================================================================================


                                  UNITED STATES
                       SECURITIES AND EXCHANGE COMMISSION
                              Washington, DC 20549

                                    FORM 10-Q


              (X) QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)
                     OF THE SECURITIES EXCHANGE ACT OF 1934

                      For the Quarter Ended March 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

         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

                             Description of                Shares Outstanding
Registrant                   Common Stock                  at April 28, 2000

 SCANA Corporation           Without Par Value                  104,729,133

South Carolina Electric      Par Value $4.50 Per Share          40,296,1471
  & Gas Company

1Held, beneficially and of record, by SCANA Corporation.

         This combined Form 10-Q is separately  filed by SCANA  Corporation  and
South Carolina Electric & Gas Company.  Information contained herein relating to
SCANA  Corporation  or any of its direct or  indirect  subsidiaries,  other than
South  Carolina  Electric & Gas  Company  and its  consolidated  operations,  is
provided  solely by SCANA  Corporation  and shall be deemed not  included in the
Form 10-Q of South Carolina Electric & Gas Company.


================================================================================


<PAGE>



                                      INDEX

                                                                           Page
PART 1.  FINANCIAL INFORMATION

SCANA Corporation Financial Section.........................................  3

Item 1.  Financial Statements

    Consolidated Balance Sheets as of March 31, 2000 and December 31, 1999... 4

    Consolidated Statements of Income and Retained Earnings for the Periods
      Ended March 31, 2000 and 1999.........................................  6

    Consolidated Statements of Cash Flows for the Periods Ended March 31,
      2000 and 1999.........................................................  7

    Notes to Consolidated Financial Statements..............................  8

Item 2.  Management's Discussion and Analysis of Financial Condition and
            Results of Operations............................................14

Item 3.  Quantitative and Qualitative Disclosures About Market Risk..........20

South Carolina Electric & Gas Company Financial Section......................22

Item 1.  Financial Statements

    Consolidated Balance Sheets as of  March 31, 2000 and December 31, 1999..23

    Consolidated Statements of Income and Retained Earnings for the Periods
        Ended March 31, 2000 and 1999........................................25

    Consolidated Statements of Cash Flows for the Periods Ended
        March 31, 2000 and 1999..............................................26

    Notes to Consolidated Financial Statements...............................27

Item 2.  Management's Discussion and Analysis of Financial Condition and
           Results of Operations.............................................31

Item 3.  Quantitative and Qualitative Disclosures About Market Risk..........35


PART II.  OTHER INFORMATION

Item 1.  Legal Proceedings...................................................36

Item 6.  Exhibits and Reports on Form 8-K....................................36

Signatures...................................................................37

Exhibit Index................................................................39





<PAGE>







                                SCANA CORPORATION
                                FINANCIAL SECTION









                         PART I. FINANCIAL INFORMATION


Item 1.  Financial Statements


                                SCANA CORPORATION
                           CONSOLIDATED BALANCE SHEETS
                   As of March 31, 2000 and December 31, 1999
                                   (Unaudited)




March 31,             December 31,
------------------------------------------------------------ ------------------
                                                        2000          1999
------------------------------------------------------------ ------------------
Assets                                                  (Millions of Dollars)
Utility Plant:
    Electric                                           $4,629        $4,633
    Gas                                                 1,387           632
    Other                                                 190           191
------------------------------------------------------------- ------------------
        Total                                           6,206         5,456
    Less accumulated depreciation and amortization      2,116         1,829
------------------------------------------------------------- ------------------
        Total                                           4,090         3,627
    Construction work in progress                         220           159
    Nuclear fuel, net of accumulated amortization          43            41
    Acquisition adjustment-gas, net of accumulated
      amortization                                        485            22
------------------------------------------------------------ ------------------
        Utility Plant, Net                              4,836         3,851
------------------------------------------------------------- ------------------

Nonutility Property, net of accumulated depreciation       62            61
Investments                                               860           938
--------------------------------------------------------------------------------
  Nonutility Property and Investments, net of
     accumulated depreciation                             922           999
-------------------------------------------------------------------------------

Current Assets:
    Cash and temporary cash investments                   116            98
    Receivables (including unbilled revenues)             423           320
    Inventories (at average cost):
        Fuel                                               55            79
        Materials and supplies                             78            55
    Prepayments                                            27            35
    Deferred income taxes                                  16            15
------------------------------------------------------------- ------------------
        Total Current Assets                              705           612
------------------------------------------------------------ ------------------

Deferred Debits:
    Emission allowances                                    31            30
    Environmental                                          24            25
    Nuclear plant decommissioning fund                     64            66
    Pension asset, net                                    162           144
    Other regulatory assets                               167           175
    Other                                                 116           111
------------------------------------------------------------- ------------------
        Total Deferred Debits                             549           566
----------------------------------------- ------------------- ------------------
            Total                                      $6,011        $7,029
========================================== ================== ==================







<PAGE>







                                SCANA CORPORATION
                           CONSOLIDATED BALANCE SHEETS
                   As of March 31, 2000 and December 31, 1999
                                   (Unaudited)


                                                     March 31,    December 31,
--------------------------------------------------------------------------------
                                                      2000            1999
--------------------------------------------------------------------------------
Capitalization and Liabilities                          (Millions of Dollars)
Stockholders' Investment:
    Common Equity                                   $ 2,100          $2,099
    Preferred stock (not subject to purchase
     or sinking funds)                                  106             106
-------------------------------------------------------------- -----------------
        Total Stockholders' Investment                2,206           2,205
Preferred Stock, net (subject to purchase or
  sinking funds)                                         11              11
SCE&G-Obligated Mandatorily Redeemable Preferred
   Securities  of  SCE&G's Subsidiary Trust, SCE&G
   Trust I, holding solely $50 million principal
   amount of the 7.55% Junior Subordinated
   Debentures of SCE&G, due 2027                         50              50
Long-Term Debt, net                                   2,413           1,563
-------------------------------------------------------------- -----------------
        Total Capitalization                          4,680           3,829
-------------------------------------------------------------- -----------------

Current Liabilities:
    Short-term borrowings                               345             266
    Current portion of long-term debt                   309             303
    Accounts payable                                    192             189
    Customer deposits                                    20              16
    Taxes accrued                                        51              86
    Interest accrued                                     46              29
    Dividends declared                                   32              31
    Other                                                23              13
-------------------------------------------------------------- -----------------
       Total Current Liabilities                      1,018             933
-------------------------------------------------------------- -----------------

Deferred Credits:
    Deferred income taxes                               861             805
    Deferred investment tax credits                     118             116
    Postretirement benefits                             109              98
    Reserve for nuclear plant decommissioning            66              64
    Other regulatory liabilities                         75              64
    Other                                               102             102
------------------------------------------------------------- -----------------
        Total Deferred Credits                        1,331           1,249
------------------------------------------------------------- -----------------
           Total                                     $7,029          $6,011
============================================================ =================

See Notes to Consolidated Financial Statements.









<PAGE>


                                SCANA CORPORATION
             CONSOLIDATED STATEMENTS OF INCOME AND RETAINED EARNINGS
                  For the Periods Ended March 31, 2000 and 1999
                                   (Unaudited)

                                                       Three Months Ended
                                                            March 31,
     ----------------------------------------------------- ---------------------
                                                        2000        1999
     --------------------------------------------------------------------------
                                                        (Millions of Dollars)
     Operating Revenues:
         Electric                                      $  294      $ 266
         Gas - Regulated                                  311        130
         Gas - Nonregulated                               216        149
         Transit                                            -          1
     -------------------------------------------------------- -----------------
             Total Operating Revenues                     821        546
     -------------------------------------------------------- -----------------
     Operating Expenses:
         Fuel used in electric generation                  70         61
         Purchased power                                    7          4
         Gas purchased for resale                         379        228
         Other operation                                   90         80
         Maintenance                                       21         18
         Depreciation and amortization                     55         42
         Income taxes                                      50         21
         Other taxes                                       29         27
     --------------------------------------------------------------------------
             Total Operating Expenses                     701        481
     --------------------------------------------------------------------------
     Operating Income                                      120        65
     ---------------------------------------------------------------------------

     Other Income:
         Allowance for equity funds used
           during construction                               1         1
         Other income, net of income taxes                  11         8
     -------------------------------------------------------- -----------------
             Total Other Income                             12         9
     -------------------------------------------------------- -----------------

     Income Before Interest Charges and
       Preferred Stock Dividends                           132        74
     --------------------------------------------------------------------------

     Interest Charges (Credits):
         Interest expense on long-term debt                 44        31
         Other interest expense                             11         4
         Allowance for borrowed funds used
           during construction                              (1)       (1)
     --------------------------------------------------------------------------
             Total Interest Charges, Net                    54        34
     --------------------------------------------------------------------------
     Income Before Preferred Dividend Requirements
         on Mandatorily Redeemable Preferred Securities     78        40
     Preferred Dividend Requirement of SCE&G -
          Obligated Mandatorily Redeemable
          Preferred Securities                               1         1
     --------------------------------------------------------- -----------------
     Income Before Preferred Stock Cash Dividends
       of Subsidiary                                        77        39
     Preferred Stock Cash Dividends of Subsidiary
      (At Stated Rates)                                     (2)       (2)
     --------------------------------------------------------- -----------------
     Income Before Cumulative Effect of
       Accounting Change                                    75        37
     Cumulative Effect of Accounting Change,
       net of taxes (Note 2)                                29         -
     ---------------------------------------------------------------------------
     Net Income                                            104        37
     Retained Earnings at Beginning of Period              720       678
     Common Stock Cash Dividends Declared                  (30)      (40)
     ==========================================================================
     Retained Earnings at End of Period                  $ 794    $   675
     ===========================================================================
     Net Income                                          $ 104    $    37
     Weighted Average Number of Common Shares
       Outstanding (Millions)                            104.0      103.6
     Earnings Per Weighted Average Share of
       Common Stock (Basic and Diluted) Before
       Cumulative Effect of Accounting Change            $ .72      $ .36
     Cumulative Effect of Accounting Change (Note 2)     $ .28          -
     Earnings Per Weighted Average Share of Common Stock
      (Basic and  Diluted)                              $ 1.00      $ .36
     Cash Dividends Declared Per Share of Common Stock   $.2875    $.3850
     ===========================================================================

     See Notes to Consolidated Financial Statements.



<PAGE>


                                SCANA CORPORATION
                      CONSOLIDATED STATEMENTS OF CASH FLOWS
                  For the Periods Ended March 31, 2000 and 1999
                                   (Unaudited)
                                                             Three Months Ended
                                                                 March 31,
------------------------------------------------------------------ -------------
                                                              2000         1999
------------------------------------------------------------------ -------------
                                                           (Millions of Dollars)
Cash Flows From Operating Activities:
  Net income                                                    $104       $37
    Adjustments to reconcile net income to net
      cash provided from operating activities, net
       of effect of subsidiary acquisition:
        Cumulative effect of accounting change                   (29)        -
        Depreciation and amortization                             55        44
        Amortization of nuclear fuel                               5         5
        Deferred income taxes, net                                21         3
        Pension asset                                            (18)       (6)
        Other regulatory assets                                   (6)        7
        Other regulatory liabilities                               7         4
        Post-retirement benefits                                  11         3
        Allowance for funds used during construction              (2)       (3)
        Over (under) collections, fuel adjustment clauses         14         9
        Changes in certain current assets and liabilities:
            (Increase) decrease in receivables                    (5)       11
            (Increase) decrease in inventories                    36       (10)
            Increase (decrease) in accounts payable              (47)      (23)
            Increase (decrease) in taxes accrued                 (40)      (60)
        Other, net                                                21         -
---------------------------------------------------------------------- --------
    Net Cash Provided From Operating Activities                  127        21
---------------------------------------------------------------------- --------

Cash Flows From Investing Activities:
    Utility property additions and construction
     expenditures, net of AFC                                    (52)      (50)
    Increase in other property and investments                    (7)      (13)
    Purchase of subsidiary,  net of cash acquired               (691)        -
    Sale of subsidiary assets                                      1         3
---------------------------------------------------------------------- --------
    Net Cash Used For Investing Activities                      (749)      (60)
---------------------------------------------------------------------- --------

Cash Flows From Financing Activities:
    Proceeds:
        Issuance of  First Mortgage Bonds                          -        99
        Issuance of notes and loans                              700         -
    Repayments:
        Other long-term debt                                      (1)       (1)
    Dividend payments:
        Common stock                                             (34)      (40)
        Preferred stock of subsidiary                             (2)       (2)
    Short-term borrowings, net                                   (59)      (21)
    Fuel and emission allowance financings, net                    -        13
---------------------------------------------------------------------- --------
    Net Cash Provided From  Financing Activities                 604        48
---------------------------------------------------------------------- --------
Net Increase (Decrease) In Cash And Temporary
  Cash Investments                                               (18)        9
Cash And Temporary Cash Investments At January 1                 116        62
---------------------------------------------------------------------- --------
Cash And Temporary Cash Investments At March 31                 $ 98       $71
====================================================================== ========

Supplemental Cash Flow Information:
    Cash paid for - Interest (includes capitalized
                    interest of $1 for 2000 and 1999)           $ 37      $24
                  - Income taxes                                  26        5
    Noncash investing activities
                  - Unrealized gain/(loss) on securities
                    available for sale, net of                   (73)      18
taxes

    In  conjunction  with the  acquisition  of Public  Service  Company of North
Carolina, Inc., liabilities were assumed as follows:

                Fair value of assets acquired                 $1,171
                Cash paid for capital stock                     (212)
                Stock issued for consideration                  (475)
                                                              --------
                     Liabilities assumed                      $  484
                                                              =======

See Notes to Consolidated Financial Statements.



<PAGE>


                                SCANA CORPORATION
                   NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
                                 March 31, 2000
                                   (Unaudited)

         The  following  notes should be read in  conjunction  with the Notes to
Consolidated Financial Statements appearing in SCANA Corporation's (the Company)
Annual  Report on Form 10-K for the year  ended  December  31,  1999.  These are
interim  financial  statements,  and  due to the  seasonality  of the  Company's
business, the amounts reported in the Consolidated  Statements of Income are not
necessarily  indicative  of amounts  expected  for the year.  In the  opinion of
management, the information furnished herein reflects all adjustments,  all of a
normal  recurring  nature  except  as  described  in  Notes 2 and 3,  which  are
necessary for a fair statement of the results for the interim periods reported.

1.   SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES:

        A.  Basis of Accounting

        The Company accounts for its regulated  utility  operations,  assets and
        liabilities in accordance  with the provisions of Statement of Financial
        Accounting  Standards No. 71 (SFAS 71). The accounting standard requires
        cost-based  rate-regulated  utilities to  recognize  in their  financial
        statements  revenues  and  expenses in  different  time  periods than do
        enterprises that are not  rate-regulated.  As a result,  the Company has
        recorded,  as of March 31,  2000,  approximately  $194  million  and $75
        million of regulatory  assets and liabilities,  respectively,  including
        amounts  recorded  for  deferred  income tax assets and  liabilities  of
        approximately $131 million and $48 million,  respectively.  The electric
        and gas  regulatory  assets  (excluding  deferred  income tax assets) of
        approximately  $35  million  and $26  million,  respectively,  are being
        recovered  through  rates,  and the Public  Service  Commission of South
        Carolina (PSC) has approved  accelerated  recovery of  approximately  $5
        million of the electric regulatory assets. In the future, as a result of
        deregulation or other changes in the regulatory environment, the Company
        may no longer meet the criteria for continued application of SFAS 71 and
        could be required to write off its  regulatory  assets and  liabilities.
        Such an event  could have a  material  adverse  effect on the  Company's
        results of operations in the period that a write-off  would be required,
        but it is not expected  that cash flows or financial  position  would be
        materially affected.

        B.  Other Comprehensive Income

        Other comprehensive  income includes net income and all other changes in
        equity except those resulting from  investments by and  distributions to
        stockholders.  Other  comprehensive  income of the  Company  totaled $31
        million and $56 million  for the three  months  ended March 31, 2000 and
        1999, respectively. For each period, other comprehensive income included
        net income and unrealized gains/losses on securities available for sale.
        Accumulated  other  comprehensive  income of the  Company  totaled  $521
        million and $286 million at March 31, 2000 and 1999, respectively.

        C.  Reclassifications

        Certain  amounts from prior  periods have been  reclassified  to conform
with the 2000 presentation.

2.      Cumulative Effect of Accounting Change

        Effective  January 1, 2000 the Company  changed its method of accounting
        for  operating  revenues  from  cycle  billing  to  full  accrual.   The
        cumulative  effect of this change was $29 million,  net of tax. Accruing
        unbilled  revenues more closely matches revenues and expenses.  Unbilled
        revenues  represent the estimated  amount  customers will be charged for
        service received,  but that has not yet been billed as of the end of the
        accounting   period.   Previously  these  revenues  were  recognized  as
        operating revenues as customers were billed.

        If this method had been  applied  retroactively,  net income  would have
        been $54 million  ($0.52 per share) for the three months ended March 31,
        1999, compared to $37 million ($0.36 per share) as previously reported.


<PAGE>


3.      ACQUISITION

        On February 10, 2000 the Company  completed  its  acquisition  of Public
        Service Company of North Carolina, Inc. (PSNC) in a business combination
        accounted  for as a purchase.  PSNC became a wholly owned  subsidiary of
        the Company. PSNC is a public utility engaged primarily in transporting,
        distributing   and  selling   natural  gas  to   approximately   351,000
        residential, commercial and industrial customers in 31 counties in North
        Carolina.   Pursuant  to  the  Agreement   and  Plan  of  Merger,   PSNC
        shareholders were paid approximately $212 million in cash and 17,413,013
        shares of SCANA  common  stock.  The results of  operations  of PSNC are
        included in the accompanying financial statements as of January 1, 2000,
        the effective date of  acquisition . The total cost of  acquisition  was
        approximately  $700  million,  which  exceeded the fair value of the net
        assets by approximately $466 million. The excess is being amortized over
        35 years.

        Operating revenues and net income previously  reported by the separate
        companies and the combined  amounts   presented  in  the   accompanying
        Consolidated Statements of Income, including the cumulative  effect of
        accounting change (See Note 2), are as follows:

--------------------------------------------------------------------------------
                                               For the Three Months Ended
                                                   March 31, 1999
(Dollars in millions,
except per share amounts)                SCANA    PSNC   Adjustments1  Combined
--------------------------------------------------------------------------------
Operating revenues                       $546     $134       $    -     $680
Income before cumulative effect            37       22        (11)        48
Cumulative effect of accounting change     17       5             -       22
Net income                                 54       27        (11)        70
Earnings per share                       0.52     1.30                  0.67
================================================================================
       1Adjustments  include  interest  charges  (net of income  tax  effect) on
        additional   debt  issued  in  conjunction   with  the  acquisition  and
        amortization of the acquisition adjustment.

4.     RATE MATTERS

        On  December  7, 1999 the North  Carolina  Utilities  Commission  (NCUC)
        issued an order  approving the  acquisition  of PSNC by the Company.  As
        specified in the NCUC order, PSNC will reduce its rates by approximately
        $2 million  ($1  million in August 2000 and another $1 million in August
        2001) and has agreed to a five-year  moratorium  on general  rate cases.
        General rate relief can be obtained  during this period to recover costs
        associated  with  materially  adverse  governmental  actions  and  force
        majeure events. The Carolina Utility Customers Association,  Inc. (CUCA)
        filed an appeal of this  order,  which is pending in the North  Carolina
        Court of Appeals.  While management  cannot predict the ultimate outcome
        of this appeal, management does not expect that such outcome will have a
        material adverse impact on the Company's financial position,  results of
        operations or cash flows.

        On October 30, 1998 the NCUC issued an order in PSNC's general rate case
        filed in April 1998. The order, effective November 1, 1998, granted PSNC
        additional  revenue of $12.4 million and allowed a 9.82 percent  overall
        rate of return on PSNC's net utility  investment.  It also  approved the
        continuation  of  the  Weather  Normalization  Adjustment  and  Rider  D
        Mechanisms  and full margin  transportation  rates.  PSNC's Rider D rate
        mechanism  authorizes  the recovery of all prudently  incurred gas costs
        from  customers on a monthly  basis.  Any difference in amounts paid and
        collected  for  these  costs is  deferred  for  subsequent  refund to or
        collection  from  customers.  CUCA, a party to PSNC's general rate case,
        formally  appealed the general rate case order on December 18, 1998.  On
        February 4, 2000 the Supreme Court of North  Carolina  affirmed the NCUC
        order.

        On November 6, 1997 the NCUC issued an order permitting PSNC, on a trial
        basis,  to establish its commodity cost of gas for large  commercial and
        industrial customers on the basis of market prices for natural gas. This
        procedure  allows  PSNC to  manage  its  deferred  gas  costs  better by
        ensuring  that the amount paid for natural gas to serve these  customers
        approximates  the  amount  collected  from  them.   PSNC's  request  for
        permanent  approval  of this  mechanism  was  approved by the NCUC in an
        order issued April 6, 2000.


<PAGE>



5.      RETAINED EARNINGS:

        The Restated  Articles of  Incorporation of the Company do not limit the
        dividends that may be payable on its common stock. However, the Restated
        Articles of  Incorporation  of SCE&G and the  Indenture  underlying  its
        First and  Refunding  Mortgage  Bonds  contain  provisions  that,  under
        certain circumstances,  could limit the payment of cash dividends on its
        common stock. In addition,  with respect to hydroelectric  projects, the
        Federal  Power Act  requires the  appropriation  of a portion of certain
        earnings  therefrom.  At March 31, 2000,  approximately $30.8 million of
        retained  earnings were restricted by this  requirement as to payment of
        cash dividends on SCE&G's common stock.

6.      INVESTMENTS IN EQUITY SECURITIES:

        At March 31, 2000, SCANA Communications  Holdings,  Inc. (SCH), a wholly
        owned,  indirect subsidiary of SCANA, held the following  investments in
        ITC Holding Company, Inc. (ITC) and its affiliates:

     o    Powertel,  Inc.  (Powertel) is a publicly traded company that owns and
          operates  personal  communications  services  (PCS) systems in several
          major Southeastern  markets. SCH owns approximately 4.9 million common
          shares of Powertel at a cost of approximately $74.1 million.  Powertel
          common stock closed at $69.1875 per share on March 31, 2000, resulting
          in a pre-tax  unrealized  holding gain of $265.1 million (a decline of
          $152.7   million  from   December   31,   1999).   Accumulated   other
          comprehensive  income includes the after-tax  amount of all unrealized
          holding gains and losses.  In addition,  SCH owns the following series
          of non-voting  convertible  preferred  shares, at the approximate cost
          noted: 100,000 shares series B ($75.1 million); 50,000 shares series D
          ($22.5  million);  and  50,000  shares  6.5  percent  series  E ($75.0
          million).  Dividends on  preferred  series E shares are paid in common
          shares of Powertel. Preferred series B shares are convertible in March
          2002 at a conversion price of $16.50 per common share or approximately
          4.5 million common shares.  Preferred  series D shares are convertible
          in March 2002 at a  conversion  price of $12.75  per  common  share or
          approximately 1.7 million common shares. Preferred series E shares are
          convertible  in June 2003 at a  conversion  price of $22.01 per common
          share or approximately 3.4 million common shares.  The market value of
          the   convertible   preferred   shares  of  Powertel  is  not  readily
          determinable.   However,  as  converted,   the  market  value  of  the
          underlying  common shares for the preferred  shares was  approximately
          $672.3 million at March 31, 2000,  resulting in an unrecorded  pre-tax
          holding  gain of $499.7  million  (a decline  of $303.0  million  from
          December 31, 1999).

     o    ITC^DeltaCom,   Inc.  (ITCD)  is  a  fiber  optic   telecommunications
          provider.  SCH owns approximately 5.1 million common shares of ITCD at
          a cost of  approximately  $42.7  million.  ITCD common stock closed at
          $35.625 per share on March 31, 2000, resulting in a pre-tax unrealized
          holding  gain of $139.2  million (an  increase of $40.8  million  from
          December 31, 1999).  Accumulated other  comprehensive  income includes
          the after-tax  amount of all unrealized  holding gains and losses.  In
          addition,  SCH owns  1,480,771  shares of series A preferred  stock of
          ITCD at a cost of  approximately  $11.2  million.  Series A  preferred
          shares are  convertible  in March 2002 into  2,961,542  shares of ITCD
          common stock.  The market value of series A preferred stock of ITCD is
          not readily determinable.  However, as converted,  the market value of
          the  underlying  common  stock for the  series A  preferred  stock was
          approximately  $105.5  million  at March  31,  2000,  resulting  in an
          unrecorded pre-tax holding gain of $94.3 million (an increase of $23.7
          million from December 31, 1999).

     o    Knology  Inc.  (Knology),  previously  Knology  Holdings,  Inc.,  is a
          broad-band  service  provider  of  cable,  television,  telephone  and
          internet  services.  SCH owns  71,050  units  of  Knology.  Each  unit
          consists of one 11.875% Senior  Discount Note due 2007 and one warrant
          entitling the holder to purchase  .003734 shares of preferred stock of
          Knology.  The cost of this investment was  approximately  $40 million.
          Prior to  February  24,  2000,  SCH owned  451,800  shares of series A
          preferred stock of Knology at a cost of approximately $1.1 million. On
          February 24, 2000 Knology Holdings, Inc. was spun off from ITC and was
          renamed  Knology,  Inc. As a result of this spin off, SCH received 6.8
          million shares of Knology Series A preferred  stock.  The market value
          of these investments is not readily determinable.

     o    ITC has an ownership interest in several  Southeastern  communications
          companies.  SCH owns approximately 3.1 million common shares,  645,153
          series  A  convertible   preferred   shares,   and  133,664  series  B
          convertible   preferred   shares  of  ITC.  These   investments   cost
          approximately   $5.8  million,   $7.2   million,   and  $4.0  million,
          respectively.  Preferred series A shares are convertible in March 2002
          at a conversion price of $13.45 per common share or approximately  2.6
          million common shares.  Preferred  series B shares are  convertible in
          March 2002 into ITC common  shares on a four to one basis.  The market
          values of these investments are not readily determinable.

7.      CONTINGENCIES:

        With respect to commitments at March 31, 2000, reference is made to Note
        10 of  Notes  to  Consolidated  Financial  Statements  appearing  in the
        Company's  Annual  Report on Form 10-K for the year ended  December  31,
        1999. Contingencies at March 31, 2000 are as follows:

        A.  Nuclear Insurance

        The  Price-Anderson   Indemnification   Act,  which  deals  with  public
        liability for a nuclear  incident,  currently  establishes the liability
        limit for third-party  claims  associated  with any nuclear  incident at
        $9.5 billion.  Each reactor licensee is currently liable for up to $88.1
        million per reactor  owned for each  nuclear  incident  occurring at any
        reactor in the United States, provided that not more than $10 million of
        the liability per reactor  would be assessed per year.  SCE&G's  maximum
        assessment,  based on its  two-thirds  ownership of V. C. Summer Nuclear
        Station  (Summer  Station),  would be  approximately  $58.7  million per
        incident, but not more than $6.7 million per year.

        SCE&G  currently  maintains  policies  (for  itself and on behalf of the
        South Carolina Public Service Authority) with Nuclear Electric Insurance
        Limited  (NEIL).  These  policies  covering  the  nuclear  facility  for
        property  damage,   excess  property  damage  and  outage  costs  permit
        assessments under certain conditions to cover insurer's losses. Based on
        the current annual premium,  SCE&G's portion of the retroactive  premium
        assessment would not exceed $8.1 million.

        To   the   extent   that   insurable   claims   for   property   damage,
        decontamination,  repair and  replacement  and other costs and  expenses
        arising  from a nuclear  incident  at Summer  Station  exceed the policy
        limits of insurance, or to the extent such insurance becomes unavailable
        in the future,  and to the extent that  SCE&G's  rates would not recover
        the cost of any purchased  replacement power, SCE&G will retain the risk
        of loss as a  self-insurer.  SCE&G has no reason to anticipate a serious
        nuclear  incident at Summer Station.  If such an incident were to occur,
        it could  have a material  adverse  impact on the  Company's  results of
        operations, cash flows and financial position.

        B.  Environmental

        SCE&G has an  environmental  assessment  program to identify  and assess
        current and former  operations  sites that could  require  environmental
        cleanup.  As site  assessments are initiated,  estimates are made of the
        expenditures,  if any, deemed necessary to investigate and clean up each
        site.  These  estimates  are refined as additional  information  becomes
        available;  therefore,  actual  expenditures could differ  significantly
        from the original  estimates.  Amounts estimated and accrued to date for
        site assessments and cleanup relate  primarily to regulated  operations.
        Such amounts are deferred and amortized with recovery  provided  through
        rates.   SCE&G  has  also  recovered   portions  of  its   environmental
        liabilities through  settlements with various insurance carriers.  SCE&G
        has  recovered  all  amounts   previously   deferred  for  its  electric
        operations. SCE&G expects to recover all deferred amounts related to its
        gas  operations  by  December  2005.  Deferred  amounts,  net of amounts
        recovered through rates and insurance settlements, totaled $20.5 million
        at March 31, 2000. The deferral  includes the estimated costs associated
        with the following matters.


<PAGE>



     o    In September 1992 the  Environmental  Protection Agency (EPA) notified
          SCE&G, the City of Charleston and the Charleston  Housing Authority of
          their  potential  liability for the  investigation  and cleanup of the
          Calhoun  Park  area  site in  Charleston,  South  Carolina.  This site
          encompasses  approximately 30 acres and includes properties which were
          locations  for  industrial  operations,  including  a wood  preserving
          (creosote)  plant,  one of  SCE&G's  decommissioned  manufactured  gas
          plants  (MGP),  properties  owned by the National Park Service and the
          City of  Charleston,  and  private  properties.  The site has not been
          placed  on the  National  Priorities  List,  but may be  added  in the
          future. The Potentially  Responsible Parties (PRPs) have negotiated an
          administrative  order  by  consent  for  the  conduct  of  a  Remedial
          Investigation/Feasibility  Study  and a  corresponding  Scope of Work.
          Field work began in  November  1993,  and the EPA  approved a Remedial
          Investigation  Report in February 1997 and a Feasibility  Study Report
          in June 1998.  In July 1998 the EPA approved  SCE&G's  Removal  Action
          Work  Plan for  soil  excavation.  SCE&G  completed  Phase  One of the
          Removal Action in 1998 at a cost of approximately $1.5 million.  Phase
          Two, which cost  approximately $3.5 million,  included  excavation and
          installation  of  several  permanent  barriers  to  mitigate  coal tar
          seepage.  On September  30, 1998 a Record of Decision was issued which
          sets forth the EPA's  view of the extent of each PRP's  responsibility
          for  site  contamination  and the  level to  which  the  site  must be
          remediated. SCE&G estimates that the Record of Decision will result in
          costs  of  approximately  $13.3  million,  of which  approximately  $4
          million  remains.  On January  13,  1999 the EPA  issued a  Unilateral
          Administrative Order for Remedial Design and Remedial Action directing
          SCE&G to design and carry out a plan of  remediation  for the  Calhoun
          Park  site.   The  Order  is  temporarily   stayed   pending   further
          negotiations  between SCE&G and the EPA.  However,  SCE&G  submitted a
          Comprehensive  Remedial  Design Work Plan on December  17, 1999 and is
          proceeding with implementation pending agency approval.

          In October 1996 the City of  Charleston   and  SCE&G   settled  all
          environmental claims the City may have had against SCE&G involving the
          Calhoun  Park  area for a  payment  of $26  million  over  four  years
          (1996-1999)  by SCE&G to the City.  SCE&G is recovering  the amount of
          the  settlement,  which does not encompass site assessment and cleanup
          costs,  through rates in the same manner as other amounts  accrued for
          site assessments and cleanup. As part of the environmental settlement,
          SCE&G  constructed  an 1,100 space parking  garage on the Calhoun Park
          site  (construction  was completed in April 2000) and  transferred the
          facility to the City in exchange for a 20-year  municipal  bond backed
          by  revenues  from the  parking  garage and a mortgage  on the parking
          garage. The total amount of the bond is still being finalized,  but is
          not to exceed $16.9 million, the maximum expected project cost.

     o    SCE&G owns three other decommissioned MGP sites which contain residues
          of  by-product  chemicals.  For the  site  located  in  Sumter,  South
          Carolina,  effective September 15, 1998, SCE&G entered into a Remedial
          Action Plan Contract with the South Carolina  Department of Health and
          Environmental  Control (DHEC) pursuant to which it agreed to undertake
          a full site investigation and remediation under the oversight of DHEC.
          Site investigation and  characterization  are proceeding  according to
          schedule.  Upon  selection  and  successful  implementation  of a site
          remedy,  DHEC  will  give  SCE&G a  Certificate  of  Completion  and a
          covenant not to sue. SCE&G is continuing to investigate  the other two
          sites,   and  is   monitoring   the  nature  and  extent  of  residual
          contamination.

       In  addition,  PSNC owns,  or has owned,  all or portions of six sites in
       North   Carolina  on  which  MGPs  were  formerly   operated.   Intrusive
       investigation  (including  drilling,  sampling and analysis) has begun at
       only  one  site  and  the  remaining  sites  have  been  evaluated  using
       historical  records and  observations of current site  conditions.  These
       evaluations  have revealed that MGP residuals are present or suspected at
       several of the sites.  The North Carolina  Department of Environment  and
       Natural  Resources has  recommended  that no further action be taken with
       respect to one site. In March and April 1994, an environmental consulting
       firm retained by PSNC estimated that the aggregate cost of  investigating
       and  monitoring   the  extent  of   environmental   degradation   and  of
       implementing remedial procedures with respect to the remaining five sites
       may range from $3.7 million to $50.1 million over a 30-year period.  PSNC
       is unable to determine  the rate at which costs may be incurred over this
       time period.  The estimated cost range has not been discounted to present
       value.  The range includes the cost of  investigating  and monitoring the
       sites  at the low end of the  range  and  investigating,  monitoring  and
       extensively  remediating  the sites at the high end of the range.  PSNC's
       associated  actual  costs  for  these  sites  will  depend on a number of
       factors,   such  as  actual  site  conditions,   third-party  claims  and
       recoveries from other PRPs.

       An order of the NCUC dated May 11, 1993  authorized  deferral  accounting
       for all costs  associated with the  investigation  and remediation of MGP
       sites. As of March 31, 2000, PSNC has recorded a liability and associated
       regulatory asset at the minimum amount of the range, or $3.7 million.

       The NCUC concluded that it is proper and in the public  interest to allow
       recovery of prudently  incurred  clean-up costs from current customers as
       reasonable  operating expenses even though the MGP sites are not used and
       useful in providing gas service to current customers.  However,  the NCUC
       will not allow recovery of carrying costs on deferred amounts.

8.  SEGMENT OF BUSINESS INFORMATION:

The  Company's  reportable  segments  are  listed in the  following  table.  The
Consolidated  Financial  Statements  report  operating  revenues,  comprised  of
reportable  segments and the  non-reportable  transit  operations  segment.  The
Company  uses  operating  income  to  measure  profitability  for  its  Electric
Operations and Gas Distribution segments. Therefore, net income is not allocated
to these segments.  The Company uses net income to measure profitability for its
Energy Marketing segment,  which includes the Company's unregulated gas sales in
Georgia.  Affiliate  revenue is derived  from  transactions  between  reportable
segments  as well as  transactions  between  separate  legal  entities  that are
combined into the same reportable segment. Assets for the period ended March 31,
1999 did not change significantly.
<TABLE>


                        Disclosure of Reportable Segments
                              (Millions of Dollars)
<S>                           <C>         <C>           <C>         <C>        <C>        <C>         <C>
------------------------------------- ------------- ------------- ----------- ------- ----------------------------
                           Electric       Gas           Gas         Energy      All   Adjustments/  Consolidated
        March 31, 2000    Operations  Distribution  Transmission  Marketing    Other  Eliminations     Total
------------------------------------- ------------- ------------- ----------- ------- ----------------------------

External  Revenue             $294        $255          $56         $217         -           -        $822
Intersegment Revenue            77           -           62            2         -        (141)          -
Operating Income (Loss)         69          37            5          n/a        (1)          10        120
Net Income                     n/a         n/a            4            9       (11)         102        104
Segment Assets               4,778       1,547          246          136     1,156         (834)      7,029
------------------------------------- ------------- ------------- ----------- ------- ----------------------------

<S>                           <C>          <C>          <C>        <C>         <C>      <C>          <C>
------------------------- ----------- ------------- ------------- ----------------- -------------- ---------------
                           Electric       Gas           Gas         Energy    All   Adjustments/    Consolidated
        March 31, 1999    Operations  Distribution  Transmission  Marketing  Other  Eliminations       Total
------------------------- ----------- ------------- ------------- ----------------- -------------- ---------------

External Revenue              $266         $86          $44        $149        1        $546                -
Intersegment Revenue           68           -            49           -        -        (117)               -
Operating Income (Loss)        62          14             4         n/a       (1)        (14)            65
Net Income                    n/a         n/a             3         (13)       -          47             37
Segment Assets              4,642         384           229          82       807       (801)         5,343
------------------------- ----------- ------------- ------------- ----------------- -------------- ---------------


</TABLE>


<PAGE>


Item 2.  Management's Discussion and Analysis of Financial Condition and
          Results of Operations

                                SCANA CORPORATION
                     MANAGEMENT'S DISCUSSION AND ANALYSIS OF
                  FINANCIAL CONDITION AND RESULTS OF OPERATIONS

        The following discussion should be read in conjunction with Management's
Discussion  and  Analysis  of  Financial  Condition  and  Results of  Operations
appearing in SCANA  Corporation's  (the Company)  Annual Report on Form 10-K for
the year ended December 31, 1999.

        Statements  included in this  discussion  and analysis (or  elsewhere in
this quarterly  report) which are not statements of historical fact are intended
to be, and are hereby identified as,  "forward-looking  statements" for purposes
of the safe harbor  provided by Section 27A of the  Securities  Act of 1933,  as
amended,  and Section 21E of the  Securities  Exchange Act of 1934,  as amended.
Readers  are  cautioned  that  any  such  forward-looking   statements  are  not
guarantees   of  future   performance   and   involve  a  number  of  risks  and
uncertainties,  and that  actual  results  could  differ  materially  from those
indicated by such forward-looking statements. Important factors that could cause
actual results to differ materially from those indicated by such forward-looking
statements  include,  but are not  limited  to,  the  following:  (1)  that  the
information  is of a  preliminary  nature and may be  subject to further  and/or
continuing  review  and  adjustment,  (2)  changes  in  the  utility  regulatory
environment, (3) changes in the economy in areas served by SCANA's subsidiaries,
(4) the impact of competition from other energy suppliers, (5) the management of
the Company's operations, (6) variations in prices of natural gas and fuels used
for electric  generation,  (7) growth  opportunities for the Company's regulated
and  non-regulated  subsidiaries,  (8) the  results of  financing  efforts,  (9)
changes in the Company's accounting  policies,  (10) weather conditions in areas
served   by   the   Company's   subsidiaries   ,   (11)   performance   of   the
telecommunications   companies  in  which  the  Company  has  made   significant
investments,   (12)  inflation,   (13)  exposure  to  environmental  issues  and
liabilities,  (14) changes in environmental regulations and (15) the other risks
and uncertainties  described from time to time in the Company's periodic reports
filed with the Securities  and Exchange  Commission.  The Company  disclaims any
obligation to update any forward-looking statements.

               MATERIAL CHANGES IN CAPITAL RESOURCES AND LIQUIDITY
                             SINCE DECEMBER 31, 1999


North Carolina Gas Market

        On February 10, 2000 the Company  completed  its  acquisition  of Public
Service  Company  of North  Carolina,  Inc.  (PSNC) in a  transaction  valued at
approximately $900 million, including the assumption of debt. The transaction is
being accounted for as a purchase. PSNC is operated as a wholly owned subsidiary
of the Company. As a result of the transaction,  the Company became a registered
public utility holding company under the Public Utilities Holding Company Act of
1935 (PUHCA).

Georgia Retail Gas Market

        During the first quarter of 2000, Energy Marketing's  Georgia retail gas
operations maintained a base of approximately 431,000 customers, compared to the
first quarter of 1999 when the customer base grew from  approximately  78,000 at
January 1 to approximately 236,000 at March 31. In addition,  Georgia retail gas
operations  reported  net income of  approximately  $8.9  million  for the three
months  ended  March 31,  2000,  compared to a net loss of  approximately  $12.5
million  for the  corresponding  period in 1999.  This  increase  resulted  from
lowering  costs and  improving  efficiency  by  transitioning  from  start-up to
ongoing  operations and from an improved margin on natural gas sales. Due to the
seasonality  of the retail  gas  business  in  Georgia,  management  anticipates
incurring  losses  through much of the remainder of the year 2000,  and breaking
even for the year.


<PAGE>



LIQUIDITY AND CAPITAL RESOURCES

        On September 14, 1999 the PSC approved an accelerated  capital  recovery
plan for SCE&G's Cope Generating  Station.  The plan was implemented  January 1,
2000 for a three-year period.  The PSC approved an accelerated  capital recovery
methodology  wherein SCE&G will  increase  depreciation  of its Cope  Generating
Station  in excess of  amounts  that  would be  recorded  based  upon  currently
approved depreciation rates. The amount of the accelerated  depreciation will be
determined by SCE&G based on the level of revenues and operating  expenses,  not
to exceed $36  million  annually  without the  approval  of the PSC.  Any unused
portion  of the $36  million in any given  year  could be  carried  forward  for
possible use in the succeeding year. The accelerated  capital recovery plan will
be accomplished through existing customer rates.

        On August 7, 1996 the City of Charleston  executed  30-year electric and
gas franchise agreements with SCE&G. In consideration for the electric franchise
agreement,  SCE&G is paying the City $25 million over seven years (1996  through
2002) and has donated to the City the existing transit assets in Charleston. The
$25  million  is  included  in  electric  plant-in-service.   In  settlement  of
environmental  claims the City may have had against SCE&G  involving the Calhoun
Park area, where SCE&G and its predecessor companies operated a manufactured gas
plant until the 1960's,  SCE&G paid the City $26 million over a four-year period
(1996 through 1999). As part of the environmental settlement,  SCE&G constructed
an 1,100  space  parking  garage  on the  Calhoun  Park site  (construction  was
completed  in April 2000) and  transferred  the facility to the City in exchange
for a 20-year  municipal  bond backed by revenues from the parking  garage and a
mortgage  on the  parking  garage.  The total  amount of the bond is still being
finalized,  but is not to exceed $16.9  million,  the maximum  expected  project
cost.

        The  following  table  summarizes  how the Company  generated  funds for
property additions and construction  expenditures  during the three months ended
March 31, 2000 and 1999:

-------------------------------------------------------------------------------
                                                     Three Months Ended
                                                         March 31,
                                                  2000               1999
-------------------------------------------------------------------------------
                                                     (Millions of Dollars)

Net cash provided from operating activities       $127               $ 21
Net cash provided from financing activities        604                 48
Cash provided from sale of subsidiary assets         1                  3
Cash and temporary cash investments available
  at the beginning of the period                   116                 62
================================================================================
Net cash available for  property additions
    and construction                              $848               $134
expenditures
================================================================================

Funds used for purchase of subsidiary             $691                   -
Funds used for utility property additions
   and construction expenditures,
   net of noncash allowance for funds
   used during construction                       $ 52               $ 50
================================================================================

Funds used for nonutility property
  additions                                       $ 7               $  13
================================================================================

       On  December  1, 1999 SCANA  signed a credit  agreement  with banks for a
maximum of $300  million for a three-year  term loan,  all of which was drawn on
February 10, 2000 to consummate SCANA's acquisition of PSNC.

       On February 8, 2000 SCANA issued $400 million of two-year  floating  rate
notes  maturing  February  8,  2002.  The  interest  rate on the  notes is reset
quarterly based on a three-month  LIBOR plus 50 basis points.  The proceeds from
these privately sold notes were used to consummate SCANA's acquisition of PSNC.

        PSNC has committed lines of credit with three  commercial banks totaling
$40 million. PSNC also has uncommitted lines of credit totaling $85 million.


<PAGE>


        The Company anticipates that the remainder of its 2000 cash requirements
will be met through internally  generated funds and the incurrence of additional
short-term and long-term debt. The Company anticipates  incurring short-term and
long-term debt to refinance long-term debt obligations. The timing and amount of
such  financings  will depend  upon market  conditions  and other  factors.  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 ratio of earnings to fixed charges for the 12 months ended March 31,
2000 was 3.41.

Investments in Equity Securities

        At March 31, 2000, SCANA Communications  Holdings,  Inc. (SCH), a wholly
owned,  indirect  subsidiary  of SCANA,  held the following  investments  in ITC
Holding Company, Inc. (ITC) and its affiliates:

     o    Powertel,  Inc.  (Powertel) is a publicly traded company that owns and
          operates  personal  communications  services  (PCS) systems in several
          major Southeastern  markets. SCH owns approximately 4.9 million common
          shares of Powertel at a cost of approximately $74.1 million.  Powertel
          common stock closed at $69.1875 per share on March 31, 2000, resulting
          in a pre-tax  unrealized  holding gain of $265.1 million (a decline of
          $152.7   million  from   December   31,   1999).   Accumulated   other
          comprehensive  income includes the after-tax  amount of all unrealized
          holding gains and losses.  In addition,  SCH owns the following series
          of non-voting  convertible  preferred  shares, at the approximate cost
          noted: 100,000 shares series B ($75.1 million); 50,000 shares series D
          ($22.5  million);  and  50,000  shares  6.5  percent  series  E ($75.0
          million).  Dividends on  preferred  series E shares are paid in common
          shares of Powertel. Preferred series B shares are convertible in March
          2002 at a conversion price of $16.50 per common share or approximately
          4.5 million common shares.  Preferred  series D shares are convertible
          in March 2002 at a  conversion  price of $12.75  per  common  share or
          approximately 1.7 million common shares. Preferred series E shares are
          convertible  in June 2003 at a  conversion  price of $22.01 per common
          share or approximately 3.4 million common shares.  The market value of
          the   convertible   preferred   shares  of  Powertel  is  not  readily
          determinable.   However,  as  converted,   the  market  value  of  the
          underlying  common shares for the preferred  shares was  approximately
          $672.3 million at March 31, 2000,  resulting in an unrecorded  pre-tax
          holding  gain of $499.7  million  (a decline  of $303.0  million  from
          December 31, 1999).

     o    ITC^DeltaCom,   Inc.  (ITCD)  is  a  fiber  optic   telecommunications
          provider.  SCH owns approximately 5.1 million common shares of ITCD at
          a cost of  approximately  $42.7  million.  ITCD common stock closed at
          $35.625 per share on March 31, 2000, resulting in a pre-tax unrealized
          holding  gain of $139.2  million (an  increase of $40.8  million  from
          December 31, 1999).  Accumulated other  comprehensive  income includes
          the after-tax  amount of all unrealized  holding gains and losses.  In
          addition,  SCH owns  1,480,771  shares of series A preferred  stock of
          ITCD at a cost of  approximately  $11.2  million.  Series A  preferred
          shares are  convertible  in March 2002 into  2,961,542  shares of ITCD
          common stock.  The market value of series A preferred stock of ITCD is
          not readily determinable.  However, as converted,  the market value of
          the  underlying  common  stock for the  series A  preferred  stock was
          approximately  $105.5  million  at March  31,  2000,  resulting  in an
          unrecorded pre-tax holding gain of $94.3 million (an increase of $23.7
          million from December 31, 1999).

     o    Knology  Inc.  (Knology),  previously  Knology  Holdings,  Inc.,  is a
          broad-band  service  provider  of  cable,  television,  telephone  and
          internet  services.  SCH owns  71,050  units  of  Knology.  Each  unit
          consists of one 11.875% Senior  Discount Note due 2007 and one warrant
          entitling the holder to purchase  .003734 shares of preferred stock of
          Knology.  The cost of this investment was  approximately  $40 million.
          Prior to  February  24,  2000,  SCH owned  451,800  shares of series A
          preferred stock of Knology at a cost of approximately $1.1 million. On
          February 24, 2000 Knology Holdings, Inc. was spun off from ITC and was
          renamed  Knology,  Inc. As a result of this spin off, SCH received 6.8
          million shares of Knology Series A preferred  stock.  The market value
          of these investments is not readily determinable.


<PAGE>



     o    ITC has an ownership interest in several  Southeastern  communications
          companies.  SCH owns approximately 3.1 million common shares,  645,153
          series  A  convertible   preferred   shares,   and  133,664  series  B
          convertible   preferred   shares  of  ITC.  These   investments   cost
          approximately   $5.8  million,   $7.2   million,   and  $4.0  million,
          respectively.  Preferred series A shares are convertible in March 2002
          at a conversion price of $13.45 per common share or approximately  2.6
          million common shares.  Preferred  series B shares are  convertible in
          March 2002 into ITC common  shares on a four to one basis.  The market
          values of these investments are not readily determinable.





<PAGE>



                              RESULTS OF OPERATIONS
                    FOR THE THREE MONTHS ENDED MARCH 31, 2000
                 AS COMPARED TO THE CORRESPONDING PERIOD IN 1999

Earnings and Dividends

        Earnings  per share of common stock for the three months ended March 31,
2000 and 1999 were as follows:

                                                    2000         1999
 ----------------------------------------------------------------------

 Earnings derived from:
     Continuing operations                        $ .72        $.36
     Change in accounting                           .28           -
 ======================================================================
     Earnings per weighted average share          $1.00        $.36
 ======================================================================


        Earnings from continuing  operations  increased $.36. This was primarily
attributable  to  improved  results  of $.21 from the  Company's  entry into the
Georgia retail gas market  (earnings of $.09 for 2000 compared to a loss of $.12
for  1999),  the  Company's  acquisition  of  Public  Service  Company  of North
Carolina,  Inc.  (PSNC) in 2000 ($.18),  and improved  electric  margins ($.10).
These increases were partially offset by interest costs associated with the PSNC
acquisition ($.09) and other ($.04).

        Earnings  from a change in  accounting  resulted  from the  recording of
unbilled revenues by SCANA's retail utility subsidiaries (See Note 2 of NOTES TO
CONSOLIDATED FINANCIAL STATEMENTS).

        Allowance  for  funds  used  during  construction  (AFC)  is  a  utility
accounting  practice  whereby a portion of the cost of both equity and  borrowed
funds  used to  finance  construction  (which is shown on the  balance  sheet as
construction  work in  progress)  is  capitalized.  Both the equity and the debt
portions of AFC are noncash items of  nonoperating  income which have the effect
of increasing  reported net income.  AFC represented  approximately 1% and 5% of
income  before  income taxes for the three months ended March 31, 2000 and 1999,
respectively.

        The  Company's  Board of  Directors  declared  the  following  quarterly
dividends on common stock:

-------------------- --------------- ------------------ ----------------------
Declaration          Dividend        Record             Payment
Date                 Per Share       Date               Date
-------------------- --------------- ------------------ ----------------------
February 22, 2000     $.2875         March 10, 2000     April 1, 2000
April 27, 2000        $.2875         June 9, 2000       July 1, 2000
-------------------- --------------- ------------------ ----------------------


Electric Operations

        Changes in the electric operations sales margins (including transactions
with affiliates) for the three months ended March 31, 2000, when compared to the
corresponding period in 1999, were as follows:

--------------------------------------------- -----------------------------
                                                        Three Months
(Millions of Dollars)                         Change         % Change
--------------------------------------------- -------------- --------------

Electric operating revenue                      $28.1           10.6
Less:  Fuel used in generation                    9.0           14.8
           Purchased power                        3.1           84.0
--------------------------------------------- -------------- --------------
Margin                                          $16.0            7.9
============================================= ============== ==============

        Electric  operations sales margins  increased for the three months ended
March 31, 2000, when compared to the corresponding  period in 1999, primarily as
a result of more favorable weather and customer growth.





<PAGE>


Gas Distribution

        Changes in the gas distribution  sales margins  (including  transactions
with affiliates) for the three months ended March 31, 2000, when compared to the
corresponding period in 1999, were as follows:

--------------------------------------------------------------------------------
                                                                Three Months
(Millions of Dollars)                  2000      1999     Change     % Change
                    -
--------------------------------------------------------------------------------

Gas distribution operating revenue    $255.6    $86.1     $169.5         *
Less:  Gas purchased for resale        152.7      49.1     103.6         *
--------------------------------------------------------------------------------
Margin                                $102.9    $37.0     $ 65.9         *
================================================================================

                                     * Greater than 100%

        Gas distribution sales margins for the three months ended March 31, 2000
increased  from 1999 levels  primarily  as a result of the  acquisition  of PSNC
(which  contributed  $64.2 million to the change).  The  remaining  increase was
attributable to more favorable weather and customer growth at SCE&G.

Gas Transmission

        Changes in the gas transmission  sales margins  (including  transactions
with affiliates) for the three months ended March 31, 2000, when compared to the
corresponding period in 1999, were as follows:

--------------------------------------------------------------------------------
                                                                 Three Months
(Millions of Dollars)                  2000       1999     Change     % Change
--------------------------------------------------------------------------------

Gas transmission operating revenue    $118.0      $93.0    $25.0        26.9
Less:  Gas purchased for resale        102.1       80.5     21.6        26.8
--------------------------------------------------------------------------------
Margin                                $ 15.9      $12.5    $ 3.4        27.2
================================================================================

        Gas transmission sales margins for the three months ended March 31, 2000
increased from 1999 levels primarily as a result of improved  industrial margins
due to an improved competitive position relative to alternate fuels.

Energy Marketing

        Changes in the energy marketing sales margins for the three months ended
March 31,  2000,  when  compared to the  corresponding  period in 1999,  were as
follows:

------------------------------------------------------------------------------
                                                           Three Months
(Millions of Dollars)                2000      1999    Change     % Change
---------------------------------------------------------------- ------------

Gas and electric sales revenue      $217.0    $149.5    $67.5       45.2
Less:  Gas and electricity
  purchased for resale               186.0    147.8     38.2       25.8
================================================================ ============
Margin                              $ 31.0    $ 1.7     $29.3         *
================================================================ ============

      *Greater than 100%

        Energy marketing sales margins for the three months ended March 31, 2000
increased  primarily  as a result of  improved  margins  in the  Georgia  retail
natural gas market. See LIQUIDITY AND CAPITAL RESOURCES.


<PAGE>



Other Operating Expenses

        Changes in other  operating  expenses,  including  taxes,  for the three
months ended March 31, 2000, when compared to the corresponding  period in 1999,
were as follows:

 -------------------------------------------- ----------------------------------
                                                              Three Months
 (Millions of Dollars)                 2000       1999    Change     % Change
 -------------------------------------------- ----------------------------------

 Other operation and maintenance      $110.8     $ 98.0    $12.8       13.1
 Depreciation and amortization           54.9       41.9    13.0       30.9
 Income taxes                            50.3       20.9    29.4      140.7
 Other taxes                             29.4       27.2     2.2        8.1
 -------------------------------------------- ----------------------------------
 Total                                $245.4     $188.0    $57.4       30.5
 ============================================ ==================================

        Other  operating  expenses  for the three  months  ended  March 31, 2000
increased  from 1999 levels  primarily as a result of the  acquisition  of PSNC.
This  acquisition  accounted for the following  increases:  Other  operation and
maintenance  ($16.2 million),  Depreciation  and  amortization  ($10.4 million),
Income taxes ($17.5 million) and Other taxes ($1.7 million).

        Apart from the PSNC acquisition, changes in other operating expenses for
the three months ended March 31, 2000 compared to the  corresponding  period for
1999 were as follows:  Other operation and maintenance  expenses  decreased $3.4
million.  This  decrease  was  primarily  attributable  to  decreased  operating
expenses at Energy  Marketing  ($8.3  million),  which were partially  offset by
higher   operating  and  maintenance   expenses  at  SCE&G.   Depreciation   and
amortization  expenses increased $2.6 million due to normal property  additions.
The increase in income taxes ($12.4  million)  primarily  reflects the change in
operating income.

Other Income

        Other income,  net of income taxes, for the three months ended March 31,
2000 increased  approximately  $2.7 million,  when compared to the corresponding
period of 1999. This increase was primarily  attributable to increased  earnings
on pension assets.

Interest Expense

        Interest  expense,  excluding  the debt  component of AFC, for the three
months ended March 31, 2000 increased approximately $19.8 million, when compared
to the  corresponding  period in 1999.  The  increase was  primarily  due to the
issuance of debt in the first  quarter of 2000 to complete  the  acquisition  of
PSNC.

Item 3.   Quantitative and Qualitative Disclosures About Market Risk

     All financial  instruments held by the Company described below are held for
purposes other than trading.

     Interest  rate  risk - The  table  below  provides  information  about  the
Company's financial instruments that are sensitive to changes in interest rates.
For debt  obligations,  the table  presents  principal  cash  flows and  related
weighted average interest rates by expected maturity dates.

 <TABLE>
                                                               March 31, 2000
                                                             Expected Maturity Date
                                     -------- ------------------------------------- ---------- ----------------
                                                        (Millions of Dollars)
                                                                                    There-              Fair
Liabilities                           2000     2001   2002       2003    2004     After      Total      Value
                                     -------- ---------------- ---------------- ---------- ---------- ----------

Long-Term Debt:
<S>        <C>                        <C>      <C>     <C>      <C>      <C>     <C>        <C>        <C>
Fixed Rate ($)                        159.3    38.1    36.8     296.8    186.3   1,276.1    1,993.4    1,835.5
Average Fixed Interest Rate (%)        6.63    7.31    7.22      6.26     7.58      7.35        7.13
Variable Rate ($)                     150.0     -     550.0     150.0      -        -         850.0      850.0
Average Variable Interest Rate (%)     7.16     -      7.53      8.02      -        -           7.45



<PAGE>



                                                                 March 31, 1999
                                                             Expected Maturity Date
                                  ------- -------- ------------------------------- ---------------------------
                                                       (Millions of Dollars)
                                                                                 There-                 Fair
Liabilities                        2000     2001     2002       2003    2004     After      Total      Value
                                  ------- -------- ---------- --------------------------- ---------- ----------

Long-Term Debt:
<S>        <C>                     <C>      <C>      <C>       <C>      <C>     <C>        <C>        <C>
Fixed Rate ($)                     213.5    27.5     27.5      284.4    129.4   1,166.7    1,849.0    1,869.2
Average Fixed Interest Rate (%)     5.95    6.86     6.86       6.29     7.52      7.33        7.

</TABLE>


     While a decrease in interest  rates would  increase the fair value of debt,
it is unlikely that events which would result in a realized loss will occur.

     In  addition,  the Company has  invested  in a  telecommunications  company
approximately  $40 million for 11.875% senior  discount notes due 2007. The fair
value of these notes  approximates  their carrying  value. An increase in market
interest  rates  would  result in a decrease  in fair value of these notes and a
corresponding adjustment, net of tax, to other comprehensive income.

     Commodity  price  risk - The table  below  provides  information  about the
Company's  financial  instruments  that are  sensitive to changes in natural gas
prices. Weighted average settlement prices are per 10,000 mmbtu.

March 31, 2000                               Expected Maturity in 2000
                            Weighted Avg        Contract            Fair
Natural Gas Derivatives:    Settlement Price     Amount             Value
--------------------------- ----------------------------------- --------------
                                             (Millions of Dollars)
Future Contracts:
   Long                         $2.9741               $  .9           $1.2
   Short                        $3.1770                $2.2           $2.6
SET Futures Contracts (1):
   Long                         $2.9553               $  .1          $  .2
   Short                              -                   -              -


March 31, 1999                          Expected Maturity in 2000
                                Weighted Avg         Contract       Fair
Natural Gas Derivatives:        Settlement Price      Amount        Value
------------------------------- ----------------------------------- ---------
                                              (Millions of Dollars)
Future Contracts:
   Long                             $2.4818          $10.2          $10.6
   Short                            $     -          $   -          $   -
SET Futures Contracts (1):
   None


March 31, 1999                                  Expected Maturity in 1999
                               Weighted Avg          Contract        Fair
Natural Gas Derivatives:       Settlement Price      Amount          Value
------------------------------ -------------------------------------------------
                                                 (Millions of Dollars)
Future Contracts:
   Long                            $2.1654           $30.1          $31.6
   Short                           $2.0434           $ 0.2          $ 0.2
SET Futures Contracts (1):
   None

(1) SCANA Energy  Trading,  LLC (SET) is a 70% owned  subsidiary of SCANA Energy
Marketing, Inc. Amounts shown are at 100%.

     Equity price risk - Investments in telecommunications companies' marketable
equity  securities  are carried at their market value of $780.0  million.  A ten
percent  decline in market  value would result in a $78.0  million  reduction in
fair value and a  corresponding  adjustment,  net of tax effect,  to the related
equity account for unrealized  gains/losses,  a component of other comprehensive
income.





<PAGE>

















                      SOUTH CAROLINA ELECTRIC & GAS COMPANY
                                FINANCIAL SECTION



















<PAGE>


Item 1.  Financial Statements

                      SOUTH CAROLINA ELECTRIC & GAS COMPANY
                           CONSOLIDATED BALANCE SHEETS
                   As of March 31, 2000 and December 31, 1999
                                   (Unaudited)




                                                        March 31,   December 31,
--------------------------------------------------------------------------------
                                                           2000          1999
-------------------------------------------------------------------------------
Assets                                                  (Millions of Dollars)
Utility Plant:
    Electric                                              $4,334        $4,337
    Gas                                                      390           392
    Other                                                    190           191
-------------------------------------------------------------------------------
        Total                                              4,914         4,920
    Less accumulated depreciation and amortization         1,643         1,611
-------------------------------------------------------------------------------
        Total                                              3,271         3,309
    Construction work in progress                            186           149
    Nuclear fuel, net of accumulated amortization             41            43
--------------------------------------------------------------------------------
        Utility Plant, Net                                 3,498         3,501
--------------------------------------------------------------------------------

Nonutility Property and Investments, net of accumulated
    depreciation                                              19            19
--------------------------------------------------------------------------------

Current Assets:
    Cash and temporary cash investments                       62            78
    Receivables (including unbilled revenues)                211           195
    Inventories (at average cost):
        Fuel                                                  28            30
        Materials and supplies                                47            48
    Prepayments                                               13             8
    Deferred income taxes                                     14            16
-------------------------------------------------------------------------------
        Total Current Assets                                 375           375
--------------------------------------------------------------------------------

Deferred Debits:
    Emission allowances                                       30            31
    Environmental                                             21            24
    Nuclear plant decommissioning fund                        66            64
    Pension asset, net                                       154           144
    Other regulatory assets                                  152           162
    Other                                                     87            84
--------------------------------------------------------------------------------
        Total Deferred Debits                                510           509
--------------------------------------------------------------------------------
            Total                                         $4,402        $4,404
================================================================================






<PAGE>




                      SOUTH CAROLINA ELECTRIC & GAS COMPANY
                           CONSOLIDATED BALANCE SHEETS
                   As of March 31, 2000 and December 31, 1999
                                   (Unaudited)


                                                     March 31,     December 31,
--------------------------------------------------------------------------------
                                                       2000           1999
--------------------------------------------------------------------------------
Capitalization and Liabilities                           (Millions of Dollars)
Stockholders' Investment:
    Common equity                                     $1,601         $1,558
    Preferred stock (not subject to purchase
      or sinking funds)                                  106            106
--------------------------------------------------------------------------------
        Total Stockholders' Investment                 1,707          1,664
Preferred Stock, net (subject to purchase or
  sinking funds)                                          11             11
SCE&G-Obligated Mandatorily Redeemable Preferred
    Securities of SCE&G's Subsidiary Trust, SCE&G
    Trust I, holding solely $50 million principal
    amount of the 7.55% Junior Subordinated
    Debentures of SCE&G, due 2027                         50             50
Long-Term Debt, net                                    1,120          1,121
--------------------------------------------------------------------------------
          Total Capitalization                         2,888          2,846
--------------------------------------------------------------------------------

Current Liabilities:
    Short-term borrowings                                187            213
    Current portion of long-term debt                    127            128
    Accounts payable                                      64             78
    Accounts payable - affiliated companies               24             33
    Customer deposits                                     17             17
    Taxes accrued                                         39             60
    Interest accrued                                      25             22
    Dividends declared                                    34             28
    Other                                                  7             10
--------------------------------------------------------------------------------
          Total Current Liabilities                      524            589
--------------------------------------------------------------------------------

Deferred Credits:
    Deferred income taxes                                579            560
    Deferred investment tax credits                      108            108
    Reserve for nuclear plant decommissioning             66             64
    Postretirement benefits                               99             98
    Other regulatory liabilities                          67             59
    Other                                                 71             80
--------------------------------------------------------------------------------
          Total Deferred Credits                         990            969
--------------------------------------------------------------------------------
                Total                                 $4,402         $4,404
================================================================================

See Notes to Consolidated Financial Statements.
















<PAGE>


                      SOUTH CAROLINA ELECTRIC & GAS COMPANY
             CONSOLIDATED STATEMENTS OF INCOME AND RETAINED EARNINGS
                  For the Periods Ended March 31, 2000 and 1999
                                   (Unaudited)

                                                          Three Months Ended
                                                               March 31,
--------------------------------------------------------------------------------
                                                          2000          1999
--------------------------------------------------------------------------------
                                                          (Millions of Dollars)
Operating Revenues:
    Electric                                              $294          $266
    Gas                                                    101            86
    Transit                                                  -             1
--------------------------------------------------------------------------------
        Total Operating Revenues                           395           353
--------------------------------------------------------------------------------
Operating Expenses:
    Fuel used in electric generation                        57            45
    Purchased power (including affiliated purchases)        29            28
    Gas purchased from affiliate  for resale                62            49
    Other operation                                         57            53
    Maintenance                                             18            17
    Depreciation and amortization                           40            38
    Income taxes                                            29            26
    Other taxes                                             25            25
--------------------------------------------------------------------------------
        Total Operating Expenses                           317           281
--------------------------------------------------------------------------------

Operating Income                                            78            72
--------------------------------------------------------------------------------

Other Income:
    Allowance for equity funds used during construction      -             1
    Other income, net of income taxes                        4             1
--------------------------------------------------------------------------------
        Total Other Income                                   4             2
--------------------------------------------------------------------------------

Income Before Interest Charges                              82            74
--------------------------------------------------------------------------------

Interest Charges (Credits):
    Interest expense on long-term debt                      24            23
    Other interest expense                                   3             3
    Allowance for borrowed funds used during construction   (1)           (1)
--------------------------------------------------------------------------------
        Total Interest Charges, Net                         26            25
--------------------------------------------------------------------------------

Income Before Preferred Dividend Requirements
    on Mandatorily Redeemable Preferred Securities          56            49
Preferred Dividend Requirement of SCE&G - Obligated
    Mandatorily Redeemable Preferred Securities              1             1
--------------------------------------------------------------------------------

Income Before Cumulative Effect of Accounting Change        55            48
Cumulative Effect of Accounting Change, net of taxes        22             -
--------------------------------------------------------------------------------

Net Income                                                  77            48
Preferred Stock Cash Dividends (At stated rates)            (2)           (2)
--------------------------------------------------------------------------------
Earnings Available for Common Stock                         75            46
Retained Earnings at Beginning of Period                   550           491
Common Stock Cash Dividends Declared                       (32)          (36)
================================================================================
Retained Earnings at End of Period                        $593          $501
================================================================================

See Notes to Consolidated Financial Statements.






<PAGE>


                      SOUTH CAROLINA ELECTRIC & GAS COMPANY
                      CONSOLIDATED STATEMENTS OF CASH FLOWS
                  For the Periods Ended March 31, 2000 and 1999
                                   (Unaudited)

                                                            Three Months Ended
                                                                 March 31,
------------------------------------------------------------------ -------------
                                                              2000        1999
------------------------------------------------------------------ -------------
                                                           (Millions of Dollars)
Cash Flows From Operating Activities:
   Net income                                                  $77        $48
      Adjustments to reconcile net income to net
       cash provided from operating activities:
          Cumulative effect of accounting change               (22)         -
          Depreciation and amortization                         40         38
          Amortization of nuclear fuel                           5          5
          Deferred income taxes, net                            21         22
          Pension asset                                        (10)        (7)
          Post retirement benefits                                1         3
          Other regulatory assets                               10          7
          Regulatory liabilities                                 8          4
          Allowance for funds used during construction          (1)        (2)
          Over (under) collections, fuel adjustment clauses     14          9
          Changes in certain current assets and liabilities:
              (Increase) decrease in receivables                 6         14
              (Increase) decrease in inventories                 3        (15)
              Increase (decrease) in accounts payable          (23)       (12)
              Increase (decrease) in taxes accrued             (21)       (49)
       Other, net                                              (30)       (33)
--------------------------------------------------------------------------------
       Net Cash Provided From Operating Activities              78         32
--------------------------------------------------------------------------------

Cash Flows From Investing Activities:
       Utility property additions and construction
         expenditures, net of AFC                              (39)       (48)
--------------------------------------------------------------------------------
       Net Cash Used For Investing Activities                  (39)       (48)
--------------------------------------------------------------------------------

Cash Flows From Financing Activities:
     Proceeds:
         Issuance of First Mortgage Bonds                        -         99
     Repayments:
         Other long-term debt                                   (1)         -
     Dividend payments:
         Common stock                                          (26)       (36)
         Preferred stock                                         (2)       (2)
     Short-term borrowings, net                                (26)       (48)
     Fuel and emission allowance financings, net                  -        13
--------------------------------------------------------------------------------
     Net Cash Provided From (Used For)
       Financing Activities                                    (55)        26
--------------------------------------------------------------------------------

Net Increase (Decrease) In Cash And Temporary
  Cash Investments                                             (16)        10
Cash And Temporary Cash Investments At January 1                78         36
================================================================================
Cash And Temporary Cash Investments At March 31                $62        $46
================================================================================

Supplemental Cash Flow Information:
    Cash paid for - Interest (includes capitalized
                    interest of $1 for 2000 and 1999)           $24       $21
                           - Income taxes                         7         4

See Notes to Consolidated Financial Statements.



<PAGE>



                      SOUTH CAROLINA ELECTRIC & GAS COMPANY
                   NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
                                 March 31, 2000
                                   (Unaudited)

         The  following  notes should be read in  conjunction  with the Notes to
Consolidated  Financial  Statements  appearing in South Carolina  Electric & Gas
Company's  (the Company)  Annual Report on Form 10-K for the year ended December
31, 1999. These are interim  financial  statements,  and the amounts reported in
the Consolidated  Statements of Income are not necessarily indicative of amounts
expected for the year. In the opinion of management,  the information  furnished
herein  reflects all  adjustments,  all of a normal  recurring  nature except as
described  in Notes 2 and 3, which are  necessary  for a fair  statement  of the
results for the interim periods reported.

1.   SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES:

       A.  Basis of Accounting

       The Company  accounts for its regulated  utility  operations,  assets and
       liabilities  in accordance  with the provisions of Statement of Financial
       Accounting  Standards No. 71 (SFAS 71). This accounting standard requires
       cost-based  rate-regulated  utilities  to  recognize  in their  financial
       statements  revenues  and  expenses in  different  time  periods  than do
       enterprises  that are not  rate-regulated.  As a result,  the Company has
       recorded,  as of March  31,  2000,  approximately  $175  million  and $67
       million of regulatory  assets and  liabilities,  respectively,  including
       amounts  recorded  for  deferred  income tax assets  and  liabilities  of
       approximately  $121 million and $43 million,  respectively.  The electric
       and gas  regulatory  assets  (excluding  deferred  income tax  assets) of
       approximately $26 million each are being recovered through rates, and the
       Public   Service   Commission  of  South   Carolina  (PSC)  has  approved
       accelerated   recovery  of  approximately  $5  million  of  the  electric
       regulatory  assets.  In the future,  as a result of deregulation or other
       changes in the regulatory environment, the Company may no longer meet the
       criteria for  continued  application  of SFAS 71 and could be required to
       write off its regulatory assets and liabilities. Such an event could have
       a material  adverse effect on the Company's  results of operations in the
       period that a write-off  would be required,  but it is not expected  that
       cash flows or financial position would be materially affected.

       B.  Reclassifications

       Certain amounts from prior periods have been reclassified to conform with
the 2000 presentation.

2.      Cumulative Effect of Accounting Change

        Effective  January 1, 2000 the Company  changed its method of accounting
        for  operating  revenues  from  cycle  billing  to  full  accrual.   The
        cumulative  effect of this change was $22 million,  net of tax. Accruing
        unbilled  revenues more closely matches revenues and expenses.  Unbilled
        revenues  represent the estimated  amount  customers will be charged for
        service received, but that has not yet been billed, as of the end of the
        accounting   period.   Previously  these  revenues  were  recognized  as
        operating revenues as customers were billed.

        If this method had been  applied  retroactively,  net income  would have
        been $65 million for the three months ended March 31, 1999,  compared to
        $48 million as previously reported.


<PAGE>



3.  RETAINED EARNINGS

       The Restated  Articles of  Incorporation of the Company and the Indenture
       underlying  its First and Refunding  Mortgage  Bonds  contain  provisions
       that,  under  certain  circumstances,  could  limit the  payment  of cash
       dividends on its common stock. In addition, with respect to hydroelectric
       projects,  the Federal Power Act requires the  appropriation of a portion
       of certain earnings  therefrom.  At March 31, 2000,  approximately  $30.8
       million of retained  earnings were  restricted by this  requirement as to
       payment of cash dividends on common stock.

4.   CONTINGENCIES

       With respect to commitments at March 31, 2000,  reference is made to Note
       10 of  Notes  to  Consolidated  Financial  Statements  appearing  in  the
       Company's  Annual  Report on Form 10-K for the year  ended  December  31,
       1999. Contingencies at March 31, 2000 are as follows:

       A. Nuclear Insurance

       The Price-Anderson Indemnification Act, which deals with public liability
       for a nuclear  incident,  currently  establishes  the liability limit for
       third-party  claims associated with any nuclear incident at $9.5 billion.
       Each  reactor  licensee is currently  liable for up to $88.1  million per
       reactor owned for each nuclear  incident  occurring at any reactor in the
       United  States,  provided that not more than $10 million of the liability
       per reactor would be assessed per year. The Company's maximum assessment,
       based on its  two-thirds  ownership of the V. C. Summer  Nuclear  Station
       (Summer Station),  would be approximately $58.7 million per incident, but
       not more than $6.7 million per year.

        The Company  currently  maintains  policies (for itself and on behalf of
        the South  Carolina  Public  Service  Authority)  with Nuclear  Electric
        Insurance  Limited (NEIL).  These policies covering the nuclear facility
        for  property  damage,  excess  property  damage and outage costs permit
        assessment under certain conditions to cover insurer's losses.  Based on
        the current annual  premium,  the Company's  portion of the  retroactive
        premium assessment would not exceed $8.1 million.

        To   the   extent   that   insurable   claims   for   property   damage,
        decontamination,  repair and  replacement  and other costs and  expenses
        arising  from a nuclear  incident  at Summer  Station  exceed the policy
        limits of insurance, or to the extent such insurance becomes unavailable
        in the  future,  and to the extent  that the  Company's  rates would not
        recover the cost of any purchased  replacement  power,  the Company will
        retain the risk of loss as a self-insurer.  The Company has no reason to
        anticipate  a serious  nuclear  incident at Summer  Station.  If such an
        incident were to occur,  it could have a material  adverse impact on the
        Company's results of operations, cash flows and financial position.

 B.  Environmental

        The  Company has an  environmental  assessment  program to identify  and
        assess   current  and  former   operations   sites  that  could  require
        environmental cleanup. As site assessments are initiated,  estimates are
        made of the  expenditures,  if any, deemed  necessary to investigate and
        clean  up  each  site.   These   estimates  are  refined  as  additional
        information  becomes  available;  therefore,  actual  expenditures could
        differ significantly from the original estimates.  Amounts estimated and
        accrued to date for site  assessments  and cleanup  relate  primarily to
        regulated  operations.  Such  amounts are deferred  and  amortized  with
        recovery provided through rates. The Company has also recovered portions
        of  its  environmental  liabilities  through  settlements  with  various
        insurance  carriers.  The Company has recovered  all amounts  previously
        deferred for its electric operations. The Company expects to recover all
        deferred  amounts  related  to its  gas  operations  by  December  2005.
        Deferred  amounts,  net of amounts recovered through rates and insurance
        settlements,  totaled  $20.8  million at March 31,  2000.  The  deferral
        includes the estimated costs associated with the following matters.


<PAGE>



     o    In September 1992 the  Environmental  Protection Agency (EPA) notified
          the  Company,  the  City  of  Charleston  and the  Charleston  Housing
          Authority  of their  potential  liability  for the  investigation  and
          cleanup of the Calhoun Park area site in Charleston,  South  Carolina.
          This site encompasses  approximately 30 acres and includes  properties
          which were  locations  for  industrial  operations,  including  a wood
          preserving  (creosote)  plant,  one  of the  Company's  decommissioned
          manufactured  gas plants (MGP),  properties owned by the National Park
          Service and the City of Charleston,  and private properties.  The site
          has not been placed on the National  Priorities List, but may be added
          in  the  future.  The  Potentially  Responsible  Parties  (PRPs)  have
          negotiated  an  administrative  order by consent  for the conduct of a
          Remedial  Investigation/Feasibility Study and a corresponding Scope of
          Work.  Field  work  began in  November  1993,  and the EPA  approved a
          Remedial Investigation Report in February 1997 and a Feasibility Study
          Report in June  1998.  In July  1998 the EPA  approved  the  Company's
          Removal Action Work Plan for soil  excavation.  The Company  completed
          Phase One of the  Removal  Action  in 1998 at a cost of  approximately
          $1.5  million.  Phase Two,  which  cost  approximately  $3.5  million,
          included  excavation and installation of several permanent barriers to
          mitigate coal tar seepage.  On September 30, 1998 a Record of Decision
          was issued which sets forth the EPA's view of the extent of each PRP's
          responsibility  for site contamination and the level to which the site
          must be remediated.  The Company estimates that the Record of Decision
          will  result  in  costs  of  approximately  $13.3  million,  of  which
          approximately $4 million remains. On January 13, 1999 the EPA issued a
          Unilateral  Administrative  Order for  Remedial  Design  and  Remedial
          Action  directing  the  Company  to  design  and  carry  out a plan of
          remediation for the Calhoun Park site. The Order is temporarily stayed
          pending further negotiations between the Company and the EPA. However,
          the Company  submitted a  Comprehensive  Remedial  Design Work Plan on
          December 17, 1999 and is proceeding with implementation pending agency
          approval.

          In October 1996 the City of Charleston and the Company  settled  all
          environmental  claims  the  City  may have  had  against  the  Company
          involving the Calhoun Park area for a payment of $26 million over four
          years  (1996-1999)  by  the  Company  to  the  City.  The  Company  is
          recovering the amount of the settlement, which does not encompass site
          assessment  and  cleanup  costs,  through  rates in the same manner as
          other amounts accrued for site assessments and cleanup. As part of the
          environmental  settlement,  the  Company  constructed  an 1,100  space
          parking garage on the Calhoun Park site (construction was completed in
          April 2000) and transferred the facility to the City in exchange for a
          20-year  municipal bond backed by revenues from the parking garage and
          a mortgage  on the  parking  garage.  The total  amount of the bond is
          still being finalized but is not to exceed $16.9 million,  the maximum
          expected project cost.

     o    The Company owns three other  decommissioned  MGP sites which  contain
          residues  of  by-product  chemicals.  For the site  located in Sumter,
          South Carolina, effective September 15, 1998, the Company entered into
          a Remedial Action Plan Contract with the South Carolina  Department of
          Health and Environmental Control (DHEC) pursuant to which it agreed to
          undertake  a  full  site   investigation  and  remediation  under  the
          oversight  of  DHEC.  Site  investigation  and   characterization  are
          proceeding  according  to  schedule.  Upon  selection  and  successful
          implementation  of a  site  remedy,  DHEC  will  give  the  Company  a
          Certificate  of  Completion  and a covenant not to sue. The Company is
          continuing to investigate  the other two sites,  and is monitoring the
          nature and extent of residual contamination.

5.  SEGMENT OF BUSINESS INFORMATION

The Company's reportable segments are listed in the following table. The Company
uses operating income to measure  profitability for its Electric  Operations and
Gas  Distribution  segments.  Therefore,  net income is not  allocated  to these
segments.  Affiliate  revenue is derived from  transactions  between  reportable
segments  as well as  transactions  between  separate  legal  entities  that are
combined into the same reportable segment.  Assets for the period did not change
significantly.



<PAGE>



                        Disclosure of Reportable Segments
                              (Millions of Dollars)

----------------------------------------------- --------------------------------
                         Electric      Gas       All   Adjustments/ Consolidated
  March 31, 2000         Operations Distribution Other Eliminations      Total
----------------------------------------------- --------------------------------

External  Revenue           $294       $101        -          -         $395
Intersegment Revenue          55          -        -        (55)           -
Operating Income (Loss)       65         15       (1)        (1)          78
----------------------------------------------- --------------------------------


------------------------------------ ------------ ---------- -------------------

--------------------------------------------- ----------------------------------
                       Electric      Gas         All   Adjustments/ Consolidated
 March 31, 1999        Operations Distribution   Other  Eliminations   Total
--------------------------------------------- ---------------------------------

External Revenue          $266        $86      $  1          -          $353
Intersegment Revenue        44          -         -        (44)
                                                                           -
Operating Income (Loss)     60         14        (1)        (1)           72
--------------------------------------------- ----------------------------------





<PAGE>


Item 2.  Management's Discussion and Analysis of Financial Condition and
          Results of Operations


                      SOUTH CAROLINA ELECTRIC & GAS COMPANY
                     MANAGEMENT'S DISCUSSION AND ANALYSIS OF
                  FINANCIAL CONDITION AND RESULTS OF OPERATIONS

        The following discussion should be read in conjunction with Management's
Discussion  and  Analysis  of  Financial  Condition  and  Results of  Operations
appearing in South  Carolina  Electric & Gas Company's  (SCE&G) Annual Report on
Form 10-K for the year ended December 31, 1999.

        Statements  included in this  discussion  and analysis (or  elsewhere in
this quarterly  report) which are not statements of historical fact are intended
to be, and are hereby  identified as, "forward looking  statements" for purposes
of the safe harbor  provided by Section 27A of the  Securities  Act of 1933,  as
amended,  and Section 21E of the  Securities  Exchange Act of 1934,  as amended.
Readers  are  cautioned  that  any  such  forward-looking   statements  are  not
guarantees   of  future   performance   and   involve  a  number  of  risks  and
uncertainties,  and that  actual  results  could  differ  materially  from those
indicated by such forward-looking statements. Important factors that could cause
actual results to differ materially from those indicated by such forward-looking
statements  include,  but are not  limited  to,  the  following:  (1)  that  the
information  is of a  preliminary  nature and may be  subject to further  and/or
continuing  review  and  adjustment,  (2)  changes  in  the  utility  regulatory
environment,  (3) changes in the economy in SCE&G's service  territory,  (4) the
impact of competition from other energy suppliers, (5) the management of SCE&G's
operations,  (6) variations in prices of natural gas and fuels used for electric
generation, (7) growth opportunities,  (8) the results of financing efforts, (9)
changes in SCE&G's accounting policies,  (10) weather conditions in areas served
by SCE&G, (11) inflation, (12) exposure to environmental issues and liabilities,
(13)  changes  in  environmental  regulations  and  (14)  the  other  risks  and
uncertainties described from time to time in SCE&G's periodic reports filed with
the Securities and Exchange Commission. SCE&G disclaims any obligation to update
any forward-looking statements.

               MATERIAL CHANGES IN CAPITAL RESOURCES AND LIQUIDITY
                             SINCE DECEMBER 31, 1999

LIQUIDITY AND CAPITAL RESOURCES

       On September 14, 1999 the PSC approved an  accelerated  capital  recovery
plan for SCE&G's Cope Generating Station. The plan will be implemented beginning
January 1, 2000 for a three-year period. The PSC approved an accelerated capital
recovery  methodology  wherein  SCE&G  will  increase  depreciation  of its Cope
Generating  Station  in excess of  amounts  that  would be  recorded  based upon
currently   approved   depreciation   rates.   The  amount  of  the  accelerated
depreciation  will be  determined  by SCE&G based on the level of  revenues  and
operating  expenses,  not to exceed $36 million annually without the approval of
the PSC.  Any  unused  portion  of the $36  million  in any given  year could be
carried forward for possible use in the succeeding year. The accelerated capital
recovery plan will be accomplished through existing customer rates.


<PAGE>



       The following table  summarizes how SCE&G generated funds for its utility
property additions and construction  expenditures  during the three months ended
March 31, 2000 and 1999:

-------------------------------------------------------------------------------
                                                           Three Months Ended
                                                               March 31,
                                                           2000         1999
------------------------------------------------------------------ -------------
                                                         (Millions of Dollars)

Net cash provided from operating activities                $ 78         $32
Net cash provided from (used for) financing
  activities                                                (55)         26
Cash and temporary cash investments available
  at the beginning of the period                             78          36
--------------------------------------------------------------------------------
Net cash available for utility property
  additions and construction expenditures                  $101         $94
--------------------------------------------------------------------------------
Funds used for utility property additions
  and construction expenditures, net of
  noncash allowance for funds used during construction    $ 39          $48
--------------------------------------------------------------------------------
Funds used for (provided from) nonutility property
  additions and investments                                $ -          $ -
================================================================================

        SCE&G  anticipates that the remainder of its 2000 cash requirements will
be met through  internally  generated  funds and the  incurrence  of  additional
short-term  and long-term  debt. The timing and amount of such  financings  will
depend upon market  conditions and other  factors.  SCE&G expects that it has or
can obtain adequate sources of financing to meet its projected cash requirements
for the next twelve months and for the foreseeable future. The ratio of earnings
to fixed charges for the twelve months ended March 31, 2000 was 3.71.





<PAGE>



                              RESULTS OF OPERATIONS
                    FOR THE THREE MONTHS ENDED MARCH 31, 2000
                 AS COMPARED TO THE CORRESPONDING PERIOD IN 1999

Earnings and Dividends

         Net income for the three  months  ended March 31, 2000 and 1999 were as
follows:

(Millions of Dollars)                                 2000         1999
---------------------------------------------------------- ------------

Net income derived from:
     Continuing operations                           $54.2        $47.8
     Change in accounting                             22.3             -
------------------------------------------------- ------------ ------------
     Total net income                                $76.5        $47.8
================================================= ============ ============

         Net income from continuing  operations increased $6.4 million. This was
primarily  attributable to improved electric and gas margins ($17.1 million) and
other income which were partially  offset by increased other operating  expenses
($10.8 million).

         Earnings  from a  change  in  accounting  resulted  from  recording  of
unbilled revenue (See NOTES TO CONSOLIDATED FINANCIAL STATEMENTS).

         Allowance  for  funds  used  during  construction  (AFC)  is a  utility
accounting  practice  whereby a portion of the cost of both equity and  borrowed
funds  used to  finance  construction  (which is shown on the  balance  sheet as
construction  work in  progress)  is  capitalized.  Both the equity and the debt
portions of AFC are noncash items of  nonoperating  income which have the effect
of increasing  reported net income.  AFC represented  approximately 1% and 3% of
income  before  income  taxes for the three months ended March 31, 2000 and 1999
respectively.

         SCE&G's  Board of Directors  authorized  payment of dividends on common
stock held by SCANA, as follows:

-------------------- ----------------- ------------------- ------------------
Declaration          Dividend          Quarter             Payment
Date                 Amount            Ended               Date
-------------------- ----------------- ------------------- ------------------
February 22, 2000    $32.0 million     March 31, 2000      April 1, 2000
April 27, 2000       $32.0 million     June  30, 2000      July 1, 2000
-------------------- ----------------- ------------------- ------------------

Electric Operations

           Changes  in  the  electric   operations   sales  margins   (including
transactions  with  affiliates)  for the three months ended March 31, 2000, when
compared to the corresponding period in 1999, were as follows:

-------------------------------------------------------------------------------
                                                     Three Months Ended
(Millions of Dollars)            2000       1999     Change     % Change
                    -
----------------------------------------------------------------------------

Electric operating revenue      $294.3     $266.2     $28.1       10.6
Less:  Fuel used in generation    57.0       44.6      12.4       27.7
           Purchased power        29.0       28.7       0.3        1.2
----------------------------------------------------------------------------
Margin                          $208.3     $192.9     $15.4        8.0
============================================================================

           Electric  operations  sales  margins  increased  for the three months
ended  March  31,  2000,  when  compared  to the  corresponding  period in 1999,
primarily as a result of more favorable weather and customer growth.


<PAGE>



Gas Distribution

           Changes in the gas  distribution  sales  margins for the three months
ended March 31, 2000, when compared to the corresponding period in 1999, were as
follows:

------------------------------------------------------------------------------
                                                       Three Months Ended
(Millions of Dollars)             2000      1999      Change      % Change
------------------------------------------------------------------------------

Gas operating revenue            $100.4     $86.1     $14.3         16.6
Less:  Gas purchased for resale    61.7      49.1      12.6         25.6
------------------------------------------------------------------------------
Margin                           $ 38.7     37.0      $ 1.7          4.6
==============================================================================

     Gas  distribution  sales  margins for the three months ended March 31, 2000
increased  from the  corresponding  period in 1999 primarily as a result of more
favorable weather and customer growth.

 Other Operating Expenses

     Changes in other operating expenses,  including taxes, for the three months
ended March 31, 2000 when compared to the corresponding  period in 1999, were as
follows:

--------------------------------------------------------------------------------
                                                          Three Months Ended
(Millions of  Dollars)                2000       1999      Change    % Change
--------------------------------------------------------------------------------

Other operation and maintenance      $ 75.3     $ 70.2     $ 5.1       7.3
Depreciation and amortization          40.4       38.2       2.2       5.6
Income taxes                           29.0       26.1       2.9      11.2
Other taxes                            25.3       24.7       0.6       2.5
--------------------------------------------------------------------------------
Total                                $170.0     $159.2     $10.8       6.8
================================================================================

     Other operation and  maintenance  expenses for the three months ended March
31, 2000 increased from 1999 levels primarily as a result of increased operating
and maintenance costs for electric generation and distribution  facilities.  The
increase in depreciation and amortization expenses resulted from normal property
additions. The change in income taxes primarily reflects the change in operating
income.

Other Income

     Other  income,  net of income  taxes,  for the three months ended March 31,
2000  increased  approximately  $2.7 million and is primarily due to earnings on
pension assets.



<PAGE>


Item 3.    Quantitative and Qualitative Disclosures About Market Risk

     All  financial  instruments  held by  SCE&G  described  below  are held for
purposes other than trading.

     Interest  rate risk - The table below  provides  information  about SCE&G's
financial  instruments that are sensitive to changes in interest rates. For debt
obligations,  the table  presents  principal  cash  flows and  related  weighted
average interest rates by expected maturity dates.

<TABLE>


                                                          March 31, 2000
                                                       Expected Maturity Date
                             --------- ---------------------------------- ------ --------------
                            (Millions of Dollars)
                                                                   There-             Fair
Liabilities                    2000  2001   2002   2003    2004    After    Total     Value
                             ------------- ----------------------------------------------------

Long-Term Debt:
<S>        <C>                <C>    <C>    <C>    <C>     <C>      <C>     <C>       <C>
Fixed Rate ($)                127.5  27.6   27.6   129.4   123.9    933.0   1,369.0   1,232.7
Average Interest Rate (%)      6.16  6.73   6.73    6.37   7.52     7.72       7.39


                                                              March 31, 1999
                                                          Expected Maturity Date
                               --------- ------------- -------------------- ---------------------
                              (Millions of Dollars)
                                                                      There-            Fair
Liabilities                      2000   2001   2002    2003    2004   After    Total    Value
                               ------- ----------------------------------------------------------

Long-Term Debt:
<S>        <C>                  <C>     <C>    <C>    <C>     <C>     <C>     <C>      <C>
Fixed Rate ($)                  122.6   22.6   22.6   124.5   124.5   944.2   1,361.0  1,356.4
Average Interest Rate (%)        7.52   6.72   6.72    7.56    7.52    7.57    7.53

</TABLE>


    While a decrease in interest  rates would  increase the fair value of debt,
it is unlikely that events which would result in a realized loss will occur.










<PAGE>


                           PART II. OTHER INFORMATION

Item 1.   Legal Proceedings

         SCANA Corporation:

         For information  regarding legal proceedings see Note 2 "Rate Matters,"
         appearing  in the  Company's  Annual  Report  on Form 10-K for the year
         ended  December  31,  1999,  and  Note 7  "Contingencies"  of  Notes to
         Consolidated Financial Statements appearing in this Quarterly Report on
         Form 10-Q.

         South Carolina Electric  & Gas Company:

         For information regarding legal proceedings see Note 2 "Rate Matters, "
         appearing in South Carolina  Electric & Gas Company's  Annual Report on
         Form  10-K  for  the  year  ended   December  31,  1999,   and  Note  4
         "Contingencies" of Notes to Consolidated Financial Statements appearing
         in this Quarterly Report on Form 10-Q.

Items 2, 3, 4 and 5 are not applicable  for SCANA  Corporation or South Carolina
Electric & Gas Company.

Item 6.    Exhibits and Reports  on Form 8-K

         SCANA Corporation and South Carolina Electric & Gas Company:

         A.  Exhibits

                Exhibits  filed  with  this  Quarterly  Report  on Form 10-Q are
                listed in the following Exhibit Index.  Certain of such exhibits
                which  have  heretofore  been  filed  with  the  Securities  and
                Exchange  Commission  and which are  designated  by reference to
                their exhibit  numbers in prior filings are hereby  incorporated
                herein by reference and made a part hereof.

         B. Reports on Form 8-K during the first quarter 2000 were as follows:

                SCANA filed a current report on Form 8-K:
                Date of report:    February 10, 2000
                Items reported:   Items 5 and 7

                SCE&G:   None



<PAGE>



                                SCANA CORPORATION


                                   SIGNATURES

       Pursuant to the requirements 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.




                                            SCANA CORPORATION
                                              (Registrant)




May 12, 2000                              By: s/M. R. Cannon
                                              --------------------

                                              M. R. Cannon
                                              Controller
                                             (principal accounting officer)






































<PAGE>




                      SOUTH CAROLINA ELECTRIC & GAS COMPANY

                                   SIGNATURES

       Pursuant to the requirements 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.



                                       SOUTH CAROLINA ELECTRIC & GAS COMPANY
                                                   (Registrant)




May  12, 2000                            By:   s/Mark R. Cannon
                                               Mark R. Cannon
                                               Controller
                                              (Principal accounting officer)






<PAGE>




                                  EXHIBIT INDEX

        Applicable to
Exhibit Form 10-Q of
No.   SCANA   SCE&G  Description
---     ---------  -------------------------------------------------------------
2.01    X     X     Agreement and Plan of Merger, dated as of February 16, 1999
                    as amended and restated as of May 10, 1999, by and among
                    Public Service Company of North Carolina, Incorporated,
                    SCANA Corporation , New Sub I, Inc. and New Sub II, Inc.
                    (Filed as Exhibit 2.1 to Registration Statement No
                    333-78227)

3.01    X           Restated Articles of Incorporation of SCANA as adopted on
                    April 26, 1989 (Filed as Exhibit 3-A to Registration
                    Statement No. 33-49145)

3.02          X     Restated Articles of Incorporation of SCE&G, as adopted on
                    December 15, 1993  (Filed as Exhibit 3.01 to Registration
                    Statement No. 333-86387)

3.03    X           Articles of Amendment of SCANA, dated April 27, 1995 (Filed
                    as Exhibit 4-B to Registration Statement No. 33-62421)

3.04          X     Articles of Amendment of SCE&G, dated June 7, 1994 filed
                    June 9, 1994  (Filed as Exhibit 3.02 to Registration
                    Statement No. 333-86387)

3.05          X     Articles of Amendment of SCE&G, dated November 9, 1994(Filed
                    as Exhibit 3.03 to Registration Statement No. 333-86387)

3.06          X     Articles of Amendment of SCE&G, dated December 9, 1994
                    (Filed as Exhibit 3.04 to Registration Statement No.
                    333-86387)

3.07          X     Articles of Correction of SCE&G, dated January 17, 1995
                    (Filed as Exhibit 3.05 to Registration Statement No.
                    333-86387)

3.08          X     Articles of Amendment of SCE&G, dated January  13, 1995 and
                    filed January 17, 1995 (Filed as Exhibit 3.06 to
                    Registration Statement No. 333-86387)

3.09          X     Articles of Amendment of SCE&G, dated March 30, 1995
                    (Filed as Exhibit 3.07 to Registration Statement No.
                    333-86387)

3.10          X     Articles of Correction of SCE&G - Amendment to Statement
                    filed March 31, 1995, dated December 13, 1995 (Filed as
                    Exhibit 3.08 to Registration Statement No. 333-86387)

3.11          X     Articles of Amendment of SCE&G, dated December 13, 1995
                    (Filed as Exhibit 3.09 to Registration Statement No.
                    333-86387)

3.12          X     Articles of Amendment of SCE&G, dated February 18, 1997
                    (Filed as Exhibit 3-L to Registration Statement No.
                    333-24919)

3.13          X     Articles of Amendment of SCE&G, dated February 21, 1997
                    (Filed as Exhibit 3.11 to Registration Statement No.
                    333-86387)

3.14          X     Articles of Amendment of SCE&G, dated April 22, 1997 (Filed
                    as Exhibit 3.12 to Registration Statement No. 333-86387)



<PAGE>



        Applicable to
Exhibit   Form 10-Q of
No.   SCANA   SCE&G  Description

3.15           X      Articles of Amendment of SCE&G, dated April 9, 1998 (Filed
                      as Exhibit 3.13 to Registration Statement No. 333-86387)

3.16           X      Articles of Amendment of SCE&G, dated May 19, 1999 (Filed
                      as Exhibit 3.16 to Form 10-K for the year ended December
                      31, 1999)

3.17           X      Articles of Amendment of SCE&G, dated August 13, 1999
                      (Filed as Exhibit 3.17 to Form 10-K for the year ended
                      December 31, 1999)

3.18           X      Articles of Amendment of SCE&G, dated March 1, 2000 (Filed
                      as Exhibit 3.18 to Form 10-K for the year ended December
                      31, 1999)

3.19     X            By-Laws of SCANA as revised and amended on February 22,
                      2000 (Filed as Exhibit 3.19 to Form 10-K for the year
                      ended December 31, 1999)

3.20           X      By-Laws of SCE&G as amended and adopted on  February 22,
                      2000 (Filed as Exhibit 3.20 to Form 10-K for the year
                      ended December 31, 1999)

4.01          X       Articles of Exchange of South Carolina Electric and Gas
                      Company and SCANA Corporation (Filed as Exhibit 4-A to
                      Post-Effective Amendment No. 1 to Registration Statement
                      No. 2-90438)

4.02    X             Indenture dated as of November 1, 1989 between SCANA
                      Corporation and The Bank of New York, as Trustee (Filed as
                      Exhibit 4-A to Registration Statement No. 33-32107)

4.03    X      X      Indenture dated as of January 1, 1945, between the South
                      Carolina Power Company and Central Hanover Bank and Trust,
                      as Trustee, as supplemented by Supplemental Indentures
                      dated respectively as of May 1, 1946, May 1, 1947 and July
                      1, 1949 (Filed as Exhibit 2-B to Registration Statement
                      No. 2-26459)

4.04    X      X      Fourth Supplemental Indenture dated as of April 1, 1950,
                      to Indenture referred to in Exhibit 4.03, pursuant to
                      which SCE&G assumed said Indenture (Filed as Exhibit 2-C
                      to Registration Statement No. 2-26459)

4.05    X      X      Fifth through Fifty-third Supplemental Indenture referred
                      to in Exhibit 4.03 dated as of the dates indicated below
                      and filed as exhibits to the Registration Statements whose
                      file numbers are set forth below:

     December 1, 1950        Exhibit 2-D        to Registration No. 2-26459
     July 1, 1951            Exhibit 2-E        to Registration No. 2-26459
     June 1, 1953            Exhibit 2-F        to Registration No. 2-26459
     June 1, 1955            Exhibit 2-G        to Registration No. 2-26459
     November 1, 1957        Exhibit 2-H        to Registration No. 2-26459
     September 1, 1958       Exhibit 2-I        to Registration No. 2-26459
     September 1, 1960       Exhibit 2-J        to Registration No. 2-26459
     June 1, 1961            Exhibit 2-K        to Registration No. 2-26459
     December 1, 1965        Exhibit 2-L        to Registration No. 2-26459
     June 1, 1966            Exhibit 2-M        to Registration No. 2-26459
     June 1, 1967            Exhibit 2-N        to Registration No. 2-29693
     September 1, 1968       Exhibit 4-O        to Registration No. 2-31569
     June 1, 1969            Exhibit 4-C        to Registration No. 33-38580


<PAGE>





            Applicable to
Exhibit       Form 10-Q of
No.        SCANA   SCE&G  Description

     December 1, 1969       Exhibit 4-O        to Registration No. 2-35388
     June 1, 1970           Exhibit 4-R        to Registration No. 2-37363
     March 1, 1971          Exhibit 2-B-17     to Registration No. 2-40324
     January 1, 1972        Exhibit 2-B        to Registration No. 33-38580
     July 1, 1974           Exhibit 2-A-19     to Registration No. 2-51291
     May 1, 1975            Exhibit 4-C        to Registration No. 33-38580
     July 1, 1975           Exhibit 2-B-21     to Registration No. 2-53908
     February 1, 1976       Exhibit 2-B-22     to Registration No. 2-55304
     December 1, 1976       Exhibit 2-B-23     to Registration No. 2-57936
     March 1, 1977          Exhibit 2-B-24     to Registration No. 2-58662
     May 1, 1977            Exhibit 4-C        to Registration No. 33-38580
     February 1, 1978       Exhibit 4-C        to Registration No. 33-38580
     June 1, 1978           Exhibit 2-A-3      to Registration No. 2-61653
     April 1, 1979          Exhibit 4-C        to Registration No. 33-38580
     June 1, 1979           Exhibit 2-A-3      to Registration No. 33-38580
     April 1, 1980          Exhibit 4-C        to Registration No. 33-38580
     June 1, 1980           Exhibit 4-C        to Registration No. 33-38580
     December 1, 1980       Exhibit 4-C        to Registration No. 33-38580
     April 1, 1981          Exhibit 4-D        to Registration No. 33-49421
     June 1, 1981           Exhibit 4-D        to Registration No. 2-73321
     March 1, 1982          Exhibit 4-D        to Registration No. 33-49421
     April 15, 1982         Exhibit 4-D        to Registration No. 33-49421
     May 1, 1982            Exhibit 4-D        to Registration No. 33-49421
     December 1, 1984       Exhibit 4-D        to Registration No. 33-49421
     December 1, 1985       Exhibit 4-D        to Registration No. 33-49421
     June 1, 1986           Exhibit 4-D        to Registration No. 33-49421
     February 1, 1987       Exhibit 4-D        to Registration No. 33-49421
     September  1, 1987     Exhibit 4-D        to Registration No. 33-49421
     January 1, 1989        Exhibit 4-D        to Registration No. 33-49421
     January 1, 1991        Exhibit 4-D        to Registration No. 33-49421
     February 1, 1991       Exhibit 4-D        to Registration No. 33-49421
     July 15, 1991          Exhibit 4-D        to Registration No. 33-49421
     August 15, 1991        Exhibit 4-D        to Registration No. 33-49421
     April 1, 1993          Exhibit 4-E        to Registration No. 33-49421
     July 1, 1993           Exhibit 4-D        to Registration No. 33-57955
     May 1, 1999            Exhibit 4.04       to Registration No. 333-86387

4.06   X     X      Indenture dated as of April 1, 1993 from South Carolina
                    Electric & Gas Company to NationsBank of Georgia, National
                    Association (Filed as Exhibit 4-F to Registration
                    Statement No. 33-49421)

4.07   X     X      First Supplemental Indenture to Indenture  referred to in
                    Exhibit 4.07 dated as of June 1, 1993 (Filed as Exhibit 4-G
                    to Registration Statement No. 33-49421)

4.08   X     X      Second Supplemental Indenture to Indenture referred to in
                    Exhibit  4.07 dated as of June 15, 1993 (Filed as Exhibit
                    4-G to Registration Statement No. 33-57955)


<PAGE>





            Applicable to
Exhibit      Form 10-Q of
No.    SCANA   SCE&G  Description
4.09       X          X      Trust Agreement for SCE&G Trust I (Filed as
                             Exhibit 4-G to SCE&G Form 10-K for the year
                             ended December 31, 1997)

4.10       X          X      Certificate of Trust for SCE&G Trust I (Filed as
                             Exhibit 4-H to SCE&G Form 10-K for the
                             year ended December 31, 1997)

4.11       X          X      Junior Subordinated Indenture for SCE&G Trust I
                             (Filed as Exhibit 4-I to SCE&G Form 10-K
                             for the year ended December 31, 1997)

4.12       X          X      Guarantee Agreement for SCE&G Trust I (Filed as
                             Exhibit 4-J to SCE&G Form 10-K for the
                             year ended December 31, 1997)

4.13       X          X      Amended and Restated Trust Agreement for SCE&G
                             Trust I (Filed as Exhibit 4-K to SCE&G
                             Form 10-K for the year ended December 31, 1997)

10.01      X                 SCANA Voluntary Deferral Plan as amended through
                             October 21, 1997 (Filed as Exhibit
                             10.01(a) to Registration Statement No. 333-86803)

10.02      X          X      Supplemental Executive Retirement Plan (Filed as
                             Exhibit 10.01(b) to Registration
                             Statement No. 333-86803)

10.03      X                 SCANA Supplementary Voluntary Deferral Plan as
                             amended and restated through October 21,
                             1997 (Filed as Exhibit 10-B to SCANA Form 10-K
                             for the year ended  December 31, 1997)

10.04          X                 SCANA Key Executive Severance Benefits Plan as
                                 amended and restated effective as of
                                 October 21, 1997 (Filed as Exhibit 10.01(c) to
                                 Registration Statement No. 333-86803)

10.05                            X SCANA  Supplementary Key Executive  Severance
                                 Benefits Plan as amended and restated effective
                                 October 21, 1997 (Filed as Exhibit  10.01(d) to
                                 Registration Statement No.
                                 333-86803)

10.06          X                 SCANA Performance Share Plan as amended and
                                 restated effective January 1, 1998  (Filed as
                                 Exhibit 10.01(e) to Registration Statement No.
                                 333-86803)

10.07                            X SCANA Key Employee  Retention Plan as amended
                                 and  restated  effective as of October 21, 1997
                                 (Filed as  Exhibit  10-E to SCANA Form 10-K for
                                 the year ended December 31, 1997)

10.08          X                 Description of SCANA Whole Life Option (Filed
                                 as Exhibit 10-F to SCANA Form 10-K for the
                                 year ended December 31, 1991, under cover of
                                 Form SE, File No. 1-8809)

10.09                            X  Description  of  SCANA  Corporation   Annual
                                 Incentive  Plan (Filed as Exhibit 10-G to SCANA
                                 Form 10-K for the year ended December 31, 1991,
                                 under cover of Form SE, File No. 1-8809)

18.01          X                 Independent Auditor's Letter regarding change
                                 in accounting principles (Filed herewith on
                                 page 43)

18.02                     X      Independent Auditor's Letter regarding change
                                 in accounting principles (Filed herewith on
                                 page 44)

27.01          X                 Financial Data Schedule (Filed herewith)

27.02                     X      Financial Data Schedule (Filed herewith)