April 23, 2015 - AEP.com€¦ · First Quarter 2015 Highlights First Quarter Company Update Refer...
Transcript of April 23, 2015 - AEP.com€¦ · First Quarter 2015 Highlights First Quarter Company Update Refer...
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1st Quarter 2015 Earnings Release Presentation
April 23, 2015
“Safe Harbor” Statement under the Private Securities Litigation Reform Act of 1995
This presentation contains forward-looking statements within the meaning of Section 21E of the Securities Exchange Act of 1934. Although AEP and each of its
Registrant Subsidiaries believe that their expectations are based on reasonable assumptions, any such statements may be influenced by factors that could cause actual
outcomes and results to be materially different from those projected. Among the factors that could cause actual results to differ materially from those in the forward-
looking statements are: the economic climate, growth or contraction within and changes in market demand and demographic patterns in our service territory, inflationary
or deflationary interest rate trends, volatility in the financial markets, particularly developments affecting the availability of capital on reasonable terms and developments
impairing our ability to finance new capital projects and refinance existing debt at attractive rates, the availability and cost of funds to finance working capital and capital
needs, particularly during periods when the time lag between incurring costs and recovery is long and the costs are material, electric load, customer growth and the
impact of retail competition, weather conditions, including storms and drought conditions, and our ability to recover significant storm restoration costs, available sources
and costs of, and transportation for, fuels and the creditworthiness and performance of fuel suppliers and transporters, availability of necessary generation capacity and
the performance of our generation plants, our ability to recover increases in fuel and other energy costs through regulated or competitive electric rates, our ability to build
or acquire generation capacity and transmission lines and facilities (including our ability to obtain any necessary regulatory approvals and permits) when needed at
acceptable prices and terms and to recover those costs, new legislation, litigation and government regulation, including oversight of nuclear generation, energy
commodity trading and new or heightened requirements for reduced emissions of sulfur, nitrogen, mercury, carbon, soot or particulate matter and other substances or
additional regulation of fly ash and similar combustion products that could impact the continued operation, cost recovery and/or profitability of our generation plants and
related assets, evolving public perception of the risks associated with fuels used before, during and after the generation of electricity, including nuclear fuel, a reduction in
the federal statutory tax rate could result in an accelerated return of deferred federal income taxes to customers, timing and resolution of pending and future rate cases,
negotiations and other regulatory decisions including rate or other recovery of new investments in generation, distribution and transmission service and environmental
compliance, resolution of litigation, our ability to constrain operation and maintenance costs, our ability to develop and execute a strategy based on a view regarding
prices of electricity and other energy-related commodities, prices and demand for power that we generate and sell at wholesale, changes in technology, particularly with
respect to new, developing, alternative or distributed sources of generation, our ability to recover through rates or market prices any remaining unrecovered investment in
generation units that may be retired before the end of their previously projected useful lives, volatility and changes in markets for capacity and electricity, coal, and other
energy-related commodities, particularly changes in the price of natural gas, changes in utility regulation and the allocation of costs within regional transmission
organizations, including ERCOT, PJM and SPP, the transition to market for generation in Ohio, including the implementation of ESPs, our ability to successfully and
profitably manage our separate competitive generation assets, changes in the creditworthiness of the counterparties with whom we have contractual arrangements,
including participants in the energy trading market, actions of rating agencies, including changes in the ratings of our debt, the impact of volatility in the capital markets on
the value of the investments held by our pension, other postretirement benefit plans, captive insurance entity and nuclear decommissioning trust and the impact of such
volatility on future funding requirements, accounting pronouncements periodically issued by accounting standard-setting bodies and other risks and unforeseen events,
including wars, the effects of terrorism (including increased security costs), embargoes, cyber security threats and other catastrophic events.
Investor
Relations
Contacts
Bette Jo Rozsa Managing Director Investor Relations
614-716-2840 [email protected]
Ryan Mills Analyst
Investor Relations 614-716-2831
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First Quarter 2015 Highlights
First Quarter Company Update
Refer to appendix for reconciliation between GAAP and Operating EPS
Earnings Update
Delivered GAAP earnings of $1.29 per share
Delivered operating earnings of $1.28 per share
Reaffirm guidance range of $3.40-$3.60
Reaffirm 4%-6% growth rate
Regulatory Update
AEP Ohio – PPA
PJM – Capacity Reform
West Virginia & Kentucky rate cases update
Clean Power Plan
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* operating adjusts GAAP results by eliminating any material non operating items and is not weather normalized
Regulated Returns Twelve Months Ended 03/31/2015 Earned ROEs (Operating Earnings*)
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First Quarter Operating Earnings Per Share Overview
See slide 14 for items excluded from GAAP Net Income to reconcile to Operating Earnings
First Quarter Results Driven By Performance of Regulated & Competitive Businesses
Weighted average no. of shares outstanding: 488M 1Q-14; 490M 1Q-15
Segment 1Q-14
EPS 1Q-15
EPS
Vertically Integrated Utilities $0.57 $0.61
Transmission & Distribution Utilities 0.20 0.20
AEP Transmission Holdco 0.05 0.07
Generation & Marketing 0.33 0.38
AEP River Operations 0.01 0.02
Corporate & Other (0.01) 0.00
EPS from Operating Earnings $1.15 $1.28
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1st Quarter 2015 vs. Prior Year By Segment
Refer to appendix for additional explanation of variances by segment
$0.02 ($0.07)
$0.06
$0.03
$0.03
2015 Actual EPS $0.61 $0.20 $0.07 $0.38 $0.02 $0.00
$1.15/sh 0.04 0.00 0.02
0.05 0.01 $1.28/sh 0.01
$0.00
$0.25
$0.50
$0.75
$1.00
$1.25
$1.50
VerticallyIntegrated
Utilities
Transmission &Distribution
Utilities
AEP TransmissionHoldco
Generation andMarketing
AEP RiverOperations
Corporate andOther
2014 Actual
2015 Actual
Rate Changes 0.04$
Reg Prov - Va 0.03$
O&M 0.03$
OSS (0.09)$
PJM Chrgs 0.04$
Normal Load (0.04)$
Other 0.03$
Rate Changes 0.01$
Normal Load 0.01$
O&M (0.01)$
Other (0.01)$
AGR 0.01$
Trading & Mrkt 0.04$
Oklaunion PPA (0.01)$
Other 0.01$
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Normalized Load Trends
Note: Charts reflect connected load and exclude firm wholesale load & Buckeye Power backup load.
4.4%
-1.5% -1.1%
2.1%
-4.0%
0.2%
-5%
0%
5%
Q1-14 Q2-14 Q3-14 Q4-14 Q1-15 2015E
AEP Residential Normalized GWh Sales % Change vs. Prior Year
2.9%
0.4% 0.2%
3.5%
-0.4% -0.4%
-5%
0%
5%
Q1-14 Q2-14 Q3-14 Q4-14 Q1-15 2015E
AEP Commercial Normalized GWh Sales % Change vs. Prior Year
-2.9% -0.5%
1.2%
3.7%
1.2%
2.0%
-5%
0%
5%
Q1-14 Q2-14 Q3-14 Q4-14 Q1-15 2015E
AEP Industrial GWh Sales % Change vs. Prior Year
1.5%
-0.5%
0.1%
3.0%
-1.3%
0.6%
-5%
0%
5%
Q1-14 Q2-14 Q3-14 Q4-14 Q1-15 2015E
AEP Total Normalized GWh Sales % Change vs. Prior Year
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Economic Data
1.9%
2.6% 2.7% 2.4%
3.3%
2.2% 2.2% 2.2% 2.2% 2.1%
0%
1%
2%
3%
4%
Q1-14 Q2-14 Q3-14 Q4-14 Q1-15
Gro
wth
vs
Pri
or
Ye
ar
GDP Growth by Quarter
US AEP
0%
1%
2%
3%
4%
Q1-14 Q2-14 Q3-14 Q4-14 Q1-15
Gro
wth
vs
Pri
or
Ye
ar
GDP Growth by Geography
US AEP-East AEP-West
1.7% 1.9%
2.0% 2.1% 2.3%
1.2% 1.3%
1.5% 1.6%
1.7%
0%
1%
2%
3%
Q1-14 Q2-14 Q3-14 Q4-14 Q1-15
Gro
wth
vs
Pri
or
Ye
ar
Employment Growth by Quarter
US AEP
0%
1%
2%
3%
Q1-14 Q2-14 Q3-14 Q4-14 Q1-15
Gro
wth
vs
Pri
or
Ye
ar
Employment Growth by Geography
US AEP-East AEP-West
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AEP Shale Play Counties
Industrial Class Data
AEP Shale Gas Counties
Shale counties in AEP service territory Non-Shale counties in AEP service territory
Shale gas development drives industrial load growth
4% 9%
17%
28% 30%
39%
28%
23%
14%
-5.3% -3.5% -3.8%
-0.7% -1.7% -1.6%
1.1%
-0.7% -0.6%
$112
$103 $110 $109 $108 $110
$102
$76
$54
$-
$20
$40
$60
$80
$100
$120
-10%
0%
10%
20%
30%
40%
50%
Q1-13 Q2-13 Q3-13 Q4-13 Q1-14 Q2-14 Q3-14 Q4-14 Q1-15
Bre
nt O
il Price
($/b
arrel) G
Wh
Gro
wth
vs
Pri
or
Ye
ar
*Excluding Ormet
AEP Industrial Sales Growth
Shale Counties
Non-ShaleCountiesOil Price
-20%
-10%
0%
10%
20%
30%
40%
50%
60%
70%
Q1-14 Q2-14 Q3-14 Q4-14 Q1-15
GW
h G
row
th v
s P
rio
r Y
ear
Industrial Sales Growth in Shale Regions Eagle Ford (TX) Marcellus (WV)
Permian (TX) Utica (OH)
Woodford (OK)
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Oil & Gas Sector Growth
$-
$20
$40
$60
$80
$100
$120
$140
-
500
1,000
1,500
2,000
2,500
3,000
3,500
Q1-13 Q2-13 Q3-13 Q4-13 Q1-14 Q2-14 Q3-14 Q4-14 Q1-15
Bre
nt O
il Price
($/B
arrel)
GW
h
AEP Industrial Sales to Oil & Gas Sectors
Oil & Gas Extraction
Pipeline Transportation
Petroleum & Coal Products
Oil Price
5.0%
-3.4%
1.2% 0.2%
-0.1%
23% 30% 33%
61%
44%
3%
10% 11% 11% 11%
-10%
0%
10%
20%
30%
40%
50%
60%
70%
Q1-14 Q2-14 Q3-14 Q4-14 Q1-15
GW
h G
row
th v
s P
rio
r Y
ear
Growth in AEP Industrial Sales to Oil & Gas Sectors
Petroleum & Coal Products
Pipeline Transportation
Oil & Gas Extraction
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(unaudited) 3/31/2015 Actual
($ in millions) Amount Maturity
Revolving Credit Facility $1,750 Jul-18
Revolving Credit Facility $1,750 Jun-17
Total Credit Facilities $3,500
Plus
Cash & Cash Equivalents $190
Less
Commercial Paper Outstanding (115)
Letters of Credit Issued (75)
Net Available Liquidity $3,500
Actual Target
FFO Interest Coverage 5.62x >3.6x
FFO to Total Debt 22.2% 15%-20%
Capitalization & Liquidity
Liquidity Summary
Credit Statistics
Note: Credit statistics represent the trailing 12 months as of 03/31/2015
Total Debt / Total Capitalization
Strong balance sheet, credit metrics, and liquidity
Qualified Pension Funding
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Summary
Strong start to 2015 for our customers, shareholders and employees
Reaffirming 4%-6% growth rate
Reaffirming 2015 Operating Earnings Guidance of $3.40 to $3.60/share
Executing on our commitments including O&M discipline & capital allocation
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Appendix
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1st Quarter Reconciliation of GAAP to Operating Earnings
$ millions Earnings Per Share
1Q-14 1Q-15 Change 1Q-14 1Q-15 Change
Reported (GAAP) Earnings $560 $629 $69 $1.15 $1.29 $0.14
Non Operating Items:
Mark-to-Market Impact of Commodity Hedging Activities
- (4) (4) - (0.01) (0.01)
AEP Operating Earnings $560 $625 $65 $1.15 $1.28 $0.13
Weighted average no. of shares outstanding: 488M 1Q-14; 490M 1Q-15
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Vertically Integrated Utilities
1Q-14 1Q-15
$ millions (except EPS)
Operating Revenues $2,586 $2,505
Operating Expenses:
Energy Costs (1,094) (983)
Operations & Maintenance (576) (576)
Depreciation & Amortization (263) (272)
Taxes Other Than Income Taxes (96) (97)
Operating Income 557 577
Net Interest/AFUDC (122) (114)
Income Taxes (157) (164)
Operating & GAAP Earnings $278 $299
EPS from Operating Earnings $0.57 $0.61
First Quarter Summary Key Drivers: 1Q-15 vs. 1Q-14
Rate changes: $30M from various jurisdictions
$23M VA Regulatory provision reversal
Weather: $4M unfavorable vs. prior year; $62M favorable vs. normal
Off-System Sales: $71M unfavorable vs. prior year due
to significantly lower market prices in both PJM & SPP
Retail load: $27M unfavorable vs. prior year due to decreased residential sales and unfavorable price variances
O&M net of offsets: $24M favorable vs. prior year primarily due to employee, environmental remediation, and storm related expenses
PJM Charges: $31M favorable vs. prior year primarily due to decreases in unrecovered PJM charges
Income Taxes: effective tax rate of 35.3% 1Q15 vs. 36.0% 1Q14
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Transmission & Distribution Utilities
1Q-14 1Q-15
$ millions (except EPS)
Operating Revenues $1,215 $1,270
Operating Expenses:
Energy Costs (434) (452)
Operations & Maintenance (293) (319)
Depreciation & Amortization (161) (168)
Taxes Other Than Income Taxes (119) (122)
Operating Income 208 209
Net Interest/AFUDC (57) (58)
Income Taxes (54) (54)
Operating & GAAP Earnings $97 $97
EPS from Operating Earnings $0.20 $0.20
First Quarter Summary Key Drivers: 1Q-15 vs. 1Q-14
Rate changes: $8M from Ohio DIR Weather: $2M favorable vs. prior year; $7M
favorable vs. normal
Retail Load: $8M favorable, primarily due to OPCO’s change in seasonal rates
O&M net of offsets: $4M unfavorable vs. prior year primarily due to a donation to the Ohio Growth Fund which was partially offset by lower storm expense
Income Taxes: effective tax rate of 35.7% 1Q15 vs. 35.6% 1Q15
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AEP Transmission Holdco
1Q-14 1Q-15
$ millions (except EPS)
Operating Revenues $28 $58
Operating Expenses:
Operations & Maintenance (5) (8)
Depreciation & Amortization (5) (9)
Taxes Other Than Income Taxes (7) (16)
Operating Income 11 25
Net Interest/AFUDC 4 4
Income Taxes (8) (14)
Equity Earnings 17 22
Other (1)
Operating & GAAP Earnings $24 $36
EPS from Operating Earnings $0.05 $0.07
First Quarter Summary Key Drivers: 1Q-15 vs. 1Q-14
$14M favorable operating income due to increased revenues and expenses, driven by increased capital investment in the wholly-owned Transcos.
Equity earnings from Joint Ventures $5M favorable vs. prior year; primarily related to Electric Transmission Texas
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Generation & Marketing
1Q-14 1Q-15
$ millions (except EPS)
Operating Revenues $1,251 $1,163
Operating Expenses:
Energy Costs (805) (716)
Operations & Maintenance (116) (100)
Depreciation & Amortization (57) (50)
Taxes Other Than Income Taxes (12) (9)
Operating Income 261 288
Net Interest/AFUDC (11) (10)
Income Taxes (87) (95)
Operating Earnings 163 183
Proforma Adjustments, Net of Tax - 4
GAAP Earnings $163 $187
EPS from Operating Earnings $0.33 $0.38
First Quarter Summary
See slide 14 for items excluded from Net Income to reconcile to Operating Earnings
Key Drivers: 1Q-15 vs. 1Q-14
Generation decreased 216 GWh (1.6%) 1Q-15
vs. 1Q-14
AEP Dayton ATC liquidations down 44%: $38.02/MWh in 1Q-15 vs. $68.07/MWh in 1Q-14
O&M : $16M favorable vs. prior year primarily due to decreased plant outages and employee related expenses
Income Taxes: effective tax rate of 34.2% 1Q-15 vs. 34.9% 1Q-14
Favorable hedge performance and fuel costs helped offset the impact of lower prices in 1Q15
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Rate Changes, net of offsets (in millions)
1Q-15 vs. 1Q-14
APCo/WPCo $16
I&M $6
KPCo $0
PSO $1
SWEPCO $7
Kingsport $0
TOTAL $30
Impact on EPS
Retail Rate Performance
May not foot due to rounding
$0.04
Rate Changes, net of offsets (in millions)
1Q-15 vs. 1Q-14
Ohio Power $8
Texas Central $0
Texas North $0
TOTAL $8
Impact on EPS $0.01
Transmission & Distribution Utilities Vertically Integrated Utilities
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Retail Load*
(weather
normalized)
1Q-15 vs. 1Q-14
Ohio Power -1.7%
Texas Central 0.5%
Texas North -2.1%
TOTAL -1.1%
Impact on EPS
Retail Load*
(weather
normalized)
1Q-15 vs. 1Q-14
APCo/WPCo -0.5%
I&M -2.6%
KPCo -4.2%
PSO 0.4%
SWEPCO -4.0%
Kingsport 2.5%
TOTAL -1.6%
Impact on EPS
Retail Load Performance
*Excludes Firm Wholesale Load
Transmission & Distribution Utilities Vertically Integrated Utilities
$0.04
$0.01
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Weather Impact
(in millions)
1Q-15 vs. 1Q-14
APCo/WPCo ($1)
I&M ($4)
KPCo $0
PSO ($1)
SWEPCO $2
Kingsport $0
TOTAL ($4)
Impact on EPS
$0.00
Weather Impact
Weather Impact
(in millions)
1Q-15 vs. 1Q-14
Ohio Power $0
Texas Central $1
Texas North $1
TOTAL $2
Impact on EPS $0.00
Transmission & Distribution Utilities Vertically Integrated Utilities
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AEP Generation Resources
Volumes Generated by Source (in million MWh)
Percentage Volumes Sold by Channel
Short-term/Spot Wholesale Retail Ohio Power & Wheeling Power PPAs
QTD/YTD Power prices down 44% Natural gas prices down 43% Volumes down 2% Capacity Factor up 3%
Hydro Natural Gas Coal