-
Fourth quarter 2015 earnings per share were impacted $0.05 due to
lower than expected retail loads from warmer weather
-
Construction continues at Carty with the company currently
targeting an in service date in July 2016
-
Initiating 2016 earnings guidance of $2.20 to $2.35 per diluted
share
Portland General Electric Company (NYSE:POR) today reported net
income of $172 million, or $2.04 per diluted share, for the year ended
Dec. 31, 2015. This compares with $175 million, or $2.18 per diluted
share, for 2014. Net income was $51 million, or 57 cents per diluted
share, for the fourth quarter of 2015 compared with $43 million, or 55
cents per diluted share, for the comparable period of 2014. Looking
forward, the company is initiating full-year 2016 earnings guidance of
$2.20 to $2.35 per diluted share.
“Our financial results reflect strong operating performance despite the
warmest year on record in Oregon,” said Jim Piro, president and CEO.
“Our delivery system and generating facilities operated extremely well,
we achieved a fair outcome in our 2016 general rate case, and employees
across the company took necessary actions in response to the financial
impacts of weather early in the year.”
2015 earnings compared to 2014 earnings
Annual earnings per diluted share decreased year over year due to lower
energy sales as a result of historically warm weather,
lower-than-expected hydro and wind generation across the whole year, and
lower-than-expected federal production tax credits as a result of the
lower wind generation. These factors were partially offset by earnings
from placing Port Westward Unit 2 and the Tucannon River Wind Farm in
service, increased AFDC from Carty construction, and the company’s
management of operating and maintenance expense. Improving economic
conditions and expansion of large high-tech industrial customers
contributed to weather-adjusted load growth of more than 2 percent for
the year, excluding one large paper customer.
Company Updates
Carty Generating Station
Construction is continuing on the Carty Generating Station, a 440 MW
natural gas-fired baseload power plant near Boardman, Ore. On Dec. 18,
2015, PGE declared the general contractor responsible for engineering,
procurement and construction in default under multiple provisions of the
Carty construction agreement and terminated the agreement. Two sureties,
Liberty Mutual and Zurich North America, have provided a performance
bond of $145.6 million under the construction agreement. PGE required
the original contractor to enter into the performance bond to guarantee
satisfactory completion of the project in the event the contractor
failed to fulfill its obligation under the construction agreement.
Following termination of the construction agreement, PGE, in
consultation with the sureties, brought on new contractors, and
construction resumed during the week of Dec. 21, 2015.
“PGE’s decisive action to replace the general contractor on Carty was
done in the best interest of our stakeholders,” Piro said. “We remain
committed to delivering this important new baseload resource that will
help us continue to serve our customers with the safe, reliable and
affordable power they need for years to come.”
As of Dec. 31, 2015, PGE had invested $424 million in Carty, including
$41 million of AFDC, which was included in Construction Work in Progress
(CWIP) for the project. PGE currently estimates that the total capital
expenditures for Carty will range from $620 million to $655 million,
including AFDC, and is targeting an in service date in July 2016. PGE is
currently in discussions with the sureties regarding their obligations
under the performance bond. The company believes that the sureties will
have an obligation under the performance bond to contribute funds toward
the completion of Carty. However, the sureties have not yet made a
determination with respect to their obligations. Accordingly, the amount
of potential recovery of costs under the performance bond remains
uncertain and cannot be reasonably estimated at this time. For
additional information on Carty construction refer to PGE’s Form 10-K
for 2015 issued on Feb. 12, 2016.
2016 General Rate Case
In November 2015, PGE filed final updated power costs and an updated
retail load forecast with the Oregon Public Utility Commission (OPUC),
and the OPUC issued an order resulting in an overall price increase of
approximately 0.7 percent which reflects:
-
Return on equity of 9.6 percent;
-
Capital structure of 50 percent debt and 50 percent equity;
-
Cost of capital of 7.51 percent;
-
Rate base of $4.4 billion;
-
Annual revenue increase of $12 million.
The net annual revenue requirement increase will be effective in two
phases. A $44 million decrease, representing a 2.5 percent decrease in
customer prices effective Jan. 1, 2016, and a $57 million annualized
revenue increase will be effective when Carty is placed into service,
provided that occurs by July 31, 2016.
The order issued by the OPUC authorized the inclusion in customer prices
of capital costs for Carty of up to $514 million, including AFDC, as
well as its operating costs at such time the plant is placed in service
provided that occurs by July 31, 2016.
In the event costs incurred by PGE to complete Carty, less any amounts
received from the sureties, exceeds the OPUC’s approved amount of $514
million, the company would seek approval to recover the excess amounts
in customer prices in a subsequent general rate case (GRC) proceeding.
However, there is no assurance that such recovery would be granted by
the OPUC.
If the Carty in-service date were to be delayed beyond July 31, 2016,
PGE would pursue one or more alternative avenues to obtain OPUC approval
for the inclusion of Carty costs in customer prices. Under such
circumstance, the company might not be able to recover some, or all, of
the net revenue requirements for Carty from the date Carty is placed
into service until the time when new approved customer prices are
effective for Carty.
Fourth-quarter operating results
Net income for the fourth quarter of 2015 was $51 million, or 57 cents
per diluted share, compared with $43 million, or 55 cents per diluted
share, for the fourth quarter of 2014. The increase in quarterly
earnings per diluted share was primarily due to the incremental earnings
from Port Westward Unit 2 and the Tucannon River Wind Farm being placed
in service and the company’s management of operating and maintenance
expense.
Retail revenues increased $4 million, or 1%, in the fourth quarter of
2015 compared with the fourth quarter of 2014, which was driven
primarily by a 1 percent price increase authorized by the OPUC in the
company’s 2015 GRC, which was effective Jan. 1, 2015. The price increase
was largely the result of the additions of Port Westward Unit 2 and the
Tucannon River Wind Farm, partially offset by lower estimated power
costs for 2015. Weather in the fourth quarter of 2015 had a comparably
negative impact on revenues as weather in the fourth quarter of 2014.
Net variable power costs (NVPC), which consist of purchased power and
fuel expense net of wholesale revenues, decreased $14 million in the
fourth quarter of 2015 compared to the fourth quarter of 2014. The
decrease is largely due to a 7 percent decrease in the average variable
power cost per MWh resulting from increases in energy received from the
company’s generating resources combined with a 5 percent increase in the
average price per MWh of wholesale power sales, net of a 4 percent
decrease in the volume of wholesale power sales.
Total operating and maintenance expense was $136 million in the fourth
quarter of 2015 compared with $139 million in the fourth quarter of
2014. The $3 million, or 2 percent, decrease was largely due to a $3
million reduction in high-voltage service costs, which were offset in
revenues, $2 million related to the economic shutdown of Boardman and
lower maintenance costs at several hydro facilities, offset by a $2
million increase related to the additions of Port Westward Unit 2 and
the Tucannon River Wind Farm.
Depreciation and amortization expense was $1 million higher in the
fourth quarter of 2015 compared with the fourth quarter of 2014. A $7
million higher expense resulting from capital additions was largely
offset by a $6 million reduction from the amortization of deferred
regulatory liabilities for the Trojan spent fuel settlement and tax
credits as they were refunded to customers in 2015.
2015 Annual Operating Results
Earnings Reconciliation of 2014 to 2015
|
|
|
|
Pre-Tax
|
|
|
|
|
|
|
($ in millions, except EPS)
|
|
|
Income
|
|
|
Net Income(1)
|
|
|
Diluted EPS
|
Reported 2014
|
|
|
$
|
235
|
|
|
|
$
|
175
|
|
|
|
$
|
2.18
|
|
Adjustment for change in share count(2)
|
|
|
|
|
|
|
|
|
(0.10
|
)
|
EPS After share count adjustment
|
|
|
|
|
|
|
|
|
2.08
|
|
Revenue Adjustments
|
|
|
|
|
|
|
|
|
|
Electric retail price increase
|
|
|
32
|
|
|
|
19
|
|
|
|
0.23
|
|
Electric volume increase
|
|
|
11
|
|
|
|
7
|
|
|
|
0.08
|
|
Supplemental tariffs (refund to customers)
|
|
|
(28
|
)
|
|
|
(17
|
)
|
|
|
(0.20
|
)
|
Electric wholesale volume increase and price decrease
|
|
|
(7
|
)
|
|
|
(4
|
)
|
|
|
(0.05
|
)
|
Other revenue adjustments
|
|
|
(10
|
)
|
|
|
(6
|
)
|
|
|
(0.07
|
)
|
Change in Revenue
|
|
|
(2
|
)
|
|
|
(1
|
)
|
|
|
(0.01
|
)
|
Power Cost Adjustments
|
|
|
|
|
|
|
|
|
|
Average power cost decrease
|
|
|
57
|
|
|
|
34
|
|
|
|
0.41
|
|
Increase in system load
|
|
|
(5
|
)
|
|
|
(3
|
)
|
|
|
(0.04
|
)
|
Change in Power Costs
|
|
|
52
|
|
|
|
31
|
|
|
|
0.37
|
|
O&M Adjustments
|
|
|
|
|
|
|
|
|
|
Generation, transmission, distribution
|
|
|
(9
|
)
|
|
|
(6
|
)
|
|
|
(0.07
|
)
|
Administrative and general
|
|
|
(14
|
)
|
|
|
(8
|
)
|
|
|
(0.10
|
)
|
Change in O&M
|
|
|
(23
|
)
|
|
|
(14
|
)
|
|
|
(0.17
|
)
|
Other Item Adjustments
|
|
|
|
|
|
|
|
|
|
Depreciation & amortization
|
|
|
(4
|
)
|
|
|
(2
|
)
|
|
|
(0.03
|
)
|
Interest
|
|
|
(18
|
)
|
|
|
(11
|
)
|
|
|
(0.12
|
)
|
AFDC equity(3)
|
|
|
(16
|
)
|
|
|
(16
|
)
|
|
|
(0.19
|
)
|
Other Items
|
|
|
(7
|
)
|
|
|
(4
|
)
|
|
|
(0.05
|
)
|
Adjustment for effective vs statutory tax rate
|
|
|
|
|
|
14
|
|
|
|
0.16
|
|
Change in Other Items
|
|
|
(45
|
)
|
|
|
(19
|
)
|
|
|
(0.23
|
)
|
Reported 2015
|
|
|
$
|
217
|
|
|
|
$
|
172
|
|
|
|
$
|
2.04
|
|
(1) After tax adjustments based on PGE’s statutory tax rate of 39.5%
|
(2) Diluted share count increased in June with an equity issuance of
10.4 million additional shares
|
(3) Statutory tax rate applied only to AFDC debt
|
|
Total retail revenues increased $12 million, or 1%, in 2015
compared with 2014, primarily due to the effect of the following:
-
An $11 million increase in revenues related to a 0.6% increase in
retail energy deliveries, consisting of 5.5% and 0.2% increases in
industrial and commercial deliveries, respectively, partially offset
by a 1.8% decrease in residential deliveries; and
-
A $4 million net increase due to a $32 million increase that related
to higher average retail prices resulting from the Jan. 1, 2015, price
increase authorized by the OPUC in the company’s 2015 GRC, which was
net of a $28 million decrease due to various supplemental tariff
changes, including $20 million in customer credits in 2015 related to
proceeds received in connection with the settlement of a legal matter
regarding the operation of the ISFSI at the former Trojan nuclear
power plant site and tax credits, all of which are offset in
Depreciation and Amortization expense.
Net variable power costs decreased $45 million for 2015 compared
with 2014, primarily driven by an 8% decline in the average variable
power cost per MWh combined with a 2% increase in the volume of
wholesale power sales, net of a 9% decrease in the average price per MWh
of wholesale power sales. The 2015 GRC had estimated lower gas and power
prices in 2015 and therefore, anticipated a decrease of approximately
$60 million in NVPC from the 2014 baseline, with customer prices set
accordingly.
For 2015, actual NVPC, as calculated for regulatory purposes under the
power cost adjustment mechanism, was $3 million below the 2015 baseline
NVPC. In 2014, NVPC was $7 million below the anticipated baseline.
Total operating and maintenance expense was $507 million in 2015
compared with $484 million in 2014. The $23 million, or 5 percent,
increase is primarily due to the following:
-
$9 million in costs associated with the additions of Port Westward
Unit 2 and the Tucannon River wind farm;
-
$14 million in administrative and general costs including a $5 million
increase in information technology expenses, an increase of $3 million
in non-labor and outside services expenses, a $3 million increase in
injuries and damages resulting from insurance recoveries received in
2014, and a $1 million increase in compensation and benefits expense.
Depreciation and amortization expense in 2015 increased $4
million, or 1%, compared with 2014. A $26 million higher expense
resulting from capital additions was largely offset by a $22 million
reduction from the amortization of deferred regulatory liabilities for
the Trojan spent fuel settlement and tax credits as they were refunded
to customers in 2015. An increase in asset retirement obligation
expenses and amortization of costs previously deferred for four capital
projects as authorized in the company’s 2011 GRC, were partially offset
by amortization of gains recorded on the sale of assets. The overall
reduction in expenses resulting from the amortization of the regulatory
liabilities is directly offset by corresponding reductions in retail
revenues.
Interest expense increased $18 million, or 19%, in 2015 compared
with 2014 as $9 million resulted from lower allowance for borrowed funds
used during construction. In December 2014, PW2 and Tucannon River were
placed into service resulting in a lower average CWIP balance, the basis
for AFDC. In addition, $7 million related to a 7% increase in the
average balance of debt outstanding.
Other income, net was $22 million in 2015 compared with $38
million in 2014. The decrease was primarily due to a $16 million
decrease in the allowance for equity funds used during construction
resulting from the lower average CWIP balance.
Income tax expense decreased $16 million, or 26%, in 2015
compared to 2014, with the effective tax rate decreased to 20.7% for
2015 from 26.0% for 2014. Lower pre-tax income accounted for $7 million
of the decrease in income tax expense. A $14 million increase in
production tax credits in 2015, resulting primarily from the addition of
Tucannon River wind generation, was partially offset by a $5 million
relative effect of lower AFDC equity.
2015 earnings guidance review
PGE initiated full-year 2015 earnings guidance on Feb. 13, 2015 of $2.20
to $2.35 per diluted share. On April 28, 2015, guidance was lowered to
$2.05 to $2.20 after warm weather impacted earnings by $0.20 in the
first quarter. In conjunction with lowering guidance, management also
committed to monitoring financial results and looking for opportunities
to temporarily reduce operating costs. For the remainder of 2015 the
company successfully managed its O&M spending and made temporary
reductions in an effort to offset the impact of the weather in the first
quarter. Despite these efforts, continued warm temperatures were
compounded by poor hydro and wind conditions which led to higher
replacement power costs and fewer than estimated production tax credits
for the year. In the final quarter of the year, warm temperatures again
impacted earnings by $0.05, resulting in a $0.25 EPS impact of weather
for the full-year 2015.
2016 earnings guidance
PGE is initiating full-year 2016 earnings guidance of $2.20 to $2.35 per
diluted share. Guidance is based on warmer than normal weather and lower
wind production in January 2016, which resulted in approximately an
$0.08 impact on earnings. Additional assumptions include the following:
-
Retail deliveries growth of approximately 1 percent weather adjusted
excluding one large paper customer;
-
Average hydro conditions;
-
Wind generation based on five years of historical levels or forecast
studies when historical data is not available;
-
Normal thermal plant operations;
-
Operating and maintenance costs between $515 and $535 million, in line
with the GRC;
-
Depreciation and amortization expense between $315 and $325 million;
and
-
Carty Generating Station in service by July 2016 at approximately the
OPUC authorized capital amount of $514 million.
Fourth Quarter 2015 earnings call and web cast — Feb. 12, 2016
PGE will host a conference call with financial analysts and investors on
Friday, Feb. 12, 2016, at 11 a.m. ET. The conference call will be web
cast live on the PGE website at PortlandGeneral.com.
A replay of the call will be available beginning at 2 p.m. ET on Friday,
Feb. 12, 2016 through Friday, Feb. 19, 2016.
Jim Piro, president and CEO; Jim Lobdell, senior vice president of
finance, CFO, and treasurer; and Bill Valach, director, investor
relations, will participate in the call. Management will respond to
questions following formal comments.
The attached unaudited consolidated statements of income, condensed
consolidated balance sheets, and condensed consolidated statements of
cash flows, as well as the supplemental operating statistics, are an
integral part of this earnings release.
About Portland General Electric Company
Portland General Electric Company is a vertically integrated electric
utility that serves approximately 852,000 residential, commercial and
industrial customers in the Portland/Salem metropolitan area of Oregon.
The company’s headquarters are located at 121 S.W. Salmon Street,
Portland, Oregon 97204. Visit PGE’s website at PortlandGeneral.com.
Safe Harbor Statement
Statements in this news release that relate to future plans, objectives,
expectations, performance, events and the like may constitute
“forward-looking statements” within the meaning of the Private
Securities Litigation Reform Act of 1995, Section 27A of the Securities
Act of 1933, as amended, and Section 21E of the Securities Exchange Act
of 1934, as amended. Forward-looking statements include statements
regarding earnings guidance; statements regarding future load, hydro
conditions, wind conditions and operating and maintenance costs;
statements concerning implementation of the company’s integrated
resource plan; statements concerning future compliance with regulations
limiting emissions from generation facilities and the costs to achieve
such compliance; as well as other statements containing words such as
“anticipates,” “believes,” “intends,” “estimates,” “promises,”
“expects,” “should,” “conditioned upon,” and similar expressions.
Investors are cautioned that any such forward-looking statements are
subject to risks and uncertainties, including reductions in demand for
electricity and the sale of excess energy during periods of low
wholesale market prices; operational risks relating to the company’s
generation facilities, including hydro conditions, wind conditions,
disruption of fuel supply, and unscheduled plant outages, which may
result in unanticipated operating, maintenance and repair costs, as well
as replacement power costs; the costs of compliance with environmental
laws and regulations, including those that govern emissions from thermal
power plants; changes in weather, hydroelectric and energy markets
conditions, which could affect the availability and cost of purchased
power and fuel; changes in capital market conditions, which could affect
the availability and cost of capital and result in delay or cancellation
of capital projects; failure to complete capital projects on schedule or
within budget, or the abandonment of capital projects which could result
in the company’s inability to recover project costs; the outcome of
various legal and regulatory proceedings; and general economic and
financial market conditions. As a result, actual results may differ
materially from those projected in the forward-looking statements. All
forward-looking statements included in this news release are based on
information available to the company on the date hereof and such
statements speak only as of the date hereof. The company assumes no
obligation to update any such forward-looking statement. Prospective
investors should also review the risks and uncertainties listed in the
company’s most recent annual report on form 10-K and the company’s
reports on forms 8-K and 10-Q filed with the United States Securities
and Exchange Commission, including management’s discussion and analysis
of financial condition and results of operations and the risks described
therein from time to time.
POR-F
Source: Portland General Electric Company
|
PORTLAND GENERAL ELECTRIC COMPANY AND SUBSIDIARIES
|
CONDENSED CONSOLIDATED STATEMENTS OF INCOME
|
(In millions, except per share amounts)
|
(Unaudited)
|
|
|
|
|
Three Months Ended
|
|
|
Years Ended
|
|
|
|
December 31,
|
|
|
December 31,
|
|
|
|
2015
|
|
|
2014
|
|
|
2015
|
|
|
2014
|
Revenues, net
|
|
|
$
|
499
|
|
|
|
$
|
500
|
|
|
|
$
|
1,898
|
|
|
|
$
|
1,900
|
|
Operating expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
Purchased power and fuel
|
|
|
171
|
|
|
|
185
|
|
|
|
661
|
|
|
|
713
|
|
Generation, transmission and distribution
|
|
|
74
|
|
|
|
76
|
|
|
|
266
|
|
|
|
257
|
|
Administrative and other
|
|
|
62
|
|
|
|
63
|
|
|
|
241
|
|
|
|
227
|
|
Depreciation and amortization
|
|
|
78
|
|
|
|
77
|
|
|
|
305
|
|
|
|
301
|
|
Taxes other than income taxes
|
|
|
30
|
|
|
|
27
|
|
|
|
116
|
|
|
|
109
|
|
Total operating expenses
|
|
|
415
|
|
|
|
428
|
|
|
|
1,589
|
|
|
|
1,607
|
|
Income from operations
|
|
|
84
|
|
|
|
72
|
|
|
|
309
|
|
|
|
293
|
|
Interest expense, net (1)
|
|
|
28
|
|
|
|
25
|
|
|
|
114
|
|
|
|
96
|
|
Other income:
|
|
|
|
|
|
|
|
|
|
|
|
|
Allowance for equity funds used during construction
|
|
|
6
|
|
|
|
11
|
|
|
|
21
|
|
|
|
37
|
|
Miscellaneous income, net
|
|
|
1
|
|
|
|
—
|
|
|
|
1
|
|
|
|
1
|
|
Other income, net
|
|
|
7
|
|
|
|
11
|
|
|
|
22
|
|
|
|
38
|
|
Income before income taxes
|
|
|
63
|
|
|
|
58
|
|
|
|
217
|
|
|
|
235
|
|
Income taxes
|
|
|
12
|
|
|
|
15
|
|
|
|
45
|
|
|
|
61
|
|
Net income
|
|
|
51
|
|
|
|
43
|
|
|
|
172
|
|
|
|
174
|
|
Less: net loss attributable to noncontrolling interests
|
|
|
—
|
|
|
|
—
|
|
|
|
—
|
|
|
|
(1
|
)
|
Net income attributable to Portland General Electric Company
|
|
|
$
|
51
|
|
|
|
$
|
43
|
|
|
|
$
|
172
|
|
|
|
$
|
175
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted-average shares outstanding (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
88,773
|
|
|
|
78,210
|
|
|
|
84,180
|
|
|
|
78,180
|
|
Diluted
|
|
|
88,933
|
|
|
|
81,174
|
|
|
|
84,341
|
|
|
|
80,494
|
|
Earnings per share:
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
$
|
0.57
|
|
|
|
$
|
0.57
|
|
|
|
$
|
2.05
|
|
|
|
$
|
2.24
|
|
Diluted
|
|
|
$
|
0.57
|
|
|
|
$
|
0.55
|
|
|
|
$
|
2.04
|
|
|
|
$
|
2.18
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1) Includes an allowance for borrowed funds used during construction
|
|
|
$
|
4
|
|
|
|
$
|
7
|
|
|
|
$
|
13
|
|
|
|
$
|
22
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
PORTLAND GENERAL ELECTRIC COMPANY AND SUBSIDIARIES
|
CONDENSED CONSOLIDATED BALANCE SHEETS
|
(In millions)
|
(Unaudited)
|
|
|
|
|
As of December 31,
|
|
|
|
2015
|
|
|
2014
|
ASSETS
|
|
|
|
|
|
|
Current assets:
|
|
|
|
|
|
|
Cash and cash equivalents
|
|
|
$
|
4
|
|
|
|
$
|
127
|
Accounts receivable, net
|
|
|
158
|
|
|
|
149
|
Unbilled revenues
|
|
|
95
|
|
|
|
93
|
Inventories
|
|
|
83
|
|
|
|
82
|
Regulatory assets—current
|
|
|
129
|
|
|
|
133
|
Other current assets
|
|
|
88
|
|
|
|
115
|
Total current assets
|
|
|
557
|
|
|
|
699
|
Electric utility plant, net
|
|
|
6,012
|
|
|
|
5,679
|
Regulatory assets—noncurrent
|
|
|
524
|
|
|
|
494
|
Nuclear decommissioning trust
|
|
|
40
|
|
|
|
90
|
Non-qualified benefit plan trust
|
|
|
33
|
|
|
|
32
|
Other noncurrent assets
|
|
|
55
|
|
|
|
48
|
Total assets
|
|
|
$
|
7,221
|
|
|
|
$
|
7,042
|
|
|
|
|
|
|
|
LIABILITIES AND EQUITY
|
|
|
|
|
|
|
Current liabilities:
|
|
|
|
|
|
|
Accounts payable
|
|
|
$
|
98
|
|
|
|
156
|
Liabilities from price risk management activities—current
|
|
|
130
|
|
|
|
106
|
Short-term debt
|
|
|
6
|
|
|
|
—
|
Current portion of long-term debt
|
|
|
133
|
|
|
|
375
|
Accrued expenses and other current liabilities
|
|
|
259
|
|
|
|
236
|
Total current liabilities
|
|
|
626
|
|
|
|
873
|
Long-term debt, net of current portion
|
|
|
2,071
|
|
|
|
2,126
|
Regulatory liabilities—noncurrent
|
|
|
928
|
|
|
|
906
|
Deferred income taxes
|
|
|
632
|
|
|
|
625
|
Unfunded status of pension and postretirement plans
|
|
|
259
|
|
|
|
237
|
Liabilities from price risk management activities—noncurrent
|
|
|
161
|
|
|
|
122
|
Asset retirement obligations
|
|
|
151
|
|
|
|
116
|
Non-qualified benefit plan liabilities
|
|
|
106
|
|
|
|
105
|
Other noncurrent liabilities
|
|
|
29
|
|
|
|
21
|
Total liabilities
|
|
|
4,963
|
|
|
|
5,131
|
Total equity
|
|
|
2,258
|
|
|
|
1,911
|
Total liabilities and equity
|
|
|
$
|
7,221
|
|
|
|
$
|
7,042
|
|
|
|
|
|
|
|
|
|
|
|
PORTLAND GENERAL ELECTRIC COMPANY AND SUBSIDIARIES
|
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
|
(In millions)
|
(Unaudited)
|
|
|
|
|
Years Ended December 31,
|
|
|
|
2015
|
|
|
2014
|
Cash flows from operating activities:
|
|
|
|
|
|
|
Net income
|
|
|
$
|
172
|
|
|
|
$
|
174
|
|
Depreciation and amortization
|
|
|
305
|
|
|
|
301
|
|
Other non-cash income and expenses, net included in Net income
|
|
|
92
|
|
|
|
70
|
|
Changes in working capital
|
|
|
(31
|
)
|
|
|
(19
|
)
|
Proceeds received from legal settlement
|
|
|
—
|
|
|
|
6
|
|
Other, net
|
|
|
(21
|
)
|
|
|
(14
|
)
|
Net cash provided by operating activities
|
|
|
517
|
|
|
|
518
|
|
Cash flows from investing activities:
|
|
|
|
|
|
|
Capital expenditures
|
|
|
(598
|
)
|
|
|
(1,007
|
)
|
Distribution from (Contribution to) Nuclear decommissioning trust
|
|
|
50
|
|
|
|
(6
|
)
|
Other, net
|
|
|
26
|
|
|
|
19
|
|
Net cash used in investing activities
|
|
|
(522
|
)
|
|
|
(994
|
)
|
Cash flows from financing activities:
|
|
|
|
|
|
|
Net issuance of long-term debt
|
|
|
(298
|
)
|
|
|
583
|
|
Proceeds from issuance of common stock, net of issuance costs
|
|
|
271
|
|
|
|
—
|
|
Issuance of commercial paper, net
|
|
|
6
|
|
|
|
—
|
|
Dividends paid
|
|
|
(97
|
)
|
|
|
(87
|
)
|
Net cash (used in) provided by financing activities
|
|
|
(118
|
)
|
|
|
496
|
|
(Decrease) Increase in cash and cash equivalents
|
|
|
(123
|
)
|
|
|
20
|
|
Cash and cash equivalents, beginning of year
|
|
|
127
|
|
|
|
107
|
|
Cash and cash equivalents, end of year
|
|
|
$
|
4
|
|
|
|
$
|
127
|
|
|
|
|
|
|
|
|
|
|
|
|
|
PORTLAND GENERAL ELECTRIC COMPANY AND SUBSIDIARIES
|
SUPPLEMENTAL OPERATING STATISTICS
|
(Unaudited)
|
|
|
|
|
Three Months Ended
|
|
|
Years Ended
|
|
|
|
December 31,
|
|
|
December 31,
|
|
|
|
2015
|
|
|
2014
|
|
|
2015
|
|
|
2014
|
Revenues (dollars in millions):
|
|
|
|
|
|
|
|
|
|
|
|
|
Retail:
|
|
|
|
|
|
|
|
|
|
|
|
|
Residential
|
|
|
$
|
245
|
|
|
|
$
|
240
|
|
|
|
$
|
895
|
|
|
|
$
|
893
|
|
Commercial
|
|
|
166
|
|
|
|
164
|
|
|
|
662
|
|
|
|
657
|
|
Industrial
|
|
|
55
|
|
|
|
57
|
|
|
|
228
|
|
|
|
221
|
|
Subtotal
|
|
|
466
|
|
|
|
461
|
|
|
|
1,785
|
|
|
|
1,771
|
|
Other accrued (deferred) revenues, net
|
|
|
2
|
|
|
|
3
|
|
|
|
(10
|
)
|
|
|
(8
|
)
|
Total retail revenues
|
|
|
468
|
|
|
|
464
|
|
|
|
1,775
|
|
|
|
1,763
|
|
Wholesale revenues
|
|
|
22
|
|
|
|
22
|
|
|
|
88
|
|
|
|
95
|
|
Other operating revenues
|
|
|
9
|
|
|
|
14
|
|
|
|
35
|
|
|
|
42
|
|
Total revenues
|
|
|
$
|
499
|
|
|
|
$
|
500
|
|
|
|
$
|
1,898
|
|
|
|
$
|
1,900
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Energy sold and delivered (MWh in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
Retail energy sales:
|
|
|
|
|
|
|
|
|
|
|
|
|
Residential
|
|
|
2,017
|
|
|
|
1,990
|
|
|
|
7,325
|
|
|
|
7,462
|
|
Commercial
|
|
|
1,756
|
|
|
|
1,733
|
|
|
|
7,002
|
|
|
|
6,931
|
|
Industrial
|
|
|
806
|
|
|
|
838
|
|
|
|
3,369
|
|
|
|
3,211
|
|
Total retail energy sales
|
|
|
4,579
|
|
|
|
4,561
|
|
|
|
17,696
|
|
|
|
17,604
|
|
Retail energy deliveries:
|
|
|
|
|
|
|
|
|
|
|
|
|
Commercial
|
|
|
108
|
|
|
|
140
|
|
|
|
509
|
|
|
|
563
|
|
Industrial
|
|
|
302
|
|
|
|
276
|
|
|
|
1,177
|
|
|
|
1,099
|
|
Total retail energy deliveries
|
|
|
410
|
|
|
|
416
|
|
|
|
1,686
|
|
|
|
1,662
|
|
Total retail energy sales and deliveries
|
|
|
4,989
|
|
|
|
4,977
|
|
|
|
19,382
|
|
|
|
19,266
|
|
Wholesale energy deliveries
|
|
|
605
|
|
|
|
628
|
|
|
|
2,560
|
|
|
|
2,520
|
|
Total energy sold and delivered
|
|
|
5,594
|
|
|
|
5,605
|
|
|
|
21,942
|
|
|
|
21,786
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Number of retail customers at end of period:
|
|
|
|
|
|
|
|
|
|
|
|
|
Residential
|
|
|
|
|
|
|
|
|
746,969
|
|
|
|
738,008
|
|
Commercial
|
|
|
|
|
|
|
|
|
104,613
|
|
|
|
103,637
|
|
Industrial
|
|
|
|
|
|
|
|
|
195
|
|
|
|
198
|
|
Direct access
|
|
|
|
|
|
|
|
|
387
|
|
|
|
430
|
|
Total retail customers
|
|
|
|
|
|
|
|
|
852,164
|
|
|
|
842,273
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Heating Degree-days
|
|
|
Cooling Degree-days
|
|
|
|
2015
|
|
|
2014
|
|
|
Average
|
|
|
2015
|
|
|
2014
|
|
|
Average
|
First quarter
|
|
|
1,481
|
|
|
1,891
|
|
|
1,864
|
|
|
—
|
|
|
—
|
|
|
—
|
Second quarter
|
|
|
513
|
|
|
530
|
|
|
713
|
|
|
207
|
|
|
57
|
|
|
70
|
Third quarter
|
|
|
76
|
|
|
18
|
|
|
85
|
|
|
573
|
|
|
579
|
|
|
382
|
Fourth Quarter
|
|
|
1,391
|
|
|
1,355
|
|
|
1,602
|
|
|
5
|
|
|
17
|
|
|
1
|
Year-to-date
|
|
|
3,461
|
|
|
3,794
|
|
|
4,264
|
|
|
785
|
|
|
653
|
|
|
453
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Note: “Average” amounts represent the 15-year rolling averages
provided by the National Weather Service (Portland Airport).
|
|
|
PORTLAND GENERAL ELECTRIC COMPANY AND SUBSIDIARIES
|
SUPPLEMENTAL OPERATING STATISTICS, continued
|
(Unaudited)
|
|
|
|
|
Three Months Ended
|
|
|
Years Ended
|
|
|
|
December 31,
|
|
|
December 31,
|
|
|
|
2015
|
|
|
2014
|
|
|
2015
|
|
|
2014
|
Sources of energy (MWh in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
Generation:
|
|
|
|
|
|
|
|
|
|
|
|
|
Thermal:
|
|
|
|
|
|
|
|
|
|
|
|
|
Coal
|
|
|
1,472
|
|
|
|
1,387
|
|
|
|
4,128
|
|
|
|
4,466
|
|
Natural gas
|
|
|
1,427
|
|
|
|
1,156
|
|
|
|
4,783
|
|
|
|
3,429
|
|
Total thermal
|
|
|
2,899
|
|
|
|
2,543
|
|
|
|
8,911
|
|
|
|
7,895
|
|
Hydro
|
|
|
390
|
|
|
|
458
|
|
|
|
1,453
|
|
|
|
1,750
|
|
Wind
|
|
|
417
|
|
|
|
219
|
|
|
|
1,788
|
|
|
|
1,172
|
|
Total generation
|
|
|
3,706
|
|
|
|
3,220
|
|
|
|
12,152
|
|
|
|
10,817
|
|
Purchased power:
|
|
|
|
|
|
|
|
|
|
|
|
|
Term
|
|
|
976
|
|
|
|
1,228
|
|
|
|
4,379
|
|
|
|
5,926
|
|
Hydro
|
|
|
333
|
|
|
|
349
|
|
|
|
1,572
|
|
|
|
1,568
|
|
Wind
|
|
|
62
|
|
|
|
50
|
|
|
|
303
|
|
|
|
317
|
|
Spot
|
|
|
391
|
|
|
|
608
|
|
|
|
2,985
|
|
|
|
2,626
|
|
Total purchased power
|
|
|
1,762
|
|
|
|
2,235
|
|
|
|
9,239
|
|
|
|
10,437
|
|
Total system load
|
|
|
5,468
|
|
|
|
5,455
|
|
|
|
21,391
|
|
|
|
21,254
|
|
Less: wholesale sales
|
|
|
(606
|
)
|
|
|
(628
|
)
|
|
|
(2,560
|
)
|
|
|
(2,520
|
)
|
Retail load requirement
|
|
|
4,862
|
|
|
|
4,827
|
|
|
|
18,831
|
|
|
|
18,734
|
|
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