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FORM 10-K
UNITED STATES SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, DC 20549
[X] ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT
OF 1934 FOR THE FISCAL YEAR ENDED DECEMBER 31, 1999
OR
[ ] Transition Report Pursuant to Section 13 or 15(d) of the Securities Exchange
Act of 1934 For the transition period from to
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Commission Registrant; State of Incorporation; IRS Employer
File Number Address; and Telephone Number Identification No.
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1-9513 CMS ENERGY CORPORATION 38-2726431
(A Michigan Corporation)
Fairlane Plaza South, Suite 1100
330 Town Center Drive, Dearborn, Michigan 48126
(313)436-9200
1-5611 CONSUMERS ENERGY COMPANY 38-0442310
(A Michigan Corporation)
212 West Michigan Avenue, Jackson, Michigan 49201
(517)788-0550
1-2921 PANHANDLE EASTERN PIPE LINE COMPANY 44-0382470
(A Delaware Corporation)
5444 Westheimer Road, P.O. Box 4967, Houston, Texas 77210-4967
(713)989-7000
SECURITIES REGISTERED PURSUANT TO SECTION 12(b) OF THE ACT:
Name of Each Exchange
Registrant Title of Class on Which Registered
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CMS ENERGY CORPORATION Common Stock, $.01 par value New York Stock Exchange
8.75% Adjustable Convertible Trust Securities New York Stock Exchange
CONSUMERS ENERGY COMPANY Preferred Stocks, $100 par value: $4.16 Series, $4.50 Series New York Stock Exchange
CONSUMERS POWER
COMPANY FINANCING I 8.36% Trust Originated Preferred Securities New York Stock Exchange
CONSUMERS ENERGY
COMPANY FINANCING II 8.20% Trust Originated Preferred Securities New York Stock Exchange
CONSUMERS ENERGY
COMPANY FINANCING III 9.25% Trust Originated Preferred Securities New York Stock Exchange
SECURITIES REGISTERED PURSUANT TO SECTION 12(g) OF THE ACT: None
Indicate by check mark whether the Registrants (1) have 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
Registrants were required to file such reports), and (2) have been subject to
such filing requirements for the past 90 days. Yes X No
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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 Registrants' 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. [ ]
Panhandle Eastern Pipe Line Company meets the conditions set forth in General
Instructions I(1)(a) and (b) of Form 10-K and is therefore filing this Form 10-K
with the reduced disclosure format. Items 4, 6, 10, 11, 12 and 13 have been
omitted and Items 1, 2 and 7 have been reduced in accordance with Instruction I.
The aggregate market value of CMS Energy voting and non-voting common equity
held by non-affiliates was $1,846,266,321 for the 110,224,855 CMS Energy Common
Stock shares outstanding on February 29, 2000.
On February 29, 2000, CMS Energy held all voting and non-voting common equity of
Consumers and Panhandle.
Documents incorporated by reference: CMS Energy's proxy statement and Consumers
information statement relating to the 2000 annual meeting of shareholders to be
held May 26, 2000, are incorporated by reference in Part III, except for the
organization and compensation committee report contained therein.
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CMS ENERGY CORPORATION
AND
CONSUMERS ENERGY COMPANY
AND
PANHANDLE EASTERN PIPE LINE COMPANY
ANNUAL REPORTS ON FORM 10-K TO THE SECURITIES
AND EXCHANGE COMMISSION FOR THE YEAR
ENDED DECEMBER 31, 1999
This combined Form 10-K is separately filed by CMS Energy Corporation, Consumers
Energy Company and Panhandle Eastern Pipe Line Company. Information contained
herein relating to each individual registrant is filed by such registrant on its
own behalf. Accordingly, except for its subsidiaries, Consumers Energy Company
and Panhandle Eastern Pipe Line Company make no representation as to information
relating to any other companies affiliated with CMS Energy Corporation.
TABLE OF CONTENTS
Page
----
Glossary .................................................................................. 3
PART I:
Item 1. Business.......................................................................... 7
Item 2. Properties........................................................................ 33
Item 3. Legal Proceedings................................................................. 43
Item 4. Submission of Matters to a Vote of Security Holders............................... 45
PART II
Item 5. Market for CMS Energy's, Consumers' and Panhandle's Common Equity and
Related Stockholder Matters.................................................. 46
Item 6. Selected Financial Data........................................................... 46
Item 7. Management's Discussion and Analysis of Financial Condition and
Results of Operations........................................................ 47
Item 7A. Quantitative and Qualitative Disclosures About Market Risk........................ 47
Item 8. Financial Statements and Supplementary Data....................................... 48
Item 9. Changes in and Disagreements With Accountants on Accounting and
Financial Disclosure.........................................................CO-1
PART III
Item 10. Directors and Executive Officers of CMS Energy and Consumers......................CO-1
Item 11. Executive Compensation............................................................CO-1
Item 12. Security Ownership of Certain Beneficial Owners and Management....................CO-1
Item 13. Certain Relationships and Related Transactions....................................CO-1
PART IV
Item 14. Exhibits, Financial Statement Schedules and Reports on Form 8-K...................CO-2
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GLOSSARY
Certain terms used in the text and financial statements are defined below.
ABATE..................................... Association of Businesses Advocating Tariff Equity
ALJ....................................... Administrative Law Judge
AMT....................................... Alternative minimum tax
Alliance.................................. Alliance Regional Transmission Organization
Anadarko.................................. Anadarko Petroleum Corporation, a non-affiliated company
Articles.................................. Articles of Incorporation
Attorney General.......................... Michigan Attorney General
Aux Sable................................. Aux Sable Liquids Products, L.P., a non-affiliated company
bcf....................................... Billion cubic feet
Big Rock.................................. Big Rock Point nuclear power plant, owned by Consumers
Board of Directors........................ Board of Directors of CMS Energy
Btu....................................... British thermal unit
Class G Common Stock...................... One of two classes of common stock of CMS Energy, no par value,
which reflects the separate performance of the Consumers Gas
Group, redeemed in October 1999.
Clean Air Act............................. Federal Clean Air Act, as amended
CMS Capital............................... CMS Capital Corp., a subsidiary of Enterprises
CMS Electric and Gas...................... CMS Electric and Gas Company, a subsidiary of Enterprises
CMS Energy................................ CMS Energy Corporation, the parent of Consumers and Enterprises
CMS Energy Common Stock................... One of two classes of common stock of CMS Energy, par value $.01 per share
CMS Gas Transmission...................... CMS Gas Transmission and Storage Company, a subsidiary of Enterprises
CMS Generation............................ CMS Generation Co., a subsidiary of Enterprises
CMS Holdings.............................. CMS Midland Holdings Company, a subsidiary of Consumers
CMS Midland............................... CMS Midland Inc., a subsidiary of Consumers
CMS MST................................... CMS Marketing, Services and Trading Company, a subsidiary of Enterprises
CMS Oil and Gas .......................... CMS Oil and Gas Company, a subsidiary of Enterprises
CMS Panhandle Holding .................... CMS Panhandle Holding Company, a subsidiary of CMS Gas Transmission
Common Stock.............................. All classes of Common Stock of CMS Energy and each of its
subsidiaries, or any of them individually, at the time of an award or
grant under the Performance Incentive Stock Plan
CPEE...................................... Companhia Paulista de Energia Electrica
Consumers................................. Consumers Energy Company, a subsidiary of CMS Energy
Consumers Gas Group....................... The gas distribution, storage and transportation businesses currently
conducted by Consumers and Michigan Gas Storage
Court of Appeals.......................... Michigan Court of Appeals
Detroit Edison............................ The Detroit Edison Company, a non-affiliated company
DOE....................................... U.S. Department of Energy
Dow....................................... The Dow Chemical Company, a non-affiliated company
DSM....................................... Demand-side management
Duke Energy............................... Duke Energy Corporation, a non-affiliated company
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EITF...................................... Emerging Issues Task Force
El Chocon................................. Hidroelectrica El Chocon S.A.
Enterprises............................... CMS Enterprises Company, a subsidiary of CMS Energy
EPA....................................... Environmental Protection Agency
EPS....................................... Earnings per share
FASB...................................... Financial Accounting Standards Board
FERC...................................... Federal Energy Regulatory Commission
FMLP...................................... First Midland Limited Partnership, a partnership which holds a
75.5% lessor interest in the Midland Cogeneration Venture facility
FTC....................................... Federal Trade Commission
GCR....................................... Gas cost recovery
GTNs...................................... CMS Energy General Term Notes(R), $250 million Series A, $125
million Series B, $150 million Series C, $200 million Series D and
$400 million Series E
Huron..................................... Huron Hydrocarbons, Inc., a subsidiary of Consumers
ITC....................................... Investment tax credit
Jorf Lasfar............................... The 1,356 MW (660 MW in operation and 696 MW under
construction) coal-fueled power plant in Morocco, jointly owned by
CMS Generation and ABB Energy Venture, Inc.
kWh....................................... Kilowatt-hour
Loy Yang.................................. The 2,000 MW brown coal fueled Loy Yang A power plant and an
associated coal mine in Victoria, Australia, in which CMS
Generation holds a 50 percent ownership interest
LNG....................................... Liquefied natural gas
Ludington................................. Ludington pumped storage plant, jointly owned by Consumers and
Detroit Edison
mcf....................................... Thousand cubic feet
MCV Facility.............................. A natural gas-fueled, combined-cycle cogeneration facility operated
by the MCV Partnership
MCV Partnership........................... Midland Cogeneration Venture Limited Partnership in which
Consumers has a 49 percent interest through CMS Midland
MD&A...................................... Management's Discussion and Analysis
MEPCC..................................... Michigan Electric Power Coordination Center
Michigan Gas Storage...................... Michigan Gas Storage Company, a subsidiary of Consumers
Mbbls..................................... Thousand barrels
MMbbls.................................... Million barrels
MMBtu..................................... Million British thermal unit
MMcf...................................... Million cubic feet
MPSC...................................... Michigan Public Service Commission
MW........................................ Megawatts
Natural Gas Act........................... Federal Natural Gas Act
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NEIL...................................... Nuclear Electric Insurance Limited, an industry mutual insurance
company owned by member utility companies
Nitrotec.................................. Nitrotec Corporation, a propriety gas technology company in which
CMS Gas Transmission owns an equity interest
NRC....................................... Nuclear Regulatory Commission
NYMEX..................................... New York Mercantile Exchange
OPEB...................................... Postretirement benefit plans other than pensions for retired
employees
Outstanding Shares........................ Outstanding shares of Class G Common Stock
Palisades................................. Palisades nuclear power plant, owned by Consumers
Pan Gas Storage........................... Pan Gas Storage Company, a subsidiary of Panhandle Eastern Pipe
Line Company
PanEnergy................................. PanEnergy Corp., a subsidiary of Duke Energy and former parent
of Panhandle
Panhandle................................. Panhandle Eastern Pipe Line Company, including its subsidiaries
Trunkline, Pan Gas Storage, Panhandle Storage, and Trunkline
LNG. Panhandle is a wholly owned subsidiary of CMS Gas Transmission
Panhandle Eastern Pipe Line............... Panhandle Eastern Pipe Line Company, a wholly owned subsidiary
of CMS Gas Transmission
Panhandle Storage......................... CMS Panhandle Storage Company, a subsidiary of Panhandle
Eastern Pipe Line Company
PCBs...................................... Poly chlorinated biphenyls
PECO...................................... PECO Energy Company, a non-affiliated company
Pension Plan.............................. The trusteed, non-contributory, defined benefit pension plan of Panhandle,
Consumers and CMS Energy
PPA....................................... The Power Purchase Agreement between Consumers and the MCV
Partnership with a 35-year term commencing in March 1990
ppm....................................... Parts per million
PSCR...................................... Power supply cost recovery
PUHCA..................................... Public Utility Holding Company Act of 1935
RTO....................................... Regional Transmission Organization
SEC....................................... Securities and Exchange Commission
Senior Credit Facilities.................. $725 million senior credit facilities consisting of a $600 million
three-year revolving credit facility and a five-year $125 million
term loan facility
SERP...................................... Supplemental Executive Retirement Plan
SFAS...................................... Statement of Financial Accounting Standards
SOP....................................... Statement of position
Stranded Costs............................ Costs incurred by utilities in order to serve their customers in a
regulated monopoly environment, but which may not be
recoverable in a competitive environment because of customers
leaving their systems and ceasing to pay for their costs. These costs
could include owned and purchased generation and regulatory
assets.
Superfund................................. Comprehensive Environmental Response, Compensation and
Liability Act
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TBtu...................................... Trillion british thermal unit
TGN....................................... Transportadora de Gas del Norte S.A., a natural gas pipeline
located in Argentina
Transition Costs.......................... Stranded Costs, as defined, plus the costs incurred in the transition
to competition.
Trunkline................................. Trunkline Gas Company, a subsidiary of Panhandle Eastern Pipe
Line Company
Trunkline LNG............................. Trunkline LNG Company, a subsidiary of Panhandle Eastern Pipe
Line Company
Trust Preferred Securities................ Securities representing an undivided beneficial interest in the assets
of statutory business trusts, which interests have a preference with
respect to certain trust distributions over the interests of either CMS
Energy or Consumers, as applicable, as owner of the common
beneficial interests of the trusts
Union..................................... Utility Workers of America, AFL-CIO
UST....................................... Underground storage tanks
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PART I
ITEM 1. BUSINESS.
GENERAL
CMS ENERGY
CMS Energy, formed in Michigan in 1987, is a leading diversified energy company
operating in the United States and around the world. Our two principal
subsidiaries are Consumers and Enterprises. Consumers is a public utility that
provides natural gas or electricity to almost six million of the nine and
one-half million residents in Michigan's lower peninsula. Enterprises, through
subsidiaries, is engaged in several domestic and international diversified
energy businesses.
Our consolidated operating revenue in 1999 was $6.1 billion. Our consolidated
operating revenue came from the following seven business segments (which
includes Consumers' utility operations):
Consumers Electric Utility Operations 44 percent
Consumers Gas Utility Operations 19 percent
Marketing, Services and Trading Operations 13 percent
Natural Gas Transmission, Storage and Processing Operations 13 percent
Independent Power Production Operations 6 percent
International Energy Distribution and other
Non-Utility Operations 3 percent; and
Oil and Gas Exploration and Production Operations 2 percent.
See "BUSINESS SEGMENTS" later in this Item 1 for further discussion of each
segment.
CONSUMERS
Consumers, formed in Michigan in 1968, is the successor to a corporation
organized in Maine in 1910. This predecessor did business in Michigan from 1915
to 1968. Consumers was originally named Consumers Power Company. In 1997,
Consumers changed its name to Consumers Energy Company to reflect its increasing
focus on providing customers with total energy solutions.
Consumers' consolidated operations account for a majority of CMS Energy's total
assets, revenues and income. Consumers' service areas include automotive, metal,
chemical, food and wood products and a diversified group of other industries. At
year-end 1999, Consumers' customer base and operating revenues were as follows:
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1999 vs 1998
Customers Served Operating Revenue Operating Revenue
(millions) (millions) % Increase (Decrease)
---------- ---------- ---------------------
Electric Utility 1.67 $ 2,667 2.3
Gas Utility Business 1.58 1,156 10.0
Non-Utility -- 51 (a) --
Total 3.25 $ 3,874 4.4
(a) Primarily represents earnings attributable to Consumers' interest in the MCV
Partnership and MCV Facility, which is reported within the Independent Power
Production business segment.
Consumers' rates and certain other aspects of its business are subject to the
jurisdiction of the MPSC and FERC, as described in CMS ENERGY, CONSUMERS AND
PANHANDLE REGULATION later in this Item 1.
PANHANDLE
Panhandle Eastern Pipe Line Company, formed in Delaware in 1929, is a wholly
owned subsidiary of CMS Gas Transmission. On March 29, 1999, Panhandle Eastern
Pipe Line Company and its principal consolidated subsidiaries, Trunkline and Pan
Gas Storage, as well as Panhandle Eastern Pipe Line Company's affiliates,
Trunkline LNG and Panhandle Storage, were acquired from subsidiaries of Duke
Energy by CMS Panhandle Holding, which was an indirect wholly owned subsidiary
of CMS Energy. Immediately following the acquisition, Trunkline LNG and
Panhandle Storage became wholly owned subsidiaries of Panhandle Eastern Pipe
Line Company.
Panhandle is primarily engaged in the interstate transmission and storage of
natural gas. Panhandle operates one of the nation's largest natural gas pipeline
networks, providing customers in the Midwest and Southwest with a comprehensive
array of transportation services. This interconnected 10,400 mile system
accesses virtually all major natural gas regions in the United States. The rates
and operations of Panhandle are subject to regulation by FERC as described in
CMS ENERGY, CONSUMERS AND PANHANDLE REGULATION later in this Item 1.
Panhandle's major customers include approximately 25 utilities located primarily
in the Midwest market area that encompasses large portions of Michigan, Ohio,
Indiana, Illinois, Missouri and Tennessee. Panhandle's consolidated operating
revenue in 1999 was $471 million. Of Panhandle's operating revenue, 84 percent
was generated from transportation services, 10 percent from storage services,
and 6 percent from other business. Transportation services for Consumers and
ProLiance Energy L.L.C., each, accounted for at least 10 percent of the 1999 and
1997 revenues of Panhandle. In 1998, ProLiance Energy, L.L.C. accounted for
approximately 10 percent of Panhandle's revenues. No other customer accounted
for 10 percent or more of Panhandle's revenues during 1999, 1998 or 1997. For
additional information, see ITEM 7. PANHANDLE'S MANAGEMENT'S DISCUSSION AND
ANALYSIS - RESULTS OF OPERATIONS and ITEM 2. PROPERTIES - PANHANDLE EASTERN PIPE
LINE COMPANY.
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CMS ENERGY'S RECENT DEVELOPMENTS
In February 2000, CMS Energy announced a financial restructuring plan to
strengthen significantly its balance sheet, to reduce fixed charges and to
enhance earnings per share growth. During the second or third quarter of 2000,
subject to market conditions, CMS Energy intends to make an initial public
offering of approximately $600 million of a tracking stock representing 20
percent of the economic interest in its electric and gas utility. In addition,
the CMS Energy Board of Directors approved the repurchase of up to 10 million
shares of CMS Energy Common Stock, from time to time, in open market or private
transactions. Substantial progress has been made toward the 10 million share
limit. For additional information, see ITEM 7. CMS ENERGY MANAGEMENT'S
DISCUSSION AND ANALYSIS - RECAPITALIZATION, incorporated by reference herein.
CMS Energy anticipates this restructuring program, along with the proceeds from
the planned sale of assets discussed below, will improve CMS Energy's balance
sheet. If market conditions are not satisfactory for issuance of the tracking
stock, CMS Energy will improve its balance sheet through additional asset sales
or alternate means. In October 1999, CMS Energy identified for possible sale $1
billion of assets, which were expected to contribute little or no earnings
benefit in the short to medium term. In addition, in February 2000, CMS Energy
announced its intention to sell Loy Yang. Excluding Loy Yang, CMS Energy plans
to sell or have agreements to sell $600 to $750 million of such assets by the
end of April 2000. As of February 1, 2000 CMS Energy had sold a partial interest
in its Northern Header gathering system through its natural gas transmission,
storage and processing business and all of its ownership interest in a Brazilian
distribution system through its international energy distribution business. In
addition, CMS Energy has an agreement to sell all its northern Michigan oil and
gas properties through its oil and gas exploration and production business.
These sales are expected to generate approximately $370 million in proceeds. For
additional information concerning the sale of these assets, see ITEM 7. CMS
ENERGY MANAGEMENT'S DISCUSSION AND ANALYSIS - CASH POSITION, INVESTING AND
FINANCING.
BUSINESS SEGMENTS
CMS ENERGY, CONSUMERS AND PANHANDLE FINANCIAL INFORMATION
For information with respect to operating revenue, net operating income,
identifiable assets and liabilities attributable to all of CMS Energy's business
segments and international and domestic operations, see ITEM 8. FINANCIAL
STATEMENTS AND SUPPLEMENTARY DATA - SELECTED FINANCIAL INFORMATION AND CMS
ENERGY'S CONSOLIDATED FINANCIAL STATEMENTS AND NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS.
For information with respect to the operating revenue, net operating income,
identifiable assets and liabilities attributable only to Consumers' business
segments, see ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA SELECTED
FINANCIAL INFORMATION AND CONSUMERS' CONSOLIDATED FINANCIAL STATEMENTS AND NOTES
TO CONSOLIDATED FINANCIAL STATEMENTS.
For information with respect to the operating revenue, net operating income,
identifiable assets and liabilities attributable only to Panhandle's business
segments, see ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA - PANHANDLE'S
CONSOLIDATED FINANCIAL STATEMENTS AND NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS.
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CMS Energy, Consumers and Panhandle are subject to certain uncertainties and
risks, which are normal for their respective businesses. Certain uncertainties
are described in CMS Energy's ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY
DATA - NOTE 4 OF CMS ENERGY'S NOTES TO CONSOLIDATED FINANCIAL STATEMENTS, NOTE 2
OF CONSUMERS' NOTES TO CONSOLIDATED FINANCIAL STATEMENTS, and NOTE 3 AND NOTE 11
OF PANHANDLE'S NOTES TO CONSOLIDATED FINANCIAL STATEMENTS. Certain risks are
described in ITEM 7. CMS ENERGY'S MANAGEMENT'S DISCUSSION AND ANALYSIS - MARKET
RISK INFORMATION and ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA - NOTE
9 OF CMS ENERGY'S NOTES TO CONSOLIDATED FINANCIAL STATEMENTS and in ITEM 7.
CONSUMERS' MANAGEMENT'S DISCUSSION AND ANALYSIS - DERIVATIVES AND HEDGES.
CMS Energy, Consumers, and Panhandle believe that they and their subsidiaries
maintain traditional insurance, similar to comparable companies in the same line
of business, for the various risk exposures including political risk from
possible nationalization or expropriation, incidental to CMS Energy's,
Consumers' or Panhandle's respective businesses.
CONSUMERS ELECTRIC UTILITY OPERATIONS
If independent, Consumers' electric utility operation would be the twelfth
largest electric company in the United States based upon the number of
customers. The electric operations of Consumers include the generation,
purchase, transmission, distribution and sale of electricity. At year-end 1999,
it served 1.67 million customers in 61 of the 68 counties of Michigan's lower
peninsula. Principal cities served include Battle Creek, Flint, Grand Rapids,
Jackson, Kalamazoo, Midland, Muskegon and Saginaw. Consumers' electric utility
customer base includes a mix of residential, commercial and diversified
industrial customers, the largest segment of which is the automotive industry.
Consumers' electric operations are not dependent upon a single customer, or even
a few customers, and the loss of any one or even a few of such customers is not
reasonably likely to have a material adverse effect on its financial condition,
subject to appropriate regulatory treatment that allows an adjustment to
Consumers rates to compensate for the loss of revenues from such customers.
Consumers' electric operations are seasonal. The summer months usually increase
demand for electric energy, principally due to the use of air conditioners and
other cooling equipment, thereby affecting revenues. Total electric sales in
1999 were 41 billion kWh, a 2.5 percent increase over 1998 levels including a
2.8 percent increase in system sales to Consumers' ultimate customers.
Consumers achieved a 1999 winter peak demand of 6,093 MW and a summer peak
demand of 7,460 MW. Based on the summer peak, Consumers' reserve margin was 14.7
percent in 1999 compared to 21.1 percent in 1998. Consumers estimates that
during the summer of 2000, it will be able to satisfy its peak demand with a 9.3
percent reserve margin from a combination of its owned electric generating
plants and existing long-term purchase contracts and a 16.7 percent reserve
margin when short-term electricity purchase contracts or options as well as
other arrangements are added. This estimate is based on 235 MW of coincident
retail open access load being served by others (Consumers will offer other
service providers with the opportunity to serve up to 600 MW of nominal retail
open access load prior to summer 2000). If 235 MW of coincident retail open
access load is not served by others, the reserve margin is expected to be
approximately 15 percent.
Consumers owned and operated 31 electric generating plants in 1999 with an
aggregate of 6,252 MW of capacity. In 1999, Consumers purchased 2,388 MW of net
capacity, which amounted to 32 percent of Consumers' total system requirements,
from other power producers, the largest being the MCV Partnership. For
additional information on Consumers' electric properties, see ITEM 2. PROPERTIES
- - CONSUMERS ELECTRIC UTILITY PROPERTIES. For additional information concerning a
long-term power sales agreement between Consumers and PECO to resell the
capacity and energy purchases under
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the PPA see ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA - NOTE 2 OF
CONSUMERS' NOTES TO CONSOLIDATED FINANCIAL STATEMENTS.
A transmission system interconnects Consumers' electric generating plants at
many locations with transmission facilities of unaffiliated systems, including
those of other utilities in Michigan and Indiana. The interconnections permit a
sharing of the reserve capacity of the connected systems. This allows mutual
assistance during emergencies and substantially reduces investment in utility
plant facilities.
FUEL SUPPLY: Consumers has four generating plant sites which use coal as a fuel
source and which constitute 78.5 percent of its baseload capacity (the capacity
used to serve a constant level of customer demand). Combined, these plants
produce a total of 19,085 million kWhs of electricity in 1999 and required 8.9
million tons of coal. Consumers' coal inventory on December 31, 1999 amounted to
approximately 40 days' supply. For additional information on future sources of
coal, see ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA - NOTE 2 OF
CONSUMERS' NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - UNCERTANTIES - OTHER
ELECTRIC UNCERTANTIES.
Consumers owned two and operated one nuclear power plant during 1999. The Big
Rock nuclear power plant, located near Charlevoix, Michigan was closed
permanently on August 29, 1997. During 1999, the net generation of the Palisades
nuclear power plant, located near South Haven, Michigan, was 5,105 million
kWhs, constituting 21 percent of Consumers' baseload generation. Consumers has
two contracts for uranium concentrate sufficient to provide up to 50 percent of
its requirements. Consumers intends to purchase the balance of its concentrate,
conversion and enrichment requirements for the next Palisades reload throughout
the year 2000. Delivery of the next completed reload is scheduled for Spring
2001. Consumers intends to maximize use of the spot market for its future
requirements. Consumers has contracts for nuclear fuel services and fabrication
of nuclear fuel assemblies. The fabrication contract for Palisades remains in
effect for the next three Palisades reloads with options to extend the contract
for an additional two reloads. These contracts are with major private industrial
suppliers of nuclear fuel and related services and with uranium producers,
converters and enrichers who participate in the world nuclear fuel marketplace.
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As shown below, Consumers generates electricity principally from coal and
nuclear fuel.
Power Generated Millions of kWhs
- --------------- ----------------
1999 1998 1997 1996 1995
---- ---- ---- ---- ----
Coal 19,085 17,959 16,427 16,928 15,956
Nuclear 5,105 5,364 5,970 5,653 5,353
Oil 809 520 258 364 318
Gas 441 302 80 74 238
Hydro 365 395 467 473 420
Net pumped storage (a) (476) (480) (477) (419) (373)
- ---------------------- ------ ------ ------ ------ ------
Total net generation 25,329 24,060 22,725 23,073 21,912
==================== ====== ====== ====== ====== ======
(a) Represents Consumers' 51 percent share of net generation from Ludington.
This facility pumps water into a storage pond using electricity generated during
off-peak hours to generate electricity later during peak demand hours.
The cost of all fuels consumed, shown below, fluctuates with the mix of fuel
burned.
Cost per Million Btu
--------------------
1999 1998 1997 1996 1995
---- ---- ---- ---- ----
Fuel Consumed
- -------------
Coal $1.38 $1.45 $1.53 $1.50 $1.51
Oil 2.69 2.73 2.97 2.67 2.64
Gas 2.74 2.66 3.36 3.60 2.18
Nuclear 0.48 0.50 0.57 0.50 0.49
All Fuels (a) 1.27 1.28 1.29 1.27 1.27
============= ==== ==== ==== ==== ====
(a) Weighted average fuel costs.
Under the Nuclear Waste Policy Act of 1982, the federal government was to be
responsible for the permanent disposal of spent nuclear fuel and high-level
radioactive waste beginning in 1998. To date, the DOE has been unable to arrange
for storage facilities to meet this obligation and it does not anticipate being
able to accept spent nuclear fuel for storage in 2000. For a discussion of
pending litigation and legislative action relating to the DOE's obligations in
this regard, see ITEM 3. LEGAL PROCEEDINGS and ITEM 8. FINANCIAL STATEMENTS AND
SUPPLEMENTARY DATA - NOTE 2 OF CMS ENERGY'S NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS and ITEM 3. LEGAL PROCEEDINGS and ITEM 8. FINANCIAL STATEMENTS AND
SUPPLEMENTARY DATA - NOTE 1 OF CONSUMERS' NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS. Consumers' on-site storage pool at Palisades is at capacity and
Consumers is currently storing spent nuclear fuel in NRC-approved steel and
concrete vaults, known as "dry casks". Currently, three storage casks are
available for future storage. For a discussion relating to the NRC approval of
dry casks and Consumers' use of the casks, see ITEM 8. FINANCIAL STATEMENTS AND
SUPPLEMENTARY DATA - NOTE 4 OF CMS ENERGY'S NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS and ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA - NOTE 2 OF
CONSUMERS' NOTES TO CONSOLIDATED FINANCIAL STATEMENTS.
INSURANCE: At Palisades, Consumers maintains primary and excess nuclear property
insurance from NEIL totaling $2.4 billion in recoverable limits. It insures
against covered risks of direct property loss, decontamination, and debris
removal subject to standard policy terms and conditions. Also covered by
insurance are a portion of the costs arising from accidental premature
decommissioning not funded by the decommissioning trust funds, and part of the
remaining book value of the plant. For any loss more than
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$100 million, stabilization and decontamination expenses must be satisfied
before Consumers receives other claim proceeds from NEIL.
Consumers also procured coverage from NEIL that would partially cover the cost
of replacement power during certain prolonged accidental outages at Palisades.
Insurance would not cover such costs during the first 12 weeks of any outage,
but insurance would cover most of such costs during the next 52 weeks of the
outage, followed by a reduced level of coverage for a period up to 110
additional weeks.
The permanently closed Big Rock remains insured by NEIL up to $500 million for
decontamination, debris removal, and covered direct property loss subject to
standard policy terms and conditions.
Consumers retains the risk of loss to the extent of the insurance deductibles
and to the extent policy limits are exceeded by a loss. Because NEIL is a mutual
insurance company, Consumers could be subject to assessments from NEIL up to
$15.5 million in any policy year if insured losses occur at its, or any other
member's nuclear facility.
Consumers maintains insurance for injuries and off-site property damage
insurance due to the nuclear hazard at Palisades up to the total limits of
liability established by the Price-Anderson Act, which are presently
approximately $9.5 billion. The Price-Anderson Act was enacted to provide
financial protection for persons who may be liable for a nuclear accident or
incident and persons who may be injured by a nuclear incident. Part of such
financial protection consists of a mandatory industry-wide program under which
owners of nuclear generating facilities could be assessed if a nuclear incident
occurs at any of such facilities. The maximum assessment against Consumers could
be $88 million per occurrence, limited to maximum annual installment payments of
$10 million. Consumers also maintains insurance under a program that covers tort
claims for bodily injury to workers caused by nuclear hazards. The policy
contains a $200 million nuclear industry aggregate limit. Under a previous
insurance program providing coverage for claims brought by nuclear workers,
Consumers remains responsible for a maximum assessment of up to $6.3 million.
The Big Rock plant remains insured for nuclear liability by a combination of
insurance and U.S. government indemnity totaling $544 million.
Consumers has not obtained insurance for property damage at its nuclear plants
caused by floods and earthquakes because it believes that the protective systems
built into these plants and the low probability of an event of this type at the
locations of these plants makes such insurance unnecessary.
Insurance policy terms, limits and conditions are subject to change during the
year as policies are renewed.
CONSUMERS GAS UTILITY OPERATIONS
If independent, Consumers' gas utility operation would be the fifth largest gas
company in the United States based upon the number of customers. Consumers' gas
utility operation purchases, transports, stores, distributes and sells natural
gas. As of December 31, 1999, it rendered gas sales and delivery service to 1.58
million customers and is authorized to provide service in 54 of the 68 counties
in Michigan's lower peninsula. Principal cities served include Bay City, Flint,
Jackson, Kalamazoo, Lansing, Pontiac and Saginaw, as well as the suburban
Detroit area, where over 900,000 of the gas customers are located. Consumers
owns gas transmission and distribution mains and other gas lines, compressor
stations and facilities, storage rights, wells and gathering facilities in
several storage fields in Michigan. See ITEM 2. PROPERTIES - CONSUMERS GAS
UTILITY PROPERTIES. Consumers and its wholly owned subsidiary, Michigan Gas
Storage, inject natural gas into storage during the summer months of the year
for use during the winter months when demand is higher. Consumers' gas operation
is not dependent upon a
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single customer, or even a few customers, and the loss of any one or even a few
of such customers is not reasonably likely to have a material adverse effect on
its financial condition, subject to appropriate regulatory treatment that
allows an adjustment to Consumers rates to compensate for the loss of revenues
from such customers.
Consumers' gas operation is seasonal to the extent that peak demand usually
occurs in winter due to colder temperatures and the resulting increased demand
for heating fuels. Total deliveries of natural gas sold by Consumers and from
other sellers over Consumers' pipeline and distribution network to ultimate
customers, including the MCV Partnership, totaled 389 bcf in 1999.
GAS SUPPLY: In 1999, Consumers purchased 80 percent of its required gas supply
under contracts longer than one year. Total 1999 purchases included 28 percent
from United States producers outside Michigan, 26 percent from Canadian
producers, 15 percent from Michigan producers and 13 percent from the spot
market. The remaining 18 percent of gas burned by customers was supplied by
authorized suppliers in the experimental gas customer choice program which
started in April 1998.
Consumers' firm transportation agreements (excluding agreements with its wholly
owned subsidiary Michigan Gas Storage Company) are with Trunkline, Panhandle,
ANR Pipeline Company and Great Lakes Gas Transmission, L.P. Consumers uses these
agreements to deliver gas to Michigan for ultimate deliveries to market. In
total, Consumers' firm transportation arrangements are capable of carrying over
90 percent of Consumers' total gas supply requirements. As of December 31, 1999,
Consumers' portfolio of firm transportation from pipelines to Michigan is as
follows:
Volume
------
(dekatherms/day) Expiration
---------------- ----------
Trunkline 336,375 October 2002
Panhandle 40,000 March 2000
25,000 March 2000
ANR Pipeline Company 10,000 December 2001
6,000 December 2002
83,790 October 2003
Great Lakes Gas Transmission, L.P. 85,092 March 2004
================================== ====== ===== ====
Consumers transports the balance of its required gas supply under interruptible
contracts. The amount of interruptible transportation service and the use of it
primarily varies with the price for such service and the availability and price
of the spot supplies to be purchased and transported. Consumers' use of
interruptible transportation is generally in off-peak summer months and after
Consumers has fully subscribed its firm transportation service.
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NATURAL GAS TRANSMISSION, STORAGE AND PROCESSING
CMS Gas Transmission, formed in 1988, owns, develops and manages domestic and
international natural gas facilities consisting of a total of 21,359 miles of
pipeline (including 488 miles of projects under construction) with a daily
capacity of approximately 10.0 bcf per day. At December 31, 1999, CMS Gas
Transmission had processing capabilities of approximately 1.0 bcf per day of
natural gas. Its Michigan carbon dioxide removal plants processed approximately
330 MMcf per day, representing more natural gas processed than any other
processor in the State of Michigan.
CMS Energy expanded the importance of this business segment with the recent
acquisition of the Panhandle Companies. In addition, CMS Gas Transmission
acquired a natural gas pipeline in Western Australia and gathering systems and
processing plants in the panhandle region of Texas and Oklahoma and the Powder
River region of Montana and Wyoming. CMS Gas Transmission's operating revenue in
1999 was $785 million.
In March 2000, CMS Gas Transmission through Trunkline acquired a 1.0 bcf natural
gas and condensate pipeline in the Gulf of Mexico offshore Louisiana, west of an
existing Trunkline system. The system consists of five offshore valving
platforms and one compressor platform, 405 miles of offshore pipeline, 40 miles
of onshore pipeline and one compressor station. Also in March 2000, Panhandle,
as part of its strategy to maximize the use of existing assets, announced an
agreement to form a limited liability company to extend and convert an existing
26" Trunkline pipeline from natural gas transmission service to liquid products
service by the end of 2001. Each of the three parties, including Panhandle, will
own a one-third interest in the limited liability company.
Panhandle's throughput volumes for the years 1995 to 1999 were 1,182 Tbtu, 1,319
Tbtu, 1,279 Tbtu, 1,141 Tbtu and 1,139 Tbtu, respectively. A majority of
delivered volumes of Panhandle's interstate pipelines represents gas transported
under long-term service agreements with local distribution company customers in
the pipeline's market areas. Firm transportation services are also provided
under contract to gas marketers, producers, other pipelines, electric power
generators and a variety of end-users. In addition, the pipelines offer both
firm and interruptible transportation to customers on a short-term or seasonal
basis. Demand for gas transmission of Panhandle's pipeline systems is seasonal,
with the highest throughput and a higher portion of revenues occurring during
the colder period in the first and fourth quarters.
For additional information, see ITEM 7. CMS ENERGY MANAGEMENT'S DISCUSSION AND
ANALYSIS - NATURAL GAS TRANSMISSION, STORAGE AND PROCESSING RESULTS OF
OPERATIONS.
INDEPENDENT POWER PRODUCTION
CMS Generation, formed in 1986, invests in, acquires, develops, constructs and
operates non-utility power generation plants both in the United States and
internationally. As of December 31, 1999, CMS Generation had ownership interests
in operating power plants totaling 8,110 gross MW (3,713 net MW) throughout the
United States and in Argentina, Australia, Chile, India, Jamaica, Morocco, the
Philippines and Thailand. At year-end 1999, its projects range in size from 3 MW
to 2,000 MW and are powered by water, coal, natural gas, oil, wood, wind and
waste material. Additional projects totaling approximately 4,847 gross MW are
under construction or advanced development at December 31, 1999.
The MCV Partnership was formed in January 1987 to convert a portion of an
abandoned Midland County, Michigan nuclear plant owned by Consumers into the MCV
Facility. The MCV Facility was sold to five owner trusts and leased back to the
MCV Partnership. CMS Holdings is a limited partner in a partnership which is a
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beneficiary of one of these trusts. CMS Holdings' indirect beneficial interest
in the MCV Facility is 35 percent. CMS Midland owns a 49 percent general
partnership interest in the MCV Partnership. The MCV Facility has a gross
capacity of 1,370 MW.
The rapid growth in CMS Generation's generating capacity has been matched by
growth in this business segment's operating revenue. In 1999, Independent Power
Production's operating revenue, which includes revenues from CMS Generation, the
MCV Facility and the MCV Partnership, was $390 million. For additional
information, see ITEM 2. PROPERTIES - CMS ENERGY OTHER PROPERTIES and ITEM 7.
CMS ENERGY'S MANAGEMENT'S DISCUSSION AND ANALYSIS INDEPENDENT POWER PRODUCTION
RESULTS OF OPERATIONS.
OIL AND GAS EXPLORATION AND PRODUCTION
CMS Oil and Gas (formerly known as CMS NOMECO Oil & Gas Co.), formed in 1967,
conducts oil and gas exploration and development operations throughout the
United States and seven other countries. Historically, most domestic operations
focused on gas exploration and production in Michigan and Texas and coal bed
methane exploration and production in Wyoming. The international operations
focus on oil exploration and production and are distributed across two other
continents. We anticipate that future domestic operations will focus on oil and
gas exploration and production in Texas and coal bed methane exploration and
production in Wyoming. International operations focus on oil exploration and
production and are located in South America and Africa. In 1999, CMS Oil and Gas
achieved production levels of 7.7 million barrels of oil, condensate and plant
products and 26.4 bcf of gas. CMS Oil and Gas' proven oil and gas reserves total
248.2 million net equivalent barrels reflecting a balanced portfolio of
high-quality reserves, including 47 percent oil and condensate and 53 percent
natural gas.
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During 1999, CMS Oil and Gas participated with a working interest in drilling
wells as follows:
Number of
Number of Wells Successful Wells Success Ratio
Type of Well Gross Net Gross Net Gross Net
- ------------ ----- --- ----- --- ----- ---
Exploratory 5 2.16 5 2.16 100% 100%
Development 32 23.70 31 22.96 97% 97%
-- ----- -- -----
Total 37 25.86 36 25.12 97% 97%
===== == ===== == ===== ===== =====
The preceding table does not include CMS Oil and Gas' participation in coal bed
methane gas wells in Wyoming and Montana, where CMS Oil and Gas drilled 160
wells (77.3 net) during 1999.
CMS Oil and Gas' operating revenue was $98 million in 1999. For additional
information, see ITEM 2. PROPERTIES - CMS ENERGY OIL AND GAS EXPLORATION AND
PRODUCTION PROPERTIES and ITEM 7. CMS ENERGY MANAGEMENT'S DISCUSSION AND
ANALYSIS - OIL AND GAS EXPLORATION AND PRODUCTION RESULTS OF OPERATIONS.
MARKETING, SERVICES AND TRADING
CMS MST, formed in 1996, provides gas, oil, coal and electric marketing, risk
management and energy management services to industrial, commercial, utility and
municipal energy users throughout the United States and internationally. CMS MST
has grown dramatically since its inception. CMS Energy intends to use CMS MST to
enhance performance of CMS Energy assets, such as gas reserves and power plants.
CMS MST markets annually approximately 470 bcf of natural gas, 3,709
gigawatt-hours of electricity, 23 million barrels of crude oil and 6.5 million
barrels of natural gas liquids. CMS MST also provided energy management services
to 1,600 projects in the past 36 months. In 1999, CMS MST acquired an energy
services company and an independent energy consulting firm in Kansas City,
Missouri and Toronto, Canada, respectively. These acquisitions expanded CMS
MST's presence in 22 cities in the United States and in Oakville, Montreal and
Vancouver, Canada. At December 31, 1999, CMS MST had more than 10,000 customers,
transported gas on more than 30 gas pipelines and was active in 35 states and 2
countries. CMS MST's operating revenue in 1999 was $799 million. For additional
information, see ITEM 7. CMS ENERGY MANAGEMENT'S DISCUSSION AND ANALYSIS
- -MARKETING, SERVICES AND TRADING RESULTS OF OPERATIONS.
INTERNATIONAL ENERGY DISTRIBUTION
CMS Electric and Gas, formed in 1996, is CMS Energy's international energy
distribution subsidiary. As of February 2000, it has ownership interests in
electric distribution companies which provide service in the states of Sao Paulo
and Minas Gerais in Brazil, the province of Entre Rios in Argentina, and on
Margarita Island in Venezuela. These electric distribution companies serve a
total of 464,000 customers with electricity sales of 3,096 GWh in 1999, after
accounting for the sale in January 2000 of CMS Electric and Gas' interest in
Companhia Forca Luz Cataguazes - Leopoldina and its subsidiaries in Brazil.
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SALES BETWEEN BUSINESS SEGMENTS
CMS Energy's sales between business segments for the years ended December 31
were as follows:
In Millions
-----------
Years Ended December 31 1999 1998 1997
- ----------------------- ---- ---- ----
Oil and Gas Exploration and Production $45 $64 $75
Natural Gas Transmission, Storage and Processing 69 9 4
Marketing, Services and Trading 73 68 16
CMS ENERGY, CONSUMERS AND PANHANDLE REGULATION
CMS Energy is exempt from registration under PUHCA. CMS Energy, Consumers,
Panhandle and their subsidiaries are subject to regulation by various federal,
state, local and foreign governmental agencies, including those specifically
described below.
MICHIGAN PUBLIC SERVICE COMMISSION
Consumers is subject to the jurisdiction of the MPSC, which regulates public
utilities in Michigan with respect to retail utility rates, accounting,
services, certain facilities and various other matters. The MPSC also has, or
will have, rate jurisdiction over several limited partnerships in which CMS Gas
Transmission has ownership interests. These partnerships own, or will own, and
operate intrastate gas transmission pipelines.
The Attorney General, ABATE and the MPSC staff typically intervene in MPSC
electric and/or gas related proceedings concerning Consumers. Unless otherwise
noted herein, these parties have intervened in such proceedings. For many years,
various parties have appealed almost every significant MPSC order affecting
Consumers. Appeals from such MPSC orders are pending in the Court of Appeals and
the Michigan Supreme Court. Consumers is vigorously pursuing these matters.
Under Michigan civil procedure, parties may file a claim of appeal with the
Court of Appeals that serves as a notice of appeal of an MPSC order. The grounds
on which they are making the appeal are not finally set forth until a later date
when the parties file their briefs.
RATE PROCEEDINGS: In 1996, the MPSC issued orders that established the electric
authorized rate of return on common equity at 12.25 percent and the gas
authorized rate of return at 11.6 percent.
MPSC REGULATORY AND MICHIGAN LEGISLATIVE CHANGES: State regulation of the retail
electric and gas utility businesses is in the process of undergoing significant
changes. For example, the MPSC issued several orders in 1997, 1998, and 1999
restructuring the electric power industry in Michigan. Under these orders, which
Consumers has voluntarily agreed to implement, Consumers will allow certain
customers the election of purchasing electric power directly from other
suppliers, such as independent power producers, power marketers and other
utilities. Consumers will continue to transmit and distribute such power
purchases to the end-use retail customers. Importantly, the orders provide for
full recovery by Consumers of its Stranded Costs. This electric customer choice
program commenced in September 1999 and will be phased in to cover 750 MW of
Consumers' retail market by 2001. On January 1, 2002, all of Consumers' electric
customers will have this option. Several MPSC orders related to restructuring
are subject to claims of appeal filed with the Court of Appeals. These appeals
question whether the MPSC has the statutory authority to mandate restructuring
on an involuntary basis and challenge various other aspects of these
restructuring orders. Several bills relative to electric and gas industry
restructuring were introduced in the
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Michigan House of Representatives or Senate for consideration in the 1999-2000
legislative session. For additional information concerning the electric industry
restructuring, see ITEM 7. CMS ENERGY MANAGEMENT'S DISCUSSION AND ANALYSIS -
OUTLOOK - CONSUMERS' ELECTRIC UTILITY OUTLOOK and ITEM 8. FINANCIAL STATEMENTS
AND SUPPLEMENTARY DATA - NOTE 4 TO CMS ENERGY'S NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS and ITEM 7. CONSUMERS' MANAGEMENT'S DISCUSSION AND ANALYSIS -
OUTLOOK - ELECTRIC UTILITY OUTLOOK and ITEM 8. FINANCIAL STATEMENTS AND
SUPPLEMENTARY DATA - NOTE 2 TO CONSUMERS' NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS.
As a result of regulatory changes in the natural gas industry, gas distribution
companies like Consumers transport the natural gas commodity, which is sold to
customers by competitors like gas producers, marketers and others. In December
1997, the MPSC approved Consumers' application to implement a statewide
three-year experimental gas transportation program eventually allowing 300,000
residential, commercial and industrial retail gas sales customers to choose
their gas supplier. The program is voluntary, and participating natural gas
customers are selected on a first-come, first-served basis, up to a limit of
100,000 customers per year. As of December 31, 1999, more than 176,000 customers
chose alternative gas suppliers, representing approximately 42.2 bcf of gas
customer requirements. Customers choosing to remain as sales customers of
Consumers will not see a rate change in their natural gas rates. This
experimental program will allow competing gas suppliers, including marketers and
brokers, to market natural gas to these retail customers in direct competition
with Consumers. For additional information concerning the MPSC order, see ITEM
8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA - NOTE 4 TO CMS ENERGY'S NOTES TO
CONSOLIDATED FINANCIAL STATEMENTS, and ITEM 8. FINANCIAL STATEMENTS AND
SUPPLEMENTARY DATA - NOTE 2 TO CONSUMERS' NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS.
In December 1999, several bills related to gas industry restructuring were
introduced into the Michigan Legislature. Combined, these bills constitute the
"gas choice program". For additional information concerning this proposed
legislation, see ITEM 7. CMS ENERGY MANAGEMENT'S DISCUSSION AND ANALYSIS -
OUTLOOK - CONSUMERS' GAS UTILITY OUTLOOK, and ITEM 7. CONSUMERS' MANAGEMENT'S
DISCUSSION AND ANALYSIS - OUTLOOK - GAS UTILITY OUTLOOK.
RETAIL WHEELING PROCEEDINGS: In April 1994, the MPSC issued an opinion and
interim order that approved the framework for a five-year experimental retail
direct-access program for "wheeling" of electric power purchased by customers
from other suppliers over the transmission systems of Consumers and Detroit
Edison. No customers ever took service under this program. After various
appeals, in June 1999, the Michigan Supreme Court held that the MPSC does not
have statutory authority to order a utility to provide a mandatory retail
wheeling service. For additional information concerning the MPSC order and
appeals, see ITEM 7. CMS ENERGY MANAGEMENT'S DISCUSSION AND ANALYSIS - OUTLOOK -
CONSUMERS' ELECTRIC UTILITY OUTLOOK - RESTRUCTURING, ITEM 8. FINANCIAL
STATEMENTS AND SUPPLEMENTARY DATA - NOTE 4 TO CMS ENERGY'S NOTES TO CONSOLIDATED
FINANCIAL STATEMENTS, ITEM 7. CONSUMERS' MANAGEMENT'S DISCUSSION AND
ANALYSIS - OUTLOOK - ELECTRIC UTILITY OUTLOOK - RESTRUCTURING and ITEM 8.
FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA - NOTE 2 TO CONSUMERS' NOTES TO
CONSOLIDATED FINANCIAL STATEMENTS.
FEDERAL ENERGY REGULATORY COMMISSION
FERC has limited rate jurisdiction over several independent power projects and
some exempt wholesale generators in which CMS Generation and Panhandle have
ownership interests. FERC also has more comprehensive jurisdiction over Michigan
Gas Storage, Panhandle Eastern Pipe Line Company, and Trunkline as natural gas
companies within the meaning of the Natural Gas Act. FERC jurisdiction relates,
among other things, to the acquisition, operation and disposal of assets and
facilities and to the service provided and rates charged. Under certain
circumstances, FERC also has the power to modify gas tariffs of interstate
pipeline companies. Some of Consumers' gas business is also subject to
regulation by FERC, including a blanket transportation tariff pursuant to which
Consumers can transport gas in interstate commerce.
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FERC has authority to regulate rates and charges for natural gas transported in
or stored for interstate commerce or sold by a natural gas company in interstate
commerce for resale. FERC also has authority over the construction and operation
of pipeline and related facilities utilized in the transportation and sale of
natural gas in interstate commerce, including the extension, enlargement or
abandonment of such facilities. Panhandle Eastern Pipe Line Company, Trunkline,
and Pan Gas Storage hold certificates of public convenience and necessity issued
by the FERC, authorizing them to construct and operate the pipelines, facilities
and properties now in operation for which such certificates are required, and to
transport and store natural gas in interstate commerce. See ITEM 8. FINANCIAL
STATEMENTS AND SUPPLEMENTARY DATA - NOTE 3 TO PANHANDLE'S NOTES TO CONSOLIDATED
FINANCIAL STATEMENTS, incorporated by reference herein.
Certain aspects of Consumers' electric operations are also subject to regulation
by FERC, including:
- - compliance with FERC's accounting rules and other regulations under the
Federal Power Act;
- - the transmission of electric energy in interstate commerce;
- - the rates and charges for the sale of electric energy at wholesale and
transmission of electrical energy in interstate commerce;
- - the transfer of certain assets, including transfers by corporate
mergers, the sale of certain facilities;
- - the construction, operation and maintenance of hydroelectric projects;
and
- - the issuance of securities, as provided by the Federal Power Act.
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FERC regulations, together with the 1992 enactment of the Energy Policy Act
have effectively granted independent power producers and electricity marketers
"direct access" to the interstate electric transmission systems owned by
electric utilities. All electric utilities are required to offer transmission
services to new market entrants on a non-discriminatory basis under tariffs
approved by the FERC. For a discussion of the effect of certain FERC Orders on
Consumers, see ITEM 7. CMS ENERGY'S MANAGEMENT'S DISCUSSION AND ANALYSIS -
OUTLOOK - CONSUMERS' ELECTRIC UTILITY OUTLOOK and ITEM 7. CONSUMERS'
MANAGEMENT'S DISCUSSION AND ANALYSIS - OUTLOOK - ELECTRIC UTILITY OUTLOOK. For a
discussion of the effect of certain FERC orders on Panhandle see ITEM 7.
PANHANDLE'S MANAGEMENT'S DISCUSSION AND ANALYSIS - OTHER MATTERS - REGULATORY
MATTERS and ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA - NOTE 3 TO
PANHANDLE'S NOTES TO CONSOLIDATED FINANCIAL STATEMENTS.
NUCLEAR REGULATORY COMMISSION
Under the Atomic Energy Act of 1954, as amended, and the Energy Reorganization
Act of 1974, Consumers is subject to the jurisdiction of the NRC with respect to
the design, construction, operation and decommissioning of its nuclear power
plants. Consumers is also subject to NRC jurisdiction with respect to certain
other uses of nuclear material. These and other matters concerning Consumers'
nuclear plants are more fully discussed in ITEM 8. FINANCIAL STATEMENTS AND
SUPPLEMENTARY DATA - NOTES 2 AND 4 TO CMS ENERGY'S CONSOLIDATED FINANCIAL
STATEMENTS, and ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA - NOTES 1
AND 2 TO CONSUMERS' CONSOLIDATED FINANCIAL STATEMENTS.
OTHER REGULATION
Regulation of the importation and exportation of natural gas is vested in the
Secretary of Energy, who has delegated various aspects of this jurisdiction to
Office of Fossil Fuels of the Department of Energy.
Panhandle is also subject to the Natural Gas Pipeline Safety Act of 1968, which
regulates gas pipeline safety requirements, and to the Hazardous Liquid Pipeline
Safety Act of 1979, which regulates oil and petroleum pipelines.
CMS ENERGY, CONSUMERS AND PANHANDLE ENVIRONMENTAL COMPLIANCE
CMS Energy, Consumers and Panhandle and their subsidiaries are subject to
various federal, state and local regulations for environmental quality,
including air and water quality, waste management, zoning and other matters.
Management believes that the responsible administration of CMS Energy's,
Consumers' and Panhandle's energy resources includes reasonable programs for the
protection and enhancement of the environment. For additional information
concerning environmental matters, see ITEM 8. FINANCIAL STATEMENTS AND
SUPPLEMENTARY DATA - NOTE 4 OF CMS ENERGY'S NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS and ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA - NOTE 2 OF
CONSUMERS' NOTES TO CONSOLIDATED FINANCIAL STATEMENTS. For additional
information on Panhandle's environmental matters, see ITEM 7. PANHANDLE'S
MANAGEMENT'S DISCUSSION AND ANALYSIS - ENVIRONMENTAL MATTERS and ITEM 8.
PANHANDLE'S FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA - NOTE 11 - COMMITMENTS
AND CONTINGENCIES ENVIRONMENTAL MATTERS.
Consumers installed modern stack emission control and monitoring systems at its
electric generating plants and converted electric generating units to burn
cleaner fuels. It has worked with others to use bottom ash as
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final cover for ash disposal areas in place of topsoil and compacted clay.
Consumers also sells fly ash for use as a filler for asphalt and for
incorporation into concrete products. It has also worked with local, state and
national organizations on waste minimization and pollution prevention
initiatives. Such work includes enhancing particular Consumers' lands for the
benefit of wildlife, and providing recreational access to its lands. Finally, it
has worked with universities and other institutions on projects to protect and,
in some instances, propagate threatened or endangered species. This effort
included making financial contributions to a variety of environmental
enhancement projects. Capital expenditures by Consumers for environmental
protection additions were $37 million in 1999. Consumers estimates 2000
expenditures at $103 million.
Federal and state laws require air permits for certain of Consumers',
Panhandle's and CMS Generation's affiliates' air emission sources. These laws
require that certain affected facilities control their sources' air emissions.
The appropriate agency or department for environmental protection in the state
in which each facility is located has issued permits for that facility and other
affected sources of air emissions. Consumers, Panhandle and CMS Generation
believe that these facilities are in substantial compliance with all air
permits.
Consumers has engaged in an aggressive testing and removal program for USTs.
Since 1985, Consumers and its subsidiaries have reduced the number of regulated
UST systems from 256 to 16. At 118 of the sites from which Consumers or its
subsidiaries removed UST systems, hydrocarbon releases occurred, either from
tank system leaks or from spillage on the surface during transfer of contents to
or from the tanks. Consumers' response activities resulted in Department of
Natural Resources/Department of Environmental Quality concurrence in closure of
115 of those releases. The remaining releases are at various stages of cleanup
completion.
Like most electric utilities, Consumers has PCB in some of its electrical
equipment. Although it has been unlawful to manufacture or sell PCB or PCB
contaminated equipment since the 1970s, its continued use in preexisting
electrical equipment is lawful. Consumers has engaged in a number of programs to
reduce the risk of exposure to the environment from possible PCB spills. These
include such actions as a contingency program of removing PCB capacitors outside
of substations and replacing them with non-PCB capacitors, draining large
transformers and refilling them with non-PCB mineral oil, and removing PCB
equipment that was found to pose a risk to food supplies or animal feed.
Consumers still has a few PCB capacitors in substations. It has nearly 500,000
distribution transformers, many of which have not been tested for PCB. By
regulation, unless the PCB level is known, mineral oil transformers built before
July 2, 1979, are presumed to be PCB-contaminated. Other types of electrical
equipment may also contain PCB. Based upon results of sampling in 1981, about 1
percent of the pole-top transformers had more than 500 ppm of PCB, and about 12
percent had from 50 to 500 ppm. Those percentages should decline over time with
the retirement of older equipment and its replacement with non-PCB equipment.
From time to time, accidental releases occur from such equipment. Consumers
typically spends less than $1 million per year for the clean up and disposal of
debris and equipment from PCB releases.
National Pollutant Discharge Elimination System and equivalent State Pollutant
Discharge Elimination System permits, as well as state ground water discharge
permits, authorize the discharge of certain waste waters from Consumers'
facilities and pipeline construction projects and certain CMS Generation
affiliates' facilities pursuant to state water quality standards and federal
effluent limitation guidelines. The appropriate agency or department for
environmental protection issued authorizations for discharges from all of
Consumers' and certain CMS Generation affiliates' major operating steam electric
generating facilities and for certain discharges from Consumers' other
facilities, including hydroelectric projects and pipeline construction projects.
Consumers and CMS Generation affiliates believe that these facilities are in
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substantial compliance with National or State Pollutant Discharge Elimination
System and groundwater discharge/exemption permits.
Certain environmental regulations affecting Panhandle include, but are not
limited to:
- - The Clean Air Act Amendments of 1990; and
- - The Comprehensive Environmental response, Compensation and Liability Act
(CERCLA), which can require any individual or entity which may have owned or
operated a disposal site, as well as transporters or generators of
hazardous wastes which were sent to such site, to share in remediation
costs for the site.
Consumers', CMS Energy's and Panhandle's current insurance coverages do not
extend to certain environmental clean-up costs, such as claims for air
pollution, some past PCB contamination and for some long-term storage or
disposal of pollutants.
For discussion of environmental matters involving Panhandle, including possible
liability and capital costs, see ITEM 7. PANHANDLE'S MANAGEMENT'S DISCUSSION AND
ANALYSIS OF RESULTS OF OPERATIONS AND FINANCIAL CONDITION, CURRENT ISSUES -
ENVIRONMENTAL and NOTE 11 TO PANHANDLE'S CONSOLIDATED FINANCIAL STATEMENTS,
COMMITMENTS AND CONTINGENCIES - ENVIRONMENTAL. Compliance with federal, state
and local provisions regulating the discharge of materials into the environment,
or otherwise protecting the environment, is not expected to have a material
adverse effect on the competitive position, consolidated results of operations
or financial position of Panhandle.
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CMS ENERGY, CONSUMERS AND PANHANDLE COMPETITION
ELECTRIC COMPETITION
Consumers' electric utility business experiences competition, actual and
potential, from many sources, both in the wholesale and retail markets, and in
electric generation, electric delivery, and retail services.
In the wholesale electricity markets, Consumers competes with other wholesale
suppliers, marketers and brokers. Electric competition in the wholesale markets
increased significantly since 1996 due to FERC Order 888. However, wholesale for
retail transactions by Consumers generated an immaterial amount of Consumers'
1999 revenues from electric operations, Consumers does not believe future loss
of wholesale for retail sales to be significant. In most instances, the
customers will continue to be transmission customers even if they cease to be
generation customers.
A significant increase in retail electric competition is likely to occur with
the introduction of retail direct access in Michigan. In a January 1998 order,
the MPSC ordered retail direct access in Michigan. The MPSC order, as
supplemented by additional MPSC orders issued later, as discussed above in CMS
ENERGY, CONSUMERS AND PANHANDLE REGULATION - Michigan Public Service Commission
- - MPSC Regulatory Changes, calls for Consumers gradually to open its electric
customer power supply requirement to competition from 1999 through 2001. The
MPSC order gives all customers the right to choose their own electric supplier
by January 1, 2002. Consumers' financial exposure to competition in a retail
direct-access environment is limited due to: 1) the expectation of recovery of
related Transition Costs attributable to retail direct access; 2) residential
and small business customers decisions to remain with Consumers; and 3) the fact
that Consumers will still be the deliverer of electricity.
Absent comprehensive deregulation in the retail electric commodity markets,
Consumers has competition or potential competition from the following sources:
1) from the threat of customers relocating outside Consumers' service territory;
2) from the possibility of municipalities owning or operating competing electric
delivery systems; 3) from customer co-generation and self-generation; 4) from
adjacent municipal utilities that extend lines to customers near service
territory boundaries; and 5) from marketers and brokers for customers under the
previously implemented Consumers' direct-access programs. Consumers addressed
this competition primarily through the offering of rate discounts and additional
services. If municipalization occurred, Consumers believes it would be entitled
to recovery of appropriate Transition Costs, thus mitigating the potential
negative financial impact.
Consumers is beginning to offer non-commodity retail services to electric
customers, and faces competition from many sources including energy management
services companies, other utilities, contractors, and retail merchandisers.
CMS Energy's non-regulated electric subsidiaries primarily face competition from
other marketers, brokers, financial management firms, energy management firms,
and other utilities through the marketing services and trading business segment;
and from other generators, marketers, brokers, and price of power on the
wholesale market through the independent power production business segment.
For additional information concerning electric competition, see ITEM 7. CMS
ENERGY'S MANAGEMENT'S DISCUSSION AND ANALYSIS - OUTLOOK - CONSUMERS' ELECTRIC
UTILITY OUTLOOK and ITEM 7. CONSUMERS MANAGEMENT'S DISCUSSION AND ANALYSIS -
OUTLOOK - ELECTRIC BUSINESS OUTLOOK.
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GAS COMPETITION
Competition has existed for several years, and is likely to increase, in various
aspects of Consumers' gas business. Competition traditionally comes from
alternate fuels and energy sources, such as propane, oil, and electricity.
Increasingly, competition comes from other suppliers of the natural gas
commodity.
The Natural Gas Policy Act of 1978 resulted in the deregulation of wellhead gas
prices. Supply and demand effects of the gas production marketplace substituted
for the regulation. Gas competition among various wellhead suppliers
subsequently increased. Order 636 effectively unbundled the transportation of
natural gas from the sale of natural gas by interstate pipelines. This Order
required pipelines to become common carriers. Consequently, pipelines must
compete for shippers in search of low-priced transportation capacity. Consumers
offers unbundled services (transportation and some storage) to its larger
end-use customers who choose to acquire gas supplies from alternative sources.
Traditionally, Consumers' earnings for its gas business have not been dependent
upon gas purchased and resold to customers because of gas cost recovery
provisions in Michigan's Public Act 304. However, in a proactive move by
Consumers to prepare for an unbundled market, where gas commodity supply is
separated from gas distribution, Consumers filed a request to conduct an
expanded experimental gas customer choice program which will be effective until
April 2001.
Consumers is aggressively pursuing legislation to give all Michigan consumers a
choice of natural gas suppliers permanently. While the prospect of passage by
the Michigan Legislature is uncertain, such legislation could have a significant
impact on the Consumers' natural gas business. See the discussion of the MPSC's
order authorizing the expanded experimental gas program above in CMS ENERGY,
CONSUMERS AND PANHANDLE REGULATION - MPSC REGULATORY CHANGES.
CMS Energy's non-utility gas subsidiaries face significant competition from
other gas pipeline companies, gas producers, gas storage companies, and
brokers/marketers.
For additional information concerning gas competition, see ITEM 7. CMS ENERGY'S
MANAGEMENT DISCUSSION AND ANALYSIS - OUTLOOK, ITEM 7. CONSUMERS' MANAGEMENT'S
DISCUSSION AND ANALYSIS - OUTLOOK and ITEM 7. PANHANDLE'S MANAGEMENT'S
DISCUSSION AND ANALYSIS - OUTLOOK.
PANHANDLE COMPETITION
Panhandle's interstate pipelines compete with other interstate and intrastate
pipeline companies in the transportation and storage of natural gas. The
principal elements of competition among pipelines are rates, terms of service
and flexibility and reliability of service. Panhandle competes directly with ANR
Pipeline Company, Natural Gas Pipeline Company of America and Texas Gas
Transmission Corporation in the Midwest market area.
Natural gas competes with other forms of energy available to Panhandle's
customers and end-users, including electricity, coal and fuel oils. The primary
competitive factor is price. Changes in the availability or price of natural gas
and other forms of energy, the level of business activity, conservation,
legislation and governmental regulations, the capability to convert to
alternative fuels, and other factors, including weather, affect the demand for
natural gas in the areas served by Panhandle.
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EMPLOYEES
CMS ENERGY
As of December 31, 1999, CMS Energy and its subsidiaries, including Consumers
and Panhandle, had 11,462 full-time equivalent employees of which 11,324 are
full-time employees and 138 full-time equivalent employees associated with the
part-time work force. Included in the total are 4,007 employees who are covered
by union contracts.
CONSUMERS
As of December 31, 1999, Consumers and its subsidiaries had 8,799 full-time
equivalent employees of which 8,674 are full-time employees and 125 full-time
equivalent employees associated with the part-time work force. Included in the
total are 3,759 full-time operating, maintenance and construction employees of
Consumers who are represented by the Union. Consumers and the Union negotiated a
collective bargaining agreement that became effective as of June 1, 1995. By its
terms, it will continue in full force and effect until June 1, 2000.
PANHANDLE
At December 31, 1999, Panhandle had 1,060 full-time equivalent employees. Of
these employees, 248 were represented by the Paper, Allied-Industrial Chemical
and Energy Workers International Union, AFL-CIO, CLC.
CMS ENERGY, CONSUMERS AND PANHANDLE FORWARD-LOOKING STATEMENTS CAUTIONARY
FACTORS.
The Private Securities Litigation Reform Act of 1995 provides a "safe harbor"
for forward-looking statements to encourage such disclosures without the threat
of litigation, providing those statements are identified as forward-looking and
are accompanied by meaningful, cautionary statements identifying important
factors that could cause the actual results to differ materially from those
projected in the statement. Forward-looking statements give our expectations or
forecasts of future events. You can identify these statements by the fact that
they do not relate strictly to historical or current facts. Forward-looking
statements have been and will be made in this Item 1, MD&A and in our other
written documents (such as press releases, visual presentations, and securities
disclosure documents) and oral presentations (such as analyst conference calls).
Such statements are based on management's beliefs as well as assumptions made by
and information currently available to management. When used in our documents or
oral presentations, the words "anticipate", "believe", "estimate", "expect",
"forecast", "intend", "objective", "plan", "possible", "potential", "project"
and variations of such words and similar expressions are intended to identify
forward-looking statements that involve risk and uncertainty.
Any or all of our forward-looking statements in oral or written statements or in
other publications may turn out to be wrong. They can be affected by inaccurate
assumptions or by known or unknown risks and uncertainties. Many such factors
will be important in determining our actual future results. Consequently, no
forward-looking statement can be guaranteed.
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In addition to any assumptions and other factors referred to specifically in
connection with such forward-looking statements, factors that could cause our
actual results to differ materially from those contemplated in any
forward-looking statements include, among others, the following:
- - ability to sell assets in accordance with our plans;
- - ability to achieve operating synergies and revenue enhancements;
- - capital and financial market conditions, including:
- current price of our common stock,
- interest rates and availability of financing,
- market perceptions of the energy industry, our company, or
any of our subsidiaries,
- our, or any of our subsidiaries', securities ratings, and
- currency exchange controls;
- - factors affecting utility and diversified energy operations, such as:
- unusual weather conditions,
- catastrophic weather-related damage,
- unscheduled generation outages, maintenance or repairs,
- unanticipated changes to fossil fuel, nuclear fuel or gas
supply costs or availability due to higher demand, shortages,
transportation problems or other developments,
- environmental incidents, or
- electric transmission or gas pipeline system constraints;
- - international, national, regional and local economic, competitive and
regulatory conditions and developments, particularly the trade,
monetary, fiscal, taxation and environmental policies of governments,
agencies and similar organizations in geographic areas where we have a
financial interest;
- - adverse regulatory or legal decisions, including:
- a possible MPSC order to reduce rates or refund alleged
excess revenues in resolution of a complaint by ABATE, and
- environmental laws and regulations;
- - pace, implementation and provisions for deregulation of the natural gas
and electric industries whether by legislative or regulatory action,
particularly:
- the ability of the electric utility business to purchase
energy at prices below that allowed in its rates due to
frozen power supply cost recovery,
- the ability of the gas utility to protect against gas price
increases due to implementation of a suspended gas cost
recovery,
- the extension of the direct access pilot program to all our
gas utility business customers,
- the ability of our electric utility business to recover its
current investment in generating facilities and the cost of
purchased power,
- the number of customers that will elect other power suppliers
when customer choice becomes available to them,
- former customers generating their own power, and
- new pricing structures;
- - federal regulation of electric sales and transmission of electricity
that grants independent power producers and electricity marketers
"direct access" to the interstate electric transmission systems owned
by electric utilities, creating opportunity for competitors to market
electricity to our wholesale customers;
- - energy markets, including the timing and extent of unanticipated
changes in commodity prices for oil, coal, natural gas, natural gas
liquids, electricity and certain related products due to higher demand,
shortages, transportation problems or other developments;
- - the timing and success of business development efforts, including:
- significant sums of money spent for international development
start-up and obtaining financing is at risk until all
elements of the project development are successfully
finalized,
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- international projects may be expropriated, required
agreements, licenses, permits and other approvals may be
changed or terminated in violation of their terms, or newer
or higher taxes may be imposed upon the project,
- the local foreign currency may be devalued or the conversion
of the currency may be restricted or prohibited or other
actions may be taken which adversely affect the value and the
recovery of the investment such as taxes, royalties, or
import duties being increased, and
- adverse financial, operating, management, or other issues
with project partners;
- - the increased competition caused by Federal Energy Regulatory
Commission approval of new pipeline and pipeline expansion projects
that transport large additional volumes of natural gas to the Midwest
from Canada, which could reduce volumes of gas transported by our
natural gas transmission businesses or cause them to lower rates in
order to meet competition;
- - potential disruption, expropriation or interruption of facilities or
operations due to accidents or political events;
- - nuclear power performance, decommissioning, policies, procedures,
incidents, and regulation, including spent nuclear fuel storage
availability;
- - technological developments in energy production, delivery and usage
that may result in competitive disadvantages and create the potential
for impairment of existing assets;
- - financial or regulatory accounting principles or policies imposed by
the Financial Accounting Standards Board, the Securities and Exchange
Commission, the Federal Energy Regulatory Commission, the Michigan
Public Service Commission and similar entities with regulatory
oversight;
- - cost and other effects of legal and administrative proceedings,
settlements, investigations and claims;
- - certain project investments made by our subsidiaries consist of
minority interests, and some future investments may take the form of
minority interests, which limits our ability to control the development
or operation of the project;
- - other uncertainties, all of which are difficult to predict and many of
which are beyond our control; and
- - other business or investment considerations that may be disclosed from
time to time in CMS Energy's, Consumers' or Panhandle's Securities and
Exchange Commission filings or in other publicly disseminated written
documents.
CMS Energy, Consumers, Panhandle and their affiliates undertake no obligation to
update or revise any forward-looking statements, whether as a result of new
information, future events or otherwise. The foregoing review of factors
pursuant to the Private Securities Litigation Reform Act should not be construed
as exhaustive or as any admission regarding the adequacy of our disclosures
prior to the effective date of the Act. Certain risk factors are detailed from
time to time in our various public filings. You are advised, however to consult
any further disclosures we make on related subjects in our reports to the
Securities and Exchange Commission. In particular, you should read the
discussion in the section entitled "Forward-Looking Statements" in our most
recent reports to the Securities and Exchange Commission on Form 10-Q or Form
8-K filed subsequent to this Form 10-K.
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CMS ENERGY AND CONSUMERS EXECUTIVE OFFICERS
As of February 29, 2000
Name Age Position Period
- ---- --- -------- ------
William T. McCormick, Jr. 55 Chairman of the Board and Chief
Executive Officer of CMS Energy 1987-Present
Chairman of the Board of Consumers 1985-Present
Chairman of the Board of Enterprises 1987-Present
Chairman of the Board and Chief
Executive Officer of Enterprises 1987-1995
Victor J. Fryling 52 President and Chief Operating Officer
of CMS Energy 1996-Present
Vice Chairman of the Board and President
of Consumers 1998-Present
President and Chief Executive Officer
of Enterprises 1995-Present
President of Consumers 1997-1998
President of CMS Energy 1992-1995
President of Enterprises 1993-1995
John W. Clark 55 Senior Vice President of CMS Energy 1987-Present
Senior Vice President of Consumers 1985-Present
James W. Cook 59 Senior Vice President of CMS Energy 1995-Present
Senior Vice President of Enterprises 1994-Present
Executive Vice President of Enterprises 1989-1994
President and Chief Executive Officer
of CMS Generation 1989-1995
Preston D. Hopper 49 Senior Vice President, Controller and
Chief Accounting Officer of CMS Energy 1996-Present
Senior Vice President and Chief
Accounting Officer of Enterprises 1997-Present
Vice President, Controller and
Chief Accounting Officer of CMS Energy 1992-1996
Senior Vice President and Controller of
Enterprises 1996-1997
Vice President and Controller of
Enterprises 1992-1996
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Name Age Position Period
---- --- -------- ------
Rodger A. Kershner 51 Senior Vice President and General
Counsel of CMS Energy 1996-Present
Senior Vice President and General
Counsel of Enterprises 1996-Present
Vice President, General Counsel
and Assistant Secretary of Enterprises 1989-1995
Deputy General Counsel and Assistant
Secretary of CMS Energy 1994-1995
Alan M. Wright 54 Senior Vice President and Chief
Financial Officer of CMS Energy 1998-Present
Senior Vice President and Chief
Financial Officer of Consumers 1993-Present
Senior Vice President and Chief
Financial Officer of Enterprises 1998-Present
Senior Vice President, Chief Financial
Officer and Treasurer of Enterprises 1994-1998
Senior Vice President, Chief Financial
Officer and Treasurer of CMS Energy 1994-1998
Rodney E. Boulanger 59 Senior Vice President of Enterprises 1996-Present
President and Chief Executive Officer
of CMS Generation 1995-Present
Carl L. English 53 Executive Vice President of Consumers
and President and Chief Executive
Officer - Gas Business Unit 1999-Present
Vice President of Consumers 1990-1999
Bradley W. Fischer 53 President and Chief Executive Officer
of CMS Oil and Gas 1998-Present
Vice President of CMS Oil and Gas 1997-1998
William J. Haener 58 Senior Vice President of Enterprises 1998-Present
President and Chief Executive Officer
of CMS Gas Transmission 1994-Present
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Name Age Position Period
- ---- --- -------- ------
David W. Joos 46 Executive Vice President of Consumers
and President and Chief Executive
Officer - Electric Business Unit 1997-Present
Executive Vice President of Consumers
and Chief Operating Officer -
Electric Business Unit 1994-1997
Senior Vice President of Consumers 1994-1994
Vice President of Consumers 1990-1994
Tamela W. Pallas 42 President and Chief Operating Officer
of CMS MST 1999-Present
Christopher A. Helms 45 President and Chief Operating Officer
of Panhandle Eastern Pipe Line Company 1999-Present
Robert A. Fenech 52 Senior Vice President of Consumers 1997-Present
Vice President of Consumers 1994-1997
Doris F. Galvin 45 Senior Vice President of CMS
Enterprises 1999-Present
Vice President and Treasurer of
CMS Energy 1998-1999
Vice President and Treasurer of
CMS Enterprises 1998-1999
Treasurer of CMS Oil and Gas 1997-1999
Vice President and Treasurer of
Consumers 1993-1999
David A. Mikelonis 51 Senior Vice President and General
Counsel of Consumers 1988-Present
Paul N. Preketes 50 Senior Vice President of Consumers 1999-Present
Vice President of Consumers 1994-1999
Dennis DaPra 57 Vice President and Controller of
Consumers 1991-Present
Ms. Pallas has served as President and Chief Operating Officer of CMS MST since
November 1999. From 1997 until November 1999, Ms. Pallas served as Senior Vice
President of Reliant Energy. From 1992 until 1997, Ms. Pallas was employed by
Basis Energy as a Senior Vice President.
Mr. Helms has served as President and Chief Operating Officer of Panhandle
Eastern Pipe Line Company since March 1999. From 1993 through March 1999, Mr.
Helms served as Director of Corporate Development and Vice President of
Corporate Affairs, respectively, of Duke Energy Corporation.
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Mr. DaPra is an executive officer of Consumers but not of CMS Energy.
The present term of office of each of the executive officers extends to the
first meeting of the Board of Directors after the next annual election of
Directors of each of CMS Energy and Consumers (scheduled to be held on May 26,
2000).
There are no family relationships among executive officers and directors of CMS
Energy and Consumers.
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ITEM 2. PROPERTIES.
CHARACTER OF OWNERSHIP
The principal properties of CMS Energy, Consumers and their subsidiaries are
owned in fee, except that most electric lines and gas mains are located,
pursuant to easements and other rights, in public roads or on land owned by
others. The statements under this item as to ownership of properties are made
without regard to tax and assessment liens, judgments, easements, rights of way,
contracts, reservations, exceptions, conditions, immaterial liens and
encumbrances, and other outstanding rights. None of these outstanding rights
impair the usefulness of such properties.
Substantially all of Consumers' properties are subject to the lien of its First
Mortgage Bond Indenture. Substantially all properties of the subsidiaries of CMS
Generation that own interests in operating plants are subject to liens of
creditors of the respective subsidiaries. Properties of certain Consumers, CMS
Gas Transmission and CMS Oil and Gas subsidiaries are also subject to liens of
creditors of the respective subsidiaries.
CONSUMERS ELECTRIC UTILITY PROPERTIES
At December 31, 1999, Consumers' electric generating system consists of four
fossil-fueled coal plant sites, one oil/gas plant, one gas plant, one pumped
storage hydroelectric facility, one nuclear plant, eight gas combustion turbine
plants and 13 conventional hydroelectric plants.
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1999 Summer Net 1999 Net
Demonstrated Generation
Size and Year Capability (Thousands
Name and Location (Michigan) Entering Service (Kilowatts) of kWhs)
- ------------------------------------------------------------------------------------------------------------
COAL GENERATION
J H Campbell 1&2 - West Olive 2 Units, 1962-1967 609,000 4,012,534
J H Campbell 3 - West Olive 1 Unit, 1980 737,100(a) 5,279,004
D E Karn - Essexville 2 Units, 1959-1961 515,000 3,515,678
B C Cobb - Muskegon 2 Units, 1956-1957 300,000 2,087,808
J R Whiting - Erie 3 Units, 1952-1953 310,000 2,110,618
J C Weadock - Essexville 2 Units, 1955-1958 310,000 2,079,779
-----------------------------------
Total coal generation 2,781,100 19,085,421
-----------------------------------
OIL/GAS GENERATION
B C Cobb - Muskegon 1 Unit, 1999 60,000(b) 27,113
D E Karn - Essexville 2 Units, 1975-1977 1,276,000 1,160,699
-----------------------------------
Total oil/gas generation 1,336,000 1,187,812
-----------------------------------
LUDINGTON PUMPED STORAGE 6 Units, 1973 954,700(c) (475,561)(d)
-----------------------------------
NUCLEAR GENERATION
Palisades - South Haven 1 Unit, 1971 760,000 5,104,581
-----------------------------------
GAS/OIL COMBUSTION TURBINE
GENERATION 8 Plants, 1966-1999 346,800(e) 62,415
-----------------------------------
CONVENTIONAL HYDRO GENERATION 13 Plants, 1907-1949 73,500 364,684
-----------------------------------
Total owned generation 6,252,100 25,329,352
==========
PURCHASED AND INTERCHANGE POWER CAPACITY 1,824,500(f)
Total 8,076,600
============================================================================================================
(a) Represents Consumers' share of the capacity of the Campbell Plant Unit 3,
net of 6.69 percent (ownership interests of the Michigan Public Power Agency and
Wolverine Power Supply Cooperative, Inc.).
(b) Consumers is in the process of converting two previously retired B C Cobb
coal units to natural gas. The conversion of these units, totaling 120 MW, is
expected to be completed mid-year 2000.
(c) Represents Consumers' share of the capacity of Ludington. Consumers and
Detroit Edison have 51 percent and 49 percent undivided ownership, respectively,
in the plant, and the capacity of the plant is shared accordingly.
(d) Represents Consumers' share of net pumped storage generation. This facility
electrically pumps water during off-peak hours for storage to later generate
electricity during peak-demand hours.
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(e) Includes 1.8 MW diesel generator entering service in 1999.
(f) This amount includes: (i) dispatchable and must-take contracts with a
duration of six-months or longer, including 1,240 MW of purchase contract
capacity from the MCV Facility, and (ii) an obligation of approximately 52 MW to
the co-owners of the Campbell 3 Units which is not otherwise reflected in
purchased capacity in ITEM 1. BUSINESS - CONSUMERS ELECTRIC UTILITY OPERATIONS.
This amount does not include (A) 128 MW of purchased capacity not required to be
included prior to the year 2000 under certain regulations and capacity being
used as back-up service and (B) 488 MW (net) of contracts with a duration less
than 6 months; whereby both (A) and (B) are reflected in purchased capacity in
ITEM 1. BUSINESS - CONSUMERS ELECTRIC UTILITY OPERATIONS.
Consumers owns 8,640 miles of electric transmission lines operating at up to 345
kilovolts, owns 60,456 miles of electric distribution lines and owns substations
having an aggregate transformer capacity of 40,452,870 kilovoltamperes.
CONSUMERS GAS UTILITY PROPERTIES
Consumers' gas distribution and transmission system consists of 23,933 miles of
distribution mains and 1,156 miles of transmission lines throughout the lower
peninsula of Michigan. Consumers owns and operates six compressor stations with
a total of 115,400 installed horsepower.
Consumers' gas storage fields, listed below, have an aggregate storage capacity
of 221.3 bcf.
Field Name Location Storage Capacity (bcf)
- ------------------------------------------------------------------------------------------------------
Overisel Allegan and Ottawa Counties 62.0
Salem Allegan and Ottawa Counties 35.0
Ira St Clair County 6.8
Lenox Macomb County 3.5
Ray Macomb County 64.5
Northville Oakland, Washtenaw and Wayne Counties 12.1
Puttygut St Clair County 14.6
Four Corner St Clair County 3.8
Swan Creek St Clair County .6
Hessen St Clair County 17.0
Lyon - 34 Oakland County 1.4
======================================================================================================
Michigan Gas Storage owns and operates two compressor stations with a total of
46,600 installed horsepower. Its transmission system consists of 518 miles of
pipelines within the lower peninsula of Michigan.
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Michigan Gas Storage's gas storage fields, listed below, have an aggregate
certified storage capacity of 109.5 bcf.
Total Certified
Field Name Location Storage Capacity (bcf)
- ------------------------------------------------------------------------------------------------
Winterfield Osceola and Clare Counties 72.3
Cranberry Lake Clare and Missaukee Counties 28.2
Riverside Missaukee County 9.0
================================================================================================
In April 1998, Consumers sold gas properties related to the Marysville Gas
Reforming Plant, located in Marysville, Michigan. In addition, Huron
Hydrocarbons, Inc., which is a wholly-owned subsidiary of Consumers, sold its
ownership in St. Clair Underground Storage. These facilities were sold to an
affiliate of Consumers, CMS Gas Transmission and Storage Company. The effective
date of the sale was January 1, 1998.
CMS ENERGY OIL AND GAS EXPLORATION AND PRODUCTION PROPERTIES
Net oil and gas production by CMS Oil and Gas for the years 1997 through 1999 is
shown in the following table.
1999 1998 1997
- ---------------------------------------------------------------------------------------------
Oil and condensate (Mbbls) (a) 7,288 7,307 6,564
Natural gas (MMcf) (a) 26,412 26,495 27,157
Plant products (Mbbls) (a) 396 413 321
Average daily production (b)
Oil (Mbbls) 24.8 23.8 20.5
Gas (MMcf) 119.6 89.3 89.1
Reserves to annual production ratio
Oil (MMbbls) 15.2 11.5 14.3
Gas (bcf) 29.9 21.3 11.9
=============================================================================================
(a) Revenue interest to CMS Oil and Gas
(b) CMS Oil and Gas working interest (includes CMS Oil and Gas' share of
royalties)
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The following table shows CMS Oil and Gas' undeveloped net acres of oil and gas
leasehold interests.
December 31 1999 1998
- --------------------------------------------------------------------------------------------
Wyoming 177,691 137,098
Montana 96,994 107,242
Michigan 71,718 113,911
Texas (including offshore acreage) 50,735 18,657
Indiana 12,212 10,293
Ohio 6,887 9,394
Louisiana (including offshore acreage in 1998) 3,480 4,155
Other states - 583
----------------------------------
Total domestic 419,717 401,333
----------------------------------
Venezuela 339,521 339,521
Colombia 251,680 294,157
Cameroon 187,636 187,636
Equatorial Guinea 148,977 117,366
Ecuador 66,430 66,430
Tunisia 64,761 64,761
Congo 17,364 17,364
Cote d'Ivoire - 89,868
----------------------------------
Total international 1,076,369 1,177,103
----------------------------------
Total net acres 1,496,086 1,578,436
============================================================================================
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The following table shows CMS Oil and Gas' estimated proved reserves of oil and
gas for the years 1997 through 1999.
Total Worldwide United States International
- -----------------------------------------------------------------------------------------------------------------
Oil Gas Oil Gas Oil Gas
(MMbbls) (bcf) (MMbbls) (bcf) (MMbbls) (bcf)
- -----------------------------------------------------------------------------------------------------------------
PROVED DEVELOPED AND
UNDEVELOPED RESERVES
December 31, 1996 76.4 323.2 1.8 273.7 74.6 49.5
Revisions and other changes 10.6 6.4 0.2 (7.2) 10.4 13.6
Extensions and discoveries 9.9 26.3 0.3 14.6 9.6 11.7
Acquisitions of reserves 8.3 - - - 8.3 -
Sales of reserves - (6.5) - (6.5) - -
Production (6.9) (27.2) (0.7) (26.5) (6.2) (0.7)
--------------------------------------------------------------------
December 31, 1997 98.3 322.2 1.6 248.1 96.7 74.1
Revisions and other changes (8.2) (27.4) 0.5 (28.8) (8.7) 1.4
Extensions and discoveries 3.3 278.3 - 7.4 3.3 270.9
Acquisitions of reserves 2.9 17.4 - - 2.9 17.4
Sales of reserves - - - - - -
Production (7.7) (26.5) (0.7) (24.6) (7.0) (1.9)
--------------------------------------------------------------------
December 31, 1998 88.6 564.0 1.4 202.1 87.2 361.9
Revisions and other changes 15.2 135.2 0.5 4.1 14.7 131.1
Extensions and discoveries 12.0 23.2 0.7 21.1 11.3 2.1
Acquisitions of reserves 8.8 92.1 - - 8.8 92.1
Sales of reserves - - - - - -
Production (7.7) (26.4) (0.7) (23.1) (7.0) (3.3)
--------------------------------------------------------------------
December 31, 1999 116.9 788.1 1.9 204.2 115.0 583.9
================================================================================================================
ESTIMATED PROVED DEVELOPED RESERVES (a)
December 31, 1996 39.2 270.0 1.8 270.0 37.4 -
December 31, 1997 45.3 267.8 1.7 238.2 43.6 29.6
December 31, 1998 50.6 448.8 1.4 197.8 49.2 251.0
December 31, 1999 74.3 652.7 1.8 191.8 72.5 460.9
================================================================================================================
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EQUITY INTEREST IN ESTIMATED
PROVED RESERVES OF COMECO
PETROLEUM, INC. (YEMEN) (B)
December 31, 1996 3.2 - - - 3.2 -
December 31, 1997 - - - - - -
December 31, 1998 - - - - - -
December 31, 1999 - - - - - -
===============================================================================================================
(a) The government license in Venezuela is an oil service contract whereby CMS
Oil and Gas is paid a fee per barrel for oil discovered, lifted, and
delivered to Maraven S.A., a subsidiary of Petroleos de Venezuela S.A..
Additionally, CMS Oil and Gas receives a fee for reimbursement of certain
capital expenditures. The volumes presented represent actual production
with respect to which CMS Oil and Gas is paid a per barrel fee.
(b) CMS Oil & Gas holdings in Comeco Petroleum, Inc. sold on December 5, 1997.
PANHANDLE PROPERTIES
PANHANDLE GAS TRANSMISSION PROPERTIES
Panhandle owns approximately 10,400 miles of interstate pipeline systems.
Panhandle Eastern Pipe Line Company's natural gas transmission system, which
consists of four large-diameter parallel pipelines and 13 mainline compressor
stations, extends a distance of approximately 1,300 miles from producing areas
in the Anadarko Basin of Texas, Oklahoma and Kansas through the states of
Missouri, Illinois, Indiana and Ohio into Michigan. Trunkline's transmission
system extends approximately 1,400 miles from the Gulf Coast areas of Texas and
Louisiana through the states of Arkansas, Mississippi, Tennessee, Kentucky,
Illinois and Indiana to a point on the Indiana-Michigan border. The system
consists principally of three large-diameter parallel pipelines, 18 mainline
compressor stations and one offshore compressor platform.
Trunkline also owns and operates two offshore Louisiana gas supply systems
consisting of 337 miles of pipeline extending approximately 81 miles into the
Gulf of Mexico.
PANHANDLE GAS STORAGE PROPERTIES
Effective April 1, 1999, Panhandle Eastern Pipe Line Company transferred four
underground storage fields located in Kansas, Illinois, Michigan and Oklahoma
with working gas capacity of 57 bcf to its subsidiary, Pan Gas Storage.
Panhandle Eastern Pipe Line Company contracts with Pan Gas Storage for storage
service. Trunkline owns and operates one 13 bcf storage field in Louisiana.
Since the implementation of Order 636, Panhandle Eastern Pipe Line Company,
Trunkline and Pan Gas Storage each provide firm and interruptible storage on an
open-access basis. In addition to owning and operating storage fields, Panhandle
also leases storage capacity. Panhandle Eastern Pipe Line Company and Trunkline
have retained the right to use up to 15 bcf and 10 bcf, respectively, of their
storage capacity for system needs.
CONSUMERS OTHER PROPERTIES
CMS Midland owns a 49 percent interest in the MCV Partnership, which was formed
to construct and operate the MCV Facility. The MCV Facility was sold to five
owner trusts and leased back to the MCV
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Partnership. CMS Holdings is a limited partner in the FMLP, which is a
beneficiary of one of these trusts. CMS Holdings' indirect beneficial interest
in the MCV Facility is 35 percent.
Consumers owns fee title to 1,140 acres of land in the City and Township of
Midland, Midland County, Michigan, occupied by the MCV Facility. The land is
leased to the owners of the MCV Facility by five separate leases, each leasing
an undivided interest and in the aggregate totaling 100 percent, for an initial
term ending December 31, 2035 with possible renewal terms to June 15, 2090.
Consumers owns or leases three principal general office buildings in Jackson,
Michigan and 51 field offices at various locations in Michigan's lower
peninsula. Of these, two general office buildings and 14 field offices are
leased. Also owned are miscellaneous parcels of real estate not now used in
utility operations.
For information on capital expenditures, see ITEM 7. CONSUMERS MANAGEMENT'S
DISCUSSION AND ANALYSIS - OUTLOOK AND ITEM 8. FINANCIAL STATEMENTS AND
SUPPLEMENTARY DATA - NOTE 10 OF CONSUMERS' NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS.
CMS ENERGY OTHER PROPERTIES
CMS Generation has ownership interests in certain facilities such as Loy Yang,
Jorf Lasfar and El Chocon. The Loy Yang assets are owned in fee, but are subject
to the security interests of its creditors. The Jorf Lasfar facility is held
pursuant to a right of possession agreement with the Moroccan state owned Office
National de l'Electricite. The El Chocon facility is held pursuant to a 30-year
possession agreement.
In Michigan, CMS Gas Transmission has ownership interests in natural gas
pipelines with transmission capacity of 770 MMcf per day, and gathering systems
with capacity of 385 MMcf per day. CMS Gas Transmission also owns five treating
plants that remove carbon dioxide from up to 360 MMcf per day of natural gas.
CMS Gas Transmission owns a hydrocarbon fractionation plant, which has a
capacity of 30,000 barrels per day, and has a 51 percent ownership interest in
an underground storage terminal for liquified petroleum gas products, which has
a storage capacity of 6,600,000 barrels.
CMS Gas Transmission owns CMS Field Services (formerly Continential Natural Gas,
Inc. and Heritage Gas Services, L.L.C.), which is based in Oklahoma and Texas
and operates over 4,300 miles of gas gathering systems and four active
processing plants producing 500,000 gallons per day of natural gas liquids. CMS
Field Services has a 51 percent interest in Bighorn Gas Gathering L.L.C.
(Bighorn), which began service in December 1999. Bighorn serves the northern
part of northeastern Wyoming's Powder River Basin and has a gathering capacity
of more than 250 million cubic feet per day of coal bed methane gas. It delivers
gas to the Fort Union Gathering System (Fort Union) and other market areas via
interstate pipelines connected to Fort Union. Bighorn consists of 60 miles of
large-diameter gathering pipeline, with about 40 additional miles under
construction. CMS Field Services also has a one-third interest in the Fort Union
Gas Gathering System, a 106 mile pipeline that will provide gathering services
through the center of the Powder River Basin.
In South America, CMS Gas Transmission owns a 29.42 percent interest in TGN,
which owns and operates 3,200 miles of pipeline that provides natural gas
transmission service to the northern and central parts of Argentina. CMS Gas
Transmission has a 20 percent interest in the 272 mile TGM pipeline, which is
under construction and, when completed in mid-2000, will transport about 100
MMcf per day of natural gas from Argentina to Brazil. CMS Gas Transmission and
CMS Generation together own a 50 percent interest in GasAtacama, which went into
service in 1999. GasAtacama owns and operates a 585 mile, 20-inch diameter
pipeline that originates in northern Argentina and transports natural gas across
the Andes
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Mountains to northern Chile. The pipeline supplies GasAtacama's 720 MW electric
generating units. An 88 mile extension to supply a power plant connected to
Chile's central electricity grid was completed in January 2000.
In western Australia, CMS Gas Transmission owns a 260 mile pipeline that
transports natural gas from the north Perth Basin to markets in the Perth area.
In December 1998 and April 1999, a consortium in which CMS Gas Transmission has
a 45 percent interest acquired an 88 percent interest in the 860 mile
Goldsfields Gas Transmission Pipeline, which transports natural gas from the
Northwest Shelf to the mining regions of western Australia.
CMS Gas Transmission and a partner are constructing a methanol plant in
Equatorial Guinea in west Africa. The plant, which will go into service in
mid-2001, will have a capacity of 2,500 metric tons per day and will use about
115 MMcf of residue gas from the CMS Oil and Gas facilities nearby.
CMS Gas Transmission also has an ownership interest in an enhanced oil recovery
project which involves flooding depleted oil reservoirs with carbon dioxide.
CMS Electric and Gas owns electric distribution facilities in South America.
Empresa Distribuidora de Electricidad de Entre Rios S.A. serves approximately
233,000 customers in the province of Entre Rios, Argentina. Sistema Electrico
Nueva Esparta C.A. serves more than 91,000 customers on Margarita Island,
Venezuela. In October 1999, CMS Electric and Gas purchased Companhia Paulista de
Energia Eletrica (CPEE), which serves more than 139,000 customers in the states
of Minas Gerais and Sao Paulo, Brazil. Through its ownership in CPEE, CMS
Electric and Gas has ownership interests in three additional electric
distribution facilities, Companhia Sue Paulista de Energia, Companhia Jaguari de
Energia and Companhia Luz e Forca de Mococa.
CMS Energy, through certain subsidiaries; owns a 50 percent interest in Bay
Harbor Company, L.L.C., a development in Emmet County, Michigan and owns
approximately 6,000 acres of undeveloped land in Benzie and Manistee Counties,
Michigan. In December 1999, the undeveloped land in Muskegon County, Michigan
was sold.
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The following table shows interests in independent power plants at December 31,
1999.
Location Ownership Interest (%) Gross Capacity (MW)
- ----------------------------------------------------------------------------------------------------------
CMS GENERATION
Wood-Fueled
Domestic 37.8 - 50.0 155
Fossil-Fueled
Domestic 8.8 - 100.0 813
International
Andhra Pradesh, India 25.3 235
Mendoza Province, Argentina 92.6 540
Port of Jorf Lasfar, Morocco 50.0 660
Prachinburi Province, Thailand 66.2 300
Second Region, Chile 50.0 555
State of Victoria, Australia 49.6 2,000
Tamil Nadu, India 49.0 200
Other 41.2-100.0 337
Scrap Tire-Fueled
Domestic 50.0 31
Hydro Generation
Domestic 1.0 - 55.5 82
International
Limay River, Argentina 17.2 1,320
Wind Generation
Domestic 8.5 - 22.7 102
Other
International
Scudder Fund, Latin America Various 780
CMS MIDLAND
Fossil-Fueled
Midland, Michigan 49.0(a) 1,370
===========================================================================================================
(a) See the previous section - CONSUMERS OTHER PROPERTIES - for more
information.
For information on capital expenditures, see ITEM 7. CMS ENERGY MANAGEMENT'S
DISCUSSION AND ANALYSIS - CAPITAL RESOURCES AND LIQUIDITY AND ITEM 8. FINANCIAL
STATEMENTS AND SUPPLEMENTARY DATA - NOTE 3 OF CMS ENERGY'S NOTES TO CONSOLIDATED
FINANCIAL STATEMENTS.
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ITEM 3. LEGAL PROCEEDINGS
CMS Energy, Consumers, Panhandle and some of their subsidiaries and affiliates
are parties to certain routine lawsuits and administrative proceedings
incidental to their businesses involving, for example, claims for personal
injury and property damage, contractual matters, various taxes, and rates and
licensing. Reference is made to the combined ITEM 1. BUSINESS - CMS ENERGY,
CONSUMERS AND PANHANDLE REGULATION, as well as to each of CMS Energy's,
Consumers' and Panhandle's ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS and CMS
Energy's, Consumers' and Panhandle's ITEM 8. FINANCIAL STATEMENTS AND
SUPPLEMENTARY DATA - NOTES TO CONSOLIDATED FINANCIAL STATEMENTS included herein
for additional information regarding various pending administrative and judicial
proceedings involving regulatory, operating and environmental matters.
CMS ENERGY
FTC CONSENT AGREEMENT: In March 1999, CMS Energy signed a consent agreement with
the FTC to settle the FTC's investigation of CMS Energy's acquisition of the
Panhandle Companies and to terminate the waiting period under the
Hart-Scott-Rodino Antitrust Improvements Act. Pursuant to the consent agreement,
CMS Energy agreed that Consumers would receive natural gas tendered for delivery
at all material interconnections with pipelines (other than those of the
Panhandle Companies and other pipelines affiliated with CMS Energy) up to design
capacity of the interconnections, except as the capacity may be reduced for
maintenance or force majeure. If CMS Energy does not provide service at the
agreed capacity, Consumers agrees to provide gas on Consumers' side of the
interconnection and accept delayed repayment in kind. The FTC accepted the
consent agreement on March 18, 1999, and this permitted the acquisition to close
on March 29, 1999. The consent agreement became final on June 2, 1999 and
expires on June 2, 2009. The requirements in the proposed FTC order are
consistent with Consumers' previous practices, and the MPSC has approved new
tariffs to reflect the proposed order.
CMS ENERGY AND CONSUMERS
ANTITRUST LITIGATION: In October 1997, Indeck Energy Services, Inc. and Indeck
Saginaw Limited Partnership, independent power producers, filed a lawsuit
against Consumers Energy Company and CMS Energy Corporation in the United States
District Court for the Eastern District of Michigan. The suit alleges antitrust
violations relating to contracts that Consumers entered into with some of its
customers as well as claims relating to independent power production projects.
The plaintiffs claim damages of $100 million (which can be trebled in antitrust
cases as provided by law). The transactions of which plaintiffs complain have
been regulated by and are subject to the jurisdiction of the MPSC. In September
1998, the United States District Court for the Eastern District of Michigan
granted CMS Energy's motion to dismiss the complaint for failure to state a
claim against which relief may be granted. On March 31, 1999, the Court issued
an opinion and order granting Consumers' motion for summary judgment, resulting
in dismissal of the case. The plaintiffs appealed this decision to the 6th
Circuit Court of Appeals. Each of the litigants has filed final briefs.
Consumers and CMS Energy believe the lawsuit is without merit and will
vigorously defend against it, but cannot predict the outcome of this matter.
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CONSUMERS
CONSUMERS' JOINT LAWSUIT AGAINST DOE: Under the Nuclear Waste Policy Act of
1982, the DOE was required to begin accepting deliveries of spent nuclear fuel
from commercial operators by January 31, 1998 for disposal, even if a permanent
storage repository was not then operational. In January 1997, in response to the
DOE's declaration in December 1996 that it would not begin to accept spent
nuclear fuel deliveries in 1998, Consumers and other utilities filed suit in the
United States Court of Appeals for the District of Columbia Circuit. In November
1997, the United States Court of Appeals decided that the contract between DOE
and the utilities provided a potentially adequate remedy if the DOE failed to
fulfill its obligations by January 31, 1998. For further information on this
litigation, see Consumers' ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - NOTE 1 - NUCLEAR FUEL COST
incorporated by reference herein.
PANHANDLE
ILLINOIS ENFORCEMENT PROCEEDINGS: The Illinois Environmental Protection Agency
has indicated that it intends to initiate an environmental enforcement
proceeding relating to alleged air quality permit violations at a natural gas
compressor station. This proceeding could result in a penalty in excess of
$100,000. Under the terms of the sale of Panhandle to CMS Energy, as discussed
see Panhandle's ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA - NOTES TO
CONSOLIDATED FINANCIAL STATEMENTS - NOTE 1, penalties incurred related to this
proceeding were retained by a subsidiary of Duke Energy. Panhandle believes the
resolution of this matter will not have a material adverse effect on
consolidated results of operations or financial position.
REGULATORY MATTERS: For a discussion of certain Panhandle regulatory matters,
see Panhandle's ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA - NOTES TO
CONSOLIDATED FINANCIAL STATEMENTS - NOTE 3 - REGULATORY MATTERS, as incorporated
by reference herein.
OTHER MATTERS: For a discussion of Panhandle's other litigation matters, see
Panhandle's ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA - NOTES TO
CONSOLIDATED FINANCIAL STATEMENTS - NOTE 11 - LITIGATION, as incorporated by
reference herein.
CMS ENERGY, CONSUMERS AND PANHANDLE
ENVIRONMENTAL MATTERS: CMS Energy, Consumers, Panhandle and their subsidiaries
and affiliates are subject to various federal, state and local laws and
regulations relating to the environment. Several of these companies have been
named parties to various actions involving environmental issues. Based on their
present knowledge and subject to future legal and factual developments, CMS
Energy and Consumers believe that it is unlikely that these actions,
individually or in total, will have a material adverse effect on their financial
condition. See ITEM 1. BUSINESS - CMS ENERGY, CONSUMERS AND PANHANDLE
ENVIRONMENTAL COMPLIANCE; CMS Energy's, Consumers' and Panhandle's ITEM 7.
MANAGEMENT'S DISCUSSION AND ANALYSIS; and CMS Energy's, Consumers' and
Panhandle's ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA.
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ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF
SECURITY HOLDERS.
CMS ENERGY
None in the fourth quarter of 1999 for CMS Energy.
CONSUMERS
None in the fourth quarter of 1999 for Consumers.
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PART II
ITEM 5. MARKET FOR CMS ENERGY'S, CONSUMERS' AND PANHANDLE'S COMMON
EQUITY AND RELATED STOCKHOLDER MATTERS.
CMS ENERGY
Market prices for CMS Energy's Common Stock and related security holder matters
are contained in ITEM 7. CMS ENERGY'S MANAGEMENT'S DISCUSSION AND ANALYSIS -
RECAPITALIZATION and ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA - CMS
ENERGY'S QUARTERLY FINANCIAL AND COMMON STOCK INFORMATION, which is incorporated
by reference herein. At February 29, 2000, the number of registered shareholders
totaled 68,048.
CONSUMERS
Consumers' common stock is privately held by its parent, CMS Energy, and does
not trade in the public market. In January, May, August and November 1999,
Consumers paid $97 million, $76 million, $34 million and $55 million in cash
dividends, respectively, on its common stock. In February, May, August and
November 1998, Consumers paid $80 million, $49 million, $44 million and $68
million in cash dividends, respectively, on its common stock.
PANHANDLE
Panhandle's common stock is privately held by its parent, CMS Gas Transmission,
and does not trade in the public market. In June, September and December 1999,
Panhandle paid $13 million, $16 million and $12 million in cash dividends,
respectively, on its common stock to CMS Gas Transmission. In 1998 and the first
quarter of 1999, Panhandle recorded dividends on common stock of $34 million and
$81 million, respectively, to a subsidiary of Duke Energy.
ITEM 6. SELECTED FINANCIAL DATA.
CMS ENERGY
Selected financial information is contained in ITEM 8. FINANCIAL STATEMENTS AND
SUPPLEMENTARY DATA - CMS ENERGY'S SELECTED FINANCIAL INFORMATION, which is
incorporated by reference herein.
CONSUMERS
Selected financial information is contained in ITEM 8. FINANCIAL STATEMENTS AND
SUPPLEMENTARY DATA - CONSUMERS' SELECTED FINANCIAL INFORMATION, which is
incorporated by reference herein.
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ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS.
CMS ENERGY
Management's discussion and analysis of financial condition and results of
operations is contained in ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA -
CMS ENERGY'S MANAGEMENT'S DISCUSSION AND ANALYSIS, which is incorporated by
reference herein.
CONSUMERS
Management's discussion and analysis of financial condition and results of
operations is contained in ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA -
CONSUMERS' MANAGEMENT'S DISCUSSION AND ANALYSIS, which is incorporated by
reference herein.
PANHANDLE
Management's discussion and analysis of financial condition and results of
operations is contained in ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA -
PANHANDLE'S MANAGEMENT'S DISCUSSION AND ANALYSIS, which is incorporated by
reference herein.
ITEM 7A. QUANTITATIVE AND QUALITATIVE
DISCLOSURES ABOUT MARKET RISK
CMS ENERGY
Quantitative and Qualitative Disclosures About Market Risk is contained in ITEM
8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA - CMS ENERGY'S MANAGEMENT'S
DISCUSSION AND ANALYSIS - RESULTS OF OPERATIONS - MARKET RISK INFORMATION, which
is incorporated by reference herein.
CONSUMERS
Quantitative and Qualitative Disclosures About Market Risk is contained in ITEM
8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA - CONSUMERS' MANAGEMENT'S
DISCUSSION AND ANALYSIS - OTHER MATTERS - MARKET RISK INFORMATION, which is
incorporated by reference herein.
PANHANDLE
Quantitative and Qualitative Disclosures About Market Risk is contained in ITEM
8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA - PANHANDLE'S MANAGEMENT'S
DISCUSSION AND ANALYSIS - OTHER MATTERS - MARKET RISK INFORMATION, which is
incorporated by reference herein.
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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA.
Index to Financial Statements:
CMS ENERGY Page
Selected Financial Information.......................................................... CMS-2
Management's Discussion and Analysis.................................................... CMS-4
Consolidated Statements of Income....................................................... CMS-20
Consolidated Statements of Cash Flows................................................... CMS-23
Consolidated Balance Sheets............................................................. CMS-24
Consolidated Statements of Preferred Stock.............................................. CMS-26
Consolidated Statements of Common Stockholders' Equity.................................. CMS-27
Notes to Consolidated Financial Statements.............................................. CMS-28
Report of Independent Public Accountants................................................ CMS-69
Quarterly Financial and Common Stock Information........................................ CMS-70
CONSUMERS ENERGY
Selected Financial Information.......................................................... CE-2
Management's Discussion and Analysis.................................................... CE-3
Consolidated Statements of Income....................................................... CE-12
Consolidated Statements of Cash Flows................................................... CE-13
Consolidated Balance Sheets............................................................. CE-14
Consolidated Statements of Long-Term Debt............................................... CE-16
Consolidated Statements of Preferred Stock.............................................. CE-17
Consolidated Statements of Common Stockholder's Equity.................................. CE-18
Notes to Consolidated Financial Statements.............................................. CE-19
Report of Independent Public Accountants................................................ CE-44
Quarterly Financial Information......................................................... CE-45
PANHANDLE EASTERN PIPE LINE COMPANY
Management's Discussion and Analysis.................................................... PE-2
Consolidated Statements of Income....................................................... PE-6
Consolidated Statements of Cash Flows................................................... PE-7
Consolidated Balance Sheets............................................................. PE-8
Consolidated Statements of Common Stockholder's Equity.................................. PE-10
Notes to Consolidated Financial Statements.............................................. PE-11
Report of Independent Public Accountants - Arthur Andersen LLP.......................... PE-27
Report of Independent Public Accountants - Deloitte & Touche LLP........................ PE-28
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[CMS ENERGY LOGO]
1999 FINANCIAL STATEMENTS
CMS-1
51
SELECTED FINANCIAL INFORMATION CMS ENERGY CORPORATION
1999 1998 1997 1996 1995
Operating revenue (in millions) ($) 6,103 5,141 4,781 4,324 3,890
Consolidated net income (in millions) ($) 277 285 244 224 195
Average common shares outstanding
(in thousands)
CMS Energy 110,140 102,446 96,144 92,462 88,810
Class G - 8,333 8,015 7,727 7,511
Earnings per average common share
CMS Energy - Basic ($) 2.18 (a) 2.65 2.39 2.27 2.16
- Diluted ($) 2.17 (a) 2.62 2.37 2.26 2.16
Class G - Basic and Diluted ($) 4.21 (a) 1.56 1.84 1.82 0.38
Cash from operations (in millions) ($) 917 516 624 647 640
Capital expenditures, excluding acquisitions,
capital lease additions and DSM (in millions) ($) 1,124 1,295 678 643 508
Total assets (in millions) ($) 15,462 11,310 9,508 8,363 7,909
Long-term debt, excluding current
maturities (in millions) ($) 6,987 4,726 3,272 2,842 2,906
Non-current portion of capital
leases (in millions) ($) 88 105 75 103 106
Total preferred stock (in millions) ($) 44 238 238 356 356
Total Trust Preferred Securities (in millions) ($) 1,119 393 393 100 -
Cash dividends declared per common share
CMS Energy ($) 1.39 1.26 1.14 1.02 0.90
Class G ($) 0.99 1.27 1.21 1.15 0.56
Market price of common stock at year-end
CMS Energy ($) 31-3/16 48-7/16 44-1/16 33-5/8 29-7/8
Class G ($) 24-9/16 (b) 25-1/4 27-1/8 18-3/8 18-7/8
Book value per common share at year-end
CMS Energy ($) 21.17 19.61 16.84 15.24 13.51
Class G ($) - 11.46 10.91 11.38 10.60
Return on average common equity (%) 11.8 14.2 14.7 15.7 17.1
Return on assets (%) 5.2 5.5 5.6 5.4 5.2
Number of employees at year-end
(full-time equivalents) 11,462 9,710 9,682 9,712 10,105
CMS-2
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SELECTED FINANCIAL INFORMATION (CONTINUED) CMS ENERGY CORPORATION
1999 1998 1997 1996 1995
ELECTRIC UTILITY STATISTICS
Sales (billions of kWh) 41.0 40.0 37.9 37.1 35.5
Customers (in thousands) 1,665 1,640 1,617 1,594 1,570
Average sales rate per kWh (cents) 6.54 6.50 6.57 6.55 6.36
GAS UTILITY STATISTICS
Sales and transportation deliveries (bcf) 389 360 420 448 404
Customers (in thousands) (c) 1,584 1,558 1,533 1,504 1,476
Average sales rate per mcf ($) 4.52 4.56 4.44 4.45 4.42
INTERNATIONAL DIVERSIFIED ENERGY STATISTICS
CMS Energy's share of unconsolidated
revenue (in millions):
Independent power production ($) 802 761 621 493 497
Natural gas transmission, storage and processing ($) 130 67 51 42 26
Marketing, services and trading ($) 524 291 202 - -
Independent power production
sales (millions of kWh) 20,472 19,017 13,126 7,823 7,422
Gas pipeline throughput (bcf) 1,131 253 226 177 79
Gas managed and marketed for end users (bcf) 470 366 243 108 101
Electric power marketed (millions of KWh) 3,709 6,973 900 - -
EXPLORATION AND PRODUCTION STATISTICS
Sales (net equiv. MMbbls) 12.1 12.1 11.4 10.1 9.0
Proved reserves (net equiv. MMbbls) 248.2 182.6 152.0 133.5 124.5
Proved reserves added (net equiv. MMbbls) (d) 77.7 42.7 29.9 19.1 25.6
Finding cost per net equiv. barrel ($) 1.94 3.35 2.38 2.94 5.06
(a) 1999 earnings per average common share includes allocation of the premium on
redemption of Class G Common Stock of $(.26) per CMS Energy basic share, $(.25)
per CMS Energy diluted share and $3.31 per Class G basic and diluted share.
(b) Reflects closing price at the October 25, 1999 exchange date.
(c) Excludes off-system transportation customers.
(d) Certain prior year amounts were restated for comparative purposes.
CMS-3
53
CMS ENERGY CORPORATION
MANAGEMENT'S DISCUSSION AND ANALYSIS
CMS Energy Corporation (CMS Energy) is the parent holding company of Consumers
Energy Company (Consumers) and CMS Enterprises Company (Enterprises). Consumers
is a combination electric and gas utility company serving the Lower Peninsula of
Michigan. Enterprises, through subsidiaries, is engaged in several domestic and
international diversified energy businesses including: natural gas transmission,
storage and processing; independent power production; oil and gas exploration
and production; energy marketing, services and trading; and international energy
distribution. On March 29, 1999, CMS Energy completed the acquisition of
Panhandle Eastern Pipe Line Company, including its subsidiaries Trunkline and
Pan Gas Storage, and its affiliates Panhandle Storage and Trunkline LNG
(Panhandle), as further discussed in the Capital Resources and Liquidity section
of this Management's Discussion and Analysis (MD&A) and Note 3. Panhandle is
primarily engaged in the interstate transportation and storage of natural gas.
This MD&A also refers to, and in some sections specifically incorporates by
reference, CMS Energy's Notes to Consolidated Financial Statements and should be
read in conjunction with such Statements and Notes. This Annual Report and other
written and oral statements made by CMS Energy from time to time contain
forward- looking statements as defined by the Private Securities Litigation
Reform Act of 1995. The words "anticipates," "believes," "estimates," "expects,"
"intends," and "plans," and variations of such words and similar expressions,
are intended to identify forward-looking statements that involve risk and
uncertainty. These forward-looking statements are subject to various factors
which could cause CMS Energy's actual results to differ materially from those
anticipated in such statements. CMS Energy disclaims any obligation to update or
revise forward-looking statements, whether from new information, future events
or otherwise. CMS Energy details certain risk factors, uncertainties and
assumptions in this MD&A and particularly in the section entitled "Forward
Looking Statements Cautionary Factors" in CMS Energy's Form 8-K filed on
February 1, 2000, and periodically in various public filings it makes with the
Securities and Exchange Commission (SEC). This discussion of potential risks and
uncertainties is by no means complete but is designed to highlight important
factors that may impact CMS Energy's outlook. This Annual Report also describes
material contingencies in the Notes to Consolidated Financial Statements and
readers are encouraged to read such Notes.
RESULTS OF OPERATIONS
In October 1999, CMS Energy exchanged .7041 shares of one of two classes of
common stock of CMS Energy, par value $.01 (CMS Energy Common Stock) for each of
the approximately 8.7 million outstanding shares of one of two classes of common
stock of CMS Energy, no par value (Class G Common Stock). This exchange ratio
represented the fair market value of CMS Energy Common Stock equal to 115
percent of the fair market value of one share of Class G Common Stock, and
resulted in a reallocation of earnings per share. CMS Energy's basic and diluted
earnings per share were reduced $.26 and $.25, respectively, and Class G's basic
and diluted earnings per share were increased $3.31, as more fully discussed in
Note 8. The per share allocation does not affect CMS Energy's net income for
1999 or for future periods.
Also in 1999, CMS Energy recorded losses of $84 million, or $49 million net of
tax, relating to its investments in Nitrotec Corporation, a proprietary gas
processing company which has patents for its helium removal and nitrogen
rejection processes for purifying natural gas (Nitrotec). After reviewing the
business alternatives and strategic outlook for its investments in Nitrotec, CMS
Energy determined that the
CMS-4
54
probability of recovering any portion of its investments was unlikely.
Accordingly, CMS Energy has recorded losses equal to the carrying amount of its
investments.
The following table depicts CMS Energy's Results of Operations before and after
the effects of the above-mentioned events of 1999.
CMS ENERGY CONSOLIDATED EARNINGS
In Millions, Except Per Share Amounts
- ---------------------------------------------------------------------------------------------------
Years Ended December 31 1999 1998 (a) Change
- ---------------------------------------------------------------------------------------------------
CONSOLIDATED NET INCOME $ 277 $ 285 $ (8)
Net Income Attributable to CMS Energy Common Stock $ 269 $ 272 $ (3)
Net Income Attributable to Class G Common Stock $ 8 $ 13 $ (5)
CONSOLIDATED NET INCOME OF CMS ENERGY
Net Income Before Losses on Investments in Nitrotec $ 318 $ 272 $ 46
Effects of Losses on Investments in Nitrotec, Net of
$35 Tax (49) - (49)
------------------------------------
Net Income Attributable to CMS Energy Common Stock $ 269 $ 272 $ (3)
====================================
- ---------------------------------------------------------------------------------------------------
BASIC EARNINGS PER AVERAGE COMMON SHARE OF CMS ENERGY
Net Income Before Reconciling Items $ 2.89 $ 2.65 $ .24
Effects of Losses on Investments in Nitrotec (.45) - (.45)
------------------------------------
2.44 2.65 (.21)
Effects of Class G Common Stock Exchange (.26) - (.26)
------------------------------------
Net Income Available After Reconciling Items $ 2.18 $ 2.65 $ (.47)
====================================
- ---------------------------------------------------------------------------------------------------
DILUTED EARNINGS PER AVERAGE COMMON SHARE OF CMS ENERGY
Net Income Before Reconciling Items $ 2.85 $ 2.62 $ .23
Effects of Losses on Investments in Nitrotec (.43) - (.43)
------------------------------------
2.42 2.62 (.20)
Effects of Class G Common Stock Exchange (.25) - (.25)
------------------------------------
Net Income Available After Reconciling Items $ 2.17 $ 2.62 $ (.45)
====================================
(a) Includes the cumulative effect of an accounting change for property taxes
which increased net income by $43 million, or $.40 per basic and diluted share
of CMS Energy Common Stock.
The increase in consolidated net income for 1999 over 1998 before the effects of
losses on investments in Nitrotec resulted from increased earnings from the
electric and gas utilities; the natural gas transmission, storage and processing
business, primarily as a result of the Panhandle acquisition; the independent
power production business; the oil and gas exploration and production business;
and lower losses from the international energy distribution business. Partially
offsetting these increases was higher interest expense principally related to
the Panhandle acquisition.
The increase in consolidated net income for 1998 over 1997 resulted from
increased earnings from the electric utility; independent power production;
natural gas transmission, storage and processing; and marketing, services and
trading businesses. Partially offsetting these increases were lower earnings
from
CMS-5
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the gas utility, oil and gas exploration and production and international energy
distribution businesses; the recognition of a $37 million loss ($24 million
after-tax) for the underrecovery of power costs under the power purchase
agreement between Consumers and the Midland Cogeneration Venture Limited
Partnership (MCV Partnership), and higher interest expense.
For further information, see the individual results of operations for each CMS
Energy business segment in this MD&A.
CONSUMERS' ELECTRIC UTILITY RESULTS OF OPERATIONS
ELECTRIC PRETAX OPERATING INCOME:
In Millions
- ---------------------------------------------------------------------
Change Compared to Prior Year 1999 vs 1998 1998 vs 1997
- ---------------------------------------------------------------------
Electric deliveries $ 37 $ 40
Power supply costs and related revenue 27 14
Net energy option costs (19) 6
Non-commodity revenue (13) (4)
Operations and maintenance (3) (3)
General taxes and depreciation (10) (10)
-------------------
Total change $ 19 $ 43
=====================================================================
ELECTRIC DELIVERIES: Electric deliveries were 41 billion kilowatt-hours (kWh)
for 1999, an increase of 1 billion kWh or 2.5 percent compared with 1998. Total
electric deliveries increased in all customer classes. Total electric deliveries
in 1998 were 40 billion kWh, an increase of 2.2 billion kWh or 6 percent
compared with 1997. The increase was primarily attributable to increased sales
to other utilities and a 3 percent increase in deliveries to ultimate customers.
POWER SUPPLY COSTS:
In Millions
- --------------------------------------------------------------------------
Years Ended December 31 1999 1998 Change 1998 1997 Change
- --------------------------------------------------------------------------
$1,193 $1,175 $18 $1,175 $1,139 $36
==========================================================================
Power supply costs increased for 1999 to meet increased electric delivery
requirements. Both the 1999 and 1998 power supply cost increases reflect higher
internal generation to meet the increased demand for electricity. In addition,
the cost increase in 1998 over the prior year reflects increased power purchases
from outside sources to meet sales demand. In 1999 and 1998 respectively,
Consumers purchased $19 million and $5 million of energy options for physical
delivery of electricity to ensure a reliable source of power during the summer
months. As a result of periodic excess daily capacity, some options were sold
for $6 million and $11 million during June, July, and August of 1999 and 1998,
respectively. All of the remaining options were exercised or expired. The costs
relating to the expired options, offset by income received from the sale of
options, were reflected as purchased power costs.
CMS-6
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CONSUMERS' GAS UTILITY RESULTS OF OPERATIONS
GAS PRETAX OPERATING INCOME:
In Millions
- --------------------------------------------------------------------------------
Change Compared to Prior Year 1999 vs 1998 1998 vs 1997
- --------------------------------------------------------------------------------
Gas deliveries $ 32 $(42)
Gas commodity and related revenue (5) 19
Gas wholesale and retail services 5 1
Operation and maintenance (14) (1)
General taxes and depreciation (12) (4)
-----------------------------
Total change $ 6 $(27)
================================================================================
GAS DELIVERIES: Gas system deliveries in 1999, including miscellaneous
transportation, totaled 389 billion cubic feet (bcf), an increase of 29 bcf or 8
percent compared with 1998. The increased deliveries reflect colder temperatures
during the first quarter of 1999. System deliveries in 1998, including
miscellaneous transportation, totaled 360 bcf, a decrease of 60 bcf or 14
percent compared with 1997. The decreased deliveries reflect milder winter
temperatures in the first and fourth quarters of 1998.
COST OF GAS SOLD:
In Millions
- --------------------------------------------------------------------------------
Years Ended December 31 1999 1998 Change 1998 1997 Change
- --------------------------------------------------------------------------------
$637 $564 $73 $564 $694 $(130)
================================================================================
The cost of gas sold increase for 1999 was the result of increased sales due to
colder temperatures during 1999 and higher gas prices. The cost of gas decrease
for 1998 was the result of decreased sales from milder temperatures during 1998
and decreased gas prices.
NATURAL GAS TRANSMISSION, STORAGE AND PROCESSING RESULTS OF OPERATIONS
PRETAX OPERATING INCOME: Pretax operating income for 1999, including $84 million
of losses on investments in Nitrotec, increased $58 million (176 percent) from
the comparable period in 1998. The increase reflects earnings from Panhandle,
which CMS Energy acquired in March 1999, increased earnings from other
international and domestic operations, and a gain on the sale of a partial
interest in the Northern Header gathering system in Wyoming's Powder River
Basin. Partially offsetting these increases were 1998 gains on the sale of Petal
Gas Storage Company and Australian gas reserves. Pretax operating income for
1998 increased $6 million (22 percent) from the comparable period in 1997
primarily due to a gain on the sale of Petal Gas Storage Company, a gain on the
sale of Australian gas reserves, and lower operating expenses. These increases
were partially offset by a decrease in earnings from international operations.
CMS-7
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INDEPENDENT POWER PRODUCTION RESULTS OF OPERATIONS
PRETAX OPERATING INCOME: Pretax operating income for 1999 increased $13 million
(9 percent) from the comparable period in 1998. This increase primarily reflects
increased operating income from international and domestic plant earnings and
fees and an increase in income earned from management service fees. Partially
offsetting these year-over-year increases were 1998 gains of $26 million on the
sale of two power purchase agreements and $9 million on the sale of two plants.
Pretax operating income for 1998 increased $48 million (50 percent) from the
comparable period in 1997. This increase primarily reflects increased operating
income from international plant earnings and fees, a $26 million gain on the
sale of two power purchase agreements, and a $9 million gain on the sale of two
plants. These increases were partially offset by higher net operating expenses
and a scheduled reduction in the industry expertise service fee income earned in
connection with the 2,000 megawatt (MW) brown coal-fueled Loy Yang A power plant
and an associated coal mine in Victoria, Australia (Loy Yang).
OIL AND GAS EXPLORATION AND PRODUCTION RESULTS OF OPERATIONS
PRETAX OPERATING INCOME: Pretax operating income for 1999 increased $11 million
(183 percent) from the comparable period in 1998 as a result of higher realized
commodity prices and lower exploration expenses. Partially offsetting this
increase were higher operating expenses. Pretax operating income for 1998
decreased $20 million (77 percent) from the comparable period in 1997 due to
lower oil prices and a gain in the prior period from the sale of CMS Oil and Gas
Company's (CMS Oil and Gas) entire interest in oil and gas properties in Yemen.
Partially offsetting this decrease were increased oil production, decreased
exploration expenses, and decreased depreciation, depletion and amortization
expenses.
MARKETING, SERVICES AND TRADING RESULTS OF OPERATIONS
PRETAX OPERATING INCOME: Pretax operating income for 1999 was unchanged from the
comparable period in 1998. Increased earnings from retail gas sales, wholesale
gas price volatility and a recent acquisition in energy management services were
offset by costs related to market development activities. Pretax operating
income for 1998 increased $9 million from the comparable period in 1997. This
increase is the result of improved margins on electricity and gas sales combined
with increased electric and gas sales volumes. The increase was partially offset
by additional operating costs relating to growth objectives.
MARKET RISK INFORMATION
CMS Energy is exposed to market risks including, but not limited to, changes in
interest rates, currency exchange rates, and certain commodity and equity
prices. Management employs established policies and procedures to manage its
risks associated with these market fluctuations, including the use of various
derivative instruments such as futures, swaps, options and forward contracts.
Management believes that any losses incurred on derivative instruments used to
hedge risk would be offset by an opposite movement of the value of the hedged
item.
In accordance with SEC disclosure requirements, CMS Energy has performed
sensitivity analyses to assess the potential loss in fair value, cash flows and
earnings based upon hypothetical 10 percent increases and decreases in market
exposures. Management does not believe that sensitivity analyses alone provide
an accurate or reliable method for monitoring and controlling risks. Therefore,
CMS Energy and its subsidiaries rely on the experience and judgment of senior
management and traders to revise strategies and adjust positions as they deem
necessary. Losses in excess of the amounts determined in the sensitivity
analyses could occur if market rates or prices exceed the 10 percent shift used
for the analyses.
CMS-8
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COMMODITY PRICE RISK: Management uses commodity futures contracts, options and
swaps (which require a net cash payment for the difference between a fixed and
variable price) to manage commodity price risk. The prices of energy
commodities, such as gas, oil, electric and natural gas liquids, fluctuate due
to changes in the supply of and demand for those commodities. To reduce price
risk caused by these market fluctuations, CMS Energy hedges certain inventory
and purchases and sales contracts. A hypothetical 10 percent adverse shift in
quoted commodity prices in the near term would not have had a material impact on
CMS Energy's consolidated financial position, results of operations or cash
flows as of December 31, 1999. The analysis assumes that the maximum exposure
associated with purchased options is limited to prices paid. The analysis also
does not quantify short-term exposure to hypothetically adverse price
fluctuations in inventories.
INTEREST RATE RISK: Management uses a combination of fixed-rate and
variable-rate debt to reduce interest rate exposure. Interest rate swaps and
rate locks may be used to adjust exposure when deemed appropriate, based upon
market conditions. These strategies attempt to provide and maintain the lowest
cost of capital. The carrying amount of long-term debt was $7 billion at
December 31, 1999 with a fair value of $6.7 billion. The fair value of CMS
Energy's interest rate swaps at December 31, 1999, with a notional amount of
$2.9 billion, was $6 million, representing the amount CMS Energy would receive
upon settlement. A hypothetical 10 percent adverse shift in interest rates in
the near term would not have a material effect on CMS Energy's consolidated
financial position, results of operations or cash flows as of December 31, 1999.
CURRENCY EXCHANGE RISK: Management uses forward exchange and option contracts to
hedge certain investments in foreign operations. A hypothetical 10 percent
adverse shift in currency exchange rates would not have a material effect on CMS
Energy's consolidated financial position or results of operations as of December
31, 1999, but would result in a net cash settlement of approximately $71
million. The estimated fair value of the foreign exchange and option contracts
at December 31, 1999 was $64 million, representing the amount CMS Energy would
pay upon settlement.
EQUITY SECURITY PRICE RISK: CMS Energy and certain of its subsidiaries have
equity investments in companies in which they hold less than a 20 percent
interest. A hypothetical 10 percent adverse shift in equity security prices
would not have a material effect on CMS Energy's consolidated financial
position, results of operations or cash flows as of December 31, 1999.
For a discussion of accounting policies related to derivative transactions, see
Note 9.
CAPITAL RESOURCES AND LIQUIDITY
CASH POSITION, INVESTING AND FINANCING
CMS Energy's primary ongoing source of cash is dividends and distributions from
subsidiaries. In 1999, Consumers paid $262 million in common dividends and
Enterprises paid $118 million in common dividends to CMS Energy. In January
2000, Consumers declared and paid a $79 million dividend to CMS Energy. In June
1999, CMS Energy contributed $150 million of paid-in capital to Consumers. CMS
Energy's consolidated cash requirements are met by its operating and financing
activities.
OPERATING ACTIVITIES: CMS Energy's consolidated net cash provided by operating
activities is derived mainly from the processing, storage, transportation and
sale of natural gas; the generation, transmission, distribution and sale of
electricity; and the sale of oil. Consolidated cash from operations totaled $917
million and $516 million for 1999 and 1998, respectively. The $401 million
increase resulted from an increase in cash earnings, reflecting higher non-cash
charges to earnings in 1999 as compared to 1998, combined with a reduction in
working capital in 1999. CMS Energy uses its cash derived from operating
CMS-9
59
activities primarily to maintain and expand its international and domestic
businesses, to maintain and expand electric and gas systems of Consumers, to pay
interest on and retire portions of its long-term debt, and to pay dividends.
INVESTING ACTIVITIES: CMS Energy's consolidated net cash used in investing
activities totaled $3.564 billion and $1.634 billion for 1999 and 1998,
respectively. The increase of $1.930 billion primarily reflects the acquisition
of Panhandle in March 1999. CMS Energy's expenditures (excluding acquisitions)
during 1999 for its utility and international businesses were $464 million and
$1.06 billion, respectively, compared to $429 million and $1.271 billion,
respectively, during the comparable period in 1998.
FINANCING ACTIVITIES: CMS Energy's net cash provided by financing activities
totaled $2.678 billion in 1999, primarily for funding the approximately $2
billion Panhandle acquisition, and $1.150 billion in 1998. The increase of $1.5
billion in net cash provided by financing activities resulted from an increase
of $1.212 billion in the issuance of debt and trust preferred securities (see
table below) and a decrease in the retirement of bonds and other long-term debt
($403 million), partially offset by an increase in the retirement of preferred
stock ($194 million) and a decrease in the issuance of common stock ($185
million).
CMS-10
60
- ------------------------------------------------------------------------------------------------------------------------------------
In Millions
- ------------------------------------------------------------------------------------------------------------------------------------
Distribution/ Principal
Month Issued Maturity Interest Rate Amount Use of Proceeds
- ------------------------------------------------------------------------------------------------------------------------------------
CMS ENERGY
GTNs Series E (1) (1) 7.4%(1) $ 244 General corporate purposes
Senior Notes January 2009 7.5% 480 Repay debt and general corporate purposes
Senior Notes February 2004 6.75% 300 Repay debt and general corporate purposes
Trust Preferred Securities June 2001 (2) 250 To refinance acquisition of Panhandle
Senior Notes June 2011 8.0%(3) 250 To refinance acquisition of Panhandle
Senior Notes June 2013 8.375%(4) 150 To refinance acquisition of Panhandle
Adjustable Convertible Trust
Preferred Securities(5) July 2004 8.75% 301 Repay debt and general corporate purposes
------
$1,975
CONSUMERS
Trust Preferred Securities October 2029 9.25% 175 Repay debt and general corporate purposes
PANHANDLE
Senior Notes (6) March 2004 6.125% 300 To fund acquisition of Panhandle
Senior Notes (6) March 2009 6.5% 200 To fund acquisition of Panhandle
Senior Notes (6) March 2029 7.0% 300 To fund acquisition of Panhandle
------
800
------
Total $2,950
====================================================================================================================================
CMS-11
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(1) CMS Energy General Term Notes (R) (GTNs) are issued from time to time with
varying maturity dates. The rate shown herein is a weighted average
interest rate.
(2) The securities representing an undivided beneficial interest in the assets
of statutory business trusts (Trust Preferred Securities) pay quarterly
distributions at a floating rate of LIBOR plus 1.75 percent. For detailed
information, see Note 7, incorporated by reference herein.
(3) The interest rate may be reset in July 2001. For detailed information, see
Note 6, incorporated by reference herein.
(4) The interest rate may be reset in July 2003. For detailed information, see
Note 6, incorporated by reference herein.
(5) For detailed information regarding the conversion provisions of these
securities, see Note 7, incorporated by reference herein.
(6) These notes were privately placed by CMS Panhandle Holding Company (CMS
Panhandle Holding) on March 29, 1999, with an irrevocable and unconditional
guarantee by Panhandle. On June 15, 1999, CMS Panhandle Holding merged into
Panhandle, at which point the notes became direct obligations of Panhandle.
In September 1999, Panhandle exchanged the $800 million of notes originally
issued by CMS Panhandle Holding with substantially identical SEC-registered
notes.
In 1999, CMS Energy declared and paid $154 million in cash dividends to holders
of CMS Energy Common Stock and $9 million in cash dividends to holders of Class
G Common Stock. In January 2000, the Board of Directors of CMS Energy (Board of
Directors) declared a quarterly dividend of $.365 per share on CMS Energy Common
Stock, payable in February 2000.
OTHER INVESTING AND FINANCING MATTERS: At December 31, 1999, the book value per
share of CMS Energy Common Stock was $21.17.
At January 31, 2000, CMS Energy had an aggregate $1.7 billion in securities
registered for future issuance.
CMS Energy has $725 million of senior credit facilities consisting of a $600
million three-year revolving credit facility and a five-year $125 million term
loan facility (Senior Credit Facilities), unsecured lines of credit and letters
of credit as anticipated sources of funds to finance working capital
requirements and to pay for capital expenditures between long-term financings.
At December 31, 1999, the total amount available under the Senior Credit
Facilities was $241 million, and under the unsecured lines of credit and letters
of credit was $218 million. For detailed information, see Note 6, incorporated
by reference herein.
Consumers has credit facilities, lines of credit and a trade receivable sale
program in place as anticipated sources of funds to fulfill its currently
expected capital expenditures. For detailed information about these sources of
funds, see Note 5, incorporated by reference herein.
In March 1999, CMS Energy acquired Panhandle from Duke Energy Corporation (Duke
Energy) for a cash payment of $1.9 billion and existing Panhandle debt of $300
million. Initially, CMS Energy financed the acquisition of Panhandle with funds
from a $600 million bridge loan negotiated with domestic banks, proceeds from
CMS Energy long-term debt, and proceeds from approximately $800 million of notes
privately placed by CMS Panhandle Holding. As of June 30, 1999, the entire
bridge loan had been repaid from proceeds of the sale of $250 million of Trust
Preferred Securities and $400 million of senior notes.
In April 1999, Consumers redeemed all 8 million outstanding shares of its $2.08
preferred stock at $25.00 per share for a total of $200 million.
In October 1999, CMS Energy exchanged approximately 6.1 million shares of CMS
Energy Common Stock for all of the approximately 8.7 million issued and
outstanding shares of Class G Common Stock in
CMS-12
62
a tax-free exchange for United States federal income tax purposes. For detailed
information, see Note 8, incorporated by reference herein.
In October 1999, CMS Energy announced that because of the low market price of
CMS Energy Common Stock at that time, it identified an alternative way to
improve its balance sheet through the sale of non-strategic assets. At that
time, CMS Energy identified for possible sale $1 billion of assets which were
expected to contribute little or no earnings benefit in the short to medium
term. In addition, in February 2000, CMS Energy announced its intention to sell
its interest in Loy Yang. The amount CMS Energy ultimately realizes from the
sale of Loy Yang could differ materially from the $500 million investment amount
currently reflected in the financial statements. Excluding Loy Yang, CMS Energy
plans to sell, or have agreements to sell, $600 to $750 million of such assets
by the end of April 2000. As of February 1, 2000, CMS Energy had sold a partial
interest in its Northern Header gathering system and all of its ownership
interest in a Brazilian distribution system. In addition, CMS Energy has an
agreement to sell all of its northern Michigan oil and gas properties. These
sales are expected to generate approximately $370 million in proceeds.
CAPITAL EXPENDITURES
CMS Energy estimates that capital expenditures, including new lease commitments
and investments in partnerships and unconsolidated subsidiaries, will total $4.2
billion during 2000 through 2002. These estimates are prepared for planning
purposes and are subject to revision. CMS Energy expects to satisfy a
substantial portion of the capital expenditures with cash from operations. CMS
Energy will continue to evaluate capital markets in 2000 as a potential source
for financing its subsidiaries' investing activities. CMS Energy estimates
capital expenditures by business segment over the next three years as follows:
In Millions
- -----------------------------------------------------------------------------
Years Ended December 31 2000 2001 2002
- -----------------------------------------------------------------------------
Consumers electric operations (a) (b) $ 426 $ 520 $ 473
Consumers gas operations (a) 113 130 127
Natural gas transmission, storage and processing 234 198 248
Independent power production 577 220 223
Oil and gas exploration and production 153 210 212
Marketing, services and trading 32 12 12
International energy distribution 66 -- --
Other 16 -- --
--------------------------
$1,617 $1,290 $1,295
=============================================================================
(a) These amounts include an attributed portion of Consumers' anticipated
capital expenditures for plant and equipment common to both the electric and gas
utility businesses. (b) These amounts do not include preliminary estimates for
capital expenditures possibly required to comply with recently revised national
air quality standards under the Federal Clean Air Act, as amended (Clean Air
Act). For further information see Note 4, Uncertainties.
CMS Energy currently plans investments from 2000 to 2002 in focused regions,
which include: North and South America; West and North Africa; the Middle East
and select areas of Asia, including India, and Western Australia. Investments
will be made in market segments which align with CMS Energy's varied business
units' skills with a focus on optimization and integration of existing assets.
CMS-13
63
OUTLOOK
As the deregulation and privatization of the energy industry takes place in the
United States and in foreign countries, CMS Energy has positioned itself to be a
leading international integrated energy company acquiring, developing and
operating energy facilities and providing energy services in major world growth
markets. CMS Energy provides a complete range of international energy expertise
from energy production to consumption. CMS Energy intends to pursue its global
growth by making energy investments that provide expansion opportunities for
multiple CMS Energy businesses.
CMS Energy also enhances its growth strategy through an active portfolio
management program (the ongoing sale of non-strategic assets), with proceeds
reinvested in assets with greater potential for synergies with existing or
planned assets. In particular, CMS Energy is reviewing its options regarding
certain assets performing below prior expectations, including Argentine
generating assets. CMS Energy also continues to seek improvement in the
profitability of all assets retained in its portfolio.
RECAPITALIZATION
On February 1, 2000, CMS Energy announced a financial restructuring plan to
strengthen significantly its balance sheet, to reduce fixed charges and to
enhance earnings per share growth. During the second or third quarter of 2000,
subject to market conditions, CMS Energy intends to make an initial public
offering of approximately $600 million of a tracking stock representing 20
percent of the economic interest in its electric and gas utility. CMS Energy
expects to pay about 75 percent of the electric and gas utility earnings as
dividends. The proceeds of the offering will be used mostly to reduce debt. Some
of the proceeds may also be used to repurchase CMS Energy Common Stock, which
management believes is currently undervalued. The CMS Energy Board of Directors
approved the repurchase of up to 10 million shares of CMS Energy Common Stock,
from time to time, in open market or private transactions. Substantial progress
has been made toward the 10 million share limit. In addition, the Board of
Directors has indicated its intention that the CMS Energy dividend, currently at
an annual rate of $1.46 per share, will be reduced after the initial public
offering to an annual rate of $.40 per share. The Board of Directors also
authorized a tax-free exchange offer to provide an opportunity for CMS Energy
Common Stock to be converted into the new tracking stock.
CMS Energy anticipates this restructuring program, along with the proceeds from
the planned sale of $600 to $750 million of assets discussed above, will improve
CMS Energy's balance sheet. If market conditions are not satisfactory for
issuance of the tracking stock, CMS Energy will improve its balance sheet
through additional asset sales or alternate means. These actions are expected to
make further issuance of CMS Energy Common Stock unnecessary in the foreseeable
future, except for issuances in connection with existing convertible securities
or a major acquisition.
DIVERSIFIED ENERGY OUTLOOK
CMS Energy expects to grow its diversified energy businesses by focusing on
acquisitions and greenfield (new construction) projects in the central portion
of the United States, as well as high-growth markets in India, South America and
the Middle East. Additionally, the growth strategy includes exploiting its West
Africa oil and gas reserves, further developing markets for the fuel and
methanol product derived in West Africa, and investigating expansion
opportunities for its existing independent power project in West Africa. CMS
Energy seeks to minimize operational and financial risks when operating
internationally by utilizing multilateral financing institutions, procuring
political risk insurance and hedging foreign currency exposure where
appropriate.
CMS-14
64
CMS Energy intends to use its marketing, services and trading business to
improve the return on CMS Energy's other business assets. One method to achieve
this goal is to use marketing and trading to enhance performance of assets, such
as gas reserves and power plants. Other strategies include expanding CMS
Energy's industrial and commercial energy services to enhance our commodity
marketing business, using CMS Energy's gas production as a hedge to commodity
risk in other areas of our business, and developing risk management products
that address customer needs.
CONSUMERS' ELECTRIC UTILITY OUTLOOK
GROWTH: Consumers expects average annual growth of 2.5 percent per year in
electric system deliveries for the years 2000 to 2004. This growth rate does not
take into account the possible impact of restructuring or changed regulation on
the industry. Abnormal weather, changing economic conditions, or the developing
competitive market for electricity may affect actual electric sales by Consumers
in future periods.
COMPETITION AND REGULATORY RESTRUCTURING: Generally, electric restructuring is
the regulatory and legislative attempt to introduce competition to the electric
industry by allowing customers to choose their electric generation supplier,
while the transmission and distribution services remain regulated. As a result,
the electric generation suppliers ultimately compete in a less regulated
environment.Competition affects, and will continue to affect, Consumers' retail
electric business. To remain competitive, Consumers has multi-year electric
supply contracts with some of its largest industrial customers to provide power
to some of their facilities. The Michigan Public Service Commission (MPSC)
approved these contracts as part of its phased introduction to competition.
Beginning in 2000 through 2005, some customers, depending on future business and
regulatory circumstances, can terminate or restructure their contracts. The
termination or restructuring of these contracts could affect approximately 600
MW of customer power supply requirements. The ultimate financial impact of
changes related to these power supply contracts is not known at this time.
As a result of a transition of the wholesale and retail electric businesses in
Michigan to competition, The Detroit Edison Company (Detroit Edison), in
December 1996, gave Consumers the required four-year notice of its intent to
terminate the current agreements under which the companies jointly operate the
Michigan Electric Power Coordination Center (MEPCC). At the same time, Detroit
Edison filed with the Federal Energy Regulatory Commission (FERC) seeking early
termination of the agreements. The FERC has not acted on Detroit Edison's
application. Detroit Edison and Consumers are currently in negotiations to
terminate or restructure the MEPCC operations. Consumers is unable to predict
the outcome of these negotiations, but does not anticipate any adverse impacts
caused by termination or restructuring of the MEPCC.
In December 1999, a large coalition of utilities, businesses, and commercial and
industrial energy users agreed upon proposed electric restructuring legislation
for Michigan. This legislation: 1) provides for customer choice of power
suppliers for all customers by January 2002; 2) ensures full recovery of costs
incurred by utilities in order to serve their customers in a regulated monopoly
environment (Stranded Costs) calculated by taking into account the difference
between the market value and the net book value of the generation assets; and 3)
provides for deregulation of electric power suppliers who control less than 30
percent of the sum of Michigan's transmission import and generating capacity by
December 31, 2002. It also provides for a three-year rate freeze through 2002
for all utility customers who keep their utility as their electric supplier. To
be able to sell electric generation services on a deregulated basis, Consumers
would be required to transfer control of sufficient generation resources to meet
the 30 percent test. The legislation precludes Consumers' generating resources
from being deregulated prior to December 31, 2002. The proposed legislation was
introduced into the Michigan Legislature in January 2000, and is expected to be
considered in hearings during the first quarter of 2000. Consumers supports this
specific legislation.
CMS-15
65
Uncertainty exists with respect to the enactment of federal legislation
restructuring the electric power industry. A variety of bills introduced in
Congress in recent years seek to change existing federal regulation of the
industry. These federal bills could potentially affect or supercede state
regulation; however, none have been enacted. Consumers cannot predict the
outcome of electric restructuring on its financial position, liquidity, or
results of operations.
RATE MATTERS: There are several pending rate issues that could affect Consumers'
electric business. These matters include MPSC rate proceedings and electric
restructuring orders and a complaint by ABATE alleging excess revenues.
For further information and material changes relating to the rate matters and
restructuring of the electric utility industry, see Note 2, Summary of
Significant Accounting Policies and Other Matters, and Note 4, Uncertainties,
"Consumers' Electric Utility Rate Matters - Electric Proceedings" and
"Consumers' Electric Utility Rate Matters - Electric Restructuring,"
incorporated by reference herein.
UNCERTAINTIES: Several trends or uncertainties may affect CMS Energy's financial
results and condition as a result of Consumers' electric business. These trends
or uncertainties have, or CMS Energy reasonably expects could have, a material
impact on net sales, revenues, or income from continuing electric operations.
Such trends and uncertainties include: 1) capital expenditures for compliance
with the Clean Air Act; 2) environmental liabilities arising from compliance
with various federal, state and local environmental laws and regulations,
including potential liability or expenses relating to the Michigan Natural
Resources and Environmental Protection Act and Comprehensive Environmental
Response, Compensation and Liability Act (Superfund); 3) cost recovery relating
to the MCV Partnership; 4) an ABATE rate complaint; 5) electric industry
restructuring; 6) implementation of a frozen power supply cost recovery (PSCR)
and initiatives undertaken to reduce exposure to energy price increases; and 7)
nuclear decommissioning issues and ongoing issues relating to the storage of
spent fuel and the operating life of Palisades Nuclear Power Plant (Palisades).
For detailed information about these trends or uncertainties, see Note 4,
Uncertainties, incorporated by reference herein.
CONSUMERS' GAS UTILITY OUTLOOK
GROWTH: Consumers currently anticipates gas deliveries, including gas customer
choice deliveries (excluding transportation to the natural gas-fueled,
combined-cycle cogeneration facility operated by the MCV Partnership (MCV
Facility) and off-system deliveries), to grow at an average annual rate of
between one and two percent over the next five years based primarily on a
steadily growing customer base. Actual gas deliveries in future periods may be
affected by abnormal weather, alternative energy prices, changes in competitive
conditions, and the level of natural gas consumption. Consumers' gas business
also offers a variety of energy-related services to electric and gas customers
focused upon appliance maintenance, home safety, commodity choice and assistance
to customers purchasing heating, ventilation and air conditioning equipment.
REGULATORY RESTRUCTURING: In December 1999, several bills related to gas
industry restructuring were introduced into the Michigan Legislature. Combined,
these bills constitute the "gas choice program." Consumers is participating in
the legislative process as part of a gas utility coalition that also includes
Michigan Consolidated Gas Company and Southeastern Michigan Gas Company. These
bills provide for 1) a phased-in approach to gas choice requiring 40 percent of
the customers to be allowed choice by April 2002, 60 percent by April 2003 and
all customers by April 2004; 2) a market-based, unregulated pricing mechanism
for gas commodity for customers who exercise choice; and 3) a new "safe haven"
pricing mechanism for customers who do not exercise choice under which NYMEX
pricing would be used to establish a statutory cap on gas commodity prices that
could be charged by gas utilities instead of
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traditional cost of service regulation. The proposed bills also provide for a
gas distribution service rate freeze until December 31, 2005, a code of conduct
governing business relationships with affiliated gas suppliers and the MPSC
licensing of all gas suppliers doing business in Michigan and imposes financial
penalties for noncompliance. They also provide customer protection by preventing
"slamming", the switching of a customer's gas supplier without consent, and
"cramming", the inclusion of optional products and services without the
customer's authorization. The bills establishing the gas choice program will
become the subject of extensive legislative hearings during which there will
undoubtedly be various amendments offered by many parties, including the gas
utility coalition. Consumers cannot predict the outcome of this legislative
process.
UNCERTAINTIES: CMS Energy's financial results and position may be affected by a
number of trends or uncertainties that have, or CMS Energy reasonably expects
could have, a material impact on net sales or revenues or income from continuing
gas operations. Such trends and uncertainties include: 1) potential
environmental costs at a number of sites, including sites formerly housing
manufactured gas plant facilities; 2) a statewide experimental gas industry
restructuring program; 3) permanent gas industry restructuring; and 4)
implementation of a suspended gas cost recovery (GCR) and initiatives undertaken
to protect against gas price increases. For detailed information about these
uncertainties see Note 4, Uncertainties, incorporated by reference herein.
PANHANDLE OUTLOOK
CMS Energy intends to use Panhandle as a platform for expansion in the United
States. Panhandle plays an important role in the growth strategy by providing
services for the development of existing gas wells, production, and throughput
of gas to the market. To this end, CMS Energy must also consider expansion of
its existing gathering and processing facilities to accommodate anticipated
increased production. The market for transmission of natural gas to the Midwest
is increasingly competitive, however, and may become more so in light of
projects in progress to increase Midwest transmission capacity for gas
originating in Canada and the Rocky Mountain region. As a result, there
continues to be pressure on prices charged by Panhandle and an increasing
necessity to discount the prices charged from the legal maximum. Panhandle
continues to be selective in offering discounts to maximize revenues from
existing capacity and to advance projects that provide expanded services to meet
the specific needs of customers.
REGULATORY MATTERS: For detailed information about Panhandle's regulatory
uncertainties see Note 4, Uncertainties - Panhandle Matters, incorporated by
reference herein.
OTHER MATTERS
NEW ACCOUNTING RULES
In 1999, the Financial Accounting Standards Board (FASB) issued Statement of
Financial Accounting Standards (SFAS) 137, Accounting for Derivative Instruments
and Hedging Activities - Deferral of the Effective Date of FASB Statement
No.133. SFAS 137 defers the effective date of SFAS 133, Accounting for
Derivative Instruments and Hedging Activities, to January 1, 2001. CMS Energy is
currently studying SFAS 133 and plans to adopt SFAS 133 as of January 1, 2001,
but has yet to quantify the effects of adoption on its financial statements.
YEAR 2000 COMPUTER MODIFICATIONS
In 1999, CMS Energy completed a detailed assessment and inventory of all
technology related to business processes, with an emphasis on mission-critical
systems. CMS Energy identified, remediated and tested
CMS-17
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those systems that were not year 2000 ready to ensure that those systems would
operate as desired on and after January 1, 2000.
As a result of its year 2000 efforts, CMS Energy successfully transitioned to
the new year without experiencing year 2000-related system failures, power
outages or disruptions in services provided to its customers.
CMS Energy expensed the cost of software modifications as incurred, and
capitalized the cost of new software and equipment, which is being amortized
over its useful life. Since 1995, the total cost of the Year 2000 Program
modifications was approximately $30 million. CMS Energy funded year 2000
compliance work primarily from operations. This cost did not have a material
effect on CMS Energy's financial position, liquidity or results of operations.
The commitment of CMS Energy resources to the year 2000 issue has not deferred
any information technology projects that could have a material adverse effect on
CMS Energy's financial position, liquidity, or results of operations.
While CMS Energy does not expect any significant year 2000 issues to develop
after year-end 1999, CMS Energy will continue to monitor its systems throughout
the year 2000 to ensure that any year 2000 issues that may arise are addressed
promptly.
FOREIGN CURRENCY TRANSLATION
CMS Energy adjusts common stockholders' equity to reflect foreign currency
translation adjustments for the operation of long-term investments in foreign
countries. The adjustment is primarily due to the exchange rate fluctuations
between the United States dollar and each of the Australian dollar, Brazilian
real and Argentine peso. During 1999, the change in the foreign currency
translation adjustment increased equity by $28 million, net of after-tax hedging
proceeds. Although management currently believes that the currency exchange rate
fluctuations over the long term will not have a material adverse affect on CMS
Energy's financial position, liquidity or results of operations, CMS Energy has
hedged its exposure to the Australian dollar, the Brazilian real and the
Argentine peso. CMS Energy uses forward exchange and option contracts to hedge
certain receivables, payables, long-term debt and equity value relating to
foreign investments. The notional amount of the outstanding foreign exchange
contracts was $1.6 billion at December 31, 1999, which includes $207 million,
$435 million and $880 million for Australian, Brazilian and Argentine foreign
exchange contracts, respectively. The estimated fair value of the foreign
exchange and option contracts at December 31, 1999 was $64 million, representing
the amount CMS Energy would pay upon settlement.
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CONSOLIDATED STATEMENTS OF INCOME CMS ENERGY CORPORATION
In Millions
Years Ended December 31 1999 1998 1997
- ---------------------------------------------------------------------------------------------------------------------------------
OPERATING REVENUE Electric utility $ 2,667 $ 2,606 $ 2,515
Gas utility 1,156 1,051 1,204
Natural gas transmission, storage and processing 785 160 96
Independent power production 390 277 168
Oil and gas exploration and production 98 63 93
Marketing, services and trading 799 939 692
Other 208 45 13
-------------------------------------
6,103 5,141 4,781
- ---------------------------------------------------------------------------------------------------------------------------------
OPERATING EXPENSES Operation
Fuel for electric generation 406 359 319
Purchased power - related parties 560 573 599
Purchased and interchange power 509 584 265
Cost of gas sold 1,546 1,212 1,311
Other 1,021 763 719
-------------------------------------
4,042 3,491 3,213
Maintenance 216 176 174
Depreciation, depletion and amortization 595 484 467
General taxes 254 215 211
Write-off of investments in Nitrotec 84 - -
-------------------------------------
5,191 4,366 4,065
- ---------------------------------------------------------------------------------------------------------------------------------
PRETAX OPERATING Electric utility 494 475 432
INCOME (LOSS) Gas utility 132 126 153
Natural gas transmission, storage and processing,
net of $84 Nitrotec write-off in 1999 91 33 27
Independent power production 157 144 96
Oil and gas exploration and production 17 6 26
Marketing, services and trading 4 4 (5)
Other 17 (13) (13)
-------------------------------------
912 775 716
- ---------------------------------------------------------------------------------------------------------------------------------
OTHER INCOME Accretion income 4 6 8
(DEDUCTIONS) Accretion expense (14) (16) (17)
Loss on MCV power purchases - (37) -
Other, net 20 1 (3)
-------------------------------------
10 (46) (12)
- ---------------------------------------------------------------------------------------------------------------------------------
FIXED CHARGES Interest on long-term debt 502 318 273
Other interest 58 47 49
Capitalized interest (41) (29) (13)
Preferred dividends 6 19 25
Trust Preferred Securities distributions 56 32 18
- ---------------------------------------------------------------------------------------------------------------------------------
581 387 352
- ---------------------------------------------------------------------------------------------------------------------------------
INCOME BEFORE INCOME TAXES 341 342 352
INCOME TAXES 64 100 108
- ---------------------------------------------------------------------------------------------------------------------------------
CONSOLIDATED NET INCOME BEFORE CUMULATIVE EFFECT OF CHANGE
IN ACCOUNTING PRINCIPLE 277 242 244
CUMULATIVE EFFECT OF CHANGE IN ACCOUNTING FOR PROPERTY TAXES,
NET OF $23 TAX - 43 -
- ---------------------------------------------------------------------------------------------------------------------------------
CONSOLIDATED NET INCOME $ 277 $ 285 $ 244
=================================================================================================================================
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In Millions, Except Per Share Amounts
Years Ended December 31 1999 1998 1997
- ----------------------------------------------------------------------------------------------------------------------
CMS ENERGY
NET INCOME
Net Income Attributable to Common Stock $ 269 $ 272 $ 229
Premium on Redemption of Class G Stock (28) - -
--------------------------------
Net Income Available to Common Stock $ 241 $ 272 $ 229
================================
BASIC EARNINGS PER AVERAGE COMMON SHARE
Net Income Attributable to Common Stock $ 2.44 $ 2.65 $ 2.39
Premium on Redemption of Class G Stock (0.26) - -
--------------------------------
Net Income Available to Common Stock $ 2.18 $ 2.65 $ 2.39
================================
DILUTED EARNINGS PER AVERAGE COMMON SHARE
Net Income Attributable to Common Stock $ 2.42 $ 2.62 $ 2.37
Premium on Redemption of Class G Stock (0.25) - -
--------------------------------
Net Income Available to Common Stock $ 2.17 $ 2.62 $ 2.37
================================
DIVIDENDS DECLARED PER COMMON SHARE $ 1.39 $ 1.26 $ 1.14
- ----------------------------------------------------------------------------------------------------------------------
CLASS G
NET INCOME
Net Income Attributable to Common Stock $ 8 $ 13 $ 15
Premium on Redemption of Class G Stock 28 - -
--------------------------------
Net Income Available to Common Stock $ 36 $ 13 $ 15
================================
BASIC EARNINGS PER AVERAGE COMMON SHARE
Net Income Attributable to Common Stock $ 0.90 $ 1.56 $ 1.84
Premium on Redemption of Class G Stock 3.31 - -
--------------------------------
Net Income Available to Common Stock $ 4.21 $ 1.56 $ 1.84
================================
DILUTED EARNINGS PER AVERAGE COMMON SHARE
Net Income Attributable to Common Stock $ 0.90 $ 1.56 $ 1.84
Premium on Redemption of Class G Stock 3.31 - -
--------------------------------
Net Income Available to Common Stock $ 4.21 $ 1.56 $ 1.84
================================
DIVIDENDS DECLARED PER COMMON SHARE $ 0.99 $ 1.27 $ 1.21
- ----------------------------------------------------------------------------------------------------------------------
THE ACCOMPANYING NOTES ARE AN INTEGRAL PART OF THESE STATEMENTS.
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CONSOLIDATED STATEMENTS OF CASH FLOWS CMS ENERGY CORPORATION
In Millions
Years Ended December 31 1999 1998 1997
- -----------------------------------------------------------------------------------------------------------------------------------
CASH FLOWS FROM Consolidated net income $ 277 $ 285 $ 244
OPERATING ACTIVITIES Adjustments to reconcile net income to net cash
provided by operating activities
Depreciation, depletion and amortization (includes nuclear
decommissioning of $50, $51 and $50, respectively) 595 484 467
Deferred income taxes and investment tax credit 10 54 24
Capital lease and debt discount amortization 35 51 44
Loss on MCV power purchases - 37 -
Accretion expense 14 16 17
Accretion income (4) (6) (8)
Write-off of investments in Nitrotec 84 - -
Undistributed earnings of related parties (45) (95) (58)
Cumulative effect of accounting change - (66) -
MCV power purchases (62) (64) (62)
Changes in other assets and liabilities 13 (180) (44)
-------------------------------------
Net cash provided by operating activities 917 516 624
- -----------------------------------------------------------------------------------------------------------------------------------
CASH FLOWS FROM
INVESTING ACTIVITIES Capital expenditures (excludes assets placed under capital lease) (1,124) (1,295) (678)
Investments in partnerships and unconsolidated subsidiaries (380) (345) (830)
Cost to retire property, net (93) (83) (46)
Other (29) 32 (46)
Acquisition of companies, net of cash acquired (1,938) - -
Proceeds from sale of property - 57 49
-------------------------------------
Net cash used in investing activities (3,564) (1,634) (1,551)
- -----------------------------------------------------------------------------------------------------------------------------------
CASH FLOWS FROM Proceeds from notes, bonds and other long-term debt 2,836 2,348 1,214
FINANCING ACTIVITIES Issuance of Common Stock 84 269 224
Proceeds from Trust Preferred Securities 726 - 286
Retirement of bonds and other long-term debt (258) (661) (521)
Repayments of lines of credit, net (237) (574) (29)
Payment of Common Stock dividends (163) (140) (119)
Increase (decrease) in notes payable, net (97) (53) 49
Payment of capital lease obligations (19) (36) (44)
Retirement of Common Stock - (3) (2)
Retirement of preferred stock (194) - (120)
-------------------------------------
Net cash provided by financing activities 2,678 1,150 938
- -----------------------------------------------------------------------------------------------------------------------------------
NET INCREASE IN CASH AND TEMPORARY CASH INVESTMENTS 31 32 11
CASH AND TEMPORARY CASH INVESTMENTS, BEGINNING OF PERIOD 101 69 58
-------------------------------------
CASH AND TEMPORARY CASH INVESTMENTS, END OF PERIOD $ 132 $ 101 $ 69
- -----------------------------------------------------------------------------------------------------------------------------------
THE ACCOMPANYING NOTES ARE AN INTEGRAL PART OF THESE STATEMENTS.
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CONSOLIDATED BALANCE SHEETS CMS ENERGY CORPORATION
ASSETS In Millions
December 31 1999 1998
- -----------------------------------------------------------------------------------------------------------------------------
PLANT AND PROPERTY Electric utility $ 6,981 $ 6,720
(AT COST) Gas utility 2,461 2,360
Natural gas transmission, storage and processing 1,934 341
Independent power production 974 518
Oil and gas properties (successful efforts method) 817 670
International energy distribution 445 324
Other 62 49
---------------------------------------
13,674 10,982
Less accumulated depreciation, depletion and amortization 6,157 5,213
---------------------------------------
7,517 5,769
Construction work-in-progress 604 271
---------------------------------------
8,121 6,040
- -----------------------------------------------------------------------------------------------------------------------------
INVESTMENTS Independent power production 950 888
Natural gas transmission, storage and processing 369 494
International energy distribution 150 209
Midland Cogeneration Venture Limited Partnership 247 209
First Midland Limited Partnership 240 240
Other 40 33
---------------------------------------
1,996 2,073
- -----------------------------------------------------------------------------------------------------------------------------
CURRENT ASSETS Cash and temporary cash investments at cost, which
approximates market 132 101
Accounts receivable, notes receivable and accrued revenue,
less allowances $12 in 1999 and $13 in 1998 959 720
Inventories at average cost
Gas in underground storage 225 219
Materials and supplies 158 99
Generating plant fuel stock 47 43
Deferred income taxes 33 -
Prepayments and other 263 225
---------------------------------------
1,817 1,407
- -----------------------------------------------------------------------------------------------------------------------------
NON-CURRENT ASSETS Goodwill, net 891 46
Nuclear decommissioning trust funds 602 557
Unamoritzed nuclear costs 519 -
Postretirement benefits 348 373
Notes receivable - related parties 251 20
Abandoned Midland project 48 71
Other 869 723
---------------------------------------
3,528 1,790
---------------------------------------
TOTAL ASSETS $ 15,462 $ 11,310
- -----------------------------------------------------------------------------------------------------------------------------
THE ACCOMPANYING NOTES ARE AN INTEGRAL PART OF THESE STATEMENTS.
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CMS ENERGY CORPORATION
STOCKHOLDERS' INVESTMENT AND LIABILITIES In Millions
December 31 1999 1998
- -----------------------------------------------------------------------------------------------------------------------------------
CAPITALIZATION Common stockholders' equity $ 2,456 $ 2,216
Preferred stock of subsidiary 44 238
Company-obligated mandatorily redeemable Trust Preferred Securities of:
Consumers Power Company Financing I (a) 100 100
Consumers Energy Company Financing II (a) 120 120
Consumers Energy Company Financing III (a) 175 -
Company-obligated convertible Trust Preferred Securities of:
CMS Energy Trust I (b) 173 173
CMS Energy Trust II (b) 301 -
Company-obligated Trust Preferred Securities of CMS RHINOS Trust (c) 250 -
Long-term debt 6,987 4,726
Non-current portion of capital leases 88 105
---------------------------
10,694 7,678
- -----------------------------------------------------------------------------------------------------------------------------------
CURRENT LIABILITIES Current portion of long-term debt and capital leases 552 293
Notes payable 230 328
Accounts payable 775 501
Accrued taxes 320 272
Accounts payable - related parties 61 79
Accrued interest 148 65
Power purchases - MCV Partnership 47 47
Accrued refunds 11 11
Other 363 211
---------------------------
2,507 1,807
- -----------------------------------------------------------------------------------------------------------------------------------
NON-CURRENT LIABILITIES Deferred income taxes 703 652
Postretirement benefits 485 489
Deferred investment tax credit 125 135
Power purchases - MCV Partnership 73 121
Regulatory liabilities for income taxes, net 64 87
Other 811 341
---------------------------
2,261 1,825
---------------------------
Commitments and Contingencies (Notes 2, 4, 14 and 19)
TOTAL STOCKHOLDERS' INVESTMENT AND LIABILITIES $ 15,462 $ 11,310
- -----------------------------------------------------------------------------------------------------------------------------------
(a) The primary asset of Consumers Power Company Financing I is $103 million
principal amount of 8.36 percent subordinated deferrable interest notes due 2015
from Consumers. The primary asset of Consumers Energy Company Financing II is
$124 million principal amount of 8.20 percent subordinated deferrable interest
notes due 2027 from Consumers. The primary asset of Consumers Energy Company
Financing III is $180 million principal amount of 9.25 percent subordinated
deferrable interest notes due 2029 from Consumers. For further discussion, see
Note 7 to the Consolidated Financial Statements.
(b) The primary asset of CMS Energy Trust I is $178 million principal amount of
7.75 percent convertible subordinated deferrable interest debentures due 2027
from CMS Energy. The primary asset of CMS Energy Trust II is $310 million
principal amount of 8.625 percent convertible junior subordinated deferrable
interest debentures due July 2004 from CMS Energy. For further discussion, see
Note 7 to the Consolidated Financial Statements.
(c) As described in Note 7, the primary asset of CMS RHINOS Trust is $258
million principal amount of LIBOR plus 1.75 percent subordinated deferrable
interest debentures due September 2001 from CMS Energy.
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CONSOLIDATED STATEMENTS OF PREFERRED STOCK CMS ENERGY CORPORATION
Optional
Redemption Number of Shares In Millions
December 31 Series Price 1999 1998 1999 1998
- ---------------------------------------------------------------------------------------------------------------------------
CONSUMERS' PREFERRED STOCK
Cumulative, $100 par value,
authorized 7,500,000 shares, $4.16 $103.25 68,451 68,451 $ 7 $ 7
with no mandatory redemption 4.50 110.00 373,148 373,148 37 37
CONSUMERS' CLASS A PREFERRED STOCK
Cumulative, no par value,
authorized 16,000,000 shares,
with no mandatory redemption 2.08 25.00 (a) - 8,000,000 - 194
----------------
TOTAL PREFERRED STOCK $ 44 $ 238
===========================================================================================================================
(a) Redeemed April 1, 1999.
THE ACCOMPANYING NOTES ARE AN INTEGRAL PART OF THESE STATEMENTS.
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CONSOLIDATED STATEMENTS OF COMMON STOCKHOLDERS' EQUITY CMS ENERGY CORPORATION
Number of Shares in Thousands In Millions
Years Ended December 31 1999 1998 1997 1999 1998 1997
- ---------------------------------------------------------------------------------------------------------------------------------
COMMON STOCK
At beginning and end of period $ 1 $ 1 $ 1
- ---------------------------------------------------------------------------------------------------------------------------------
OTHER PAID-IN CAPITAL - CMS ENERGY
At beginning of period 108,104 100,792 94,813 2,452 2,131 1,916
Redemption of affiliate's preferred stock - - - (2) - -
Common stock reacquired (61) (72) (54) (2) (3) (2)
Common stock issued 1,823 7,383 6,031 83 324 217
Common stock reissued 39 1 2 1 - -
Exchange of Class G common stock 6,133 - - 217 -
--------------------------------------------------------------------------
At end of period 116,038 108,104 100,792 2,749 2,452 2,131
- ---------------------------------------------------------------------------------------------------------------------------------
OTHER PAID-IN CAPITAL - CLASS G
At beginning of period 8,453 8,219 7,877 142 136 129
Common stock reacquired - (1) (1) - - -
Common stock issued 257 235 343 6 6 7
Redemption of common stock (8,710) - - (148) - -
--------------------------------------------------------------------------
At end of period - 8,453 8,219 - 142 136
- ---------------------------------------------------------------------------------------------------------------------------------
REVALUATION CAPITAL
At beginning of period (9) (6) (6)
Change in unrealized investment-gain (loss) (a) 12 (3) -
---------------------------------------
At end of period 3 (9) (6)
- ---------------------------------------------------------------------------------------------------------------------------------
FOREIGN CURRENCY TRANSLATION
At beginning of period (136) (96) -
Change in foreign currency translation (a) 28 (40) (96)
---------------------------------------
At end of period (108) (136) (96)
- ---------------------------------------------------------------------------------------------------------------------------------
RETAINED EARNINGS (DEFICIT)
At beginning of period (234) (379) (504)
Consolidated net income (a) 277 285 244
Redemption of Class G common stock (69) - -
Common stock dividends declared:
CMS Energy (154) (129) (109)
Class G (9) (11) (10)
---------------------------------------
At end of period (189) (234) (379)
---------------------------------------
TOTAL COMMON STOCKHOLDERS' EQUITY $ 2,456 $ 2,216 $ 1,787
=================================================================================================================================
(A) DISCLOSURE OF COMPREHENSIVE INCOME:
Revaluation capital
Unrealized investment-gain (loss), net of tax of
$(6), $2 and $0, respectively $ 12 $ (3) $ -
Foreign currency translation 28 (40) (96)
Consolidated net income 277 285 244
---------------------------------------
Total Consolidated Comprehensive Income $ 317 $ 242 $ 148
=======================================
THE ACCOMPANYING NOTES ARE AN INTEGRAL PART OF THESE STATEMENTS.
CMS-27
77
CMS ENERGY CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
1: CORPORATE STRUCTURE
CMS Energy Corporation (CMS Energy) is the parent holding company of Consumers
Energy Company (Consumers) and CMS Enterprises Company (Enterprises). Consumers,
a combination electric and gas utility company serving the Lower Peninsula of
Michigan, is a subsidiary of CMS Energy. Enterprises, through subsidiaries, is
engaged in several domestic and international diversified energy businesses
including: natural gas transmission, storage and processing; independent power
production; oil and gas exploration and production; energy marketing, services
and trading; and international energy distribution. In March 1999, CMS Energy
completed the acquisition of Panhandle Eastern Pipe Line Company, including its
subsidiaries Trunkline and Pan Gas Storage, and its affiliates Panhandle Storage
and Trunkline LNG (Panhandle), as discussed further below. Panhandle is
primarily engaged in the interstate transportation, storage and processing of
natural gas.
2: SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES AND OTHER MATTERS
BASIS OF PRESENTATION: The consolidated financial statements include CMS Energy,
Consumers and Enterprises and their majority owned subsidiaries. The financial
statements are prepared in conformity with generally accepted accounting
principles and use management's estimates where appropriate. Affiliated
companies (where CMS Energy has more than 20 percent but less than a majority
ownership interest) are accounted for by the equity method.
CHANGE IN METHOD OF ACCOUNTING FOR PROPERTY TAXES: During the first quarter of
1998, Consumers implemented a change in the method of accounting for property
taxes so that such taxes are recognized during the fiscal period of the taxing
authority for which the taxes are levied. This change better matches property
tax expense with the services provided by the taxing authorities, and is
considered the most acceptable basis of recording property taxes. Prior to 1998,
Consumers recorded property taxes monthly during the year following the
assessment date (December 31). The cumulative effect of this one-time change in
accounting increased other income in 1998 by $66 million, and earnings, net of
tax, by $43 million or $.40 per basic and diluted share of CMS Energy Common
Stock, including increased other income by $18 million and earnings, net of tax,
of $12 million, or $.36 per basic and diluted share of Class G Common Stock. The
pro forma effect on prior years' consolidated net income of retroactively
recording property taxes as if the new method of accounting had been in effect
for all periods presented is not material.
NON-RECURRING CHARGE: In 1999, CMS Gas Transmission and Storage Company (CMS Gas
Transmission) wrote off the carrying amounts of investments in Nitrotec
Corporation, a proprietary gas processing company which has patents for its
helium removal and nitrogen rejection processes for purifying natural gas. This
write-off occurred after determining that it was unlikely CMS Gas Transmission
would recover any portion of its investments. The write-off of these investments
resulted in a reduction in 1999 operating income of $84 million and reduced net
earnings by $49 million, or $.45 and $.43 per basic and diluted share of CMS
Energy Common Stock, respectively.
CMS-28
78
ACCRETION INCOME AND EXPENSE: In 1991, the Michigan Public Service Commission
(MPSC) allowed Consumers to recover a portion of its abandoned Midland
investment over a 10-year period, but did not allow Consumers to earn a return
on that amount. Consumers reduced the recoverable investment to the present
value of the future recoveries. During the recovery period, Consumers adjusts
the unrecovered asset to its present value. It reflects this adjustment as
accretion income. Conversely, Consumers recorded a loss in 1992 for the present
value of its estimated future underrecoveries of power costs resulting from
purchases from the Midland Cogeneration Venture Limited Partnership (MCV
Partnership) (see Note 4). It now recognizes accretion expense annually to
reflect the time value of money on the recorded loss.
GAS INVENTORY: Consumers uses the weighted average cost method for valuing
working gas inventory. It records cushion gas, which is gas stored to maintain
reservoir pressure for recovery of working gas, in the appropriate gas utility
plant account. Consumers stores gas inventory in its underground storage
facilities.
GOODWILL AMORTIZATION: Goodwill represents the excess of the purchase price over
the fair value of the net assets of acquired companies and is amortized using
the straight-line method principally over 40 years. The carrying amount of
goodwill is reviewed annually using undiscounted cash flows for the businesses
acquired over the remaining amortization periods. At December 31, 1999, no
impairments existed. Accumulated amortization of goodwill at December 31, 1999
and 1998 was $25 million and $2 million, respectively.
MAINTENANCE, DEPRECIATION AND DEPLETION: Consumers charges property repairs and
minor property replacements to maintenance expense. Depreciable property retired
or sold, plus cost of removal (net of salvage credits), is charged to
accumulated depreciation. Consumers bases depreciation provisions for utility
property on straight-line and units-of-production rates approved by the MPSC.
The composite depreciation rate for electric utility property was 3.0 percent
for 1999, 3.5 percent for 1998 and 3.6 percent for 1997. The composite rate for
gas utility property was 4.4 percent for 1999, 4.2 percent for 1998 and 4.1
percent for 1997. The composite rate for other property was 8.6 percent for
1999, 7.4 percent for 1998 and 8.2 percent for 1997.
CMS Oil and Gas Company (CMS Oil and Gas) follows the successful efforts method
of accounting for its investments in oil and gas properties. CMS Oil and Gas
capitalizes, as incurred, the costs of property acquisitions, successful
exploratory wells, all development costs, and support equipment and facilities.
It expenses unsuccessful exploratory wells when they are determined to be
non-productive. CMS Oil and Gas also charges to expense, as incurred, production
costs, overhead, and all exploration costs other than exploratory drilling. CMS
Oil and Gas determines depreciation, depletion and amortization of proved oil
and gas properties on a field-by-field basis using the units-of-production
method over the life of the remaining proved reserves.
Other nonutility depreciable property is amortized over its estimated useful
life; gains and losses on asset sales are recognized at the time of sale.
NUCLEAR FUEL COST: Consumers amortizes nuclear fuel cost to fuel expense based
on the quantity of heat produced for electric generation. Interest on leased
nuclear fuel is expensed as incurred. Under current federal law, as confirmed by
court decision, the U.S. Department of Energy (DOE) was to begin accepting
deliveries of spent nuclear fuel for disposal by January 31, 1998. For fuel used
after April 6, 1983, Consumers charges disposal costs to nuclear fuel expense,
recovers them through electric rates, and then remits them to the DOE quarterly.
Consumers elected to defer payment for disposal of spent nuclear fuel burned
before April 7, 1983. At December 31, 1999, Consumers had a recorded liability
to the DOE of $123 million, including interest, which is payable upon the first
delivery of spent nuclear fuel to the DOE.
CMS-29
79
Consumers recovered through electric rates the amount of this liability,
excluding a portion of interest. In January 1997, in response to the DOE's
declaration that it would not begin to accept spent nuclear fuel deliveries in
1998, Consumers and other utilities filed suit in federal court. The court
issued a decision in late 1997 affirming the DOE's duty to take delivery of
spent fuel, but was not specific as to the relief available for failure of the
DOE to comply. Further litigation brought by Consumers and others in 1998 that
was intended to produce specific relief for the DOE's failure to comply has not
been successful to date, although such litigation efforts continue. In January
1999, federal legislation was reintroduced in the House of Representatives to
clarify the timing of the DOE's obligation to accept spent nuclear fuel and to
direct the DOE to establish an integrated spent fuel management system that
includes designing and constructing an interim storage facility in Nevada.
Similar legislation was reintroduced in the Senate. Consumers cannot predict the
outcome of this process.
NUCLEAR PLANT DECOMMISSIONING: Consumers collected $50 million in 1999 from its
electric customers for decommissioning of its two nuclear plants. Amounts
collected from electric retail customers and deposited in trusts (including
trust earnings) are credited to accumulated depreciation. On March 22, 1999,
Consumers received a decommissioning order from the MPSC that approved estimated
decommissioning costs for Big Rock Point nuclear power plant (Big Rock) and
Palisades nuclear power plant (Palisades) of $315 million and $566 million
(calculated in 1999 dollars), respectively. Consumers' site-specific
decommissioning cost estimates for Big Rock and Palisades assume that each plant
site will eventually be restored to conform to the adjacent landscape, and all
contaminated equipment will be disassembled and disposed of in a licensed burial
facility. The MPSC order also set the annual decommissioning surcharges for Big
Rock and Palisades at $32 million and $14 million a year, respectively, and
required Consumers to file revised decommissioning surcharges for Palisades that
incorporate a gradual reduction in the decommissioning trust's equity
investments following the plant's retirement. On December 16, 1999, the MPSC
approved a revised decommissioning surcharge for Palisades in the amount of $6
million a year, effective January 1, 2000.
Big Rock closed permanently in 1997 because management determined that it would
be uneconomical to operate in an increasingly competitive environment. The plant
was originally scheduled to close on May 31, 2000, at the end of the plant's
operating license. The MPSC allowed Consumers to continue collecting
decommissioning surcharges through December 31, 2000. Plant decommissioning
began in 1997 and it may take five to ten years to return the site to its
original condition. For 1999, Consumers incurred costs of $51 million that were
charged to the accumulated depreciation reserve for decommissioning and withdrew
$43 million from the Big Rock nuclear decommissioning trust fund. In total,
Consumers has incurred costs of $126 million that have been charged to the
accumulated depreciation reserve for decommissioning and withdrew $112 million
from the Big Rock nuclear decommissioning trust fund. These activities had no
material impact on net income. At December 31, 1999, Consumers is the
beneficiary of the investment in nuclear decommissioning trust funds of $181
million for Big Rock.
After retirement of Palisades, Consumers plans to maintain the facility in
protective storage if radioactive waste disposal facilities are not available.
Consumers will incur most of the Palisades decommissioning costs after the
plant's Nuclear Regulatory Commission (NRC) operating license expires. When
Palisades' NRC license expires in 2007, the trust funds are currently estimated
to have accumulated $667 million, assuming currently approved MPSC surcharge
levels. Consumers estimates that at the time Palisades is fully decommissioned
in the year 2046, the trust funds will have provided $1.9 billion, including
trust earnings, over this decommissioning period. At December 31, 1999,
Consumers is the beneficiary of the investment in nuclear decommissioning trust
funds of $421 million for Palisades.
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RECLASSIFICATIONS: CMS Energy has reclassified certain prior year amounts for
comparative purposes. These reclassifications did not affect consolidated net
income for the years presented.
RELATED-PARTY TRANSACTIONS: In 1999, 1998 and 1997, Consumers paid $52 million,
$51 million and $51 million, respectively, for electric generating capacity and
the energy generated by that capacity from affiliates of Enterprises. Affiliates
of CMS Energy sold, stored and transported natural gas and provided other
services to the MCV Partnership totaling $37 million, $21 million and $21
million for 1999, 1998 and 1997. For additional discussion of related-party
transactions with the MCV Partnership and the First Midland Limited Partnership
(FMLP), see Notes 4 and 19. Other related-party transactions are immaterial.
UTILITY REGULATION: Consumers accounts for the effects of regulation based on
the regulated utility accounting standard Statement of Financial Accounting
Standards (SFAS) 71, Accounting for the Effects of Certain Types of Regulation.
As a result, the actions of regulators affect when Consumers recognizes
revenues, expenses, assets and liabilities.
In March 1999, Consumers received MPSC electric restructuring orders which,
among other things, identified the terms and timing for implementing electric
restructuring in Michigan. Consistent with these orders, Consumers discontinued
application of SFAS 71 for the energy supply portion of its business in the
first quarter of 1999 because Consumers expected to implement retail open access
for its electric customers in September 1999. Discontinuation of SFAS 71 for the
energy supply portion of Consumers' business resulted in Consumers reducing the
carrying value of its Palisades plant-related assets by approximately $535
million and establishing a regulatory asset for a corresponding amount. The
regulatory asset is collectible as part of the costs incurred by Stranded Costs,
as defined, plus the costs incurred in the transition to competition (Transition
Costs) which are recoverable through the regulated transmission and distribution
portion of Consumers' business as approved by an MPSC order in 1998. This order
also allowed Consumers to recover any energy supply-related regulatory assets,
plus a return on any unamortized balance of those assets, from its transmission
and distribution customers. According to current accounting standards, Consumers
can continue to carry its energy supply-related regulatory assets if legislation
or an MPSC rate order allows the collection of cash flows, to recover these
regulatory assets, from its regulated transmission and distribution customers.
At December 31,1999, Consumers had a net investment in energy supply facilities
of $949 million included in electric plant and property.
SFAS 121, Accounting for the Impairment of Long-Lived Assets and for
Long-LivedAssets to be Disposed of, imposes stricter criteria for retention of
regulatory-created assets by requiring that such assets be probable of future
recovery at each balance sheet date. Management believes these assets will be
recovered.
The following regulatory assets (liabilities), which include both current and
non-current amounts, are reflected in the Consolidated Balance Sheets. These
costs are being recovered through rates over periods of up to 13 years.
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In Millions
December 31 1999 1998
- --------------------------------------------------------------------------------
Postretirement benefits $ 366 $ 397
Income taxes 193 148
Abandoned Midland project 48 71
Manufactured gas plant sites 65 48
Demand-side management (DSM) - deferred costs 13 32
Uranium enrichment facility 18 20
Other 33 38
---------------------
Total regulatory assets $ 736 $ 754
===============================================================================
Income taxes $(257) $(235)
DSM - deferred revenue (17) (24)
---------------------
Total regulatory liabilities $(274) $(259)
===============================================================================
IMPLEMENTATION OF NEW ACCOUNTING STANDARDS: In 1999, CMS Energy implemented
statement of position (SOP) 98-1, Accounting for the Costs of Computer Software
Developed for Internal Use, and SOP 98-5, Reporting on the Costs of Start-Up
Activities. Application of these standards has not had a material effect on CMS
Energy's financial position, liquidity, or results of operations. Effective
January 1, 1999, CMS Energy adopted Emerging Issues Task Force (EITF) Issue
98-10, Accounting for Energy Trading and Risk Management Activities, which
requires mark-to-market accounting for energy contracts entered into for trading
purposes. Under mark-to-market accounting, gains and losses resulting from
changes in market prices on contracts entered into for trading purposes are
reflected in current earnings. The after-tax mark-to-market adjustment resulting
from the adoption of EITF 98-10 did not have a material effect on CMS Energy's
consolidated financial position, results of operations and cash flows as of
December 31, 1999. For energy contracts that are hedges of non-trading
activities, CMS Energy will continue to use accrual accounting until it adopts
SFAS 133, Accounting for Derivative Instruments and Hedging Activities, which
will be effective January 1, 2001.
FOREIGN CURRENCY TRANSLATION: Foreign currency translation adjustments relating
to the operation of CMS Energy's long-term investments in foreign countries are
included in common stockholders' equity. For the year ended December 31, 1999
the change in the foreign currency translation adjustment increased equity by
$28 million, net of after-tax hedging proceeds.
OTHER: For significant accounting policies regarding cash equivalents, see Note
17; for income taxes, see Note 10; for executive incentive compensation, see
Note 12; and for pensions and other postretirement benefits, see Note 13.
3: ACQUISITION
In March 1999, CMS Energy completed the acquisition of Panhandle from Duke
Energy Corporation (Duke Energy) for a cash payment of $1.9 billion and existing
Panhandle debt of $300 million. CMS Energy used the purchase method of
accounting to account for the acquisition and, accordingly, included
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the results of operations of Panhandle for the period from March 29, 1999 in the
accompanying consolidated financial statements. Assets acquired and liabilities
assumed are recorded at their estimated fair values and are subject to
adjustment when additional information concerning asset and liability valuations
is finalized by the end of the first quarter of 2000. CMS Energy allocated the
tentative excess purchase price over the estimated fair value of net assets
acquired of approximately $800 million to goodwill and amortizes this amount on
a straight-line basis over 40 years.
The following unaudited pro forma amounts for operating revenue, consolidated
net income, basic earnings per share and diluted earnings per share, as if the
acquisition had occurred on January 1, 1998, illustrate the effects of: (1)
various restructuring, realignment, and elimination of activities between
Panhandle and Duke Energy prior to the closing of the acquisition by CMS Energy;
(2) the adjustments resulting from the acquisition by CMS Energy; and (3)
financing transactions which include the public issuance of $800 million of
senior notes by Panhandle, $850 million of senior notes by CMS Energy, and the
private sale of $250 million of Trust Preferred Securities by CMS Energy.
In Millions, Except Per Share Amounts
- ------------------------------------------------------------------------------------------------------
Years Ended December 31 1999 1998
- ------------------------------------------------------------------------------------------------------
Operating revenue $6,216 $5,566
Consolidated net income $287 $289
BASIC EARNINGS PER SHARE:
Basic earnings per share before
Class G Common Stock Exchange $2.53 $2.70
Effects of Premium on Redemption
of Class G Common Stock (.26) -
Basic earnings per share after
--------------------------------------------
Class G Common Stock Exchange $2.27 $2.70
============================================
DILUTED EARNINGS PER SHARE:
Diluted earnings per share before
Class G Common Stock Exchange $2.51 $2.67
Effects of Premium on Redemption
of Class G Common Stock (.25) -
Diluted earnings per share after
--------------------------------------------
Class G Common Stock Exchange $2.26 $2.67
======================================================================================================
4: UNCERTAINTIES
CONSUMERS' ELECTRIC UTILITY CONTINGENCIES
ELECTRIC ENVIRONMENTAL MATTERS: The Clean Air Act limits emissions of sulfur
dioxide and nitrogen oxides and requires emissions and air quality monitoring.
Consumers currently operates within these limits and meets current emission
requirements. The Clean Air Act requires the Environmental Protection Agency
(EPA) to review periodically the effectiveness of the national air quality
standards in preventing adverse health effects. In 1997, the EPA revised these
standards to impose further limitations on nitrogen oxide and small
particulate-related emissions. In May 1999, a United States Court of Appeals
ruled that
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the grant of authority to the EPA, to revise the standards as the EPA did, would
amount to an unconstitutional delegation of legislative power. As a result, the
EPA will not implement the standards under the 1997 rule. On October 28, 1999,
the United States Court of Appeals denied a request by the EPA for a rehearing.
On January 27, 2000, the Department of Justice filed a petition for the United
States Supreme Court to review the case. Because of the United States Court of
Appeals decisions, the EPA has proposed to reinstate the pre-1997 standards.
In September 1998, based in part upon the 1997 standards, the EPA Administrator
issued final regulations requiring the state of Michigan to limit further
nitrogen oxide emissions. Consumers anticipates a reduction in nitrogen oxide
emissions by 2003 to only 32 percent of levels allowed for the year 2000. The
state of Michigan had one year to submit an implementation plan. The state of
Michigan filed a lawsuit objecting to the extent of the required emission
reductions and requesting an extension of the submission date. In May 1999 the
United States Court of Appeals granted an indefinite stay of the submission date
for the state of Michigan's implementation plan. In early 2000, the United
States Court of Appeals upheld the EPA's final regulations. The state of
Michigan is expected to appeal this ruling. Until the appeal is decided, it is
unlikely that the state of Michigan will establish Consumers' nitrogen oxide
emissions reduction target. In December 1999, the EPA Administrator signed a
revised final rule under Section 126 of the Clean Air Act. The rule requires
some electric utility generators, including some of Consumers' electric
generating facilities, to achieve the same emission rate as that required by the
currently challenged September 1998 EPA final rule. Under the revised Section
126 rule, the emission rate will become effective on May 1, 2003 and apply
during the ozone season in 2003 and during each subsequent year. Various
parties' petitions challenging the EPA's rule have been filed. Until these
targets are lawfully established, the estimated cost of compliance discussed
below is subject to revision.
The preliminary estimates of capital expenditures to reduce nitrogen
oxide-related emissions to the level proposed by the state of Michigan for
Consumers' fossil-fueled generating units range from $150 million to $290
million, calculated in 1999 dollars. If Consumers had to meet the EPA's 1997
proposed requirements, the estimated cost to Consumers would be between $290
million and $500 million, calculated in 1999 dollars. In both these cases the
lower estimate represents the capital expenditure level that would
satisfactorily meet the proposed emissions limits but would result in higher
operating expense. The higher estimate in the range includes expenditures that
result in lower operating costs while complying with the proposed emissions
limit. Consumers anticipates that it will incur these capital expenditures
between 2000 and 2004, or between 2000 and 2003 if the EPA ultimately imposes
its limits.
Consumers may need an equivalent amount of capital expenditures to comply with
the new small particulate standards sometime after 2004 if those standards
become effective.
Consumers' coal-fueled electric generating units burn low-sulfur coal and are
currently operating at or near the sulfur dioxide emission limits that will be
effective in the year 2000. During the past few years, to comply with the Clean
Air Act, Consumers incurred capital expenditures totaling $67 million to install
equipment at certain generating units. Consumers estimates an additional $5
million of capital expenditures for ongoing and proposed modifications at the
remaining coal-fueled units to meet year 2000 requirements. Management believes
that these expenditures will not materially affect Consumers' annual operating
costs.
Under the Michigan Natural Resources and Environmental Protection Act, Consumers
expects that it will ultimately incur investigation and remedial action costs at
a number of sites. Nevertheless, it believes that these costs are properly
recoverable in rates under current ratemaking policies.
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Consumers is a potentially responsible party at several contaminated sites
administered under the Comprehensive Environmental Response, Compensation and
Liability Act (Superfund). Superfund liability is joint and several; along with
Consumers, many other creditworthy, potentially responsible parties with
substantial assets cooperate with respect to the individual sites. Based upon
past negotiations, Consumers estimates that its share of the total liability for
the known Superfund sites will be between $2 million and $9 million. At December
31, 1999, Consumers has accrued the minimum amount of the range for its
estimated Superfund liability.
While decommissioning Big Rock, Consumers found that some areas of the plant
have coatings that contain both metals and poly chlorinated biphenyls (PCBs).
Consumers believes it now has viable disposal options for these materials. It
estimates the additional cost associated with PCB waste at $1.5 million. The
cost of removal and disposal will constitute part of the cost to decommission
the plant and will be paid from the decommissioning fund.
ANTITRUST: In October 1997, two independent power producers sued Consumers in a
federal court. The suit alleged antitrust violations relating to contracts which
Consumers entered into with some of its customers, and interference with
contract claims relating to proposed power facilities. On March 31, 1999, the
court issued an opinion and order granting Consumers' motion for summary
judgment, resulting in the dismissal of the case. The plaintiffs have appealed
this decision. Consumers cannot predict the outcome of this appeal.
CONSUMERS' ELECTRIC UTILITY RATE MATTERS
ELECTRIC PROCEEDINGS: In 1996, the MPSC issued a final order that authorized
Consumers to recover costs associated with the purchase of the additional 325
megawatts (MW) of the natural gas-fueled, combined-cycle cogeneration facility
operated by the MCV Partnership (MCV Facility) capacity (see "Power Purchases
from the MCV Partnership" in this Note). In addition, the order allowed
Consumers to recover its nuclear plant investment by increasing prospective
annual nuclear plant depreciation expense by $18 million, with a corresponding
decrease in fossil-fueled generating plant depreciation expense. The order also
established an experimental direct-access program. Customers having a maximum
demand for electric power of 2 MW or greater are eligible to purchase generation
services directly from any eligible third-party power supplier. Consumers will
transmit that power for a fee. Delivery of electric power through this
direct-access program is limited to 134 MW. In accordance with the MPSC order,
Consumers held a lottery to select the customers that would participate in the
direct-access program. Subsequently, direct-access for a portion of this 134 MW
began in late 1997. The program was substantially filled by the end of March
1999. The Michigan Attorney General (Attorney General), Association of
Businesses Advocating Tariff Equity (ABATE), the MCV Partnership and other
parties filed appeals with the Michigan Court of Appeals (Court of Appeals)
challenging the MPSC's 1996 order. In August 1999, the Court of Appeals affirmed
the MPSC's 1996 order in all respects. In October 1999, the Attorney General
filed an application for leave to appeal this decision to the Michigan Supreme
Court.
In November 1997, ABATE filed a complaint with the MPSC. The complaint alleged
that Consumers' electric earnings are more than its authorized rate of return
and sought an immediate reduction in Consumers' electric rates. In testimony
filed in this case, ABATE claimed that Consumers received approximately $189
million in excess revenues for 1998. In its testimony, the MPSC staff stated
that 1998 financial results show excess revenues of $118 million compared to the
previously authorized electric return on equity. The MPSC staff offered several
alternatives for the MPSC to consider. These alternatives involve several
different refunds or reductions that the MPSC could consider separately or in
combination,
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but if made, would not result in a permanent future reduction in electric rates
in the amount being sought by ABATE. Consumers filed testimony showing that
after ratemaking adjustments and normalizations, there is a revenue deficiency
of approximately $3 million. ABATE and other interveners bear the burden of
convincing the MPSC to reduce electric rates, which will otherwise remain
unchanged. Consumers believes that ABATE has not met its burden of proving that
a reduction in rates is required. Consumers also believes that ABATE's request
for refunds from 1995 to present is inappropriate and unlawful; no such
retroactive rate adjustment has ever been granted by the MPSC. In December 1999,
an announcement was made that an agreement concerning legislation in Michigan on
electric deregulation had been reached by Consumers, ABATE, and numerous other
industrial and commercial business interests. In anticipation of the legislation
being introduced, ABATE and Consumers jointly filed a request with the MPSC to
suspend ABATE's electric rate complaint to allow for consideration of the
proposed legislation. The MPSC granted a temporary suspension for 120 days
(expiring in April 2000), subject to its authority to withdraw the suspension at
any time. As part of the suspension, Consumers agreed that, if the case is
resumed and a rate reduction is ultimately ordered by the MPSC, it would
implement the rate reduction retroactively for a period equal to the length of
the actual suspension. In January 2000, the legislation was introduced into the
Michigan Legislature. Consumers is unable to predict the outcome of this matter.
In January 1998, the Court of Appeals affirmed an MPSC conclusion that the MPSC
has statutory authority to authorize an experimental electric retail wheeling
program. In June 1999, the Michigan Supreme Court reversed the Court of Appeals
and held that the MPSC does not have the statutory authority to order a utility
to provide a mandatory retail wheeling service. For more information on the
experimental retail wheeling program see "Electric Restructuring" below.
ELECTRIC RESTRUCTURING: As part of ongoing proceedings relating to the
restructuring of the electric utility industry in Michigan, the MPSC issued
numerous orders since June 1997 proposing that Consumers transmit and distribute
energy for competing power suppliers to retail customers (also known as "retail
open access"). The restructuring orders provide for: 1) recovery of estimated
Stranded Costs of $1.755 billion through a charge to all customers purchasing
their power from other sources until the end of the transition period in 2007,
subject to an adjustment through a true-up mechanism; 2) commencement of the
phase-in of retail open access beginning September 1999; 3) suspension of the
power supply cost recovery (PSCR) clause as discussed below; and 4) the right of
all customers to choose their power suppliers on January 1, 2002. The recovery
of costs of implementing a retail open access program, preliminarily estimated
at an additional $200 million, will be reviewed for prudence by the MPSC and
recovered via a charge approved by the MPSC. Nuclear decommissioning costs will
also continue to be collected through a separate surcharge to all customers.
Consumers submitted its plan for implementing retail open access to the MPSC in
1998. The primary issues addressed in the plan are: 1) the implementation
schedule; 2) the retail open access service options available to customers and
suppliers; 3) the process and requirements for customers and others to obtain
retail open access service; and 4) the roles and responsibilities for Consumers,
customers and suppliers. In March 1999, Consumers received MPSC electric
restructuring orders, which generally supported Consumers' implementation plan.
Consumers began implementing electric retail customer open access in September
1999, and will extend open access to 750 MW of Consumers' retail market by 2001.
On January 1, 2002, all of Consumers' electric customers will have the right to
choose generation suppliers.
Numerous appeals are pending at the Court of Appeals relating to the MPSC's
restructuring orders. Because of the June 1999 Michigan Supreme Court decision
described above in "Electric Proceedings", Consumers believes that the MPSC
lacks statutory authority to mandate industry restructuring. The MPSC
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ultimately issued an order in August 1999 finding that it has jurisdiction to
approve rates, terms, and conditions for electricity retail wheeling (also known
as electric customer choice) if a utility voluntarily chooses to offer that
service. ABATE and the Attorney General have each appealed the August 1999 order
to the Court of Appeals. It is uncertain how the issues raised by the MPSC's
August 1999 order will be resolved by the regulatory process, the appellate
courts or by legislation addressing electric restructuring issues.
During periods when electric demand is high, the cost of purchasing energy on
the spot market can be substantial. Consumers is planning to maintain sufficient
generation and to purchase electricity from others to create a power reserve
(also called a reserve margin) that provides Consumers with approximately 15
percent additional power above its anticipated power demands. This allows
Consumers to provide reliable service to its electric service customers and to
protect itself against unscheduled plant outages and unanticipated demand.
Before 1998, the PSCR process provided for the recovery of any prudent and
necessary power supply costs through customer rates, thus minimizing the risk to
shareholders for fluctuations in such costs. In 1998, as a result of an MPSC
order associated with electric restructuring efforts, the PSCR process was
suspended for 4 years. Under the suspension, customers' rates previously subject
to adjustment under the PSCR process, will not be adjusted to reflect the actual
costs of fuel, interchange power and purchased power, through 2001. To reduce
the risk of high energy prices during peak demand periods, Consumers has
employed a strategy of purchasing electric option contracts for the physical
delivery of electricity during the months of June through September in order to
achieve its reserve margin target. Consumers expects to use a similar strategy
in the future. In 1999, Consumers' purchase of electric option contracts cost
approximately $19 million.
In June 1999, Consumers and four other electric utility companies sought
approval from the Federal Energy Regulatory Commission (FERC) to form the
Alliance Regional Transmission Organization (Alliance). The proposed structure
provided for the creation of a transmission entity that would control, operate
and own transmission facilities of one or more of the member companies, and
would control and operate, but not necessarily own, the transmission facilities
of other companies. The proposal was structured to give the member companies the
flexibility to maintain or divest ownership of their transmission facilities
while ensuring independent operation of the regional transmission system. In
December 1999, the FERC conditionally approved formation of Alliance, but asked
the applicants to make a number of changes in the proposal and to provide
additional information. Among other things, the FERC expressed concern about the
proposed governance of Alliance, its rates and its geographic configuration. On
the same day as the Alliance order, the FERC issued Order No. 2000, which
describes the characteristics the FERC would find acceptable in an Regional
Transmission Organization (RTO). In Order No. 2000, the FERC declined to mandate
that utilities join RTOs, but did order utilities to make filings in October
2000 and January 2001 declaring their intentions with respect to RTO membership.
Consumers and the Alliance companies have sought a rehearing on the Alliance
order. Consumers is uncertain about the outcome of the Alliance matter before
the FERC and its continued participation in Alliance.
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OTHER CONSUMERS' ELECTRIC UTILITY UNCERTAINTIES
THE MIDLAND COGENERATION VENTURE: The MCV Partnership, which leases and operates
the MCV Facility, contracted to sell electricity to Consumers for a 35-year
period beginning in 1990 and to supply electricity and steam to Dow Chemical
Company (Dow). Consumers, through two wholly owned subsidiaries, holds the
following assets related to the MCV Partnership and MCV Facility: 1) CMS Midland
Inc. (CMS Midland) owns a 49 percent general partnership interest in the MCV
Partnership; and 2) CMS Midland Holdings Company (CMS Holdings) holds, through
FMLP, a 35 percent lessor interest in the MCV Facility.
Summarized Statements of Income for CMS Midland and CMS Holdings (unaudited)
In Millions
- ------------------------------------------------------------------------------------------------------------------
Years Ended December 31 1999 1998 1997
- ------------------------------------------------------------------------------------------------------------------
Pretax operating income $49 $49 $46
Income taxes and other 15 15 14
----------------------------------------------------------------
Net income $34 $34 $32
==================================================================================================================
Power Purchases from the MCV Partnership: Consumers' annual obligation to
purchase capacity from the MCV Partnership is 1,240 MW through the termination
of the power purchase agreement (PPA) between Consumers and the MCV Partnership
in 2025. The PPA provides that Consumers is to pay, based on the MCV Facility's
availability, a levelized average capacity charge of 3.77 cents per
kilowatt-hour (kWh), a fixed energy charge, and a variable energy charge based
primarily on Consumers' average cost of coal consumed for all kWh delivered.
Since January 1, 1993, the MPSC has permitted Consumers to recover capacity
charges averaging 3.62 cents per kWh for 915 MW, plus a substantial portion of
the fixed and variable energy charges. Since January 1, 1996, the MPSC has also
permitted Consumers to recover capacity charges for the remaining 325 MW of
contract capacity with an initial average charge of 2.86 cents per kWh,
increasing periodically to an eventual 3.62 cents per kWh by 2004 and
thereafter. Because the MPSC has already approved recovery of these capacity
costs, Consumers will recover these increases through an adjustment to the
currently frozen PSCR factor that will be effective through 2001. Consumers
expects to recover the remaining increases through the Transition Cost true-up
process and through further adjustments to the PSCR factor. After September
2007, under the terms of the PPA, Consumers will only be required to pay the MCV
Partnership capacity and energy charges that the MPSC has authorized for
recovery from electric customers.
In March 1999, Consumers signed a long-term power sales agreement to resell to
PECO Energy Company (PECO) its capacity and energy purchases under the PPA until
September 2007. After a three-year transition period during which 100 to 150 MW
will be sold to PECO, beginning in 2002, Consumers will sell all 1,240 MW of PPA
capacity and associated energy to PECO. In March 1999, Consumers also filed an
application with the MPSC for accounting and ratemaking approvals related to the
PECO agreement. If used as an offset to electric customers' Transition Cost
responsibility, Consumers estimates that there could be a reduction of as much
as $58 million (on a net present value basis) of Transition Cost related to the
MCV PPA. In an order issued in April 1999, the MPSC conditionally approved the
requests for accounting and rate-making treatment to the extent that customer
rates are not increased from the current level absent the agreement and as
modified by the order. In response to Consumers' and other parties'
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requests for clarification and rehearing, in an August 1999 opinion, the MPSC
partially granted the relief Consumers requested on rehearing and attached
certain additional conditions to its approval. Those conditions relate to
Consumers' continued decision to carry out the electricity customer choice
program (which Consumers has affirmed as discussed above) and a determination to
revise its capacity solicitation process (which Consumers has filed but is
awaiting an MPSC decision). The August opinion is a companion order to a power
supply cost reconciliation order issued on the same date in another case. This
order affects the level of frozen power supply costs recoverable in rates during
future years when the transaction with PECO would be taking place. Consumers
filed a motion for clarification of the order relating to the PECO agreement,
which is still pending. Due to the pending electric industry restructuring
legislation in Michigan and the overall uncertainty that exists concerning
restructuring, Consumers and PECO have entered into an interim arrangement for
the sale of 125MW of PPA capacity associated energy to PECO during 2000. Prices
in the interim arrangement are identical to the March 1999 power sales
agreement.
Consumers recognized a loss in 1992 for the present value of the estimated
future underrecoveries of power costs under the PPA based on MPSC recovery
orders. At December 31, 1999 and December 31, 1998, the remaining after-tax
present value of the estimated future PPA liability associated with the 1992
loss totaled $78 million and $110 million, respectively. At December 31, 1999,
the undiscounted after-tax amount associated with this liability totaled $142
million. These after-tax cash underrecoveries are based on the assumption that
the MCV Facility would be available to generate electricity 91.5 percent of the
time over its expected life. Historically the MCV Facility has operated above
the 91.5 percent level. Accordingly, in 1998, Consumers increased its PPA
liability by $37 million. Because the MCV Facility operated above the 91.5
percent level in 1998 and in 1999, Consumers has an accumulated unrecovered
after-tax shortfall of $30 million as of December 31, 1999. Consumers believes
that this shortfall will be resolved in the context of the electric
restructuring effort. If the MCV Facility generates electricity at the 91.5
percent level during the next five years, Consumers' after-tax underrecoveries
associated with the PPA would be as follows.
In Millions
- ------------------------------------------------------------------------------------------------------------------
2000 2001 2002 2003 2004
- ------------------------------------------------------------------------------------------------------------------
Estimated cash underrecoveries, net of tax $21 $20 $19 $18 $17
==================================================================================================================
If the MCV Facility operates at availability levels above management's 91.5
percent estimate made in 1992 for the remainder of the PPA and expected
shortfalls are not resolved in the context of the electric restructuring effort,
Consumers will need to recognize additional losses for future underrecoveries.
In March 1999, Consumers and the MCV Partnership reached an agreement effective
January 1, 1999 that capped availability payments to the MCV Partnership at 98.5
percent. For further discussion on the impact of the frozen PSCR, see "Electric
Restructuring" in this Note. Management is evaluating the adequacy of the
contract loss liability considering actual MCV Facility operations and any other
relevant circumstances.
In February 1998, the MCV Partnership filed a claim of appeal from the January
1998 and February 1998 MPSC orders in the electric utility industry
restructuring. At the same time, the MCV Partnership filed suit in the United
States District Court seeking a declaration that the MPSC's failure to provide
Consumers and the MCV Partnership a certain source of recovery of capacity
payments after 2007 deprived the MCV Partnership of its rights under the Public
Utilities Regulatory Policies Act of 1978. In July 1999, the United States
District Court issued an order granting the MCV Partnership's motion for summary
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judgment. The order permanently prohibits enforcement of the restructuring
orders in any manner which denies any utility the ability to recover amounts
paid to qualifying facilities such as the MCV Facility or which precludes the
MCV Partnership from recovering the avoided cost rate. The MPSC has appealed the
United States District Court order. Consumers cannot predict the outcome of this
litigation.
NUCLEAR MATTERS: In January 1997, the NRC issued its Systematic Assessment of
Licensee Performance report for Palisades. The report rated all areas as good.
The NRC suspended this assessment process for all licensees in 1998. Until the
NRC completes its review of processes for assessing performance at nuclear power
plants, the NRC uses the Plant Performance Review to provide an assessment of
licensee performance. Palisades received its annual performance review dated
March 26, 1999 in which the NRC stated that the overall performance at Palisades
was acceptable.
Palisades' temporary on-site storage pool for spent nuclear fuel is at capacity.
Consequently, Consumers is using NRC-approved steel and concrete vaults,
commonly known as "dry casks", for temporary on-site storage. As of December 31,
1999, Consumers had loaded 18 dry storage casks with spent nuclear fuel at
Palisades. In June 1997, the NRC approved Consumers' process for unloading spent
fuel from a cask previously discovered to have minor weld flaws. Consumers
intends to transfer the spent fuel to a new transportable cask when one is
available.
Consumers maintains insurance against property damage, debris removal, personal
injury liability and other risks that are present at its nuclear generating
facilities. Consumers also maintains coverage for replacement power costs during
prolonged accidental outages at Palisades. Insurance would not cover such costs
during the first 12 weeks of any outage, but would cover most of such costs
during the next 52 weeks of the outage, followed by reduced coverage to 80
percent for 110 additional weeks. If certain covered losses occur at its own or
other nuclear plants similarly insured, Consumers could be required to pay
maximum assessments of $15.5 million in any one year to Nuclear Electric
Insurance Limited (NEIL); $88 million per occurrence under the nuclear liability
secondary financial protection program, limited to $10 million per occurrence in
any year; and $6 million if nuclear workers claim bodily injury from radiation
exposure. Consumers considers the possibility of these assessments to be remote.
The NRC requires Consumers to make certain calculations and report on the
continuing ability of the Palisades reactor vessel to withstand postulated
pressurized thermal shock events during its remaining license life, considering
the embrittlement of reactor materials. In December 1996, Consumers received an
interim Safety Evaluation Report from the NRC indicating that the reactor vessel
can be safely operated through 2003 before reaching the NRC's screening criteria
for reactor embrittlement. Consumers believes that with fuel management designed
to minimize embrittlement, it can operate Palisades to the end of its license
life in the year 2007 without annealing the reactor vessel. Nevertheless,
Consumers will continue to monitor the matter.
COMMITMENTS FOR COAL SUPPLIES: Consumers has entered into coal supply contracts
with various suppliers for its coal-fired generating stations. Under the terms
of these agreements, Consumers is obligated to take physical delivery of the
coal and make payment based upon the contract terms. Consumers' current
contracts have expiration dates that range from 2001 to 2004. Consumers enters
into long-term contracts for approximately 50 to 75 percent of its annual coal
requirements. In 1999, coal purchases totaled $262.5 million of which $197.2
million (75 percent of the tonnage requirement) was under long-term contract.
Consumers supplements its long-term contracts with spot-market purchases.
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CONSUMERS' GAS UTILITY CONTINGENCIES
GAS ENVIRONMENTAL MATTERS: Under the Michigan Natural Resources and
Environmental Protection Act, Consumers expects that it will ultimately incur
investigation and remedial action costs at a number of sites. These include 23
sites that formerly housed manufactured gas plant facilities, even those in
which it has a partial or no current ownership interest. Consumers has completed
initial investigations at the 23 sites. On sites where Consumers has received
site-wide study plan approvals, it will continue to implement these plans. It
will also work toward closure of environmental issues at sites as studies are
completed. Consumers has estimated its costs related to further investigation
and remedial action for all 23 sites using the Gas Research
Institute-Manufactured Gas Plant Probabilistic Cost Model. Using this model,
Consumers estimates the costs to be between $66 million and $118 million. These
estimates are based on undiscounted 1999 costs. As of December 31, 1999,
Consumers has an accrued liability of $62 million and a regulatory asset of $65
million. Any significant change in assumptions, such as remediation techniques,
nature and extent of contamination, and legal and regulatory requirements, could
affect the estimate of remedial action costs for the sites. Consumers defers and
amortizes, over a period of ten years, environmental clean-up costs above the
amount currently being recovered in rates. Rate recognition of amortization
expense cannot begin until after a prudence review in a future general gas rate
case. Consumers is allowed current recovery of $1 million annually. Consumers
has initiated lawsuits against certain insurance companies regarding coverage
for some or all of the costs that it may incur for these sites.
CONSUMERS' GAS UTILITY MATTERS
GAS RESTRUCTURING: In December 1997, the MPSC approved Consumers' application to
implement an experimental gas transportation program. The program will extend
over a three-year period, ending March 31, 2001, eventually allowing 300,000
residential, commercial and industrial retail gas sales customers to choose an
alternative gas commodity supplier in direct competition with Consumers. The
program is voluntary and participating natural gas customers are selected on a
first-come, first-served basis, up to a limit of 100,000 per year. As of
December 31, 1999, more than 176,000 customers chose alternative gas suppliers,
representing approximately 42.2 billion cubic feet (bcf) of gas load. Customers
choosing to remain as sales customers of Consumers will not see a rate change in
their natural gas rates. This three-year program: 1) freezes gas distribution
rates through March 31, 2001, establishing a gas commodity cost at a fixed rate
of $2.84 per thousand cubic feet (mcf); 2) establishes an earnings sharing
mechanism with customers if Consumers' earnings exceed certain pre-determined
levels; and 3) establishes a gas transportation code of conduct that addresses
the relationship between Consumers and marketers, including its affiliated
marketers. In December 1999, the Court of Appeals affirmed in its entirety the
December 1997 MPSC Order. Petitions for rehearing filed by several parties were
subsequently denied by the Court of Appeals.
Consumers contracts to purchase gas to limit its risk associated with gas price
increases. Management's intent is to take physical delivery of the commodity and
failure could result in a significant penalty for nonperformance. At December
31, 1999, Consumers had an exposure to gas price increases if the ultimate cost
of gas was to exceed $2.84 per mcf for the following volumes: 50 percent of its
2000 requirements; and 50 percent of its first quarter 2001 requirements.
Additional contract coverage is currently under review. The gas purchase
contracts currently in place were consummated at an average price of less than
$2.84 per mcf. Consumers uses gas purchase contracts to protect against gas
price increases in a three-year experimental gas program where Consumers is
recovering from its customers $2.84 per mcf for gas.
COMMITMENTS FOR GAS SUPPLIES: Consumers contracts to purchase gas and
transportation from various
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suppliers for its natural gas business. These contracts have
expiration dates that range from 2000 to 2004. Consumers' 1999 gas requirements
totaled 200 bcf at a cost of $542 million, 80 percent of which was under
long-term contracts for one year or more. As of the end of 1999, Consumers had
50 percent of its 2000 gas requirements under such long-term contracts, and will
supplement them with additional long-term and short-term contracts and
spot-market purchases.
PANHANDLE MATTERS
REGULATORY MATTERS: Effective August 1996, Trunkline placed into effect in Rate
Proceeding 96-129 a general rate increase, subject to refund. On September 16,
1999, Trunkline filed a FERC settlement agreement to resolve certain issues in
this proceeding. This settlement was approved on February 1, 2000 and will
require refunds of approximately $2 million expected to be made in April 2000,
with supplemental refunds expected in July 2000. On January 12, 2000, the FERC
issued an order on the remainder of the rate proceeding which, if approved
without modification, would result in a substantial reduction to Trunkline's
tariff rates which would impact future revenues and require additional refunds.
Trunkline has requested rehearing of certain matters in this order.
In conjunction with a FERC order issued in September 1997, certain natural gas
producers were required to refund previously collected Kansas ad-valorem taxes
to interstate natural gas pipelines. These pipelines were ordered to refund
these amounts to their customers. All payments are to be made in compliance with
prescribed FERC requirements. At December 31, 1999, accounts receivable included
$54 million due from natural gas producers, and other current liabilities
included $54 million for related obligations.
ENVIRONMENTAL MATTERS: Panhandle is subject to federal, state and local
regulations regarding air and water quality, hazardous and solid waste disposal
and other environmental matters. Panhandle has identified environmental
contamination at certain sites on its systems and has undertaken cleanup
programs at these sites. The contamination resulted from the past use of
lubricants in compressed air systems containing PCBs and the prior use of
wastewater collection facilities and other on-site disposal areas. Under the
terms of the sale of Panhandle to CMS Energy, a subsidiary of Duke Energy is
obligated to complete the Panhandle cleanup programs at certain agreed-upon
sites and to indemnify Panhandle against certain future environmental litigation
and claims. The Illinois EPA included Panhandle and Trunkline, together with
other non-affiliated parties, in a cleanup of former waste oil disposal sites in
Illinois. Prior to a partial cleanup by the United States EPA, a preliminary
study estimated the cleanup costs at one of the sites to be between $5 million
and $15 million. The state of Illinois contends that Panhandle's and Trunkline's
share for the costs of assessment and remediation of the sites, based on the
volume of waste sent to the facilities, is 17.32 percent. Management believes
that the costs of cleanup, if any, will not have a material adverse impact on
CMS Energy's financial position, liquidity, or results of operations.
OTHER UNCERTAINTIES
CMS GENERATION CO. (CMS GENERATION) ENVIRONMENTAL MATTERS: CMS Generation does
not currently expect to incur significant capital costs at its power facilities
for compliance with current environmental regulatory standards.
CAPITAL EXPENDITURES: CMS Energy estimates capital expenditures, including
investments in unconsolidated subsidiaries and new lease commitments, of $1.617
billion for 2000, $1.290 billion for 2001, and $1.295 billion for 2002. For
further information, see Capital Resources and Liquidity-Capital Expenditures in
the Management's Discussion and Analysis
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CMS MARKETING, SERVICES AND TRADING COMPANY (CMS MST) GAS SUPPLY CONTRACTS:
During 1999, CMS MST entered into two sales arrangements to provide natural gas
to various entities over periods of up to 12 years. These contracts obligate CMS
MST to provide 179 bcf of gas to these entities at predetermined price levels
over the period of the contracts. CMS MST has established a liability for these
outstanding obligations and hedged its exposures under these arrangements.
OTHER: As of December 31, 1999, CMS Energy and Enterprises guaranteed up to $517
million in contingent obligations of unconsolidated affiliates and related
parties.
In addition to the matters disclosed in this Note, Consumers and certain other
subsidiaries of CMS Energy are parties to certain lawsuits and administrative
proceedings before various courts and governmental agencies arising from the
ordinary course of business. These lawsuits and proceedings may involve personal
injury, property damage, contractual matters, environmental issues, federal and
state taxes, rates, licensing and other matters.
CMS Energy has accrued estimated losses for certain contingencies discussed in
this Note. Resolution of these contingencies is not expected to have a material
adverse impact on CMS Energy's financial position, liquidity, or results of
operations.
5: SHORT-TERM FINANCINGS
CMS Energy utilized $600 million of a bridge loan facility to partially fund the
acquisition of Panhandle. As of December 31, 1999, CMS Energy had repaid this
entire bridge loan facility.
At February 1, 2000, Consumers had FERC authorization to issue or guarantee
through June 2000, up to $900 million of short-term securities outstanding at
any one time. Consumers also had remaining FERC authorization to issue through
June 2000, up to $275 million and $365 million of long-term securities with
maturities up to 30 years for refinancing purposes and for general corporate
purposes, respectively.
Consumers has an unsecured $300 million credit facility and unsecured lines of
credit aggregating $135 million. These facilities are available to finance
seasonal working capital requirements and to pay for capital expenditures
between long-term financings. At December 31, 1999, a total of $214 million was
outstanding at a weighted average interest rate of 6.6 percent, compared with
$215 million outstanding at December 31, 1998, at a weighted average interest
rate of 5.8 percent. In January 1999, Consumers renegotiated a variable-to-fixed
interest rate swap totaling $175 million. In September 1999, Consumers entered
into two variable-to-fixed interest rate swaps totaling $740 million; this
amount was reduced by $70 million to $670 million by December 31, 1999 and
terminate January 31, 2000.
Consumers also has in place a $325 million trade receivables sale program. At
December 31, 1999 and 1998, receivables sold under the program totaled $325
million and $306 million, respectively. Accounts receivable and accrued revenue
in the Consolidated Balance Sheets have been reduced to reflect receivables
sold.
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6: LONG-TERM DEBT
Long-term debt consists of the following:
In Millions
- -----------------------------------------------------------------------------------------------------------------
December 31 Maturing/Expiring Interest Rate 1999 1998
- -----------------------------------------------------------------------------------------------------------------
First Mortgage Bonds 1999 to 2023 6.4% to 8.9% $ 563 $ 628
Long-Term Bank Debt 2003 5.8%(a) 175 175
Senior Notes:
CMS Energy 2000 to 2009 7.5%(a) 1,610 830
CMS Energy 2011 8.0%(b) 250 -
CMS Energy 2013 8.375%(c) 150 -
Consumers 2008 to 2028 6.5%(a) 1,074 1,075
Panhandle 2004 to 2029 6.9%(a) 1,100 -
Extendible Tenor Rate
Adjusted Securities (d) 2005 7.0%(a) 180 180
Senior Credit Facilities 2000 to 2002 7.5%(a) 444 669
General Term Notes(TM)
Series A to E 2000 to 2009 7.5%(a) 849 625
Pollution Control Revenue Bonds 2000 to 2018 5.1%(a) 131 131
Revolving Line of Credit 2002 7.1%(a) 175 168
Nuclear Fuel Disposal (e) 4.7%(a) 123 117
Bank Loans and Other 2000 to 2014 7.2%(a) 709 410
----------------------
Principal Amount Outstanding 7,533 5,008
Current Amounts (516) (258)
Net Unamortized Discount (30) (24)
------------------------
Total Long-Term Debt $6,987 $4,726
=================================================================================================================
(a) Represents the weighted average interest rate at December 31, 1999.
(b) The interest rate may be reset in July 2001. For detailed information, see
discussion below.
(c) The interest rate may be reset in July 2003. For detailed information, see
discussion below.
(d) May be extended for an additional seven years.
(e) Maturity date uncertain (see Note 4).
The scheduled maturities of long-term debt and improvement fund obligations are
as follows: $516 million in 2000, $88 million in 2001, $988 million in 2002,
$599 million in 2003 and $1.1 billion in 2004.
CMS ENERGY
CMS Energy's $725 million senior credit facilities consist of a $600 million
three-year revolving credit facility and a five-year $125 million term loan
facility (Senior Credit Facilities). Additionally, CMS Energy has unsecured
lines of credit and letters of credit in an aggregate amount of $357 million. At
December 31, 1999, the total amount utilized under the Senior Credit Facilities
was $484 million, including
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$41 million of contingent obligations, and under the unsecured lines of credit
and letters of credit was $139 million.
In January 1999, CMS Energy received net proceeds of approximately $473 million
from the sale of $480 million of senior notes. In February 1999, CMS Energy
received net proceeds of approximately $296 million from the sale of $300
million of senior notes. Proceeds from these offerings were used to repay debt
and for general corporate purposes.
In June 1999, CMS Energy sold $250 million of 8 percent senior notes, due July
1, 2011 and $150 million of 8.375 percent senior notes, due July 1, 2013. The
$250 million senior notes and the $150 million senior notes are subject to a
call option and mandatory put on July 1, 2001 and July 1, 2003, respectively.
The call option allows the callholder to purchase the notes, at which point the
coupon rate will be reset for the remaining term of the notes. If the call
option is not exercised by the callholder, the notes will be mandatorily put to
CMS Energy at a price equal to 100 percent of the principal amount. Net proceeds
of approximately $404 million, which includes approximately $9 million for the
sale of the call options, were also used to pay down the remaining portion of
the bridge loan obtained for the acquisition of Panhandle.
CONSUMERS
Consumers issued long-term bank debt of $15 million in February 1999, maturing
in February 2002, at an initial interest rate of 5.3 percent.
In May 1999, Michigan Gas Storage Company (Michigan Gas Storage) repaid its $20
million outstanding term loan with Toronto Dominion Bank.
Consumers secures its First Mortgage Bonds by a mortgage and lien on
substantially all of its property. Consumers' ability to issue and sell
securities is restricted by certain provisions in its First Mortgage Bond
Indenture, its Articles of Incorporation (Articles) and the need for regulatory
approvals to meet appropriate federal law.
In November 1999, $64 million of Consumers' First Mortgage Bonds matured and
were retired.
Consumers has a total of $131 million of long-term pollution control revenue
bonds outstanding, secured by first mortgage bonds and insurance policies. These
bonds had a weighted average interest rate of 5.1 percent at December 31, 1999.
PANHANDLE
In March 1999, CMS Energy, through its subsidiary CMS Panhandle Holding Company
(CMS Panhandle Holding), received net proceeds of approximately $789 million
from the sale of $800 million of senior notes issued by CMS Panhandle Holding.
Proceeds from this offering were used to initially fund the acquisition of
Panhandle. On June 15, 1999 CMS Panhandle Holding merged into Panhandle, at
which point the notes became direct obligations of Panhandle. In September 1999,
Panhandle exchanged the $800 million of notes originally issued by CMS Panhandle
Holding with substantially identical Security and Exchange Commission
(SEC)-registered notes.
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CMS OIL AND GAS
In May 1999, CMS Oil and Gas renegotiated a three-year $225 million floating
rate revolving credit facility which matures in May 2002. At December 31, 1999,
the amount utilized under the credit facility was $175 million.
7: CAPITALIZATION
CMS ENERGY
The authorized capital stock of CMS Energy consists of 250 million shares of CMS
Energy Common Stock, one of two classes of common stock of CMS Energy, par value
$.01 per share (CMS Energy Common Stock), 60 million shares of Class G Common
Stock, one of two classes of common stock of CMS Energy, no par value (Class G
Common Stock) and 10 million shares of CMS Energy Preferred Stock, $.01 par
value.
In June 1999, a Delaware statutory business trust established by CMS Energy
privately sold $250 million of Trust Preferred Securities to an entity organized
by Banc of America Securities LLC. The Trust Preferred Securities pay quarterly
distributions at a floating rate. Under the terms of the Trust Preferred
Securities, if the price of the CMS Energy Common Stock is less than $29 per
share, the holders may request that the Trust Preferred Securities be remarketed
to third parties. In such case, the interest rate and certain other terms of the
subordinated notes could be reset. Net proceeds of approximately $244 million
were used to pay down a portion of the bridge loan obtained for the acquisition
of Panhandle. In exchange for these proceeds, CMS Energy sold subordinated notes
to the trust. In connection with this financing, CMS Energy also agreed to sell
$250 million of CMS Energy Common Stock at prevailing market prices through Banc
of America Securities LLC within 24 months.
In July 1999, 7.25 million units of 8.75 percent Adjustable Convertible Trust
Securities were sold by CMS Energy and CMS Energy Trust II, a Delaware statutory
business trust established by CMS Energy. Each security consists of a Trust
Preferred Security of CMS Energy Trust II maturing in five years and a contract
for the purchase of CMS Energy Common Stock in three years at a conversion
premium up to 28 percent or an effective price of $53 per common share. Net
proceeds from the sale totaled $291 million and were used to repay portions of
various lines of credit and the revolving credit facility.
In November 1999, CMS Energy privately placed 125,000 shares of its Mandatorily
Convertible Preferred Stock with CMS Share Trust, a Delaware statutory business
trust established by CMS Energy, in connection with a $125 million secured debt
issuance by an unconsolidated subsidiary. The Mandatorily Convertible Preferred
Stock has a liquidation preference of $1,000 per share and does not pay
dividends while held by the CMS Share Trust. Under certain circumstances
involving the unconsolidated subsidiary's and CMS Energy's inability to pay
principal and/or interest on the subsidiary's debt, the Mandatorily Convertible
Preferred Stock may be remarketed to third parties with the proceeds applied to
payment of the subsidiary's debt. At the time of remarketing, if any, a
market-based dividend rate and the terms of the conversion into CMS Energy
Common Stock would be established.
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During the second or third quarter of 2000, subject to market conditions, CMS
Energy intends to make an initial public offering of approximately $600 million
of a tracking stock representing 20 percent of the economic interest in its
electric and gas utility. The proceeds of the offering will be used mostly to
reduce debt, with the remaining proceeds to be used for repurchase of up to 10
million shares of CMS Energy Common Stock from time to time, in open market or
private transactions.
OTHER: Under its most restrictive borrowing arrangement at December 31, 1999,
none of CMS Energy's consolidated net income was restricted for payment of
common dividends. CMS Energy could pay $1 billion in common dividends under its
most restrictive debt covenant.
CONSUMERS
On April 1, 1999, Consumers redeemed all 8 million outstanding shares of its
$2.08 preferred stock at $25.00 per share for a total of $200 million.
In October 1999, 7 million shares of 9.25 percent Trust Preferred Securities
were issued and sold through Consumers Energy Company Financing III, a wholly
owned business trust consolidated with Consumers. Net proceeds from the sale
totaled approximately $169 million. Consumers formed the trust for the sole
purpose of issuing the Trust Preferred Securities. Consumers' obligations with
respect to the Trust Preferred Securities under the related tax-deductible
notes, under the indenture through which Consumers issued the notes, under
Consumers' guarantee of the Trust Preferred Securities, and under the
declaration by the trust, taken together, constitute a full and unconditional
guarantee by Consumers of the trust's obligations under the Trust Preferred
Securities.
Under the provisions of its Articles of Incorporation, Consumers had $359
million of unrestricted retained earnings available to pay common dividends at
December 31, 1999. In January 2000, Consumers declared and paid a $79 million
common dividend.
8: EARNINGS PER SHARE AND DIVIDENDS
On October 25, 1999, CMS Energy exchanged approximately 6.1 million shares of
CMS Energy Common Stock for all of the approximately 8.7 million issued and
outstanding shares of Class G Common Stock in a tax-free exchange for United
States federal income tax purposes. The exchange ratio of .7041 share of CMS
Energy Common Stock for each share of Class G Common Stock represents the fair
market value of CMS Energy Common Stock equal to 115 percent of the fair market
value of one share of Class G Common Stock. Fair market values of CMS Energy
Common Stock and Class G Common Stock were determined by calculating the average
of the daily closing prices on the New York Stock Exchange from July 28, 1999 to
August 24, 1999. The resulting 15 percent exchange premium of $28 million
resulted in a reallocation of earnings per share between CMS Energy Common Stock
and Class G Common Stock. For the year ended December 31, 1999, CMS Energy's
basic and diluted earnings per share were reduced $.26 and $.25, respectively,
and Class G's basic and diluted earnings per share were increased $3.31, as
shown separately in the calculation of earnings per share in the Consolidated
Statements of Income.
Earnings per share attributable to all classes of Common Stock of CMS Energy and
each of its subsidiaries (Common Stock) from January 1, 1999 to October 25, 1999
and for the years ended December 31, 1998
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and 1997 reflect the performance of the gas distribution, storage and
transportation business currently conducted by Consumers and Michigan Gas
Storage (Consumers Gas Group). The allocation of earnings attributable to each
class of Common Stock and the related amounts per share are computed by
considering the weighted average number of shares outstanding.
Earnings attributable to the outstanding shares of Class G Common Stock
(Outstanding Shares) are equal to Consumers Gas Group net income multiplied by a
fraction; the numerator is the weighted average number of Outstanding Shares
during the period and the denominator is the weighted average number of
Outstanding Shares and authorized but unissued shares of Class G Common Stock
not held by holders of the Outstanding Shares during the period.
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COMPUTATION OF EARNINGS PER SHARE (EPS):
In Millions, Except Per Share Amounts
- -----------------------------------------------------------------------------------------------------------------
1999 1998 1997
---------------------------------------------------------
(a)
NET INCOME APPLICABLE TO BASIC AND DILUTED EPS
Consolidated Net Income $277 $285 $ 244
=========================================================
Net Income Attributable to Common Stocks:
CMS Energy - Basic $241(b) $272 $ 229
Add conversion of 7.75% Trust
Preferred Securities (net of tax) 9 9 5
---------------------------------------------------------
CMS Energy - Diluted $250(b) $281 $ 234
=========================================================
Class G:
Basic and Diluted $36(b)(c) $ 13 $ 15
==========================================================
AVERAGE COMMON SHARES OUTSTANDING
APPLICABLE TO BASIC AND DILUTED EPS
CMS Energy:
Average Shares - Basic 110.1 102.4 96.1
Add conversion of 7.75% Trust
Preferred Securities 4.3 4.3 2.3
Options-Treasury Shares 0.3 0.5 0.3
---------------------------------------------------------
Average Shares - Diluted 114.7 107.2 98.7
=========================================================
Class G:
Average Shares
Basic and Diluted 8.6(c) 8.3 8.0
=========================================================
EARNINGS PER AVERAGE COMMON SHARE
CMS Energy:
Basic $2.18(b) $2.65 $ 2.39
Diluted $2.17(b) $2.62 $ 2.37
Class G:
Basic and Diluted $4.21(b)(c) $1.56 $ 1.84
=================================================================================================================
(a) Includes the cumulative effect of an accounting change in the first quarter
of 1998 which increased net income attributable to CMS Energy Common Stock
$43 million ($.40 per share - basic and diluted) and Class G Common Stock
$12 million ($.36 per share - basic and diluted).
(b) Reflects the reallocation of net income and earnings per share as a result
of the premium on exchange of Class G Common Stock. As a result, CMS
Energy's basic and diluted earnings per share were reduced $.26 and $.25,
respectively, and Class G's basic and diluted earnings per share were
increased $3.31.
(c) From January 1, 1999 to October 25, 1999.
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In February and May 1999, CMS Energy paid dividends of $.33 per share on CMS
Energy Common Stock and $.325 per share on Class G Common Stock. In August 1999,
CMS Energy paid dividends of $.365 per share on CMS Energy Common Stock and $.34
per share on Class G Common Stock. In November 1999, CMS Energy paid dividends
of $.365 per share on CMS Energy Common Stock. As a result of the exchange of
Class G Common Stock for CMS Energy Common Stock, no Class G Common Stock
dividend was declared in September. Class G Common Stock shareholders prior to
the exchange received the CMS Energy Common Stock dividend. In January 2000, the
Board of Directors of CMS Energy (Board of Directors) declared a quarterly
dividend of $.365 per share on CMS Energy Common Stock, which was paid in
February 2000.
CMS Energy will reduce the CMS Energy Common Stock annual dividend to $.40 per
share at the time of a proposed initial public offering of approximately $600
million of a tracking stock representing 20 percent of the financial interest in
CMS Energy's electric and gas utility. The offering is currently expected for
issuance during the second or third quarter of 2000, subject to market
conditions.
9: RISK MANAGEMENT ACTIVITIES AND DERIVATIVES TRANSACTIONS
CMS Energy and its subsidiaries use a variety of derivative instruments
(derivatives), including futures contracts, swaps, options and forward
contracts, to manage exposure to fluctuations in commodity prices, interest
rates and foreign exchange rates. To qualify for hedge accounting, derivatives
must meet the following criteria: i) the item to be hedged exposes the
enterprise to price, interest or exchange rate risk; and ii) the derivative
reduces that exposure and is designated as a hedge.
Derivative instruments contain credit risk if the counterparties, including
financial institutions and energy marketers, fail to perform under the
agreements. CMS Energy minimizes such risk by performing financial credit
reviews using, among other things, publicly available credit ratings of such
counterparties. Nonperformance by counterparties is not expected to have a
material adverse impact on CMS Energy's financial position, liquidity, or
results of operations.
COMMODITY PRICE HEDGES: CMS Energy engages in both energy trading and
non-trading activities as defined by EITF 98-10, Accounting for Energy Trading
and Risk Management Activities. CMS Energy accounts for its non-trading
commodity price derivatives as hedges and, as such, defers any changes in market
value and gains and losses resulting from settlements until the hedged
transaction is complete. If there was a loss of correlation between the changes
in the market value of the commodity price contracts and the market price
ultimately received for the hedged item, and the impact was material, the open
commodity price contracts would be marked-to-market and gains and losses would
be recognized in the income statement currently. Effective January 1, 1999, CMS
Energy adopted mark-to-market accounting for energy trading contracts in
accordance with EITF 98-10. Mark-to-market accounting requires gains and losses
resulting from changes in market prices on contracts entered into for trading
purposes to be reflected in earnings currently. The after-tax mark-to-market
adjustment resulting from the adoption of EITF 98-10 did not have a material
effect on CMS Energy's financial position, results of operations and cash flows
as of December 31, 1999.
Consumers enters into electric option contracts to ensure a reliable source of
capacity to meet its customers'
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electricity requirements and to limit its risk associated with electricity price
increases. It is management's intent to take physical delivery of the commodity.
Consumers continuously evaluates its daily capacity needs and sells the option
contracts, if marketable, when it has excess daily capacity. Consumers' maximum
exposure associated with these options is limited to premiums paid.
CMS Oil and Gas has one arrangement which is used to fix the prices that CMS Oil
and Gas will pay for gas supplied to the MCV Facility for the years 2001 through
2006 by purchasing the economic equivalent of 10,000 million British thermal
units (MMBtu) per day at a fixed price, escalating at 8 percent per year
thereafter, starting at $2.82 per MMBtu in 2001. The settlement periods are each
a one-year period ending December 31, 2001 through 2006 on 3.65 million MMBtu.
If the floating price, essentially the then-current Gulf Coast spot price, for a
period is higher than the fixed price, the seller pays CMS Oil and Gas the
difference, and vice versa.
The contract with the seller provides a calculation of exposure for the purpose
of requiring an exposed party to post a standby letter of credit. Under this
calculation, if a party's exposure at any time exceeds $5 million, that party is
required to obtain a letter of credit in favor of the other party for the excess
over $5 million and up to $10 million. At December 31, 1999, the terms of this
contract reflected no letter of credit by either party. As of December 31, 1999,
the fair value of this contract is $19 million, representing the amount CMS Oil
and Gas would be required to pay to the counterparty at settlement if settled at
this date.
A subsidiary of CMS Gas Transmission uses natural gas futures contracts and CMS
Marketing, Services and Trading Company uses natural gas and oil futures
contracts, options and swaps (which require a net cash payment for the
difference between a fixed and variable price).
INTEREST RATE HEDGES: CMS Energy and some of its subsidiaries enter into
interest rate swap agreements to exchange variable rate interest payment
obligations to fixed rate obligations without exchanging the underlying notional
amounts. These agreements convert variable rate debt to fixed rate debt to
reduce the impact of interest rate fluctuations. The notional amounts parallel
the underlying debt levels and are used to measure interest to be paid or
received and do not represent the exposure to credit loss. The notional amount
of CMS Energy's and its subsidiaries' interest rate swaps was $2.9 billion at
December 31, 1999. The difference between the amounts paid and received under
the swaps is accrued and recorded as an adjustment to interest expense over the
life of the hedged agreement.
FOREIGN EXCHANGE HEDGES: CMS Energy uses forward exchange and option contracts
to hedge certain receivables, payables, long-term debt and equity value relating
to foreign investments. The purpose of CMS Energy's foreign currency hedging
activities is to protect the company from the risk that U.S. dollar net cash
flows resulting from sales to foreign customers and purchases from foreign
suppliers and the repayment of non-U.S. dollar borrowings as well as equity
reported on the company's balance sheet, may be adversely affected by changes in
exchange rates. These contracts do not subject CMS Energy to risk from exchange
rate movements because gains and losses on such contracts offset losses and
gains, respectively, on assets and liabilities being hedged. The notional amount
of the outstanding foreign exchange contracts was $1.6 billion at December 31,
1999, which includes $207 million, $435 million and $880 million for Australian,
Brazilian and Argentine foreign exchange contracts, respectively. The estimated
fair value of the foreign exchange and option contracts at December 31, 1999 was
$64 million, representing the amount CMS Energy would pay upon settlement.
CMS-51
101
10: INCOME TAXES
CMS Energy and its subsidiaries file a consolidated federal income tax return.
Income taxes are generally allocated based on each company's separate taxable
income. CMS Energy and Consumers practice full deferred tax accounting for
temporary differences, but federal income taxes have not been recorded on the
undistributed earnings of international subsidiaries where CMS Energy intends to
permanently reinvest those earnings. Upon distribution, those earnings may be
subject to both U.S. income taxes (adjusted for foreign tax credits or
deductions) and withholding taxes payable to various foreign countries. It is
not practical to estimate the amount of unrecognized deferred income taxes or
withholding taxes on undistributed earnings.
CMS Energy used investment tax credit (ITC) to reduce current income taxes
payable, and amortizes ITC over the life of the related property. Any
alternative minimum tax (AMT) paid generally becomes a tax credit that CMS
Energy can carry-forward indefinitely to reduce regular tax liabilities in
future periods when regular taxes paid exceed the tax calculated for AMT. The
significant components of income tax expense (benefit) consisted of:
In Millions
- -----------------------------------------------------------------------------------------------
Years Ended December 31 1999 1998 1997
- -----------------------------------------------------------------------------------------------
Current income taxes
Federal and other $ 40 $ 61 $ 76
State and local 2 5 3
Foreign 12 3 5
------- -------------------------------------
54 69 84
Deferred income taxes
Federal 21 77(a) 41
State 4 - -
Foreign (6) (7) (7)
--------- -------------------------------------
19 70 34
Deferred ITC, net (9) (16) (10)
--------- -------------------------------------
$ 64 $123 $108
===============================================================================================
(a) Includes $23 million for 1998 change in property tax accounting.
CMS-52
102
The principal components of CMS Energy's deferred tax assets (liabilities)
recognized in the balance sheet are as follows:
In Millions
- -----------------------------------------------------------------------------------------------------
December 31 1999 1998
- -----------------------------------------------------------------------------------------------------
Property $ (606) $ (564)
Unconsolidated investments (208) (288)
Postretirement benefits (128) (139)
Abandoned Midland project (17) (25)
Employee benefit obligations (includes postretirement benefits
of $140 and $141 174 182
AMT carryforward 112 134
Power purchases 42 59
Other (34) 4
------------------------
$ (665) $ (637)
Valuation allowances (5) (15)
------------------------
$ (670) $ (652)
=====================================================================================================
Gross deferred tax liabilities $(1,512) $(1,789)
Gross deferred tax assets 842 1,137
------------------------
$ (670) $ (652)
=====================================================================================================
CMS-53
103
The actual income tax expense differs from the amount computed by applying the
statutory federal tax rate of 35% to income before income taxes as follows:
In Millions
- ------------------------------------------------------------------------------------------------------------------
Years Ended December 31 1999 1998 1997
- ------------------------------------------------------------------------------------------------------------------
Consolidated net income before
preferred dividends
Domestic $ 187 $247 $222
Foreign 96 57 47
------------------------------------------------
283 304 269
Income tax expense 64 123(a) 108
------------------------------------------------
347 427 377
Statutory federal income tax rate x 35% x 35% x 35%
-------------------------------------------------
Expected income tax expense 121 149 132
Increase (decrease) in taxes from:
Capitalized overheads previously flowed through 5 5 5
Differences in book and tax depreciation
not previously deferred 19 14 14
Impact of foreign taxes, tax rates and credits 15 (5) 1
Undistributed earnings of international subsidiaries (45) (13) (10)
ITC amortization/adjustments (8) (16) (10)
Section 29 Fuel Tax Credits (12) (13) (13)
Valuation allowances, net (10)(b) - -
Reversal of income tax accruals (8) - -
Other, net (13) 2 (11)
----------------------------------------------------------
$ 64 $123 $ 108
=================================================================================================================
Effective tax rate 18.4% 28.8% 28.6%
=================================================================================================================
(a) Includes $23 million for 1998 change in property tax accounting.
(b) Benefit realization of preacquisition carryforwards.
11: FINANCIAL INSTRUMENTS
The carrying amounts of cash, short-term investments and current liabilities
approximate their fair values due to their short-term nature. The estimated fair
values of long-term investments are based on quoted market prices or, in the
absence of specific market prices, on quoted market prices of similar
investments or other valuation techniques. Judgement may also be required to
interpret market data to develop certain estimates of fair value. Accordingly,
the estimates determined as of December 31, 1999 and 1998 are not necessarily
indicative of the amounts which may be realized in current market exchanges.
CMS-54
104
The carrying amounts of all long-term investments in financial instruments,
except as shown below, approximate fair value.
Years Ended December 31 1999 1998 In Millions
- --------------------------------------------------------------------------------------------------------------------
Gross Gross
Carrying Fair Unrealized Carrying Fair Unrealized
Cost Value Gain (Loss) Cost Value Gain (Loss)
- -------------------------------------------------------------------------------------------------------------------
Long-Term Debt (a) $6,987 $6,722 $ (265) $4,726 $4,762 $ 36
Interest Rate Swaps (b) - 6 6 - 15 15
Preferred Stock and
Trust Preferred Securities 1,163 1,042 (121) 631 631 -
Available-for-Sale
Securities
- -------------------------------------------------------------------------------------------------------------------
Investments $ - $ - $ - $82 $67 $(15)
Nuclear Decommissioning 448 602 154 425 557 132
SERP 56 60 4 40 53 13
- -------------------------------------------------------------------------------------------------------------------
a) Settlement of long-term-debt is generally not expected until maturity.
b) Amounts shown represent estimated amounts CMS Energy would receive if
agreements were settled at current market rates.
Years Ended December 31 1999 1998
- -------------------------------------------------------------------------------------------------------------------
Gross Gross
Fair Unrealized Fair Unrealized
Trading Securities Value Gain (Loss) Value Gain (Loss)
- -------------------------------------------------------------------------------------------------------------------
Investments $91 $17 $ 6 $ 3
In 1999, CMS Energy transferred $85 million of investment from the
available-for-sale category into the trading category, and correspondingly,
reflected $14 million of unrealized gains in consolidated net income for the
year ended December 31, 1999.
CMS-55
105
12: EXECUTIVE INCENTIVE COMPENSATION
Under CMS Energy's Performance Incentive Stock Plan, restricted shares of Common
Stock as well as stock options and stock appreciation rights relating to Common
Stock may be granted to key employees based on their contributions to the
successful management of CMS Energy and its subsidiaries. Awards under the plan
may consist of any class of Common Stock. Certain plan awards are subject to
performance-based business criteria. The plan reserves for award not more than
five percent, as amended January 1, 1999, of Common Stock outstanding on January
1 each year, less (i) the number of shares of restricted Common Stock awarded
and (ii) Common Stock subject to options granted under the plan during the
immediately preceding four calendar years. The number of shares of restricted
Common Stock awarded under this plan cannot exceed 20% of the aggregate number
of shares reserved for award. Any forfeitures of shares previously awarded will
increase the number of shares available to be awarded under the plan. At
December 31, 1999, awards of up to 2,466,524 shares of CMS Energy Common Stock
may be issued.
Restricted shares of Common Stock are outstanding shares with full voting and
dividend rights. These awards vest over five years at the rate of 25 percent per
year after two years. The restricted shares are subject to achievement of
specified levels of total shareholder return and are subject to forfeiture if
employment terminates before vesting. If performance objectives are exceeded,
the plan provides additional awards. Restricted shares vest fully if control of
CMS Energy changes, as defined by the plan. At December 31, 1999, 679,232 of the
884,129 shares of restricted CMS Energy Common Stock outstanding are subject to
performance objectives.
Under the plan, stock options and stock appreciation rights relating to Common
Stock are granted with an exercise price equal to the closing market price on
each grant date. Some options may be exercised upon grant; others vest over five
years at the rate of 25 percent per year after one year. All options expire up
to ten years and one month from date of grant. In 1999, all outstanding Class G
Common Stock and options were converted to CMS Energy Common Stock and options
at an exchange rate of .7041 per Class G Common Stock or option held. The
original vesting or exercise period was retained for all converted shares or
options. The status of the restricted stock granted to CMS Energy's key
employees under the Performance Incentive Stock Plan and options granted under
the plan follows.
CMS-56
106
Restricted
Stock Options
---------- ----------------------------------
Number Number Weighted-Average
of Shares of Shares Exercise Price
- ----------------------------------------------------------------------------------------------------------------
CMS Energy Common Stock:
Outstanding at January 1, 1997 600,838 1,716,626 $ 26.24
Granted 366,360 431,500 $ 35.91
Exercised or Issued (159,405) (479,422) $ 26.54
Forfeited (59,582) - -
Expired - (2,987) $ 30.13
------------------------------------------------------------
Outstanding at December 31, 1997 748,211 1,665,717 $ 28.65
Granted 304,750 376,000 $ 43.38
Exercised or Issued (185,217) (331,925) $ 27.69
Forfeited (6,000) - -
-----------------------------------------------------------
Outstanding at December 31, 1998 861,744 1,709,792 $ 32.07
Granted 284,364 1,137,912 $ 39.23
Converted from Class G 6,060 19,503 $ 32.62
Exercised or Issued (172,916) (258,267) $ 29.44
Forfeited (95,123) - -
Expired - (78,900) $ 39.58
-----------------------------------------------------------
Outstanding at December 31, 1999 884,129 2,530,040 $ 35.33
================================================================================================================
- ----------------------------------------------------------------------------------------------------------------
Class G Common Stock:
Outstanding at January 1, 1997 16,347 21,000 $ 17.88
Granted 8,784 12,000 $ 20.24
Exercised or Issued (1,385) (5,000) $ 17.88
Forfeited (3,955) - -
-------------------------------------------------------
Outstanding at December 31, 1997 19,791 28,000 $ 18.89
Granted 14,720 45,900 $ 24.50
Exercised or Issued (4,021) - -
-------------------------------------------------------
Outstanding at December 31, 1998 30,490 73,900 $ 22.37
Granted 3,427 - -
Exercised or Issued (7,360) (19,000) $ 18.45
Forfeited (17,949) - -
Expired - (27,200) $ 24.50
Converted to CMS Energy (8,608) (27,700) $ 22.98
-------------------------------------------------------
Outstanding at December 31, 1999 - - -
================================================================================================================
CMS-57
107
The following table summarizes information about stock options outstanding at
December 31, 1999:
Number Weighted- Weighted-
Range of of Shares Average Average
Exercise Prices Outstanding Remaining Life Exercise Price
- --------------------------------------------------------------------------------------------------------------
CMS Energy Common Stock:
$17.13 - $35.94 1,151,128 5.61 years $29.11
$37.19 - $41.44 1,020,412 9.55 years $39.53
$41.75 - $44.06 358,500 8.66 years $43.34
- --------------------------------------------------------------------------------------------------------------
$17.13 - $44.06 2,530,040 7.63 years $35.33
==============================================================================================================
The weighted average fair value of options granted for CMS Energy Common Stock
was $5.93 in 1999, $6.43 in 1998 and $6.38 in 1997. Fair value is estimated
using the Black-Scholes model, a mathematical formula used to value options
traded on securities exchanges, with the following assumptions:
Years Ended December 31 1999 1998 1997
- -------------------------------------------------------------------------------------------------------------------
CMS ENERGY COMMON STOCK OPTIONS
Risk-free interest rate 5.65% 5.45% 6.06%
Expected stock-price volatility 16.81% 15.93% 17.43%
Expected dividend rate $.365 $ .33 $ .30
Expected option life (years) 4.5 years 4 years 5 years
===================================================================================================================
CMS Energy applies Accounting Principles Board Opinion 25 and related
interpretations in accounting for the Performance Incentive Stock Plan. Since
stock options are granted at market price, no compensation cost has been
recognized for stock options granted under the plan. The compensation cost
charged against income for restricted stock was $12 million in 1999, $9 million
in 1998 and $6 million in 1997. If compensation cost for stock options had been
determined in accordance with SFAS 123, Accounting for Stock-Based Compensation,
CMS Energy's consolidated net income and earnings per share would have been as
follows:
CMS-58
108
In Millions, Except Per Share Amounts
- ---------------------------------------------------------------------------------------------------------------
Pro Forma As Reported
Years Ended December 31 1999 1998 1999 1998
- ---------------------------------------------------------------------------------------------------------------
Consolidated Net Income $ 272 $ 283 $ 277 $ 285
Net Income Attributable to Common Stocks
CMS Energy 236 270 241 272
Class G 36 13 36 13
Earnings Per Average Common Share
CMS Energy
Basic 2.14 2.64 2.18 2.65
Diluted 2.14 2.61 2.17 2.62
Class G
Basic and Diluted 4.21 1.54 4.21 1.56
===============================================================================================================
13: RETIREMENT BENEFITS
CMS Energy and its subsidiaries provide retirement benefits under a number of
different plans, including certain health care and life insurance benefits under
its postretirement benefit plans other than pensions for retired employees
(OPEB), benefits to certain management employees under its Supplemental
Executive Retirement Plan (SERP), and benefits to substantially all its
employees under a trusteed, non-contributory, defined benefit pension plan of
Consumers and CMS Energy (Pension Plan), and a defined contribution 401(k) plan.
Amounts presented below for the Pension Plan include amounts for employees of
CMS Energy and nonutility affiliates which were not distinguishable from the
plan's total assets.
Weighted-Average Assumptions:
Pension & SERP OPEB
-------------------------------- --------------------------------
Years Ended December 31 1999 1998 1997 1999 1998 1997
- --------------------------------------------------------------------------------------------------------------
Discount rate 7.75% 7.00% 7.50% 7.75% 7.00% 7.50%
Expected long-term rate
of return on plan assets 9.25% 9.25% 9.25% 7.00% 7.00% 7.00%
Rate of compensation increase:
Pension - to age 45 5.25% 5.25% 5.25%
- age 45 to assumed retirement 3.75% 3.75% 3.75%
SERP 5.50% 5.50% 5.50%
==============================================================================================================
Retiree health care costs at December 31, 1999 are based on the assumption that
costs would increase 7.0 percent in 2000, then decrease gradually to 5.5 percent
in 2006 and thereafter.
CMS-59
109
Net Pension Plan, SERP and OPEB costs consist of:
In Millions
- ------------------------------------------------------------------------------------------------------------------
Pension & SERP OPEB
-------------------------------------------------------
Years Ended December 31 1999 1998 1997 1999 1998 1997
- ------------------------------------------------------------------------------------------------------------------
Service cost $ 34 $ 27 $ 26 $ 15 $ 11 $ 10
Interest expense 71 64 61 47 43 41
Expected return on plan assets (84) (73) (70) (25) (18) (13)
Amortization of unrecognized transition (asset) (5) (5) (5) - - -
Amortization of prior service cost 4 4 4 - - -
Ad Hoc Retiree Increase 3 - - - - -
-------------------------------------------------------
Net periodic pension and
postretirement benefit cost $ 23 $ 17 $ 16 $ 37 $ 36 $ 38
==================================================================================================================
The health care cost trend rate assumption significantly affects the amounts
reported. A one percentage point change in the assumed health care cost trend
assumption would have the following effects:
In Millions
- ----------------------------------------------------------------------------------------------------------------
One Percentage One Percentage
Point Increase Point Decrease
- ----------------------------------------------------------------------------------------------------------------
Effect on total service and interest cost components $ 11 $ (9)
Effect on postretirement benefit obligation $ 109 $ (91)
================================================================================================================
CMS-60
110
The funded status of CMS Energy's Pension Plan, SERP and OPEB plans is
reconciled with the liability recorded at December 31 as follows:
In Millions
- ------------------------------------------------------------------------------------------------------------------
Pension Plan SERP OPEB
1999 1998 1999 1998 1999 1998
- ------------------------------------------------------------------------------------------------------------------
Benefit obligation, January 1 $ 874 $792 $50 $ 41 $ 655 $582
Service cost 31 25 3 2 15 11
Interest cost 68 60 4 3 47 43
Plan amendments 4 - - - - -
Business Combinations 70 - 3 - 29 -
Actuarial loss (gain) 3 76 (6) 5 21 47
Benefits paid (79) (79) (1) (1) (31) (28)
-----------------------------------------------------------
Benefit obligation, December 971 874 53 50 736 655
-----------------------------------------------------------
Plan assets at fair value, January 1 970 882 - - 327 224
Actual return on plan assets 120 167 - - 50 54
Company contribution - - 1 1 55 49
Business Combinations 83 - - - - -
Actual benefits paid (79) (79) (1) (1) - -
-----------------------------------------------------------
Plan assets at fair
value, December 31 1,094(a) 970(a) - - 432 327
-----------------------------------------------------------
Benefit obligation less than
(in excess of) plan assets 123 96 (52) (50) (305) (328)
Unrecognized net (gain) loss from
experience different than assumed (212) (176) 4 10 (68) (72)
Unrecognized prior service cost 28 31 1 1 - -
Unrecognized net transition (asset) obligation (11) (16) - - - -
-----------------------------------------------------------
Recorded liability $ (72) $(65) $(47) $(39) $(373) $(400)
==================================================================================================================
(a) Primarily stocks and bonds, including $108 million in 1999 and $168 million
in 1998 of CMS Energy Common Stock.
SERP benefits are paid from a trust established in 1988. SERP is not a qualified
plan under the Internal Revenue Code, and as such, earnings of the trust are
taxable and trust assets are included in consolidated assets. At December 31,
1999 and 1998, trust assets were $60 million and $53 million, respectively, and
were classified as other noncurrent assets. The accumulated benefit obligation
for SERP was $33 million in 1999 and $31 million in 1998.
Contributions to the 40l(k) plan are invested in CMS Energy Common Stock.
Amounts charged to expense for this plan were $20 million in 1999, $18 million
in 1998 and $20 million in 1997.
Beginning January 1, 1986, the amortization period for the Pension Plan's
unrecognized net transition asset is 16 years and 11 years for the SERP's
unrecognized net transition obligation. Prior service costs are amortized on a
straight-line basis over the average remaining service period of active
employees.
CMS-61
111
CMS Energy and its subsidiaries adopted SFAS 106, Employers' Accounting for
Postretirement Benefits Other Than Pensions, effective as of the beginning of
1992 and Consumers recorded a liability of $466 million for the accumulated
transition obligation and a corresponding regulatory asset for anticipated
recovery in utility rates (see Note 2, Utility Regulation). The MPSC authorized
recovery of the electric utility portion of these costs in 1994 over 18 years
and the gas utility portion in 1996 over 16 years. At December 31, 1999,
Consumers had recorded a FERC regulatory asset and liability of $5 million. The
FERC has authorized recovery of these costs.
14: LEASES
CMS Energy, Consumers, and Enterprises lease various assets, including vehicles,
rail cars, aircraft, construction equipment, computer equipment, nuclear fuel
and buildings. Consumers' nuclear fuel capital leasing arrangement expires in
November 2001, yet provides for additional one-year extensions upon mutual
agreement by the parties. Upon termination of the lease, the lessor would be
entitled to a cash payment equal to its remaining investment, which was $58
million as of December 31, 1999. Consumers is responsible for payment of taxes,
maintenance, operating costs, and insurance.
Minimum rental commitments under CMS Energy's non-cancelable leases at December
31, 1999 were:
In Millions
- -------------------------------------------------------------------------------------------
Capital Operating
Leases Leases
- -------------------------------------------------------------------------------------------
2000 $ 47 $ 35
2001 58 30
2002 19 25
2003 15 18
2004 11 15
2005 and thereafter 10 69
--------------------------
Total minimum lease payments 160 $ 192
=====
Less imputed interest 35
-------
Present value of net minimum lease payments 125
Less current portion 36
-------
Noncurrent portion $ 89
===========================================================================================
Consumers recovers lease charges from customers and accordingly charges payments
for its capital and operating leases to operating expense. Operating lease
charges, including charges to clearing and other accounts for the years ended
December 31, 1999, 1998 and 1997, were $35 million, $19 million, and $10
million, respectively.
CMS-62
112
Capital lease expenses for the years ended December 31, 1999, 1998 and 1997 were
$42 million, $42 million and $43 million, respectively. Included in these
amounts for the years ended 1999, 1998 and 1997 are nuclear fuel lease expenses
of $23 million, $23 million and $31 million, respectively.
15: JOINTLY OWNED UTILITY FACILITIES
Consumers is responsible for providing its share of financing for the jointly
owned utility facilities. Consumers includes in operating expenses the direct
expenses of the joint plants. The following table indicates the extent of
Consumers' investment in jointly owned utility facilities:
In Millions
- ---------------------------------------------------------------------------------------
Net Investment Accumulated Depreciation
December 31 1999 1998 1999 1998
- ---------------------------------------------------------------------------------------
Campbell Unit 3 - 93.3 percent $284 $299 $295 $279
Ludington - 51 percent 104 106 100 94
Transmission lines - various 32 33 16 15
=======================================================================================
16: REPORTABLE SEGMENTS
CMS Energy operates principally in the following six reportable segments:
electric utility; gas utility; independent power production; oil and gas
exploration and production; natural gas transmission, storage and processing;
and energy marketing, services and trading.
The electric utility segment consists of regulated activities associated with
the generation, transmission and distribution of electricity in the state of
Michigan. The gas utility segment consists of regulated activities associated
with the transportation, storage and distribution of natural gas in the state of
Michigan. The other reportable segments consist of the development and
management of electric, gas and other energy-related projects in the United
States and internationally, including energy trading and marketing. CMS Energy's
reportable segments are strategic business units organized and managed by the
nature of the products and services each provides. The accounting policies of
each reportable segment are the same as those described in the summary of
significant accounting policies. CMS Energy's management evaluates performance
based on pretax operating income. Intersegment sales and transfers are accounted
for at current market prices and are eliminated in consolidated pretax operating
income by segment.
The Consolidated Statements of Income show operating revenue and pretax
operating income by reportable segment. Revenues from an international energy
distribution business and a land development business fall below the
quantitative thresholds for reporting. Neither of these segments has ever met
any of the quantitative thresholds for determining reportable segments. Amounts
shown for the natural gas transmission, storage and processing segment include
Panhandle, which was acquired in March 1999. Other financial data for reportable
segments and geographic area are as follows:
CMS-63
113
Reportable Segments
- -------------------
In Millions
- ------------------------------------------------------------------------------------------------------------------
Years Ended December 31 1999 1998 1997
- ------------------------------------------------------------------------------------------------------------------
Depreciation, Depletion and Amortization
Electric utility $ 315 $ 304 $ 296
Gas utility 107 97 93
Natural gas transmission, storage and processing 68 14 14
Independent power production 35 22 13
Oil and gas exploration and production 44 38 48
Marketing, services and trading 3 2 1
Other 23 7 2
---------------------------------------------
$ 595 $ 484 $ 467
==================================================================================================================
Identifiable Assets
Electric utility (a) $ 4,675 $ 4,640 $ 4,472
Gas utility (a) 1,731 1,726 1,644
Natural gas transmission, storage and processing 3,526 971 508
Independent power production 3,076 2,252 1,710
Oil and gas exploration and production 659 547 456
Marketing, services and trading 367 152 191
Other 1,428 1,022 527
---------------------------------------------
$15,462 $11,310 $ 9,508
==================================================================================================================
Capital Expenditures (b)
Electric utility $ 385 $ 331 $ 255
Gas utility 120 114 116
Natural gas transmission, storage and processing 2,216 573 115
Independent power production 392 462 704
Oil and gas exploration and production 151 143 99
Marketing, services and trading 42 1 28
Other 99 76 202
---------------------------------------------
$ 3,405 $ 1,700 $ 1,519
==================================================================================================================
Investments in Equity Method Investees
Natural gas transmission, storage and processing $ 369 $ 494 $ 241
Independent power production 1,437 1,337 1,205
Marketing, services and trading 27 25 26
Other 163 217 274
---------------------------------------------
$ 1,996 $ 2,073 $ 1,746
==================================================================================================================
CMS-64
114
Earnings from Equity Method Investees (c)
Natural gas transmission, storage and processing $ 20 $ 9 $ 4
Independent power production 119 158 89
Marketing, services and trading 3 2 2
Other (4) 2 8
----------------------------------------------------------
$ 138 $ 171 $ 103
=======================================================================================================
Geographic Areas (d)
- -------------------
Pretax
Operating Operating Identifiable
Revenue Income Assets
- ------------------------------------------------------------------------------------------------------
1999
United States $ 5,573 $ 794 $11,936
International 530 118 3,526
1998
United States $ 4,867 $ 702 $ 8,842
International 274 73 2,468
1997
United States $ 4,576 $ 665 $ 7,872
International 205 51 1,636
======================================================================================================
(a) Amounts include an attributed portion of Consumers' other common assets to
both the electric and gas utility businesses.
(b) Includes electric restructuring implementation plan, capital leases for
nuclear fuel and other assets and electric DSM costs. Amounts also include
an attributed portion of Consumers' capital expenditures for plant and
equipment common to both the electric and gas utility businesses.
(c) These amounts are included in operating revenue in the Consolidated
Statements of Income.
(d) Revenues are attributed to countries based on location of customers.
17: SUPPLEMENTAL CASH FLOW INFORMATION
For purposes of the Consolidated Statements of Cash Flows, all highly liquid
investments with an original maturity of three months or less are considered
cash equivalents. Other cash flow activities and noncash investing and financing
activities were:
CMS-65
115
In Millions
- ------------------------------------------------------------------------------------------------------------------
Years Ended December 31 1999 1998 1997
- ------------------------------------------------------------------------------------------------------------------
CASH TRANSACTIONS
Interest paid (net of amounts capitalized) $ 424 $313 $293
Income taxes paid (net of refunds) 59 64 67
NONCASH TRANSACTIONS
Nuclear fuel placed under capital leases 6 $ 46 $ 4
Other assets placed under capital leases 14 14 7
Common stock issued to retire Class G Common Stock 217 - -
Common stock issued to acquire companies - 61 -
Assumption of debt 305 88 -
================================================================================================================
Changes in other assets and liabilities as shown on the Consolidated Statements
of Cash Flows are described below:
In Millions
- ------------------------------------------------------------------------------------------------------------------
Years Ended December 31 1999 1998 1997
- ------------------------------------------------------------------------------------------------------------------
Sale of receivables, net $ 19 $ (29) $ 17
Accounts receivable (293) (183) (160)
Accrued revenue 42 (5) 64
Inventories (7) (42) (15)
Accounts payable 172 104 67
Accrued refunds - (1) 4
Other current assets and liabilities, net 124 126 (6)
Noncurrent deferred amounts, net (44) (150) (15)
----- ----- -----
$ 13 $(180) $ (44)
================================================================================================================
18: EQUITY METHOD INVESTMENTS
Certain of CMS Energy's investments in companies, partnerships and joint
ventures, where CMS Energy's ownership in its affiliates is more than 20 percent
but less than a majority, are accounted for by the equity method. Consolidated
net income includes undistributed equity earnings of $45 million in 1999, $95
million in 1998, and $58 million in 1997 from these investments. The more
significant of these investments are CMS Energy's 50 percent interest in Loy
Yang, a 2,000 MW brown coal-fueled power plant and coal mine in Australia, and
CMS Energy's 50 percent interest in Jorf Lasfar, a 1,356 MW coal-fueled power
plant in Africa. Summarized combined financial information of CMS Energy's
equity method investees follows, except for the MCV Partnership, which is
disclosed separately in Note 19.
CMS-66
116
INCOME STATEMENT DATA (UNAUDITED)
In Millions
- -------------------------------------------------------------------------------------------------------------------
Years Ended December 31 1999 1998 1997
- -------------------------------------------------------------------------------------------------------------------
Operating revenue $3,055 $2,255 $ 1,603
Operating expenses 2,186 1,503 1,154
--------------------------------------------------
Operating income 869 752 449
Other expense, net 558 409 271
--------------------------------------------------
Net income $ 311 $ 343 $ 178
===================================================================================================================
BALANCE SHEET DATA (UNAUDITED)
In Millions
- -------------------------------------------------------------------------------------------------------------------
December 31 1999 1998
- -------------------------------------------------------------------------------------------------------------------
ASSETS
Current assets $ 1,006 $ 646
Property, plant and equipment, net 7,581 6,783
Other assets 3,432 2,694
--------------------------------------------------
$12,019 $10,123
===================================================================================================================
LIABILITIES AND EQUITY
Current liabilities $ 971 $ 804
Long-term debt and other noncurrent liabilities 7,885 6,341
Equity 3,163 2,978
--------------------------------------------------
$12,019 $10,123
===================================================================================================================
19: SUMMARIZED FINANCIAL INFORMATION OF SIGNIFICANT
RELATED ENERGY SUPPLIER
Under the PPA with the MCV Partnership discussed in Note 4, Consumers' 1999
obligation to purchase electric capacity from the MCV Partnership provided 15.5
percent of Consumers' owned and contracted electric generating capacity.
Summarized financial information of the MCV Partnership follows:
CMS-67
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STATEMENTS OF INCOME (UNAUDITED)
In Millions
- -------------------------------------------------------------------------------------------------------------------
Years Ended December 31 1999 1998 1997
- -------------------------------------------------------------------------------------------------------------------
Operating revenue (a) $ 617 $ 627 $ 652
Operating expenses 401 405 435
---------------------------------------
Operating income 216 222 217
Other expense, net 136 142 154
-------------------------------------
Net income before cumulative effect of accounting change 80 80 63
Cumulative effect of change in method of accounting for property tax - - 15
-------------------------------------
Net income $ 80 $ 80 $ 78
===================================================================================================================
BALANCE SHEETS (UNAUDITED)
In Millions
- -------------------------------------------------------------------------------------------------------------------
December 31 1999 1998 1999 1998
- -------------------------------------------------------------------------------------------------------------------
ASSETS LIABILITIES AND EQUITY
Current assets (b) $ 397 $ 341 Current liabilities $ 275 $ 204
Plant, net 1,732 1,773 Noncurrent liabilities (c) 1,586 1,725
Other assets 170 173 Partners' equity (d) 438 358
--------------------- -----------------------
$2,299 $2,287 $2,299 $2,287
===================================================================================================================
(a) Revenue from Consumers totaled $586 million, $584 million and $609 million
for 1999, 1998, and 1997, respectively.
(b) Receivables from Consumers totaled $49, each year, at December 31, 1999 and
1998.
(c) FMLP is the sole beneficiary of an owner trust that is the lessor in a
long-term direct finance lease with the lessee, MCV Partnership. CMS Holdings
holds a 46.4 percent ownership interest in FMLP. At December 31, 1999 and 1998,
lease obligations of $1.36 billion and $1.41 billion, respectively, were owed to
the owner trust. CMS Holdings' share of the interest and principal portion for
the 1999 lease payments was $55 million and $23 million, respectively, and for
the 1998 lease payments was $59 million and $49 million, respectively. The lease
payments service $854 million and $907 million in non-recourse debt outstanding
as of December 31, 1999 and 1998, respectively, of the owner-trust. FMLP's debt
is secured by the MCV Partnership's lease obligations, assets, and operating
revenues. For 1999 and 1998, the owner-trust made debt payments (including
interest) of $167 million and $233 million, respectively. FMLP's earnings for
1999, 1998, and 1997 were $24 million, $23 million, and $20 million,
respectively.
(d) CMS Midland's recorded investment in the MCV Partnership includes
capitalized interest, which is being amortized to expense over the life of its
investment in the MCV Partnership. Covenants contained in financing agreements
prohibit the MCV Partnership from paying distributions until certain financial
test requirements are met. Consumers does not anticipate receiving a cash
distribution in the near future.
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Report of Independent Public Accountants
To CMS Energy Corporation:
We have audited the accompanying consolidated balance sheets and consolidated
statements of preferred stock of CMS ENERGY CORPORATION (a Michigan corporation)
and subsidiaries as of December 31, 1999 and 1998, and the related consolidated
statements of income, common stockholder's equity and cash flows for each of the
three years in the period ended December 31, 1999. These financial statements
are the responsibility of the Company's management. Our responsibility is to
express an opinion on these financial statements based on our audits.
We conducted our audits in accordance with generally accepted auditing
standards. Those standards require that we plan and perform the audit to obtain
reasonable assurance about whether the financial statements are free of material
misstatement. An audit includes examining, on a test basis, evidence supporting
the amounts and disclosures in the financial statements. An audit also includes
assessing the accounting principles used and significant estimates made by
management, as well as evaluating the overall financial statement presentation.
We believe that our audits provide a reasonable basis for our opinion.
In our opinion, the financial statements referred to above present fairly, in
all material respects, the financial position of CMS Energy Corporation and
subsidiaries as of December 31, 1999 and 1998, and the results of their
operations and their cash flows for each of the three years in the period ended
December 31, 1999 in conformity with generally accepted accounting principles.
As explained in Note 2 to the financial statements, effective January 1, 1998,
Consumers Energy Company, a wholly owned subsidiary of CMS Energy Corporation,
changed its method of accounting for property taxes.
/s/ Arthur Andersen LLP
Detroit, Michigan,
February 4, 2000.
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QUARTERLY FINANCIAL AND COMMON STOCK INFORMATION CMS ENERGY CORPORATION
1999 (Unaudited)
Quarters Ended March 31 June 30 Sept. 30 Dec. 31
- ----------------------------------------------------------------------------------------------------------
Operating revenue (a) $1,538 $1,331 $1,466 $1,768
Pretax operating income $245 $232 $271 $164
Consolidated net income $98 $75 $83 $21
Basic earnings (loss) per
average common
share (b):
CMS Energy $0.82 $0.68 $0.79 ($0.08)(c)
Class G $1.19 $0.10 ($0.38) $3.31 (c)
Diluted earnings (loss) per
average common
share (b):
CMS Energy $0.80 $0.67 $0.78 ($0.08)(c)
Class G $1.19 $0.10 ($0.38) $3.31 (c)
Dividends declared per
common share:
CMS Energy $0.33 $0.33 $0.365 $0.365
Class G $0.325 $0.325 $0.34 N/A
Common stock prices (d)
CMS Energy:
High $48-7/16 $47-1/16 $41-15/16 $38-1/16
Low $39-9/16 $39-1/4 $33-5/8 $30-5/16
Class G:
High $26 $25-3/8 $26-7/8 $24-15/16 (e)
Low $20-1/8 $20-1/2 $22-3/8 $22-1/4 (e)
- ---------------------------------------------------------------------------------------------------------
In Millions, Except Per Share Amounts
1998 (Unaudited)
Quarters Ended March 31 June 30 Sept. 30 Dec. 31
- ---------------------------------------------------------------------------------------------------------
Operating revenue (a) $1,374 $1,132 $1,286 $1,349
Pretax operating income $197 $188 $222 $168
Consolidated net income $88 $65 $81 $51
Basic earnings (loss) per
average common
share (b):
CMS Energy $0.79 $0.63 $0.81 $0.44
Class G $1.09 $0.12 ($0.16) $0.52
Diluted earnings (loss) per
average common
share (b):
CMS Energy $0.77 $0.62 $0.80 $0.44
Class G $1.09 $0.12 ($0.16) $0.52
Dividends declared per
common share:
CMS Energy $0.30 $0.30 $0.33 $0.33
Class G $0.31 $0.31 $0.325 $0.325
Common stock prices (d)
CMS Energy:
High $47-5/16 $47-3/16 $44-3/4 $50-1/8
Low $41-7/8 $40-11/16 $38-3/4 $43-3/16
Class G:
High $26-5/8 $26-7/8 $25-1/4 $26-1/2
Low $22-1/4 $23-1/4 $21-3/8 $23-1/8
- ---------------------------------------------------------------------------------------------------------
(a) Amounts in the second and third quarter of 1999 were restated for
comparative purposes.
(b) The sum of the quarters may not equal the annual earnings per share due to
changes in shares outstanding.
(c) Includes allocation of the premium on redemption of Class G Common Stock of
$(.26) per CMS Energy basic share, $ (.25) per CMS Energy diluted share and
$3.31 per Class G basic and diluted share.
(d) Based on New York Stock Exchange - Composite transactions.
(e) Through October 25, 1999.
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[CONSUMERS ENERGY LOGO]
1999 FINANCIAL STATEMENTS
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SELECTED FINANCIAL INFORMATION CONSUMERS ENERGY COMPANY
1999 1998 1997 1996 1995
- -----------------------------------------------------------------------------------------------------------------
Operating revenue (in millions) ($) 3,874 3,709 3,769 3,770 3,511
Net income (in millions) (Note 1) ($) 340 349 321 296 255
Net income available to common
stockholder (in millions) ($) 313 312 284 260 227
Cash from operations (in millions) ($) 781 625 761 672 642
Capital expenditures, excluding capital
lease additions and DSM (in millions) ($) 444 369 360 410 414
Total assets (in millions) ($) 7,170 7,163 6,949 7,025 6,954
Long-term debt, excluding current
maturities (in millions) ($) 2,006 2,007 1,369 1,900 1,922
Non-current portion of capital
leases (in millions) ($) 85 100 74 100 104
Total preferred stock (in millions) ($) 44 238 238 356 356
Total preferred securities (in millions) ($) 395 220 220 100 -
Number of preferred shareholders at year-end 2,534 5,649 6,178 9,540 10,084
Book value per common share at year-end ($) 23.87 21.94 20.38 19.96 19.00
Return on average common equity (%) 16.2 17.5 16.8 15.9 15.0
Return on average assets (%) 6.4 6.6 6.2 5.7 5.3
Number of full-time equivalent
employees at year-end
Consumers 8,736 8,456 8,640 8,938 9,262
Michigan Gas Storage 63 65 66 67 70
ELECTRIC STATISTICS
Sales (billions of kWh) 41.0 40.0 37.9 37.1 35.5
Customers (in thousands) 1,665 1,640 1,617 1,594 1,570
Average sales rate per kWh (cent) 6.54 6.50 6.57 6.55 6.36
GAS STATISTICS
Sales and transportation deliveries (bcf) 389 360 420 448 404
Customers (in thousands) (a) 1,584 1,558 1,533 1,504 1,476
Average sales rate per mcf ($) 4.52 4.56 4.44 4.45 4.42
- -----------------------------------------------------------------------------------------------------------------
(a) Excludes off-system transportation customers.
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CONSUMERS ENERGY COMPANY
MANAGEMENT'S DISCUSSION AND ANALYSIS
Consumers is a combination electric and gas utility company serving the lower
peninsula of Michigan and is a subsidiary of CMS Energy, a holding company.
Consumers' customer base includes a mix of residential, commercial and
diversified industrial customers, the largest segment of which is the automotive
industry.
This Annual Report and other written and oral statements made by Consumers from
time to time contain forward-looking statements as defined by the Private
Securities Litigation Reform Act of 1995. The words "anticipates," "believes,"
"estimates," "expects," "intends," and "plans," and variations of such words and
similar expressions, are intended to identify forward-looking statements that
involve risk and uncertainty. These forward-looking statements are subject to
various factors which could cause Consumers' actual results to differ materially
from those anticipated in such statements. Consumers disclaims any obligation to
update or revise forward-looking statements, whether from new information,
future events or otherwise. Consumers details certain risk factors,
uncertainties and assumptions in this Management's Discussion and Analysis and
particularly in the section entitled "Forward Looking Statements Cautionary
Factors" in Consumers' Form 8-K filed on February 1, 2000, and periodically in
various public filings it makes with the SEC. This discussion of potential risks
and uncertainties is by no means complete, but is designed to highlight
important factors that may impact Consumers' outlook. This Annual Report also
describes material contingencies in Consumers' Notes to Consolidated Financial
Statements and readers are encouraged to read such Notes.
RESULTS OF OPERATIONS
CONSUMERS CONSOLIDATED EARNINGS
In Millions
- -------------------------------------------------------------------------------------------------------------------
Years Ended December 31 1999 1998 Change 1998 1997 Change
- -------------------------------------------------------------------------------------------------------------------
Net income available to common stockholder $313 $312 $1 $312 $284 $28
===================================================================================================================
The 1999 net income available to the common stockholder is an increase of $1
million over the 1998 level. This increase includes the net impact of higher
electric and gas deliveries and reduced power costs. Changes in regulation have
allowed Consumers to temporarily benefit when power costs are lower than those
used to establish rates. Somewhat masking these improvements was a change in
accounting for property taxes (as described in Note 1) that provided a
non-recurring benefit in 1998 of $66 million ($43 million after-tax) and the
recognition of a $37 million loss ($24 million after-tax) for the underrecovery
of power costs under the PPA. In addition, 1999 net income reflects $9 million
of gains for the sale of property. The 1998 net income available to the common
stockholder is a $28 million increase over the 1997 level. This increase
reflects higher electric deliveries, improved earnings from the MCV Partnership,
and an adjustment of prior years' income taxes associated with investment tax
credits. Although other operating and maintenance expenses were higher than
1997, a continued focus on cost control benefited net income by nearly
offsetting the amount spent on significant restoration work on the electric
distribution system, which suffered damages caused by several storms. Additional
items that had an impact upon earnings were the recognition of the property tax
benefit reduced by the underrecovery of power costs under the PPA discussed
above, and decreased gas deliveries due to the extreme mild temperatures during
the 1998 heating season. For further information, see the Electric and Gas
Utility Results of Operations sections and Note 2, Uncertainties.
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ELECTRIC UTILITY RESULTS OF OPERATIONS
ELECTRIC PRETAX OPERATING INCOME:
In Millions
- -------------------------------------------------------------------------------------------------------------------
Years Ended December 31 1999 1998 Change 1998 1997 Change
- -------------------------------------------------------------------------------------------------------------------
$494 $475 $19 $475 $432 $43
===================================================================================================================
Electric pretax operating income increased $19 million in 1999 from the
comparable period in 1998. The earnings increase reflects higher electric
deliveries and effective management of power costs. Changes in regulation,
effective in 1998, allow Consumers the opportunity to temporarily benefit from
reduced power supply costs. In the past such cost reductions had no impact on
net income because power cost savings were passed on to Consumers' electric
customers. This earnings increase was partially offset by higher depreciation
costs for new property and equipment and lower non-commodity revenues. Electric
pretax operating income for 1998 increased $43 million from the comparable
period in 1997. The increase reflects higher electric deliveries, cost control,
and the changes in regulation mentioned above. Partially offsetting these
increases were higher general taxes and depreciation for new property and
equipment. The following table quantifies these impacts on pretax operating
income:
In Millions
- ---------------------------------------------------------------------------------------------------------------
Change Compared to Prior Year 1999 vs 1998 1998 vs 1997
- ---------------------------------------------------------------------------------------------------------------
Electric deliveries $37 $ 40
Power supply costs and related revenue 27 14
Net energy option costs (19) 6
Non-commodity revenue (13) (4)
Operations and maintenance (3) (3)
General taxes and depreciation (10) (10)
--------------------------
Total change $19 $43
===============================================================================================================
ELECTRIC DELIVERIES: Electric deliveries were 41 billion kWh for 1999, an
increase of 1 billion kWh or 2.5 percent compared with 1998. Total electric
deliveries increased in all customer classes. Total electric deliveries in 1998
were 40 billion kWh, an increase of 2.2 billion kWh or 6 percent compared with
1997. The increase was primarily attributable to increased sales to other
utilities and a 3 percent increase in deliveries to ultimate customers.
POWER SUPPLY COSTS:
In Millions
- --------------------------------------------------------------------------------------------------------------
Years Ended December 31 1999 1998 Change 1998 1997 Change
- --------------------------------------------------------------------------------------------------------------
$1,193 $1,175 $18 $1,175 $1,139 $36
==============================================================================================================
Power supply costs increased for 1999 to meet increased electric delivery
requirements. Both the 1999 and 1998 power supply cost increases reflect higher
internal generation to meet the increased demand for electricity. In addition,
the cost increase in 1998 over the prior year reflects increased power purchases
from outside sources to meet sales demand. In 1999 and 1998 respectively,
Consumers purchased $19 million and $5 million of energy options for physical
delivery of electricity to ensure a reliable source of power during the summer
months. As a result of periodic excess daily capacity, some options were sold
for $6 million and $11
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million during June, July, and August of 1999 and 1998, respectively. All of the
remaining options were exercised or expired. The costs relating to the expired
options, offset by income received from the sale of options, were reflected as
purchased power costs.
GAS UTILITY RESULTS OF OPERATIONS
GAS PRETAX OPERATING INCOME:
In Millions
- --------------------------------------------------------------------------------------------------------------
Years Ended December 31 1999 1998 Change 1998 1997 Change
- --------------------------------------------------------------------------------------------------------------
$132 $126 $6 $126 $153 $(27)
==============================================================================================================
Gas pretax operating income increased by $6 million in 1999 from the comparable
period in 1998. The earnings increase is primarily the result of increased gas
deliveries due to colder temperatures during the first and fourth quarters of
1999 and increased revenues from gas wholesale and retail services activity.
Partially offsetting this earnings increase were a regulatory disallowance,
higher operation and maintenance costs, and increased depreciation and general
taxes due to new property and equipment. Gas pretax operating income decreased
by $27 million in 1998 from the comparable period in 1997. The earnings decrease
is primarily the result of reduced gas deliveries due to significantly milder
temperatures during the first and fourth quarters of 1998 and increased
depreciation and general taxes associated with additional plant investments to
serve new customers. The impact of the mild temperatures on sales was partially
tempered by the suspension of Consumers GCR clause in 1998. Changes in
regulation related to the gas industry restructuring initiatives provided
Consumers the opportunity to temporarily benefit from low gas prices. In the
past these cost reductions would have had no impact on pretax operating income
because any gas cost savings were passed on to Consumers' gas customers; see
Note 2, Uncertainties, "Gas Rate Matters - Gas Restructuring", for more detailed
information on this matter. The following table quantifies these impacts on
Pretax Operating Income.
In Millions
- ----------------------------------------------------------------------------------------------------------------
Change Compared to Prior Year 1999 vs 1998 1998 vs 1997
- ----------------------------------------------------------------------------------------------------------------
Gas deliveries $32 $ (42)
Gas commodity and related revenue (5) 19
Gas wholesale and retail services 5 1
Operation and maintenance (14) (1)
General taxes and depreciation (12) (4)
------------------------------
Total change $ 6 $ (27)
================================================================================================================
GAS DELIVERIES: Gas system deliveries in 1999, including miscellaneous
transportation, totaled 389 bcf, an increase of 29 bcf or 8 percent compared
with 1998. The increased deliveries reflect colder temperatures during the first
quarter of 1999. System deliveries in 1998, including miscellaneous
transportation, totaled 360 bcf, a decrease of 60 bcf or 14 percent compared
with 1997. The decreased deliveries reflect milder winter temperatures in the
first and fourth quarters of 1998.
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COST OF GAS SOLD:
In Millions
- ----------------------------------------------------------------------------------------------------------------
Years Ended December 31 1999 1998 Change 1998 1997 Change
- ----------------------------------------------------------------------------------------------------------------
$637 $564 $73 $564 $694 $(130)
===============================================================================================================
The cost of gas sold increase for 1999 was the result of increased sales due to
colder temperatures during 1999 and higher gas prices. The cost of gas decrease
for 1998 was the result of decreased sales from milder temperatures during 1998
and decreased gas prices.
CAPITAL RESOURCES AND LIQUIDITY
CASH POSITION, INVESTING AND FINANCING
OPERATING ACTIVITIES: Consumers derives cash from operating activities from the
sale and transportation of natural gas and from the generation, transmission,
distribution and sale of electricity. Cash from operations totaled $781 million
and $625 million for 1999 and 1998, respectively. The $156 million increase
resulted primarily from a $48 million increase in the sale of accounts
receivable and a $39 million decrease in gas and coal inventories. The remaining
change is the result of a $21 million increase in depreciation and from the
timing of cash payments related to normal operations. For additional
information, see Note 12, Supplemental Cash Flow Information. Other items
included in 1998 income but which had no effect on cash flow were a one-time
change in accounting for property taxes resulting in a $66 million ($43 million
after-tax) gain and the recognition of a $37 million loss ($24 million
after-tax) for the underrecovery of power costs under the PPA. Consumers
primarily uses cash derived from operating activities to maintain and expand
electric and gas systems, to retire portions of long-term debt and to pay
dividends.
INVESTING ACTIVITIES: Cash used for investing activities totaled $509 million
and $374 million for 1999 and 1998, respectively. The change of $135 million is
primarily the result of a $75 million increase in capital expenditures, a $15
million increase in electric restructuring implementation plan costs, a $10
million increase in the cost of plant retired and the absence of $27 million of
proceeds from the 1998 sale of two non-utility partnerships.
FINANCING ACTIVITIES: Cash used in financing activities totaled $279 and $233
million for 1999 and 1998, respectively. The change of $46 million is primarily
the result of a $133 million net decrease in proceeds from the refinancing and
issuance of Consumers' debt and a $21 million increase in the payment of common
stock dividends offset by $100 million contribution from Consumers' common
stockholder and $9 million decrease in the payment of preferred stock dividends.
OTHER INVESTING AND FINANCING MATTERS: Consumers has credit facilities, lines of
credit and a trade receivable sale program in place as anticipated sources of
funds to fulfill its currently expected capital expenditures. For detailed
information about these source of funds, see Note 1, "Nuclear Fuel Cost" and
Note 3, Short-Term Financings and Capitalization.
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OUTLOOK
CAPITAL EXPENDITURES OUTLOOK
Consumers estimates the following capital expenditures, including new lease
commitments, by company and by business segments over the next three years.
These estimates are prepared for planning purposes and are subject to revision.
In Millions
- ----------------------------------------------------------------------------------------------------------------
Years Ended December 31 2000 2001 2002
- ----------------------------------------------------------------------------------------------------------------
Construction $510 $609 $547
Nuclear fuel lease 3 19 28
Capital leases other than nuclear fuel 26 22 25
-------------------------------
$539 $650 $600
================================================================================================================
Electric utility operations (a)(b) $426 $520 $473
Gas utility operations (a) 113 130 127
-------------------------------
$539 $650 $600
================================================================================================================
(a) These amounts include an attributed portion of Consumers' anticipated
capital expenditures for plant and equipment common to both the electric and gas
utility businesses.
(b) These amounts do not include preliminary estimates for capital expenditures
possibly required to comply with recently revised national air quality standards
under the Clean Air Act. For further information see Note 2, Uncertainties.
ELECTRIC BUSINESS OUTLOOK
GROWTH: Consumers expects average annual growth of two and one half percent per
year in electric system deliveries for the years 2000 to 2004. This growth rate
does not take into account the possible impact of restructuring or changed
regulation on the industry. Abnormal weather, changing economic conditions, or
the developing competitive market for electricity may affect actual electric
sales by Consumers in future periods.
COMPETITION AND REGULATORY RESTRUCTURING: Generally, electric restructuring is
the regulatory and legislative attempt to introduce competition to the electric
industry by allowing customers to choose their electric generation supplier,
while the transmission and distribution services remain regulated. As a result,
the electric generation suppliers ultimately compete in a less regulated
environment. Competition affects, and will continue to affect, Consumers' retail
electric business. To remain competitive, Consumers has multi-year electric
supply contracts with some of its largest industrial customers to provide power
to some of their facilities. The MPSC approved these contracts as part of its
phased introduction to competition. Beginning in 2000 through 2005, some
customers, depending on future business and regulatory circumstances, can
terminate or restructure their contracts. The termination or restructuring of
these contracts could affect approximately 600 MW of customer power supply
requirements. The ultimate financial impact of changes related to these power
supply contracts is not known at this time.
As a result of a transition of the wholesale and retail electric businesses in
Michigan to competition, Detroit Edison, in December 1996, gave Consumers the
required four-year notice of its intent to terminate the current agreements
under which the companies jointly operate the MEPCC. At the same time, Detroit
Edison filed
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127
with the FERC seeking early termination of the agreements. The FERC has not
acted on Detroit Edison's application. Detroit Edison and Consumers are
currently in negotiations to terminate or restructure the MEPCC operations.
Consumers is unable to predict the outcome of these negotiations, but does not
anticipate any adverse impacts caused by termination or restructuring of the
MEPCC.
In December 1999, a large coalition of utilities, businesses, and commercial and
industrial energy users agreed upon proposed electric restructuring legislation
for Michigan. This legislation: 1) provides for customer choice of power
suppliers for all customers by January 2002; 2) ensures full recovery of
Stranded Costs by utilities calculated by taking into account the difference
between the market value and the net book value of the generation assets; and 3)
provides for deregulation of electric power suppliers who control less than 30
percent of the sum of Michigan's transmission import and generating capacity by
December 31, 2002. It also provides for a three-year rate freeze through 2002
for all utility customers who keep their utility as their electric supplier. To
be able to sell electric generation services on a deregulated basis, Consumers
would be required to transfer control of sufficient generation resources to meet
the 30 percent test. The legislation precludes Consumers' generating resources
from being deregulated prior to December 31, 2002. The proposed legislation was
introduced into the Michigan Legislature in January 2000, and is expected to be
considered in hearings during the first quarter of 2000. Consumers supports this
specific legislation.
Uncertainty exists with respect to the enactment of federal legislation
restructuring the electric power industry. A variety of bills introduced in
Congress in recent years seek to change existing federal regulation of the
industry. These federal bills could potentially affect or supercede state
regulation; however, none have been enacted. Consumers cannot predict the
outcome of electric restructuring on its financial position, liquidity, or
results of operations.
RATE MATTERS: There are several pending rate issues that could affect Consumers'
electric business. These matters include MPSC rate proceedings and electric
restructuring orders and a complaint by ABATE alleging excess revenues.
For further information and material changes relating to the rate matters and
restructuring of the electric utility industry, see Note 1, Corporate Structure
and Summary of Significant Accounting Policies, and Note 2, Uncertainties,
"Electric Rate Matters - Electric Proceedings" and "Electric Rate Matters -
Electric Restructuring," incorporated by reference herein.
UNCERTAINTIES: Several trends or uncertainties may affect Consumers' financial
results and condition as a result of Consumers' electric business. These trends
or uncertainties have, or Consumers reasonably expects could have, a material
impact on net sales, revenues, or income from continuing electric operations.
Such trends and uncertainties include: 1) capital expenditures for compliance
with the Clean Air Act; 2) environmental liabilities arising from compliance
with various federal, state and local environmental laws and regulations,
including potential liability or expenses relating to the Michigan Natural
Resources and Environmental Protection Act and Superfund; 3) cost recovery
relating to the MCV Partnership; 4) an ABATE rate complaint; 5) electric
industry restructuring; 6) implementation of a frozen PSCR and initiatives
undertaken to reduce exposure to energy price increases; and 7) nuclear
decommissioning issues and ongoing issues relating to the storage of spent fuel
and the operating life of Palisades. For detailed information about these trends
or uncertainties, see Note 2, Uncertainties, incorporated by reference herein.
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GAS BUSINESS OUTLOOK
GROWTH: Consumers currently anticipates gas deliveries, including gas customer
choice deliveries (excluding transportation to the MCV Facility and off-system
deliveries), to grow at an average annual rate of between one and two percent
over the next five years based primarily on a steadily growing customer base.
Actual gas deliveries in future periods may be affected by abnormal weather,
alternative energy prices, changes in competitive conditions, and the level of
natural gas consumption. Consumers' gas business also offers a variety of
energy-related services to electric and gas customers focused upon appliance
maintenance, home safety, commodity choice and assistance to customers
purchasing heating, ventilation and air conditioning equipment.
REGULATORY RESTRUCTURING: In December 1999, several bills related to gas
industry restructuring were introduced into the Michigan Legislature. Combined,
these bills constitute the "gas choice program." Consumers is participating in
the legislative process as part of a gas utility coalition that also includes
Michigan Consolidated Gas Company and Southeastern Michigan Gas Company. These
bills provide for 1) a phased-in approach to gas choice requiring 40 percent of
the customers to be allowed choice by April 2002, 60 percent by April 2003 and
all customers by April 2004; 2) a market-based, unregulated pricing mechanism
for gas commodity for customers who exercise choice; and 3) a new "safe haven"
pricing mechanism for customers who do not exercise choice under which NYMEX
pricing would be used to establish a statutory cap on gas commodity prices that
could be charged by gas utilities instead of traditional cost of service
regulation. The proposed bills also provide for a gas distribution service rate
freeze until December 31, 2005, a code of conduct governing business
relationships with affiliated gas suppliers and the MPSC licensing of all gas
suppliers doing business in Michigan and imposes financial penalties for
noncompliance. They also provide customer protection by preventing "slamming",
the switching of a customer's gas supplier without consent, and "cramming", the
inclusion of optional products and services without the customer's
authorization. The bills establishing the gas choice program will become the
subject of extensive legislative hearings during which there will undoubtedly be
various amendments offered by many parties, including the gas utility coalition.
Consumers cannot predict the outcome of this legislative process.
UNCERTAINTIES: Consumers' financial results and position may be affected by a
number of trends or uncertainties that have, or Consumers reasonably expects
could have, a material impact on net sales or revenues or income from continuing
gas operations. Such trends and uncertainties include: 1) potential
environmental costs at a number of sites, including sites formerly housing
manufactured gas plant facilities; 2) a statewide experimental gas industry
restructuring program; 3) permanent gas industry restructuring; and 4)
implementation of a suspended GCR and initiatives undertaken to protect against
gas price increases. For detailed information about these uncertainties see Note
2, Uncertainties, incorporated by reference herein.
OTHER MATTERS
NEW ACCOUNTING STANDARDS
In 1999, the FASB issued SFAS 137, Accounting for Derivative Instruments and
Hedging Activities Deferral of the Effective Date of FASB Statement No. 133.
SFAS 137 defers the effective date of SFAS 133, Accounting for Derivative
Instruments and Hedging Activities to January 1, 2001. Consumers will adopt the
standard on January 1, 2001 and is currently analyzing the effects of adoption
on its financial statements.
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YEAR 2000 COMPUTER MODIFICATIONS
In 1999, Consumers completed a detailed assessment and inventory of all
technology related to business processes, with an emphasis on mission-critical
systems. Consumers identified, remediated and tested those systems that were not
year 2000 ready to ensure that those systems would operate as desired on and
after January 1, 2000.
As a result of its year 2000 efforts, Consumers successfully transitioned to the
new year without experiencing year 2000-related system failures, power outages
or disruptions in services provided to its customers.
Consumers expensed the cost of software modifications as incurred, and
capitalized the cost of new software and equipment, which is being amortized
over its useful life. Since 1995, the total cost of the Year 2000 Program
modifications was $22 million. Consumers funded year 2000 compliance work
primarily from operations. This cost did not have a material effect on
Consumers' financial position, liquidity, or results of operations. The
commitment of Consumers resources to the year 2000 issue has not deferred any
information technology projects whereby the deferral of those projects could
cause a material adverse effect on Consumers' financial position, liquidity, or
results of operations.
While Consumers does not expect any significant year 2000 issues to develop
after year-end 1999, Consumers will continue to monitor its systems throughout
the year 2000 to ensure that any year 2000 issues that may arise are addressed
promptly.
DERIVATIVES AND HEDGES
MARKET RISK INFORMATION: Consumers' exposure to market risk sensitive
instruments and positions include, but are not limited to, changes in interest
rates, debt prices and equity prices in which Consumers holds less than a 20
percent interest. In accordance with the SEC's disclosure requirements,
Consumers performed a 10 percent sensitivity analysis on its derivative and
non-derivative financial instruments. The analysis measures the change in the
net present values based on a hypothetical 10 percent adverse change in the
market rates to determine the potential loss in fair values, cash flows and
earnings. Losses in excess of the amounts determined could occur if market rates
or prices exceed the 10 percent change used for the analysis. Management does
not believe that a sensitivity analysis alone provides an accurate or reliable
method for monitoring and controlling risk. Therefore, Consumers relies on the
experience and judgment of senior management to revise strategies and adjust
positions, as they deem necessary.
For purposes of the analysis below, Consumers has not quantified short-term
exposures to hypothetically adverse changes in the price or nominal amounts
associated with inventories or trade receivables and payables. Furthermore,
Consumers enters into all derivative financial instruments for purposes other
than trading. In the case of hedges, management believes that any losses
incurred on derivative instruments used as a hedge would be offset by the
opposite movement of the underlying hedged item.
EQUITY SECURITY PRICE RISK: Consumers has equity investments in companies in
which it holds less than a 20 percent interest in the entity. A hypothetical 10
percent adverse change in market price would result in a $12 million change in
its investment and equity since this equity instrument is currently
marked-to-market through equity. Consumers believes that such an adverse change
would not have a material effect on its consolidated financial position, results
of operation or cash flows. For further information, regarding Consumers equity
investments, see Note 5, Financial Instruments.
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DEBT PRICE AND INTEREST RATE RISK: Management uses a combination of fixed-rate
and variable-rate debt to reduce interest rate exposure. Interest rate swaps and
rate locks may be used to adjust exposure when deemed appropriate, based upon
market conditions. These strategies attempt to provide and maintain the lowest
cost of capital.
As of December 31, 1999, Consumers had outstanding $108 million of variable-rate
debt net of any interest rate swaps. To minimize adverse interest-rate changes,
Consumers entered into fixed interest-rate swaps for a notional amount of $845
million. Assuming a hypothetical 10 percent adverse change in market interest
rates, Consumers' exposure to earnings is limited to $1 million. As of December
31, 1999, Consumers has outstanding fixed-rate debt including fixed-rate swaps
of $2.907 billion with a fair value of $2.765 billion. Assuming a hypothetical
10 percent adverse change in market rates, Consumers would have an exposure of
$135 million to its fair value. Consumers believes that any adverse change in
debt price and interest rates would not have a material effect on its
consolidated financial position, results of operation or cash flows.
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CONSOLIDATED STATEMENTS OF INCOME CONSUMERS ENERGY COMPANY
In Millions
Years Ended December 31 1999 1998 1997
- -----------------------------------------------------------------------------------------------------------------
OPERATING REVENUE Electric $ 2,667 $ 2,606 $2,515
Gas 1,156 1,051 1,204
Other 51 52 50
----------------------------------
3,874 3,709 3,769
- ------------------------------------------------------------------------------------------------------------------
OPERATING EXPENSES Operation
Fuel for electric generation 336 317 297
Purchased power - related parties 560 573 599
Purchased and interchange power 297 285 243
Cost of gas sold 637 564 694
Other 570 544 542
----------------------------------
2,400 2,283 2,375
Maintenance 174 173 170
Depreciation, depletion and amortization 424 403 391
General taxes 201 201 200
----------------------------------
3,199 3,060 3,136
- ------------------------------------------------------------------------------------------------------------------
PRETAX OPERATING Electric 494 475 432
INCOME Gas 132 126 153
Other 49 48 48
----------------------------------
675 649 633
- ------------------------------------------------------------------------------------------------------------------
OTHER INCOME Loss on MCV power purchases - (37) -
(DEDUCTIONS) Dividends and interest from affiliates 11 14 24
Accretion income (Note 1) 4 6 8
Accretion expense (Note 1) (14) (16) (17)
Other, net 17 - (2)
----------------------------------
18 (33) 13
- ------------------------------------------------------------------------------------------------------------------
INTEREST CHARGES Interest on long-term debt 140 138 138
Other interest 41 38 36
Capitalized interest - (1) (1)
----------------------------------
181 175 173
- ------------------------------------------------------------------------------------------------------------------
NET INCOME BEFORE INCOME TAXES 512 441 473
INCOME TAXES 172 135 152
----------------------------------
NET INCOME BEFORE CUMULATIVE EFFECT OF CHANGE IN ACCOUNTING PRINCIPLE 340 306 321
CUMULATIVE EFFECT OF CHANGE IN ACCOUNTING FOR PROPERTY TAXES,
NET OF $23 TAX (NOTE 1) - 43 -
----------------------------------
NET INCOME 340 349 321
PREFERRED STOCK DIVIDENDS 6 19 25
PREFERRED SECURITIES DISTRIBUTIONS 21 18 12
----------------------------------
NET INCOME AVAILABLE TO COMMON STOCKHOLDER $ 313 $ 312 $ 284
==================================================================================================================
THE ACCOMPANYING NOTES ARE AN INTEGRAL PART OF THESE STATEMENTS.
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CONSOLIDATED STATEMENTS OF CASH FLOWS CONSUMERS ENERGY COMPANY
In Millions
Years Ended December 31 1999 1998 1997
- ---------------------------------------------------------------------------------------------------------------------
CASH FLOWS FROM Net income $ 340 $ 349 $ 321
OPERATING ACTIVITIES Adjustments to reconcile net income to net cash
provided by operating activities
Depreciation, depletion and amortization (includes nuclear
decommissioning of $50, $51 and $50, respectively) 424 403 391
Loss on MCV power purchases - 37 -
Capital lease and other amortization 35 36 44
Accretion expense 14 16 17
Deferred income taxes and investment tax credit 2 21 13
Accretion income - abandoned Midland project (4) (6) (8)
Undistributed earnings of related parties (50) (50) (47)
MCV power purchases (62) (64) (62)
Cumulative effect of accounting change - (66) -
Changes in other assets and liabilities 82 (51) 92
---------------------------
Net cash provided by operating activities 781 625 761
- ---------------------------------------------------------------------------------------------------------------------
CASH FLOWS FROM Capital expenditures (excludes assets placed under capital lease) (444) (369) (360)
INVESTING ACTIVITIES Cost to retire property, net (93) (83) (46)
Investments in nuclear decommissioning trust funds (50) (51) (50)
Investment in Electric Restructuring Implementation Plan (32) (17) (3)
Associated company preferred stock redemption 50 50 50
Proceeds from nuclear decommissioning trust funds 43 53 17
Proceeds from the sale of two non-utility partnerships - 27 -
Proceeds from FMLP 10 12 -
Other 7 4 (3)
----------------------------
Net cash used in investing activities (509) (374) (395)
- ----------------------------------------------------------------------------------------------------------------------
CASH FLOWS FROM Payment of common stock dividends (262) (241) (218)
FINANCING ACTIVITIES Retirement of preferred stock (200) - (120)
Retirement of bonds and other long-term debt (87) (854) (50)
Payment of capital lease obligations (33) (35) (44)
Preferred securities distributions (21) (18) (12)
Payment of preferred stock dividends (10) (19) (29)
Increase (decrease) in notes payable, net - (162) 44
Proceeds from preferred securities 169 - 116
Contribution from (return of equity to) stockholder 150 50 (50)
Proceeds from senior notes & bank loans 15 1,046 -
---------------------------
Net cash used in financing activities (279) (233) (363)
- ----------------------------------------------------------------------------------------------------------------------
NET INCREASE (DECREASE) IN CASH AND TEMPORARY CASH INVESTMENT (7) 18 3
Cash and temporary cash investments - Beginning of year 25 7 4
---------------------------
End of year $ 18 $ 25 $ 7
=====================================================================================================================
OTHER CASH FLOW ACTIVITIES AND NON-CASH INVESTING AND FINANCING ACTIVITIES WERE:
CASH TRANSACTIONS
Interest paid (net of amounts capitalized) $ 168 $ 161 $ 166
Income taxes paid (net of refunds) 187 153 116
NON-CASH TRANSACTIONS
Nuclear fuel placed under capital lease $ 6 $ 46 $ 4
Other assets placed under capital leases 14 14 7
=====================================================================================================================
ALL HIGHLY LIQUID INVESTMENTS WITH AN ORIGINAL MATURITY OF THREE MONTHS OR LESS
ARE CONSIDERED CASH EQUIVALENTS.
THE ACCOMPANYING NOTES ARE AN INTEGRAL PART OF THESE STATEMENTS.
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CONSOLIDATED BALANCE SHEETS CONSUMERS ENERGY COMPANY
ASSETS In Millions
December 31 1999 1998
- ------------------------------------------------------------------------------------------------------------------
PLANT (AT ORIGINAL COST) Electric $6,981 $6,720
Gas 2,461 2,360
Other 25 25
------------------------------
9,467 9,105
Less accumulated depreciation, depletion
and amortization 5,643 4,862
------------------------------
3,824 4,243
Construction work-in-progress 199 165
------------------------------
4,023 4,408
- ------------------------------------------------------------------------------------------------------------------
INVESTMENTS Stock of affiliates 139 241
First Midland Limited Partnership 240 240
Midland Cogeneration Venture Limited Partnership 247 209
------------------------------
626 690
- ------------------------------------------------------------------------------------------------------------------
CURRENT ASSETS Cash and temporary cash investments at cost, which
approximates market 18 25
Accounts receivable and accrued revenue, less allowances
of $4 in 1999 and $5 in 1998 98 114
Accounts receivable - related parties 67 63
Inventories at average cost
Gas in underground storage 216 219
Materials and supplies 62 67
Generating plant fuel stock 46 43
Postretirement benefits 25 25
Deferred income taxes 8 -
Prepaid property taxes and other 159 162
------------------------------
699 718
- ------------------------------------------------------------------------------------------------------------------
NON-CURRENT ASSETS Regulatory Assets
Unamortized nuclear costs 519 -
Postretirement benefits 341 372
Abandoned Midland project 48 71
Other 125 133
Nuclear decommissioning trust funds 602 557
Other 187 214
------------------------------
1,822 1,347
- ------------------------------------------------------------------------------------------------------------------
TOTAL ASSETS $7,170 $7,163
==================================================================================================================
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CONSUMERS ENERGY COMPANY
STOCKHOLDERS' INVESTMENT AND LIABILITIES In Millions
December 31 1999 1998
- ------------------------------------------------------------------------------------------------------------------
CAPITALIZATION (NOTE 3) Common stockholder's equity
Common stock $ 841 $ 841
Paid-in capital 645 502
Revaluation capital 37 68
Retained earnings since December 31, 1992 485 434
------------------------------
2,008 1,845
Preferred stock 44 238
Company-obligated mandatorily redeemable
preferred securities of:
Consumers Power Company Financing I (a) 100 100
Consumers Energy Company Financing II (a) 120 120
Consumers Energy Company Financing III (a) 175 -
Long-term debt 2,006 2,007
Non-current portion of capital leases 85 100
------------------------------
4,538 4,410
- ------------------------------------------------------------------------------------------------------------------
CURRENT LIABILITIES Current portion of long-term debt and capital leases 90 152
Notes payable 214 215
Accounts payable 224 190
Accrued taxes 232 238
Accounts payable - related parties 82 79
Power purchases - MCV Partnership 47 47
Accrued interest 37 36
Deferred income taxes - 9
Accrued refunds 11 11
Other 139 138
------------------------------
1,076 1,115
- ------------------------------------------------------------------------------------------------------------------
NON-CURRENT LIABILITIES Deferred income taxes 700 666
Postretirement benefits 420 456
Deferred investment tax credit 125 134
Power purchases - MCV Partnership 73 121
Regulatory liabilities for income taxes, net 64 87
Other 174 174
------------------------------
1,556 1,638
- ------------------------------------------------------------------------------------------------------------------
Commitments and Contingencies (Notes 1, 2, 8 and 11)
TOTAL STOCKHOLDERS' INVESTMENT AND LIABILITIES $7,170 $7,163
==================================================================================================================
(a) The primary asset of Consumers Power Company Financing I is $103 million
principal amount of 8.36% subordinated deferrable interest notes due 2015 from
Consumers. The primary asset of Consumers Energy Company Financing II is $124
million principal amount of 8.20% subordinated deferrable interest notes due
2027 from Consumers. The primary asset of Consumers Energy Company Financing III
is $180 million principal amount of 9.25% subordinated deferrable interest notes
due 2029 from Consumers. For further discussion, see Note 3.
THE ACCOMPANYING NOTES ARE AN INTEGRAL PART OF THESE BALANCE SHEETS.
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CONSOLIDATED STATEMENTS OF LONG-TERM DEBT CONSUMERS ENERGY COMPANY
In Millions
December 31 1999 1998
- ----------------------------------------------------------------------------------------------------------------
FIRST MORTGAGE BONDS SERIES (%) DUE
8-7/8 1999 $ - $ 64
6-3/8 2003 300 300
7-3/8 2023 263 264
----------------------
563 628
SENIOR NOTES 6-3/8 2008 250 250
6-7/8 2018 225 225
6-1/5 2008 250 250
6-1/2 2018 200 200
6-1/2 2028 149 150
----------------------
1,637 1,703
LONG-TERM BANK DEBT 190 175
POLLUTION CONTROL REVENUE BONDS 131 131
NUCLEAR FUEL DISPOSAL (A) 123 117
OTHER - 22
----------------------
PRINCIPAL AMOUNT OUTSTANDING 2,081 2,148
CURRENT AMOUNTS (55) (119)
NET UNAMORTIZED DISCOUNT (20) (22)
----------------------
TOTAL LONG-TERM DEBT $2,006 $2,007
================================================================================================================
LONG-TERM DEBT MATURITIES In Millions
First Mortgage Long-Term
Bonds Bank Debt Other Total
- ----------------------------------------------------------------------------------------------------------------
2000 $ - $ 50 $ 5 $ 55
2001 - - - -
2002 - 56 - 56
2003 300 84 - 384
2004 - - - -
================================================================================================================
(a) Due date uncertain (see Note 1)
THE ACCOMPANYING NOTES ARE AN INTEGRAL PART OF THESE STATEMENTS.
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CONSOLIDATED STATEMENTS OF PREFERRED STOCK CONSUMERS ENERGY COMPANY
Optional
Redemption Number of Shares In Millions
December 31 Series Price 1999 1998 1999 1998
- ------------------------------------------------------------------------------------------------------------------
PREFERRED STOCK
Cumulative, $100 par value,
authorized 7,500,000 shares,
with no mandatory redemption $4.16 $103.25 68,451 68,451 $ 7 $ 7
4.50 110.00 373,148 373,148 37 37
CLASS A PREFERRED STOCK
Cumulative, no par value,
authorized 16,000,000 shares,
with no mandatory redemption 2.08 25.00 (a) - 8,000,000 - 194
--------------
TOTAL PREFERRED STOCK $44 $238
==================================================================================================================
(a) Redeemed April 1, 1999.
THE ACCOMPANYING NOTES ARE AN INTEGRAL PART OF THESE STATEMENTS.
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CONSOLIDATED STATEMENTS OF COMMON STOCKHOLDER'S EQUITY CONSUMERS ENERGY COMPANY
In Millions
Years Ended December 31 1999 1998 1997
- ---------------------------------------------------------------------------------------------------------------
COMMON STOCK At beginning and end of period (a) $ 841 $ 841 $ 841
- ---------------------------------------------------------------------------------------------------------------
OTHER PAID-IN CAPITAL At beginning of period 502 452 504
Capital stock reacquired (7) - (2)
Stockholder's contribution 150 100 -
Return of stockholder's contribution - (50) (50)
------------------------------
At end of period 645 502 452
- ---------------------------------------------------------------------------------------------------------------
REVALUATION CAPITAL At beginning of period 68 58 37
Change in unrealized investment - gain (loss)(b) (31) 10 21
------------------------------
At end of period 37 68 58
- ---------------------------------------------------------------------------------------------------------------
RETAINED EARNINGS At beginning of period 434 363 297
Net income (b) 340 349 321
Cash dividends declared - Common Stock (262) (241) (218)
Cash dividends declared - Preferred Stock (6) (19) (25)
Preferred securities distributions (21) (18) (12)
------------------------------
At end of period 485 434 363
------------------------------
TOTAL COMMON STOCKHOLDER'S
EQUITY $2,008 $1,845 $1,714
===============================================================================================================
(a) Number of shares of common stock outstanding was 84,108,789 for all periods
presented.
(b) Disclosure of Comprehensive Income:
Revaluation capital
Unrealized investment - gain (loss), net of tax of $(17), $6 and $11,
respectively $ (31) $ 10 $ 21
Net income 340 349 321
-----------------------------
Total Comprehensive Income $ 309 $ 359 $ 342
=============================
THE ACCOMPANYING NOTES ARE AN INTEGRAL PART OF THESE STATEMENTS.
CE-18
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CONSUMERS ENERGY COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
1: CORPORATE STRUCTURE AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
CORPORATE STRUCTURE: Consumers is a combination electric and gas utility company
serving the lower peninsula of Michigan and is a subsidiary of CMS Energy, a
holding company. Consumers' customer base includes a mix of residential,
commercial and diversified industrial customers, the largest segment of which is
the automotive industry.
BASIS OF PRESENTATION: The consolidated financial statements include Consumers
and its wholly owned subsidiaries. The financial statements are prepared in
conformity with generally accepted accounting principles and include the use of
management's estimates. Consumers uses the equity method of accounting for
investments in its companies and partnerships where it has more than a 20
percent but less than a majority ownership interest and includes these results
in operating income.
ACCRETION INCOME AND EXPENSE: In 1991, the MPSC allowed Consumers to recover a
portion of its abandoned Midland investment over a 10-year period, but did not
allow Consumers to earn a return on that amount. Consumers reduced the
recoverable investment to the present value of the future recoveries. During the
recovery period, Consumers adjusts the unrecovered asset to its present value.
It reflects this adjustment as accretion income. Conversely, Consumers recorded
a loss in 1992 for the present value of its estimated future underrecoveries of
power costs resulting from purchases from the MCV Partnership (see Note 2). It
now recognizes accretion expense annually to reflect the time value of money on
the recorded loss.
GAS INVENTORY: Consumers uses the weighted average cost method for valuing
working gas inventory. It records cushion gas, which is gas stored to maintain
reservoir pressure for recovery of working gas, in the appropriate gas utility
plant account. Consumers stores gas inventory in its underground storage
facilities.
MAINTENANCE, DEPRECIATION AND DEPLETION: Consumers charges property repairs and
minor property replacements to maintenance expense. Depreciable property retired
or sold, plus cost of removal (net of salvage credits), is charged to
accumulated depreciation. Consumers bases depreciation provisions for utility
property on straight-line and units-of-production rates approved by the MPSC.
The composite depreciation rate for electric utility property was 3.0 percent
for 1999, 3.5 percent for 1998 and 3.6 percent for 1997. The composite rate for
gas utility property was 4.4 percent for 1999, 4.2 percent for 1998 and 4.1
percent for 1997. The composite rate for other property was 8.6 percent for
1999, 7.4 percent for 1998 and 8.2 percent for 1997.
NUCLEAR FUEL COST: Consumers amortizes nuclear fuel cost to fuel expense based
on the quantity of heat produced for electric generation. Interest on leased
nuclear fuel is expensed as incurred. Under current federal law, as confirmed by
court decision, the DOE was to begin accepting deliveries of spent nuclear fuel
for disposal by January 31, 1998. For fuel used after April 6, 1983, Consumers
charges disposal costs to nuclear fuel expense, recovers them through electric
rates, and then remits them to the DOE quarterly. Consumers elected to defer
payment for disposal of spent nuclear fuel burned before April 7, 1983. At
December 31, 1999, Consumers had a recorded liability to the DOE of $123
million, including interest, which is payable upon the first delivery of spent
nuclear fuel to the DOE. Consumers recovered through electric rates the amount
of this liability, excluding a portion of interest. In January 1997, in response
to the DOE's declaration that it would not begin to accept spent nuclear fuel
deliveries in 1998, Consumers and other utilities filed suit in federal court.
The court issued a decision in late 1997 affirming the DOE's duty to take
delivery of spent fuel, but was not specific as to the relief available for
failure of the DOE to comply. Further litigation brought by Consumers and others
in 1998 that was intended to produce specific relief for the DOE's failure to
comply
CE-19
139
has not been successful to date, although such litigation efforts continue. In
January 1999, federal legislation was reintroduced in the House of
Representatives to clarify the timing of the DOE's obligation to accept spent
nuclear fuel and to direct the DOE to establish an integrated spent fuel
management system that includes designing and constructing an interim storage
facility in Nevada. Similar legislation was reintroduced in the Senate.
Consumers cannot predict the outcome of this process.
NUCLEAR PLANT DECOMMISSIONING: Consumers collected $50 million in 1999 from its
electric customers for decommissioning of its two nuclear plants. Amounts
collected from electric retail customers and deposited in trusts (including
trust earnings) are credited to accumulated depreciation. On March 22, 1999,
Consumers received a decommissioning order from the MPSC that approved estimated
decommissioning costs for Big Rock and Palisades of $315 million and $566
million (calculated in 1999 dollars), respectively. Consumers' site-specific
decommissioning cost estimates for Big Rock and Palisades assume that each plant
site will eventually be restored to conform to the adjacent landscape, and all
contaminated equipment will be disassembled and disposed of in a licensed burial
facility. The MPSC order also set the annual decommissioning surcharges for Big
Rock and Palisades at $32 million and $14 million a year, respectively, and
required Consumers to file revised decommissioning surcharges for Palisades that
incorporate a gradual reduction in the decommissioning trust's equity
investments following the plant's retirement. On December 16, 1999, the MPSC
approved a revised decommissioning surcharge for Palisades in the amount of $6
million a year, effective January 1, 2000.
Big Rock closed permanently in 1997 because management determined that it would
be uneconomical to operate in an increasingly competitive environment. The plant
was originally scheduled to close on May 31, 2000, at the end of the plant's
operating license. The MPSC allowed Consumers to continue collecting
decommissioning surcharges through December 31, 2000. Plant decommissioning
began in 1997 and it may take five to ten years to return the site to its
original condition. For 1999, Consumers incurred costs of $51 million that were
charged to the accumulated depreciation reserve for decommissioning and withdrew
$43 million from the Big Rock nuclear decommissioning trust fund. In total,
Consumers has incurred costs of $126 million that have been charged to the
accumulated depreciation reserve for decommissioning and withdrew $112 million
from the Big Rock nuclear decommissioning trust fund. These activities had no
material impact on net income. At December 31, 1999, Consumers is the
beneficiary of the investment in nuclear decommissioning trust funds of $181
million for Big Rock.
After retirement of Palisades, Consumers plans to maintain the facility in
protective storage if radioactive waste disposal facilities are not available.
Consumers will incur most of the Palisades decommissioning costs after the
plant's NRC operating license expires. When the Palisades' NRC license expires
in 2007, the trust funds are currently estimated to have accumulated $667
million, assuming currently approved MPSC surcharge levels. Consumers estimates
that at the time Palisades is fully decommissioned in the year 2046, the trust
funds will have provided $1.9 billion, including trust earnings, over this
decommissioning period. At December 31, 1999, Consumers is the beneficiary of
the investment in nuclear decommissioning trust funds of $421 million for
Palisades.
RECLASSIFICATIONS: Consumers has reclassified certain prior year amounts for
comparative purposes. These reclassifications did not affect consolidated net
income for the years presented.
RELATED-PARTY TRANSACTIONS: Consumers' investment in Enterprises' preferred
stock was $100 million at December 31, 1999 and $150 million at December 31,
1998. Beginning in 1997, Enterprises commenced a five-year redemption program of
$50 million per year. In addition, Consumers has an investment in 2.9 million
shares of CMS Energy Common Stock with a fair value totaling $90 million at
December 31, 1999 (see Note 5). From these two investments, Consumers received
dividends from affiliates' common and preferred stock totaling $11 million, $14
million, and $17 million in 1999, 1998 and 1997, respectively.
CE-20
140
Consumers purchases a portion of its gas from CMS Oil and Gas. The purchases for
the years ended 1999, 1998 and 1997 were $19 million, $24 million and $25
million, respectively. In 1999, 1998 and 1997, Consumers paid $52 million, $51
million and $51 million, respectively, for electric generating capacity and the
energy generated by that capacity from affiliates of Enterprises. Consumers pays
a portion of its gas transportation costs to Panhandle and its subsidiary
Trunkline. Transportation fees paid for the nine months ended December 31, 1999
following the March 29, 1999 acquisition were $33 million. Consumers and its
subsidiaries sold, stored and transported natural gas and provided other
services to the MCV Partnership totaling $23 million, $13 million and $13
million in 1999, 1998 and 1997, respectively. For additional discussion of
related-party transactions with the MCV Partnership and the FMLP, see Notes 2
and 11. Other related-party transactions are immaterial.
UTILITY REGULATION: Consumers accounts for the effects of regulation based on
the regulated utility accounting standard SFAS 71, Accounting for the Effects of
Certain Types of Regulation. As a result, the actions of regulators affect when
Consumers recognizes revenues, expenses, assets and liabilities.
In March 1999, Consumers received MPSC electric restructuring orders which,
among other things, identified the terms and timing for implementing electric
restructuring in Michigan. Consistent with these orders, Consumers discontinued
application of SFAS 71 for the energy supply portion of its business in the
first quarter of 1999 because Consumers expected to implement retail open access
for its electric customers in September 1999. Discontinuation of SFAS 71 for the
energy supply portion of Consumers' business resulted in Consumers reducing the
carrying value of its Palisades plant-related assets by approximately $535
million and establishing a regulatory asset for a corresponding amount. The
regulatory asset is collectible as part of the Transition Costs which are
recoverable through the regulated transmission and distribution portion of
Consumers' business as approved by an MPSC order in 1998. This order also
allowed Consumers to recover any energy supply-related regulatory assets, plus a
return on any unamortized balance of those assets, from its transmission and
distribution customers. According to current accounting standards, Consumers can
continue to carry its energy supply-related regulatory assets if legislation or
an MPSC rate order allows the collection of cash flows to recover these
regulatory assets from its regulated transmission and distribution customers. At
December 31,1999, Consumers had a net investment in energy supply facilities of
$949 million included in electric plant and property.
SFAS 121, Accounting for the Impairment of Long-Lived Assets and for Long-Lived
Assets to be Disposed of imposes stricter criteria for retention of
regulatory-created assets by requiring that such assets be probable of future
recovery at each balance sheet date. Management believes these assets will be
recovered.
The following regulatory assets (liabilities), which include both current and
non-current amounts, are reflected in the Consolidated Balance Sheets. These
costs are being recovered through rates over periods of up to 13 years.
CE-21
141
In Millions
- ----------------------------------------------------------------------------------------------------------------
December 31 1999 1998
- ----------------------------------------------------------------------------------------------------------------
Postretirement benefits (Note 7) $366 $ 397
Income taxes (Note 4) 193 148
Abandoned Midland project 48 71
Manufactured gas plant sites (Note 2) 65 48
DSM - deferred costs 13 32
Uranium enrichment facility 18 20
Other 33 38
------------------------
Total regulatory assets $736 $ 754
================================================================================================================
Income taxes (Note 4) $(257) $(235)
DSM - deferred revenue (17) (24)
------------------------
Total regulatory liabilities $(274) $(259)
================================================================================================================
RISK MANAGEMENT ACTIVITIES AND DERIVATIVES TRANSACTIONS: Consumers and its
subsidiaries use derivative instruments, including swaps and options, to manage
exposure to fluctuations in interest rates and commodity prices, respectively.
To qualify for hedge accounting, derivatives must meet the following criteria:
1) the item to be hedged exposes the enterprise to price and interest rate risk;
and 2) the derivative reduces that exposure and is designated as a hedge.
Derivative instruments contain credit risk if the counterparties, including
financial institutions and energy marketers, fail to perform under the
agreements. Consumers minimizes such risk by performing financial credit reviews
using, among other things, publicly available credit ratings of such
counterparties. The risk of nonperformance by the counterparties is considered
remote.
Consumers enters into interest rate swap agreements to exchange variable-rate
interest payment obligations for fixed-rate obligations without exchanging the
underlying notional amounts. These agreements convert variable-rate debt to
fixed-rate debt in order to reduce the impact of interest rate fluctuations. The
notional amounts parallel the underlying debt levels and are used to measure
interest to be paid or received and do not represent the exposure to credit
loss.
Consumers enters into electric option contracts to ensure a reliable source of
capacity to meet its customers' electric requirements and to limit its risk
associated with electricity price increases. It is management's intent to take
physical delivery of the commodity. Consumers continuously evaluates its daily
capacity needs and sells the option contracts, if marketable, when it has excess
daily capacity. Consumers' maximum exposure associated with these options is
limited to the price paid.
OTHER: For significant accounting policies regarding income taxes, see Note 4;
for executive incentive compensation, see Note 6; and for pensions and other
postretirement benefits, see Note 7.
IMPLEMENTATION OF NEW ACCOUNTING STANDARDS: In 1998, the American Institute of
Certified Public Accountants issued Statement of Position 98-1, Accounting for
the Costs of Computer Software Developed or Obtained for Internal Use, and
Statement of Position 98-5, Reporting on the Costs of Start-Up Activities. Also
in 1998, the Emerging Issues Task Force published Issue 98-10, Accounting for
Energy Trading and Risk Management Activities. Each of these statements was
effective for 1999. Application of these standards has not had a material affect
on Consumers' financial position, liquidity or results of operations.
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CHANGE IN METHOD OF ACCOUNTING FOR PROPERTY TAXES: During the first quarter of
1998, Consumers implemented a change in the method of accounting for property
taxes so that such taxes are recognized during the fiscal period of the taxing
authority for which the taxes are levied. This change better matches property
tax expense with the services provided by the taxing authorities, and is
considered the most acceptable basis of recording property taxes. Prior to 1998,
Consumers recorded property taxes monthly during the year following the
assessment date (December 31). The cumulative effect of this one-time change in
accounting increased other income in 1998 by $66 million, and earnings, net of
tax, by $43 million. The pro forma effect on prior years' consolidated net
income of retroactively recording property taxes as if the new method of
accounting had been in effect for all periods presented is not material.
2: UNCERTAINTIES
ELECTRIC CONTINGENCIES
ELECTRIC ENVIRONMENTAL MATTERS: The Clean Air Act limits emissions of sulfur
dioxide and nitrogen oxides and requires emissions and air quality monitoring.
Consumers currently operates within these limits and meets current emission
requirements. The Clean Air Act requires the EPA to review periodically the
effectiveness of the national air quality standards in preventing adverse health
effects. In 1997, the EPA revised these standards to impose further limitations
on nitrogen oxide and small particulate-related emissions. In May 1999, a United
States Court of Appeals ruled that the grant of authority to the EPA, to revise
the standards as the EPA did, would amount to an unconstitutional delegation of
legislative power. As a result, the EPA will not implement the standards under
the 1997 rule. On October 28, 1999, the United States Court of Appeals denied a
request by the EPA for a rehearing. On January 27, 2000, the Department of
Justice filed a petition for the United States Supreme Court to review the case.
Because of the United States Court of Appeals decisions, the EPA has proposed to
reinstate the pre-1997 standards.
In September 1998, based in part upon the 1997 standards, the EPA Administrator
issued final regulations requiring the state of Michigan to limit further
nitrogen oxide emissions. Consumers anticipates a reduction in nitrogen oxide
emissions by 2003 to only 32 percent of levels allowed for the year 2000. The
state of Michigan had one year to submit an implementation plan. The state of
Michigan filed a lawsuit objecting to the extent of the required emission
reductions and requesting an extension of the submission date. In May 1999, the
United States Court of Appeals granted an indefinite stay of the submission date
for the state of Michigan's implementation plan. In early 2000, the United
States Court of Appeals upheld the EPA's final regulations. The state of
Michigan is expected to appeal this ruling. Until the appeal is decided, it is
unlikely that the state of Michigan will establish Consumers' nitrogen oxide
emissions reduction target. In December 1999, the EPA Administrator signed a
revised final rule under Section 126 of the Clean Air Act. The rule requires
some electric utility generators, including some of Consumers' electric
generating facilities, to achieve the same emission rate as that required by the
currently challenged September 1998 EPA final rule. Under the revised Section
126 rule, the emission rate will become effective on May 1, 2003 and apply
during the ozone season in 2003 and during each subsequent year. Various
parties' petitions challenging the EPA's rule have been filed. Until these
targets are lawfully established, the estimated cost of compliance discussed
below is subject to revision.
The preliminary estimates of capital expenditures to reduce nitrogen
oxide-related emissions to the level proposed by the state of Michigan for
Consumers' fossil-fueled generating units range from $150 million to $290
million, calculated in 1999 dollars. If Consumers had to meet the EPA's 1997
proposed requirements, the estimated cost to Consumers would be between $290
million and $500 million, calculated in 1999 dollars. In both these cases the
lower estimate represents the capital expenditure level that would
satisfactorily meet the proposed emissions limits but would result in higher
operating expense. The higher estimate in the range includes expenditures that
result in lower operating costs while complying
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with the proposed emissions limit. Consumers anticipates that it will incur
these capital expenditures between 2000 and 2004, or between 2000 and 2003 if
the EPA ultimately imposes its limits.
Consumers may need an equivalent amount of capital expenditures to comply with
the new small particulate standards sometime after 2004 if those standards
become effective.
Consumers' coal-fueled electric generating units burn low-sulfur coal and are
currently operating at or near the sulfur dioxide emission limits that will be
effective in the year 2000. During the past few years, to comply with the Clean
Air Act, Consumers incurred capital expenditures totaling $67 million to install
equipment at certain generating units. Consumers estimates an additional $5
million of capital expenditures for ongoing and proposed modifications at the
remaining coal-fueled units to meet year 2000 requirements. Management believes
that these expenditures will not materially affect Consumers' annual operating
costs.
Under the Michigan Natural Resources and Environmental Protection Act, Consumers
expects that it will ultimately incur investigation and remedial action costs at
a number of sites. Nevertheless, it believes that these costs are properly
recoverable in rates under current ratemaking policies.
Consumers is a potentially responsible party at several contaminated sites
administered under Superfund. Superfund liability is joint and several; along
with Consumers, many other creditworthy, potentially responsible parties with
substantial assets cooperate with respect to the individual sites. Based upon
past negotiations, Consumers estimates that its share of the total liability for
the known Superfund sites will be between $2 million and $9 million. At December
31, 1999, Consumers has accrued the minimum amount of the range for its
estimated Superfund liability.
While decommissioning Big Rock, Consumers found that some areas of the plant
have coatings that contain both metals and PCBs. Consumers believes it now has
viable disposal options for these materials. It estimates the additional cost
associated with PCB waste at $1.5 million. The cost of removal and disposal will
constitute part of the cost to decommission the plant and will be paid from the
decommissioning fund.
ANTITRUST: In October 1997, two independent power producers sued Consumers in a
federal court. The suit alleged antitrust violations relating to contracts which
Consumers entered into with some of its customers, and interference with
contract claims relating to proposed power facilities. On March 31, 1999, the
court issued an opinion and order granting Consumers' motion for summary
judgment, resulting in the dismissal of the case. The plaintiffs have appealed
this decision. Consumers cannot predict the outcome of this appeal.
ELECTRIC RATE MATTERS
ELECTRIC PROCEEDINGS: In 1996, the MPSC issued a final order that authorized
Consumers to recover costs associated with the purchase of the additional 325 MW
of MCV Facility capacity (see "Power Purchases from the MCV Partnership" in this
Note). In addition, the order allowed Consumers to recover its nuclear plant
investment by increasing prospective annual nuclear plant depreciation expense
by $18 million, with a corresponding decrease in fossil-fueled generating plant
depreciation expense. The order also established an experimental direct-access
program. Customers having a maximum demand for electric power of 2 MW or greater
are eligible to purchase generation services directly from any eligible
third-party power supplier. Consumers will transmit that power for a fee.
Delivery of electric power through this direct-access program is limited to 134
MW. In accordance with the MPSC order, Consumers held a lottery to select the
customers that would participate in the direct-access program. Subsequently,
direct-access for a portion of this 134 MW began in late 1997. The program was
substantially filled by the end of March 1999. The Attorney General, ABATE, the
MCV Partnership and other parties filed appeals with the Court of Appeals
challenging the MPSC's 1996 order. In August 1999, the Court of Appeals affirmed
the MPSC's 1996 order in all respects.
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In October 1999, the Attorney General filed an application for leave to appeal
this decision to the Michigan Supreme Court.
In November 1997, ABATE filed a complaint with the MPSC. The complaint alleged
that Consumers' electric earnings are more than its authorized rate of return
and sought an immediate reduction in Consumers' electric rates. In testimony
filed in this case, ABATE claimed that Consumers received approximately $189
million in excess revenues for 1998. In its testimony, the MPSC staff stated
that 1998 financial results show excess revenues of $118 million compared to the
previously authorized electric return on equity. The MPSC staff offered several
alternatives for the MPSC to consider. These alternatives involve several
different refunds or reductions that the MPSC could consider separately or in
combination, but if made, would not result in a permanent future reduction in
electric rates in the amount being sought by ABATE. Consumers filed testimony
showing that after ratemaking adjustments and normalizations, there is a revenue
deficiency of approximately $3 million. ABATE and other interveners bear the
burden of convincing the MPSC to reduce electric rates, which will otherwise
remain unchanged. Consumers believes that ABATE has not met its burden of
proving that a reduction in rates is required. Consumers also believes that
ABATE's request for refunds from 1995 to present is inappropriate and unlawful;
no such retroactive rate adjustment has ever been granted by the MPSC. In
December 1999, an announcement was made that an agreement concerning legislation
in Michigan on electric deregulation had been reached by Consumers, ABATE, and
numerous other industrial and commercial business interests. In anticipation of
the legislation being introduced, ABATE and Consumers jointly filed a request
with the MPSC to suspend ABATE's electric rate complaint to allow for
consideration of the proposed legislation. The MPSC granted a temporary
suspension for 120 days (expiring in April 2000), subject to its authority to
withdraw the suspension at any time. As part of the suspension, Consumers agreed
that, if the case is resumed and a rate reduction is ultimately ordered by the
MPSC, it would implement the rate reduction retroactively for a period equal to
the length of the actual suspension. In January 2000, the legislation was
introduced into the Michigan Legislature.
Consumers is unable to predict the outcome of this matter.
In January 1998, the Court of Appeals affirmed an MPSC conclusion that the MPSC
has statutory authority to authorize an experimental electric retail wheeling
program. In June 1999, the Michigan Supreme Court reversed the Court of Appeals
and held that the MPSC does not have the statutory authority to order a utility
to provide a mandatory retail wheeling service. For more information on the
experimental retail wheeling program see "Electric Restructuring" below.
ELECTRIC RESTRUCTURING: As part of ongoing proceedings relating to the
restructuring of the electric utility industry in Michigan, the MPSC issued
numerous orders since June 1997 proposing that Consumers transmit and distribute
energy for competing power suppliers to retail customers (also known as "retail
open access"). The restructuring orders provide for: 1) recovery of estimated
Stranded Costs of $1.755 billion through a charge to all customers purchasing
their power from other sources until the end of the transition period in 2007,
subject to an adjustment through a true-up mechanism; 2) commencement of the
phase-in of retail open access beginning September 1999; 3) suspension of the
PSCR clause as discussed below; and 4) the right of all customers to choose
their power suppliers on January 1, 2002. The recovery of costs of implementing
a retail open access program, preliminarily estimated at an additional $200
million, will be reviewed for prudence by the MPSC and recovered via a charge
approved by the MPSC. Nuclear decommissioning costs will also continue to be
collected through a separate surcharge to all customers.
Consumers submitted its plan for implementing retail open access to the MPSC in
1998. The primary issues addressed in the plan are: 1) the implementation
schedule; 2) the retail open access service options available to customers and
suppliers; 3) the process and requirements for customers and others to obtain
retail open access service; and 4) the roles and responsibilities for Consumers,
customers and suppliers. In March 1999, Consumers received MPSC electric
restructuring orders, which generally supported Consumers' implementation plan.
Consumers began implementing electric retail customer open access in September
1999,
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and will extend open access to 750 MW of Consumers' retail market by 2001. On
January 1, 2002, all of Consumers' electric customers will have the right to
choose generation suppliers.
Numerous appeals are pending at the Court of Appeals relating to the MPSC's
restructuring orders. Because of the June 1999 Michigan Supreme Court decision
described above in "Electric Proceedings", Consumers believes that the MPSC
lacks statutory authority to mandate industry restructuring. The MPSC ultimately
issued an order in August 1999 finding that it has jurisdiction to approve
rates, terms, and conditions for electricity retail wheeling (also known as
electric customer choice) if a utility voluntarily chooses to offer that
service. ABATE and the Attorney General have each appealed the August 1999 order
to the Court of Appeals. It is uncertain how the issues raised by the MPSC's
August 1999 order will be resolved by the regulatory process, the appellate
courts or by legislation addressing electric restructuring issues.
During periods when electric demand is high, the cost of purchasing energy on
the spot market can be substantial. Consumers is planning to maintain sufficient
generation and to purchase electricity from others to create a power reserve
(also called a reserve margin) that provides Consumers with approximately 15
percent additional power above its anticipated power demands. This allows
Consumers to provide reliable service to its electric service customers and to
protect itself against unscheduled plant outages and unanticipated demand.
Before 1998, the PSCR process provided for the recovery of any prudent and
necessary power supply costs through customer rates, thus minimizing the risk to
shareholders for fluctuations in such costs. In 1998, as a result of an MPSC
order associated with electric restructuring efforts, the PSCR process was
suspended for 4 years. Under the suspension, customers' rates previously subject
to adjustment under the PSCR process, will not be adjusted to reflect the actual
costs of fuel, interchange power and purchased power, through 2001. To reduce
the risk of high energy prices during peak demand periods, Consumers has
employed a strategy of purchasing electric option contracts for the physical
delivery of electricity during the months of June through September in order to
achieve its reserve margin target. Consumers expects to use a similar strategy
in the future. In 1999, Consumers' purchase of electric option contracts cost
approximately $19 million.
In June 1999, Consumers and four other electric utility companies sought
approval from the FERC to form the Alliance RTO. The proposed structure provided
for the creation of a transmission entity that would control, operate and own
transmission facilities of one or more of the member companies, and would
control and operate, but not necessarily own, the transmission facilities of
other companies. The proposal was structured to give the member companies the
flexibility to maintain or divest ownership of their transmission facilities
while ensuring independent operation of the regional transmission system. In
December 1999, the FERC conditionally approved formation of Alliance, but asked
the applicants to make a number of changes in the proposal and to provide
additional information. Among other things, the FERC expressed concern about the
proposed governance of Alliance, its rates and its geographic configuration. On
the same day as the Alliance order, the FERC issued Order No. 2000, which
describes the characteristics the FERC would find acceptable in an RTO. In Order
No. 2000, the FERC declined to mandate that utilities join RTOs, but did order
utilities to make filings in October 2000 and January 2001 declaring their
intentions with respect to RTO membership. Consumers and the Alliance companies
have sought a rehearing on the Alliance order. Consumers is uncertain about the
outcome of the Alliance matter before the FERC and its continued participation
in Alliance.
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OTHER ELECTRIC UNCERTAINTIES
THE MIDLAND COGENERATION VENTURE: The MCV Partnership, which leases and operates
the MCV Facility, contracted to sell electricity to Consumers for a 35-year
period beginning in 1990 and to supply electricity and steam to Dow. Consumers,
through two wholly owned subsidiaries, holds the following assets related to the
MCV Partnership and MCV Facility: 1) CMS Midland owns a 49 percent general
partnership interest in the MCV Partnership; and 2) CMS Holdings holds, through
FMLP, a 35 percent lessor interest in the MCV Facility.
Summarized Statements of Income for CMS Midland and CMS Holdings (unaudited)
In Millions
- ------------------------------------------------------------------------------------------------------------------
Year Ended December 31 1999 1998 1997
- ------------------------------------------------------------------------------------------------------------------
Pretax operating income $49 $49 $46
Income taxes and other 15 15 14
----------------------------------------------------------------
Net income $34 $34 $32
==================================================================================================================
Power Purchases from the MCV Partnership- Consumers' annual obligation to
purchase capacity from the MCV Partnership is 1,240 MW through the termination
of the PPA in 2025. The PPA provides that Consumers is to pay, based on the MCV
Facility's availability, a levelized average capacity charge of 3.77 cents per
kWh, a fixed energy charge, and a variable energy charge based primarily on
Consumers' average cost of coal consumed for all kWh delivered. Since January 1,
1993, the MPSC has permitted Consumers to recover capacity charges averaging
3.62 cents per kWh for 915 MW, plus a substantial portion of the fixed and
variable energy charges. Since January 1, 1996, the MPSC has also permitted
Consumers to recover capacity charges for the remaining 325 MW of contract
capacity with an initial average charge of 2.86 cents per kWh increasing
periodically to an eventual 3.62 cents per kWh by 2004 and thereafter. Because
the MPSC has already approved recovery of these capacity costs, Consumers will
recover these increases through an adjustment to the currently frozen PSCR
factor that will be effective through 2001. Consumers expects to recover the
remaining increases through the Transition Cost true-up process and through
further adjustments to the PSCR factor. After September 2007, under the terms of
the PPA, Consumers will only be required to pay the MCV Partnership capacity and
energy charges that the MPSC has authorized for recovery from electric
customers.
In March 1999, Consumers signed a long-term power sales agreement to resell to
PECO its capacity and energy purchases under the PPA until September 2007. After
a three-year transition period during which 100 to 150 MW will be sold to PECO,
beginning in 2002 Consumers will sell all 1,240 MW of PPA capacity and
associated energy to PECO. In March 1999, Consumers also filed an application
with the MPSC for accounting and ratemaking approvals related to the PECO
agreement. If used as an offset to electric customers' Transition Cost
responsibility, Consumers estimates that there could be a reduction of as much
as $58 million (on a net present value basis) of Transition Cost related to the
MCV PPA. In an order issued in April 1999, the MPSC conditionally approved the
requests for accounting and rate-making treatment to the extent that customer
rates are not increased from the current level absent the agreement and as
modified by the order. In response to Consumers' and other parties' requests for
clarification and rehearing, in an August 1999 opinion, the MPSC partially
granted the relief Consumers requested on rehearing and attached certain
additional conditions to its approval. Those conditions relate to Consumers
continued decision to carry out the electricity customer choice program (which
Consumers has affirmed as discussed above) and a determination to revise its
capacity solicitation process (which Consumers has filed but is awaiting an MPSC
decision). The August opinion is a companion order to a power supply cost
reconciliation order issued on the
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same date in another case. This order affects the level of frozen power supply
costs recoverable in rates during future years when the transaction with PECO
would be taking place. Consumers filed a motion for clarification of the order
relating to the PECO agreement, which is still pending. Due to the pending
electric industry restructuring legislation in Michigan and the overall
uncertainty that exists concerning restructuring, Consumers and PECO have
entered into an interim arrangement for the sale of 125 MW of PPA capacity
associated energy to PECO during 2000. Prices in the interim arrangement are
identical to the March 1999 power sales agreement.
Consumers recognized a loss in 1992 for the present value of the estimated
future underrecoveries of power costs under the PPA based on MPSC recovery
orders. At December 31, 1999 and December 31, 1998, the remaining after-tax
present value of the estimated future PPA liability associated with the 1992
loss totaled $78 million and $110 million, respectively. At December 31, 1999,
the undiscounted after-tax amount associated with this liability totaled $142
million. These after-tax cash underrecoveries are based on the assumption that
the MCV Facility would be available to generate electricity 91.5 percent of the
time over its expected life. Historically the MCV Facility has operated above
the 91.5 percent level. Accordingly, in 1998, Consumers increased its PPA
liability by $37 million. Because the MCV Facility operated above the 91.5
percent level in 1998 and in 1999, Consumers has an accumulated unrecovered
after-tax shortfall of $30 million as of December 31, 1999. Consumers believes
that this shortfall will be resolved in the context of the electric
restructuring effort. If the MCV Facility generates electricity at the 91.5
percent level during the next five years, Consumers' after-tax cash
underrecoveries associated with the PPA would be as follows.
- --------------------------------------------------------------------------------
In Millions
- --------------------------------------------------------------------------------
2000 2001 2002 2003 2004
- --------------------------------------------------------------------------------
Estimated cash underrecoveries, net of tax $21 $20 $19 $18 $17
================================================================================
If the MCV Facility operates at availability levels above management's 91.5
percent estimate made in 1992 for the remainder of the PPA and expected
shortfalls are not resolved in the context of the electric restructuring effort,
Consumers will need to recognize additional losses for future underrecoveries.
In March 1999, Consumers and the MCV Partnership reached an agreement effective
January 1, 1999 that capped availability payments to the MCV Partnership at 98.5
percent. For further discussion on the impact of the frozen PSCR, see "Electric
Restructuring" in this Note. Management is evaluating the adequacy of the
contract loss liability considering actual MCV Facility operations and any other
relevant circumstances.
In February 1998, the MCV Partnership filed a claim of appeal from the January
1998 and February 1998 MPSC orders in the electric utility industry
restructuring. At the same time, the MCV Partnership filed suit in the United
States District Court seeking a declaration that the MPSC's failure to provide
Consumers and the MCV Partnership a certain source of recovery of capacity
payments after 2007 deprived the MCV Partnership of its rights under the Public
Utilities Regulatory Policies Act of 1978. In July 1999, the United States
District Court issued an order granting the MCV Partnership's motion for summary
judgment. The order permanently prohibits enforcement of the restructuring
orders in any manner which denies any utility the ability to recover amounts
paid to qualifying facilities such as the MCV Facility or which precludes the
MCV Partnership from recovering the avoided cost rate. The MPSC has appealed the
United States District Court order. Consumers cannot predict the outcome of this
litigation.
NUCLEAR MATTERS: In January 1997, the NRC issued its Systematic Assessment of
Licensee Performance report for Palisades. The report rated all areas as good.
The NRC suspended this assessment process for all licensees in 1998. Until the
NRC completes its review of processes for assessing performance at nuclear power
plants, the NRC uses the Plant Performance Review to provide an assessment of
licensee performance. Palisades received its annual performance review dated
March 26, 1999 in which the NRC stated that the overall performance at Palisades
was acceptable.
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Palisades' temporary on-site storage pool for spent nuclear fuel is at capacity.
Consequently, Consumers is using NRC-approved steel and concrete vaults,
commonly known as "dry casks", for temporary on-site storage. As of December 31,
1999, Consumers had loaded 18 dry storage casks with spent nuclear fuel at
Palisades. In June 1997, the NRC approved Consumers' process for unloading spent
fuel from a cask previously discovered to have minor weld flaws. Consumers
intends to transfer the spent fuel to a new transportable cask when one is
available.
Consumers maintains insurance against property damage, debris removal, personal
injury liability and other risks that are present at its nuclear generating
facilities. Consumers also maintains coverage for replacement power costs during
prolonged accidental outages at Palisades. Insurance would not cover such costs
during the first 12 weeks of any outage, but would cover most of such costs
during the next 52 weeks of the outage, followed by reduced coverage to 80
percent for 110 additional weeks. If certain covered losses occur at its own or
other nuclear plants similarly insured, Consumers could be required to pay
maximum assessments of $15.5 million in any one year to NEIL; $88 million per
occurrence under the nuclear liability secondary financial protection program,
limited to $10 million per occurrence in any year; and $6 million if nuclear
workers claim bodily injury from radiation exposure. Consumers considers the
possibility of these assessments to be remote.
The NRC requires Consumers to make certain calculations and report on the
continuing ability of the Palisades reactor vessel to withstand postulated
pressurized thermal shock events during its remaining license life, considering
the embrittlement of reactor materials. In December 1996, Consumers received an
interim Safety Evaluation Report from the NRC indicating that the reactor vessel
can be safely operated through 2003 before reaching the NRC's screening criteria
for reactor embrittlement. Consumers believes that with fuel management designed
to minimize embrittlement, it can operate Palisades to the end of its license
life in the year 2007 without annealing the reactor vessel. Nevertheless,
Consumers will continue to monitor the matter.
CAPITAL EXPENDITURES: Consumers estimates electric capital expenditures,
including new lease commitments, of $426 million for 2000, $520 million for
2001, and $473 million for 2002. For further information, see the Capital
Expenditures Outlook section in the MD&A.
COMMITMENTS FOR COAL SUPPLIES: Consumers has entered into coal supply contracts
with various suppliers for its coal-fired generating stations. Under the terms
of these agreements, Consumers is obligated to take physical delivery of the
coal and make payment based upon the contract terms. Consumers' current
contracts have expiration dates that range from 2001 to 2004. Consumers enters
into long-term contracts for approximately 50 to 75 percent of its annual coal
requirements. In 1999, coal purchases totaled $262.5 million of which $197.2
million (75 percent of the tonnage requirement) was under long-term contract.
Consumers supplements its long-term contracts with spot-market purchases.
GAS CONTINGENCIES
GAS ENVIRONMENTAL MATTERS: Under the Michigan Natural Resources and
Environmental Protection Act, Consumers expects that it will ultimately incur
investigation and remedial action costs at a number of sites. These include 23
sites that formerly housed manufactured gas plant facilities, even those in
which it has a partial or no current ownership interest. Consumers has completed
initial investigations at the 23 sites. On sites where Consumers has received
site-wide study plan approvals, it will continue to implement these plans. It
will also work toward closure of environmental issues at sites as studies are
completed. Consumers has estimated its costs related to further investigation
and remedial action for all 23 sites using the Gas Research
Institute-Manufactured Gas Plant Probabilistic Cost Model. Using this model,
Consumers estimates the costs to be between $66 million and $118 million. These
estimates are based on undiscounted 1999 costs. As of December 31, 1999,
Consumers has an accrued liability of $62 million and a regulatory asset of $65
million. Any significant change in assumptions, such as remediation techniques,
nature and extent of contamination,
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and legal and regulatory requirements, could affect the estimate of remedial
action costs for the sites. Consumers defers and amortizes, over a period of ten
years, environmental clean-up costs above the amount currently being recovered
in rates. Rate recognition of amortization expense cannot begin until after a
prudence review in a future general gas rate case. Consumers is allowed current
recovery of $1 million annually. Consumers has initiated lawsuits against
certain insurance companies regarding coverage for some or all of the costs that
it may incur for these sites.
GAS RATE MATTERS
GAS RESTRUCTURING: In December 1997, the MPSC approved Consumers' application to
implement an experimental gas transportation program. The program will extend
over a three-year period, ending March 31, 2001, eventually allowing 300,000
residential, commercial and industrial retail gas sales customers to choose an
alternative gas commodity supplier in direct competition with Consumers. The
program is voluntary and participating natural gas customers are selected on a
first-come, first-served basis, up to a limit of 100,000 per year. As of
December 31, 1999, more than 176,000 customers chose alternative gas suppliers,
representing approximately 42.2 bcf of gas load. Customers choosing to remain as
sales customers of Consumers will not see a rate change in their natural gas
rates. This three-year program: 1) freezes gas distribution rates through March
31, 2001, establishing a gas commodity cost at a fixed rate of $2.84 per mcf; 2)
establishes an earnings sharing mechanism with customers if Consumers' earnings
exceed certain pre-determined levels; and 3) establishes a gas transportation
code of conduct that addresses the relationship between Consumers and marketers,
including its affiliated marketers. In December 1999, the Court of Appeals
affirmed in its entirety the December 1997 MPSC Order. Petitions for rehearing
filed by several parties were subsequently denied by the Court of Appeals.
Consumers contracts to purchase gas to limit its risk associated with gas price
increases. Management's intent is to take physical delivery of the commodity and
failure could result in a significant penalty for nonperformance. At December
31, 1999, Consumers had an exposure to gas price increases if the ultimate cost
of gas was to exceed $2.84 per mcf for the following volumes: 50 percent of its
2000 requirements; and 50 percent of its first quarter 2001 requirements.
Additional contract coverage is currently under review. The gas purchase
contracts currently in place were consummated at an average price of less than
$2.84 per mcf. Consumers uses gas purchase contracts to protect against gas
price increases in a three-year experimental gas program where Consumers is
recovering from its customers $2.84 per mcf for gas.
OTHER GAS UNCERTAINTIES
CAPITAL EXPENDITURES: Consumers estimates gas capital expenditures, including
new lease commitments, of $113 million for 2000, $130 million for 2001, and $127
million for 2002. For further information, see the Capital Expenditures Outlook
section in the MD&A.
COMMITMENTS FOR GAS SUPPLIES: Consumers contracts to purchase gas and
transportation from various suppliers for its natural gas business. These
contracts have expiration dates that range from 2000 to 2004. Consumers' 1999
gas requirements totaled 200 bcf at a cost of $542 million, 80 percent of which
was under long-term contracts for one year or more. As of the end of 1999,
Consumers had 50 percent of its 2000 gas requirements under such long-term
contracts, and will supplement them with additional long-term and short-term
contracts and spot-market purchases.
OTHER UNCERTAINTIES
In addition to the matters disclosed in this note, Consumers and certain of its
subsidiaries are parties to certain lawsuits and administrative proceedings
before various courts and governmental agencies arising from the
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ordinary course of business. These lawsuits and proceedings may involve personal
injury, property damage, contractual matters, environmental issues, federal and
state taxes, rates, licensing and other matters.
Consumers has accrued estimated losses for certain contingencies discussed in
this Note. Resolution of these contingencies is not expected to have a material
adverse impact on Consumers' financial position, liquidity, or results of
operations.
3: SHORT-TERM FINANCINGS AND CAPITALIZATION
AUTHORIZATION: At February 1, 2000, Consumers had FERC authorization to issue or
guarantee through June 2000, up to $900 million of short-term securities
outstanding at any one time. Consumers also had remaining FERC authorization to
issue through June 2000, up to $275 million and $365 million of long-term
securities with maturities up to 30 years for refinancing purposes and for
general corporate purposes, respectively.
SHORT-TERM FINANCINGS: Consumers has an unsecured $300 million credit facility
and unsecured lines of credit aggregating $135 million. These facilities are
available to finance seasonal working capital requirements and to pay for
capital expenditures between long-term financings. At December 31, 1999, a total
of $214 million was outstanding at a weighted average interest rate of 6.6
percent, compared with $215 million outstanding at December 31, 1998, at a
weighted average interest rate of 5.8 percent. In January 1999, Consumers
renegotiated a variable-to-fixed interest rate swap totaling $175 million. In
September 1999, Consumers entered into two variable-to-fixed interest rate swaps
totaling $740 million; this amount was reduced by $70 million to $670 million by
December 31, 1999 and terminated January 31, 2000.
Consumers also has in place a $325 million trade receivables sale program. At
December 31, 1999 and 1998, receivables sold under the program totaled $325
million and $306 million, respectively. Accounts receivable and accrued revenue
in the Consolidated Balance Sheets have been reduced to reflect receivables
sold.
LONG-TERM FINANCINGS: Consumers issued long-term bank debt of $15 million in
February 1999, maturing in February 2002, at an initial interest rate of 5.3
percent. For detailed information about long-term financing, see the
Consolidated Statements of Long-Term Debt.
In May 1999, Michigan Gas Storage repaid its $20 million outstanding term loan
with Toronto Dominion Bank.
FIRST MORTGAGE BONDS: Consumers secures its First Mortgage Bonds by a mortgage
and lien on substantially all of its property. Consumers' ability to issue and
sell securities is restricted by certain provisions in its First Mortgage Bond
Indenture, its Articles of Incorporation and the need for regulatory approvals
to meet appropriate federal law.
In November 1999, $64 million of Consumers' First Mortgage Bonds matured and
were retired.
PREFERRED SECURITIES: On April 1, 1999, Consumers redeemed all 8 million
outstanding shares of its $2.08 preferred stock at $25.00 per share for a total
of $200 million.
In October 1999, 7 million shares of 9.25 percent Trust Preferred Securities
were issued and sold through Consumers Energy Company Financing III, a wholly
owned business trust consolidated with Consumers. Net proceeds from the sale
totaled approximately $169 million. Consumers formed the trust for the sole
purpose of issuing the Trust Preferred Securities. Consumers' obligations with
respect to the Trust Preferred Securities under the related tax-deductible
notes, under the indenture through which Consumers issued the notes, under
Consumers' guarantee of the Trust Preferred Securities, and under the
declaration by the trust, taken together,
CE-31
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constitute a full and unconditional guarantee by Consumers of the trust's
obligations under the Trust Preferred Securities.
OTHER: Consumers has a total of $131 million of long-term pollution control
revenue bonds outstanding, secured by first mortgage bonds and insurance
policies. These bonds had a weighted average interest rate of 5.1 percent at
December 31, 1999.
Under the provisions of its Articles of Incorporation, Consumers had $359
million of unrestricted retained earnings available to pay common dividends at
December 31, 1999. In January 2000, Consumers declared and paid a $79 million
common dividend.
4: INCOME TAXES
Consumers and its subsidiaries file a consolidated federal income tax return
with CMS Energy. Income taxes are generally allocated based on each company's
separate taxable income. Consumers practices full deferred tax accounting for
temporary differences as authorized by the MPSC.
Consumers used ITC to reduce current income taxes payable, and defers and
amortizes ITC over the life of the related property. Any AMT paid generally
becomes a tax credit that Consumers can carry forward indefinitely to reduce
regular tax liabilities in future periods when regular taxes paid exceed the tax
calculated for AMT. The significant components of income tax expense (benefit)
consisted of:
In Millions
- ----------------------------------------------------------------------------------------------------------------
Years Ended December 31 1999 1998 1997
- ----------------------------------------------------------------------------------------------------------------
Current federal income taxes $170 $138 $139
Deferred income taxes, includes $23 for 1998 change
in accounting (Note 1) 11 36 23
Deferred ITC, net (9) (16) (10)
-------------------------------------------
$172 $158 $152
================================================================================================================
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The principal components of Consumers' deferred tax assets (liabilities)
recognized in the balance sheet are as follows:
In Millions
- -----------------------------------------------------------------------------------------------------------------
December 31 1999 1998
- ----------------------------------------------------------------------------------------------------------------
Property $ (587) $ (563)
Unconsolidated investments (230) (248)
Postretirement benefits (Note 7) (128) (139)
Abandoned Midland project (17) (25)
Employee benefit obligations, includes postretirement benefits
of $134 and $139 (Note 7) 171 172
Power purchases (Note 2) 42 59
AMT carryforward 48 64
Other 9 5
----------------------------
$ (692) $ (675)
================================================================================================================
Gross deferred tax liabilities $ (1,388) $ (1,377)
Gross deferred tax assets 696 702
----------------------------
$ (692) $ (675)
================================================================================================================
The actual income tax expense differs from the amount computed by applying the
statutory federal tax rate to income before income taxes as follows:
In Millions
- -----------------------------------------------------------------------------------------------------------------
Years Ended December 31 1999 1998 1997
- ----------------------------------------------------------------------------------------------------------------
Net income $ 340 $ 349 $ 321
Income tax expense, includes $23 for 1998 change
in accounting (Note 1) 172 158 152
Preferred securities distributions (21) (18) (12)
----------------------------------------------
Pretax income 491 489 461
Statutory federal income tax rate x35% x35% x35%
----------------------------------------------
Expected income tax expense 172 171 161
Increase (decrease) in taxes from
Capitalized overheads previously flowed through 5 5 5
Differences in book and tax depreciation
not previously deferred 19 14 14
ITC amortization/adjustments (9) (16) (10)
Affiliated companies' dividends (4) (5) (6)
Other, net (11) (11) (12)
-----------------------------------------------
Actual income tax expense $ 172 $ 158 $ 152
================================================================================================================
Effective tax rate 35.0% 32.3% 32.9%
================================================================================================================
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5: FINANCIAL INSTRUMENTS
The carrying amounts of cash, short-term investments and current liabilities
approximate their fair values due to their short-term nature. The estimated fair
values of long-term investments are based on quoted market prices or, in the
absence of specific market prices, on quoted market prices of similar
investments or other valuation techniques. The carrying amounts of all long-term
investments, except as shown below, approximate fair value.
In Millions
- ---------------------------------------------------------------------------------------------------------------
December 31 1999 1998
- ---------------------------------------------------------------------------------------------------------------
Fair Unrealized Fair Unrealized
Available-for-sale securities Cost Value Gain Cost Value Gain
- ---------------------------------------------------------------------------------------------------------------
Common stock of CMS Energy (a) $ 42 $ 90 $ 48 $ 43 $ 142 $ 99
SERP 20 28 8 18 25 7
Nuclear decommissioning
investments (b) 448 602 154 425 557 132
===============================================================================================================
(a) As of February 17, 2000, the fair value of Consumers investment in CMS
Energy common stock is $53 million.
(b) Consumers classifies its unrealized gains and losses on nuclear
decommissioning investments in accumulated depreciation.
The carrying amount of long-term debt was $2.0 billion at December 31, 1999 and
$2.0 billion at December 31, 1998, and the fair values were $1.9 billion and
$2.0 billion, respectively. For held-to-maturity securities and related-party
financial instruments, see Note 1.
6: EXECUTIVE INCENTIVE COMPENSATION
Consumers participates in CMS Energy's Performance Incentive Stock Plan. Under
the plan, restricted shares of Common Stock of CMS Energy, stock options and
stock appreciation rights related to Common Stock may be granted to key
employees based on their contributions to the successful management of CMS
Energy and its subsidiaries. Awards under the plan may consist of any class of
Common Stock of CMS Energy. Certain plan awards are subject to performance-based
business criteria. The plan reserves for award not more than five percent, as
amended January 1, 1999, of CMS Energy's Common Stock outstanding on January 1
each year, less (1) the number of shares of restricted Common Stock awarded and
(2) Common Stock subject to options granted under the plan during the
immediately preceding four calendar years. The number of shares of restricted
Common Stock awarded under this plan cannot exceed 20% of the aggregate number
of shares reserved for award. Any forfeiture of shares previously awarded will
increase the number of shares available to be awarded under the plan. At
December 31, 1999, awards of up to 2,466,524 shares of CMS Energy Common Stock
may be issued.
Restricted shares of Common Stock are outstanding shares with full voting and
dividend rights. These awards vest over five years at the rate of 25 percent per
year after two years. The restricted shares are subject to achievement of
specified levels of total shareholder return and are subject to forfeiture if
employment terminates before vesting. If performance objectives are exceeded,
the plan provides additional awards. Restricted shares vest fully if control of
CMS Energy changes, as defined by the plan. At December 31, 1999,
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208,557 of the 283,057 shares of restricted CMS Energy Common Stock outstanding
are subject to performance objectives.
The plan grants stock options and stock appreciation rights relating to Common
Stock with an exercise price equal to the closing market price on each grant
date. Some options may be exercised upon grant; others vest over five years at
the rate of 25 percent per year after one year. All options expire up to ten
years and one month from date of grant. In 1999, all outstanding Class G Common
Stock and options were converted to CMS Energy Common Stock and options at an
exchange rate of .7041 per Class G Common Stock or option held. The original
vesting or exercise period was retained for all converted shares or options. The
status of the restricted stock and options granted to Consumers' key employees
under the Performance Incentive Stock Plan follows.
Restricted
Stock Options
- --------------------------------------------------------------------------------------------------------------
Number Number Weighted Average
CMS ENERGY COMMON STOCK of Shares of Shares Exercise Price
- --------------------------------------------------------------------------------------------------------------
Outstanding at January 1, 1997 277,366 762,745 $ 26.55
Granted 165,942 152,352 $ 35.97
Exercised or Issued (73,375) (377,317) $ 27.21
Forfeited (59,582) -
---------------------------------------------------------
Outstanding at December 31, 1997 310,351 537,780 $ 28.84
Granted 92,319 116,164 $ 43.38
Exercised or Issued (74,319) (123,288) $ 28.05
---------------------------------------------------------
Outstanding at December 31, 1998 328,351 530,656 $ 32.21
Granted 71,025 250,020 $ 38.56
Exercised or Issued (80,489) (68,609) $ 29.76
Forfeited (41,890) -
Expired - (37,900) $ 39.21
Class G Common Stock Converted 6,060 19,503 $ 32.64
---------------------------------------------------------
Outstanding at December 31, 1999 283,057 693,670 $ 34.37
==============================================================================================================
Restricted
Stock Options
- --------------------------------------------------------------------------------------------------------------
Number Number Weighted Average
CLASS G COMMON STOCK of Shares of Shares Exercise Price
- --------------------------------------------------------------------------------------------------------------
Outstanding at January 1, 1997 16,347 21,000 $ 17.88
Granted 8,784 12,000 $ 20.24
Exercised or Issued (1,385) (5,000) $ 17.88
Forfeited (3,955) -
--------------------------------------------------------
Outstanding at December 31, 1997 19,791 28,000 $ 18.89
Granted 14,720 45,900 $ 24.50
Exercised or Issued (4,021) -
--------------------------------------------------------
Outstanding at December 31, 1998 30,490 73,900 $ 22.37
Granted 3,427 -
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Exercised or Issued (7,360) (19,000) $18.45
Forfeited (17,949) -
Expired - (27,200) $24.50
Converted to CMS Energy Common Stock (8,608) (27,700) $22.98
---------------------------------------------------------
Outstanding at December 31, 1999 - - -
==============================================================================================================
The following table summarizes information about CMS Energy Common Stock options
outstanding at December 31, 1999:
Number Weighted Weighted
Range of of Shares Average Average
Exercise Prices Outstanding Remaining Life Exercise Price
- ----------------------------------------------------------------------------------------------------------------
CMS Energy Common Stock:
$17.13 - $27.61 157,076 4.00 years $23.09
$30.63 - $38.00 232,410 6.84 years $33.81
$39.06 - $43.38 304,184 9.26 years $40.60
- ----------------------------------------------------------------------------------------------------------------
$17.13 - $43.38 693,670 7.26 years $34.37
================================================================================================================
The weighted average fair value of options granted for CMS Energy Common Stock
was $6.08 in 1999, $6.43 in 1998, and $6.38 in 1997. The weighted average fair
value of options granted for Class G Common Stock was $3.03 in 1998 and $1.87 in
1997. Fair value is estimated using the Black-Scholes model, a mathematical
formula used to value options traded on securities exchanges, with the following
assumptions:
Years Ended December 31 1999 1998 1997
- ----------------------------------------------------------------------------------------------------------------
CMS ENERGY COMMON STOCK OPTIONS
Risk-free interest rate 5.66% 5.45% 6.06%
Expected stock price volatility 16.96% 15.93% 17.43%
Expected dividend rate $ .365 $ .33 $ .30
Expected option life 4.7 years 4 years 5 years
CLASS G COMMON STOCK OPTIONS
Risk-free interest rate 5.44% 6.06%
Expected stock price volatility 20.02% 18.05%
Expected dividend rate $ .325 $ .31
Expected option life 5 years 5 years
================================================================================================================
Consumers applies Accounting Principles Board Opinion 25 and related
interpretations in accounting for the Performance Incentive Stock Plan. Since
stock options are granted at market price, no compensation cost has been
recognized for stock options granted under the plan. If compensation cost for
stock options had been determined in accordance with SFAS 123, Accounting for
Stock-Based Compensation, Consumers' net income would have decreased by less
than $1 million for 1999, 1998 and 1997. The compensation cost charged against
income for restricted stock was $3 million in 1999, $4 million in 1998, and $2
million in 1997.
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7: RETIREMENT BENEFITS
Consumers provides retirement benefits under a number of different plans,
including certain health care and life insurance benefits under OPEB, benefits
to certain management employees under SERP, and benefits to substantially all
its employees under a trusteed, non-contributory, defined benefit Pension Plan,
and a defined contribution 401(k) plan.
Amounts presented below for the Pension Plan include amounts for employees of
CMS Energy and non-utility affiliates which were not distinguishable from the
plan's total assets.
Weighted-Average Assumptions
- -------------------------------------------------------------------------------------------------------------------
Pension & SERP OPEB
Years Ended December 31 1999 1998 1997 1999 1998 1997
- -------------------------------------------------------------------------------------------------------------------
Discount rate 7.75% 7.00% 7.50% 7.75% 7.00% 7.50%
Expected long-term rate
of return on plan assets 9.25% 9.25% 9.25% 7.00% 7.00% 7.00%
Rate of compensation increase:
Pension - to age 45 5.25% 5.25% 5.25%
- age 45 to
assumed retirement 3.75% 3.75% 3.75%
SERP 5.50% 5.50% 5.50%
===================================================================================================================
Retiree health care costs at December 31, 1999 are based on the assumption that
costs would increase 7.0 percent in 2000, then decrease gradually to 5.5 percent
in 2006 and thereafter.
CMS Energy's Net Pension Plan, Consumers' SERP and OPEB benefit costs consist
of:
In Millions
- -------------------------------------------------------------------------------------------------------------------
Pension & SERP OPEB
Years Ended December 31 1999 1998 1997 1999 1998 1997
- -------------------------------------------------------------------------------------------------------------------
Service cost $ 32 $ 26 $ 25 $12 $10 $ 9
Interest expense 69 61 60 44 42 40
Expected return on plan assets (84) (73) (70) (24) (17) (12)
Amortization of unrecognized transition (asset) (5) (5) (5) - - -
Ad Hoc Retiree Increase 3 - - - - -
Amortization of prior service cost 4 4 4 (1) (1) -
--------------------------------------------------------
Net periodic pension and
postretirement benefit cost $ 19 $13 $14 $31 $34 $37
===================================================================================================================
The health care cost trend rate assumption significantly affects the amounts
reported. A one percentage point change in the assumed health care cost trend
assumption would have the following effects:
In Millions
- -------------------------------------------------------------------------------------------------------------------
One Percentage One Percentage
Point Increase Point Decrease
- -------------------------------------------------------------------------------------------------------------------
Effect on total service and interest cost component $ 10 $ (8)
Effect on postretirement benefit obligation $ 98 $(82)
===================================================================================================================
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The funded status of the CMS Energy Pension Plan, Consumers' SERP and OPEB is
reconciled with the liability recorded at December 31 as follows:
In Millions
- -------------------------------------------------------------------------------------------------------------------
Pension Plan SERP OPEB
1999 1998 1999 1998 1999 1998
- -------------------------------------------------------------------------------------------------------------------
Benefit obligation January 1 $ 874 $ 792 $ 21 $ 18 $ 643 $ 570
Service cost 31 25 1 1 12 10
Interest cost 68 60 1 1 44 42
Plan amendments 4 - - - - -
Business combinations 70 - - - - -
Actuarial loss (gain) 3 76 (3) 2 17 49
Benefits paid (79) (79) (1) (1) (31) (28)
-------------------------------------------------------------
Benefit obligation December 31 971 874 19 21 685 643
-------------------------------------------------------------
Plan assets at fair value at January 1 970 882 - - 321 219
Actual return on plan assets 120 167 - - 49 54
Company contribution - - - - 48 48
Business combinations 83 - - - - -
Actual benefits paid (79) (79) - - - -
-------------------------------------------------------------
Plan assets at fair
value at December 31 1,094(a) 970(a) - - 418 321
-------------------------------------------------------------
Benefit obligation less than
(in excess of) plan assets 123 96 (19) (21) (267) (322)
Unrecognized net (gain) loss from
experience different than assumed (212) (176) 2 4 (79) (71)
Unrecognized prior service cost 28 31 1 1 (1) (1)
Unrecognized net transition (asset) obligation (11) (16) - - - -
-------------------------------------------------------------
Recorded liability $ (72) $ (65) $ (16) $(16) $ (347) $ (394)
===================================================================================================================
(a) Primarily stocks and bonds, including $108 million in 1999 and $168 million
in 1998 of CMS Energy Common Stock.
SERP benefits are paid from a trust established in 1988. SERP is not a qualified
plan under the Internal Revenue Code, and as such, earnings of the trust are
taxable and trust assets are included in consolidated assets. At December 31,
1999 and 1998, trust assets were $28 million and $25 million, respectively, and
were classified as other non-current assets. The accumulated benefit obligation
for SERP was $13 million in 1999 and $14 million in 1998.
Contributions to the 40l(k) plan are invested in CMS Energy Common Stock.
Amounts charged to expense for this plan were $16 million in 1999, $15 million
in 1998, and $18 million in 1997.
Beginning January 1, 1986, the amortization period for the Pension Plan's
unrecognized net transition asset is 16 years and 11 years for the SERP's
unrecognized net transition obligation. Prior service costs are amortized on a
straight-line basis over the average remaining service period of active
employees.
Consumers adopted the required accounting for postretirement benefits effective
in 1992 and recorded a liability of $466 million for the accumulated transition
obligation and a corresponding regulatory asset for
CE-38
158
anticipated recovery in utility rates (see Note 1, Utility Regulation). The MPSC
authorized recovery of the electric utility portion of these costs in 1994 over
18 years and the gas utility portion in 1996 over 16 years. At December 31,
1999, Consumers had a recorded FERC regulatory asset and liability of $5
million. The FERC has authorized recovery of these costs.
8: LEASES
Consumers leases various assets, including vehicles, rail cars, aircraft,
construction equipment, computer equipment, nuclear fuel and buildings. In
November 1999, Consumers was granted an extension to the nuclear fuel capital
leasing arrangement. The lease expires in November 2001, yet provides for
additional one-year extensions upon mutual agreement by the parties. Upon
termination of the lease, the lessor would be entitled to a cash payment equal
to its remaining investment, which was $58 million as of December 31, 1999.
Consumers generally is responsible for payment of taxes, maintenance, operating
costs, and insurance.
Minimum rental commitments under Consumers' non-cancelable leases at December
31, 1999, were:
In Millions
- ----------------------------------------------------------------------------------------------------------------
Capital Leases Operating Leases
- ----------------------------------------------------------------------------------------------------------------
2000 $ 45 $ 14
2001 56 13
2002 17 11
2003 14 11
2004 11 8
2005 and thereafter 10 53
------------------------------------
Total minimum lease payments 153 $110
====
Less imputed interest 33
---
Present value of net minimum lease payments 120
Less current portion 35
---
Non-current portion $ 85
================================================================================================================
Consumers recovers lease charges from customers and accordingly charges payments
for its capital and operating leases to operating expense. Operating lease
charges, including charges to clearing and other accounts for the years ended
December 31, 1999, 1998 and 1997, were $14 million, $11 million and $3 million,
respectively.
Capital lease expenses for the years ended December 31, 1999, 1998 and 1997 were
$41 million, $41 million and $49 million, respectively. Included in these
amounts, for the years ended 1999, 1998 and 1997, are nuclear fuel lease
expenses of $23 million, $23 million and $31 million, respectively.
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159
9: JOINTLY OWNED UTILITY FACILITIES
Consumers is responsible for providing its share of financing for the jointly
owned utility facilities. Consumers includes in operating expenses the direct
expenses of the joint plants. The following table indicates the extent of
Consumers' investment in jointly owned utility facilities:
In Millions
- ------------------------------------------------------------------------------------------------------------------
Net Investment Accumulated Depreciation
December 31 1999 1998 1999 1998
- ------------------------------------------------------------------------------------------------------------------
Campbell Unit 3 - 93.3 percent $284 $299 $295 $279
Ludington - 51 percent 104 106 100 94
Transmission lines - various 32 33 16 15
==================================================================================================================
10: REPORTABLE SEGMENTS
Consumers has two reportable segments: electric and gas. The electric segment
consists of regulated activities associated with the generation, transmission
and distribution of electricity. The gas segment consists of regulated
activities associated with the transportation, storage and distribution of
natural gas. Consumers' reportable segments are domestic strategic business
units organized and managed by the nature of the product and service each
provides. The accounting policies of the segments are the same as those
described in the summary of significant accounting policies. Consumers'
management evaluates performance based on pretax operating income. The
Consolidated Statements of Income show operating revenue and pretax operating
income by reportable segment. These amounts include earnings from investments
accounted for by the equity method of $50 million, $50 million and $49 million
for 1999, 1998 and 1997, respectively. Consumers had investments accounted for
by the equity method of $487 million, $449 million and $420 million for 1999,
1998 and 1997, respectively. In 1998, Consumers implemented a change in the
method of accounting for property taxes. The cumulative effect of this one-time
change in accounting increased electric and gas earnings, net of tax, by $31
million and $12 million, respectively. Intersegment sales and transfers are
accounted for at current market prices and are eliminated in consolidated pretax
operating income by segment. Other segment information follows:
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160
In Millions
- ------------------------------------------------------------------------------------------------------------------
Years Ended December 31 1999 1998 1997
- ------------------------------------------------------------------------------------------------------------------
Depreciation, depletion and amortization
Electric $ 315 $ 304 $ 296
Gas 107 97 93
Other 2 2 2
-------------------------------------------------
Total Consolidated $ 424 $ 403 $ 391
==================================================================================================================
Interest Charges
Electric $133 $129 $123
Gas 48 44 41
Other 19 19 19
-------------------------------------------------
Subtotal 200 192 183
Eliminations (19) (17) (10)
-------------------------------------------------
Total Consolidated $181 $175 $173
==================================================================================================================
Income Taxes
Electric $126 $110 $103
Gas 41 35 45
Other (a) 5 23 4
-------------------------------------------------
Total Consolidated $172 $158 $152
==================================================================================================================
Total assets
Electric (b) $4,675 $4,640 $4,472
Gas (b) 1,731 1,726 1,644
Other 764 797 833
-------------------------------------------------
Total Consolidated $7,170 $7,163 $6,949
==================================================================================================================
Capital expenditures (c)
Electric $ 385 $ 331 $ 255
Gas 120 114 116
-------------------------------------------------
Total $ 505 $ 445 $ 371
==================================================================================================================
(a) 1998 amount includes the tax effect of the change in accounting method for
property taxes.
(b) Amounts include an attributed portion of Consumers' other common assets to
both the electric and gas utility businesses.
(c) Includes electric restructuring implementation plan, capital leases for
nuclear fuel and other assets and electric DSM costs. Amounts also include an
attributed portion of Consumers' capital expenditures for plant and equipment
common to both the electric and gas utility businesses.
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11: SUMMARIZED FINANCIAL INFORMATION OF SIGNIFICANT RELATED ENERGY
SUPPLIER
Under the PPA with the MCV Partnership discussed in Note 2, Consumers' 1999
obligation to purchase electric capacity from the MCV Partnership provided 15.5
percent of Consumers' owned and contracted electric generating capacity.
Summarized financial information of the MCV Partnership follows:
STATEMENTS OF INCOME (UNAUDITED)
In Millions
- -------------------------------------------------------------------------------------------------------------------
Years Ended December 31 1999 1998 1997
- -------------------------------------------------------------------------------------------------------------------
Operating revenue (a) $ 617 $ 627 $ 652
Operating expenses 401 405 435
--------------------------------------
Operating income 216 222 217
Other expense, net 136 142 154
--------------------------------------
Net income before cumulative effect of accounting change 80 80 63
Cumulative effect of change in method of accounting for property tax - - 15
--------------------------------------
Net income $ 80 $ 80 $ 78
===================================================================================================================
BALANCE SHEETS (UNAUDITED)
In Millions
- -------------------------------------------------------------------------------------------------------------------
December 31 1999 1998 1999 1998
- -------------------------------------------------------------------------------------------------------------------
ASSETS LIABILITIES AND EQUITY
Current assets (b) $ 397 $ 341 Current liabilities $ 275 $ 204
Plant, net 1,732 1,773 Noncurrent liabilities (c) 1,586 1,725
Other assets 170 173 Partners' equity (d) 438 358
--------------------- -----------------------
$2,299 $2,287 $2,299 $2,287
===================================================================================================================
(a) Revenue from Consumers totaled $586 million, $584 million and $609 million
for 1999, 1998, and 1997, respectively.
(b) Receivables from Consumers totaled $49, each year, at December 31, 1999 and
1998.
(c) FMLP is the sole beneficiary of an owner trust that is the lessor in a
long-term direct finance lease with the lessee, MCV Partnership. CMS Holdings
holds a 46.4 percent ownership interest in FMLP. At December 31, 1999 and 1998,
lease obligations of $1.36 billion and $1.41 billion, respectively, were owed to
the owner trust. CMS Holdings' share of the interest and principal portion for
the 1999 lease payments was $55 million and $23 million, respectively, and for
the 1998 lease payments was $59 million and $49 million, respectively. The lease
payments service $854 million and $907 million in non-recourse debt outstanding
as of December 31, 1999 and 1998, respectively, of the owner-trust. FMLP's debt
is secured by the MCV Partnership's lease obligations, assets, and operating
revenues. For 1999 and 1998, the owner-trust made debt payments (including
interest) of $167 million and $233 million, respectively. FMLP's earnings for
1999, 1998, and 1997 were $24 million, $23 million, and $20 million,
respectively.
CE-42
162
(d) CMS Midland's recorded investment in the MCV Partnership includes
capitalized interest, which is being amortized to expense over the life of its
investment in the MCV Partnership. Covenants contained in financing agreements
prohibit the MCV Partnership from paying distributions until certain financial
test requirements are met. Consumers does not anticipate receiving a cash
distribution in the near future.
12: SUPPLEMENTAL CASH FLOW INFORMATION
Changes in other assets and liabilities as shown on the Consolidated Statements
of Cash Flows are described below:
In Millions
- ----------------------------------------------------------------------------------------------------------------
Years Ended December 31 1999 1998 1997
- ----------------------------------------------------------------------------------------------------------------
Accounts payable $ 36 $ 19 $(30)
Non-current deferred amounts, net 32 2 38
Accrued revenue 22 (12) 20
Sale of receivables, net 19 (29) 17
Inventories 5 (34) (10)
Accrued refunds - (1) 4
Other current assets and liabilities, net (3) (3) 22
Accounts receivable (29) 7 31
------------------------------------------
$ 82 $ (51) $ 92
================================================================================================================
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163
Report of Independent Public Accountants
To Consumers Energy Company:
We have audited the accompanying consolidated balance sheets and consolidated
statements of long-term debt and preferred stock of CONSUMERS ENERGY COMPANY (a
Michigan corporation and wholly owned subsidiary of CMS Energy Corporation) and
subsidiaries as of December 31, 1999 and 1998, and the related consolidated
statements of income, common stockholder's equity and cash flows for each of the
three years in the period ended December 31, 1999. These financial statements
are the responsibility of the Company's management. Our responsibility is to
express an opinion on these financial statements based on our audits.
We conducted our audits in accordance with generally accepted auditing
standards. Those standards require that we plan and perform the audit to obtain
reasonable assurance about whether the financial statements are free of material
misstatement. An audit includes examining, on a test basis, evidence supporting
the amounts and disclosures in the financial statements. An audit also includes
assessing the accounting principles used and significant estimates made by
management, as well as evaluating the overall financial statement presentation.
We believe that our audits provide a reasonable basis for our opinion.
In our opinion, the financial statements referred to above present fairly, in
all material respects, the financial position of Consumers Energy Company and
subsidiaries as of December 31, 1999 and 1998, and the results of their
operations and their cash flows for each of the three years in the period ended
December 31, 1999 in conformity with generally accepted accounting principles.
As explained in Note 1 to the financial statements, effective January 1, 1998,
Consumers Energy Company changed its method of accounting for property taxes.
/s/ Arthur Andersen LLP
Detroit, Michigan,
February 4, 2000.
CE-44
164
QUARTERLY FINANCIAL INFORMATION CONSUMERS ENERGY COMPANY
In Millions
1999 (Unaudited) 1998 (Unaudited)
Quarters Ended March 31 June 30 Sept. 30 Dec. 31 March 31 June 30 Sept. 30 Dec. 31
- -------------------------------------------------------------------------------------------------------------------------
Operating revenue $1,156 $850 $878 $990 $1,052 $832 $860 $965
Pretax operating income $227 $149 $175 $124 $183 $141 $171 $154
Net income before cumulative
effect of change in accounting
principle $119 $73 $93 $55 $69 $69 $86 $82
Cumulative effect of change
in accounting for property
taxes, net of $23 tax - - - - $43 - - -
Net income $119 $73 $93 $55 $112 $69 $86 $82
Preferred stock dividends $5 - - $1 $5 $5 $5 $4
Preferred securities
distributions $5 $5 $5 $6 $5 $4 $4 $5
Net income available to
common stockholder $109 $68 $88 $48 $102 $60 $77 $73
- -------------------------------------------------------------------------------------------------------------------------
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[PANHANDLE EASTERN PIPE LINE COMPANIES LOGO]
1999 FINANCIAL STATEMENTS
PE-1
167
PANHANDLE EASTERN PIPE LINE COMPANY
MANAGEMENT'S DISCUSSION AND ANALYSIS
Panhandle is primarily engaged in the interstate transportation and storage of
natural gas. Panhandle owns a LNG regasification plant and related tanker port
unloading facilities and LNG and gas storage facilities. The rates and
conditions of service of interstate natural gas transmission, storage and LNG
operations of Panhandle are subject to the rules and regulations of the FERC.
This report contains forward-looking statements, as defined by the Private
Securities Litigation Reform Act of 1995. While forward-looking statements are
based on assumptions and such assumptions are believed to be reasonable and are
made in good faith, Panhandle cautions that assumed results almost always vary
from actual results and differences between assumed and actual results can be
material. The type of assumptions that could materially affect the actual
results are discussed in the Outlook section in this MD&A. More specific risk
factors are contained in various public filings made by Panhandle with the SEC.
This Annual Report also describes material contingencies in the Notes to
Consolidated Financial Statements and the readers are encouraged to read such
Notes.
On March 29, 1999, Panhandle Eastern Pipe Line Company and its principal
subsidiaries, Trunkline and Pan Gas Storage, as well as Panhandle Eastern Pipe
Line Company's affiliates, Trunkline LNG and Panhandle Storage, were acquired
from subsidiaries of Duke Energy by CMS Panhandle Holding, which was an indirect
wholly owned subsidiary of CMS Energy. Immediately following the acquisition,
Trunkline LNG and Panhandle Storage became direct wholly owned subsidiaries of
Panhandle Eastern Pipe Line Company.
Prior to the acquisition, Panhandle's interests in Northern Border Pipeline
Company, Panhandle Field Services Company, Panhandle Gathering Company, and
certain other assets, including the Houston corporate headquarters building,
were transferred to other subsidiaries of Duke Energy; certain intercompany
accounts and notes between Panhandle and Duke Energy subsidiaries were
eliminated; with respect to certain other liabilities, including tax,
environmental and legal matters, CMS Energy was indemnified for any resulting
losses. In addition, Duke Energy agreed to continue its environmental clean-up
program at certain properties and to defend and indemnify Panhandle against
certain future environmental litigation and claims with respect to certain
agreed-upon sites or matters.
CMS Panhandle Holding privately placed $800 million of senior unsecured notes
and received a $1.1 billion initial capital contribution from CMS Energy to fund
the acquisition of Panhandle. On June 15, 1999, CMS Panhandle Holding was merged
into Panhandle. Panhandle then became a wholly owned subsidiary of CMS Gas
Transmission and Storage Company, a subsidiary of CMS Energy. At that time, the
CMS Panhandle Holding notes became direct obligations of Panhandle. In September
1999, Panhandle completed an exchange offer which replaced the $800 million of
notes originally issued by CMS Panhandle Holding with substantially identical
SEC-registered notes issued by Panhandle.
The acquisition by CMS Panhandle Holding was accounted for using the purchase
method of accounting in accordance with generally accepted accounting
principles, with Panhandle allocating the purchase price paid by CMS Panhandle
Holding to Panhandle's net assets as of the acquisition date based on a
preliminary appraisal completed in December 1999. Accordingly, the
post-acquisition financial statements reflect a new basis of accounting, and
pre-acquisition period and post-acquisition period financial results (separated
by a heavy black line) are presented but are not comparable (See Note 1).
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The following information is provided to facilitate increased understanding of
the 1999 and 1998 consolidated financial statements and accompanying notes of
Panhandle but should be read in conjunction with these financial statements.
Because all of the outstanding common stock of Panhandle is owned by CMS Gas
Transmission and Storage Company, a subsidiary of CMS Energy, the following
discussion uses the reduced disclosure format permitted by Form 10K for issuers
that are wholly owned subsidiaries of reporting companies.
RESULTS OF OPERATIONS
NET INCOME:
In Millions
- --------------------------------------------------------------------------------------------------------------------
December 31 1999 1998 Change
- --------------------------------------------------------------------------------------------------------------------
Twelve Months Ended $74 $91 $ (17)
===================================================================================================================
For the year ending December 31, 1999, net income was $74 million, down $17
million from the corresponding period in 1998. Total natural gas transportation
volumes for the twelve months ending December 31, 1999 were almost unchanged
from 1998.
Revenues for the twelve months ended December 31, 1999 decreased $25 million
from the corresponding period in 1998; $15 million was as a result of the
transfer of Panhandle Field Services to Duke Energy in March 1999; $14 million
from declining reservation rates; and $5 million due to Pan Border's 1998
revenues from Northern Border Pipe Line Company partnership; partially offset by
$13 million of Trunkline LNG terminal revenues in 1999.
Operating expenses for the twelve months ended December 31, 1999 decreased $17
million from the corresponding period in 1998 due primarily to lower
administrative costs and the transfer of Panhandle Field Services to Duke
Energy.
Other income for the twelve months ended December 31, 1999 decreased $18 million
from the corresponding period in 1998 primarily due to a gain recorded in 1998
on the sale of the general partnership interests in Northern Border of $14
million.
Interest on long-term debt for the twelve months ended December 31, 1999
increased $39 million from the corresponding period in 1998 primarily due to
interest on the new debt assumed by Panhandle (See Notes 1 and 9). Other
interest decreased $38 million for the twelve months ended December 31, 1999
from the corresponding period in 1998 primarily due to interest for a partial
year on the intercompany note with PanEnergy; the note was eliminated with the
sale of Panhandle to CMS Panhandle Holding (See Note 1 and Note 4).
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OPERATING INCOME:
In Millions
- -------------------------------------------------------------------------------------------------------------------
Twelve Months
Ended December 31
Change Compared to Prior Year 1999 vs. 1998
- -------------------------------------------------------------------------------------------------------------------
Commodity revenue $ (1)
Reservation and other revenues (24)
Operations and maintenance 22
Depreciation and amortization (2)
General taxes (3)
------------
Total Change $ (8)
===================================================================================================================
OUTLOOK
CMS Energy intends to use Panhandle as a platform for expansion in the United
States. Panhandle plays an important role in the growth strategy by providing
services for the development of existing gas wells, production and throughput of
gas to the market. The market for transmission of natural gas to the Midwest is
increasingly competitive, however, and may become more so in light of projects
recently completed or in progress to increase Midwest transmission capacity for
gas originating in Canada and the Rocky Mountain region. As a result, there
continues to be pressure on prices charged by Panhandle and an increasing
necessity to discount the prices charged from the legal maximum, which reduces
revenues. New contracts in the current market conditions tend to be of shorter
duration than the expiring contracts being replaced, which will also increase
revenue volatility. In addition, Trunkline in 1996 filed with FERC and placed
into effect a general rate increase, however a subsequent January 2000 FERC
order could, if approved without modification upon rehearing, reduce Trunkline's
tariff rates and future revenue levels by up to 3% of Panhandle's consolidated
revenues. Panhandle continues to be selective in offering discounts to maximize
revenues from existing capacity and to advance projects that provide expanded
services to meet the specific needs of customers. In addition, Panhandle will
continue to evaluate opportunities to acquire synergistic operations such as the
Sea Robin pipeline system (See Note 14), and attempt to maximize the use and
value of its existing assets, such as the proposed conversion of Trunkline's 26
inch pipeline to a liquid products pipeline (See Note 3).
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OTHER MATTERS
ENVIRONMENTAL MATTERS
PCB (POLYCHLORINATED BIPHENYL) ASSESSMENT AND CLEAN-UP PROGRAMS: Panhandle has
identified environmental contamination at certain sites on its systems and has
undertaken clean-up programs at these sites. The contamination resulted from the
past use of lubricants in compressed air systems containing PCBs and the prior
use of wastewater collection facilities and other on-site disposal areas. Soil
and sediment testing to date has detected no significant off-site contamination.
Panhandle has communicated with the EPA and appropriate state regulatory
agencies on these matters. Under the terms of the sale of Panhandle to CMS
Energy (See Note 1), a subsidiary of Duke Energy is obligated to complete the
Panhandle clean-up programs at certain agreed-upon sites and to defend and
indemnify Panhandle against certain future environmental litigation and claims.
These clean-up programs are expected to continue until 2001.
YEAR 2000 COMPUTER MODIFICATIONS
In 1999, Panhandle completed a detailed assessment of all information technology
and non-information technology hardware and software, with emphasis on mission
critical systems. Panhandle inventoried its information and non-information
technology hardware and software. Panhandle also identified, remediated and
tested those systems that were not year 2000 ready to ensure they would operate
as desired on and after January 1, 2000.
As a result of its year 2000 efforts, Panhandle successfully transitioned to the
new year without experiencing year 2000 related system failures, power outages
or disruptions in services provided to its customers. Panhandle expensed the
cost of software modifications as incurred, and capitalized the cost of new
software and equipment, which is being amortized over its useful life. Since
1995, the total cost of the Year 2000 Program modifications was approximately
$425,000. The commitment of Panhandle resources to the Year 2000 Program has not
deferred any information technology projects that could have a material adverse
effect on Panhandle's financial position, liquidity or results of operations.
While Panhandle does not expect any significant year 2000 issues to develop,
Panhandle will continue to monitor its mission critical applications throughout
the year 2000 to ensure that any year 2000 issues that may arise are addressed
promptly through the use of contingency plans.
MARKET RISK INFORMATION
INTEREST RATE RISK: Panhandle is exposed to risk resulting from changes in
interest rates as a result of its issuance of variable-rate debt and fixed-rate
debt. Panhandle manages its interest rate exposure by limiting its variable-rate
and fixed-rate exposure to a certain percentage of total capitalization, as set
by policy, and by monitoring the effects of market changes in interest rates
(See Notes 8 and 9).
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PANHANDLE EASTERN PIPE LINE COMPANY
CONSOLIDATED STATEMENTS OF INCOME
(IN MILLIONS)
Years Ended December 31,
Mar. 29 - Jan. 1 - ------------------------
Dec. 31, Mar. 28,
1999 1999 1998 1997
-------- -------- ---------- ----------
OPERATING REVENUE
Transportation and storage of natural gas $ 318 $ 123 $ 468 $ 501
Other 25 5 28 33
----- ----- ----- -----
Total operating revenue 343 128 496 534
----- ----- ----- -----
OPERATING EXPENSES
Operation and maintenance 151 40 213 254
Depreciation and amortization 44 14 56 59
General taxes 22 7 26 26
----- ----- ----- -----
Total operating expenses 217 61 295 339
----- ----- ----- -----
PRETAX OPERATING INCOME 126 67 201 195
OTHER INCOME, NET 2 4 24 6
INTEREST CHARGES
Interest on long-term debt 59 5 25 25
Other interest 1 13 52 48
----- ----- ----- -----
Total interest charges 60 18 77 73
----- ----- ----- -----
NET INCOME BEFORE INCOME TAXES 68 53 148 128
INCOME TAXES 27 20 57 48
----- ----- ----- -----
CONSOLIDATED NET INCOME $ 41 $ 33 $ 91 $ 80
----- ----- ----- -----
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PANHANDLE EASTERN PIPE LINE COMPANY
CONSOLIDATED STATEMENTS OF CASH FLOWS
(IN MILLIONS)
Mar. 29 - Jan. 1 - Years Ended December 31,
Dec. 31, Mar. 28, ------------------------
1999 1999 1998 1997
--------- --------- ----------- ----------
CASH FLOWS FROM OPERATING ACTIVITIES
Net income $ 41 $ 33 $ 91 $ 80
Adjustments to reconcile net income to net cash provided by
operating activities:
Depreciation and amortization 44 14 61 61
Deferred income taxes 34 - 17 2
Rate settlement - - - (70)
Changes in current assets and liabilities 51 (29) 4 9
Other, net 9 3 1 24
------- ------- ---- ----
Net cash provided by operating activities 179 21 174 106
------- ------- ---- ----
CASH FLOWS FROM INVESTING ACTIVITIES
Acquisition of Panhandle (1,900) - - -
Capital and investment expenditures (53) (4) (85) (105)
Net increase in advances receivable - PanEnergy - (17) (106) (9)
Retirements and other (1) - 17 8
------- ------- ---- ----
Net cash used in investing activities (1,954) (21) (174) (106)
------- ------- ---- ----
CASH FLOWS FROM FINANCING ACTIVITIES
Contribution from parent 1,116 - - -
Proceeds from senior notes 785 - - -
Net increase in note receivable - CMS (85) - - -
Dividends paid (41) - - -
------- ------- ---- ----
Net cash provided by financing activities 1,775 - - -
------- ------- ---- ----
Net Increase (Decrease) in Cash and Temporary Cash Investments - - - -
CASH AND TEMPORARY CASH INVESTMENTS, BEGINNING OF PERIOD - - - -
------- ------- ---- ----
CASH AND TEMPORARY CASH INVESTMENTS, END OF PERIOD $ - $ - $ - $ -
======= ======= ==== ====
OTHER CASH FLOW ACTIVITIES WERE:
Interest paid (net of amounts capitalized) $ 31 $ 12 $ 78 $ 81
Income taxes paid (net of refunds) 8 37 56 65
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PANHANDLE EASTERN PIPE LINE COMPANY
CONSOLIDATED BALANCE SHEETS
(IN MILLIONS)
December 31, December 31,
1999 1998
------------ ------------
ASSETS
PROPERTY, PLANT AND EQUIPMENT
Cost $ 1,492 $ 2,749
Less accumulated depreciation and amortization 37 1,798
------------ ------------
Sub-total 1,455 951
Construction work-in-progress 45 28
------------ ------------
Net property, plant and equipment 1,500 979
------------ ------------
INVESTMENTS
Advances receivable - PanEnergy - 738
Investment in affiliates 2 44
Other - 6
------------ ------------
Total investments and other assets 2 788
------------ ------------
CURRENT ASSETS
Receivables, less allowances of $1 for 1999 and $2 in 1998 112 94
Inventory and supplies 34 55
Deferred income taxes 11 2
Current portion of regulatory assets - 6
Note receivable - CMS Capital 85 -
Other 30 23
------------ ------------
Total current assets 272 180
------------ ------------
NON-CURRENT ASSETS
Goodwill, net 774 -
Debt issuance cost 11 11
Other 1 15
------------ ------------
Total non-current assets 786 26
------------ ------------
TOTAL ASSETS $ 2,560 $ 1,973
============ ============
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December 31, December 31,
1999 1998
------------- -------------
COMMON STOCKHOLDER'S EQUITY AND LIABILITIES
CAPITALIZATION
Common stockholder's equity
Common stock, no par, 1,000 shares authorized, issued and outstanding $ 1 $ 1
Paid-in capital 1,127 466
Retained earnings - 91
------------- -------------
Total common stockholder's equity 1,128 558
Long-term debt 1,094 299
------------- -------------
Total capitalization 2,222 857
------------- -------------
CURRENT LIABILITIES
Note payable - PanEnergy - 675
Accounts payable 28 56
Accrued taxes 8 58
Accrued interest 29 8
Other 139 117
------------- -------------
Total current liabilities 204 914
------------- -------------
NON-CURRENT LIABILITIES
Deferred income taxes 45 99
Other 89 103
------------- -------------
Total non-current liabilities 134 202
------------- -------------
TOTAL COMMON STOCKHOLDER'S EQUITY AND LIABILITIES $ 2,560 $ 1,973
============= =============
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PANHANDLE EASTERN PIPE LINE COMPANY
CONSOLIDATED STATEMENTS OF COMMON STOCKHOLDER'S EQUITY
(IN MILLIONS)
Mar. 29 - Jan. 1 - Years Ended December 31,
Dec. 31, Mar. 28, ------------------------
1999 1999 1998 1997
--------- -------- ---------- ----------
COMMON STOCK
At beginning and end of period $ 1 $ 1 $ 1 $ 1
--------- -------- ---------- ----------
OTHER PAID-IN CAPITAL
At beginning of period 466 466 466 466
Acquisition adjustment to eliminate original
paid-in capital (466) - - -
Capital contribution of acquisition costs by parent 11 - - -
Cash capital contribution by parent 1,116 - - -
--------- -------- ---------- ----------
At end of period 1,127 466 466 466
--------- -------- ---------- ----------
RETAINED EARNINGS
At beginning of period 101 92 34 29
Acquisition adjustment to eliminate original
retained earnings (101) - - -
Net Income 41 33 91 80
Assumption of net liability by PanEnergy - 57 - -
Common stock dividends (41) (81) (34) (75)
--------- --------- ---------- ----------
At end of period - 101 91 34
--------- --------- ---------- ----------
TOTAL COMMON STOCKHOLDER'S EQUITY $ 1,128 $ 568 $ 558 $ 501
========= ========= ========== ==========
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PANHANDLE EASTERN PIPE LINE COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
1. CORPORATE STRUCTURE
Panhandle Eastern Pipe Line Company is a wholly owned subsidiary of CMS Gas
Transmission and Storage Company, which is an indirect wholly owned subsidiary
of CMS Energy. Panhandle Eastern Pipe Line Company was incorporated in Delaware
in 1929. Panhandle is primarily engaged in interstate transportation and storage
of natural gas, which are subject to the rules and regulations of the FERC.
On March 29, 1999, Panhandle Eastern Pipe Line Company and its principal
consolidated subsidiaries, Trunkline and Pan Gas Storage, as well as its
affiliates, Trunkline LNG and Panhandle Storage, were acquired from subsidiaries
of Duke Energy by CMS Panhandle Holding for $1.9 billion in cash and assumption
of existing Panhandle debt of $300 million. Immediately following the
acquisition, CMS Panhandle Holding contributed the stock of Trunkline LNG and
Panhandle Storage to Panhandle Eastern Pipe Line Company. As a result, Trunkline
LNG and Panhandle Storage became wholly owned subsidiaries of Panhandle Eastern
Pipe Line Company.
In conjunction with the acquisition, Panhandle's interests in Northern Border
Pipeline Company, Panhandle Field Services Company, Panhandle Gathering Company,
and certain other assets, including the Houston corporate headquarters building,
were transferred to other subsidiaries of Duke Energy; all intercompany accounts
and notes between Panhandle and Duke Energy subsidiaries were eliminated; and
with respect to certain other liabilities, including tax, environmental and
legal matters, CMS Energy was indemnified for any resulting losses. In addition,
Duke Energy agreed to continue its environmental clean-up program at certain
properties and to defend and indemnify Panhandle against certain future
environmental litigation and claims with respect to certain agreed-upon sites or
matters.
CMS Panhandle Holding privately placed $800 million of senior unsecured notes
and received a $1.1 billion initial capital contribution from CMS Energy to fund
the acquisition of Panhandle. On June 15, 1999, CMS Panhandle Holding was merged
into Panhandle, at which point the CMS Panhandle Holding notes became direct
obligations of Panhandle. In September 1999, Panhandle completed an exchange
offer which replaced the $800 million of notes originally issued by CMS
Panhandle Holding with substantially identical SEC-registered notes.
The acquisition by CMS Panhandle Holding was accounted for using the purchase
method of accounting in accordance with generally accepted accounting
principles, with Panhandle allocating the purchase price paid by CMS Panhandle
Holding to Panhandle's net assets as of the acquisition date based on a
preliminary appraisal completed December 1999. Accordingly, the post-acquisition
financial statements reflect a new basis of accounting, and pre-acquisition
period and post-acquisition period financial results (separated by a heavy black
line) are presented but are not comparable.
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Assets acquired and liabilities assumed are recorded at their estimated fair
values and are subject to adjustment when additional information concerning
asset and liability valuations is finalized by the end of the first quarter of
2000. Panhandle has allocated the tentative excess purchase price over the
estimated fair value of net assets acquired of approximately $800 million to
goodwill and is amortizing this amount on a straight-line basis over forty
years. The amortization of the excess purchase price over 40 years reflects the
nature of the industry in which Panhandle competes as well as the long-lived
nature of Panhandle's assets. As a result of regulation, high replacement costs,
and competition, entry into the natural gas transmission and storage business
requires a significant investment. The excess purchase price over the prior
carrying amount of Panhandle's net assets as of March 29, 1999 totaled $1.3
billion, and was allocated as follows:
In Millions
- -------------------------------------------------------------
Property, plant and equipment $ 633
Accounts receivable 3
Inventory (9)
Goodwill 788
Regulatory assets, net (15)
Liabilities (72)
Long-term debt (6)
Other (16)
- -------------------------------------------------------------
Total $1,306
=============================================================
Pro forma results of operations for 1999 and 1998 as though Panhandle had been
acquired and purchase accounting applied at the beginning of 1999 and 1998,
respectively, are as follows:
In Millions
=======================================================================================
Year Ended Year Ended
December 31, 1999 December 31, 1998
(Unaudited) (Unaudited)
- ---------------------------------------------------------------------------------------
Revenues $ 467 $ 470
Net income 67 60
Total assets 2,560 2,477
- --------------------------------------------------------------------------------------
2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES AND OTHER MATTERS
CONSOLIDATIONS: The consolidated financial statements include the accounts of
all of Panhandle's majority-owned subsidiaries after the elimination of
significant intercompany transactions and balances. Investments in other
entities that are not controlled by Panhandle, but where it has significant
influence over operations, are accounted for using the equity method.
The preparation of financial statements in conformity with generally accepted
accounting principles requires management to make estimates and assumptions that
affect the amounts reported in the financial statements and accompanying notes.
Although these estimates are based on management's knowledge of current and
expected future events, actual results could differ from those estimates.
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CASH AND CASH EQUIVALENTS: All liquid investments with maturities at date of
purchase of three months or less are considered cash equivalents.
INVENTORY: Inventory consists of gas held for operations and materials and
supplies and is recorded at the lower of cost or market, using the weighted
average cost method. Effective January 1, 1999, Trunkline changed to the
weighted average cost method from the last-in first-out method for its gas held
for operations with no material impact on the financial statements.
GAS IMBALANCES: Gas imbalances occur as a result of differences in volumes
of gas received and delivered. Gas imbalance receivables and payables are
valued at lower of cost or market.
PROPERTY, PLANT AND EQUIPMENT: On March 29, 1999, Panhandle's assets were
acquired by CMS Panhandle Holding. The acquisition was accounted for using the
purchase method of accounting in accordance with generally accepted accounting
principles. Panhandle's property, plant and equipment was adjusted to estimated
fair market value on March 29, 1999 and depreciated based on revised estimated
remaining useful lives. Panhandle's accumulated depreciation and amortization
provision balance at March 29, 1999 was eliminated pursuant to the purchase
method of accounting (See Note 1).
Ongoing additions of property, plant and equipment are stated at original cost.
Panhandle capitalizes all construction-related direct labor and material costs,
as well as indirect construction costs. The cost of renewals and betterments
that extend the useful life of property, plant and equipment is also
capitalized. The cost of repairs and replacements of minor items is charged to
expense as incurred. Depreciation is generally computed using the straight-line
method. The composite weighted-average depreciation rates were 2.6%, 2.2% and
2.2% for 1999, 1998 and 1997, respectively.
When property, plant and equipment is retired, the original cost plus the cost
of retirement, less salvage, is charged to accumulated depreciation and
amortization. When entire regulated operating units are sold or non-regulated
properties are retired or sold, the property and related accumulated
depreciation and amortization accounts are reduced, and any gain or loss is
recorded in income.
IMPAIRMENT OF LONG-LIVED ASSETS: The recoverability of long-lived assets and
intangible assets are reviewed whenever events or changes in circumstances
indicate that the carrying amount of the asset may not be recoverable. Such
evaluation is based on various analyses, including undiscounted cash flow
projections.
UNAMORTIZED DEBT PREMIUM, DISCOUNT AND EXPENSE: Premiums, discounts and expenses
incurred in connection with the issuance of presently outstanding long-term debt
are amortized over the terms of the respective issues.
ENVIRONMENTAL EXPENDITURES: Environmental expenditures that relate to an
existing condition caused by past operations that do not contribute to current
or future revenue generation are expensed. Environmental expenditures relating
to current or future revenues are expensed or capitalized as appropriate.
Liabilities are recorded when environmental assessments and/or clean-ups are
probable and the costs can be reasonably estimated. Under the terms of the sale
of Panhandle to CMS Energy (See Note 1), a subsidiary of Duke Energy is
obligated to complete the Panhandle clean-up programs at certain agreed-upon
sites and to defend and indemnify Panhandle against certain future environmental
litigation and claims. These clean-up programs are expected to continue until
2001.
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REVENUES: Revenues on transportation and storage of natural gas are recognized
as service is provided. When rate cases are pending final approval, a portion of
the revenues is subject to possible refund. Reserves have been established where
required for such cases.
During 1999 and 1997, sales to ProLiance Energy, L.L.C., a nonaffiliated gas
marketer, and Consumers Energy, a subsidiary of CMS Energy, each accounted for
at least 10% of consolidated revenues of Panhandle. During 1998, sales to
ProLiance Energy, L.L.C. accounted for approximately 10% of consolidated
revenues of Panhandle. No other customer accounted for 10% or more of
consolidated revenues during 1999, 1998 or 1997.
INTEREST COST CAPITALIZED: SFAS 34, Capitalization of Interest Cost, requires
capitalization of interest on certain qualifying assets that are undergoing
activities to prepare them for their intended use. SFAS 34 limits the
capitalization of interest for the period to the actual interest cost that is
incurred and prohibits imputing interest costs on any equity funds. As a result
of the discontinuance of SFAS 71, Panhandle is now subject to the provisions of
SFAS 34.
INCOME TAXES: CMS Energy and its subsidiaries file a consolidated federal income
tax return. Federal income taxes have been provided by Panhandle on the basis of
its separate company income and deductions in accordance with established
practices of the consolidated group. Deferred income taxes have been provided
for temporary differences. Temporary differences occur when events and
transactions recognized for financial reporting result in taxable or
tax-deductible amounts in different periods.
GOODWILL AMORTIZATION: Goodwill represents the excess of the purchase price over
the fair value of the net assets of acquired companies and is amortized using
the straight-line method over forty years. Accumulated amortization of goodwill
at December 31, 1999 was $14 million.
RECLASSIFICATIONS: Certain amounts have been reclassified in the Consolidated
Financial Statements to conform to the current presentation.
NEW ACCOUNTING STANDARD: In 1999, the FASB issued SFAS 137, Accounting for
Derivative Instruments and Hedging Activities - Deferral of the Effective Date
of FASB Statement No.133. SFAS 137 defers the effective date of SFAS 133,
Accounting for Derivative Instruments and Hedging Activities, to January 1,
2001. Panhandle is currently studying SFAS 133 and plans to adopt SFAS 133 as of
January 1, 2001, and has yet to quantify the effects of adoption on its
financial statements.
CHANGE IN ACCOUNTING POLICY: As a result of Panhandle's new cost basis resulting
from the merger with CMS Panhandle Holding, which includes costs not likely to
be considered for regulatory recovery, in addition to the level of discounting
being experienced by Panhandle, it no longer meets the criteria of SFAS 71 and
has discontinued application of SFAS 71. Accordingly, upon acquisition by CMS
Panhandle Holding, the remaining net regulatory assets of approximately $15
million were eliminated in purchase accounting (See Note 1).
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3. REGULATORY MATTERS
Effective August 1996, Trunkline placed into effect a general rate increase,
subject to refund. On September 16, 1999, Trunkline filed a FERC settlement
agreement to resolve certain issues in this proceeding. This settlement was
approved on February 1, 2000 and will require refunds of approximately $2
million expected to be made in April 2000, with supplemental refunds expected in
July 2000. On January 12, 2000, FERC issued an order on the remainder of the
rate proceeding which, if approved without modification, would result in a
substantial reduction to Trunkline's tariff rates which would impact future
revenues and require refunds. Trunkline has requested rehearing of certain
matters in this order.
In conjunction with a FERC order issued in September 1997, certain natural gas
producers were required to refund previously collected Kansas ad-valorem taxes
to interstate natural gas pipelines. These pipelines were ordered to refund
these amounts to their customers. All payments are to be made in compliance with
prescribed FERC requirements. At December 31, 1999 and December 31, 1998,
accounts receivable included $54 million and $50 million, respectively, due from
natural gas producers, and other current liabilities included $54 million and
$50 million, respectively, for related obligations.
In June 1998, Trunkline filed a petition with the FERC to abandon 720 miles of
its 26-inch diameter pipeline that extends from Longville, Louisiana to Bourbon,
Illinois. Trunkline requested permission to transfer the pipeline to an
affiliate, which had entered into an option agreement with Aux Sable for
potential conversion of the line to allow transportation of hydrocarbon vapors.
Trunkline requested FERC to grant the abandonment authorization in time to
separate the pipeline from existing facilities and allow Aux Sable to convert
the pipeline to hydrocarbon vapor service by October 1, 2000, if the option was
exercised. The option expired on July 1, 1999 and was not renewed by Aux Sable.
On November 8, 1999, the FERC issued a letter order dismissing Trunkline's
filing without prejudice to refiling the abandonment to reflect changed
circumstances. Trunkline on March 9, 2000 refiled its abandonment application
with FERC. This filing is in conjunction with a plan for a joint venture, to
convert the line from natural gas transmission service to a refined products
pipeline by the end of 2001. Panhandle will own a one third interest in the
joint venture.
On May 19, 1999, Trunkline and Trunkline LNG submitted a compliance filing
advising the FERC that the acquisition by CMS Energy of Trunkline LNG triggered
certain provisions of a 1992 settlement. The settlement resolved issues related
to minimum bill provisions of the Trunkline LNG Rate Schedule PLNG-1, as well as
pending rate matters for Trunkline and refund matters for Trunkline LNG.
Specifically, the settlement provisions require Trunkline LNG, and Trunkline in
turn, to make refunds to customers, including Panhandle Eastern Pipe Line
Company and Consumers, who were parties to the settlement, if the ownership of
all or portion of the LNG terminal is transferred to an unaffiliated entity. The
total refund due customers of approximately $17 million will be paid within 30
days of final FERC approval of the compliance filing. In conjunction with the
acquisition of Panhandle by CMS Energy, Duke Energy indemnified Panhandle for
this refund obligation. In conjunction with the settlement, Panhandle Eastern
Pipe Line Company and its customers entered into an agreement, whereby upon FERC
approval of the compliance filing described above, Panhandle Eastern Pipe Line
Company will file to flow through its portion of the settlement amounts to its
customers. The May 19, 1999 compliance filing is pending FERC approval.
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4. RELATED PARTY TRANSACTIONS
In Millions
- -------------------------------------------------------------------------------------------------------------------
Mar.29 - Jan.1 - For the Years Ended
Dec.31 Mar.28 December 31,
- -------------------------------------------------------------------------------------------------------------------
1999 1999 1998 1997
--------- --------------------------------------------
Transportation of natural gas $64 $6 $29 $32
Other operating revenues - 2 15 27
Operation and maintenance(a) 25 8 60 66
Interest income 2 - - -
Interest expense - 13 55 49
- -------------------------------------------------------------------------------------------------------------------
(a) Includes allocated benefit plan costs.
Amounts for 1999 reflect only related party transactions with CMS Energy and its
subsidiaries for the period after the sale of Panhandle to CMS Energy. Interest
charges include $55 million for the twelve months ended 1998 for interest
associated with notes payable to a subsidiary of Duke Energy. Note receivable
from CMS Capital included an $85 million note at December 31, 1999, which bore
interest at the 30-day commercial paper interest rate. Other income includes $2
million for the period ended December 31, 1999 for interest on note receivable
from CMS Capital.
A summary of certain balances due to or due from related parties included in the
Consolidated Balance Sheets is as follows:
In Millions
- ----------------------------------------------------------------
December 31,
- ----------------------------------------------------------------
1999 1998
------------ -------------
Receivables $8 $2
Accounts payable 16 46
Taxes accrued - 35
- ----------------------------------------------------------------
In conjunction with the acquisition of Panhandle by a subsidiary of CMS Energy,
all intercompany advance and note balances between Panhandle and subsidiaries of
Duke Energy were eliminated. Transactions with prior affiliates before the
acquisition are now reflected as receivables on the Consolidated Balance Sheet.
5. GAS IMBALANCES
The Consolidated Balance Sheets include in-kind balances as a result of
differences in gas volumes received and delivered. At December 31, 1999 and
1998, other current assets included $22 million and $20 million, respectively,
and other current liabilities included $30 million and $22 million,
respectively, related to gas imbalances.
PE-16
182
6. INCOME TAXES
The separate components of income tax expense consist of:
In Millions
===============================================================================================================
INCOME TAX EXPENSE
- ---------------------------------------------------------------------------------------------------------------
Mar.29 - Jan.1 - For the Years Ended
Dec. 31 Mar.28 December 31,
- ---------------------------------------------------------------------------------------------------------------
1999 1999 1998 1997
--------------------------------------------------------
Current income taxes
Federal $ (7) $ 18 $ 34 $ 41
State - 2 6 5
--------------------------------------------------------
Total current income taxes (7) 20 40 46
--------------------------------------------------------
Deferred income taxes, net
Federal 29 - 14 1
State 5 - 3 1
--------------------------------------------------------
Total deferred income taxes, net 34 - 17 2
--------------------------------------------------------
Total income tax expense $ 27 $ 20 $ 57 $ 48
===============================================================================================================
The actual income tax expense differs from the amount computed by applying the
statutory federal tax rate to income before income taxes as follows:
In Millions
===================================================================================================================
INCOME TAX EXPENSE RECONCILIATION TO STATUTORY
- -------------------------------------------------------------------------------------------------------------------
Mar.29 - Jan.1 - For the Years Ended
Dec. 31 Mar. 28 December 31,
- -------------------------------------------------------------------------------------------------------------------
1999 1999 1998 1997
------------------------------------------------------------
Income tax, computed at the statutory rate $24 $18 $52 $45
Adjustments resulting from:
State income tax, net of federal income
tax effect 3 2 5 3
------------------------------------------------------------
Total income tax expense $27 $20 $57 $48
============================================================
Effective tax rate 39.6% 38.2% 38.5% 37.5%
- -------------------------------------------------------------------------------------------------------------------
PE-17
183
The principal components of Panhandle's deferred tax assets (liabilities)
recognized in the balance sheet are as follows:
In Millions
==============================================================================================
NET DEFERRED INCOME TAX LIABILITY COMPONENTS
- ----------------------------------------------------------------------------------------------
December 31,
- ----------------------------------------------------------------------------------------------
1999 1998
------------------------------
Deferred credits and other liabilities $ 30 $ 85
Other 32 3
------------------------------
Total deferred income tax assets 62 88
------------------------------
Investments and other assets (18) (18)
Property, plant and equipment (10) (148)
Goodwill (65) -
Regulatory assets - (12)
------------------------------
Total deferred income tax liabilities (93) (178)
------------------------------
State deferred income tax, net of federal tax effect (3) (7)
Net deferred income tax liability (34) (97)
------------------------------
Portion classified as current asset 11 2
------------------------------
Noncurrent liability $(45) $ (99)
==============================================================================================
As described in Note 1, the stock of Panhandle was acquired from subsidiaries of
Duke Energy by CMS Panhandle Holding for a total of $2.2 billion in cash and
acquired debt. The acquisition was treated as an asset acquisition for tax
purposes, which eliminated Panhandle's deferred tax liability and gave rise to a
new tax basis in Panhandle's assets equal to the purchase price.
7. PROPERTY, PLANT AND EQUIPMENT
In Millions
==============================================================================================
1999 1998
-------------------------------
Transmission $1,189 $2,003
Gathering 18 265
Underground storage 245 320
General plant 40 161
Construction work-in-progress 45 28
-------------------------------
Total property, plant and equipment 1,537 2,777
Less accumulated depreciation and amortization 37 1,798
-------------------------------
Net property, plant and equipment $1,500 $979
==============================================================================================
PE-18
184
8. FINANCIAL INSTRUMENTS
Panhandle's financial instruments include approximately $1.1 billion and $299
million of long-term debt at December 31, 1999 and 1998, respectively, with an
approximate fair value of $1 billion and $318 million as of December 31, 1999
and 1998, respectively. Estimated fair value amounts of long-term debt were
obtained from independent parties. Judgment is required in interpreting market
data to develop the estimates of fair value. Accordingly, the estimates
determined as of December 31, 1999 and 1998 are not necessarily indicative of
the amounts Panhandle could have realized in current market exchanges.
Guarantees made to related parties have no book value associated with them and
there are no fair values readily determinable since quoted market prices are not
available. The fair values of advances and note receivable -- related parties
are not readily determinable since such amounts are carried as open accounts
(See Note 4).
9. LONG-TERM DEBT
In Millions
==========================================================================================
December 31,
-----------------------------
Year Due 1999 1998
- ------------------------------------------------------------------------------------------
6.125% - 7.875% Notes 2004 - 2029 $ 900 $100
7.2% - 7.95% Debentures 2023 - 2024 200 200
Unamortized debt (discount) and premium, net (6) (1)
-----------------------------
Total long-term debt $1,094 $299
=============================
On March 29, 1999, CMS Panhandle Holding privately placed $800 million of senior
notes (See Note 1) including: $300 million of 6.125 percent senior notes due
2004; $200 million of 6.5 percent senior notes due 2009; and $300 million of 7.0
percent senior notes due 2029. On June 15, 1999, CMS Panhandle Holding was
merged into Panhandle and the obligations of CMS Panhandle Holding under the
notes and the related indenture were assumed by Panhandle. In September 1999,
Panhandle completed an exchange offer which replaced the $800 million of notes
originally issued by CMS Panhandle Holding with substantially identical
SEC-registered notes.
In conjunction with the application of purchase accounting, Panhandle's existing
notes totaling $300 million were revalued resulting in a net premium recorded of
approximately $5 million.
The 7.2% - 7.95% debentures have call options whereby Panhandle has the option
to repay the debt early. Based on the year in which Panhandle may first exercise
the redemption options, all $200 million could potentially be repaid in 2003.
At December 31, 1998, Note payable-PanEnergy consisted of a $675 million note
bearing interest at prime rate. The note was eliminated immediately prior to the
acquisition by CMS Energy.
OTHER: Under its most restrictive borrowing arrangement at December 31, 1999,
none of Panhandle's consolidated net income was restricted for payment of common
dividends.
PE-19
185
10. INVESTMENT IN AFFILIATES
Investments in affiliates, which are not controlled by Panhandle but where
Panhandle has significant influence over operations, are accounted for by the
equity method. These investments include undistributed earnings of $.4 million
and $14 million in 1999 and 1998, respectively. Panhandle's proportionate share
of net income from these affiliates for the years ended December 31, 1999, 1998
and 1997 was $.2 million, $6 million and $5 million, respectively. These amounts
are reflected in the Consolidated Statements of Income as Other Operating
Revenues. Investment in affiliates includes the following:
LEE 8 STORAGE. Panhandle, through its subsidiary Panhandle Storage, owns a 40
percent interest in the Lee 8 partnership, which operates a 1.4 bcf natural gas
storage facility in Michigan. This interest results from the contribution of the
stock of Panhandle Storage to Panhandle Eastern Pipe Line Company by CMS
Panhandle Holding on March 29, 1999.
NORTHERN BORDER PARTNERS, L.P. Northern Border Partners, L.P. is a master
limited partnership that owns 70 percent of Northern Border Pipeline Company, a
partnership operating a pipeline transporting natural gas from Canada to the
Midwest area of the United States. At December 31, 1998, Panhandle held a 7.0
percent limited partnership interest in Northern Border Partners, L.P., and
thus, an indirect 4.9 percent ownership interest in Northern Border Pipeline
Company. In conjunction with the acquisition of Panhandle by CMS Energy,
Panhandle transferred its interest in Northern Border to a subsidiary of Duke
Energy in the first quarter of 1999.
WESTANA GATHERING COMPANY. Westana Gathering Company is a joint venture that
provides gathering, processing and marketing services for natural gas producers
in Oklahoma. In conjunction with the acquisition of Panhandle by CMS Energy,
Panhandle's interest in Westana Gathering Company was transferred to a
subsidiary of Duke Energy in the first quarter of 1999.
11. COMMITMENTS AND CONTINGENCIES
CAPITAL EXPENDITURES: Panhandle estimates capital expenditures and investments,
including allowance for funds used during construction, to be approximately $130
million in 2000 and $60 million in each of the two following years. The year
2000 estimate includes the Sea Robin acquisition (see Note 14). These estimates
are prepared for planning purposes and are subject to revision. Capital
expenditures for 1999 were satisfied by cash from operations.
LITIGATION: Under the terms of the sale of Panhandle to CMS Energy discussed in
Note 1 to the Consolidated Financial Statements, subsidiaries of Duke Energy
indemnified CMS Energy from losses resulting from certain legal and tax
liabilities of Panhandle, including the matter specifically discussed below:
PE-20
186
In May 1997, Anadarko filed suits against Panhandle and other PanEnergy
affiliates, as defendants, both in the United States District Court for the
Southern District of Texas and State District Court of Harris County, Texas.
Pursuing only the federal court claim, Anadarko claims that it was effectively
indemnified by the defendants against any responsibility for refunds of Kansas
ad valorem taxes which are due from purchasers of gas from Anadarko, retroactive
to 1983. In October 1998 and January 1999, the FERC issued orders on ad valorem
tax issues, finding that first sellers of gas were primarily liable for refunds.
The FERC also noted that claims for indemnity or reimbursement among the parties
would be better addressed by the United States District Court for the Southern
District of Texas. Panhandle believes the resolution of this matter will not
have a material adverse effect on consolidated results of operations or
financial position.
Panhandle is also involved in other legal, tax and regulatory proceedings before
various courts, regulatory commissions and governmental agencies regarding
matters arising in the ordinary course of business, some of which involve
substantial amounts. Where appropriate, Panhandle has made accruals in
accordance with SFAS 5, Accounting for Contingencies, in order to provide for
such matters. Management believes the final disposition of these proceedings
will not have a material adverse effect on consolidated results of operations or
financial position.
ENVIRONMENTAL MATTERS: Panhandle is subject to federal, state and local
regulations regarding air and water quality, hazardous and solid waste disposal
and other environmental matters. Panhandle has identified environmental
contamination at certain sites on its systems and has undertaken clean-up
programs at these sites. The contamination resulted from the past use of
lubricants in compressed air systems containing PCBs and the prior use of
wastewater collection facilities and other on-site disposal areas. Under the
terms of the sale of Panhandle to CMS Energy, a subsidiary of Duke Energy is
obligated to complete the Panhandle clean-up programs at certain agreed-upon
sites and to indemnify against certain future environmental litigation and
claims. The Illinois EPA included Panhandle and Trunkline, together with other
non-affiliated parties, in a cleanup of former waste oil disposal sites in
Illinois. Prior to a partial cleanup by the United States EPA, a preliminary
study estimated the cleanup costs at one of the sites to be between $5 million
and $15 million. The State of Illinois contends that Panhandle Eastern Pipe Line
Company's and Trunkline's share for the costs of assessment and remediation of
the sites, based on the volume of waste sent to the facilities, is 17.32
percent. Management believes that the costs of cleanup, if any, will not have a
material adverse impact on Panhandle's financial position, liquidity, or results
of operations.
OTHER COMMITMENTS AND CONTINGENCIES: In 1993, the U.S. Department of the
Interior announced its intention to seek additional royalties from gas producers
as a result of payments received by such producers in connection with past
take-or-pay settlements, and buyouts and buydowns of gas sales contracts with
natural gas pipelines. Panhandle's pipelines, with respect to certain producer
contract settlements, may be contractually required to reimburse or, in some
instances, to indemnify producers against such royalty claims. The potential
liability of the producers to the government and of the pipelines to the
producers involves complex issues of law and fact which are likely to take
substantial time to resolve. If required to reimburse or indemnify the
producers, Panhandle's pipelines will file with FERC to recover a portion of
these costs from pipeline customers. Management believes these commitments and
contingencies will not have a material adverse effect on consolidated results of
operations or financial position.
PE-21
187
Under the terms of a settlement related to a transportation agreement between
Panhandle and Northern Border Pipeline Company, Panhandle guarantees payment to
Northern Border Pipeline Company under a transportation agreement held by a
third party. The transportation agreement requires estimated total payments of
$33 million for the remainder of 2000 through 2001. Management believes the
probability that Panhandle will be required to perform under this guarantee is
remote.
LEASES: Panhandle utilizes assets under operating leases in several areas of
operation. Consolidated rental expense amounted to $14 million ($11 million
related to the CMS Energy ownership period and $3 million during the Duke Energy
ownership period), $15 million and $20 million in 1999, 1998 and 1997,
respectively. Future minimum rental payments under Panhandle's various operating
leases for the years 2000 through 2004 are $14 million, $13 million, $10
million, $4 million and $4 million, respectively and $11 million for 2005 and
thereafter.
12. EXECUTIVE INCENTIVE COMPENSATION
Panhandle participates in CMS Energy's Performance Incentive Stock Plan. Under
the plan, restricted shares of Common Stock of CMS Energy, as well as stock
options and stock appreciation rights related to Common Stock may be granted to
key employees based on their contributions to the successful management of CMS
Energy and its subsidiaries. Awards under the plan may consist of any class of
Common Stock. Certain plan awards are subject to performance-based business
criteria. The plan reserves for awards not more than five percent, as amended
January 1, 1999, of Common Stock outstanding on January 1 each year, less (i)
the number of shares of restricted Common Stock awarded and (ii) Common Stock
subject to options granted under the plan during the immediately preceding four
calendar years. The number of shares of restricted Common Stock awarded under
this plan can not exceed 20% of the aggregate number of shares reserved for
award. Any forfeiture of shares previously awarded will increase the number of
shares available to be awarded under the plan. At December 31, 1999, awards of
up to 2,466,524 shares of CMS Energy Common Stock may be issued.
Restricted shares of Common Stock are outstanding shares with full voting and
dividend rights. These awards vest over five years at the rate of 25 percent per
year after two years. The restricted shares are subject to achievement of
specific levels of total shareholder return and are subject to forfeiture if
employment terminates before vesting. If performance objectives are exceeded,
the plan provides additional awards. Restricted shares vest fully if control of
CMS Energy changes, as defined by the plan. At December 31, 1999, all of the
12,000 shares of restricted CMS Energy Common Stock outstanding are subject to
performance objectives.
The plan grants stock options and stock appreciation rights relating to Common
Stock with an exercise price equal to the closing market price on each grant
date. Some options may be exercised upon grant; others vest over five years at
the rate of 25 percent per year after one year. All options expire up to ten
years and one month from date of grant. The status of the restricted stock and
options granted to Panhandle's key employees under the Performance Incentive
Stock Plan follows:
PE-22
188
Restricted
Stock Options
- ---------------------------------------------------------------------------------------------------------------------
Number Number Weighted Average
CMS ENERGY COMMON STOCK of Shares of Shares Exercise Price
- ---------------------------------------------------------------------------------------------------------------------
Outstanding at December 31, 1998 - - NA
Granted 12,000 299,912 $41.07
Exercised or Issued - - NA
Outstanding at December 31, 1999 12,000 299,912 $41.07
- ---------------------------------------------------------------------------------------------------------------------
The following table summarizes Panhandle information about CMS Energy Common
Stock options outstanding at December 31, 1999:
Number Weighted Weighted
Range of of Shares Average Average
Exercise Prices Outstanding Remaining Life Exercise Price
- ---------------------------------------------------------------------------------------------------------------------
CMS Energy Common Stock
$39.0625 - $41.750 299,912 9.46 years $41.07
- ---------------------------------------------------------------------------------------------------------------------
The weighted average fair value of options granted to Panhandle employees for
CMS Energy Common Stock was $5.93 in 1999. Fair value is estimated using the
Black-Scholes model, a mathematical formula used to value options traded on
securities exchanges, with the following assumptions:
Year Ended
December 31, 1999
- ------------------------------------------------------------------------------
Risk-free interest rate 5.65%
Expected stock price volatility 16.81%
Expected dividend rate $.365
Expected option life 4.5 years
- ------------------------------------------------------------------------------
Panhandle applies Accounting Principles Board Opinion 25 and related
interpretations in accounting for the Performance Incentive Stock Plan. Since
stock options are granted at market price, no compensation cost has been
recognized for stock options granted under the plan. If compensation cost for
stock options had been determined in accordance with SFAS 123, Accounting for
Stock-Based Compensation, Panhandle's net income would have decreased by
approximately $1.2 million for 1999. The compensation cost charged against
income for restricted stock was $.1 million in 1999.
PE-23
189
13. BENEFIT PLANS
Under the terms of the acquisition of Panhandle by CMS Energy, benefit
obligations related to active employees and certain plan assets were transferred
to CMS Energy. Benefit obligations related to existing retired employees and
remaining plan assets were retained by a subsidiary of Duke Energy.
Following the acquisition of Panhandle by CMS Energy described in Note 1,
Panhandle now participates in CMS Energy's non-contributory defined benefit
retirement plan covering most employees with a minimum of one year vesting
service. Panhandle, through CMS Energy, provides retirement benefits under a
number of different plans, including certain health care and life insurance
benefits under OPEB, benefits to certain management employees under SERP, and
benefits to substantially all its employees under a trusted, non-contributory,
defined benefit pension plan of CMS Energy (Pension Plan) and a defined
contribution 401(K) plan.
CMS Energy's policy is to fund amounts, as necessary, on an actuarial basis to
provide assets sufficient to meet benefits to be paid to plan participants. With
respect to the CMS Pension Plan, the fair value of the plan assets was $1,094
million at December 31, 1999 as compared to the benefit obligation of $971
million. With respect to the prior Duke Energy plan, the fair value of the plan
assets of $819 million at December 31, 1998, exceeded the projected benefit
obligations of $338 million, as of December 31, 1998.
Panhandle's net periodic pension benefit cost, as allocated by CMS Energy, was
$2 million in 1999. For 1998 and 1997, Panhandle's net periodic pension benefit
cost, as allocated by a subsidiary of Duke Energy, was $14 million and $13
million, respectively.
Amounts presented below for the Pension Plan include amounts for employees of
CMS Energy and nonutility affiliates which were not distinguishable from the
plan's total assets.
Weighted-Average Assumptions:
Pension & SERP OPEB
-------------------------------------- --------------------------------------
Years Ended December 31 1999(a) 1998 1997 1999(a) 1998 1997
- -----------------------------------------------------------------------------------------------------------------------
Discount rate 7.75% 6.75% 7.25% 7.75% 6.75% 7.25%
Expected long-term rate of
return on plan assets 9.25% 9.25% 9.25% 7.00% 9.25% 9.25%
Rate of compensation increase 4.67% 4.75%
Pension - to age 45 5.25% NA NA
- age 45 to assumed
retirement 3.75% NA NA
SERP 5.50% NA NA
- -----------------------------------------------------------------------------------------------------------------------
(a) 1999 reflects CMS Energy's Pension and Other Postretirement benefits
accounting.
The Pension Plan's net unrecognized transition obligation, resulting from the
implementation of accrual accounting, is amortized over 16 years and 11 years
for the SERP's on a straight-line basis over the average remaining service
period of active employees.
PE-24
190
Panhandle accrues health care and life insurance benefit costs over the active
service period of employees to the date of full eligibility for the benefits.
With respect to the CMS OPEB Plan, the fair value of the plan assets was $431
million at December 31, 1999 as compared to the benefit obligation of $736
million. With respect to the prior Duke Energy plan, the fair value of the plan
assets of $150 million at December 31, 1998, versus projected benefit
obligations of $225 million, as of December 31, 1998.
It is Panhandle's and CMS Energy's general policy to fund accrued postretirement
health care costs. CMS Energy's retiree life insurance plan is fully funded
based on actuarially determined requirements.
Panhandle's net periodic postretirement benefit cost, as allocated by CMS
Energy, was $4 million in 1999. For each year in 1998 and 1997, Panhandle's net
periodic postretirement benefit cost, as allocated by a subsidiary of Duke
Energy, was $7 million.
For measurement purposes, a 7.0 percent weighted average rate of increase in the
per capita cost of covered health care benefits was assumed for 1999. The rate
is based on assumptions that it will decrease gradually to 5.5 percent in 2006
and thereafter. Assumed health care cost trend rates have a significant effect
on the amounts reported for Panhandle's health care plans.
In Millions
=========================================================================================================
SENSITIVITY TO CHANGES IN ASSUMED HEALTH CARE COST TREND RATES
- ---------------------------------------------------------------------------------------------------------
1-Percentage- 1-Percentage-
Point Increase Point Decrease
- ---------------------------------------------------------------------------------------------------------
Effect on total service and interest cost components $ 1 $ (1)
Effect on postretirement benefit obligation $ 8 $ (7)
=========================================================================================================
14. SUBSEQUENT EVENT (UNAUDITED)
In January 2000, Panhandle announced that Trunkline has entered into a
definitive agreement to acquire the Sea Robin Pipeline system, a 1 bcf per day
capacity offshore Gulf of Mexico pipeline, from Southern Natural Gas Company, a
subsidiary of Sonat, Inc., for a total price including certain transaction costs
of approximately $74 million. This transaction is expected to close in March
2000.
PE-25
191
15. QUARTERLY FINANCIAL DATA (UNAUDITED)
- -------------------------------------------------------------------------------------------------------------
First Second Third Fourth
(In millions) Quarter Quarter Quarter Quarter Total
- -------------------------------------------------------------------------------------------------------------
1999
Operating revenue $133(a) $104(a) $107 $127 $471
Pretax Operating Income 69(a) 44(a) 41 39 193
Net income 34 14 14 12 74
=============================================================================================================
1998
Operating revenue $139 $116 $111 $130 $496
Pretax Operating Income 70 44 36 51 201
Net income 35 17 11 28(b) 91
- -------------------------------------------------------------------------------------------------------------
(a) First and second quarters of 1999 were restated to include certain
miscellaneous income, including rental income and gain or loss on sale of
assets, as other revenue.
(b) Includes a gain on sale of certain general partnership interests of $14
million.
PE-26
192
REPORT OF INDEPENDEDENT PUBLIC ACCOUNTANTS
To Panhandle Eastern Pipe Line Company:
We have audited the accompanying consolidated balance sheet of Panhandle Eastern
Pipe Line Company (a Delaware corporation) and subsidiaries as of December 31,
1999, and the related consolidated statements of income, cash flows and common
stockholder's equity for the period from January 1, 1999 through March 28, 1999
and for the period from March 29, 1999 through December 31, 1999. These
financial statements are the responsibility of the Company's management. Our
responsibility is to express an opinion on these financial statements based on
our audits.
We conducted our audits in accordance with auditing standards generally accepted
in the United States. Those standards require that we plan and perform the audit
to obtain reasonable assurance about whether the financial statements are free
of material misstatement. An audit includes examining, on a test basis, evidence
supporting the amounts and disclosures in the financial statements. An audit
also includes assessing the accounting principles used and significant estimates
made by management, as well as evaluating the overall financial statement
presentation. We believe that our audits provide a reasonable basis for our
opinion.
In our opinion, the financial statements referred to above present fairly, in
all material respects, the financial position of Panhandle Eastern Pipe Line
Company and subsidiaries as of December 31, 1999, and the results of their
operations and their cash flows for the period from January 1, 1999 through
March 28, 1999 and for the period from March 29, 1999 through December 31, 1999
in conformity with accounting principles generally accepted in the Unites
States.
/s/ Arthur Andersen LLP
Houston, Texas
February 25, 2000
PE-27
193
INDEPENDENT AUDITORS' REPORT
Panhandle Eastern Pipe Line Company:
We have audited the accompanying consolidated balance sheets of Panhandle
Eastern Pipe Line Company and subsidiaries (the "Company") as of December
31, 1998 and 1997, and the related consolidated statements of income, common
stockholder's equity and cash flows for each of the two years in the period
ended December 31, 1998. These financial statements are the responsibility
of the Company's management. Our responsibility is to express an opinion on
the 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, such consolidated financial statements present fairly, in all
material respects, the financial position of the Company as of December 31,
1998 and 1997, and the results of its operations and its cash flows for each of
the two years in the period ended December 31, 1998 in conformity with generally
accepted accounting principles.
/s/ DELOITTE & TOUCHE LLP
Charlotte, North Carolina
February 12, 1999
PE-28
194
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS
ON ACCOUNTING AND FINANCIAL DISCLOSURE.
CMS ENERGY
None for CMS Energy.
CONSUMERS
None for Consumers.
PANHANDLE
Effective upon the closing of the acquisition of Panhandle by CMS Energy,
Panhandle's Board of Directors dismissed Deloitte & Touche LLP as Panhandle's
certifying accountant and retained Arthur Andersen LLP for 1999. Arthur Andersen
LLP is serving as certifying accountant for CMS Energy and its principal
subsidiaries in 1999. Deloitte & Touche LLP's report on the Panhandle financial
statements for 1997 and 1998 did not contain an adverse opinion or a disclaimer
of opinion, nor was it qualified or modified as to uncertainty, audit scope, or
accounting principles. During 1997, 1998 and the interim period from January 1,
1999 through March 29, 1999 (effective upon the closing of the acquisition),
there were no disagreements or "reportable events" as described in Items
304(a)(1)(iv) and (v) of Regulation S-K between Panhandle and Deloitte & Touche
LLP.
PART III
(ITEMS 10., 11., 12. AND 13.)
CMS ENERGY
CMS Energy's definitive proxy statement, except for the organization and
compensation committee report contained therein, is incorporated by reference
herein. See also ITEM 1. BUSINESS for information pursuant to ITEM 10.
CONSUMERS
Consumers' definitive information statement, except for the organization and
compensation committee report contained therein, is incorporated by reference
herein. See also ITEM 1. BUSINESS for information pursuant to ITEM 10.
CO-1
195
PART IV
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES
AND REPORTS ON FORM 8-K.
(a)(1) Financial Statements and Reports of Independent Public Accountants for
CMS Energy, Consumers, and Panhandle are listed in ITEM 8. FINANCIAL
STATEMENTS AND SUPPLEMENTARY DATA and are incorporated by reference
herein.
(a)(2) Financial Statement Schedules and Reports of Independent Public
Accountants for CMS Energy, Consumers and Panhandle are listed after
the Exhibits in the Index to Financial Statement Schedules, and are
incorporated by reference herein.
(a)(3) Exhibits for CMS Energy, Consumers, and Panhandle are listed after Item
(c) below and are incorporated by reference herein.
(b) Reports on Form 8-K for CMS Energy, Consumers and Panhandle
CMS ENERGY
Current Reports filed October 18, 1999, October 26, 1999, December 6,
1999 and February 1, 2000 covering matters reported pursuant to ITEM 5.
OTHER EVENTS.
CONSUMERS
Current Reports filed October 18, 1999, October 26, 1999, December 6,
1999 and February 1, 2000 covering matters reported pursuant to ITEM 5.
OTHER EVENTS.
PANHANDLE
Current Report filed March 16, 2000 covering matters reported pursuant
to ITEM 5. OTHER EVENTS.
(c) Exhibits, including those incorporated by reference (see also Exhibit
volume).
CO-2
196
CMS ENERGY, CONSUMERS AND PANHANDLE EXHIBITS
Previously Filed
-------------------------
With File As Exhibit
Exhibits Number Number Description
- -------------------------------------------------------------------------------------------------------------------
(3)(a) 1-9513 (3)(a) - Restated Articles of Incorporation of CMS Energy. (3rd qtr. 1999
Form 10-Q)
(3)(b) - By-Laws of CMS Energy.
(3)(c) 1-5611 (3)(c) - Certificate of Amendment to the Articles of Incorporation dated
March 10, 1997 and Restated Articles of Incorporation dated March
25, 1994 of Consumers. (1996 Form 10-K)
(3)(d) - By-Laws of Consumers.
(3)(e) 1-2921 3.01 - Restated Certificate of Incorporation of Panhandle. (1993 Form 10-K)
(3)(f) - By-Laws of Panhandle.
(4)(a) 2-65973 (b)(1)-4 - Indenture dated as of September 1, 1945, between Consumers and
Chemical Bank (successor to Manufacturers Hanover Trust Company),
as Trustee, including therein indentures supplemental thereto
through the Forty-third Supplemental Indenture dated as of May 1,
1979.
- Indentures Supplemental thereto:
33-31866 (4)(d) - 67th dated as of 11/15/89
33-41126 (4)(c) - 68th dated as of 06/15/93
1-5611 (4) - 69th dated as of 09/15/93 (Form 8-K dated Sep. 21, 1993)
1-5611 (4)(a) - 70th dated as of 02/01/98 (1997 Form 10-K)
1-5611 (4)(a) - 71st dated as of 03/06/98 (1997 Form 10-K)
1-5611 (4)(b) - 72nd dated as of 05/01/98 (1st Qtr. 1998 Form 10-Q)
333-58943 (4)(d) - 73rd dated as of 06/15/98
1-5611 (4)(b) - 74th dated as of 10/29/98 (3rd Qtr. 1998 Form 10-Q)
(4)(b) - 75th dated as of 10/1/99
(4)(c) - 76th dated as of 10/4/99
(4)(d) - 77th dated as of 10/1/99
(4)(e) 1-5611 (4)(b) - Indenture dated as of January 1, 1996 between Consumers and The
Bank of New York, as Trustee. (1995 Form 10-K)
- Indentures Supplemental thereto:
1-5611 (4)(b) - 1st dated as of 01/18/96 (1995 Form 10-K)
1-5611 (4)(a) - 2nd dated as of 09/04/97 (3rd qtr 1997 Form 10-Q)
1-9513 (4)(a) - 3rd 11/04/99 (3rd qtr 1999 Form 10-Q)
(4)(f) 1-5611 (4)(c) - Indenture dated as of February 1, 1998 between Consumers and The
Chase Manhattan Bank, as Trustee. (1997 Form 10-K)
1-5611 (4)(a) - 1st dated as of 05/01/98 (1st Qtr. 1998 Form 10-Q)
333-58943 (4)(b) - 2nd dated as of 06/15/98
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197
1-5611 (4)(a) - 3rd 10/29/98 (3rd Qtr. 1998 Form 10-Q)
(4)(g) 33-47629 (4)(a) - Indenture dated as of September 15, 1992 between CMS Energy and NBD
Bank, as Trustee. (Form S-3 filed May 1, 1992)
- Indentures Supplemental thereto:
1-9513 (4) - 1st dated as of 10/01/92 (Form 8-K dated October 1, 1992)
1-9513 (4) (a) - 2nd dated as of 10/01/92 (Form 8-K dated October 1, 1992)
1-9513 (4) - 3rd dated as of 05/06/97 (1st qtr 1997 Form 10-Q)
333-37241 (4)(a) - 4th dated as of 09/26/97 (Form S-3 filed October 6, 1997)
1-9513 (4)(b) - 5th dated as of 11/04/97 (3rd qtr 1997 Form 10-Q)
1-9513 (4)(d) - 6th dated as of 01/13/98 (1997 Form 10-K)
1-9513 (4)(d)(i) - 7th dated as of 01/25/99 (1998 Form 10-K)
1-9513 (4)(d)(ii) - 8th dated as of 02/03/99 (1998 Form 10-K)
1-9513 (4)(a) - 9th dated as of 06/22/99 (2nd qtr 1999 Form 10-Q)
(4)(h) 1-9513 (4)(b) - Indenture between CMS Energy and The Chase Manhattan Bank, as Trustee,
dated as of January 15, 1994. (Form 8-K dated March 29, 1994)
- Indentures Supplemental thereto:
1-9513 (4b) - 1st dated as of 01/20/94 (Form 8-K dated March 29, 1994)
1-9513 (4) - 2nd dated as of 03/19/96 (1st qtr 1996 Form 10-Q)
1-9513 (4)(a)(iv) - 3rd dated as of 03/17/97 (Form 8-K dated May 1, 1997)
333-36115 (4)(d) - 4th dated as of 09/17/97 (Form S-3 filed September 22, 1997)
333-63229 (4)(c) - 5th dated as of 08/26/98 (Form S-4 filed September 10, 1998)
(4)(i) 1-9513 (4a) - Indenture dated as of June 1, 1997, between CMS Energy and The Bank
of New York, as trustee. (Form 8-K filed July 1, 1997)
- Indentures Supplemental thereto:
1-9513 (4)(b) - 1st dated as of 06/20/97 (Form 8-K filed July 1, 1997)
1-9513 (4)(b) - 2nd dated as of 06/01/99 (2nd qtr 1999 Form 10-Q)
Pursuant to Item 601(b)(4)(iii) of Regulation S-K, in lieu of filing
a copy of such agreement, CMS Energy agrees to furnish a copy of such
agreement to the Commission upon request.
(4)(j) 1-5611 (4)(a) - Indenture dated as of March 29, 1999, among CMS Panhandle Holding
Company, Panhandle Eastern Pipe Line Company and NBD Bank, as
Trustee. (1st Qtr. 1999 10-Q)
(4)(k) 1-9513 (4)(b) - 1st Supplemental Indenture dated as of March 29, 1999, among CMS
Panhandle Holding Company, Panhandle Eastern Pipe Line Company and
NBD Bank, as Trustee, including a form of Guarantee by Panhandle
Eastern Pipe Line Company of the obligations of CMS Panhandle
Holding Company. (1st qtr 1999 Form 10-Q)
(4)(l) 33-58552 4 - Indenture, dated as of February 1, 1993, between Panhandle and
Morgan Guaranty Trust Company of New York. (Form S-3 filed February
19, 1993)
(10)(a) 1-9513 (4) - Credit Agreement dated as of July 2, 1997, among CMS Energy, the
Administrative Agent, Collateral Agent, Documentation Agent,
Syndication Agent, Co-Agents and Lead Manager, all as
CO-4
198
defined therein, and the Exhibits and Schedules thereto. (2nd qtr 1997
Form 10-Q)
333-63229 (4)(f) - 1st Amendment dated 01/30/98. (Form S-4 filed September 10, 1998)
1-9513 (10)(b)(i) - 2nd Amendment dated 11/05/98. (1998 Form 10-K)
1-9513 (10)(a) - 3rd Amendment dated 06/22/99. (2nd qtr 1999 Form 10-Q)
(10)(b) - Form of Employment Agreement entered into by CMS Energy's and
Consumers' executive officers.
(10)(c) 1-5611 (10)(g) - Consumers' Executive Stock Option and Stock Appreciation Rights
Plan effective December 1, 1989. (1990 Form 10-K)
(10)(d) - CMS Energy's Performance Incentive Stock Plan effective February 3,
1988, as amended December 3, 1999.
(10)(e) 1-9513 (10)(m) - CMS Deferred Salary Savings Plan effective January 1, 1994. (1993
Form 10-K)
(10)(f) 1-5611 (10)(n) - CMS Energy and Consumers Annual Executive Incentive Compensation
Plan effective January 1, 1986, as amended January 1995. (1995 Form
10-K)
(10)(g) 1-5611 (10)(o) - Consumers' Supplemental Executive Retirement Plan effective
November 1, 1990. (1993 Form 10-K)
(10)(h) - Supplemental Executive Retirement Plan for Employees of CMS
Energy / Consumers Energy Company effective January 1, 1982,
as amended December 3, 1999
(10)(i) 33-37977 4.1 - Senior Trust Indenture, Leasehold Mortgage and Security Agreement
dated as of June 1, 1990 between The Connecticut National Bank and
United States Trust Company of New York. (MCV Partnership)
Indenture Supplemental thereto:
33-37977 4.2 - Supplement No. 1 dated as of June 1, 1990. (MCV Partnership)
(10)(j) 1-9513 (28)(b) - Collateral Trust Indenture dated as of June 1, 1990 among Midland
Funding Corporation I, MCV Partnership and United States Trust
Company of New York, Trustee. (3rd qtr 1990 Form 10-Q)
Indenture Supplemental thereto:
33-37977 4.4 - Supplement No. 1 dated as of June 1, 1990. (MCV Partnership)
(10)(k) 1-9513 (10)(v) - Amended and Restated Investor Partner Tax Indemnification Agreement
dated as of June 1, 1990 among Investor Partners, CMS Midland as
Indemnitor and CMS Energy as Guarantor. (1990 Form 10-K)
(10)(l) 1-9513 (19)(d)** - Environmental Agreement dated as of June 1, 1990 made by CMS Energy
to The Connecticut National Bank and Others. (1990 Form 10-K)
(10)(m) 1-9513 (10)(z)** - Indemnity Agreement dated as of June 1, 1990 made by CMS Energy to
Midland Cogeneration Venture Limited Partnership. (1990 Form 10-K)
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199
(10)(n) 1-9513 (10)(aa)** - Environmental Agreement dated as of June 1, 1990 made by CMS Energy
to United States Trust Company of New York, Meridian Trust Company,
each Subordinated Collateral Trust Trustee and Holders from time to
time of Senior Bonds and Subordinated Bonds and Participants from
time to time in Senior Bonds and Subordinated Bonds. (1990 Form
10-K)
(10)(o) 33-37977 10.4 - Amended and Restated Participation Agreement dated as of June 1,
1990 among MCV Partnership, Owner Participant, The Connecticut
National Bank, United States Trust Company, Meridian Trust Company,
Midland Funding Corporation I, Midland Funding Corporation II, MEC
Development Corporation and Institutional Senior Bond Purchasers.
(MCV Partnership)
1-5611 (10)(w) - Amendment No. 1 dated as of July 1, 1991. (1991 Form 10-K)
(10)(p) 33-3797 10.4 - Power Purchase Agreement dated as of July 17, 1986 between MCV
Partnership and Consumers. (MCV Partnership)
Amendments thereto:
33-37977 10.5 - Amendment No. 1 dated September 10, 1987. (MCV Partnership)
33-37977 10.6 - Amendment No. 2 dated March 18, 1988. (MCV Partnership)
33-37977 10.7 - Amendment No. 3 dated August 28, 1989. (MCV Partnership)
33-37977 10.8 - Amendment No. 4A dated May 25, 1989. (MCV Partnership)
(10)(q) 1-5611 (10)(y) - Unwind Agreement dated as of December 10, 1991 by and among CMS
Energy, Midland Group, Ltd., Consumers, CMS Midland, Inc., MEC
Development Corp. and CMS Midland Holdings Company. (1991 Form
10-K)
(10)(r) 1-5611 (10)(z) - Stipulated AGE Release Amount Payment Agreement dated as of June 1,
1990, among CMS Energy, Consumers and The Dow Chemical Company.
(1991 Form 10-K)
(10)(s) 1-5611 (10)(aa)** - Parent Guaranty dated as of June 14, 1990 from CMS Energy to MCV,
each of the Owner Trustees, the Indenture Trustees, the Owner
Participants and the Initial Purchasers of Senior Bonds in the MCV
Sale Leaseback transaction, and MEC Development. (1991 Form 10-K)
(10)(t) 1-8157 10.41 - Contract for Firm Transportation of Natural Gas between Consumers
Power Company and Trunkline Gas Company, dated November 1, 1989,
and Amendment, dated November 1, 1989. (1989 Form 10-K of PanEnergy
Corp.)
(10)(u) 1-8157 10.41 - Contract for Firm Transportation of Natural Gas between Consumers
Power Company and Trunkline Gas Company, dated November 1, 1989.
(1991 Form 10-K of PanEnergy Corp.)
(10)(v) 1-2921 10.03 - Contract for Firm Transportation of Natural Gas between Consumers
Power Company and Trunkline Gas Company, dated September 1, 1993.
(1993 Form 10-K)
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200
(12) - Statements regarding computation of CMS Energy's Ratio of Earnings
to Fixed Charges.
(16)(b) 1-0291 (16)(b) - Letter of Deloitte & Touche LLP
(Form 8-K/A dated July 19, 1999)
(21)(a) - Subsidiaries of CMS Energy.
(21)(b) - Subsidiaries of Consumers.
(23)(a) - Consent of Arthur Andersen LLP for CMS Energy.
(23)(b) - Consent of Arthur Andersen LLP for Consumers.
(24)(a) - Power of Attorney for CMS Energy.
(24)(b) - Power of Attorney for Consumers.
(27)(a) - Financial Data Schedule UT for CMS Energy .
(27)(b) - Financial Data Schedule UT for Consumers.
(27)(c) - Financial Data Schedule UT for Panhandle.
** Obligations of only CMS Holdings and CMS Midland, second tier subsidiaries
of Consumers, and of CMS Energy but not of Consumers.
Exhibits listed above which have heretofore been filed with the Securities and
Exchange Commission pursuant to various acts administered by the Commission, and
which were designated as noted above, are hereby incorporated herein by
reference and made a part hereof with the same effect as if filed herewith.
201
INDEX TO FINANCIAL STATEMENT SCHEDULES
Page
Schedule II Valuation and Qualifying Accounts and Reserves 1999,
1998 and 1997:
CMS Energy Corporation............................................................. CO-9
Consumers Power Company............................................................ CO-9
Report of Independent Public Accountants
CMS Energy Corporation............................................................. CO-10
Consumers Power Company............................................................ CO-10
Schedules other than those listed above are omitted because they are either not
required, not applicable or the required information is shown in the financial
statements or notes thereto.
Columns omitted from schedules filed have been omitted because the information
is not applicable.
CO-8
202
CMS ENERGY CORPORATION
Schedule II - Valuation and Qualifying Accounts and Reserves
Years Ended December 31, 1999, 1998 and 1997
(In Millions)
Balance at Charged Charged to Balance
Beginning to other at End
Description of Period Expense Accounts Deductions of Period
- ------------------------------------------------------------------------------------------------------------------
Accumulated provision for uncollectible accounts:
1999 $13 $15 $(3) $13(a) $12
1998 $7 $12 $5 $11(a) $13
1997 $10 $8 $1 $12(a) $7
==================================================================================================================
(a) Accounts receivable written off including net uncollectible amounts of $12
in 1999, $10 in 1998 and $11 in 1997 charged directly to operating expense
and credited to accounts receivable.
CONSUMERS ENERGY COMPANY
Schedule II - Valuation and Qualifying Accounts and Reserves
Years Ended December 31, 1999, 1998 and 1997
(In Millions)
Balance at Charged Charged to Balance
Beginning to other at End
Description of Period Expense Accounts Deductions of Period
- -----------------------------------------------------------------------------------------------------------------
Accumulated provision for uncollectible accounts:
1999 $5 $7 - $8(a) $4
1998 $6 $10 - $11(a) $5
1997 $10 $8 - $12(a) $6
=================================================================================================================
(a) Accounts receivable written off including net uncollectible amounts of $7
in 1999, $10 in 1998 and $11 in 1997 charged directly to operating expense
and credited to accounts receivable.
CO-9
203
Report of Independent Public Accountants
To CMS Energy Corporation:
We have audited in accordance with generally accepted auditing standards, CMS
Energy Corporation's consolidated financial statements included in this Form
10-K, and have issued our report thereon dated February 4, 2000. Our audit was
made for the purpose of forming an opinion on those basic consolidated financial
statements taken as a whole. The schedule listed in Item 14(a) is the
responsibility of the Company's management and is presented for the purpose of
complying with the Securities and Exchange Commission's rules and is not part of
the basic consolidated financial statements. This schedule has been subjected to
the auditing procedures applied in the audit of the basic consolidated financial
statements and, in our opinion, fairly states in all material respects the
financial data required to be set forth therein in relation to the basic
consolidated financial statements taken as a whole.
/s/ Arthur Andersen LLP
Detroit, Michigan,
February 4, 2000.
Report of Independent Public Accountants
To Consumers Energy Company:
We have audited in accordance with generally accepted auditing standards,
Consumers Energy Company's consolidated financial statements included in this
Form 10-K, and have issued our report thereon dated February 4, 2000. Our audit
was made for the purpose of forming an opinion on those basic consolidated
financial statements taken as a whole. The schedule listed in
Item 14(a) is the responsibility of the Company's management and is presented
for the purpose of complying with the Securities and Exchange Commission's rules
and is not part of the basic consolidated financial statements. This schedule
has been subjected to the auditing procedures applied in the audit of the basic
consolidated financial statements and, in our opinion, fairly states in all
material respects the financial data required to be set forth therein in
relation to the basic consolidated financial statements taken as a whole.
/s/ Arthur Andersen LLP
Detroit, Michigan,
February 4, 2000.
CO-10
204
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange
Act of 1934, CMS Energy Corporation has duly caused this Annual Report to be
signed on its behalf by the undersigned, thereunto duly authorized, on the 29th
day of March 2000.
CMS ENERGY CORPORATION
By William T. McCormick, Jr.
-----------------------------
WILLIAM T. MCCORMICK, JR.
CHAIRMAN OF THE BOARD
AND CHIEF EXECUTIVE OFFICER
Pursuant to the requirements of the Securities Exchange Act of 1934, this Annual
Report has been signed below by the following persons on behalf of CMS Energy
Corporation and in the capacities and on the 29th day of March 2000.
Signature Title
--------- -----
(i) Principal executive officer:
Chairman of the Board,
Chief Executive Officer
William T. McCormick, Jr. and Director
--------------------------------------
WILLIAM T. MCCORMICK, JR.
(ii) Principal financial officer:
Senior Vice President,
and Chief Financial Officer
A. M. Wright
--------------------------------------
ALAN M. WRIGHT
(iii) Controller or principal accounting officer:
Senior Vice President, Controller
P. D. Hopper and Chief Accounting Officer
--------------------------------------
PRESTON D. HOPPER
(iv) A majority of the Directors including those named above:
John M Deutch* Director
--------------------------------------
JOHN M. DEUTCH
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205
Signature Title
--------- -----
James J. Duderstadt* Director
--------------------------------------
JAMES J. DUDERSTADT
K R Flaherty* Director
--------------------------------------
KATHLEEN R. FLAHERTY
Victor J. Fryling* Director
--------------------------------------
VICTOR J. FRYLING
Earl D. Holton* Director
--------------------------------------
EARL D. HOLTON
W. U. Parfet* Director
--------------------------------------
WILLIAM U. PARFET
Percy A. Pierre* Director
--------------------------------------
PERCY A. PIERRE
Kenneth L. Way* Director
--------------------------------------
KENNETH L. WAY
K. Whipple* Director
--------------------------------------
KENNETH WHIPPLE
John B. Yasinsky* Director
--------------------------------------
JOHN B. YASINSKY
* By Thomas A. McNish
--------------------------------------
THOMAS A. MCNISH, ATTORNEY-IN-FACT
CO-12
206
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange
Act of 1934, Consumers Energy Company has duly caused this Annual Report to be
signed on its behalf by the undersigned, thereunto duly authorized, on the 29th
day of March 2000.
CONSUMERS ENERGY COMPANY
By William T. McCormick Jr.
--------------------------------
WILLIAM T. MCCORMICK, JR.
CHAIRMAN OF THE BOARD
Pursuant to the requirements of the Securities Exchange Act of 1934, this Annual
Report has been signed below by the following persons on behalf of Consumers
Energy Company and in the capacities and on the 29th day of March 2000.
Signature Title
--------- -----
(i) Principal executive officer:
Vice Chairman of the Board,
President and Director
Victor J. Fryling
--------------------------------------
VICTOR J.FRYLING
(ii) Principal financial officer:
Senior Vice President and
A. M. Wright Chief Financial Officer
--------------------------------------
ALAN M. WRIGHT
(iii) Controller or principal accounting officer:
Vice President and
Dennis DaPra Controller
--------------------------------------
DENNIS DAPRA
(iv) A majority of the Directors including those named above:
John M Deutch* Director
--------------------------------------
JOHN M. DEUTCH
CO-13
207
Signature Title
--------- -----
James J. Duderstadt* Director
--------------------------------------
JAMES J. DUDERSTADT
K R Flaherty* Director
--------------------------------------
KATHLEEN R. FLAHERTY
Earl D. Holton* Director
--------------------------------------
EARL D. HOLTON
William T. McCormick, Jr.* Director
--------------------------------------
WILLIAM T. MCCORMICK, JR.
W. U. Parfet* Director
--------------------------------------
WILLIAM U. PARFET
Percy A. Pierre* Director
--------------------------------------
PERCY A. PIERRE
Kenneth L. Way* Director
--------------------------------------
KENNETH L. WAY
K. Whipple* Director
--------------------------------------
KENNETH WHIPPLE
John B. Yasinsky* Director
--------------------------------------
JOHN B. YASINSKY
*By Thomas A. McNish
--------------------------------------
THOMAS A. MCNISH, ATTORNEY-IN-FACT
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208
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange
Act of 1934, Panhandle Eastern Pipe Line Company has duly caused this Annual
Report to be signed on its behalf by the undersigned, thereunto duly authorized,
on the 29th day of March 2000.
PANHANDLE EASTERN PIPE LINE COMPANY
By William T. McCormick, Jr.
---------------------------------
WILLIAM T. MCCORMICK, JR.
CHAIRMAN OF THE BOARD
Pursuant to the requirements of the Securities Exchange Act of 1934, this Annual
Report has been signed below by the following persons on behalf of Panhandle
Eastern Pipe Line Company and in the capacities and on the 29th day of March
2000.
Signature Title
--------- -----
(i) Principal executive officer:
Vice Chairman of the Board,
Chief Executive Officer and Director
William J. Haener
--------------------------------------
WILLIAM J. HAENER
(ii) Principal financial officer:
Senior Vice President,
Chief Financial Officer, Treasurer and Director
A. M. Wright
--------------------------------------
ALAN M. WRIGHT
(iii) Controller or principal accounting officer:
Controller
G. W. Lefelar
--------------------------------------
GARY W. LEFELAR
(iv) A majority of the Directors including those named above:
William T. McCormick, Jr. Director
--------------------------------------
WILLIAM T. MCCORMICK, JR.
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209
EXHIBIT INDEX
CMS ENERGY, CONSUMERS AND PANHANDLE EXHIBITS
Previously Filed
-------------------------
With File As Exhibit
Exhibits Number Number Description
- -------------------------------------------------------------------------------------------------------------------
(3)(a) 1-9513 (3)(a) - Restated Articles of Incorporation of CMS Energy. (3rd qtr. 1999
Form 10-Q)
(3)(b) - By-Laws of CMS Energy.
(3)(c) 1-5611 (3)(c) - Certificate of Amendment to the Articles of Incorporation dated
March 10, 1997 and Restated Articles of Incorporation dated
March 25, 1994 of Consumers. (1996 Form 10-K)
(3)(d) - By-Laws of Consumers.
(3)(e) 1-2921 3.01 - Restated Certificate of Incorporation of Panhandle. (1993 Form 10-K)
(3)(f) - By-Laws of Panhandle.
(4)(a) 2-65973 (b)(1)-4 - Indenture dated as of September 1, 1945, between Consumers and
Chemical Bank (successor to Manufacturers Hanover Trust Company),
as Trustee, including therein indentures supplemental thereto
through the Forty-third Supplemental Indenture dated as of May 1,
1979.
- Indentures Supplemental thereto:
33-31866 (4)(d) - 67th dated as of 11/15/89
33-41126 (4)(c) - 68th dated as of 06/15/93
1-5611 (4) - 69th dated as of 09/15/93 (Form 8-K dated Sep. 21, 1993)
1-5611 (4)(a) - 70th dated as of 02/01/98 (1997 Form 10-K)
1-5611 (4)(a) - 71st dated as of 03/06/98 (1997 Form 10-K)
1-5611 (4)(b) - 72nd dated as of 05/01/98 (1st Qtr. 1998 Form 10-Q)
333-58943 (4)(d) - 73rd dated as of 06/15/98
1-5611 (4)(b) - 74th dated as of 10/29/98 (3rd Qtr. 1998 Form 10-Q)
(4)(b) - 75th dated as of 10/1/99
(4)(c) - 76th dated as of 10/4/99
(4)(d) - 77th dated as of 10/1/99
(4)(e) 1-5611 (4)(b) - Indenture dated as of January 1, 1996 between Consumers and The
Bank of New York, as Trustee. (1995 Form 10-K)
- Indentures Supplemental thereto:
1-5611 (4)(b) - 1st dated as of 01/18/96 (1995 Form 10-K)
1-5611 (4)(a) - 2nd dated as of 09/04/97 (3rd qtr 1997 Form 10-Q)
1-9513 (4)(a) - 3rd 11/04/99 (3rd qtr 1999 Form 10-Q)
(4)(f) 1-5611 (4)(c) - Indenture dated as of February 1, 1998 between Consumers and The
Chase Manhattan Bank, as Trustee. (1997 Form 10-K)
1-5611 (4)(a) - 1st dated as of 05/01/98 (1st Qtr. 1998 Form 10-Q)
333-58943 (4)(b) - 2nd dated as of 06/15/98
210
1-5611 (4)(a) - 3rd 10/29/98 (3rd Qtr. 1998 Form 10-Q)
(4)(g) 33-47629 (4)(a) - Indenture dated as of September 15, 1992 between CMS Energy and NBD
Bank, as Trustee. (Form S-3 filed May 1, 1992)
- Indentures Supplemental thereto:
1-9513 (4) - 1st dated as of 10/01/92 (Form 8-K dated October 1, 1992)
1-9513 (4) (a) - 2nd dated as of 10/01/92 (Form 8-K dated October 1, 1992)
1-9513 (4) - 3rd dated as of 05/06/97 (1st qtr 1997 Form 10-Q)
333-37241 (4)(a) - 4th dated as of 09/26/97 (Form S-3 filed October 6, 1997)
1-9513 (4)(b) - 5th dated as of 11/04/97 (3rd qtr 1997 Form 10-Q)
1-9513 (4)(d) - 6th dated as of 01/13/98 (1997 Form 10-K)
1-9513 (4)(d)(i) - 7th dated as of 01/25/99 (1998 Form 10-K)
1-9513 (4)(d)(ii) - 8th dated as of 02/03/99 (1998 Form 10-K)
1-9513 (4)(a) - 9th dated as of 06/22/99 (2nd qtr 1999 Form 10-Q)
(4)(h) 1-9513 (4)(b) - Indenture between CMS Energy and The Chase Manhattan Bank, as Trustee,
dated as of January 15, 1994. (Form 8-K dated March 29, 1994)
- Indentures Supplemental thereto:
1-9513 (4b) - 1st dated as of 01/20/94 (Form 8-K dated March 29, 1994)
1-9513 (4) - 2nd dated as of 03/19/96 (1st qtr 1996 Form 10-Q)
1-9513 (4)(a)(iv) - 3rd dated as of 03/17/97 (Form 8-K dated May 1, 1997)
333-36115 (4)(d) - 4th dated as of 09/17/97 (Form S-3 filed September 22, 1997)
333-63229 (4)(c) - 5th dated as of 08/26/98 (Form S-4 filed September 10, 1998)
(4)(i) 1-9513 (4a) - Indenture dated as of June 1, 1997, between CMS Energy and The Bank
of New York, as trustee. (Form 8-K filed July 1, 1997)
- Indentures Supplemental thereto:
1-9513 (4)(b) - 1st dated as of 06/20/97 (Form 8-K filed July 1, 1997)
1-9513 (4)(b) - 2nd dated as of 06/01/99 (2nd qtr 1999 Form 10-Q)
Pursuant to Item 601(b)(4)(iii) of Regulation S-K, in lieu of filing
a copy of such agreement, CMS Energy agrees to furnish a copy of such
agreement to the Commission upon request.
(4)(j) 1-5611 (4)(a) - Indenture dated as of March 29, 1999, among CMS Panhandle Holding
Company, Panhandle Eastern Pipe Line Company and NBD Bank, as
Trustee. (1st Qtr. 1999 10-Q)
(4)(k) 1-9513 (4)(b) - 1st Supplemental Indenture dated as of March 29, 1999, among CMS
Panhandle Holding Company, Panhandle Eastern Pipe Line Company and
NBD Bank, as Trustee, including a form of Guarantee by Panhandle
Eastern Pipe Line Company of the obligations of CMS Panhandle
Holding Company. (1st qtr 1999 Form 10-Q)
(4)(l) 33-58552 4 - Indenture, dated as of February 1, 1993, between Panhandle and
Morgan Guaranty Trust Company of New York. (Form S-3 filed February
19, 1993)
(10)(a) 1-9513 (4) - Credit Agreement dated as of July 2, 1997, among CMS Energy, the
Administrative Agent, Collateral Agent, Documentation Agent,
Syndication Agent, Co-Agents and Lead Manager, all as
211
defined therein, and the Exhibits and Schedules thereto. (2nd qtr 1997
Form 10-Q)
333-63229 (4)(f) - 1st Amendment dated 01/30/98. (Form S-4 filed September 10, 1998)
1-9513 (10)(b)(i) - 2nd Amendment dated 11/05/98. (1998 Form 10-K)
1-9513 (10)(a) - 3rd Amendment dated 06/22/99. (2nd qtr 1999 Form 10-Q)
(10)(b) - Form of Employment Agreement entered into by CMS Energy's and
Consumers' executive officers.
(10)(c) 1-5611 (10)(g) - Consumers' Executive Stock Option and Stock Appreciation Rights
Plan effective December 1, 1989. (1990 Form 10-K)
(10)(d) - CMS Energy's Performance Incentive Stock Plan effective February 3,
1988, as amended December 3, 1999.
(10)(e) 1-9513 (10)(m) - CMS Deferred Salary Savings Plan effective January 1, 1994. (1993
Form 10-K)
(10)(f) 1-5611 (10)(n) - CMS Energy and Consumers Annual Executive Incentive Compensation
Plan effective January 1, 1986, as amended January 1995. (1995 Form
10-K)
(10)(g) 1-5611 (10)(o) - Consumers' Supplemental Executive Retirement Plan effective
November 1, 1990. (1993 Form 10-K)
(10)(h) - Supplemental Executive Retirement Plan for Employees of CMS Energy
/ Consumers Energy Company effective January 1, 1982, as amended
December 3, 1999
(10)(i) 33-37977 4.1 - Senior Trust Indenture, Leasehold Mortgage and Security Agreement
dated as of June 1, 1990 between The Connecticut National Bank and
United States Trust Company of New York. (MCV Partnership)
Indenture Supplemental thereto:
33-37977 4.2 - Supplement No. 1 dated as of June 1, 1990. (MCV Partnership)
(10)(j) 1-9513 (28)(b) - Collateral Trust Indenture dated as of June 1, 1990 among Midland
Funding Corporation I, MCV Partnership and United States Trust
Company of New York, Trustee. (3rd qtr 1990 Form 10-Q)
Indenture Supplemental thereto:
33-37977 4.4 - Supplement No. 1 dated as of June 1, 1990. (MCV Partnership)
(10)(k) 1-9513 (10)(v) - Amended and Restated Investor Partner Tax Indemnification Agreement
dated as of June 1, 1990 among Investor Partners, CMS Midland as
Indemnitor and CMS Energy as Guarantor. (1990 Form 10-K)
(10)(l) 1-9513 (19)(d)** - Environmental Agreement dated as of June 1, 1990 made by CMS Energy
to The Connecticut National Bank and Others. (1990 Form 10-K)
(10)(m) 1-9513 (10)(z)** - Indemnity Agreement dated as of June 1, 1990 made by CMS Energy to
Midland Cogeneration Venture Limited Partnership. (1990 Form 10-K)
212
(10)(n) 1-9513 (10)(aa)** - Environmental Agreement dated as of June 1, 1990 made by CMS Energy
to United States Trust Company of New York, Meridian Trust Company,
each Subordinated Collateral Trust Trustee and Holders from time to
time of Senior Bonds and Subordinated Bonds and Participants from
time to time in Senior Bonds and Subordinated Bonds. (1990 Form
10-K)
(10)(o) 33-37977 10.4 - Amended and Restated Participation Agreement dated as of June 1,
1990 among MCV Partnership, Owner Participant, The Connecticut
National Bank, United States Trust Company, Meridian Trust Company,
Midland Funding Corporation I, Midland Funding Corporation II, MEC
Development Corporation and Institutional Senior Bond Purchasers.
(MCV Partnership)
1-5611 (10)(w) - Amendment No. 1 dated as of July 1, 1991. (1991 Form 10-K)
(10)(p) 33-3797 10.4 - Power Purchase Agreement dated as of July 17, 1986 between MCV
Partnership and Consumers. (MCV Partnership)
Amendments thereto:
33-37977 10.5 - Amendment No. 1 dated September 10, 1987. (MCV Partnership)
33-37977 10.6 - Amendment No. 2 dated March 18, 1988. (MCV Partnership)
33-37977 10.7 - Amendment No. 3 dated August 28, 1989. (MCV Partnership)
33-37977 10.8 - Amendment No. 4A dated May 25, 1989. (MCV Partnership)
(10)(q) 1-5611 (10)(y) - Unwind Agreement dated as of December 10, 1991 by and among CMS
Energy, Midland Group, Ltd., Consumers, CMS Midland, Inc., MEC
Development Corp. and CMS Midland Holdings Company. (1991 Form
10-K)
(10)(r) 1-5611 (10)(z) - Stipulated AGE Release Amount Payment Agreement dated as of June 1,
1990, among CMS Energy, Consumers and The Dow Chemical Company.
(1991 Form 10-K)
(10)(s) 1-5611 (10)(aa)** - Parent Guaranty dated as of June 14, 1990 from CMS Energy to MCV,
each of the Owner Trustees, the Indenture Trustees, the Owner
Participants and the Initial Purchasers of Senior Bonds in the MCV
Sale Leaseback transaction, and MEC Development. (1991 Form 10-K)
(10)(t) 1-8157 10.41 - Contract for Firm Transportation of Natural Gas between Consumers
Power Company and Trunkline Gas Company, dated November 1, 1989,
and Amendment, dated November 1, 1989. (1989 Form 10-K of PanEnergy
Corp.)
(10)(u) 1-8157 10.41 - Contract for Firm Transportation of Natural Gas between Consumers
Power Company and Trunkline Gas Company, dated November 1, 1989.
(1991 Form 10-K of PanEnergy Corp.)
(10)(v) 1-2921 10.03 - Contract for Firm Transportation of Natural Gas between Consumers
Power Company and Trunkline Gas Company, dated September 1, 1993.
(1993 Form 10-K)
213
(12) - Statements regarding computation of CMS Energy's Ratio of Earnings
to Fixed Charges.
(16)(b) 1-0291 (16)(b) - Letter of Deloitte & Touche LLP
(Form 8-K/A dated July 19, 1999)
(21)(a) - Subsidiaries of CMS Energy.
(21)(b) - Subsidiaries of Consumers.
(23)(a) - Consent of Arthur Andersen LLP for CMS Energy.
(23)(b) - Consent of Arthur Andersen LLP for Consumers.
(24)(a) - Power of Attorney for CMS Energy.
(24)(b) - Power of Attorney for Consumers.
(27)(a) - Financial Data Schedule UT for CMS Energy.
(27)(b) - Financial Data Schedule UT for Consumers.
(27)(c) - Financial Data Schedule UT for Panhandle.
** Obligations of only CMS Holdings and CMS Midland, second tier subsidiaries
of Consumers, and of CMS Energy but not of Consumers.
Exhibits listed above which have heretofore been filed with the Securities and
Exchange Commission pursuant to various acts administered by the Commission, and
which were designated as noted above, are hereby incorporated herein by
reference and made a part hereof with the same effect as if filed herewith.