planning
and Strategic Planning 1992 to 1995 President of Oklahoma
Alliance for Manufacturing
Excellence, Inc.
1989 to 1992 President and CEO of
Stairmaster
- -------------------------------------------------------------------------------------------------------------
FRANK W. SCHEMM 61 1994 to present VP of Business
VP of Business Development Development
1990-1994 VP of Enid District
- -------------------------------------------------------------------------------------------------------------
</TABLE>
There is no relationship among any of the executive officers either by blood,
marriage, or adoption.
19
<PAGE> 20
PART II
ITEM 5. MARKET PRICE AND DIVIDENDS ON THE REGISTRANT'S COMMON STOCK AND
RELATED SHAREHOLDER MATTERS
(A) MARKET INFORMATION
The Company's common stock is listed on the New York Stock Exchange
under the trading symbol OKE. The corporate name ONEOK is used in
newspaper stock listings. The high and low market prices of the
Company's common stock for each fiscal quarter during the last two
fiscal years were as follows:
<TABLE>
<CAPTION>
- ---------------------------------------------
1995 HIGH LOW
- ---------------------------------------------
<S> <C> <C>
First quarter $18 $15 7/8
Second quarter $18 3/8 $16 7/8
Third quarter $19 5/8 $17 1/4
Fourth quarter $23 7/8 $18 3/4
- ---------------------------------------------
</TABLE>
<TABLE>
<CAPTION>
- ---------------------------------------------
1994 HIGH LOW
- ---------------------------------------------
<S> <C> <C>
First quarter $22 5/8 $19 5/8
Second quarter $20 1/2 $17 5/8
Third quarter $18 1/2 $15 3/4
Fourth quarter $19 3/4 $15 3/4
- ---------------------------------------------
</TABLE>
(B) HOLDERS
There were 11,563 holders of the Company's common stock at August 31,
1995.
(C) DIVIDENDS
Quarterly dividends declared on the Company's common stock during the
last two fiscal years were as follows:
<TABLE>
<CAPTION>
- --------------------------------------------
1995 1994
- --------------------------------------------
<S> <C> <C>
First quarter $ .28 $ .27
Second quarter .28 .28
Third quarter .28 .28
Fourth quarter .28 .28
- --------------------------------------------
Total $1.12 $1.11
- --------------------------------------------
</TABLE>
Debt agreements pursuant to which the Company's outstanding long-term
and short-term debt has been issued limit dividends and other
distributions on the Company's common stock. Under the most restrictive
of these provisions, $27,412,000 of retained earnings is so restricted.
On August 31, 1995, $159,813,000 was available for dividends on the
Company's common stock.
20
<PAGE> 21
ITEM 6. SELECTED FINANCIAL DATA
Following are selected financial data for the Company for each of the last five
fiscal years. Dollar amounts are in millions of dollars, except per share
amounts.
<TABLE>
<CAPTION>
- --------------------------------------------------------------------------------------------------------------
1995 1994 1993 1992 1991
- --------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C> <C>
Operating revenues $949.9 $792.4 $789.1 $677.1 $689.5
Operating income $80.2 $70.9 $75.7 $65.0 $62.4
Net income $42.8 $36.2 $38.4 $32.6 $35.9
Total assets $1,169.5 $1,137.0 $1,104.5 $1,069.9 $1,051.9
Long-term debt $364.0 $376.9 $391.9 $397.9 $291.2
Earnings per common
share $1.58 $1.34 $1.43 $1.21 $1.33
Dividends per common
share $1.12 $1.11 $1.06 $.96 $.82
Percent of payout 70.9% 82.8% 74.1% 79.3% 61.7%
Common equity per
share $14.38 $13.88 $13.63 $13.28 $13.03
Return on common
equity 10.90% 9.65% 10.46 % 9.09% 10.24%
Ratio of earnings to
fixed charges 2.56 2.39 2.33 2.21 2.54
- --------------------------------------------------------------------------------------------------------------
</TABLE>
21
<PAGE> 22
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS
A. RESULTS OF OPERATIONS
ONEOK Inc. provides natural gas energy and related products and services to its
customers. One of the Company's divisions, Oklahoma Natural Gas, provides
natural gas distribution and transmission for about 75 percent of Oklahoma. A
second division, Energy Companies of ONEOK, processes and sells natural gas
liquids, markets natural gas to customers primarily outside of Oklahoma, and
explores for and produces natural gas and oil.
During fiscal 1995, significant changes occurred to better position the Company
to meet the demand of the changing energy industry. Some of these are as
follows:
- - November 1994 Rate Order - Ending a three year rate proceeding the
Company received a final rate order from the Oklahoma Corporation
Commission (OCC) ratifying the $18.2 million interim rate increase and
providing $5.5 million in additional revenue. The rate order also
instituted a monthly connection fee that will reduce the impact of
seasonality of weather on earnings.
- - June 1995 Rate Order - The Company filed a new rate request within 45
days of approval of the previous filing. The intent of the filing was
to totally revise the rate structure of its customers. The resulting
Joint Stipulation agreed to by the Company, its customers, and the OCC
reduced the cost of service to the large industrial customers and
shifted the reduction in revenue to its core residential and commercial
customers (core customers) through a tariff rider. The core customers
will benefit from changes in gas purchasing and pricing practices which
are anticipated to offset the effect of the tariff rider and produce a
net savings to these customers. A temperature normalization clause was
adopted to further reduce the impact of seasonality of weather on
earnings.
- - Sale of Pipeline Investment - The Company sold its 25 percent
partnership interest in the Ozark Gas Transmission System for its net
book value of approximately $11 million.
- - Natural Gas Production and Marketing Activities - The Company acquired
the remaining 50 percent interest in a natural gas marketing business.
The Company also acquired working interests in oil and gas reserves that
add 7.5 million cubic feet of gas and 450 barrels of crude oil
production per day.
The Company will continue to be proactive in addressing demands of the changing
energy industry.
22
<PAGE> 23
CONSOLIDATED OPERATIONS
[GRAPH]
This graph illustrates Consolidated Earnings per Share of $1.43 in 1993, $1.34
in 1994, and $1.58 in 1995.
NET INCOME
<TABLE>
<CAPTION>
-------------------------------------------------------------------------------
(THOUSANDS OF DOLLARS) 1995 1994 1993
-------------------------------------------------------------------------------
<S> <C> <C> <C>
Distribution and transmission $ 36,743 $ 35,696 $ 32,982
Exploration and production 1,139 (405) 574
Gas processing 6,665 3,657 6,199
Gas marketing (610) 267 606
Other operations (1,133) (3,034) (1,937)
-------------------------------------------------------------------------------
Consolidated $ 42,804 $ 36,181 $ 38,424
===============================================================================
</TABLE>
Net income improved primarily due to increased contributions from the Company's
gas processing segment and elimination of the losses attributable to its
contract drilling operation, which was sold in May 1994. Increased margins from
pipeline capacity leases from distribution and transmission operations were
largely offset by warmer weather.
DISTRIBUTION AND TRANSMISSION
ONEOK's distribution and transmission segment is primarily involved in natural
gas services to commercial, residential, and large industrial customers and is
subject to regulatory oversight by the OCC.
[GRAPH]
This graph illustrates Distribution and Transmission Earnings per Share of
$1.23 in 1993, $1.32 in 1994, and $1.35 in 1995.
NET INCOME
<TABLE>
<CAPTION>
-------------------------------------------------------------------------------
(THOUSANDS OF DOLLARS) 1995 1994 1993
-------------------------------------------------------------------------------
<S> <C> <C> <C>
Gas sales $ 498,849 $ 524,961 $ 538,879
Cost of gas 319,048 358,278 375,649
-------------------------------------------------------------------------------
Gross margins on gas sales 179,801 166,683 163,230
Pipeline capacity lease margins 83,590 76,171 69,496
Other revenues 18,801 18,034 20,301
-------------------------------------------------------------------------------
Net revenues 282,192 260,888 253,027
Operating expenses 190,622 173,038 168,222
Income taxes 21,905 20,865 18,024
-------------------------------------------------------------------------------
Operating income 69,665 66,985 66,781
Interest expense 32,922 31,289 33,799
-------------------------------------------------------------------------------
Net income $ 36,743 $ 35,696 $ 32,982
===============================================================================
</TABLE>
Gross margins on gas sales generally result from sales to core customers and
are typically affected by variations in weather and number of customers served.
As a result of the November 1994 and June 1995 rate orders, the Company has
minimized weather volatility through monthly connection fees and temperature
normalization clauses. Gross margins increased in 1995 primarily as a result of
increases in the base revenue provided by the two rate proceedings plus
additional customers.
Pipeline capacity lease (PCL) margins are affected by through-put, spot-market
gas prices, and the conversion rate for gas received as payment-in-kind (PIK).
In recent years, the Company has been under increased competitive pressure to
reduce costs to its large industrial customers. In response to this demand, the
Company requested and received approval from the OCC to restructure its rates
for all customer classes. The June 1995 rate order will have the effect of
reducing PCL margins to preserve the Company's competitive position in this
area. The reduction of revenue will be offset by increased revenue from the
core customers under a tariff rider. Margins increased due to increased
throughput and conversion rates for both periods plus reduced spot-market gas
prices for 1995.
23
<PAGE> 24
Prior to the latest rate orders, the Company was deferring a significant
portion of its net periodic pension and postretirement benefit costs pending
regulatory approval allowing recovery of these costs. The OCC approved recovery
of these costs on an accrual basis and provided for the recovery of all costs
previously deferred. The increase in operating expenses in 1995 results from
the recognition of these expenses as well as increased compensation costs
relating to lump-sum incentive payments resulting from the attainment of
corporate performance objectives. Increases in 1995 and 1994 are also
attributable to higher levels of depreciation resulting from capital additions.
EXPLORATION AND PRODUCTION
ONEOK's exploration and production segment is engaged in the acquisition,
exploration, and production of crude oil, natural gas, and related liquid
products.
[GRAPH]
This graph illustrates Exploration and Production Earnings Per Share of $.02 in
1993, $(.01) in 1994, and $.04 in 1995.
NET INCOME
<TABLE>
<CAPTION>
-----------------------------------------------------------------------
(THOUSANDS OF DOLLARS) 1995 1994 1993
-----------------------------------------------------------------------
<S> <C> <C> <C>
Revenues $ 24,872 $ 24,480 $ 25,132
Operating expenses 21,295 23,745 22,678
Income taxes 432 (528) 372
-----------------------------------------------------------------------
Operating income 3,145 1,263 2,082
Interest expense 2,006 1,668 1,508
-----------------------------------------------------------------------
Net income (loss) $ 1,139 $ (405) $ 574
=======================================================================
</TABLE>
[GRAPH]
This graph illustrates barrels of oil production of 442,931 in 1993, 515,195 in
1994, and 466,105 in 1995; as well as oil prices related to that production of
$18.50 per barrel in 1993, $14.81 per barrel in 1994, and $16.23 per barrel in
1995.
[GRAPH]
This graph illustrates MMcf of gas production of 8,401 in 1993, 8,043 in 1994,
and 8,775 in 1995; as well as prices related to that production of $2.01 per Mcf
in 1993, $1.99 per Mcf in 1994, and $1.51 per Mcf in 1995.
[GRAPH]
This graph illustrates MGal. of liquids production of 2.391 in 1994, and 9,154
in 1995; as well as prices related to that production of $.20 per gallon in
1994 and $.27 in 1995.
The Company has proved equivalent gas reserves of 55,708, 46,074, and 55,782
MMcf as of August 31, 1995, 1994, and 1993, respectively. Reserves have been
replaced primarily through the acquisition of working interests. A fiscal 1995
acquisition of $17.6 million of natural gas and crude oil working interests
resulted in a 34 percent increase in equivalent reserves. An acquisition in
fiscal 1993 resulted in a 25 percent increase in equivalent reserves. Drilling,
exploration, and acquisition costs approximated $25 and $8 million in fiscal
1995 and 1994. The result was that 159 percent of production was replaced in
1995. Minimal production was replaced in 1994.
24
<PAGE> 25
Revenues for 1995 were relatively unchanged despite increased natural gas
sales, liquid sales, and oil prices. These increases were offset as a result of
a 35 percent decline in the spot market price of natural gas and decreased oil
production. Revenues for 1994 were lower primarily due to lower crude oil
prices.
Fluctuations in operating expenses are primarily attributable to depreciation
and depletion costs.
GAS PROCESSING
ONEOK Products Company extracts and sells natural gas liquids and buys and
sells natural gas.
[GRAPH]
This graph illustrates Earnings Per Share for Gas Processing of $.23 in 1993,
$.14 in 1994, and $.25 in 1995.
NET INCOME
<TABLE>
<CAPTION>
---------------------------------------------------------------------------------
(THOUSANDS OF DOLLARS) 1995 1994 1993
---------------------------------------------------------------------------------
<S> <C> <C> <C>
Gas sales $ 39,165 $ 41,853 $ 83,578
Cost of gas 33,778 38,702 81,560
---------------------------------------------------------------------------------
Gross margins on gas sales 5,387 3,151 2,018
Liquids, residue, and other revenues 64,874 65,403 74,831
---------------------------------------------------------------------------------
Net revenues 70,261 68,554 76,849
Operating expenses 58,545 61,990 65,967
Income taxes 4,085 2,077 3,942
---------------------------------------------------------------------------------
Operating income 7,631 4,487 6,940
Interest expense 966 830 741
---------------------------------------------------------------------------------
Net income $ 6,665 $ 3,657 $ 6,199
=================================================================================
</TABLE>
[GRAPH]
This graph illustrates MMcf of gas sales for gas processing of 40,436 in 1993,
18,551 in 1994, and 19,641 in 1995, as well as prices related to those sales of
$2.07 per Mcf in 1993, $2.26 per Mcf in 1994, and $1.99 per Mcf in 1995.
[GRAPH]
This graph illustrates MGal. of liquids sales for gas processing of 195,067 in
1993, 194,378 in 1994, and 205,464 in 1995, as well as prices related to those
sales of $.31 in 1993, $.25 in 1994, and $.26 in 1995.
[GRAPH]
This graph illustrates MMcf of residue gas sales for gas processing of 7,328 in
1993, 7,180 in 1994 and 7,560 in 1995; as well as related prices of $2.02 per
Mcf in 1993, $1.99 per Mcf in 1994, and $1.47 per Mcf in 1995.
Gas sales represent both term and market sales. Term sales are currently under
contracts that extend through 1996. Margins on gas sales increased in 1995 as
a result of lower gas supply cost. The increase in margins in 1994 was
attributable to improved market rates under the term-sales agreements.
Liquids, residue gas, and other revenues declined slightly in 1995 despite
greater liquids sales volumes, higher liquids prices, and greater residue gas
volumes, because of significantly lower residue gas prices. The decline in 1994
was principally the result of significantly lower product prices.
Reductions in operating expenses are the result of reduced fuel costs caused by
lower spot-market prices, thereby significantly improving margins for liquids
products sales. Other operating costs remained relatively flat.
25
<PAGE> 26
GAS MARKETING
ONEOK Gas Marketing Company buys and sells natural gas on the open market.
[GRAPH]
This graph illustrates Earnings Per Share for Gas Marketing of $.02 in 1993,
$.01 in 1994, and $(.02) in 1995.
NET INCOME
<TABLE>
<CAPTION>
---------------------------------------------------------------------
(THOUSANDS OF DOLLARS) 1995 1994 1993
---------------------------------------------------------------------
<S> <C> <C> <C>
Revenues $ 290,186 $ 128,322 $ 9,330
Cost of gas 287,564 126,990 8,102
---------------------------------------------------------------------
Gross margins 2,622 1,332 1,228
Operating expenses 3,230 720 216
Income taxes (365) 167 381
---------------------------------------------------------------------
Operating income (loss) (243) 445 631
Interest expense 367 178 25
---------------------------------------------------------------------
Net income (loss) $ (610) $ 267 $ 606
=====================================================================
</TABLE>
In October 1992, the Company entered the gas marketing business by acquiring a
50 percent interest in an entity established in that line of business. The
results of operations attributable to the 50 percent interest are included in
operating expenses in 1994 and 1993. In February 1995, the Company acquired the
remaining interest in the entity. As a result of continuing competition, gross
margins remained low for 1995. To improve its performance, the Company
initiated changes during its last quarter that increased its sales volumes by
approximately 30 percent for that quarter.
OTHER OPERATIONS
Other operations include the Company's leasing and parking operations, and for
1994 and 1993, ONEOK's contract drilling business.
ONEOK Leasing Company and ONEOK Parking Company operate the headquarters office
building and a parking garage in downtown Tulsa, leasing space in excess of the
Company's requirements in the Tulsa commercial market. The Company, through a
subsidiary, has made a tender offer in an attempt to ultimately acquire
ownership of the building.
[GRAPH]
This graph illustrates Earnings Per Share for Other Operations of $(.07) in
1993, $(.12) in 1994, and $(.04) in 1995.
NET INCOME
<TABLE>
<CAPTION>
---------------------------------------------------------------------
(THOUSANDS OF DOLLARS) 1995 1994 1993
---------------------------------------------------------------------
<S> <C> <C> <C>
Revenues $ 9,664 $ 14,785 $ 17,625
Operating expenses 10,406 18,516 20,269
Income taxes (715) (1,485) (1,914)
---------------------------------------------------------------------
Operating income (loss) (27) (2,246) (730)
Interest expense 1,106 788 1,207
---------------------------------------------------------------------
Net income (loss) $ (1,133) $ (3,034) $ (1,937)
=====================================================================
</TABLE>
Leasing and parking revenues for space in the Company's corporate headquarters
building, ONEOK Plaza, have declined due to continuing soft commercial leasing
demand in the Tulsa area.
Net losses attributable to the contract drilling operations were $1.5 million
and $1.4 million in 1994 and 1993, respectively. This business was sold in
1994.
26
<PAGE> 27
FINANCIAL FLEXIBILITY AND LIQUIDITY
With the current mix and relative sizes of ONEOK's business segments, the
Company's goals are to achieve an equity to capital ratio of approximately 50
percent and to preserve or improve its current debt ratings. At August 31,
1995, the equity component was 49 percent, an improvement from 47 percent at
August 31, 1994. Debt ratings are A3 by Moody's Investors Service and A-by
Standard & Poor's Corporation. Moody's upgraded its rating from Baa1 in July
1995. The Company's long-term debt represents 46.9 percent of total capital at
August 31, 1995.
Cash provided by operating activities remains strong and continues as the
primary source for meeting cash requirements. However, due to seasonal
fluctuations and additional capital requirements, the Company accesses funds
through a short-term credit agreement and, if necessary, through long-term
borrowings.
SOURCES OF CASH
<TABLE>
<CAPTION>
----------------------------------------------------------------------------------
(ESTIMATED)
(MILLIONS OF DOLLARS) 1996 1995 1994 1993
----------------------------------------------------------------------------------
<S> <C> <C> <C> <C>
Operating activities $ 99.9 $ 109.1 $ 80.3 $ 104.3
Short-term debt - 5.2 28.0 17.0
Long-term debt - - - 77.0
Other - 11.0 8.0 13.9
----------------------------------------------------------------------------------
Total sources of cash $ 99.9 $ 125.3 $ 116.3 $ 212.2
==================================================================================
</TABLE>
OPERATING CASH FLOWS
Operating cash flows for 1995 include enhanced earnings primarily as a result
of increased contributions from gas processing operations and elimination of
losses attributable to the drilling business, which was sold in 1994. Cash
flows for 1994 were influenced by reduced earnings due to soft liquid product
prices. Other major factors affecting cash flows for both 1995 and 1994 were
fluctuations in the Company's purchased gas cost adjustment, rate treatment of
deferred costs, and changes in the components of current and deferred income
taxes.
INVESTING CASH FLOWS
The Company anticipates that capital expenditures for 1996, excluding potential
acquisitions, will be less than the previous three years.
Expenditures for exploration and production for 1995 and 1993 include
acquisition costs of approximately $17.6 and $16.7 million, respectively.
[Graph]
This graph illustrates Capital expenditures of $86.2 million in 1993, $73.9
million in 1994, $83.0 million in 1995 and an estimate of $54.1 million in
1996.
<TABLE>
<CAPTION>
- ------------------------------------------------------------------------------------
(Estimated)
1993 1994 1995 1996
- ------------------------------------------------------------------------------------
<S> <C> <C> <C> <C>
Distribution & Transmission $58.8 $62.2 $55.8 $44.0
- ------------------------------------------------------------------------------------
Exploration and Production 24.9 8.3 25.0 3.8
- ------------------------------------------------------------------------------------
Gas Processing 1.7 2.7 1.2 5.7
- ------------------------------------------------------------------------------------
Other 0.8 0.7 1.0 0.6
- ------------------------------------------------------------------------------------
</TABLE>
27
<PAGE> 28
FINANCING CASH FLOW
The Company has a short-term unsecured credit agreement with several banks in
which the banks have agreed to provide loans not to exceed $125 million at any
one time for general corporate purposes. The maximum amount of short-term debt
authorized by the board of directors is $150 million. At August 31, 1995, $364
million of long-term debt was outstanding. As of that date, the Company could
have issued approximately $160 million of additional long-term debt under the
most restrictive provisions contained in its various borrowing agreements.
All long-term debt that can be called has been refinanced at lower rates. Of
the remaining debt, the 9.7 and 9.75 percent series due 2019 and 2020 can be
called December 1, 1999, and December 1, 2000, respectively.
ONEOK had approximately 28 million unrestricted shares of common stock, 160,000
shares of preferred stock, and three million shares of preference stock
available for issue at August 31, 1995.
The Company believes that internally generated funds and access to financial
markets will be sufficient to meet its debt service, dividend requirements, and
capital expenditures. However, certain events, such as significant
acquisitions, may require additional debt or equity financing.
LIQUIDITY
The distribution and transmission segment continues to face competitive
pressure to serve the substantial market represented by its large industrial
customers. The loss of a substantial portion of its industrial load, without
recoupment of the revenues from that loss, would have a materially adverse
effect on the Company's financial condition. The Company has successfully
competed in large part with such innovative methods as its Pipeline Capacity
Lease program, Special Industrial Sales Program, and Payment-in-Kind program.
These programs were all designed to provide competitive alternatives for
Oklahoma industry. Rate restructuring achieved in the June 1995 rate order
further reduces the Company's risk in serving its large industrial customers.
The Company's position has improved significantly as a result of regulatory
actions within the three years' comparisons contained in this analysis. On
January 6, 1994, the Oklahoma Corporation Commission approved recovery of
deferred take-or-pay costs. On November 22, 1994, the OCC made permanent and
increased an interim rate increase and approved amortization of deferred
pension costs. On June 19, 1995, the OCC authorized a general rate increase,
restructured large industrial customer rates by shifting costs to the Company's
core customers, changed gas purchasing practices with a net reduced cost to
those core customers, initiated a temperature adjustment clause, approved
funding of Other Postretirement Benefit costs in the rates, and approved
recovery of additional deferred costs.
OTHER
IMPAIRMENTS. The Financial Accounting Standards Board has issued Statement of
Financial Accounting Standards No. 121 (SFAS No. 121), Accounting for the
Impairment of Long-Lived Assets and for Long-Lived Assets to Be Disposed Of,
which is effective for fiscal years beginning after December 15, 1995. This
Statement requires that long-lived assets and certain identifiable intangibles
to be held and used by an entity be reviewed for impairment whenever events or
changes in circumstances indicate that the carrying amount of an asset may not
be recoverable. Furthermore, this Statement requires that most long-lived
assets and certain identifiable intangibles to be disposed of be reported at
the lower of carrying amount or fair value less cost to sell. SFAS No. 121 also
requires that a rate-regulated enterprise recognize an impairment for the
amount of cost excluded when a regulator excludes all or part of a cost from
the enterprises's rate base. The Company does not expect the adoption of SFAS
No. 121 to have a significant impact on its consolidated financial statements.
28
<PAGE> 29
PRICE RISK MANAGEMENT. Commodity futures contracts and swaps are periodically
used in the exploration and production, gas processing, and marketing
operations to hedge the impact of natural gas price fluctuations. Natural gas
futures require the Company to buy or sell natural gas at a fixed price. Under
swap agreements, the Company receives or makes payments based on the
differential between a specified price and the actual price of natural gas. The
Company's exploration and production operation periodically uses commodity
futures contracts and swaps to hedge the impact of oil and natural gas price
fluctuations. The Company's gas processing operation uses futures to hedge the
price of gas used in the natural gas liquid extraction process. The gas
marketing operation uses futures and swaps to lock in margins on preexisting
purchase or sale commitments for physical quantities of natural gas. The
Company adheres to policies and procedures which limit its exposure to market
risk from open positions and monitors daily its exposure to market risk. Gains
and losses on commodity futures contracts and swaps are recognized when the
related physical gas purchases or sales transactions are recognized. At August
31, 1995, the net deferred gain on these contracts was approximately $1.1
million.
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA MANAGEMENT'S RESPONSIBILITY
FOR FINANCIAL REPORTING
The management of ONEOK Inc. is responsible for all information included in the
Annual Report, whether audited or unaudited. The financial statements have been
prepared in accordance with generally accepted accounting principles, applied
in a consistent manner, and necessarily include some amounts that are based on
the best estimates and judgments of management.
Management maintains a system of internal accounting policies, procedures, and
controls designed to provide reasonable assurance that assets are safeguarded
against loss or unauthorized use and that the financial records are reliable
for preparing financial statements. ONEOK Inc. maintains an internal auditing
staff responsible for evaluating the adequacy and application of financial and
operating controls and for testing compliance with management's policies and
procedures.
The accompanying consolidated financial statements of ONEOK Inc. and
subsidiaries as of August 31, 1995 and 1994, and for each of the years in the
three-year period ended August 31, 1995, have been audited by KPMG Peat Marwick
LLP, independent certified public accountants. Their audits include reviews of
the system of internal controls to the extent considered necessary to determine
the audit procedures required to support their opinion on the consolidated
financial statements. The Independent Auditors' Report appears herein.
The Board of Directors performs its oversight role for reviewing the accounting
and auditing procedures and financial reporting of ONEOK Inc. through its Audit
Committee. Both KPMG Peat Marwick LLP and our internal auditors have free
access to the Committee, without the presence of management, to discuss
accounting, auditing, and financial reporting matters.
29
<PAGE> 30
INDEPENDENT AUDITORS' REPORT
To the Board of Directors and Shareholders
ONEOK Inc.:
We have audited the accompanying consolidated balance sheets of ONEOK Inc. and
subsidiaries as of August 31, 1995 and 1994, and the related consolidated
statements of income, shareholders' equity, and cash flows for each of the
years in the three-year period ended August 31, 1995. These consolidated
financial statements are the responsibility of the Company's management. Our
responsibility is to express an opinion on these consolidated 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 consolidated financial statements referred to above present
fairly, in all material respects, the financial position of ONEOK Inc. and
subsidiaries at August 31, 1995 and 1994, and the results of their operations
and their cash flows for each of the years in the three-year period ended
August 31, 1995, in conformity with generally accepted accounting principles.
As discussed in Note H to the consolidated financial statements, the Company
changed its method of accounting for certain postretirement and postemployment
benefit obligations by adopting the provisions of Statements of Financial
Accounting Standards Nos. 106 and 112 in 1994.
KPMG Peat Marwick LLP
Tulsa, Oklahoma
October 19, 1995
30
<PAGE> 31
ONEOK Inc. and Subsidiaries
CONSOLIDATED STATEMENTS OF INCOME
<TABLE>
<CAPTION>
- ---------------------------------------------------------------------------------------------------------
Years Ended August 31, 1995 1994 1993
- ---------------------------------------------------------------------------------------------------------
<S> <C> <C> <C>
(Thousands of Dollars)
Operating Revenues
Distribution and transmission $ 599,488 $ 617,487 $ 626,951
Exploration and production 22,500 23,023 24,092
Gas processing 96,652 106,589 125,435
Gas marketing 227,260 36,723 243
Other 3,986 8,561 12,388
- ---------------------------------------------------------------------------------------------------------
Total Operating Revenues 949,886 792,383 789,109
- ---------------------------------------------------------------------------------------------------------
Operating Expenses
Cost of gas 567,827 432,371 426,675
Operations and maintenance 205,903 198,041 199,166
Depreciation, depletion, and amortization 50,354 50,858 48,026
General taxes 20,289 19,083 18,732
Income taxes 25,342 21,096 20,806
- ---------------------------------------------------------------------------------------------------------
Total Operating Expenses 869,715 721,449 713,405
- ---------------------------------------------------------------------------------------------------------
Operating Income 80,171 70,934 75,704
- ---------------------------------------------------------------------------------------------------------
Interest
Interest on long-term debt 32,345 32,979 35,250
Other interest 4,934 1,855 1,120
Amortization of debt expense 512 525 2,117
Interest income on cash deposit - - (668)
Allowance for funds used during construction (424) (606) (539)
- ---------------------------------------------------------------------------------------------------------
Net Interest 37,367 34,753 37,280
- ---------------------------------------------------------------------------------------------------------
Net Income 42,804 36,181 38,424
Preferred Stock Dividends 428 428 428
- ---------------------------------------------------------------------------------------------------------
Income Available for Common Stock $ 42,376 $ 35,753 $ 37,996
=========================================================================================================
Earnings Per Share of Common Stock $1.58 $1.34 $1.43
=========================================================================================================
Average Shares of Common Stock
Outstanding (Thousands) 26,862 26,674 26,632
=========================================================================================================
</TABLE>
See accompanying notes to consolidated financial statements.
31
<PAGE> 32
ONEOK Inc. and Subsidiaries
CONSOLIDATED BALANCE SHEETS
<TABLE>
<CAPTION>
- --------------------------------------------------------------------------------------------------------
August 31, 1995 1994
- --------------------------------------------------------------------------------------------------------
<S> <C> <C>
(Thousands of Dollars)
Assets
Property
Distribution system $ 584,144 $ 549,655
Transmission system 286,252 332,109
Gas storage 49,736 45,944
Gas gathering 45,064 -
Exploration and production 120,223 101,997
Gas processing 70,363 69,954
Other 119,961 118,080
- --------------------------------------------------------------------------------------------------------
Total Property 1,275,743 1,217,739
Accumulated depreciation, depletion, and amortization 509,833 480,288
- --------------------------------------------------------------------------------------------------------
Net Property 765,910 737,451
- --------------------------------------------------------------------------------------------------------
Current Assets
Cash and cash equivalents 12,461 4,545
Accounts receivable 81,805 49,079
Income taxes receivable - 1,950
Materials and supplies 5,803 4,950
Gas in storage 76,320 89,504
Advance payments for gas 6,214 1,958
Purchased gas cost adjustment - 11,809
Deferred income taxes 3,440 -
Other current assets 8,036 5,458
- --------------------------------------------------------------------------------------------------------
Total Current Assets 194,079 169,253
- --------------------------------------------------------------------------------------------------------
Deferred Charges and Other Assets
Advance payments for gas - 8,870
Investments 17,077 34,015
Regulatory assets, net 168,889 169,566
Other 23,510 17,845
- --------------------------------------------------------------------------------------------------------
Total Deferred Charges and Other Assets 209,476 230,296
- --------------------------------------------------------------------------------------------------------
Total Assets $1,169,465 $1,137,000
========================================================================================================
</TABLE>
See accompanying notes to consolidated financial statements.
32
<PAGE> 33
ONEOK Inc. and Subsidiaries
CONSOLIDATED BALANCE SHEETS
<TABLE>
<CAPTION>
- ---------------------------------------------------------------------------------------------------------
August 31, 1995 1994
- ---------------------------------------------------------------------------------------------------------
<S> <C> <C>
(Thousands of Dollars)
Liabilities and Shareholders' Equity
Common Shareholders' Equity
Common stock without par value: authorized 60,000,000
shares; issued and outstanding 27,020,004 and 26,690,004
shares in 1995 and 1994 $ 201,404 $ 195,568
Retained earnings 187,225 174,926
- ---------------------------------------------------------------------------------------------------------
Total Common Shareholders' Equity 388,629 370,494
Preferred stock: $50 par and involuntary liquidation value;
$53 voluntary liquidation value; Series A and B, 4 3/4%
(cumulative); authorized 340,000 shares; issued 180,000
shares of Series A in 1995 and 1994 9,000 9,000
- ---------------------------------------------------------------------------------------------------------
Total Shareholders' Equity 397,629 379,494
- ---------------------------------------------------------------------------------------------------------
Long-Term Debt 350,900 362,897
Current Liabilities
Long-term debt 13,076 14,050
Notes payable 55,170 50,000
Accounts payable 58,152 44,238
Accrued income taxes 5,031 -
Accrued general taxes 10,418 9,845
Accrued interest 8,529 8,711
Purchased gas cost adjustment 2,706 -
Customers' deposits 6,824 6,413
Deferred income taxes - 3,822
Other 14,082 11,429
- ---------------------------------------------------------------------------------------------------------
Total Current Liabilities 173,988 148,508
- ---------------------------------------------------------------------------------------------------------
Deferred Credits and Other Liabilities
Deferred income taxes 189,330 197,156
Customers' advances for construction
and other deferred credits 57,618 48,945
- ---------------------------------------------------------------------------------------------------------
Total Deferred Credits and Other Liabilities 246,948 246,101
- ---------------------------------------------------------------------------------------------------------
Commitments and Contingencies
- ---------------------------------------------------------------------------------------------------------
Total Liabilities and Shareholders' Equity $1,169,465 $1,137,000
=========================================================================================================
</TABLE>
33
<PAGE> 34
ONEOK Inc. and Subsidiaries
CONSOLIDATED STATEMENTS OF CASH FLOWS
<TABLE>
<CAPTION>
- ---------------------------------------------------------------------------------------------------------
Years Ended August 31, 1995 1994 1993
- ---------------------------------------------------------------------------------------------------------
<S> <C> <C> <C>
(Thousands of Dollars)
Operating Activities
Net income $ 42,804 $ 36,181 $ 38,424
Depreciation, depletion, and amortization 50,354 50,858 48,026
Net losses of equity investees 811 1,455 1,208
Deferred income taxes (15,270) 10,021 (1,999)
Other 613 (528) 1,344
Changes in assets and liabilities:
(Increase) decrease in trade accounts receivable (32,726) 2,466 (586)
(Increase) decrease in income taxes receivable 1,950 (1,950) -
(Increase) decrease in inventories 12,331 (1,547) 342
(Increase) decrease in other assets 2,182 5,576 57,493
(Increase) decrease in regulatory assets 145 (19,481) (48,959)
Increase (decrease) in accounts payable and
accrued liabilities 22,400 2,733 23,696
Change in purchased gas cost adjustment 14,515 (20,658) (770)
Increase (decrease) in deferred credits
and other liabilities 9,412 15,148 (11)
- ---------------------------------------------------------------------------------------------------------
Cash provided by operating activities 109,521 80,274 118,208
- ---------------------------------------------------------------------------------------------------------
Investing Activities
(Increase) decrease in other investments 5,226 (2,324) (6,031)
Proceeds from sale of investment 10,901 - -
Capital expenditures, net of salvage (80,982) (73,999) (86,771)
Proceeds from sale of property 1,556 7,966 -
- ---------------------------------------------------------------------------------------------------------
Cash used in investing activities (63,299) (68,357) (92,802)
- ---------------------------------------------------------------------------------------------------------
Financing Activities
Payments of long-term debt (12,971) (15,000) (82,925)
Issuance of long-term debt - - 77,000
Issuance of notes payable 274,152 315,000 92,000
Payments of notes payable (268,982) (287,000) (75,000)
Issuance of common stock - - (194)
Dividends paid (30,505) (30,039) (28,657)
- ---------------------------------------------------------------------------------------------------------
Cash used in financing activities (38,306) (17,039) (17,776)
- ---------------------------------------------------------------------------------------------------------
Change in Cash and Cash Equivalents 7,916 (5,122) 7,630
Cash and Cash Equivalents at the
Beginning of Year 4,545 9,667 2,037
- ---------------------------------------------------------------------------------------------------------
Cash and Cash Equivalents at
End of Year $ 12,461 $ 4,545 $ 9,667
=========================================================================================================
</TABLE>
See accompanying notes to consolidated financial statements.
34
<PAGE> 35
ONEOK Inc. and Subsidiaries
CONSOLIDATED STATEMENTS OF SHAREHOLDERS' EQUITY
<TABLE>
<CAPTION>
Common Shareholders' Equity
-------------------------------------------
Common Retained Preferred
Stock Earnings Total Stock
- --------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C>
(Thousands of Dollars)
Balance at September 1, 1992 $ 194,559 $ 159,017 $ 353,576 $ 9,000
Net income - 38,424 38,424 -
Net change in common stock (194) - (194) -
Preferred stock dividends -
$2.375 per share - (428) (428) -
Common stock dividends -
$1.06 per share - (28,229) (28,229) -
- --------------------------------------------------------------------------------------------------------------
Balance at August 31, 1993 $ 194,365 $ 168,784 $ 363,149 $ 9,000
==============================================================================================================
Balance at September 1, 1993 $ 194,365 $ 168,784 $ 363,149 $ 9,000
Net income - 36,181 36,181 -
Issuance of common stock 1,203 - 1,203 -
Preferred stock dividends -
$2.375 per share - (428) (428) -
Common stock dividends -
$1.11 per share - (29,611) (29,611) -
- --------------------------------------------------------------------------------------------------------------
Balance at August 31, 1994 $ 195,568 $ 174,926 $ 370,494 $ 9,000
==============================================================================================================
Balance at September 1, 1994 $ 195,568 $ 174,926 $ 370,494 $ 9,000
Net income - 42,804 42,804 -
Issuance of common stock 5,836 - 5,836 -
Preferred stock dividends -
$2.375 per share - (428) (428) -
Common stock dividends -
$1.12 per share - (30,077) (30,077) -
- --------------------------------------------------------------------------------------------------------------
Balance at August 31, 1995 $ 201,404 $ 187,225 $ 388,629 $ 9,000
==============================================================================================================
</TABLE>
See accompanying notes to consolidated financial statements.
35
<PAGE> 36
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(A) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
CONSOLIDATION. The consolidated financial statements include the accounts of
ONEOK Inc. and its wholly owned subsidiaries. All significant intercompany
accounts and transactions have been eliminated in consolidation.
REGULATION. The distribution and transmission operations of the Company are
subject to the rate regulation and accounting requirements of the Oklahoma
Corporation Commission (OCC). Certain activities of the Company are subject to
regulation by the Federal Energy Regulatory Commission (FERC). Allocation of
costs and revenues to accounting periods for ratemaking and regulatory purposes
may differ from bases generally applied by nonregulated companies. Such
allocations to meet regulatory accounting requirements are considered to be
generally accepted accounting principles for regulated utilities provided that
there is a demonstrable ability to recover any deferred costs in future rates.
REVENUE RECOGNITION. The Company recognizes revenue when services are rendered
or product is delivered. Major industrial and commercial gas distribution
customers are invoiced as of the end of each month. Certain gas distribution
customers, primarily residential and some commercial, are invoiced on a cycle
basis throughout each month, and the Company accrues unbilled revenues at the
end of each month. Revenues from oil and gas production, gas liquids
extraction, and gas marketing are recognized on the sales method. Credit is
granted to these customers under customary terms.
DISTRIBUTION AND TRANSMISSION PROPERTY. Distribution and transmission property
is stated at cost. Such cost includes personnel costs, general and
administrative costs, and an allowance for funds used during construction. The
allowance for funds used during construction represents the capitalization of
estimated average cost of borrowed funds (8.24 percent, 8.21 percent, and 9.18
percent, in 1995, 1994, and 1993, respectively) used during the construction of
major projects and is recorded as a credit to earnings.
Depreciation is calculated using the straight-line method based upon rates
prescribed for ratemaking purposes. The average depreciation rate approximated
3.7 percent in 1995, 3.8 percent in 1994, and 3.7 percent in 1993.
Maintenance and repairs are charged directly to expense. The cost of property
retired or sold, plus removal costs, less salvage, is charged to accumulated
depreciation. Gains and losses from retirements or sales of other property,
plant, and equipment are recognized in income.
EXPLORATION AND PRODUCTION PROPERTY. The Company uses the successful-efforts
method to account for costs incurred in the acquisition, exploration, and
development of oil and natural gas reserves. Costs to acquire mineral interests
in oil and gas properties, to drill exploratory wells which find proved
reserves, and to drill and equip development wells are capitalized. Geological
and geophysical costs and costs to drill exploratory wells which do not find
proved reserves are expensed. Unproved oil and gas properties which are
individually significant are periodically assessed for impairment of value, and
a loss is recognized at the time of impairment by providing an impairment
allowance. The remaining unproved oil and gas properties are aggregated, and an
overall impairment allowance is provided based on the Company's experience.
Depreciation and depletion are calculated using the unit-of-production method
based upon periodic estimates of oil and gas reserves. Undeveloped properties
are amortized based upon remaining lease terms and exploratory and
developmental drilling experience.
36
<PAGE> 37
OTHER PROPERTIES. Gas processing plants and all other properties are stated at
cost. Gas processing plants are depreciated using various rates based on
estimated lives of available gas reserves. All other property and equipment is
depreciated using the straight-line method over its estimated useful life.
INVENTORIES. Materials and supplies are priced at average cost. Long-term gas
in storage is classified as property and is priced at cost. Current gas in
storage is valued using the last-in, first-out method. The estimated
replacement cost of current gas in storage was $72.4 million at August 31,
1995, and $114.8 million at August 31, 1994.
INCOME TAXES. Deferred income taxes are recognized for the tax consequences of
"temporary differences" by applying enacted statutory tax rates applicable to
future years to differences between the financial statement carrying amounts
and the tax bases of existing assets and liabilities. The effect on deferred
taxes of a change in tax rates is deferred and amortized for the OCC regulated
operations and is recognized in income in the period that includes the
enactment date for nonregulated operations. The Company continues to amortize
previously deferred investment tax credits on gas distribution and transmission
properties over the period prescribed by the OCC for ratemaking purposes.
EARNINGS PER SHARE. Earnings per share computations are based upon the weighted
average number of common shares outstanding during each year. Weighted average
shares outstanding were 26,862,000 during 1995; 26,674,000 during 1994; and
26,632,000 during 1993.
CASH AND CASH EQUIVALENTS. Items classified as cash equivalents for the purpose
of the Consolidated Statements of Cash Flows include highly liquid temporary
investments, with original maturities of three months or less, in "money
market" or "pooled" investment accounts backed by government securities, bank
certificates of deposit, or bank lines of credit.
RECLASSIFICATION. Certain amounts in the 1994 and 1993 consolidated financial
statements have been reclassified to conform with the 1995 presentation.
(B) REGULATORY ASSETS
The following table is a summary of regulatory assets, net of amortization:
<TABLE>
<CAPTION>
----------------------------------------------------------------------
AUGUST 31, 1995 1994
(THOUSANDS OF DOLLARS)
----------------------------------------------------------------------
<S> <C> <C>
Recoupable take-or-pay settlements $ 106,122 $ 107,492
Pension costs 40,302 43,285
Postretirement costs other than pensions 10,603 6,396
Postemployment benefit costs 2,975 2,975
Income tax rate changes 8,887 9,418
----------------------------------------------------------------------
Regulatory assets, net $ 168,889 $ 169,566
======================================================================
</TABLE>
During 1995 and 1994, the Company incurred approximately $3.1 million and $.4
million, respectively, of recoupable costs attributable to resolutions of
take-or-pay and pricing issues.
The OCC has authorized recovery of the take-or-pay settlement costs through a
combination of a surcharge to customers and revenues derived from certain
transportation customers. The costs related to pensions and postretirement
benefits are currently being recovered through revenue and are being amortized
into expense over a 10 to 18 year period. The Company anticipates that
postemployment benefit costs will be recovered in future rate filings.
Amortization expense related to regulatory assets was approximately $8.2
million, $3.1 million, and $.5 million in 1995, 1994, and 1993, respectively.
37
<PAGE> 38
(C) INVESTMENTS
Through a subsidiary, the Company is a 25 percent partner in a natural gas
transmission system, Red River Pipeline (Red River), which operates in Texas.
It is the Company's intent to exit from the partnership during the coming year.
<TABLE>
<CAPTION>
-----------------------------------------------------------
(UNAUDITED) RED RIVER
(THOUSANDS OF DOLLARS) 1995 1994
-----------------------------------------------------------
<S> <C> <C>
Current assets $ 1,832 $ 1,304
Current liabilities 4,863 4,088
-----------------------------------------------------------
Working capital $ (3,031) $ (2,784)
===========================================================
Property, net $ 62,940 $ 68,385
Long-term debt $ 6,538 $ 9,808
Partners' capital $ 53,463 $ 55,927
ONEOK's investment $ 12,522 $ 13,832
Gross revenue $ 2,122 $ 1,741
Earnings (loss)before
income taxes $ (6,846) $ (6,123)
ONEOK's portion of earnings
(loss) before income taxes $ (1,796) $ (1,500)
-----------------------------------------------------------
</TABLE>
Effective April 28, 1995, Caney River Transmission Company, which owned a 25
percent interest in Ozark Gas Transmission System, was sold for its approximate
net book value. Earnings attributable to the Company's interest in Ozark
through the date of disposition and for the year ended August 31, 1994 were $.8
million and $.6 million, respectively. The Company's investment at August 31,
1994 was $10.2 million.
(D) LINES OF CREDIT AND SHORT-TERM NOTES PAYABLE
At August 31, 1995, the Company had a short-term unsecured credit agreement
with several banks pursuant to which the banks have agreed to make loans to the
Company from time to time in an aggregate amount not to exceed $125 million at
any one time for general corporate purposes. The short-term credit agreement
provides a back-up line of credit for short-term debt from other sources in
addition to providing short-term funds. The facility fee requirement for this
line of credit is .075 percent applied annually to the total line of credit.
Borrowings under the agreement bear interest at offshore IBOR rates plus .225
percent per annum. No compensating balance requirements existed at August 31,
1995.
Short-term notes payable totaling $55.2 million at August 31, 1995, and $50
million at August 31, 1994, were outstanding. The notes carried average
interest rates of 6.16 percent and 5.23 percent, respectively.
(E) LONG-TERM DEBT
All long-term notes payable at August 31, 1995, are unsecured. The aggregate
current maturities of long-term debt for each of the five years ending August
31, 2000, are $13.1 million; $15.1 million; $15.1 million; $13.1 million; and
$16.1 million, respectively, including $1.1 million each year callable at the
option of the holder.
<TABLE>
<CAPTION>
-------------------------------------------------------------
AUGUST 31, 1995 1994
(THOUSANDS OF DOLLARS)
-------------------------------------------------------------
<S> <C> <C>
Long-Term Notes Payable
4.50% due 1995 $ - $ 13,000
5.00% due 1996 12,000 12,000
5.57% due 1997 14,000 14,000
5.90% due 1998 10,000 10,000
6.20% due 1999 8,000 8,000
6.43% due 2000 5,000 5,000
8.32% due 2007 40,000 40,000
8.44% due 2004 40,000 40,000
8.70% due 2021 34,976 34,947
9.70% due 2019 125,000 125,000
9.75% due 2020 75,000 75,000
-------------------------------------------------------------
Total 363,976 376,947
Current maturities of
long-term debt 13,076 14,050
-------------------------------------------------------------
Long-term notes payable $ 350,900 $ 362,897
-------------------------------------------------------------
</TABLE>
Based on the expected current rates which would have been offered to the
Company for debt with the same terms and maturities, the estimated fair value
of the Company's long-term debt at August 31, 1995, was approximately $393
million.
Under the most restrictive covenants of the Company's loan agreements, $159.8
million (85 percent) of retained earnings at August 31, 1995, was available to
pay dividends.
38
<PAGE> 39
(F) CAPITAL STOCK
The holders of Series A preferred stock have full voting rights (two votes per
share) and may redeem those shares in whole or in part at any time at the
option of the Company. Holders are entitled to $53 per share, plus all
dividends accrued or in arrears thereon, upon voluntary redemption or
liquidation and $50 per share upon involuntary liquidation. No dividends were
in arrears at August 31, 1995.
The Company has authorized three million shares of preference stock, none of
which was outstanding at August 31, 1995, and approximately 28 million shares
of unrestricted common stock available for issue. The Board has reserved two
million shares of the Company's common stock for the Direct Stock Purchase and
Dividend Reinvestment Plan, effective September 1, 1995; 700,000 shares for the
ONEOK Inc. Stock Performance Plan, effective September 21, 1993; and
approximately two million shares for the Thrift Plan for Employees of ONEOK
Inc. and Subsidiaries, effective March 18, 1994.
During 1993, the Company issued common stock through two stock option plans
which provided certain officers and key employees options to purchase common
stock at a price not less than fair market value at date of grant. All options
for both of these plans were exercised during that year at prices ranging from
$14 to $16 per share.
The Board has a five-year Stock Performance Plan effective through 1996, which
provides for compensation of certain officers and key employees with common
stock and cash. During 1995, $1.9 million was expensed. During 1993, $2.0
million was expensed, and 55,946 shares of common stock were issued. No amounts
were expensed in fiscal 1994. It is the Company's intent to replace the
existing Stock Performance Plan, upon Shareholder approval of the ONEOK Inc.
Employee Stock Purchase Plan and the ONEOK Inc. Key Employee Stock Plan.
(G) INCOME TAXES
The provisions for income taxes are as follows:
<TABLE>
<CAPTION>
-----------------------------------------------------------------------------------------
FOR THE YEARS ENDED AUGUST 31, 1995 1994 1993
(THOUSANDS OF DOLLARS)
-----------------------------------------------------------------------------------------
<S> <C> <C> <C>
Current income taxes
Federal $ 34,837 $ 9,874 $ 19,575
State 5,775 1,201 3,230
-----------------------------------------------------------------------------------------
Total current income taxes $ 40,612 $ 11,075 $ 22,805
=========================================================================================
Deferred income taxes
Federal $ (13,007) $ 8,555 $ (1,391)
State (2,263) 1,466 (608)
-----------------------------------------------------------------------------------------
Total deferred income taxes $ (15,270) $ 10,021 $ (1,999)
=========================================================================================
</TABLE>
39
<PAGE> 40
Following is a reconciliation of the provision for income taxes.
<TABLE>
<CAPTION>
---------------------------------------------------------------------------------------
FOR THE YEARS ENDED AUGUST 31, 1995 1994 1993
(THOUSANDS OF DOLLARS)
---------------------------------------------------------------------------------------
<S> <C> <C> <C>
Pretax income $ 68,146 $ 57,277 $ 59,230
Federal statutory income tax rate 35.00% 35.00% 34.63%
---------------------------------------------------------------------------------------
Provision for federal income taxes 23,851 20,047 20,511
Amortization of distribution property
investment tax credits (739) (739) (739)
State income taxes, net of credits and
federal tax benefit 2,372 1,549 1,793
Other, net (142) 239 (759)
---------------------------------------------------------------------------------------
Actual income tax expense $ 25,342 $ 21,096 $ 20,806
=======================================================================================
</TABLE>
At August 31, 1995, the Company had $2.8 million in deferred investment tax
credits recorded in other deferred credits which will be amortized over the
next four years.
<TABLE>
<CAPTION>
---------------------------------------------------------------------------------------
AUGUST 31, 1995 1994
(THOUSANDS OF DOLLARS)
---------------------------------------------------------------------------------------
<S> <C> <C>
Deferred Tax Assets
Investment write-down $ 1,373 $ 1,325
Accrued liabilities not deductible until paid 5,099 562
Net operating loss carryforwards 800 810
Regulatory assets 5,518 3,627
Other 1,789 2,563
---------------------------------------------------------------------------------------
Total deferred tax assets 14,579 8,887
Valuation allowance for net operating loss
carry forwards expected to expire prior to
utilization 800 810
---------------------------------------------------------------------------------------
Net deferred tax assets 13,779 8,077
Deferred Tax Liabilities
Excess of tax over book depreciation and depletion 131,485 129,759
Investment in joint ventures 5,394 10,569
Regulatory assets 59,294 66,763
Other 3,496 1,964
---------------------------------------------------------------------------------------
Gross deferred tax liabilities 199,669 209,055
---------------------------------------------------------------------------------------
Net Deferred Tax Liabilities $ 185,890 $ 200,978
=======================================================================================
</TABLE>
The tax effects of temporary differences that gave rise to significant portions
of the deferred tax assets and liabilities are shown in the accompanying table.
The Company had remaining net operating loss carry-forwards for state income
tax purposes of approximately $14.1 million at August 31, 1995, which expire,
unless previously utilized, at various dates through the year 2009.
(H) EMPLOYEE BENEFIT PLANS
Retirement Plan. The Company has a defined benefit retirement plan covering
substantially all employees. Company officers and certain key employees are
also eligible to participate in a supplemental retirement plan.
Net pension costs, as determined by an independent actuary, included the
following:
<TABLE>
<CAPTION>
---------------------------------------------------------------------------------------
FOR THE YEARS ENDED AUGUST 31, 1995 1994 1993
(THOUSANDS OF DOLLARS)
---------------------------------------------------------------------------------------
<S> <C> <C> <C>
Service cost $ 6,078 $ 6,518 $ 5,760
Interest cost 22,659 20,599 20,409
Actual return on assets (27,438) (12,404) (31,286)
Net amortization and deferral 6,920 (6,761) 13,154
---------------------------------------------------------------------------------------
Net pension cost $ 8,219 $ 7,952 $ 8,037
=======================================================================================
</TABLE>
40
<PAGE> 41
The Company generally funds pension costs at a level at least equal to the
minimum amount required under the Employee Retirement Income Security Act of
1974. The accompanying table sets forth the funded status of the Company's
plans, as determined by the independent actuary.
<TABLE>
<CAPTION>
------------------------------------------------------------------------------------------
AUGUST 31, 1995 1994
(THOUSANDS OF DOLLARS)
------------------------------------------------------------------------------------------
<S> <C> <C>
Actuarial present value of vested benefit obligation $ (254,138) $ (237,548)
Accumulated benefit obligation $ (266,227) $ (249,815)
Projected benefit obligation $ (311,526) $ (299,012)
Plan assets at fair value, principally equity
securities and an IPG fund 269,180 250,398
------------------------------------------------------------------------------------------
Plan assets less than projected benefit obligation (42,346) (48,614)
Unrecognized net loss 59,172 67,701
Unrecognized prior service cost 672 821
Unrecognized net asset (4,206) (4,673)
------------------------------------------------------------------------------------------
Prepaid pension cost $ 13,292 $ 15,235
==========================================================================================
</TABLE>
The projected benefit obligation for 1995 and 1994 was determined using an
annual discount rate of 7.75 percent; a long- term rate of return on plan
assets of 9 percent; and an average assumed long-term annual rate of salary
increase of 5 percent.
Other Postretirement Benefit Plans. The Company sponsors a defined benefit
health care plan that provides postretirement medical benefits and life and
accidental death and dismemberment benefits to substantially all employees who
reach normal retirement age while working for the Company. The plan is
contributory, with retiree contributions adjusted periodically, and contains
other cost-sharing features such as deductibles and coinsurance. The Company
funds the cost of benefits as claims or premiums are paid.
The Company adopted SFAS No. 106, "Employers' Accounting for Postretirement
Benefits Other than Pensions," effective September 1, 1993, and elected to
delay recognition of the accumulated postretirement benefit obligation (APBO)
of approximately $72.2 million and amortize it over 20 years as a component of
net periodic postretirement benefit cost.
Net periodic postretirement benefit cost includes the following components:
<TABLE>
<CAPTION>
----------------------------------------------------------------------------------------
FOR THE YEARS ENDED AUGUST 31, 1995 1994
(THOUSANDS OF DOLLARS)
----------------------------------------------------------------------------------------
<S> <C> <C>
Service cost $ 1,820 $ 1,942
Interest cost 5,282 5,114
Net amortization and deferral 3,608 3,608
----------------------------------------------------------------------------------------
Net periodic postretirement benefit cost $ 10,710 $ 10,664
========================================================================================
</TABLE>
For measurement purposes, a 9.4 percent annual rate of increase in the per
capita cost of covered medical benefits (i.e., medical cost trend rate) was
assumed for 1995, the rate was assumed to decrease gradually to 5.0 percent by
the year 2003 and remain at that level thereafter. The medical cost trend rate
assumption has a significant effect on the amounts reported. For example,
increasing the assumed medical cost trend rate by one percentage point in each
year would increase the accumulated postretirement benefit obligation as of
August 31, 1995, by $10.4 million and the aggregate of the service and interest
cost components of net periodic postretirement benefit cost for the year ended
August 31, 1995, by $843,000.
The weighted average discount rate used in determining the accumulated
postretirement benefit obligation was 7.75 percent at August 31, 1995.
41
<PAGE> 42
The following table presents the plan's funded status reconciled with amounts
recognized in the Company's consolidated balance sheet.
<TABLE>
<CAPTION>
---------------------------------------------------------------------------------------
AUGUST 31, 1995 1994
(THOUSANDS OF DOLLARS)
---------------------------------------------------------------------------------------
<S> <C> <C>
Accumulated Postretirement Benefit Obligation
Retirees $ (48,164) $ (41,129)
Fully eligible active plan participants (4,176) (327)
Other active plan participants (22,868) (28,392)
---------------------------------------------------------------------------------------
Accumulated postretirement benefit obligation (75,208) (69,848)
Unrecognized transition obligation 64,949 68,557
Unrecognized net gain (6,050) (6,999)
---------------------------------------------------------------------------------------
Accrued postretirement benefit cost $ (16,309) $ (8,290)
=======================================================================================
</TABLE>
Employee Thrift Plan. The Company has a Thrift Plan covering all employees.
Employee contributions are discretionary. Subject to certain limits, employee
contributions are matched by the Company. The annual cost of the plan was $3.4
million in 1995; $3.7 million in 1994; and $3.8 million in 1993 .
Postemployment Benefits. The Company adopted SFAS No. 112, "Employers'
Accounting for Postemployment Benefits Other Than Pensions," effective
September 1, 1993. Postemployment benefits represent amounts payable to former
or inactive employees after employment but before retirement.
(I) SEGMENT INFORMATION
The Company conducts its business through four reporting segments: (1)
Distribution and transmission, which includes gathering, transmission, storage,
and distribution of natural gas, transportation of gas for others, and leasing
pipeline capacity. (2)Exploration and production includes exploring for,
producing, and selling natural gas and oil. (3) Gas processing operations,
which includes extracting and selling natural gas liquids and buying and
selling natural gas. (4) Other, which includes gas marketing, operating and
leasing the Company's headquarters building and a related parking facility, and
the Company's former contract drilling business, which was sold effective May
1, 1994.
42
<PAGE> 43
Following is information relative to the Company's operations in different
segments.
<TABLE>
<CAPTION>
DISTRIBUTION EXPLORATION
AND AND GAS
FOR THE YEARS ENDED AUGUST 31, TRANSMISSION PRODUCTION PROCESSING OTHER TOTAL
(MILLIONS OF DOLLARS)
- -----------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C>
1995
Sales to unaffiliated customers $599.5 $22.5 $ 96.6 $231.3 $ 949.9
Intersegment sales 1.8 2.4 7.4 68.6 80.2
- -----------------------------------------------------------------------------------------------------------
Total revenues $601.3 $24.9 $ 104.0 $299.9 $ 1,030.1
- -----------------------------------------------------------------------------------------------------------
Operating income (loss)
before income taxes $91.5 $3.6 $ 11.7 $(1.3) $ 105.5
Income tax expense 21.9 .5 4.0 (1.1) 25.3
Interest expense 32.9 2.0 1.0 1.5 37.4
- -----------------------------------------------------------------------------------------------------------
Net income (loss) $36.7 $1.1 $ 6.7 $(1.7) $ 42.8
- -----------------------------------------------------------------------------------------------------------
Earnings (loss) per share $1.35 $.04 $.25 $(.06) $1.58
Identifiable assets $1,023.0 $60.0 $25.2 $61.3 $1,169.5
Depreciation, depletion, and
amortization $38.1 $10.4 $1.8 $.4 $50.4
Capital expenditures $55.8 $25.0 $1.2 $1.0 $83.0
===========================================================================================================
- -----------------------------------------------------------------------------------------------------------
1994
Sales to unaffiliated customers $617.5 $23.0 $106.6 $ 45.3 $792.4
Intersegment sales 1.7 1.5 .6 97.8 101.6
- -----------------------------------------------------------------------------------------------------------
Total revenues $619.2 $24.5 $107.2 $ 143.1 $894.0
- -----------------------------------------------------------------------------------------------------------
Operating income (loss)
before income taxes $87.9 $ .7 $6.6 $(3.2) $92.0
Income tax expense 20.9 (.5) 2.0 (1.3) 21.1
Interest expense 31.3 1.6 .9 .9 34.7
- -----------------------------------------------------------------------------------------------------------
Net income (loss) $35.7 $(.4) $3.7 $(2.8) $36.2
- -----------------------------------------------------------------------------------------------------------
Earnings (loss) per share $1.32 $(.01) $.14 $(.11) $1.34
Identifiable assets $1,011.0 $42.7 $28.8 $54.5 $1,137.0
Depreciation, depletion, and
amortization $35.9 $12.2 $1.9 $.9 $50.9
Capital expenditures $62.2 $8.3 $2.7 $.7 $73.9
===========================================================================================================
- -----------------------------------------------------------------------------------------------------------
1993
Sales to unaffiliated customers $626.9 $24.1 $125.4 $12.7 $789.1
Intersegment sales 1.7 1.0 33.0 14.2 49.9
- -----------------------------------------------------------------------------------------------------------
Total revenues $628.6 $25.1 $158.4 $26.9 $839.0
- -----------------------------------------------------------------------------------------------------------
Operating income (loss)
before income taxes $84.8 $2.5 $ 10.9 $(1.7) $96.5
Income tax expense 18.0 .4 3.9 (1.5) 20.8
Interest expense 33.8 1.5 .8 1.2 37.3
- -----------------------------------------------------------------------------------------------------------
Net income (loss) $33.0 $ .6 $ 6.2 $(1.4) $38.4
- -----------------------------------------------------------------------------------------------------------
Earnings (loss) per share $1.23 $ .02 $ .23 $(0.5) $1.43
Identifiable assets $975.0 $49.3 $ 26.5 $53.7 $1,104.5
Depreciation, depletion, and
amortization $33.1 $10.9 $2.8 $1.2 $48.0
Capital expenditures $58.8 $24.9 $1.7 $.8 $86.2
===========================================================================================================
</TABLE>
43
<PAGE> 44
(J) COMMITMENTS AND CONTINGENCIES
Leases. The initial lease term on the Company's headquarters building, ONEOK
Plaza, is for 25 years, expiring in 2009, with six five-year renewal options.
At the end of the initial term or any renewal period, the Company can purchase
the property at its fair market value. Rent for the lease accrues annually at
$6.8 million a year until 2009. Rent payments were $5.8 million for 1995, 1994,
and 1993. Estimated future minimum rental payments for the lease are $5.8
million for each of the years ended August 31, 1996 through 1999, $7.6 million
for the year ended August 31, 2000, $9.3 million for each of the years ended
August 31, 2001 through 2009, $7.8 million for the year ended August 31, 2010,
and $6.2 million thereafter.
The Company has the right to sublet excess office space in ONEOK Plaza. The
Company received $2.4 million, $2.1 million, and $2.4 million in rental revenue
during 1995, 1994, and 1993, respectively, for various subleases. Estimated
minimum future rental payments to be received under existing contracts for
subleases are: $2.6 million in 1996; $2.2 million in 1997; $1.5 million in
1998; $1.3 million in 1999, $.7 million in 2000; and a total of $1.1 million
thereafter.
Other. The Company is involved in claims and legal actions arising in the
ordinary course of business. In the opinion of management, the ultimate
disposition of these matters will not have a materially adverse effect on the
Company's financial condition, results of operation, or cash flows.
(K) OIL AND GAS PRODUCING ACTIVITIES
The following is historical revenue and cost information relating to the
Company's exploration and production operations:
<TABLE>
<CAPTION>
----------------------------------------------------------------------------------------
(THOUSANDS OF DOLLARS) 1995 1994 1993
----------------------------------------------------------------------------------------
<S> <C> <C> <C>
Capitalized costs at end of year:
Unproved properties $ 5,030 $ 6,363 $ 8,216
Proved properties 111,459 94,507 87,315
----------------------------------------------------------------------------------------
Total Capitalized Costs 116,489 100,870 95,531
Accumulated depreciation, depletion,
and amortization 65,376 61,052 51,016
----------------------------------------------------------------------------------------
Net Capitalized Costs $ 51,113 $ 39,818 $ 44,515
========================================================================================
Costs incurred during the year:
Property acquisition costs (unproved) $ 926 $ 1,021 $ 1,938
Exploration costs $ 1,228 $ 2,731 $ 1,977
Development costs $ 4,839 $ 4,729 $ 4,379
Purchase of minerals in place $ 15,099 $ 101 $ 17,136
----------------------------------------------------------------------------------------
</TABLE>
44
<PAGE> 45
The accompanying schedule presents the results of operation for the Company's
oil and gas production activities. The results exclude general office overhead
and interest expense attributable to oil and gas production.
<TABLE>
<CAPTION>
---------------------------------------------------------------------------------------
(THOUSANDS OF DOLLARS) 1995 1994 1993
---------------------------------------------------------------------------------------
<S> <C> <C> <C>
Net revenues from production:
Sales to unaffiliated customers $ 18,427 $ 22,693 $ 24,058
Gas sold to affiliates 2,372 1,457 1,040
---------------------------------------------------------------------------------------
Net revenues from production 20,799 24,150 25,098
---------------------------------------------------------------------------------------
Production costs 4,565 4,912 4,883
Exploration expenses 680 1,419 1,946
Depreciation, depletion, and amortization 9,447 12,048 10,779
Income tax expense 2,265 2,097 2,718
---------------------------------------------------------------------------------------
Total expenses 16,957 20,476 20,326
---------------------------------------------------------------------------------------
Results of operations from
producing activities $ 3,842 $ 3,674 $ 4,772
=======================================================================================
</TABLE>
(L) OIL AND GAS RESERVES (UNAUDITED)
Following are estimates of the Company's proved oil and gas reserves, net of
royalty interests and changes therein, for the 1995, 1994, and 1993 fiscal
years.
<TABLE>
<CAPTION>
----------------------------------------------------------------------------------------
OIL GAS
PROVED RESERVES (MBBLS) (MMCF)
----------------------------------------------------------------------------------------
<S> <C> <C>
September 1, 1992 1,459 41,390
Revisions of prior estimates (567) (541)
Extensions, discoveries, and other additions 589 4,541
Purchases of minerals in place 1,801 1,827
Sales of minerals in place (7) (26)
Production (443) (8,401)
----------------------------------------------------------------------------------------
August 31, 1993 2,832 38,790
Revisions of prior estimates (201) (756)
Extensions, discoveries, and other additions 224 2,264
Purchases of minerals in place 1 115
Production (572) (8,043)
----------------------------------------------------------------------------------------
August 31, 1994 2,284 32,370
Revisions of prior estimates 579 83
Extensions, discoveries, and other additions 241 4,002
Purchases of minerals in place 637 11,931
Sales of minerals in place (28) (386)
Production (466) (8,774)
----------------------------------------------------------------------------------------
August 31, 1995 3,247 39,226
========================================================================================
Proved Developed Reserves:
August 31, 1993 2,352 34,792
August 31, 1994 1,943 29,193
August 31, 1995 3,068 36,946
----------------------------------------------------------------------------------------
</TABLE>
The Company emphasizes that the volumes of reserves shown above are estimates,
which, by their nature, are subject to later revision. The estimates are made
by the Company's petroleum engineers and geologists utilizing all available
geological and reservoir data as well as production performance data. These
estimates are reviewed annually and revised, either upward or downward, as
warranted by additional performance data.
45
<PAGE> 46
(M) DISCOUNTED FUTURE NET CASH FLOWS (UNAUDITED)
Estimates of the standard measure of discounted future cash flows from proved
reserves of oil and natural gas shown in the accompanying table are based on
prices at the end of the year. Gas prices are escalated only for fixed and
determinable amounts under provisions of applicable regulations in some
contracts. These estimated future cash flows are reduced by estimated future
development and production costs based on year-end cost levels, assuming
continuation of existing economic conditions, and by estimated future income
tax expense. This tax expense is calculated by applying the current year-end
statutory tax rates to pretax net cash flows (net of tax depreciation,
depletion, and lease amortization allowances) applicable to oil and gas
production.
<TABLE>
<CAPTION>
----------------------------------------------------------------------------------------
(THOUSANDS OF DOLLARS) 1995 1994 1993
----------------------------------------------------------------------------------------
<S> <C> <C> <C>
Future cash inflows $ 111,370 $ 98,270 $ 121,107
Future production and development costs 29,684 26,103 30,346
Future income tax expense 16,375 16,278 21,372
----------------------------------------------------------------------------------------
Future net cash flows 65,311 55,889 69,389
10% annual discount for estimated
timing of cash flows 17,484 15,660 20,761
----------------------------------------------------------------------------------------
Standardized measure of discounted future
net cash flows relating to oil and gas
reserves $ 47,827 $ 40,229 $ 48,628
========================================================================================
</TABLE>
The changes in standardized measure of discounted future net cash flows
relating to proved oil and gas reserves are as follows:
<TABLE>
<CAPTION>
----------------------------------------------------------------------------------------
(THOUSANDS OF DOLLARS) 1995 1994 1993
----------------------------------------------------------------------------------------
<S> <C> <C> <C>
Beginning of year $ 40,229 $ 48,628 $ 35,879
Changes resulting from:
Sales of oil and gas produced, net of
production costs (16,234) (19,238) (20,215)
Net changes in price, development, and
production costs (4,874) (3,839) 7,327
Extensions, discoveries, additions, and
improved recovery, less related costs 6,377 5,112 11,625
Purchases of minerals in place 14,707 126 20,365
Sales of minerals in place (871) - (87)
Revisions of previous quantity estimates 5,520 (2,379) (5,589)
Accretion of discount 5,107 6,360 4,747
Net change in income taxes (274) 3,260 (3,296)
Other, net (1,860) 2,199 (2,128)
----------------------------------------------------------------------------------------
End of year $ 47,827 $ 40,229 $ 48,628
========================================================================================
</TABLE>
46
<PAGE> 47
(N) QUARTERLY FINANCIAL DATA (UNAUDITED)
Among the quarters, total operating revenues are consistently greater from
November through May due to the large volume of natural gas sold to customers
for heating. A summary of the unaudited quarterly results of operations for
1995 and 1994 follows:
<TABLE>
<CAPTION>
-------------------------------------------------------------------------------------------------------------
Quarter
-------------------------------------------------------
1995 First Second Third Fourth
-------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C>
(Thousands of Dollars, Except Per Share Amounts)
Total operating revenues $166,268 $287,358 $304,498 $191,762
Income before interest and
income taxes $21,907 $55,937 $23,254 $4,415
Income taxes $4,835 $17,810 $4,811 $(2,114)
Net income (loss) $7,788 $28,287 $9,040 $(2,311)
Earnings (loss) per common share $.29 $1.05 $.33 $(.09)
Dividends per common share $.28 $.28 $.28 $.28
Weighted average shares
outstanding (thousands) 26,690 26,712 27,020 27,020
-------------------------------------------------------------------------------------------------------------
</TABLE>
<TABLE>
<CAPTION>
-------------------------------------------------------------------------------------------------------------
Quarter
-------------------------------------------------------
1994 First Second Third Fourth
-------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C>
(Thousands of Dollars, Except Per Share Amounts)
Total operating revenues $177,191 $295,444 $190,480 $129,268
Income before interest and
income taxes $21,386 $51,900 $16,606 $2,138
Income taxes $4,794 $16,518 $2,456 $(2,672)
Net income (loss) $7,812 $26,387 $5,692 $(3,710)
Earnings (loss) per common share $.29 $.98 $.21 $(.14)
Dividends per common share $.27 $.28 $.28 $.28
Weighted average shares
outstanding (thousands) 26,634 26,681 26,690 26,690
-------------------------------------------------------------------------------------------------------------
</TABLE>
(O) SUPPLEMENTAL CASH FLOW INFORMATION
<TABLE>
<CAPTION>
-----------------------------------------------------------------------------------------
(THOUSANDS OF DOLLARS) 1995 1994 1993
-----------------------------------------------------------------------------------------
<S> <C> <C> <C>
Cash Paid During the Year
Interest (including amount capitalized) $ 37,642 $ 34,694 $ 37,056
Income taxes $ 34,513 $ 14,948 $ 22,433
Noncash Transactions:
Gas received as payment in kind $ 86,033 $ 74,584 $ 77,663
Decrease in take-or-pay deferrals
reflected by decrease in take-or-pay
liabilities - - $ 20,000
Issuance of common stock related to:
Stock Performance Plan - $ 1,203 -
Acquisition of gas marketing
partnership $5,836 - -
-----------------------------------------------------------------------------------------
</TABLE>
47
<PAGE> 48
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE
None
PART III
ITEM 10. DIRECTORS, EXECUTIVE OFFICERS, PROMOTERS, AND CONTROL PERSONS OF THE
REGISTRANT
(A) DIRECTORS OF THE REGISTRANT
Information concerning the directors of the Company is shown in the 1995
definitive Proxy Statement, which is incorporated herein by this
reference.
(B) EXECUTIVE OFFICERS OF THE REGISTRANT
Information concerning the executive officers of the Company is included
in Part I of this Form 10-K.
(C) COMPLIANCE WITH SECTION 16(A) OF THE EXCHANGE ACT
Information on compliance with Section 16(a) of the Exchange Act is
included in the 1995 definitive Proxy Statement, which is incorporated
herein by this reference.
ITEM 11. EXECUTIVE COMPENSATION
Information on executive compensation is shown in the 1995 definitive Proxy
Statement, which is incorporated herein by this reference.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
(A) SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS
Information on security ownership of certain beneficial owners is shown
in the 1995 definitive Proxy Statement, which is incorporated herein by
this reference.
(B) SECURITY OWNERSHIP OF MANAGEMENT
Information on security ownership of directors and officers is shown in
the 1995 definitive Proxy Statement, which is incorporated herein by
this reference.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
None
48
<PAGE> 49
PART IV
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS ON FORM 8-K
(A) DOCUMENTS FILED AS A PART OF THIS REPORT
(1) Exhibits
(3)(a) Third Restated Certificate of Incorporation of ONEOK Inc.,
incorporated by reference from Form 10-K dated August 31, 1994.
(3)(b) By-Laws of ONEOK Inc. as Amended, incorporated by reference from
Form 10-K dated August 31, 1994.
(4)(a) Article "Fourth" of Third Restated Certificate of Incorporation
of ONEOK Inc. (Preferred Stock, Preference Stock, and Common
Stock), pages 48 through 70, incorporated by reference from Form
10-K dated August 31, 1994.
(4)(b) Indenture dated November 28, 1989, between ONEOK Inc. and
Security Pacific National Bank, incorporated by reference from
Form S-3 Registration Statement No. 33-31979.
(4)(c) Indenture and First Supplemental Indenture dated December 1,
1990, between ONEOK Inc. and Security Pacific National Bank,
incorporated by reference from Form 10-K dated August 31, 1991.
(4)(d) Second Supplemental Indenture dated October 1, 1991, between
ONEOK Inc. and Security Pacific National Bank, incorporated by
reference from Form 10-K dated August 31, 1991.
NOTE: Certain instruments defining the rights of holders of
long-term debt are not being filed as exhibits hereto pursuant
to Item 601(b)(4)(iii) of Regulation S-K. The Company agrees to
furnish copies of such agreements to the SEC upon request.
(4)(e) Rights Agreement between ONEOK Inc. and Chase Manhattan Bank, N.
A. dated March 31, 1988, incorporated by reference from Form 8-A
Registration Statement dated March 1988.
(10)(a) ONEOK Inc. Stock Performance Plan, incorporated by reference
from the 1991 Definitive Proxy Statement.
(10)(b) Unfunded Excess Benefit Plan of ONEOK Inc., incorporated by
reference from the 1991 Definitive Proxy Statement.
(10)(c) Termination Agreement between ONEOK Inc. and ONEOK Inc.
Executives dated January 20, 1984, incorporated by reference
from Form 10-K dated August 31, 1984.
(10)(d) Indemnification Agreement between ONEOK Inc. and ONEOK Inc.
Officers and Directors, incorporated by reference from Form 10-K
dated August 31, 1987.
(10)(e) Ground Lease Between ONEOK Leasing Company and Southwestern
Associates dated May 15, 1983, incorporated by reference from
Form 10-K dated August 31, 1983.
49
<PAGE> 50
(10)(f) First Amendment to Ground Lease between ONEOK Leasing Company
and Southwestern Associates dated October 1, 1984, incorporated
by reference from Form 10-K dated August 31, 1984.
(10)(g) Sublease Between RMZ Corp. and ONEOK Leasing Company dated May
15, 1983, incorporated by reference from Form 10-K dated August
31, 1983.
(10)(h) First Amendment to Sublease between RMZ Corp. and ONEOK Leasing
Company dated October 1, 1984, incorporated by reference from
Form 10-K dated August 31, 1984.
(10)(i) ONEOK Leasing Company Lease Agreement with Oklahoma Natural Gas
Company dated August 31, 1984, incorporated by reference from
Form 10-K dated August 31, 1985.
(10)(j) Credit Agreement between ONEOK Inc. and Bank of America National
Trust and Savings Association, dated August 20, 1993,
incorporated by reference from Form 10-K dated August 31, 1994.
(10)(k) First Amendment to Credit Agreement between ONEOK Inc. and Bank
of America National Trust and Savings Association, dated August
18, 1994, incorporated by reference from Form 10-K dated August
31, 1994.
(10)(l) Second Amendment to Credit Agreement between ONEOK Inc. and Bank
of America National Trust and Savings Association, dated August
17, 1995, filed herewith on pages 56 through 63.
(10)(m) Private Placement Agreement between ONEOK Inc. and Paine Webber
Incorporated, dated April 6, 1993, (Medium-Term Notes, Series A,
up to U.S. $150,000,000), incorporated by reference from Form
10-K dated August 31, 1993.
(10)(n) Issuing and Paying Agency Agreement between Bank America Trust
Company of New York, as Issuing and Paying Agent, and ONEOK Inc.
(Medium-Term Notes, Series A, up to U.S. $150,000,000),
incorporated by reference from Form 10-K dated August 31, 1993.
(21) Required information concerning the registrant's subsidiaries is
included in Item 1. of this Form 10-K.
(24) Independent Auditors' Consent, filed herewith on page 64.
(99)(a) History of Gas Pricing, incorporated by reference from Form 10-K
dated August 31, 1993.
(99)(b) Joint Stipulation, Cause No. PUD 940000477, Oklahoma Corporation
Commission (June 1, 1995), incorporated by reference from Form
8-K dated June 19, 1995.
50
<PAGE> 51
<TABLE>
<CAPTION>
Page No.
<S> <C> <C>
(2) Financial Statements
(a) Independent Auditors' Report 30
(b) Consolidated Statements of Income for the
years ended August 31, 1995, 1994, and 1993 31
(c) Consolidated Balance Sheets at August 31, 1995 and 1994 32 - 33
(d) Consolidated Statements of Cash Flows for the
years ended August 31, 1995, 1994, and 1993 34
(e) Consolidated Statements of Shareholders'Equity
for the years ended August 31, 1995, 1994, and 1993. 35
(f) Notes to Consolidated Financial Statements 36 - 47
</TABLE>
(3) Financial Statement Schedules
None.
(B) REPORTS ON FORM 8-K
Three reports on Form 8-K were filed by the Company during the last
quarter of the 1995 fiscal year or prior to the filing of this Form
10-K. The first Form 8-K was dated June 19, 1995, and reported the
settlement of the Company's rate proceeding. The second Form 8-K was
dated July 20, 1995, and reported the election of two new members to the
Board of Directors.
The third Form 8-K was dated July 21, 1995, and reported that Moody's
Investors Service raised the senior debt ratings of ONEOK Inc. to A3
from Baa1.
There were no financial statements filed with any of these Forms 8-K.
OTHER MATTERS
For the purpose of complying with the amendments to the rules governing Form
S-8 (effective July 13, 1990) under the Securities Act of 1933, the undersigned
registrant hereby undertakes as follows, which undertaking shall be
incorporated by reference in registrant's Registration Statements on Form S-8,
Registration Nos. 33-38059 (filed December 3, 1990), 33-52733 (filed March 18,
1994), and 33-69062 (filed September 21, 1993):
Insofar as indemnification for liabilities arising under the Securities
Act of 1933 may be permitted to directors, officers, and controlling
persons of the registrant pursuant to the foregoing provisions, or
otherwise, the registrant has been advised that in the opinion of the
Securities and Exchange Commission such indemnification is against
public policy as expressed in the Act and is, therefore, unenforceable.
In the event that a claim for indemnification against such liabilities
(other than the payment by the registrant of expenses incurred or paid
by a director, officer, or controlling person of the registrant in the
successful defense of any action, suit, or proceeding) is asserted by
such director, officer, or controlling person in connection with the
securities being registered, the registrant will, unless in the opinion
of its Counsel the matter has been settled by a controlling precedent,
submit to a court of appropriate jurisdiction the question whether such
indemnification by it is against public policy as expressed by the Act
and will be governed by the final adjudication of such issue.
51
<PAGE> 52
SIGNATURE
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange
Act of 1934, the registrant has duly caused this report to be signed on its
behalf by the undersigned, thereunto duly authorized, on this 19th day of
October, 1995.
ONEOK Inc.
Registrant
By: J. D. NEAL
-----------------------
J. D. Neal
Vice President, Chief Financial Officer,
and Treasurer (Principal Financial and
Accounting Officer)
52
<PAGE> 53
SIGNATURE
Pursuant to the requirements of the Securities Exchange Act of 1934,this report
has been signed below by the following persons on behalf of the registrant and
in the capacities indicated, on the 19th day of October, 1995.
<TABLE>
<S> <C>
LARRY W. BRUMMETT J. D. NEAL
- --------------------------------- ----------------------------------
Larry W. Brummett J. D. Neal
Chairman of the Board, Vice President, Chief
President, Chief Executive Financial Officer, and
Officer, and Director Treasurer (Principal Financial
and Accounting Officer)
E. G. ANDERSON D. A. NEWSOM
- --------------------------------- ----------------------------------
E. G. Anderson D. A. Newsom
Director Director
W. M. BELL G. D. PARKER
- --------------------------------- ----------------------------------
W. M. Bell G. D. Parker
Director Director
D. R. CUMMINGS J. D. SCOTT
- --------------------------------- ----------------------------------
D. R. Cummings J. D. Scott
Director Director
W. L. FORD
- --------------------------------- ----------------------------------
W. L. Ford G. R. Williams
Director Director
J. M. GRAVES S. L. YOUNG
- --------------------------------- ----------------------------------
J. M. Graves S. L. Young
Director Director
S. J. JATRAS
- ---------------------------------
S. J. Jatras
Director
D. L. KYLE
- ---------------------------------
D. L. Kyle
Director
B. H. MACKIE
- ---------------------------------
B. H. Mackie
Director
</TABLE>
53
<PAGE> 54
EXHIBITS INDEX
<TABLE>
<S> <C>
(3)(a) Third Restated Certificate of Incorporation of ONEOK Inc.,
incorporated by reference from Form 10-K dated August 31, 1994.
(3)(b) By-Laws of ONEOK Inc. as Amended, incorporated by reference from
Form 10-K dated August 31, 1994.
(4)(a) Article "Fourth" of Third Restated Certificate of Incorporation
of ONEOK Inc. (Preferred Stock, Preference Stock, and Common
Stock), pages 48 through 70, incorporated by reference from Form
10-K dated August 31, 1994.
(4)(b) Indenture dated November 28, 1989, between ONEOK Inc. and
Security Pacific National Bank, incorporated by reference from
Form S-3 Registration Statement No. 33-31979.
(4)(c) Indenture and First Supplemental Indenture dated December 1,
1990, between ONEOK Inc. and Security Pacific National Bank,
incorporated by reference from Form 10-K dated August 31, 1991.
(4)(d) Second Supplemental Indenture dated October 1, 1991, between
ONEOK Inc. and Security Pacific National Bank, incorporated by
reference from Form 10-K dated August 31, 1991.
NOTE: Certain instruments defining the rights of holders of
long-term debt are not being filed as exhibits hereto pursuant
to Item 601(b)(4)(iii) of Regulation S-K. The Company agrees to
furnish copies of such agreements to the SEC upon request.
(4)(e) Rights Agreement between ONEOK Inc. and Chase Manhattan Bank, N.
A. dated March 31, 1988, incorporated by reference from Form 8-A
Registration Statement dated March 1988.
(10)(a) ONEOK Inc. Stock Performance Plan, incorporated by reference
from the 1991 Definitive Proxy Statement.
(10)(b) Unfunded Excess Benefit Plan of ONEOK Inc., incorporated by
reference from the 1991 Definitive Proxy Statement.
(10)(c) Termination Agreement between ONEOK Inc. and ONEOK Inc.
Executives dated January 20, 1984, incorporated by reference
from Form 10-K dated August 31, 1984.
(10)(d) Indemnification Agreement between ONEOK Inc. and ONEOK Inc.
Officers and Directors, incorporated by reference from Form 10-K
dated August 31, 1987.
(10)(e) Ground Lease Between ONEOK Leasing Company and Southwestern
Associates dated May 15, 1983, incorporated by reference from
Form 10-K dated August 31, 1983.
(10)(f) First Amendment to Ground Lease between ONEOK Leasing Company
and Southwestern Associates dated October 1, 1984, incorporated
by reference from Form 10-K dated August 31, 1984.
(10)(g) Sublease Between RMZ Corp. and ONEOK Leasing Company dated May
15, 1983, incorporated by reference from Form 10-K dated August
31, 1983.
(10)(h) First Amendment to Sublease between RMZ Corp. and ONEOK Leasing
Company dated October 1, 1984, incorporated by reference from
Form 10-K dated August 31, 1984.
</TABLE>
54
<PAGE> 55
<TABLE>
<S> <C>
(10)(i) ONEOK Leasing Company Lease Agreement with Oklahoma Natural Gas
Company dated August 31, 1984, incorporated by reference from
Form 10-K dated August 31, 1985.
(10)(j) Credit Agreement between ONEOK Inc. and Bank of America National
Trust and Savings Association, dated August 20, 1993,
incorporated by reference from Form 10-K dated August 31, 1994.
(10)(k) First Amendment to Credit Agreement between ONEOK Inc. and Bank
of America National Trust and Savings Association, dated August
18, 1994, incorporated by reference from Form 10-K dated August
31, 1994.
(10)(l) Second Amendment to Credit Agreement between ONEOK Inc. and Bank
of America National Trust and Savings Association, dated August
17, 1995, filed herewith on pages 56 through 63.
(10)(m) Private Placement Agreement between ONEOK Inc. and Paine Webber
Incorporated, dated April 6, 1993, (Medium-Term Notes, Series A,
up to U.S. $150,000,000), incorporated by reference from Form
10-K dated August 31, 1993.
(10)(n) Issuing and Paying Agency Agreement between Bank America Trust
Company of New York, as Issuing and Paying Agent, and ONEOK Inc.
(Medium-Term Notes, Series A, up to U.S. $150,000,000),
incorporated by reference from Form 10-K dated August 31, 1993.
(21) Required information concerning the registrant's subsidiaries is
included in Item 1. of this Form 10-K.
(24) Independent Auditors' Consent, filed herewith on page 64.
(99)(a) History of Gas Pricing, incorporated by reference from Form 10-K
dated August 31, 1993.
(99)(b) Joint Stipulation, Cause No. PUD 940000477, Oklahoma Corporation
Commission (June 1, 1995), incorporated by reference from Form
8-K dated June 19, 1995.
</TABLE>
55
<PAGE> 1
Exhibit (10)(l)
SECOND AMENDMENT TO CREDIT AGREEMENT
THIS SECOND AMENDMENT TO CREDIT AGREEMENT IS MADE AND DATED AS OF AUGUST
17, 1995 (THE "AMENDMENT") among ONEOK Inc., a Delaware corporation (the
"COMPANY"), the financial institutions (the "EXISTING BANKS") party to the
Credit Agreement and the new financial institutions (the "NEW BANKS")
(collectively, the "BANKS") referred to below, and BANK OF AMERICA NATIONAL
TRUST AND SAVINGS ASSOCIATION, as Agent (the "AGENT"), and amends that certain
Credit Agreement dated as of August 20, 1993, and the First Amendment dated as
of August 18, 1994, among the Company, the Banks and the Agent (as so amended
or modified from time to time, the "CREDIT AGREEMENT").
RECITALS
WHEREAS, the Company has requested that the Credit Agreement be amended
and that the New Banks be added as lenders, the Aggregate Commitment be reduced
and that the Commitments be adjusted, and the Banks and the Agent are willing
to do so on the terms and conditions set forth herein.
NOW, THEREFORE, for good and valuable consideration, the receipt and
adequacy of which are hereby acknowledged, the parties hereby agree as follows:
1. Terms. All terms used herein shall have the same meanings as in
the Credit Agreement unless otherwise defined herein. All references to the
Credit Agreement shall mean the Credit Agreement as hereby amended.
2. Amendments to Credit Agreement.
2.1 Add a new Section 2.1(a) as follows:
Section 2.1 (a) Additional Banks. (a) On the effective date (when
all conditions precedent set forth in Section 4 hereof have been met) each
Additional Bank and each Existing Bank shall purchase or sell, as the case may
be, such an interest in the Loans outstanding as is required to give each Bank
its share of the Aggregate Commitment indicated on Schedule 1.1 hereto.
2.2 Schedules 1.1 and 3 attached to the Credit Agreement shall
be deleted and Schedule 1.1 and 3 attached to this Second Amendment shall be
inserted in lieu thereof.
2.3 The definition of "Maturity Date" in Section 1.1 of the
Credit Agreement is hereby amended by deleting "August 17, 1995" and inserting
"August 15, 1996" in lieu thereof.
2.4 The definition of "Offshore Applicable Margin" in Section
1.1 of the Credit Agreement shall be amended and restated in its entirety as
follows:
"Offshore Applicable Margin" means, with respect to Offshore Rate
Loans, 0.225% per annum."
2.5 Section 2.10(b) shall be amended by substituting the words
"facility fee" for the words "commitment fee" wherever they appear in this
Section and by amending and restating the first sentence thereof in its
entirety as follows:
"The Company shall pay to the Agent a facility fee on the
Aggregate Commitment, computed on a quarterly basis in arrears on the last
Business Day of each calendar quarter, equal to .075% per annum to be
distributed to each Bank in accordance with its Pro Rata Share."
56
<PAGE> 2
2.6 Section 5.5 shall be amended by deleting "August 31, 1993"
and inserting "August 31, 1994" and by deleting "November 30, 1993, February
28, 1994 and May 31, 1994" and inserting "November 30, 1994, February 28, 1995
and May 31, 1995" in lieu thereof.
2.7 Section 5.11(b) shall be amended by deleting "August 31,
1993" and inserting "August 31, 1994" in lieu thereof.
3. Representations and Warranties. Company represents and warrants
to Banks and Agent that, on and as of the date hereof, and after giving effect
to this Amendment:
3.1 Authorization. The execution, delivery and performance of
this Amendment have been duly authorized by all necessary corporate action by
the Company and this Amendment has been duly executed and delivered by the
Company.
3.2 Binding Obligation. This Amendment is the legal, valid and
binding obligation of Company, enforceable against the Company in accordance
with its terms.
3.3 No Legal Obstacle to Credit Agreement. The execution,
delivery and performance of this Amendment will not (a) contravene the terms of
the Company's certificate of incorporation, by-laws or other organization
document; (b) conflict with or result in any breach or contravention of the
provisions of any contract to which the Company is a party, or the violation of
any law, judgment, decree or governmental order, rule or regulation applicable
to Company, or result in the creation under any agreement or instrument of any
security interest, lien, charge, or encumbrance upon any of the assets of the
Company. No approval or authorization of any governmental authority is required
to permit the execution, delivery or performance by the Company of this
Amendment, or the transactions contemplated hereby.
3.4 Incorporation of Certain Representations. The
representations and warranties of the Company set forth in Section 5 of the
Credit Agreement are true and correct in all respects on and as of the date
hereof as though made on and as of the date hereof.
3.5 Default. No Default or Event of Default under the Credit
Agreement has occurred and is continuing.
4. Conditions, Effectiveness. The effectiveness of this Amendment shall
be subject to the compliance by the Company with its agreements herein
contained, and to the delivery of the following to the Agent in form and
substance satisfactory to the Agent and the Banks:
4.1 Authorized Signatories. A certificate, signed by the
Secretary or an Assistant Secretary of Company and dated the date of this
Amendment, as to the incumbency of the person or persons authorized to execute
and deliver this Amendment and any instrument or agreement required hereunder
on behalf of Company.
4.2 Other Evidence. Such other evidence with respect to the
Company or any other person as the Agent or any Bank may reasonably request in
connection with this Amendment and the compliance with the conditions set forth
herein.
5. Miscellaneous.
5.1 Effectiveness of the Credit Agreement and the Loan
Documents. Except as hereby expressly amended, the Credit Agreement and each
other Loan Document shall each remain in full force and effect, and are hereby
ratified and confirmed in all respects on and as of the date hereof.
57
<PAGE> 3
5.2 Waivers. This Amendment is limited solely to the matters
expressly set forth herein and is specific in time and in intent and does not
constitute, nor should it be construed as, a waiver or amendment of any other
term or condition, right, power or privilege under the Credit Agreement, the
Loan Documents, or under any agreement, contract, indenture, document or
instrument mentioned therein; nor does it preclude or prejudice any rights of
the Agent or the Banks thereunder, or any exercise thereof or the exercise of
any other right, power or privilege, nor shall it require the Requisite Banks
to agree to an amendment, waiver or consent for a similar transaction or on a
future occasion, nor shall any future waiver of any right, power, privilege or
default hereunder, or under any agreement, contract, indenture, document or
instrument mentioned in the Credit Agreement, constitute a waiver of any other
default of the same or of any other term or provision.
5.3 Counterparts. This Amendment may be executed in any
number of counterparts and all of such counterparts taken together shall be
deemed to constitute one and the same instrument. This Amendment shall not
become effective until the Company, the Banks and the Agent shall have signed a
copy hereof, whether the same or counterparts, and the same shall have been
delivered to the Agent.
5.4 Jurisdiction. This Amendment shall be governed by and
construed under the laws of the State of California.
58
<PAGE> 4
IN WITNESS WHEREOF, the parties hereto have caused this Amendment to be
duly executed and delivered as of the date first written above.
ONEOK Inc.
By: JERRY D. NEAL
Name: Jerry D. Neal
Title: Vice President, Treasurer,
Chief Financial Officer, and
Chief Accounting Officer
BANK OF AMERICA NATIONAL TRUST AND
SAVINGS ASSOCIATION, as Agent
By: PEGGY FUJIMOTO
Vice President
BANK OF AMERICA NATIONAL TRUST AND
SAVINGS ASSOCIATION, as a Bank
By: VANESSA SHEH MEYER
Vice President
TEXAS COMMERCE BANK NATIONAL
ASSOCIATION
By: DALE S. HURD
Title: SVP
THE BANK OF NOVA SCOTIA
By: A. S. NORSWOTTHY
A. S. Norsworthy
Title: Assistant Agent
MELLON BANK, N.A.
By: SCOTT HENNESSEE
Title: Assistant Vice President
BANK OF OKLAHOMA, N.A.
By: JANE FAULKENBERRY
Title: Vice President
(Signatures continue)
59
<PAGE> 5
BANK IV OKLAHOMA N.A.
By: GLENN ELROD
Title: Senior V.P.
BOATMEN'S FIRST NATIONAL BANK
OF OKLAHOMA
By: LINDA W. PARRISH
Title: Vice President
LIBERTY BANK & TRUST COMPANY OF
OKLAHOMA CITY, N.A.
By: SCOTT F. HAMILTON
Title: Scott F. Hamilton - Vice President
LIBERTY BANK & TRUST CO.
OF TULSA, N.A.
By: ROBERT D. MATTAX
Title: Vice President
THE STILLWATER NATIONAL BANK AND
TRUST COMPANY
By: ROBERT L. MCCORMICK
Title: CEO
CITIZENS BANK OF LAWTON
By: DAN TORBETT
Title: EVP
WESTAR BANK OF BARTLESVILLE
By: DAVID KEDY
Title: Senior Vice President
60
<PAGE> 6
SCHEDULE 1.1
COMMITMENTS
AND PRO RATA SHARES
<TABLE>
<CAPTION>
- ------------------------------------------------------------------------------------------------
PRO RATA
BANK COMMITMENT SHARE
- ------------------------------------------------------------------------------------------------
<S> <C> <C>
Bank of America National Trust
and Savings Association $30,500,000 24.40%
Texas Commerce Bank
National Association 20,500,000 16.40
The Bank of Nova Scotia 15,000,000 12.00
Mellon Bank, N.A. 10,000,000 8.00
Bank of Oklahoma, N.A. 11,500,000 9.20
Bank IV Oklahoma, N.A. 11,500,000 9.20
Boatmen's First National Bank
of Oklahoma 11,500,000 9.20
Liberty Bank & Trust Company
of Oklahoma City, N.A. 6,500,000 5.20
Liberty Bank & Trust Co.
of Tulsa, N.A. 5,000,000 4.00
The Stillwater National Bank
and Trust Company 1,000,000 0.80
Citizens Bank of Lawton 1,000,000 0.80
Westar Bank of Bartlesville 1,000,000 0.80
- ------------------------------------------------------------------------------------------------
TOTAL: $125,000,000 100.00%
- ------------------------------------------------------------------------------------------------
</TABLE>
61
<PAGE> 7
SCHEDULE 3
OFFSHORE AND DOMESTIC LENDING OFFICES
ADDRESSES FOR NOTICES
<TABLE>
<S> <C>
DONNA GERMAN ROBERT D. MATTAX
Texas Commerce Bank N.A. Liberty Bank & Trust Company of Tulsa
P.O. Box 660197 Fourth Floor
Dallas, TX 75266-0197 15 East Fifth Street
Phone: (214) 922-2540 Tulsa, OK 74103
Fax: (214) 922-2389 Phone: (918) 586-5179
Fax: (918) 586-5952
JANE A. FAULKENBERRY LAUREN BIACHI
Bank of Oklahoma The Bank of Nova Scotia
Eighth Floor Atlanta Agency
One Williams Center 600 Peachtree Street N.E., Suite 2700
Tulsa, OK 74172 Atlanta, GA 30308
Phone: (918) 588-6272 Phone: (404) 877-1500
Fax: (918) 588-6880 Fax: (404) 888-8998
LAURA L. CHRISTOFFERSON SCOTT HENNESSEE
Liberty National Bank and Trust Company Mellon Bank
100 North Broadway One Mellon Bank Center
Oklahoma City, OK 73102 Pittsburgh, PA 15258
Phone: (405) 231-6853 Phone: (412) 234-4458
Fax: (405) 231-6788 Fax: (412) 234-6375
GLENN A. ELROD VANESSA SHEH MEYER
Senior Vice President Vice President
Bank IV Bank of America NT&SA (Lender)
P.O. Box 2360 555 South Flower Street
Tulsa, OK 74101-2360 Los Angeles, CA 90071
Phone: (918) 591-8388 Phone: (213) 228-9737
Fax: (918) 591-8487 Fax: (213) 228-4062
LINDA W. PARISH PEGGY FUJIMOTO
Boatmen's First National Bank of Oklahoma Bank of America NT&SA (Agent)
9 East 4th Street Agency Management Services #5596
Tulsa, OK 74103 1455 Market Street
Phone: (918) 599-8105 San Francisco, CA 94103
Fax: (918) 585-3914 Phone: (415) 622-4469
Fax: (415) 622-4894
</TABLE>
62
<PAGE> 8
<TABLE>
<S> <C>
DAN TORBETT ROBERT L. MCCORMICK, JR.
Citizens Bank, Lawton, Oklahoma The Stillwater National Bank &
1420 W. Lee Boulevard Trust Company
Lawton, OK 73501 608 South Main Street
Phone: (405) 250-4145 Stillwater, OK 74076
Fax: (405) 250-4343 Phone: (405) 372-2230
Fax: (405) 377-3808
DAVID KEDY
WestStar Bank
100 South East Frank Phillips Blvd.
Bartlesville, OK 74003
Phone: (918) 337-3000
Fax: (918) 337-3506
</TABLE>
63
<PAGE> 1
EXHIBIT (24)
INDEPENDENT AUDITORS' CONSENT
The Board of Directors
ONEOK Inc.:
We consent to incorporation by reference in the Registration Statement Nos.
33-38059, 33-52733, and 33-69062 on Form S-8 and Nos. 33-61637 and 33-58555 on
Form S-3 of ONEOK Inc. of our report dated October 19, 1995, relating to the
consolidated balance sheets of ONEOK Inc.and subsidiaries as of August 31, 1995
and 1994, and the related consolidated statements of income, shareholders'
equity, and cash flows for each of the years in the three-year period ended
August 31, 1995, which report appears in the August 31, 1995 annual report on
Form 10-K of ONEOK Inc. Our report refers to a change in the method of
accounting for certain postemployment and postretirement benefit obligations
in 1994.
KPMG Peat Marwick LLP
Tulsa, Oklahoma
October 26, 1995
64
<TABLE> <S> <C>
<ARTICLE> 5
<LEGEND>
THIS SCHEDULE CONTAINS SUMMARY FINANCIAL INFORMATION EXTRACTED FROM THE
CONSOLIDATED STATEMENT OF EARNINGS FOR THE FISCAL YEAR ENDED AUGUST 31, 1995,
AND THE CONSOLIDATED BALANCE SHEET AT AUGUST 31, 1995, FOR ONEOK INC. AND
SUBSIDIARIES AND IS QUALIFIED IN ITS ENTIRETY BY REFERENCE TO SUCH FINANCIAL
STATEMENTS.
</LEGEND>
<MULTIPLIER> 1,000
<S> <C>
<PERIOD-TYPE> YEAR
<FISCAL-YEAR-END> AUG-31-1995
<PERIOD-START> SEP-01-1994
<PERIOD-END> AUG-31-1995
<CASH> 12,461
<SECURITIES> 0
<RECEIVABLES> 81,805
<ALLOWANCES> 0
<INVENTORY> 82,123
<CURRENT-ASSETS> 194,079
<PP&E> 1,275,743
<DEPRECIATION> 509,833
<TOTAL-ASSETS> 1,169,465
<CURRENT-LIABILITIES> 173,988
<BONDS> 0
<COMMON> 201,404
0
9,000
<OTHER-SE> 187,225
<TOTAL-LIABILITY-AND-EQUITY> 1,169,465
<SALES> 0
<TOTAL-REVENUES> 949,886
<CGS> 0
<TOTAL-COSTS> 844,373
<OTHER-EXPENSES> 0
<LOSS-PROVISION> 0
<INTEREST-EXPENSE> 37,367
<INCOME-PRETAX> 68,146
<INCOME-TAX> 25,342
<INCOME-CONTINUING> 42,804
<DISCONTINUED> 0
<EXTRAORDINARY> 0
<CHANGES> 0
<NET-INCOME> 42,804
<EPS-PRIMARY> 1.58
<EPS-DILUTED> 1.58
</TABLE>
