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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, DC 20549
Amendment No. 3
FORM 10-K/A
(X) ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
For the Fiscal Year Ended December 31, 2000
OR
( ) TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
For the Transition Period from to
Commission Registrant, State of Incorporation, I.R.S. Employer
File Number Address and Telephone Number Identification No.
1-8809 SCANA Corporation 57-0784499
(a South Carolina Corporation)
1426 Main Street, Columbia,
South Carolina 29201
(803) 217-9000
1-3375 South Carolina Electric & Gas Company 57-0248695
(a South Carolina Corporation)
1426 Main Street, Columbia,
South Carolina 29201
(803) 217-9000
1-11429 Public Service Company of North
Carolina, Incorporated 56-2128483
(a South Carolina Corporation)
1426 Main Street, Columbia,
South Carolina 29201
(803) 217-9000
Securities registered pursuant to Section 12(b) of the Act:
Each of the following classes or series of securities is registered on the New
York Stock Exchange.
Title of each class Registrant
Common Stock, without par value SCANA Corporation
5% Cumulative Preferred Stock South Carolina Electric & Gas Company
par value $50 per share
7.55% Trust Preferred Securities, South Carolina Electric & Gas Company
Series A liquidation value $25 per
Trust Preferred Security
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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
Indicate by check mark if disclosure of delinquent filers pursuant to
Item 405 of Regulation S-K is not contained herein, and will not be contained,
to the best of registrant's knowledge, in definitive proxy or information
statements incorporated by reference in Part III of this Form 10-K or any
amendment to this Form 10-K.
SCANA Corporation ( )
South Carolina Electric & Gas Company ( )
Public Service Company of North Carolina, Incorporated (X)
The aggregate market value of voting stock held by non-affiliates of
SCANA Corporation was $2.8 billion at February 28, 2001, based on a price of
$27.21. Each of the other registrants is a wholly-owned subsidiary of SCANA
Corporation and has no voting stock other than its common stock. A description
of registrants' common stock follows:
Shares Outstanding
Registrant Description of Common Stock at February 28, 2001
---------- --------------------------- --------------------
SCANA Corporation Without Par Value 104,729,131
South Carolina Electric
and Gas Company $4.50 Par Value 40,296,147
Public Service Company of
North Carolina, Incorporated Without Par Value 1,000
Documents incorporated by reference: Specified sections of SCANA
Corporation's 2001 Proxy Statement, dated March 19, 2001, in connection with its
2001 Annual Meeting of Stockholders, are incorporated by reference in Part III
hereof.
This combined Form 10-K/A is separately filed by SCANA Corporation, South
Carolina Electric & Gas Company and Public Service Company of North Carolina,
Incorporated. Information contained herein relating to any individual company is
filed by such company on its own behalf. Each company makes no representation as
to information relating to the other companies.
Public Service Company of North Carolina, Incorporated meets the conditions set
forth in General Instruction I (1) (a) and (b) of Form 10-K and therefore is
filing this form with the reduced disclosure format allowed under General
Instruction I (2).
The undersigned registrants hereby amend the ratios of earnings to
fixed charges (SEC method) in Item 1. Business and included in Exhibit 12.01,
Statement Re Computation of Ratios.
PART I
ITEM 1. BUSINESS
ORGANIZATION
SCANA, a South Carolina corporation having general business powers, was
incorporated on October 10, 1984, and registered as a public utility holding
company under PUHCA on February 10, 2000, concurrent with the completion of its
acquisition of PSNC. SCANA holds, directly or indirectly, all of the capital
stock of each of its subsidiaries except for the preferred stock of SCE&G, the
preferred securities of SCE&G Trust I and 30 percent of an indirect subsidiary.
SCANA and its subsidiaries (the Company) had 5,426 full-time, permanent
employees as of February 28, 2001 as compared to 5,488 full-time, permanent
employees as of February 29, 2000. SCE&G was incorporated under the laws of
South Carolina in 1924, and is an operating public utility. SCE&G had 2,412
full-time, permanent employees as of February 28, 2001 as compared to 3,771
full-time, permanent employees as of February 29, 2000. Prior to being acquired
by SCANA, PSNC was incorporated under the laws of North Carolina in 1938.
Subsequent to its acquisition, PSNC is incorporated under the laws of South
Carolina. PSNC is an operating public utility in North Carolina with 653
full-time, permanent employees as of February 28, 2001 as compared to 879
full-time, permanent employees as of February 29, 2000.
SEGMENTS OF BUSINESS
SCANA neither owns nor operates any physical properties. It has 11
direct, wholly owned subsidiaries that are engaged in the functionally distinct
operations described below. It also has investments in two LLCs: one has built
and operates a cogeneration facility in Charleston, South Carolina and the other
has constructed and operates a lime production facility in Charleston, South
Carolina. SCANA also has four other direct, wholly owned subsidiaries that are
in liquidation.
Information with respect to major segments of business for the years
ended December 31, 2000, 1999 and 1998 is contained in Management's Discussion
and Analysis of Financial Condition and Results of Operations for SCANA and
SCE&G and the Notes to Consolidated Financial Statements appearing in Item 8,
FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA for SCANA (Note 14), SCE&G (Note 13)
and PSNC (Note 14). All such information is incorporated herein by reference.
Regulated Utilities
SCE&G is a regulated public utility engaged in the generation,
transmission, distribution and sale of electricity and in the purchase and sale,
primarily at retail, of natural gas in South Carolina. SCE&G also renders urban
bus service in the metropolitan area of Columbia, South Carolina. SCE&G's
business is subject to seasonal fluctuations. Generally, sales of electricity
are higher during the summer and winter months because of air-conditioning and
heating requirements, and sales of natural gas are greater in the winter months
due to heating requirements.
SCE&G's electric service area extends into 24 counties covering more than
15,000 square miles in the central, southern and southwestern portions of South
Carolina. The service area for natural gas encompasses all or part of 31 of the
46 counties in South Carolina and covers more than 21,000 square miles. The
total population of the counties representing the combined service area is
approximately 2.5 million.
Predominant industries in the areas served by SCE&G include: synthetic
fibers; chemicals; fiberglass; paper and wood; metal fabrication; stone, clay
and sand mining and processing; and textile.
GENCO owns and operates Williams Station and sells electricity solely to
SCE&G. Fuel Company acquires, owns and provides financing for SCE&G's nuclear
fuel, fossil fuel and sulfur dioxide emission allowance requirements.
Pipeline Corporation is engaged in the purchase, transmission and sale of
natural gas on a wholesale basis to distribution companies and directly to
industrial customers in 41 counties throughout South Carolina. Pipeline
Corporation owns LNG liquefaction and storage facilities. It also supplies the
natural gas for SCE&G's gas distribution system. Other resale customers include
municipalities and county gas authorities and gas utilities. The industrial
customers of Pipeline Corporation are primarily engaged in the manufacturing or
processing of ceramics, paper, metal, food and textiles. Pipeline Corporation
also operates a 62-mile six-inch propane pipeline that is owned by Suburban
Propane, L.P. of Whippany, New Jersey.
On February 10, 2000 SCANA completed its acquisition of PSNC. PSNC is a
public utility engaged primarily in transporting, distributing and selling
natural gas to approximately 370,000 residential, commercial and industrial
customers. PSNC provides service to 25 of its 28 franchised counties covering
approximately 11,500 square miles in North Carolina. The industrial customers of
PSNC include manufacturers or processors of textiles, chemicals, ceramics and
clay products, glass, automotive products, minerals, pharmaceuticals, plastics,
metals, electronic equipment, furniture and a variety of food and tobacco
products. PSNC, through wholly owned, non-regulated subsidiaries, refuels
natural gas vehicles and converts gasoline-fueled vehicles to natural gas.
Effective January 1, 2001, PSNC's gas brokering activities were transferred to
Energy Marketing.
Nonregulated Businesses
Energy Marketing markets electricity, natural gas and other light
hydrocarbons primarily in the southeast. Energy Marketing, also provides
energy-related risk management services to producers and customers. In addition,
SCANA Energy, a division of Energy Marketing, markets natural gas to
approximately 432,000 customers in Georgia's deregulated natural gas market.
SCI owns and operates a 500-mile fiber optics telecommunications network
in South Carolina. In addition, SCI provides tower site construction, management
and rental services in South Carolina and Georgia. SCI also owns an 800 Mhz
radio service network within the state, and in January 2001, signed a letter of
intent to sell the network. The sale is expected in April 2001. SCANA
Communications Holdings, Inc. (SCH), a Delaware corporation and a wholly owned
subsidiary of SCI, has investments in Powertel, Inc., ITC Holding Company, Inc.,
ITC^DeltaCom, Inc., and Knology, Inc., which are telecommunications services
companies in the southeastern United States. On August 28, 2000 SCH announced
that Powertel has agreed to be acquired by either Deutsche Telekom AG or
VoiceStream Wireless Corporation, as further discussion under "Other" in the
Liquidity and Capital Resources section of Management's Discussion and Analysis
of Financial Condition and Results of Operations for SCANA.
ServiceCare, Inc. is engaged in providing energy-related products and
services beyond the energy meter. Its primary businesses are providing
homeowners with service contracts on their home appliances and home security
services. ServiceCare has announced the sale of its home security business
expected to be completed in March 2001.
Primesouth, Inc. is engaged in power plant management and maintenance
services.
SCANA Resources, Inc. conducts energy-related businesses and provides
energy-related services.
Service Company
SCANA Services, Inc. provides administrative, management and other services
to the subsidiaries and business units within the Company.
COMPETITION
For a discussion of the impact of competition, see the Competition
section of Management's Discussion and Analysis of Financial Condition and
Results of Operations for SCANA and SCE&G.
CAPITAL REQUIREMENTS AND FINANCING PROGRAM
Capital Requirements
The Company's cash requirements arise primarily from SCE&G's and PSNC's
operational needs, the Company's construction program, the need to fund the
activities or investments of SCANA's nonregulated subsidiaries and payment of
dividends. The ability of SCANA's regulated subsidiaries to replace existing
plant investment, as well as to expand to meet future demand for electricity and
gas, will depend upon their ability to attract the necessary financial capital
on reasonable terms. SCANA's regulated subsidiaries recover the costs of
providing services through rates charged to customers. Rates for regulated
services are generally based on historical costs. Depending on customer growth
and inflation, and as the regulated subsidiaries continue their ongoing
construction programs, it may be necessary to seek increases in rates. The
Company's future financial position and results of operations will be affected
by the regulated subsidiaries' ability to obtain adequate and timely rate and
other regulatory relief, if requested.
For a discussion of the impact of various rate matters on the Company's
capital requirements, see Regulatory Matters in the Liquidity and Capital
Resources section of Management's Discussion and Analysis of Financial Condition
and Results of Operations for SCANA and SCE&G and the Notes to Consolidated
Financial Statements appearing in Item 8, FINANCIAL STATEMENTS AND SUPPLEMENTARY
DATA for SCANA (Note 4), SCE&G (Note 3) and PSNC (Note 5).
During 2001 the Company is expected to meet its capital requirements
principally through internally generated funds (approximately 61 percent, after
payment of dividends) and the incurrence of additional short-term and long-term
indebtedness. Sales of additional equity securities may also occur. The Company
expects that it has or can obtain adequate sources of financing to meet its
projected cash requirements for the next 12 months and for the foreseeable
future.
The Company's current estimates of its cash requirements for construction
and nuclear fuel expenditures, which are subject to continuing review and
adjustment, for 2001 and the two-year period 2002-2003 are as follows:
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Type of Facilities 2002-2003 2001
------------------ --------- ----
(Millions of Dollars)
South Carolina Electric & Gas Company:
Electric Plant:
Generation $329 $249
Transmission 43 22
Distribution 178 83
Other 17 15
Nuclear Fuel 36 26
Gas 38 20
Common 17 6
Other 1 1
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Total SCE&G 659 422
PSNC Gas 91 42
Other Companies Combined 193 63
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Total $943 $527
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During 2000 SCE&G and GENCO expended approximately $23.2 million and
$0.5 million, respectively, as part of a program to extend the operating lives
of certain non-nuclear generating facilities. Additional improvements to be made
under the program during 2001, included in the table above, are estimated to
cost approximately $80.3 million for SCE&G.
In addition to the capital requirements for 2001 described above, the
Company, SCE&G and PSNC will require approximately $41.5 million, $28.2 million
and $4.3 million, respectively, to refund and retire outstanding securities and
obligations in 2001. For the years 2002-2005, the Company has an aggregate of
$1,705.4 million of long-term debt maturing, which includes an aggregate of
$455.2 million for SCE&G, $2.2 million of purchase or sinking fund requirements
for SCE&G's preferred stock and $22.5 million for PSNC. SCE&G's long-term debt
maturities for the years 2002-2005 include approximately $94.0 million for
sinking fund requirements, of which $93.9 million may be satisfied by deposit
and cancellation of bonds issued upon the basis of property additions or bond
retirement credits.
SCANA and Westvaco each own a 50 percent interest in Cogen South LLC
(Cogen). Cogen was formed to build and operate a cogeneration facility at
Westvaco's Kraft Division Paper Mill in North Charleston, South Carolina. The
facility began operations in March 1999. On September 10, 1998, the contractor
in charge of construction filed suit in Circuit Court seeking approximately $52
million from Cogen, alleging that it incurred construction cost overruns
relating to the facility and that the construction contract provides for
recovery of these costs. In addition to Cogen, Westvaco, SCE&G and SCANA were
also named as defendants in the suit. SCANA and the other defendants believe the
suit is without merit and are mounting an appropriate defense. SCANA and SCE&G
do not believe that the resolution of this issue will have a material impact on
their results of operations, cash flows or financial position.
On October 15, 1999 FERC notified SCE&G of its agreement with SCE&G's
plan to reinforce Lake Murray Dam in order to maintain the lake in case of an
extreme earthquake. SCE&G and FERC have been discussing possible reinforcement
alternatives for the dam over the past several years as part of SCE&G's ongoing
hydroelectric operating license with FERC. Until discussions are concluded, it
is not possible to finalize the cost of the project; however, it is possible
that the cost could range up to $250 million. Although any costs incurred by
SCE&G are expected to be recoverable through electric rates, SCE&G also is
exploring alternative sources of funding. The project is expected to be
completed in 2004.
On September 21, 1999 SCE&G announced a $256 million gas turbine
generator project in Aiken County, South Carolina. Two combined-cycle turbines
will burn natural gas to produce 300 megawatts of new electric generation and
use exhaust heat to replace coal-fired steam that powers two existing 75
megawatt turbines at the Urquhart Generating Station. The turbine project is
scheduled to be completed by June 2002.
On October 7, 2000 Summer Station was removed from service for a planned
maintenance and refueling outage scheduled to last 38 1/2 days. During initial
inspection activities, plant personnel discovered a small leak coming from a
hole in a weld in a primary coolant system pipe. SCE&G performed extensive
ultrasonic testing of similar welds in the cooling system, which confirmed that
the problem was limited to this single weld. A root cause analysis determined
that the cause of the crack was primary water stress corrosion cracking. The
repair involved cutting out a twelve-inch long spool of the pipe, which included
the entire weld, and installing a new spool piece. Repairs have been completed
and the integrity of the new welds have been verified through extensive testing.
The plant was returned to service in March 2001. The NRC was closely involved
throughout this process and approved SCE&G's actions to repair the crack, as
well as the restart schedule. SCE&G will continue to monitor primary coolant
system pipes during the next outage, scheduled for Spring of 2002. SCE&G
recorded a pretax charge of approximately $6 million in the fourth quarter of
2000 to expense repair costs to date. Additional costs that may be recorded in
the first quarter of 2001 are not expected to be material. The cost of
replacement power is expected to be recovered through SCE&G's electric fuel
adjustment clause.
In January 2001 SCE&G's 385 megawatt coal-fired Cope Generating Station
was taken out of service due to an electrical ground in the generator. The unit
is expected to be returned to service in Spring 2001. The cost of replacement
power is expected to be recovered through SCE&G's fuel adjustment clause.
Financing Program
SCANA and PSNC each have in effect a medium-term note program for the
issuance from time to time of unsecured medium-term debt securities. At December
31, 2000 SCANA had registered with the SEC and available for issuance $1 billion
under its program, the proceeds of which may be used to refinance indebtedness
incurred in connection with the acquisition of PSNC, to fund additional business
activities in nonutility subsidiaries, to reduce short-term debt or for general
corporate purposes.
SCE&G's First and Refunding Mortgage Bond Indenture, dated April 1, 1945
(Old Mortgage), contains provisions prohibiting the issuance of additional bonds
thereunder (Class A Bonds) unless net earnings (as therein defined) for 12
consecutive months out of the 18 months prior to the month of issuance are at
least twice the annual interest requirements on all Class A Bonds to be
outstanding (Bond Ratio). For the year ended December 31, 2000 the Bond Ratio
was 6.43. The Old Mortgage allows the issuance of additional Class A Bonds to an
additional principal amount equal to (i) 70 percent of unfunded net property
additions (which unfunded net property additions totaled approximately $1,452
million at December 31, 2000), (ii) retirements of Class A Bonds (which
retirement credits totaled $68.4 million at December 31, 2000), and (iii) cash
on deposit with the Trustee.
SCE&G is subject to a bond indenture dated April 1, 1993 (New Mortgage)
covering substantially all of its electric properties under which its future
mortgage-backed debt (New Bonds) will be issued. New Bonds are issued under the
New Mortgage on the basis of a like principal amount of Class A Bonds issued
under the Old Mortgage which have been deposited with the Trustee of the New
Mortgage (of which $665 million were available for such purpose at December 31,
2000). New Bonds will be issuable under the New Mortgage only if adjusted net
earnings (as therein defined) for 12 consecutive months out of the 18 months
immediately preceding the month of issuance are at least twice the annual
interest requirements on all outstanding bonds (including Class A Bonds) and New
Bonds to be outstanding (New Bond Ratio). For the year ended December 31, 2000
the New Bond Ratio was 6.34.
The following additional financing transactions have occurred since
January 1, 2000:
o On February 8, 2000 the Company issued $400 million of two-year floating
rate notes maturing February 8, 2002. The interest rate on the notes is
reset quarterly based on three-month LIBOR plus 50 basis points. The
proceeds from these privately sold notes were used to consummate SCANA's
acquisition of PSNC. On February 10, 2000 SCANA borrowed $300 million for a
three-year term under a credit agreement with several banks. The interest
rate is reset every one, two, three or six months and is based on LIBOR
plus 100 basis points. These funds also were used to consummate SCANA's
acquisition of PSNC.
o On June 14, 2000 SCE&G issued $150 million of First Mortgage Bonds having
an annual interest rate of 7.50 percent and maturing on June 15, 2005. The
proceeds from the sale of these bonds were used to pay the maturity of
SCE&G's $100 million First Mortgage Bonds due June 15, 2000, to reduce
short-term debt and for general corporate purposes.
o On July 13, 2000 SCANA issued $300 million two-year floating rate notes
maturing on July 15, 2002. The interest rate is reset quarterly based on
three-month LIBOR plus 65 basis points. Proceeds from the debt were used to
repay medium-term notes totaling $170 million, to reduce short-term debt
and for general corporate purposes.
o On January 24, 2001 SCANA issued $202 million two-year floating rate notes
maturing on January 24, 2003. The interest rate is reset quarterly based on
three-month LIBOR plus 110 basis points. Proceeds from the debt were used
to reduce short-term debt and for general corporate purposes.
o On January 24, 2001 SCE&G issued $150 million First Mortgage Bonds having
an annual interest rate of 6.70 percent and maturing on February 1, 2011.
The proceeds from the sale of these bonds were used to reduce short-term
debt and for general corporate purposes.
o On February 16, 2001 PSNC issued $150 million of medium-term notes having
an annual interest rate of 6.625 percent and maturing on February 15, 2011.
These funds were used to reduce short-term debt and for general corporate
purposes.
The Company's electric and natural gas businesses are seasonal in
nature, with the primary demand for electricity being experienced during summer
and winter and the primary demand for natural gas being experienced during
winter. As a result of the significant increase during the latter half of 2000
in the cost to the Company of natural gas and the colder than normal weather
experienced in December, the Company experienced significant increases in its
working capital requirements, contributing to the need for the financings by
SCANA and PSNC in early 2001 described above.
Without the consent of at least a majority of the total voting power of
SCE&G's preferred stock, SCE&G may not issue or assume any unsecured
indebtedness if, after such issue or assumption, the total principal amount of
all such unsecured indebtedness would exceed ten percent of the aggregate
principal amount of all of SCE&G's secured indebtedness and capital and surplus;
however, no such consent is required to enter into agreements for payment of
principal, interest and premium for securities issued for pollution control
purposes.
Pursuant to Section 204 of the Federal Power Act, SCE&G and GENCO must
obtain FERC authority to issue short-term debt. FERC has authorized SCE&G to
issue up to $250 million of unsecured promissory notes or commercial paper with
maturity dates of 12 months or less, but not later than December 31, 2002. GENCO
has not sought such authorization.
The SEC order authorizing the Company to register as a public utility
holding company under PUHCA imposes various limits during the three years ending
February 11, 2003 (the Authorization Period) on SCANA's, SCE&G's and PSNC's
ability to issue long- and short-term debt. The order, as amended, requires
SCANA, SCE&G and PSNC to maintain common equity of at least 30 percent of their
consolidated capitalization. SCANA's issuance of capital securities is limited
to $2.385 billion, including securities issued to repay acquisition debt
financing. SCANA's short-term borrowings outstanding are limited to $450
million. SCE&G and PSNC may issue commercial paper and establish bank lines of
credit for $300 million and $200 million, respectively. In addition, PSNC
requires SEC approval under PUHCA prior to issuing long-term debt. SCANA plans
to request such approval for PSNC in 2001.
At December 31, 2000 SCE&G had $250 million of unused authorized lines of
credit which consist of a credit agreement for a maximum of $250 million to
support the issuance of commercial paper. SCE&G's commercial paper outstanding
at December 31, 2000 and 1999 was $117.5 million and $143.1 million,
respectively. In addition, Fuel Company has a credit agreement for a maximum of
$125 million with the full amount available at December 31, 2000. The credit
agreement supports the issuance of short-term commercial paper for the financing
of nuclear and fossil fuels and sulfur dioxide emission allowances. Fuel Company
commercial paper outstanding at December 31, 2000 was $70.2 million. This
commercial paper and amounts outstanding under the revolving credit agreement,
if any, are guaranteed by SCE&G.
At December 31, 2000 PSNC had $125 million authorized lines of credit
which consist of a credit agreement for a maximum of $125 million to support the
issuance of commercial paper. Unused lines of credit at December 31, 2000
totaled $125 million. PSNC's commercial paper outstanding on December 31, 2000
was $125 million.
SCE&G's Restated Articles of Incorporation prohibit issuance of
additional shares of preferred stock without the consent of the preferred
stockholders unless net earnings (as defined therein) for the 12 consecutive
months immediately preceding the month of issuance are at least one and one-half
times the aggregate of all interest charges and preferred stock dividend
requirements (Preferred Stock Ratio). For the year ended December 31, 2000 the
Preferred Stock Ratio was 2.09.
As a result of SCANA's acquisition of PSNC on February 10, 2000, PSNC
shareholders were paid $212 million in cash and 17.4 million shares of SCANA
common stock valued at approximately $488 million. In connection with this
transaction, certain SCANA shareholders were paid $488 million in cash for 16.3
million shares of SCANA common stock. During 2000, shares for the SPSP and the
Investor Plus Plan were purchased on the open market.
The Company's ratios of earnings to fixed charges (SEC method) were 2.47,
2.77, 3.38, 3.27 and 3.38 for the years ended December 31, 2000, 1999, 1998,
1997 and 1996, respectively. For SCE&G these ratios were 4.24, 3.71, 4.40, 3.85
and 3.80 for the same periods. For PSNC these ratios were 3.05 for the year
ended December 31, 2000 and 3.18, 3.22, 3.41 and 3.62 for the fiscal years ended
September 30, 1999, 1998, 1997 and 1996, respectively.
ELECTRIC OPERATIONS
Electric Sales
In 2000 residential sales of electricity accounted for 40% of electric
sales revenues; commercial sales 30%; industrial sales 19%; sales for resale 3%;
and all other 8%. The Company's KWH sales by classification, excluding volumes
attributable to the cumulative effect of accounting change, for the years ended
December 31, 2000 and 1999 are presented below:
Sales
KWH (Millions)
----------------------------------------------------------------------------
CLASSIFICATION 2000 1999 % CHANGE
---------------------------------- -----------------------------------------
Residential 6,665 6,269 6%
Commercial 6,305 5,950 6%
Industrial 6,665 6,140 9%
Sales for resale 1,222 1,189 3%
Other 553 518 7%
---------------------------------- -----------------------------
Total Territorial 21,410 20,066 7%
Negotiated Market Sales Tariff 1,942 1,678 16%
---------------------------------- -----------------------------
Total 23,352 21,744 7%
================================== =============================
Sales for resale includes electricity furnished for resale to two
municipalities and two electric cooperatives. Sales under the Negotiated Market
Sales Tariff during 2000 include sales to 36 investor-owned utilities and
registered marketers, seven electric cooperatives, two municipalities and four
federal/state electric agencies. During 1999 sales under the Negotiated Market
Sales Tariff included sales to 32 investor-owned utilities and registered
marketers, seven electric cooperatives, two municipalities and four
federal/state electric agencies.
The electric sales volume from residential sales increased for 2000
primarily as a result of colder weather. During 2000 the Company recorded a net
increase of 13,701 customers, increasing its total customers to 537,253. The
all-time peak demand of 4,211 MW was set on July 20, 2000.
Electric Interconnections
SCE&G purchases all of the electric generation of Williams Station,
owned by GENCO, under a Unit Power Sales Agreement which has been approved by
FERC. Williams Station has a generating capacity of 580 MW.
SCE&G's transmission system is part of the interconnected grid
extending over a large part of the southern and eastern portions of the nation.
SCE&G, Virginia Power Company, Duke Power Company, Carolina Power & Light
Company, Yadkin, Incorporated and South Carolina Public Service Authority
(Santee Cooper) are members of the Virginia-Carolinas Reliability Group, one of
several geographic divisions within the Southeastern Electric Reliability
Council. This Council provides for coordinated planning for reliability among
bulk power systems in the Southeast. SCE&G is also interconnected with Georgia
Power Company, Savannah Electric & Power Company, Oglethorpe Power Corporation
and the Southeastern Power Administration's Clark Hill Project.
On February 9, 2000 the FERC issued FERC Order 2000. The Order requires
utilities which operate electric transmission systems to submit plans for the
possible formation of an RTO. On October 16, 2000 the Company and two other
southeastern electric utilities filed a joint request with FERC to establish
GridSouth Transco, LLC (GridSouth). When operational, GridSouth will function as
an independent transmission company. Initially, the three utilities will
continue to own their respective transmission networks, while GridSouth will
provide planning and operational oversight of the electric transmission grid.
FERC gave provisional approval to GridSouth in March 2001. GridSouth is expected
to be operational by December 2001.
Fuel Costs
The following table sets forth the average cost of nuclear fuel and
coal and the weighted average cost of all fuels (including oil and natural gas)
used by the Company for the years 1998-2000.
2000 1999 1998
---- ---- ----
Nuclear:
Per million BTU $.46 $.46 $.46
Coal:
SCE&G
Per ton $37.10 $39.37 $38.19
Per million BTU 1.48 1.50 1.57
GENCO
Per ton $38.98 $41.46 $41.67
Per million BTU 1.51 1.63 1.61
Weighted Average Cost of All Fuels:
Per million BTU $1.31 $1.32 $1.26
Fuel Supply
The following table shows the sources and approximate percentages of
the Company's total KWH generation by each category of fuel for the years
1998-2000 and the estimates for 2001 and 2002.
Percent of Total KWH Generated
------------------------------------------------------------
Estimated Actual
--------------------- -----------------------------------
2002 2001 2000 1999 1998
---- ---- ---- ---- ----
Coal 67% 73% 77% 73% 69%
Nuclear 20 20 18 22 25
Hydro 6 5 4 4 5
Natural Gas & Oil 7 2 1 1 1
--------- ----------- -- -----------------------------------
100% 100% 100% 100% 100%
========= =========== == ===================================
Coal is used at all five of SCE&G's fossil fuel-fired plants and
GENCO's Williams Station. Unit train deliveries are used at all of these plants.
On December 31, 2000 SCE&G had approximately a 37-day supply of coal in
inventory and GENCO had approximately a 43-day supply.
Coal is obtained through contracts and purchases on the spot market.
Spot market purchases are expected to continue for coal requirements in excess
of those provided by SCANA's existing contracts.
Contract coal is purchased from ten suppliers located in eastern
Kentucky, Tennessee, southwest Virginia and West Virginia. Contract commitments,
which expire at various times from 2001 through 2009, approximate 6.1 million
tons annually, which is 88 percent of total expected coal purchases for 2001.
Sulfur restrictions on the contract coal range from 0.75 percent to 1.5 percent.
SCE&G is building two combined-cycle turbines that will burn natural
gas to produce 300 megawatts of new electric generation and use exhaust heat to
replace coal-fired steam that powers two existing 75 megawatt turbines at the
Urquhart Generating Station. The turbine project is schedule to be completed by
June 2002.
The Company believes that SCE&G's and GENCO's operations are in
compliance with all existing regulations relating to the discharge of sulfur
dioxide and nitrogen oxides. The Company is unaware that any more stringent
sulfur content requirements for existing plants are contemplated at the state
level by DHEC.
SCE&G has adequate supplies of uranium or enriched uranium product
under contract to manufacture nuclear fuel for Summer Station through 2005. The
following table summarizes all contract commitments for the stages of nuclear
fuel assemblies:
Remaining Expiration
Commitment Contractor Regions(1) Date
Enrichment United States Enrichment Corporation (2) 16-18 2005
Fabrication Westinghouse Electric Corporation 16-21 2009
(1) A region represents approximately one-third to one-half of the nuclear
core in the reactor at any one time. Region 15 was loaded in 2001.
Region 16 will be loaded in 2002.
(2) Contract provisions for the delivery of enriched uranium product
encompass supply, conversion and enrichment services.
SCE&G has on-site spent nuclear fuel storage capability until at least
2006 and expects to be able to expand its storage capacity to accommodate the
spent fuel output for the life of the plant through spent fuel pool reracking,
dry cask storage or other technology as it becomes available. In addition, there
is sufficient on-site storage capacity over the life of Summer Station to permit
storage of the entire reactor core in the event that complete unloading should
become desirable or necessary for any reason. (See Nuclear Fuel Disposal under
Environmental Matters for information regarding the contract with the DOE for
disposal of spent fuel.)
On October 7, 2000 Summer Station was removed from service for a
planned maintenance and refueling outage. See preceding discussion of this
matter on page 8.
Decommissioning
For information regarding the decommissioning of Summer Station, see
Note 1H, Nuclear Decommissioning, of the Notes to Consolidated Financial
Statements appearing in Item 8, FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA for
SCANA and SCE&G.
GAS OPERATIONS
Gas Sales - Regulated
In 2000 the Company's residential sales accounted for 38% of gas sales
revenues; commercial sales 22%; industrial sales 28%; sales for resale 8%; and
other 4%. During the same period, SCE&G's residential sales accounted for 41% of
gas sales revenues; commercial sales 32%; and industrial sales 27%. Also during
the same period, PSNC's residential sales accounted for 64% of gas sales
revenues; commercial sales 27%; and industrial sales 9%. Dekatherm sales by
classification, excluding volumes associated with the cumulative effect of
accounting change, for the years ended December 31, 2000 and 1999 are presented
below:
Sales
Dekatherms (000)
-------------------------------------------------------------------------------------------------------------------------------
The Company SCE&G PSNC
% % %
CLASSIFICATION 2000 1999* Change 2000 1999 Change 2000 1999 Change
-------------------------- ---------- ------------ ------------ ---------- --------- ---------- --------- --------- -----------
Residential 35,365 11,823 199.1% 12,235 11,823 3.5% 23,130 19,976 15.8%
Commercial 25,039 11,790 112.4% 12,076 11,699 3.2% 12,850 11,609 10.7%
Industrial 61,662 61,748 17,129 17,958 (4.6%) 5,307 6,349 (16.4%)
(0.1%)
Sales for Resale 16,931 15,947 6.2% - -
- - - -
Transportation gas 31,634 2,252 1,304.7% 2,085 1,975 5.6% 29,372 28,750 2.2%
-------- ---------- -- ----- ------- ------ ------
Total 170,631 103,560 64.8% 43,525 43,455 0.2% 70,659 66,684 6.0%
========================== ========== ============ ============ ========== ========= ========== ========= ========= ===========
*SCANA acquired PSNC effective January 1, 2000 for accounting purposes.
Therefore, the Company's 1999 sales do not include PSNC.
The Company's and SCE&G's gas sales volume increased for 2000 primarily
as a result of customer growth. The Company obtained 354,763 customers when it
acquired PSNC. In addition, during 2000 the Company recorded a net increase of
21,798 customers, increasing its total customers to 637,017. SCE&G recorded a
net increase of 6,103 gas customers, increasing its total customers to 266,348.
PSNC recorded a net increase of 15,148 customers, increasing its total customers
to 370,181.
The demand for gas is affected by the weather, the price relationship
between gas and alternate fuels and other factors.
Pipeline Corporation, operating wholly within the State of South
Carolina, provides natural gas utility and transportation services for its
customers, and supplies natural gas to SCE&G and other wholesale purchasers.
Pipeline Corporation is developing plans for an interstate natural gas pipeline
to ensure adequate supplies to growing gas markets. The anticipated interstate
pipeline will require Pipeline Corporation to file an application for approval
with FERC and other federal and state agencies. Energy Marketing acquires and
sells natural gas in regulated and deregulated markets. Energy Marketing has not
supplied natural gas to any affiliate for use in providing regulated gas utility
services.
Gas Cost and Supply
Pipeline Corporation purchases natural gas under contracts with
producers and marketers on a short-term basis at current price indices and on a
long-term basis for reliability assurance at index prices plus a gas inventory
charge. The gas is brought to South Carolina through transportation agreements
with Southern Natural (expiring in 2005 and 2006) and Transco (expiring in 2008
and 2017). The daily volume of gas that Pipeline Corporation is entitled to
transport under these contracts on a firm basis is 188 MMCF from Southern
Natural and 105 MMCF from Transco. Additional natural gas volumes are brought to
Pipeline Corporation's system as capacity is available for interruptible
transportation. SCE&G, under contract with Pipeline Corporation, is entitled to
receive a daily contract demand of 266,495 dekatherms. The contract allows SCE&G
to receive amounts in excess of this demand based on availability.
During 2000 Pipeline Corporation's average cost per MCF of natural gas
purchased for resale, including firm service demand charges, was $4.42 compared
to $2.99 during 1999. SCE&G's average cost per MCF was $5.35 and $3.73 during
2000 and 1999, respectively.
Pipeline Corporation has engaged in hedging activities on the New York
Mercantile Exchange (NYMEX) of its gas supply pursuant to a limited program
authorized and monitored by the PSC. Any gains or losses associated with that
hedging activity are accounted for in Pipeline Corporation's purchased gas
adjustment clause and, therefore, have no impact on net income.
To meet the requirements of its high priority natural gas customers
during periods of maximum demand, Pipeline Corporation supplements its supplies
of natural gas from two LNG plants. The LNG plants are capable of storing the
liquefied equivalent of 1,880 MMCF of natural gas. Approximately 1,192 MMCF of
gas were in storage at December 31, 2000. On peak days the LNG plants can
regasify up to 150 MMCF per day. Additionally, Pipeline Corporation had
contracted for 6,447 MMCF of natural gas storage space. Approximately 3,713 MMCF
of gas were in storage on December 31, 2000.
PSNC Energy purchases natural gas under contracts with producers and
marketers on a short-term basis at current price indices and on a long-term
basis for reliability assurance at index prices plus a reservation charge. The
gas is brought to North Carolina through transportation agreements with Transco
and Dominion Gas Transmission with expiration dates ranging through 2016. The
daily volume of gas that PSNC Energy is entitled to transport under these
contracts on a firm basis is 259,894 dekatherms from Transco and 30,331
dekatherms from Dominion Gas Transmission. PSNC Energy has submitted non-binding
nominations for firm transportation service on three proposed pipeline projects
to meet incremental capacity requirements beginning in 2003.
During 2000 PSNC Energy's average cost per dekatherm of natural gas
purchased for resale, including firm service demand charges, was $5.63 compared
to $3.71 during 1999.
To meet the requirements of its high priority natural gas customers
during periods of maximum demand, PSNC Energy supplements its supplies of
natural gas with underground natural gas storage services and liquefied natural
gas (LNG) peaking services. Underground natural gas storage service agreements
with Dominion Gas Transmission, Columbia Gas Transmission and Transco provide
for storage capacity of approximately 8,657 MMCF. In addition, PSNC Energy's own
LNG facility is capable of storing the liquefied equivalent of 1,000 MMCF of
natural gas with daily regasification capability of 106 MMCF. Approximately 835
MMCF were in storage at December 31, 2000. LNG storage service agreements with
Transco, Cove Point LNG and Pine Needle LNG provide for approximately 1,266 MMCF
of storage space. At December 31, 2000 approximately 869 MMCF were stored in
these three facilities.
The Company believes that supplies under long-term contract and
supplies available for spot market purchase are adequate to meet existing
customer demands and to accommodate growth.
Curtailment Plans
The PSC has established allocation priorities applicable to the firm
and interruptible capacities of Pipeline Corporation. The curtailment plan
priorities of Pipeline Corporation apply to the resale distribution customers of
Pipeline Corporation, including SCE&G.
Gas Marketing - Nonregulated
Energy Marketing markets natural gas and provides energy-related risk
management services to producers and consumers. Energy Marketing is also a power
marketer, which allows it to buy and sell large blocks of electric capacity in
wholesale markets. In addition, SCANA Energy, a division of Energy Marketing,
markets natural gas to approximately 432,000 customers in Georgia's deregulated
natural gas market.
Although Energy Marketing's activities are primarily focused in the
southeast, Energy Marketing has maintained smaller scale operations in the
Midwest and in California. While Energy Marketing has from time to time been a
customer of the California utilities (PG&E, SoCalEdison and SDG&E), it has not
been a supplier to such companies and does not have material direct or indirect
credit risk related to them.
The Company's Board of Directors has established a Risk Management
Committee which is responsible for developing corporate policies and overseeing
the management of risk within tolerance parameters approved by the Board.
REGULATION
General
SCANA became a registered public utility holding company under PUHCA on
February 10, 2000, concurrent with completion of its acquisition of PSNC. SCANA
and its subsidiaries are subject to the jurisdiction of the SEC as to
financings, acquisitions and diversifications, affiliate transactions and other
matters.
SCE&G is subject to the jurisdiction of the PSC as to retail electric,
gas and transit rates, service, accounting, issuance of securities (other than
short-term promissory notes) and other matters.
Pipeline Corporation is subject to the jurisdiction of the PSC as to
gas rates, service, accounting and other matters.
PSNC is subject to the jurisdiction of the NCUC as to gas rates,
issuance of securities (other than notes with a maturity of two years or less or
renewals of notes over a six-year or shorter period), service, accounting and
other matters.
Federal Energy Regulatory Commission
SCE&G and GENCO are subject to regulation under the Federal Power Act,
administered by FERC and DOE, in the transmission of electric energy in
interstate commerce and in the sale of electric energy at wholesale for resale,
as well as with respect to licensed hydroelectric projects and certain other
matters, including accounting and the issuance of short-term promissory notes.
(See Capital Requirements and Financing Program.)
SCE&G holds licenses under the Federal Water Power Act or the Federal
Power Act with respect to all of its hydroelectric projects. The expiration
dates of the licenses covering the projects are as follows:
License License
Project Expiration Project Expiration
Neal Shoals 2036 Saluda 2007
Stevens Creek 2025 Parr Shoals 2020
Columbia 2000 Fairfield Pumped Storage 2020
SCE&G filed an application for a new license for Columbia on June 30,
1998. The application was officially accepted for filing by FERC notice dated
December 23, 1999, and is currently in environmental review. The current license
for Columbia expired on June 30, 2000; subsequent to that date, FERC issued a
temporary operating license to allow SCE&G to continue to operate the project
until a new license is issued.
At the termination of a license under the Federal Power Act, the United
States government may take over the project covered thereby, or FERC may extend
the license or issue a license to another applicant. If the Federal government
takes over a project or FERC issues a license to another applicant, the original
licensee is entitled to be paid its net investment in the project, not to exceed
fair value, plus severance damages.
For a discussion of SCE&G's agreement with FERC related to reinforcing
the Lake Murray Dam (related to the Saluda hydroelectric project), see previous
discussion under Capital Requirements and see Liquidity and Capital Resources in
Management's Discussion and Analysis of Financial Condition and Results of
Operations for SCANA and SCE&G.
Nuclear Regulatory Commission
SCE&G is subject to regulation by the NRC with respect to the
ownership, operation and decommissioning of Summer Station. The NRC's
jurisdiction encompasses broad supervisory and regulatory powers over the
construction and operation of nuclear reactors, including matters of health and
safety, antitrust considerations and environmental impact. In addition, the
Federal Emergency Management Agency is responsible for the review, in
conjunction with the NRC, of certain aspects of emergency planning relating to
the operation of nuclear plants.
National Energy Policy Act of 1992 and FERC Orders No. 636, 888 and 2000
The Company's regulated business operations were impacted by the NEPA
and FERC Orders No. 636, 888 and 2000. NEPA was designed to create a more
competitive wholesale power supply market by creating "exempt wholesale
generators" and by potentially requiring utilities owning transmission
facilities to provide transmission access to wholesalers. Order No. 636 was
intended to deregulate the markets for interstate sales of natural gas by
requiring that pipelines provide transportation services that are equal in
quality for all gas suppliers whether the customer purchases gas from the
pipeline or another supplier. Orders No. 888 and 2000 require utilities under
FERC jurisdiction that own, control or operate transmission lines to file
nondiscriminatory open access tariffs that offer to others the same transmission
service they provide to themselves and to submit plans for the possible
formation of an RTO. The Company believes it will continue to be able to meet
successfully the challenges of these altered business climates and does not
anticipate there will be any material adverse impact from these Orders on the
Company's results of operations, cash flows, financial position or business
prospects.
RATE MATTERS
For a discussion of the impact of various rate matters, see Regulatory
Matters in the Liquidity and Capital Resources section of Management's
Discussion and Analysis of Financial Condition and Results of Operations for
SCANA and SCE&G, and the Notes to Consolidated Financial Statements appearing in
Item 8, FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA for SCANA (Note 4), SCE&G
(Note 3) and PSNC (Note 5).
General
SCE&G and PSNC's gas rate schedules for their residential and small
commercial customers include a WNA. SCE&G's and PSNC's WNA were approved by the
PSC and NCUC, respectively, and are in effect for bills rendered during the
period from November 1 through April 30 of each year. In each case the WNA
increases tariff rates if weather is warmer than normal and decreases rates if
weather is colder than normal. The WNA does not change the seasonality of gas
revenues; however, it does reduce fluctuations caused by abnormal weather.
Fuel Cost Recovery Procedures
The PSC has established a fuel cost recovery procedure which determines
the fuel component in SCE&G's retail electric base rates annually based on
projected fuel costs for the ensuing 12-month period, adjusted for any
overcollection or undercollection from the preceding 12-month period. SCE&G has
the right to request a formal proceeding at any time should circumstances
dictate such a review. In the April 2000 annual review of the fuel cost
component of electric rates, the PSC decreased the fuel cost component of the
electric rate to 13.30 mills per KWH. For the April 2001 annual review, SCE&G
has filed for an increase in the fuel cost component of electric rates to 15.79
mills per KWH.
SCE&G's gas rate schedules and contracts include mechanisms that allow
it to recover from its customers changes in the actual cost of gas. SCE&G's firm
gas rates allow for the recovery of a fixed cost of gas, based on projections,
as established by the PSC in annual gas cost and gas purchase practice hearings.
Any differences between actual and projected gas costs are deferred and included
when projecting gas costs during the next annual gas cost recovery hearing. In
July 2000 the PSC approved SCE&G's request for an out-of-period adjustment to
increase the cost of gas component from 54.334 cents per therm to 68.835 cents
per therm, effective with the first billing cycle in August 2000. In the October
2000 review the PSC increased the base cost of gas to 78.151 cents per therm. In
December 2000 the PSC approved SCE&G's request for an out-of-period adjustment
to increase the cost of gas component to 99.340 cents per therm, effective with
the first billing cycle in January 2001. In March 2001 the PSC approved SCE&G's
request to decrease the cost of gas component to 79.340 cents per therm,
effective with the first billing cycle in March 2001.
PSNC also operates under two rate provisions in addition to WNA that
serve to reduce fluctuations in PSNC's earnings. First, its Rider D rate
mechanism allows PSNC to recover, in any manner authorized by the NCUC, margin
losses on negotiated gas sales. The Rider D rate mechanism also allows PSNC to
recover from customers all prudently incurred gas costs, including changes in
natural gas prices. Second, PSNC operates with full margin transportation rates.
These rates allow PSNC to earn the same margin on gas delivered to customers
regardless of whether the gas is sold, or only transported, by PSNC to the
customer.
PSNC's rates are established using a base cost of gas approved by the
NCUC, which may be modified periodically to reflect changes in the market price
of natural gas and changes in the rates charged by PSNC's pipeline transporters.
PSNC may file revised tariffs with the NCUC coincident with these changes or it
may track the changes in its deferred accounts for subsequent rate
consideration. The NCUC reviews PSNC's gas purchasing practices annually.
ENVIRONMENTAL MATTERS
General
Federal and state authorities have imposed environmental regulations
and standards relating primarily to air emissions, wastewater discharges and
solid, toxic and hazardous waste management. Developments in these areas may
require that equipment and facilities be modified, supplemented or replaced. The
ultimate effect of these regulations and standards upon existing and proposed
operations cannot be forecast. For a more complete discussion of how these
regulations and standards impact the Company and SCE&G, see the Environmental
Matters section of Management's Discussion and Analysis of Financial Condition
and Results of Operations for SCANA and SCE&G.
Capital Expenditures
In the years 1998 through 2000, the Company's capital expenditures for
environmental control amounted to approximately $98.4 million (including
approximately $88.1 million for SCE&G). This was in addition to expenditures
included in "Other operation and maintenance" expenses, which were approximately
$19.6 million, $18.2 million, and $18.8 million during 2000, 1999 and 1998,
respectively (including approximately $16.6 million, $15.0 million and $16.2
million for SCE&G during 2000, 1999 and 1998, respectively). It is not possible
to estimate all future costs for environmental purposes, but forecasts for
capitalized environmental expenditures for the Company are $23.3 million for
2001 and $192.8 million for the four-year period 2002 through 2005 (including
$22.8 million for 2001 and $129.4 million for the four-year period 2002 through
2005 for SCE&G). These expenditures are included in the Company's and SCE&G's
construction program.
In October 1998 the EPA issued a final rule requiring 22 states,
including South Carolina, to modify their state implementation plans (SIP) to
address the issue of NOx pollution. On May 25, 1999 a federal appeals court
delayed indefinitely the implementation of the rule. On March 3, 2000 the court
affirmed the EPA's NOx rule for the affected states. South Carolina was
subsequently ordered to amend its SIP to achieve significant NOx reductions.
South Carolina failed to submit a revised SIP as required under the CAA, and the
EPA has issued official notice to South Carolina (and a number of other states)
to comply. While not final, South Carolina has proposed NOx reductions that
would require the Company to install pollution control equipment. Because DHEC
had not amended its SIP as of December 31, 2000 to set out or allocate any NOx
reductions, it is not possible to estimate what, if any, capital expenditures
will be required to comply with any potential mandated reductions.
Nuclear Fuel Disposal
The Nuclear Waste Policy Act of 1982 required that the United States
government make available by 1998 a permanent repository for high-level
radioactive waste and spent nuclear fuel and imposes a fee of 1.0 mil per KWH of
net nuclear generation after April 7, 1983. Payments, which began in 1983, are
subject to change and will extend through the operating life of SCE&G's Summer
Station. SCE&G entered into a contract with the DOE on June 29, 1983 providing
for permanent disposal of its spent nuclear fuel by the DOE. The DOE presently
estimates that the permanent storage facility will not be available until 2010.
SCE&G has on-site spent nuclear fuel storage capability until at least 2006 and
expects to be able to expand its storage capacity to accommodate the spent
nuclear fuel output for the life of the plant through spent fuel pool reracking,
dry cask storage or other technology as it becomes available. The Act also
imposes on utilities the primary responsibility for storage of their spent
nuclear fuel until the repository is available.
OTHER MATTERS
With regard to SCE&G's insurance coverage for Summer Station, reference
is made to the Notes to Consolidated Financial Statements (Note 13B for the
Company and Note 12B for SCE&G), which are incorporated herein by reference.
For a description of the Company's investments in various
telecommunications companies, see Other in the Liquidity and Capital Resources
section of Management's Discussion and Analysis of Financial Condition and
Results of Operations for SCANA.
Exhibit 12.01
SCANA CORPORATION
COMPUTATION OF RATIO OF EARNINGS TO FIXED CHARGES
For Each of the Five Years Ended December 31, 2000
(Millions of Dollars)
Years Ended December 31,
-------------------------------------------------------
2000 1999 1998 1997 1996
---- ---- ---- ---- ----
Fixed Charges as defined:
Interest expense $226.1 $143.0 $128.0 $124.6 $125.6
Amortization of debt premium, discount and expense (net) 4.4 3.1 2.7 2.6 2.6
Interest component on rentals 1.2 0.8 0.9 1.8 2.3
Preference security dividend requirement 15.8 15.8 15.8 15.6 8.8
----------------------------------------------------------------- ------------- ----------- ---------- -------- ---------
Total Fixed Charges (A) $247.5 $162.7 $147.4 $144.6 $139.3
================================================================= ============= =========== ========== ======== =========
Earnings, as defined:
Pretax income from continuing operations $374.3 $302.5 $366.2 $344.2 $339.8
Total fixed charges above 247.5 162.7 147.4 144.6 139.3
Distributions from equity investee 5.9 1.3 - - -
Preference security dividend requirements from above (15.8) (15.8) (15.8) (15.6) (8.8)
----------------------------------------------------------------- ------------- ----------- ---------- -------- ---------
Total Earnings (B) $611.9 $450.7 $497.8 $473.2 $470.3
================================================================= ============= =========== ========== ======== =========
Ratio of Earnings to fixed charges (B/A) 2.47 2.77 3.38 3.27 3.38
================================================================= ============= =========== ========== ======== =========
Exhibit 12.01
SOUTH CAROLINA ELECTRIC & GAS COMPANY
COMPUTATION OF RATIO OF EARNINGS TO FIXED CHARGES
For Each of the Five Years Ended December 31, 2000
(Millions of Dollars)
Years Ended December 31,
-----------------------------------------------------------
2000 1999 1998 1997 1996
---- ---- ---- ---- ----
Fixed Charges as defined:
Interest expense $106.4 $103.0 $98.8 $98.9 $102.2
Amortization of debt premium, discount and expense (net) 2.6 2.5 2.3 2.3 2.3
Interest component on rentals 1.1 0.8 0.9 1.8 2.3
Preference security dividend requirement 3.8 3.8 3.8 0.7 -
---------------------------------------------------------------- ---------- ------------ ---------- ----------- ------------
Total Fixed Charges (A) $113.9 $110.1 $105.8 $103.7 $106.8
================================================================ ========== ============ ========== =========== ============
Earnings, as defined:
Pretax income from continuing operations $372.7 $302.7 $363.1 $295.9 $298.6
Total fixed charges above 113.9 110.1 105.8 103.7 106.8
Preference security dividend requirements from above (3.8) (3.8) (3.8) (0.7) -
---------------------------------------------------------------- ---------- ------------ ---------- ----------- ------------
Total Earnings (B) $482.8 $409.0 $465.1 $398.9 $405.4
================================================================ ========== ============ ========== =========== ============
Ratio of Earnings to fixed charges (B/A) 4.24 3.71 4.40 3.85 3.80
================================================================ ========== ============ ========== =========== ============
Exhibit 12.01
PUBLIC SERVICE COMPANY OF NORTH CAROLINA, INCORPORATED
COMPUTATION OF RATIO OF EARNINGS TO FIXED CHARGES
For the Year Ended December 31, 2000 and Each of the Previous Four Years Ended September 30
(Millions of Dollars)
Twelve Months
Ended
December 31, Years Ended September 30,
2000 1999 1998 1997 1996
---- ---- ---- ---- ----
Fixed Charges as defined:
Interest expense $12.4 $13.6 $15.1 $15.1 $12.3
Amortization of debt premium,
discount and expense (net) 0.2 0.4 0.2 0.2 0.1
Other interest expense 8.1 4.8 3.2 2.4 2.7
------------------------------------------------ ------------------ --- -------- --------- ---------- ----------
Total Fixed Charges (A) $20.7 $18.8 $18.5 $17.7 $15.1
================================================ ================== === ======== ========= ========== ==========
Earnings, as defined:
Pretax income from continuing operations $39.7 $40.9 $41.0 $42.7 $39.6
Total fixed charges above 20.7 18.8 18.5 17.7 15.1
Distributed income of equity investees 2.7 - - - -
------------------------------------------------ ------------------ --- -------- --------- ---------- ----------
Total Earnings (B) $63.1 $59.7 $59.5 $60.4 $54.7
================================================ ================== === ======== ========= ========== ==========
Ratio of Earnings to fixed charges (B/A) 3.05 3.18 3.22 3.41 3.62
================================================ ================== === ======== ========= ========== ==========
SIGNATURE
Pursuant to the requirements of Section 13 or 15(d) of the Securities
Exchange Act of 1934, the registrant has duly caused this report to be signed on
its behalf by the undersigned, thereunto duly authorized. The signature of the
undersigned company shall be deemed to relate only to matters having reference
to such company and any subsidiaries thereof.
SCANA CORPORATION
s/W. B. Timmerman
By: W. B. Timmerman, Chairman of the Board,
President, Chief Executive Officer and Director
DATE: October 1, 2001
s/Mark R. Cannon
By: Mark R. Cannon
Controller
DATE: October 1, 2001
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities
Exchange Act of 1934, the registrant has duly caused this report to be signed on
its behalf by the undersigned, thereunto duly authorized. The signature of the
undersigned company shall be deemed to relate only to matters having reference
to such company and any subsidiaries thereof.
SOUTH CAROLINA ELECTRIC & GAS COMPANY
By: s/N. O. Lorick
N. O. Lorick, President and Chief
Operating Officer
Date: October 1, 2001
s/Mark R. Cannon
By: Mark R. Cannon
Controller
DATE: October 1, 2001
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities
Exchange Act of 1934, the registrant has duly caused this report to be signed on
its behalf by the undersigned, thereunto duly authorized. The signature of the
undersigned company shall be deemed to relate only to matters having reference
to such company and any subsidiaries thereof.
PUBLIC SERVICE COMPANY OF NORTH CAROLINA, INCORPORATED
By: s/Kevin B. Marsh
Kevin B. Marsh, Senior Vice President, Chief
Financial Officer
Date: October 1, 2001
s/Mark R. Cannon
By: Mark R. Cannon
Controller
DATE: October 1, 2001