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3rd Quarter 2015 Earnings Release Presentation
October 22, 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]
Brad Funk Director
Regulated Accounting 614-716-3162
3
Third Quarter 2015 Highlights
Third Quarter 2015 Company Update
Refer to appendix for reconciliation between GAAP and Operating EPS
Earnings Update Delivered GAAP and operating earnings of $1.06 per share
for the third quarter 2015 Delivered GAAP and operating earnings of $3.22 per share
and $3.21 per share respectively, for YTD September 2015 Increasing operating earnings guidance range from $3.50-$3.65 to $3.67-$3.77 per share
Reaffirming 4%-6% EPS growth rate
Dividend Increase Board declared dividend of $0.56/share
This is a 5.7% increase (from $2.12 to $2.24 on an annual
basis
Regulatory Update AEP Ohio – PPA
Clean Power Plan
PJM Auction Results
Sale of AEP River Operations
YTD 2015
4
* operating adjusts GAAP results by eliminating any material non operating items and is not weather normalized
Regulated Returns Twelve Months Ended 09/30/2015 Earned ROEs (Operating Earnings*)
5
3rd Quarter 2015 vs. Prior Year By Segment
Refer to appendix for additional explanation of variances by segment
($0.07)
$0.06
$0.03
$0.03
Strong regulated operations drive 3rd quarter earnings
2015 Actual EPS $0.56 $0.23 $0.09 $0.19 $0.01 $(0.02)
6
YTD September 2015 vs. Prior Year By Segment
Refer to appendix for additional explanation of variances by segment
$0.06
$0.03
$0.03
Raising operating earnings guidance to $3.67 to $3.77 per share
2015 Actual EPS $1.59 $0.59 $0.30 $0.73 $0.03 $(0.03)
7
Normalized Load Trends
Note: Charts reflect connected load and exclude firm wholesale load & Buckeye Power backup load.
Q3-15: Positive load growth in all major retail classes, but earnings impacted by sales mix
8
Economic Data
Source – Moody’s Analytics
2.9%
2.5% 2.9%
2.7%
2.0%
2.7% 2.3%
1.9% 1.6% 1.6%
0%
1%
2%
3%
4%
Q3-14 Q4-14 Q1-15 Q2-15 Q3-15
Gro
wth
vs
Pri
or
Ye
ar
GDP Growth by Quarter
US AEP
0%
1%
2%
3%
4%
Q3-14 Q4-14 Q1-15 Q2-15 Q3-15
Gro
wth
vs
Pri
or
Ye
ar
GDP Growth by Geography
US AEP-East AEP-West
2.0% 2.1% 2.3%
2.1% 2.0%
1.4% 1.3% 1.1% 0.9% 0.9%
0%
1%
2%
3%
Q3-14 Q4-14 Q1-15 Q2-15 Q3-15
Gro
wth
vs
Pri
or
Ye
ar
Employment Growth by Quarter US AEP
0%
1%
2%
3%
Q3-14 Q4-14 Q1-15 Q2-15 Q3-15
Gro
wth
vs
Pri
or
Ye
ar
Employment Growth by Geography
US AEP-East AEP-West
9
AEP Shale Play Counties
Industrial Class Data
Shale counties in AEP service territory Non-Shale counties in AEP service territory
Shale gas development drives industrial load growth
10
(unaudited) 9/30/2015 Actual
($ 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 $178
Less
Commercial Paper Outstanding (32)
Letters of Credit Issued (33)
Net Available Liquidity $3,613
Actual Target
FFO Interest Coverage 5.7x >3.6x
FFO to Total Debt 21.6% 15%-20%
Capitalization & Liquidity
Liquidity Summary
Credit Statistics
Note: Credit statistics represent the trailing 12 months as of 09/30/2015
Total Debt / Total Capitalization
Strong balance sheet, credit metrics, and liquidity
Qualified Pension Funding
11
EEI Financial Conference Themes
The new BOLD™ transmission line technology
Confirm 4% - 6% operating earnings growth rate
Update 2016 operating earnings guidance range and provide
details by segment
Detail growth in Regulated Utility Operations
Three year Cap-Ex forecast
Transmission opportunities update
Three year financing plan
Fleet Transition, Environmental Investment
Ohio PPA and Strategic Update
12
Appendix
13
Third Quarter Operating Earnings Per Share Overview
See slides 14 & 15 for items excluded from GAAP Net Income to reconcile to Operating Earnings
Weighted average no. of shares outstanding: 489M Q3-14 & 488M YTD-14; 491M Q3-15 & 490M YTD-15
Segment Q3-14
EPS Q3-15
EPS YTD-14
EPS YTD-15
EPS
Vertically Integrated Utilities $0.45 $0.56 $1.33 $1.59
Transmission & Distribution Utilities
0.19 0.23 0.57 0.59
AEP Transmission Holdco 0.09 0.09 0.23 0.30
Generation & Marketing 0.24 0.19 0.78 0.73
AEP River Operations 0.02 0.01 0.03 0.03
Corporate & Other 0.02 (0.02) 0.01 (0.03)
EPS from Operating Earnings $1.01 $1.06 $2.95 $3.21
14
3rd Quarter Reconciliation of GAAP to Operating Earnings
$ millions Earnings Per Share
Q3-14 Q3-15 Change Q3-14 Q3-15 Change
Reported (GAAP) Earnings $493 $519 $26 $1.01 $1.06 $0.05
Non Operating Items:
Mark-to-Market Impact of Commodity Hedging Activities
- 2 2 - - -
AEP Operating Earnings $493 $521 $28 $1.01 $1.06 $0.05
Weighted average no. of shares outstanding: 489M Q3-14 & 491M Q3-15
15
YTD September Reconciliation of GAAP to Operating Earnings
$ millions Earnings Per Share
YTD-14 YTD-15 Change YTD-14 YTD-15 Change
Reported (GAAP) Earnings $1,443 $1,578 $135 $2.95 $3.22 $0.27
Non Operating Items:
Mark-to-Market Impact of Commodity Hedging Activities
- (3) (3) - (0.01) (0.01)
AEP Operating Earnings $1,443 $1,575 $132 $2.95 $3.21 $0.26
Weighted average no. of shares outstanding: 488M YTD-14 & 490M YTD-15
16
Vertically Integrated Utilities
Q3-14 Q3-15
$ millions (except EPS)
Operating Revenues $2,450 $2,471
Operating Expenses:
Energy Costs (1,010) (931)
Operations & Maintenance (615) (653)
Depreciation & Amortization (257) (264)
Taxes Other Than Income Taxes (95) (97)
Operating Income 473 526
Net Interest/AFUDC (118) (109)
Income Taxes (135) (142)
Other (1) (1)
Operating & GAAP Earnings $219 $274
EPS from Operating Earnings $0.45 $0.56
Third Quarter EPS Summary Key Drivers: Q3-15 vs. Q3-14
Rate changes: $64M primarily from APCo, SWEPCo & I&M
Weather: $51M favorable vs. prior year; $5M favorable vs. normal
Off-System Sales: $23M unfavorable vs. prior year due
to lower market prices in both PJM & SPP
Retail load: $22M unfavorable vs. prior year due to unfavorable retail prices variances and decreased residential sales
O&M: $21M unfavorable (net of offsets) vs. prior year primarily due to employee related expenses
Income Taxes: effective tax rate of 34.2% Q3-15 vs. 38.1% Q3-14
17
Vertically Integrated Utilities
YTD-14 YTD-15
$ millions (except EPS)
Operating Revenues $7,288 $7,159
Operating Expenses:
Energy Costs (3,038) (2,695)
Operations & Maintenance (1,809) (1,844)
Depreciation & Amortization (772) (802)
Taxes Other Than Income Taxes (278) (288)
Operating Income 1,391 1,530
Net Interest/AFUDC (358) (333)
Income Taxes (380) (416)
Other (2) (1)
Operating & GAAP Earnings $651 $780
EPS from Operating Earnings $1.33 $1.59
YTD EPS Summary Key Drivers: YTD-15 vs. YTD-14
Rate changes: $176M primarily from APCo, SWEPCo & I&M
$23M VA Regulatory provision reversal
Weather: $52M favorable vs. prior year; $76M
favorable vs. normal Off-System Sales: $118M unfavorable vs. prior year due
to lower market prices in both PJM & SPP
Retail load: $55M unfavorable vs. prior year due to decreased residential sales and change in sales mix
O&M: $19M favorable (net of offsets) vs. prior year primarily due to lower forestry and storm related expenses
PJM Charges: $30M favorable vs. prior year primarily due to decreases in unrecovered PJM charges
Income Taxes: effective tax rate of 34.7% YTD-15 vs. 36.8% YTD-14
18
Transmission & Distribution Utilities
Q3-14 Q3-15
$ millions (except EPS)
Operating Revenues $1,231 $1,189
Operating Expenses:
Energy Costs (404) (284)
Operations & Maintenance (329) (348)
Depreciation & Amortization (182) (198)
Taxes Other Than Income Taxes (117) (122)
Operating Income 199 237
Net Interest/AFUDC (56) (65)
Income Taxes (51) (59)
Operating & GAAP Earnings $92 $113
EPS from Operating Earnings $0.19 $0.23
Third Quarter EPS Summary Key Drivers: Q3-15 vs. Q3-14
Rate changes: $7M primarily from Ohio DIR
A $33M regulatory provision was recorded in Q3-2014
Weather: $4M favorable vs. prior year; $5M favorable vs. normal
Retail Load comparable to prior year and normal
OSS: Unfavorable $9M due to OVEC
O&M: $9M unfavorable (net of offsets) vs. prior year primarily due to higher employee related and customer expenses
Income Taxes: effective tax rate of 34.3% Q3-15
vs. 35.5% Q3-14
19
Transmission & Distribution Utilities
YTD-14 YTD-15
$ millions (except EPS)
Operating Revenues $3,580 $3,520
Operating Expenses:
Energy Costs (1,206) (1,042)
Operations & Maintenance (920) (956)
Depreciation & Amortization (499) (536)
Taxes Other Than Income Taxes (344) (362)
Operating Income 611 624
Net Interest/AFUDC (173) (180)
Income Taxes (159) (156)
Operating & GAAP Earnings $279 $288
EPS from Operating Earnings $0.57 $0.59
YTD EPS Summary Key Drivers: YTD-15 vs. YTD-14
Rate changes: $22M from Ohio DIR A $33M regulatory provision was recorded in
2014
Weather: $5M favorable vs. prior year; $10M favorable vs. normal
Retail Load: $5M unfavorable, primarily due to
sales mix
O&M: $25M unfavorable (net of offsets) vs. prior year primarily due to a donation to the Ohio Growth Fund and higher transmission and distribution services costs
Income Taxes: effective tax rate of 35.2% YTD-15 vs. 36.3% YTD-14
20
AEP Transmission Holdco
Q3-14 Q3-15
$ millions (except EPS)
Operating Revenues $55 $88
Operating Expenses:
Operations & Maintenance (7) (11)
Depreciation & Amortization (7) (12)
Taxes Other Than Income Taxes (9) (17)
Operating Income 32 48
Net Interest/AFUDC 7 4
Income Taxes (18) (23)
Equity Earnings 22 17
Other
Operating & GAAP Earnings $43 $46
EPS from Operating Earnings $0.09 $0.09
Third Quarter EPS Summary Key Drivers: Q3-15 vs. Q3-14
$16M favorable operating income due to increased revenues and expenses, driven by increased capital investment in the wholly-owned Transcos
Taxes Other Than Income Taxes unfavorable $8M vs. prior year primarily due to higher property taxes
Equity Earnings from Joint Ventures $5M unfavorable vs. prior year primarily related to ETT expenses
21
AEP Transmission Holdco
YTD-14 YTD-15
$ millions (except EPS)
Operating Revenues $140 $245
Operating Expenses:
Operations & Maintenance (18) (27)
Depreciation & Amortization (17) (30)
Taxes Other Than Income Taxes (23) (50)
Operating Income 82 138
Net Interest/AFUDC 17 13
Income Taxes (47) (66)
Equity Earnings 62 63
Other - (1)
Operating & GAAP Earnings $114 $147
EPS from Operating Earnings $0.23 $0.30
YTD EPS Summary Key Drivers: YTD-15 vs. YTD-14
$56M favorable operating income due to increased revenues and expenses, driven by increased capital investment in the wholly-owned Transcos
Taxes Other Than Income Taxes unfavorable $27M vs. prior year primarily due to higher property taxes
22
Generation & Marketing
Q3-14 Q3-15
$ millions (except EPS)
Operating Revenues $901 $840
Operating Expenses:
Energy Costs (529) (565)
Operations & Maintenance (122) (60)
Depreciation & Amortization (56) (51)
Taxes Other Than Income Taxes (12) (10)
Operating Income 182 154
Net Interest/AFUDC (10) (10)
Income Taxes (55) (51)
Operating Earnings 117 93
Proforma Adjustments, Net of Tax - (2)
GAAP Earnings $117 $91
EPS from Operating Earnings $0.24 $0.19
Third Quarter EPS Summary
See slide 14 for items excluded from Net Income to reconcile to Operating Earnings
Key Drivers: Q3-15 vs. Q3-14
Generation decreased 759 GWh (6.8%) Q3-15 vs.
Q3-14 AEP Dayton ATC liquidations down 10%:
$29.72/MWh in Q3-15 vs. $33.06/MWh in Q3-14
Generation revenue decreased due to lower capacity revenue
O&M: $62M favorable vs. prior year primarily due to decreased plant outages and settlement of asset retirement obligations
Income Taxes: effective tax rate of 35.1% Q3-15 vs. 31.7% Q3-14
Favorable hedge performance and fuel costs helped offset the impact of lower prices in Q3-15
23
Generation & Marketing
YTD-14 YTD-15
$ millions (except EPS)
Operating Revenues $3,065 $2,803
Operating Expenses:
Energy Costs (1,894) (1,771)
Operations & Maintenance (363) (277)
Depreciation & Amortization (169) (152)
Taxes Other Than Income Taxes (37) (30)
Operating Income 602 573
Net Interest/AFUDC (31) (29)
Income Taxes (193) (187)
Operating Earnings 378 357
Proforma Adjustments, Net of Tax - 3
GAAP Earnings $378 $360
EPS from Operating Earnings $0.78 $0.73
YTD EPS Summary
See slide 15 for items excluded from Net Income to reconcile to Operating Earnings
Key Drivers: YTD-15 vs. YTD-14
Generation decreased 2,552 GWh (7.1%) YTD-15
vs. YTD-14
AEP Dayton ATC liquidations down 30%: $33.00/MWh in 2015 vs. $47.02/MWh 2014
Generation revenue decreased due to lower capacity revenue
O&M : $86M favorable vs. prior year primarily due to decreased plant outages and settlement of asset retirement obligations
Income Taxes: effective tax rate of 34.3% YTD-15 vs. 33.7% YTD-14
Favorable hedge performance and fuel costs helped offset the impact of lower prices
24
Rate Changes, net of offsets (in millions)
Q3-15 vs. Q3-14
APCo/WPCo $34
I&M $12
KPCo -
PSO $1
SWEPCO $17
Kingsport -
TOTAL $64
Impact on EPS
Retail Rate Performance
May not foot due to rounding
$0.09
Rate Changes, net of offsets (in millions)
Q3-15 vs. Q3-14
Ohio Power $7
Texas Central -
Texas North -
TOTAL $7
Impact on EPS $0.01
Transmission & Distribution Utilities Vertically Integrated Utilities
25
Rate Changes, net of offsets (in millions)
YTD-15 vs. YTD-14
APCo/WPCo $70
I&M $48
KPCo -
PSO $3
SWEPCO $55
Kingsport -
TOTAL $176
Impact on EPS
Retail Rate Performance
May not foot due to rounding
$0.23
Rate Changes, net of offsets (in millions)
YTD-15 vs. YTD-14
Ohio Power $22
Texas Central -
Texas North -
TOTAL $22
Impact on EPS $0.03
Transmission & Distribution Utilities Vertically Integrated Utilities
26
Retail Load*
(weather
normalized)
Q3-15 vs. Q3-14
Ohio Power 4.2%
Texas Central 0.9%
Texas North 1.2%
TOTAL 2.8%
Impact on EPS -
Retail Load*
(weather
normalized)
Q3-15 vs. Q3-14
APCo/WPCo -1.4%
I&M 2.0%
KPCo 0.8%
PSO 1.0%
SWEPCO -3.3%
Kingsport -2.5%
TOTAL -0.6%
Impact on EPS
Retail Load Performance
*Excludes Firm Wholesale Load
Transmission & Distribution Utilities Vertically Integrated Utilities
$0.03
27
Retail Load*
(weather
normalized)
YTD-15 vs. YTD-14
Ohio Power 1.5%
Texas Central 1.3%
Texas North 0.7%
TOTAL 1.4%
Impact on EPS
Retail Load*
(weather
normalized)
YTD-15 vs. YTD-14
APCo/WPCo -0.7%
I&M -0.2%
KPCo -2.2%
PSO 1.0%
SWEPCO -2.8%
Kingsport 0.5%
TOTAL -0.8%
Impact on EPS
Retail Load Performance
*Excludes Firm Wholesale Load
Transmission & Distribution Utilities Vertically Integrated Utilities
$0.07
$0.01
28
Weather Impact
(in millions)
Q3-15 vs. Q3-14
APCo/WPCo $15
I&M $9
KPCo $2
PSO $9
SWEPCO $16
Kingsport -
TOTAL $51
Impact on EPS
Weather Impact vs. Prior Year
Weather Impact
(in millions)
Q3-15 vs. Q3-14
Ohio Power -
Texas Central $3
Texas North $1
TOTAL $4
Impact on EPS
Transmission & Distribution Utilities Vertically Integrated Utilities
$0.01
$0.07
29
Weather Impact
(in millions)
YTD-15 vs. YTD-14
APCo/WPCo $19
I&M $1
KPCo $4
PSO $6
SWEPCO $22
Kingsport -
TOTAL $52
Impact on EPS
Weather Impact
Weather Impact
(in millions)
YTD-15 vs. YTD-14
Ohio Power -
Texas Central $5
Texas North -
TOTAL $5
Impact on EPS
Transmission & Distribution Utilities Vertically Integrated Utilities
May not foot due to rounding
$0.01
$0.07