2016 eei financial conference presentation

1November 2016 1

SCANA Corporation| Investor Presentation

November 2016

2November 2016

Safe Harbor Statement/Regulation G InformationStatements included in this presentation which are not statements of historical fact are intended to be, and are hereby identified as, “forward-looking statements” for purposes of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities and Exchange Act of 1934, as amended. Forward-looking statements include, but are not limited to, statements concerning key earnings drivers, customer growth, environmental regulations and expenditures, leverage ratio, projections for pension fund contributions, financing activities, access to sources of capital, impacts of the adoption of new accounting rules and estimated construction and other expenditures. In some cases, forward-looking statements can be identified by terminology such as “may,” “will,” “could,” “should,” “expects,” “forecasts,” “plans,” “anticipates,” “believes,” “estimates,” “projects,” “predicts,” “potential” or “continue” or the negative of these terms or other similar terminology. 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) the information is of a preliminary nature and may be subject to further and/or continuing review and adjustment; (2) legislative and regulatory actions, particularly changes in electric and gas services, rate regulation, regulations governing electric grid reliability and pipeline integrity, environmental regulations, and actions affecting the construction of new nuclear units; (3) current and future litigation; (4) changes in the economy, especially in areas served by subsidiaries of SCANA; (5) the impact of competition from other energy suppliers, including competition from alternate fuels in industrial markets; (6) the impact of conservation and demand side management efforts and/or technological advances on customer usage; (7) the loss of sales to distributed generation, such as solar photovoltaic systems; (8) growth opportunities for SCANA’s regulated and other subsidiaries; (9) the results of short- and long-term financing efforts, including prospects for obtaining access to capital markets and other sources of liquidity; (10) the effects of weather, especially in areas where the generation and transmission facilities of SCANA and its subsidiaries (the Company) are located and in areas served by SCANA’s subsidiaries; (11) changes in SCANA’s or its subsidiaries’ accounting rules and accounting policies; (12) payment and performance by counterparties and customers as contracted and when due; (13) the results of efforts to license, site, construct and finance facilities for electric generation and transmission, including nuclear generating facilities; (14) the results of efforts to operate the Company’s electric and gas systems and assets in accordance with acceptable performance standards, including the impact of additional distributed generation and nuclear generation; (15) maintaining creditworthy joint owners for SCE&G’s new nuclear generation project; (16) the ability of suppliers, both domestic and international, to timely provide the labor, secure processes, components, parts, tools, equipment and other supplies needed, at agreed upon quality and prices, for our construction program, operations and maintenance; (17) the results of efforts to ensure the physical and cyber security of key assets and processes; (18) the availability of fuels such as coal, natural gas and enriched uranium used to produce electricity; the availability of purchased power and natural gas for distribution; the level and volatility of future market prices for such fuels and purchased power; and the ability to recover the costs for such fuels and purchased power; (19) the availability of skilled, licensed, and experienced human resources to properly manage, operate, and grow the Company’s businesses; (20) labor disputes; (21) performance of SCANA’s pension plan assets; (22) changes in tax laws and realization of tax benefits and credits, including production tax credits for new nuclear units; (23) inflation or deflation; (24) compliance with regulations; (25) natural disasters and man-made mishaps that directly affect our operations or the regulations governing them; and (26) the other risks and uncertainties described from time to time in the reports filed by SCANA or SCE&G with the Securities and Exchange Commission.SCANA and SCE&G disclaim any obligation to update any forward-looking statements.

During this presentation, certain non-GAAP measures (as defined by SEC Regulation G) may be disclosed. A reconciliation of those measures to the most directly comparable GAAP measures is included on our website at www.scana.com in the Investor Relations section under Webcasts & Presentations and attached as an appendix to this presentations.

3November 2016 33

STRATEGIC, REGULATED GROWTH PLAN Positive customer growth in service territories Constructive regulatory environment Strong economic improvement Excellent operational reliability and customer

satisfaction Transparent and strategic operations Investing in the communities we live in and serve New Nuclear Development project has a fixed price

contract

Delivering Strong Investor Value

CONTINUED STRONG FINANCIAL PROFILE Targeted earnings per share of 4-6%

~95% from regulated operations Dividend to grow in line with earnings

Dividend has increased ~45% since 2005 Increased dividend in 61 of last 65 years

Investment grade credit ratings Balanced approach to financing growth Beneficial investments to customers and investors Proven management team Distinctly strong employee/director ownership

Regulated Electric & Natural Gas Deregulated Natural Gas

Electric & Natural Gas

Natural Gas Only

4November 2016 4

| Key Slides

5November 2016 55

Impact of 174 Tax Deduction

• Regulatory Strategy:

• ORS Support Letter sent to SCPSC on October 28, 2016

• SCPSC approved Accounting Order on November 2, 2016

• Decrement Rider expected to keep SCE&G’s base electric ROE ~9.5%-9.75% including DSM net earnings

• Credit Ratings Support:Significant improvement in cash flow metrics

• Financing Strategy:

• No equity until 2018, plans likely supply needs

Rating Outlook

Moody’s Baa3 Stable

S&P BBB Stable

Fitch BBB- Stable

Rating Outlook

Moody’s A3 Stable

S&P A Stable

Fitch A- Stable

SCANA Medium Term Notes SCE&G First Mortgage Bonds

6November 2016 66

Total Depreciation Deduction

Note: Not to scale

Tax Depreciation Deductions

Remaining Cost Eligible for 15 Year MACRS Depreciation

Expenditures Eligible for 174

Deduction


Expenditures Eligible for 30% or 40% Bonus Depreciation

Total Expenditures Eligible for 15 Year MACRS Depreciation

Deduction


Total Depreciation Deduction with Bonus

Depreciation

Total Depreciation Deduction with Bonus Depreciation and

174 Deduction

15 Year MACRS Beginning At In-Service

Taken At In-Service Taken In Tax Year As Spent

7November 2016 77

2016E 2017E 2018E($ in Millions)

Debt

Refinancings:

SCANA $ - $ - $ 160

SCE&G - - 550

New Issues:

SCE&G 500 875 575

PSNC 100 150 100

Total Debt $ 600 $ 1,025 $ 1,385

Equity $ - $ - $ 125

Total Equity $ - $ - $ 125

Financing Plan Estimated

Note: Reflects the Fixed Price Option and the impact of the 174 tax credits.

= Complete

2016 2017 2018

Cash (Total = $1.1 billion) $350M $325M $425M

Section 174 Tax Deduction Projected Annual Cash Impact

8November 2016 88

Section 174 Impact

Generates Tax Savings (Cash)

Offsets potential debt and equity financings

Less Interest Expense and Dilution

Increases ADIT Liability

(not contemplated by

BLRA)Lowers Rate Base on

the Base Electric Business

Lowers Earnings

Neutral Impact to Earnings

Increases Earnings

Pushes Up ROE and Drives Decrement

Rider

Financial Path

Regulatory Path

174 Deduction

9November 2016 99

Order #2015-661 (Prior EPC)

Fixed Price Option

Guaranteed Substantial Completion Dates

Unit 2 - June 2019Unit 3 – June 2020

Unit 2 - August 2019Unit 3 – August 2020

Total Project Costs $6.827 Billion $7.674 Billion*

Liquidated Damages$155 million @ 100% $86 million – SCE&G

$676 million @ 100%$372 million – SCE&G

Bonuses Capacity Performance RelatedCompletion Based


Change in Law Language Generally defined

Explicitly defined – Formal written adoption of a new statute, regulation, requirement, or

code or new NRC regulatory requirement that did not exist as of this amendment

Design Control Document Revision 16 Revision 19

Settlement with Consortium (Amendment to EPC Contract)

* As listed in the Q3 2016 BLRA Quarterly Report which includes the impact of the ORS Settlement Agreement for the Fixed Price Option.

10November 2016 1010

PSNC Base Rate Increase

Docket Number G-5, Sub 565 Effective Date November 1, 2016

Test Period Data:

Test Period 12 Months Ended Dec. 31, 2015, As AdjustedRetail Natural Gas Rate Base $843 MillionReturn on Rate Base 7.84%

Approval in Final Order:

Total Annual Revenue Increase 19.1 Million, approximately 4.39%Retail Natural Gas Rate Base $947 Million Return on Rate Base 7.53%Return on Common Equity 9.70%

• Authority to implement an Integrity Management Rider. ~20% of our CAPEX over the next three years will be subject to recovery under this rider. ~50% of CAPEX over next three years is due to industrial contracts.

• Established regulatory accounting treatment for distribution integrity management O&M expenses.

11November 2016 11

12November 2016 12

| Shareholder Return


GAAP-Adjusted Earnings Guidance

2016 GAAP-Adjusted Weather Normalized Earnings Guidance

$4.00

$4.10

2016 Target

$3.90

Long-Term GAAP-Adjusted Weather-Normalized Average Annual Growth Rate

• Base year reset to 2015 GAAP-Adjusted Weather-Normalized EPS of $3.73.

• Long-Term GAAP-Adjusted Weather-Normalized Average Annual Growth Rate of 4% to 6% over the next 3 to 5 years.


GAAP-Adjusted Weather-Normalized Earnings per Share

Note: CGT and SCI were sold during the first quarter of 2015 for a net of tax gain on the sales of $1.41 per share.

Higher Other Electric Margin & Other Income

Lower Effective Tax Rate

Higher Depreciation

Higher O&M

Lower Gas Margin (Impact of Sale of CGT)

Higher Interest, net of AFUDC

Higher Other Taxes

$0.12 EPS variance

Year-To-Date September 30,

2016 2015 Change

SCE&G $ 2.76 $ 2.61 $ 0.15

PSNC 0.20 0.21 (0.01)

SCANA Energy 0.16 0.17 (0.01)

Corporate & Other (0.10) (0.09) (0.01)

GAAP EPS $ 3.02 $ 2.90 $ 0.12


Dividend GrowthDIVIDEND POLICY: To increase the annual cash dividend at a rate that reflects the earnings growth in the Company’s businesses,

while maintaining a payout ratio of 55-60%

• Paid dividend for 259 consecutive quarters

• Increased dividend in 61 out of the last 65 years

$1.90

$1.94

$1.98

$2.03

$2.10

$2.18

$2.30*

$1.80

$1.90

$2.00

$2.10

$2.20

$2.30

$2.40

2010 2011 2012 2013 2014 2015 2016

Common Dividends

63.5%64.5%

61.9%

59.7%58.7% 58.4%

50%

55%

60%

65%

70%

2010 2011 2012 2013 2014 2015

Payout Ratio

Policy

“We are within our stated payout policy of 55%-60% and expect to grow dividends fairly consistent with earnings growth prospectively.”

* 2016 indicated rate (1) GAAP-Adjusted Weather Normalized Dividend Payout Ratio

(1) (1)

5.5% Increase


9%

68%

23%

Insider Institutional Retail

9% Employee/Director Ownership

“It is like a stockholders meeting every day.” ~ Kevin Marsh, Chief Executive Officer

As of 9/30/2016

Investor Composition

17November 2016 17

| CAPEX & Financing


CAPEX Estimated

2016E 2017E 2018E TOTAL($ in Millions) SCE&G - NormalGeneration $ 88 $ 130 $ 91 $ 309Transmission & Distribution 192 163 187 542 Other 12 9 15 36 Gas 61 63 60 184 Common 3 2 4 9

Total SCE&G - Normal 356 367 357 1,080

PSNC Energy 198 279 212 689 Other 27 30 21 78 Total "Normal" 581 676 590 1,847

New Nuclear 901 1,381 970 3,252 Cash Requirements for Construction 1,482 2,057 1,560 5,099

Nuclear Fuel 122 80 89 291 Total Estimated Capital Expenditures $ 1,604 $ 2,137 $ 1,649 $ 5,390

($ in Millions) 2015 2016 2017E 2018E 2019E 2020E

Incremental New Nuclear CWIP as of 6/30

$547 $574 $1,507 $1,338 $727 $314

Note: Reflects new nuclear capex as estimated from the Q3 2016 BLRA Quarterly Filing

Note: Reflects new nuclear CWIP from July 1 through June 30 as anticipated to be filed


Impact of 174 Tax Deduction

• Regulatory Strategy:

• ORS Support Letter sent to SCPSC on October 28, 2016

• SCPSC approved Accounting Order on November 2, 2016

• Decrement Rider expected to keep SCE&G’s base electric ROE ~9.5%-9.75% including DSM net earnings

• Credit Ratings Support:Significant improvement in cash flow metrics

• Financing Strategy:

• No equity until 2018, plans likely supply needs

Rating Outlook

Moody’s Baa3 Stable

S&P BBB Stable

Fitch BBB- Stable

Rating Outlook

Moody’s A3 Stable

S&P A Stable

Fitch A- Stable

SCANA Medium Term Notes SCE&G First Mortgage Bonds


Total Depreciation Deduction

Note: Not to scale

Tax Depreciation Deductions


Expenditures Eligible for 174

Deduction



Total Expenditures Eligible for 15 Year MACRS Depreciation

Deduction


Total Depreciation Deduction with Bonus

Depreciation

Total Depreciation Deduction with Bonus Depreciation and

174 Deduction

15 Year MACRS Beginning At In-Service

Taken At In-Service Taken In Tax Year As Spent


2016E 2017E 2018E($ in Millions)

Debt

Refinancings:

SCANA $ - $ - $ 160

SCE&G - - 550

New Issues:

SCE&G 500 875 575

PSNC 100 150 100

Total Debt $ 600 $ 1,025 $ 1,385

Equity $ - $ - $ 125

Total Equity $ - $ - $ 125

Financing Plan Estimated

Note: Reflects the Fixed Price Option and the impact of the 174 tax credits.

= Complete

2016 2017 2018

Cash (Total = $1.1 billion) $350M $325M $425M

Section 174 Tax Deduction Projected Annual Cash Impact


Section 174 Impact

Generates Tax Savings (Cash)

Offsets potential debt and equity financings

Less Interest Expense and Dilution

Increases ADIT Liability

(not contemplated by

BLRA)Lowers Rate Base on

the Base Electric Business

Lowers Earnings

Neutral Impact to Earnings

Increases Earnings

Pushes Up ROE and Drives Decrement

Rider

Financial Path

Regulatory Path

174 Deduction

23November 2016 23

| Regulatory Update, Economy, Electric Sales, & IRP


Retail Rate Base, Returns, & Schedule

Regulatory Schedule for 2016

1/30: Demand Side Mgmt Filing 2/26: Integrated Resource Plan

4/7: Electric Fuel Cost Review 6/15: Gas RSA Filing

10/15: Gas RSA Order TBD: Purchased Gas Cost Review

CompanyRegulatory Earned ROE

Regulatory Allowed ROE

SCE&G Electric (Non NND) ~10.10% 10.25%

SCE&G Electric NND(2) 11.00% / 10.50% / 10.25%

SCE&G Gas(3) 9.03% 10.25%

PSNC(4) 8.28% 9.70%$4,922

$4,215

$553

$939

Rate Base (millions)(As of 9/30/2016)

SCE&G Electric (Non NND)

SCE&G Electric NND

SCE&G Gas

PSNC

(3)

(1)

NND = New Nuclear Development(1) Total project spend as of 9/30/2016. $3,788 million of CWIP related to the financing cost recovery

under the Annual Request for Revised Rates.(2) Financing cost in rates (11.00% for all Annual Requests for Revised Rates approved prior to 2016.

The 2016 request applies a 10.5% ROE. Should the SCPSC approve the ORS Settlement Agreement then the ROE will be revised to 10.25% for 2017 requests and beyond)

(3) Twelve months ended 6/30/2016(4) New Allowed ROE effective as of 11/1/2016. Amounts represent per book returns and rate base & may not

reflect NCUC’s determinations of rate base, capitalization and/or ROE

(4)

Twelve Months Ended 9/30/2016


PSNC Base Rate Increase

Docket Number G-5, Sub 565 Effective Date November 1, 2016

Test Period Data:

Test Period 12 Months Ended Dec. 31, 2015, As AdjustedRetail Natural Gas Rate Base $843 MillionReturn on Rate Base 7.84%

Approval in Final Order:

Total Annual Revenue Increase 19.1 Million, approximately 4.39%Retail Natural Gas Rate Base $947 Million Return on Rate Base 7.53%Return on Common Equity 9.70%

• Authority to implement an Integrity Management Rider. ~20% of our CAPEX over the next three years will be subject to recovery under this rider. ~50% of CAPEX over next three years is due to industrial contracts.

• Established regulatory accounting treatment for distribution integrity management O&M expenses.


Economic Trends

• Economic announcements in 2016:• SC Territory:

– Approximately $709 billion investment – Approximately 2,240 projected jobs

• NC Territory: – Approximately $533 million investment – Approximately 2,400 projected jobs

4.0%

5.0%

6.0%

7.0%

8.0%

9.0%

10.0%

11.0%

12.0%

13.0%

2008 2009 2010 2011 2012 2013 2014 2015 2016

National Georgia North Carolina South Carolina SCE&G Electric Territory*

September Unemployment Rates

* Data as of August 2016 for Charleston and Columbia metropolitan areas only; not seasonally adjusted

5.0% 5.1% 4.7% 4.9% 4.9%

27November 2016 2727Source: Von Nesson (research economist - University of South Carolina Darla Moore School of Business)

South Carolina State Ports Authority

Statewide impact of the ports authority:

• $53 billion in annual economic output (represents nearly 10% of the state’s annual gross state product)

• 187,000 jobs and $10.2 billion in compensation

• 1 in every 11 jobs in the state can be attributed directly or indirectly to the SC State Ports Authority

• Port operations produce more than $912 million in SC tax revenue annually


Domestic Migration

According to the United Van Lines’ 39th Annual National Movers Study:

• South Carolina ranked 2nd for the third straight year for domestic migration, with North Carolina finishing in the top 5 for the third straight year.

• Approximately 62% and 58% of migration to or from South Carolina and North Carolina respectively, were from inbound moves


1.6% 1.5% 1.5% 1.6% 1.5%

3.1%

2.7% 2.7%2.9% 2.9%2.8%

2.5% 2.5%

3.0%2.8%

0.0%

0.5%

1.0%

1.5%

2.0%

2.5%

3.0%

3.5%

Q3 2015 Q4 2015 Q1 2016 Q2 2016 Q3 2016

SCE&G Electric SCE&G Gas PSNC

Customer Growth

Customer Growth (Year over Year Change)

0.0%

0.5%

1.0%

1.5%

2.0%

2.5%

3.0%

3.5%

2008 2009 2010 2011 2012 2013 2014 2015 2016

SCE&G Electric SCE&G Gas PSNC

Historical Customer Growth (Year over Year Change)


Electric Sales

-3%

-2%

-1%

0%

1%

2%

3%

4%

2013 2014 2015 2016

Rolling 12 Month Weather Normalized Sales

Total Retail Residential

Kilowatt-Hour Sales(In Millions of KWH)

Twelve Months Ended September 30,

2016 2015 Change

Weather Adjusted

Change

Sales:

Residential 8,003 8,211 (2.5)% 0.3%

Commercial 7,493 7,449 0.6% 0.3%

Industrial 6,235 6,298 (1.0)% (1.3)%

Other 599 598 0.1% (0.4)%

Total Retail Sales 22,330 22,556 (1.0)% (0.1)%


Electric Sales Forecast

Average per year over next 15 years

Baseline Sales 1.6%

Energy Efficiency/DSM (0.3)%

Net Territorial Sales 1.3%

Source: 2016 Integrated Resource Plan

2016 Integrated Resource Plan

• Filed annually with the South Carolina Public Service Commission

• 2016 IRP filed February 26, 2016

• Outlines the plan to retire and/or re-tool six coal-fired units

• Retired Canadys Units 1, 2, and 3

• Converted Urquhart Unit 3 to be fired with natural gas and dismantled coal handling facilities at this unit

• Capacity (250 MWs) of the remaining two coal-fired units, McMeekin Units 1 and 2, is required to maintain system reliability until the new nuclear capacity is available. Under MATS, these units cannot run on coal after April 15, 2016 so they will be fired with natural gas and any additional capacity needs will be purchased.


Solar Farm Projects

Charleston, SC

November 2016

• As a part of Distributed Energy Resource (DER) Program and in response to SCE&G customer and other South Carolina stakeholders, SCE&G plans to add approximately 100 MWs of additional renewable energy to its system by 2021.

• Solar Projects:• Charleston, SC – 500 KW facility (Completed)• 16.5 MW of customer scale solar interconnected; an additional 14MW approved.• 16 MW of community solar is being developed.

32


2007 2015 2020 2021

Coal 65% 39% 26% 20%

Gas 12% 36% 22% 18%

Nuclear 18% 20% 45% 55%

Hydro 5% 4% 3% 3%

Alt. Resources 0% 1% 4% 4%

0%

10%

20%

30%

40%

50%

60%

70%

80%

90%

100%By Dispatch

Coal

Gas

Nuclear

Hydro

Alt. Resources

Generation Mix by Dispatch and Capacity

Non-emitting

62%

Balanced Portfolio

2007 2015 2020 2021

Coal 45% 33% 29% 26%

Gas 30% 38% 34% 30%

Nuclear 11% 13% 21% 29%

Hydro 14% 15% 13% 12%

Alt. Resources 0% 1% 3% 3%

0%

10%

20%

30%

40%

50%

60%

70%

80%

90%

100%By Capacity


SCE&G CO2 Emissions

Note: Reflects emissions as filed February 2016 in the 2016 Integrated Resource Plan.

7

9

11

13

15

17

19

21

2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022

M T

on

s

Actual Projected 2005 Actual 32% below 2005

If the Clean Power Plan is implemented, the EPA anticipates that CO2 emissions will be 32% below 2005 levels by the year 2030. The following chart shows that SCE&G’s CO2 emissions will fall well below the “32% below 2005”

emission level after new nuclear begins generating.

35November 2016 35

| BLRA & Nuclear Costs


ORS Settlement Agreement for 2016 Petition Filing

• Petition filed May 26, 2016 with the Public Service Commission of South Carolina electing the Fixed Price Option.

• Settlement Agreement reached on September 21, 2016 with (5 of 9 interveners) the South Carolina Office of Regulatory Staff, the Central Electric Power Cooperative, Inc., the Electric Cooperatives of South Carolina, Inc., Frank Knapp, Jr., and the South Carolina Energy Users Committee.

• New In Service Dates:- Unit 2: August 31, 2019- Unit 3: August 31, 2020

• $831 million increase in Project Costs over the Base Project costs ($6.827 billion) last approved by the SCPSC in Order #2015-661 for Total Project Costs agreed to in Settlement of $7.658 billion.

• Prospectively apply a 10.25% ROE to revised rates filings beginning January 1, 2017.

• SCE&G agreed not to file any future amendments to capital costs until January 28, 2019.


SCPSC Petition Filing Process

Update Petition

6 months

TestimonyFile PetitionPotential

Settlement Hearing Order

Petition Dates:• SCE&G Testimony July 1, 2016• ORS Testimony/Settlement Agreement September 1, 2016• Hearing held October 4, 2016 and October 12 – 13, 2016 (split dates due to Hurricane Matthew)• Decision by November 28, 2016

May 26 Nov 28(at latest)


Order #2015-661 (Prior EPC)

Fixed Price Option

Guaranteed Substantial Completion Dates

Unit 2 - June 2019Unit 3 – June 2020

Unit 2 - August 2019Unit 3 – August 2020

Total Project Costs $6.827 Billion $7.674 Billion*

Liquidated Damages$155 million @ 100% $86 million – SCE&G


Bonuses Capacity Performance RelatedCompletion Based


Change in Law Language Generally defined

Explicitly defined – Formal written adoption of a new statute, regulation, requirement, or

code or new NRC regulatory requirement that did not exist as of this amendment

Design Control Document Revision 16 Revision 19

Settlement with Consortium (Amendment to EPC Contract)

* As listed in the Q3 2016 BLRA Quarterly Report which includes the impact of the ORS Settlement Agreement for the Fixed Price Option.


$5.247

$1.300

$0.280

Order #2015-661 Current Status

Base Cost in 2007 $’s

Expected Inflation during Construction

Interest

$6.827

New Nuclear Projected Costs (in billions)

$6.805

$0.529

$0.340

$7.674

Q3 2016 BLRA (includes ORS Settlement)

* As filed in the September ORS Settlement Agreement in relation to the Petition filing for the Fixed Price Option


BLRA Filings & Rate Increases

$7.8

$22.5

$47.3 $52.8 $52.1

$67.2 $66.2 $64.5 $64.4

$-

$10

$20

$30

$40

$50

$60

$70

$80

April 2009 Nov 2009 Nov 2010 Nov 2011 Nov 2012 Nov 2013 Nov 2014 Nov 2015 Nov 2016

BLRA Increases to Rates (Millions)

0.4%

1.1%

2.3%2.4% 2.3%

2/12 – Q4 2014 Status

Report

5/13 – Q1 2015 Status

Report

5/30 – BLRA Revised Rate Application

8/14 – Q2 2015 Status

Report

11/4 – Q3 2015 Status

Report

2016 BLRA Filings

Completed

• 9 Consecutive BLRA Increases approved • Recover financing costs on construction work in progress annually

Approved by PSC at 11.0% ROE

2.9% 2.8%

Note: BLRA Filings are posted in the Investor Relations New Nuclear Section of SCANA’s website

2.6% 2.7%

Approved by PSC at 10.5% ROE


Incremental New Nuclear Acquisition

• Purchase to be funded in part by increased cash flows resulting from the depreciation associated with the commercial operation of Units 2 and 3

• No change under the Base Load Review Act mechanism

• Incremental ownership added to rate base over three years

TimingIncremental Percentage

Unit 2 & 3Ownership

MWs*

Commercial Operation Date of First New

Nuclear Unit+1% 56% +22 MWs

1st Anniversary of Commercial Operation

Date+2% 58% +44 MWs

2nd Anniversary of Commercial Operation

Date+2% 60% +44MWs

Total +5% 60% +110 MWs

* One-half of MWs are not available until Commercial Operation Date of Unit 3

42November 2016 42

| New Nuclear Construction


NND Site Aerial View

Turbine Building

Nuclear Island

HLD

MAB

Unit 2

Unit 3

Nuclear Island

Transformer Pads

Turbine Building

Cooling Towers

Containment Vessel Rings

43November 2016


~3,800 Workers Currently On Site

44November 2016


CA Modules

45November 2016


CA Modules

Fourth Quarter 2014 | Earnings Conference Call

CA04

46


Shield Building / Containment Vessel

Shield Building

Containment Vessel

Structural Modules

Annular Space

48November 2016 48

CA01

CA04 & Reactor Vessel

CA05

Containment Vessel Ring 1

CA20

Shield Building

CA03

CA02

48

Unit 2 Nuclear Island

November 2016



49November 2016

50November 2016 505052

Unit 2 CA01

November 2016


Unit 2 CA02

51November 2016


Unit 2 CA03

52November 2016


Unit 2 CA-04

53November 2016


Unit 2 CA-05

54November 2016

55November 2016 55

Unit 2 Reactor Vessel

55November 2016



56November 2016


Unit 3 CA20

57November 2016


Unit 3 CA04

58November 2016


Unit 3 CA01

59November 2016


Unit 3 CA02

60


Unit 3 Ring 1

61

62November 2016 62

Unit 2 Turbine Island/Deaereator Set

62November 2016


Unit 3 Turbine Building

Upper Condensers

Lower Condensers

63November 2016


Update

Unit 2 Shield Building Panels


Unit 2 Shield Building Assembly

65November 2016


2nd Course

1st Course

3rd Course

Unit 2 Shield Building

66November 2016

67November 2016 67

Unit 2 Stator

67November 2016


Unit 2 Main Transformers

68November 2016


First Unit 3 CA-01 Sub-Module from Japan Shipped

69November 2016


Unit 3 Reactor Vessel

70November 2016


Unit 2 Steam Generator

71November 2016


Unit 3 Pressurizer

72November 2016

73November 2016 737373

Unit 2 Reactor

Vessel

Unit 2 Diesel

GeneratorsUnit 2 Moisture

Separator Reheater

Unit 2 Auxiliary

Transformers

Other Components on Site

73November 2016

74November 2016 747474SCANA | Investor Presentation | 74SCANA | Rating Agency Update |

VC Summer 2 & 3 – Suppliers

74November 2016

75November 2016 75

Delivering Strong Investor Value 1 Settlement with Consortium 38

Key Slides 5-10 New Nuclear Project Costs 39

GAAP-Adjusted Earnings Guidance 13 BLRA Filings & Rate Increases 40

GAAP-Adjusted Weather-Normalized EPS 14 Incremental New Nuclear Acquisition 41

Dividend Growth 15 NND Aerial View Photos 43-44

Investor Composition 16 CA Modules 45-47

CAPEX Estimated 18 Unit 2 Nuclear Island & CA Modules Photos 48-55

Section 174 Deduction 19-21 Unit 3 Nuclear Island & CA Modules Photos 56-61

Financing Plan Estimated 22 Unit 2 Nuclear Island & CA Modules Photos 47-54

Retail Rate Base, Returns, & Schedule 24 Unit 3 Nuclear Island & CA Modules Photos 55-60

PSNC Base Rate Increase 25 Photos of Turbine Buildings 61-63

Economic Trends 26-28 Photos of Shield Building Panels 64-66

Customer Growth 29 Photos of Various Component Placings 67-68

Electric Sales 30 Pictures of Components Arriving on Site 69-73

2016 Integrated Resource Plan 31 VC Summer 2 & 3 Suppliers 74

Solar Farm Projects 32 Appendix Slides 77-81

Generation Mix by Dispatch & Capacity 33

SCE&G CO2 Emissions 34

ORS Settlement Agreement 36

SCPSC Petition Filing Process 37

Directory

76November 2016 76

Appendix



The table below calculates GAAP-Adjusted Weather-Normalized EPS By Company for the Quarter period:

Earnings Per Share By Company:

(Unaudited) Quarter Ended September 30,

2016 2015

SCE&G(1) PSNC

Energy

SCANA

Energy(1)

Corporate

and

Others

Total SCE&G(1) PSNC

Energy

SCANA

Energy(1)

Corporate

and

Others

Total

GAAP EPS $1.43 $(0.05) $(0.01) $(0.05) $1.32 $1.17 $(0.04) $(0.03) $(0.06) $1.04

Abnormal weather

on electric margins

(pre-tax)

(0.40) - - - (0.40) (0.17) - - - (0.17)

Less tax effect 0.13 - - - 0.13 0.06 - - - 0.06

GAAP-Adjusted,

Weather-

Normalized EPS

$1.16 $(0.05) $(0.01) $(0.05) $1.05 $1.06 $(0.04) $(0.03) $(0.06) $0.93

Note (1): SC Electric & Gas’ earnings are adjusted in determining the GAAP-Adjusted Weather-Normalized EPS measurement to exclude the impact of abnormal weather in its electric business. SCANA Energy’s earnings are not adjusted in determining the GAAP-Adjusted Weather-Normalized EPS measurement as the impact of abnormal weather is generally insignificant on an annual basis.



The table below calculates GAAP-Adjusted Weather-Normalized EPS By Company for the Year-to-Date period:

Note (1): SC Electric & Gas’ earnings are adjusted in determining the GAAP-Adjusted Weather-Normalized EPS measurement to exclude the impact of abnormal weather in its electric business. SCANA Energy’s earnings are not adjusted in determining the GAAP-Adjusted Weather-Normalized EPS measurement as the impact of abnormal weather is generally insignificant on an annual basis.

Note (2): Carolina Gas Transmission and SCANA Communications Inc. were sold during the first quarter of 2015.

Earnings Per Share By Company:

(Unaudited) Nine Months Ended September 30,

2016 2015

SCE&G(1) PSNC

Energy

SCANA

Energy(1)

Corporate

and

Others(2)

Total SCE&G(1) PSNC

Energy

SCANA

Energy(1)

Corporate

and

Others(2)

Total

GAAP EPS $3.03 $0.20 $0.16 $(0.10) $3.29 $2.83 $0.21 $0.17 $1.32 $4.53

Abnormal weather

on electric margins

(pre-tax)

(0.40) - - - (0.40) (0.33) - - - (0.33)

Less tax effect 0.13 - - - 0.13 0.11 - - - 0.11

Remove gains on

sales of CGT and

SCI (pre-tax)

- - - - - - - - (2.39) (2.39)

Less tax effect - - - - - - - - 0.98 0.98

GAAP-Adjusted,

Weather-

Normalized EPS

$2.76 $0.20 $0.16 $(0.10) $3.02 $2.61 $0.21 $0.17 $(0.09) $2.90


Long-Term Growth Rate - Reconciliation to GAAP

In addition to the guidance information provided on slide 12 of this presentation, which is provided using a GAAP-Adjusted Weather Normalized basis, the following information is provided in accordance with SEC Regulation G. Based on 2015 GAAP earnings per share of $5.22, the Company’s targeted average annual earnings per share growth rate is negative 6 to 0 percent over the next 3 to 5 years due to the

impact of the gains on the sales of the subsidiaries and incremental electric margins due to favorable weather in 2015.


2015 GAAP-Adjusted Weather-Normalized Earnings per Share

The table below calculates SCANA’s GAAP-Adjusted Weather-Normalized EPS for the period:

Year Ended December 31,

2015 2014

GAAP EPS $ 5.22 $ 3.79

SCE&G: Electric - weather (0.08) (0.21)

Corporate & Other: Gains on the sales of subsidiaries, net of tax

(1.41) -

GAAP-Adjusted Weather-Normalized EPS $ 3.73 $ 3.58

Note: Carolina Gas Transmission and SCANA Communications Inc. were sold during the first quarter of 2015.


GAAP-Adjusted Dividend Payout Ratio

2010(1) 2011(1) 2012(1) 2013(1) 2014(2) 2015(2)

GAAP Dividend Payout Ratio 63.5% 64.5% 61.9% 59.7% 56.8% 41.8%

GAAP-Adjusted Dividend Payout Ratio 63.5% 64.5% 61.9% 59.7% 58.7% 58.4%

(1) – No GAAP adjustments for 2010 through 2013. No weather adjustment due to the pilot eWNA program.(2) – Calculation uses GAAP-Adjusted Weather-Normalized EPS for calculation

82November 2016 82

2016 eei financial conference presentation

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