Commission
|
|
Exact name of registrant as specified in its charter;
|
|
IRS Employer
|
File Number
|
|
State or other jurisdiction of incorporation or organization
|
|
Identification No.
|
001-14881
|
|
BERKSHIRE HATHAWAY ENERGY COMPANY
|
|
94-2213782
|
|
|
(An Iowa Corporation)
|
|
|
|
|
666 Grand Avenue, Suite 500
|
|
|
|
|
Des Moines, Iowa 50309-2580
|
|
|
|
|
515-242-4300
|
|
|
|
|
|
|
|
001-05152
|
|
PACIFICORP
|
|
93-0246090
|
|
|
(An Oregon Corporation)
|
|
|
|
|
825 N.E. Multnomah Street
|
|
|
|
|
Portland, Oregon 97232
|
|
|
|
|
888-221-7070
|
|
|
|
|
|
|
|
333-90553
|
|
MIDAMERICAN FUNDING, LLC
|
|
47-0819200
|
|
|
(An Iowa Limited Liability Company)
|
|
|
|
|
666 Grand Avenue, Suite 500
|
|
|
|
|
Des Moines, Iowa 50309-2580
|
|
|
|
|
515-242-4300
|
|
|
|
|
|
|
|
333-15387
|
|
MIDAMERICAN ENERGY COMPANY
|
|
42-1425214
|
|
|
(An Iowa Corporation)
|
|
|
|
|
666 Grand Avenue, Suite 500
|
|
|
|
|
Des Moines, Iowa 50309-2580
|
|
|
|
|
515-242-4300
|
|
|
|
|
|
|
|
000-52378
|
|
NEVADA POWER COMPANY
|
|
88-0420104
|
|
|
(A Nevada Corporation)
|
|
|
|
|
6226 West Sahara Avenue
|
|
|
|
|
Las Vegas, Nevada 89146
|
|
|
|
|
702-402-5000
|
|
|
|
|
|
|
|
000-00508
|
|
SIERRA PACIFIC POWER COMPANY
|
|
88-0044418
|
|
|
(A Nevada Corporation)
|
|
|
|
|
6100 Neil Road
|
|
|
|
|
Reno, Nevada 89511
|
|
|
|
|
775-834-4011
|
|
|
Registrant
|
Securities registered pursuant to Section 12(b) of the Act:
|
BERKSHIRE HATHAWAY ENERGY COMPANY
|
None
|
PACIFICORP
|
None
|
MIDAMERICAN FUNDING, LLC
|
None
|
MIDAMERICAN ENERGY COMPANY
|
None
|
NEVADA POWER COMPANY
|
None
|
SIERRA PACIFIC POWER COMPANY
|
None
|
Registrant
|
Securities registered pursuant to Section 12(g) of the Act:
|
BERKSHIRE HATHAWAY ENERGY COMPANY
|
None
|
PACIFICORP
|
None
|
MIDAMERICAN FUNDING, LLC
|
None
|
MIDAMERICAN ENERGY COMPANY
|
None
|
NEVADA POWER COMPANY
|
Common Stock, $1.00 stated value
|
SIERRA PACIFIC POWER COMPANY
|
Common Stock, $3.75 par value
|
Registrant
|
Name of exchange on which registered:
|
BERKSHIRE HATHAWAY ENERGY COMPANY
|
None
|
PACIFICORP
|
None
|
MIDAMERICAN FUNDING, LLC
|
None
|
MIDAMERICAN ENERGY COMPANY
|
None
|
NEVADA POWER COMPANY
|
None
|
SIERRA PACIFIC POWER COMPANY
|
None
|
Registrant
|
Yes
|
No
|
BERKSHIRE HATHAWAY ENERGY COMPANY
|
|
X
|
PACIFICORP
|
|
X
|
MIDAMERICAN FUNDING, LLC
|
|
X
|
MIDAMERICAN ENERGY COMPANY
|
X
|
|
NEVADA POWER COMPANY
|
|
X
|
SIERRA PACIFIC POWER COMPANY
|
|
X
|
Registrant
|
Yes
|
No
|
BERKSHIRE HATHAWAY ENERGY COMPANY
|
|
X
|
PACIFICORP
|
|
X
|
MIDAMERICAN FUNDING, LLC
|
X
|
|
MIDAMERICAN ENERGY COMPANY
|
|
X
|
NEVADA POWER COMPANY
|
|
X
|
SIERRA PACIFIC POWER COMPANY
|
|
X
|
Registrant
|
Yes
|
No
|
BERKSHIRE HATHAWAY ENERGY COMPANY
|
X
|
|
PACIFICORP
|
X
|
|
MIDAMERICAN FUNDING, LLC
|
|
X
|
MIDAMERICAN ENERGY COMPANY
|
X
|
|
NEVADA POWER COMPANY
|
X
|
|
SIERRA PACIFIC POWER COMPANY
|
X
|
|
Registrant
|
Large accelerated filer
|
Accelerated filer
|
Non-accelerated filer
|
Smaller reporting company
|
BERKSHIRE HATHAWAY ENERGY COMPANY
|
|
|
X
|
|
PACIFICORP
|
|
|
X
|
|
MIDAMERICAN FUNDING, LLC
|
|
|
X
|
|
MIDAMERICAN ENERGY COMPANY
|
|
|
X
|
|
NEVADA POWER COMPANY
|
|
|
X
|
|
SIERRA PACIFIC POWER COMPANY
|
|
|
X
|
|
PART I
|
||
|
|
|
Item 2
.
|
||
Mine Safety Disclosures
|
||
|
|
|
PART II
|
||
|
|
|
|
|
|
PART III
|
||
|
|
|
|
|
|
PART IV
|
||
|
|
|
|
||
|
Entity Definitions
|
||
BHE
|
|
Berkshire Hathaway Energy Company
|
Berkshire Hathaway Energy or the Company
|
|
Berkshire Hathaway Energy Company and its subsidiaries
|
PacifiCorp
|
|
PacifiCorp and its subsidiaries
|
MidAmerican Funding
|
|
MidAmerican Funding, LLC and its subsidiaries
|
MidAmerican Energy
|
|
MidAmerican Energy Company
|
NV Energy
|
|
NV Energy, Inc. and its subsidiaries
|
Nevada Power
|
|
Nevada Power Company and its subsidiaries
|
Sierra Pacific
|
|
Sierra Pacific Power Company and its subsidiaries
|
Nevada Utilities
|
|
Nevada Power Company and Sierra Pacific Power Company
|
Registrants
|
|
Berkshire Hathaway Energy, PacifiCorp, MidAmerican Energy, MidAmerican Funding, Nevada Power and Sierra Pacific
|
Subsidiary Registrants
|
|
PacifiCorp, MidAmerican Energy, MidAmerican Funding, Nevada Power and Sierra Pacific
|
Northern Powergrid
|
|
Northern Powergrid Holdings Company
|
Northern Natural Gas
|
|
Northern Natural Gas Company
|
Kern River
|
|
Kern River Gas Transmission Company
|
AltaLink
|
|
BHE Canada Holdings Corporation
|
ALP
|
|
AltaLink, L.P.
|
BHE U.S. Transmission
|
|
BHE U.S. Transmission, LLC
|
BHE Renewables, LLC
|
|
BHE Renewables, LLC
|
HomeServices
|
|
HomeServices of America, Inc. and its subsidiaries
|
BHE Pipeline Group or Pipeline Companies
|
|
Consists of Northern Natural Gas and Kern River
|
BHE Transmission
|
|
Consists of AltaLink and BHE U.S. Transmission
|
BHE Renewables
|
|
Consists of BHE Renewables, LLC and CalEnergy Philippines
|
ETT
|
|
Electric Transmission Texas, LLC
|
Domestic Regulated Businesses
|
|
PacifiCorp, MidAmerican Energy Company, Nevada Power Company, Sierra Pacific Power Company, Northern Natural Gas Company and Kern River Gas Transmission Company
|
Regulated Businesses
|
|
PacifiCorp, MidAmerican Energy Company, Nevada Power Company, Sierra Pacific Power Company, Northern Natural Gas Company, Kern River Gas Transmission Company and AltaLink, L.P.
|
Utilities
|
|
PacifiCorp, MidAmerican Energy Company, Nevada Power Company and Sierra Pacific Power Company
|
Northern Powergrid Distribution Companies
|
|
Northern Powergrid (Northeast) Limited and Northern Powergrid (Yorkshire) plc
|
Berkshire Hathaway
|
|
Berkshire Hathaway Inc.
|
Topaz
|
|
Topaz Solar Farms LLC
|
Topaz Project
|
|
550-megawatt solar project in California
|
Agua Caliente
|
|
Agua Caliente Solar, LLC
|
Agua Caliente Project
|
|
290-megawatt solar project in Arizona
|
Bishop Hill II
|
|
Bishop Hill Energy II LLC
|
Bishop Hill Project
|
|
81-megawatt wind-powered generating facility in Illinois
|
Pinyon Pines I
|
|
Pinyon Pines Wind I, LLC
|
Pinyon Pines II
|
|
Pinyon Pines Wind II, LLC
|
Pinyon Pines Projects
|
|
168-megawatt and 132-megawatt wind-powered generating facilities in California
|
Jumbo Road
|
|
Jumbo Road Holdings, LLC
|
Jumbo Road Project
|
|
300-megawatt wind-powered generating facility in Texas
|
Solar Star Funding
|
|
Solar Star Funding, LLC
|
Solar Star Projects
|
|
A combined 586-megawatt solar project in California
|
Solar Star I
|
|
Solar Star California XIX, LLC
|
Solar Star II
|
|
Solar Star California XX, LLC
|
|
|
|
Certain Industry Terms
|
|
|
AESO
|
|
Alberta Electric System Operator
|
AFUDC
|
|
Allowance for Funds Used During Construction
|
AUC
|
|
Alberta Utilities Commission
|
Bcf
|
|
Billion cubic feet
|
BTER
|
|
Base Tariff Energy Rates
|
California ISO
|
|
California Independent System Operator Corporation
|
CPUC
|
|
California Public Utilities Commission
|
DEAA
|
|
Deferred Energy Accounting Adjustment
|
Dodd-Frank Reform Act
|
|
Dodd-Frank Wall Street Reform and Consumer Protection Act
|
Dth
|
|
Decatherms
|
DSM
|
|
Demand-side Management
|
EBA
|
|
Energy Balancing Account
|
ECAC
|
|
Energy Cost Adjustment Clause
|
ECAM
|
|
Energy Cost Adjustment Mechanism
|
EEIR
|
|
Energy Efficiency Implementation Rate
|
EEPR
|
|
Energy Efficiency Program Rate
|
EIM
|
|
Energy Imbalance Market
|
EPA
|
|
United States Environmental Protection Agency
|
ERCOT
|
|
Electric Reliability Council of Texas
|
FERC
|
|
Federal Energy Regulatory Commission
|
GEMA
|
|
Gas and Electricity Markets Authority
|
GHG
|
|
Greenhouse Gases
|
GWh
|
|
Gigawatt Hours
|
ICC
|
|
Illinois Commerce Commission
|
IPUC
|
|
Idaho Public Utilities Commission
|
IRP
|
|
Integrated Resource Plan
|
IUB
|
|
Iowa Utilities Board
|
kV
|
|
Kilovolt
|
LNG
|
|
Liquefied Natural Gas
|
LDC
|
|
Local Distribution Company
|
MATS
|
|
Mercury and Air Toxics Standards
|
MISO
|
|
Midcontinent Independent System Operator, Inc.
|
MW
|
|
Megawatts
|
MWh
|
|
Megawatt Hours
|
NERC
|
|
North American Electric Reliability Corporation
|
NRC
|
|
Nuclear Regulatory Commission
|
OCA
|
|
Iowa Office of Consumer Advocate
|
OPUC
|
|
Oregon Public Utility Commission
|
PCAM
|
|
Power Cost Adjustment Mechanism
|
PTAM
|
|
Post Test-year Adjustment Mechanism
|
PUCN
|
|
Public Utilities Commission of Nevada
|
RCRA
|
|
Resource Conservation and Recovery Act
|
REC
|
|
Renewable Energy Credit
|
RPS
|
|
Renewable Portfolio Standards
|
RRA
|
|
Renewable Energy Credit and Sulfur Dioxide Revenue Adjustment Mechanism
|
RTO
|
|
Regional Transmission Organization
|
SEC
|
|
United States Securities and Exchange Commission
|
SIP
|
|
State Implementation Plan
|
TAM
|
|
Transition Adjustment Mechanism
|
UPSC
|
|
Utah Public Service Commission
|
WECC
|
|
Western Electricity Coordinating Council
|
WPSC
|
|
Wyoming Public Service Commission
|
WUTC
|
|
Washington Utilities and Transportation Commission
|
•
|
general economic, political and business conditions, as well as changes in, and compliance with, laws and regulations, including income tax reform, initiatives regarding deregulation and restructuring of the utility industry, and reliability and safety standards, affecting the respective Registrant's operations or related industries;
|
•
|
changes in, and compliance with, environmental laws, regulations, decisions and policies that could, among other items, increase operating and capital costs, reduce facility output, accelerate facility retirements or delay facility construction or acquisition;
|
•
|
the outcome of regulatory rate reviews and other proceedings conducted by regulatory agencies or other governmental and legal bodies and the respective Registrant's ability to recover costs through rates in a timely manner;
|
•
|
changes in economic, industry, competition or weather conditions, as well as demographic trends, new technologies and various conservation, energy efficiency and private generation measures and programs, that could affect customer growth and usage, electricity and natural gas supply or the respective Registrant's ability to obtain long-term contracts with customers and suppliers;
|
•
|
performance, availability and ongoing operation of the respective Registrant's facilities, including facilities not operated by the Registrants, due to the impacts of market conditions, outages and repairs, transmission constraints, weather, including wind, solar and hydroelectric conditions, and operating conditions;
|
•
|
the effects of catastrophic and other unforeseen events, which may be caused by factors beyond the control of each respective Registrant or by a breakdown or failure of the Registrants' operating assets, including storms, floods, fires, earthquakes, explosions, landslides, mining accidents, litigation, wars, terrorism, embargoes, and cyber security attacks, data security breaches, disruptions, or other malicious acts;
|
•
|
a high degree of variance between actual and forecasted load or generation that could impact a Registrant's hedging strategy and the cost of balancing its generation resources with its retail load obligations;
|
•
|
changes in prices, availability and demand for wholesale electricity, coal, natural gas, other fuel sources and fuel transportation that could have a significant impact on generating capacity and energy costs;
|
•
|
the financial condition and creditworthiness of the respective Registrant's significant customers and suppliers;
|
•
|
changes in business strategy or development plans;
|
•
|
availability, terms and deployment of capital, including reductions in demand for investment-grade commercial paper, debt securities and other sources of debt financing and volatility in the London Interbank Offered Rate, the base interest rate for the Registrants' credit facilities;
|
•
|
changes in the respective Registrant's credit ratings;
|
•
|
risks relating to nuclear generation, including unique operational, closure and decommissioning risks;
|
•
|
hydroelectric conditions and the cost, feasibility and eventual outcome of hydroelectric relicensing proceedings;
|
•
|
the impact of certain contracts used to mitigate or manage volume, price and interest rate risk, including increased collateral requirements, and changes in commodity prices, interest rates and other conditions that affect the fair value of certain contracts;
|
•
|
the impact of inflation on costs and the ability of the respective Registrants to recover such costs in regulated rates;
|
•
|
fluctuations in foreign currency exchange rates, primarily the British pound and the Canadian dollar;
|
•
|
increases in employee healthcare costs;
|
•
|
the impact of investment performance and changes in interest rates, legislation, healthcare cost trends, mortality and morbidity on pension and other postretirement benefits expense and funding requirements;
|
•
|
changes in the residential real estate brokerage and mortgage industries and regulations that could affect brokerage and mortgage transactions;
|
•
|
unanticipated construction delays, changes in costs, receipt of required permits and authorizations, ability to fund capital projects and other factors that could affect future facilities and infrastructure additions;
|
•
|
the availability and price of natural gas in applicable geographic regions and demand for natural gas supply;
|
•
|
the impact of new accounting guidance or changes in current accounting estimates and assumptions on the consolidated financial results of the respective Registrants;
|
•
|
the ability to successfully integrate future acquired operations into a Registrant's business; and
|
•
|
other business or investment considerations that may be disclosed from time to time in the Registrants' filings with the SEC or in other publicly disseminated written documents.
|
•
|
90% of Berkshire Hathaway Energy's consolidated operating income during
2016
was generated from rate-regulated businesses.
|
•
|
The
Utilities
serve 4.7 million electric and natural gas customers in
11
states in the United States,
Northern Powergrid
serves
3.9 million
end-users in northern England and
ALP
serves approximately
85%
of Alberta, Canada's population.
|
•
|
As of December 31,
2016
, Berkshire Hathaway Energy owned approximately
31,600
MW of generation capacity in operation and under construction:
|
◦
|
Approximately
27,600
MW of generation capacity is owned by its regulated electric utility businesses;
|
◦
|
Approximately
4,000
MW of generation capacity is owned by its nonregulated subsidiaries, the majority of which provides power to utilities under long-term contracts; and
|
◦
|
Berkshire Hathaway Energy's generation capacity in operation and under construction consists of 33% natural gas, 30% wind and solar, 30% coal, 4% hydroelectric and 3% nuclear and other.
|
◦
|
As of December 31,
2016
, Berkshire Hathaway Energy has invested $19 billion in solar, wind, geothermal and biomass generation facilities.
|
•
|
Berkshire Hathaway Energy owns approximately
32,900
miles of transmission lines and owns a 50% interest in ETT that has approximately
1,200
miles of transmission lines.
|
•
|
The
BHE Pipeline Group
owns approximately
16,400
miles of pipeline with a design capacity of approximately 7.9
Bcf
of natural gas per day and transported approximately 8% of the total natural gas consumed in the United States during
2016
.
|
•
|
HomeServices closed over $86.5 billion of home sales in
2016
, up 11.0% from
2015
, and continued to grow its brokerage, mortgage and franchise businesses. HomeServices' franchise business operates in
47
states with over
375
franchisees throughout the country.
|
|
2016
|
|
2015
|
|
2014
|
||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Utah
|
24,020
|
|
|
44
|
%
|
|
24,158
|
|
|
44
|
%
|
|
24,105
|
|
|
44
|
%
|
Oregon
|
12,869
|
|
|
24
|
|
|
12,863
|
|
|
24
|
|
|
12,959
|
|
|
24
|
|
Wyoming
|
9,189
|
|
|
17
|
|
|
9,330
|
|
|
17
|
|
|
9,568
|
|
|
17
|
|
Washington
|
3,982
|
|
|
7
|
|
|
4,108
|
|
|
8
|
|
|
4,118
|
|
|
8
|
|
Idaho
|
3,510
|
|
|
7
|
|
|
3,443
|
|
|
6
|
|
|
3,495
|
|
|
6
|
|
California
|
748
|
|
|
1
|
|
|
739
|
|
|
1
|
|
|
754
|
|
|
1
|
|
|
54,318
|
|
|
100
|
%
|
|
54,641
|
|
|
100
|
%
|
|
54,999
|
|
|
100
|
%
|
|
|
|
|
|
|
|
|
Facility
|
|
Net Owned
|
||
|
|
|
|
|
|
|
|
Net Capacity
|
|
Capacity
|
||
Generating Facility
|
|
Location
|
|
Energy Source
|
|
Installed
|
|
(MW)
(1)
|
|
(MW)
(1)
|
||
COAL:
|
|
|
|
|
|
|
|
|
|
|
||
Jim Bridger Nos. 1, 2, 3 and 4
|
|
Rock Springs, WY
|
|
Coal
|
|
1974-1979
|
|
2,123
|
|
|
1,415
|
|
Hunter Nos. 1, 2 and 3
|
|
Castle Dale, UT
|
|
Coal
|
|
1978-1983
|
|
1,363
|
|
|
1,158
|
|
Huntington Nos. 1 and 2
|
|
Huntington, UT
|
|
Coal
|
|
1974-1977
|
|
909
|
|
|
909
|
|
Dave Johnston Nos. 1, 2, 3 and 4
|
|
Glenrock, WY
|
|
Coal
|
|
1959-1972
|
|
760
|
|
|
760
|
|
Naughton Nos. 1, 2 and 3
(2)
|
|
Kemmerer, WY
|
|
Coal
|
|
1963-1971
|
|
637
|
|
|
637
|
|
Cholla No. 4
|
|
Joseph City, AZ
|
|
Coal
|
|
1981
|
|
395
|
|
|
395
|
|
Wyodak No. 1
|
|
Gillette, WY
|
|
Coal
|
|
1978
|
|
332
|
|
|
266
|
|
Craig Nos. 1 and 2
|
|
Craig, CO
|
|
Coal
|
|
1979-1980
|
|
855
|
|
|
165
|
|
Colstrip Nos. 3 and 4
|
|
Colstrip, MT
|
|
Coal
|
|
1984-1986
|
|
1,480
|
|
|
148
|
|
Hayden Nos. 1 and 2
|
|
Hayden, CO
|
|
Coal
|
|
1965-1976
|
|
446
|
|
|
78
|
|
|
|
|
|
|
|
|
|
9,300
|
|
|
5,931
|
|
NATURAL GAS:
|
|
|
|
|
|
|
|
|
|
|
||
Lake Side 2
|
|
Vineyard, UT
|
|
Natural gas/steam
|
|
2014
|
|
631
|
|
|
631
|
|
Lake Side
|
|
Vineyard, UT
|
|
Natural gas/steam
|
|
2007
|
|
546
|
|
|
546
|
|
Currant Creek
|
|
Mona, UT
|
|
Natural gas/steam
|
|
2005-2006
|
|
524
|
|
|
524
|
|
Chehalis
|
|
Chehalis, WA
|
|
Natural gas/steam
|
|
2003
|
|
477
|
|
|
477
|
|
Hermiston
|
|
Hermiston, OR
|
|
Natural gas/steam
|
|
1996
|
|
461
|
|
|
231
|
|
Gadsby Steam
|
|
Salt Lake City, UT
|
|
Natural gas
|
|
1951-1955
|
|
238
|
|
|
238
|
|
Gadsby Peakers
|
|
Salt Lake City, UT
|
|
Natural gas
|
|
2002
|
|
119
|
|
|
119
|
|
|
|
|
|
|
|
|
|
2,996
|
|
|
2,766
|
|
HYDROELECTRIC:
(3)
|
|
|
|
|
|
|
|
|
|
|
||
Lewis River System
|
|
WA
|
|
Hydroelectric
|
|
1931-1958
|
|
578
|
|
|
578
|
|
North Umpqua River System
|
|
OR
|
|
Hydroelectric
|
|
1950-1956
|
|
204
|
|
|
204
|
|
Klamath River System
|
|
CA, OR
|
|
Hydroelectric
|
|
1903-1962
|
|
170
|
|
|
170
|
|
Bear River System
|
|
ID, UT
|
|
Hydroelectric
|
|
1908-1984
|
|
105
|
|
|
105
|
|
Rogue River System
|
|
OR
|
|
Hydroelectric
|
|
1912-1957
|
|
52
|
|
|
52
|
|
Minor hydroelectric facilities
|
|
Various
|
|
Hydroelectric
|
|
1895-1986
|
|
26
|
|
|
26
|
|
|
|
|
|
|
|
|
|
1,135
|
|
|
1,135
|
|
WIND:
(3)
|
|
|
|
|
|
|
|
|
|
|
||
Marengo
|
|
Dayton, WA
|
|
Wind
|
|
2007-2008
|
|
210
|
|
|
210
|
|
Glenrock
|
|
Glenrock, WY
|
|
Wind
|
|
2008-2009
|
|
138
|
|
|
138
|
|
Seven Mile Hill
|
|
Medicine Bow, WY
|
|
Wind
|
|
2008
|
|
119
|
|
|
119
|
|
Dunlap Ranch
|
|
Medicine Bow, WY
|
|
Wind
|
|
2010
|
|
111
|
|
|
111
|
|
Leaning Juniper
|
|
Arlington, OR
|
|
Wind
|
|
2006
|
|
100
|
|
|
100
|
|
High Plains
|
|
McFadden, WY
|
|
Wind
|
|
2009
|
|
99
|
|
|
99
|
|
Rolling Hills
|
|
Glenrock, WY
|
|
Wind
|
|
2009
|
|
99
|
|
|
99
|
|
Goodnoe Hills
|
|
Goldendale, WA
|
|
Wind
|
|
2008
|
|
94
|
|
|
94
|
|
Foote Creek
|
|
Arlington, WY
|
|
Wind
|
|
1999
|
|
41
|
|
|
32
|
|
McFadden Ridge
|
|
McFadden, WY
|
|
Wind
|
|
2009
|
|
28
|
|
|
28
|
|
|
|
|
|
|
|
|
|
1,039
|
|
|
1,030
|
|
OTHER:
(3)
|
|
|
|
|
|
|
|
|
|
|
||
Blundell
|
|
Milford, UT
|
|
Geothermal
|
|
1984, 2007
|
|
32
|
|
|
32
|
|
|
|
|
|
|
|
|
|
32
|
|
|
32
|
|
Total Available Generating Capacity
|
|
|
|
|
|
14,502
|
|
|
10,894
|
|
(1)
|
Facility Net Capacity represents the lesser of nominal ratings or any limitations under applicable interconnection, power purchase, or other agreements for intermittent resources and the total net dependable capability available during summer conditions for all other units. An intermittent resource's nominal rating is the manufacturer's contractually specified capability (in MW) under specified conditions. Net Owned Capacity indicates PacifiCorp's ownership of Facility Net Capacity.
|
(2)
|
As required by current state permits, PacifiCorp currently plans to remove Naughton Unit No. 3 (280 MW) from coal-fueled service by year-end 2017. However, a request has been submitted to and is being considered by the state of Wyoming that would allow the unit to operate as a coal-fueled unit until no later than January 30, 2019, and then either close or be converted to natural gas. Refer to "Environmental Laws and Regulations" in Item 1 of this Form 10-K for further discussion.
|
(3)
|
All or some of the renewable energy attributes associated with generation from these generating facilities may be: (a) used in future years to comply with RPS or other regulatory requirements or (b) sold to third parties in the form of RECs or other environmental commodities.
|
|
2016
|
|
2015
|
|
2014
|
|||
|
|
|
|
|
|
|||
Coal
|
56
|
%
|
|
61
|
%
|
|
60
|
%
|
Natural gas
|
15
|
|
|
14
|
|
|
16
|
|
Hydroelectric
(1)
|
6
|
|
|
4
|
|
|
5
|
|
Wind and other
(1)
|
5
|
|
|
4
|
|
|
5
|
|
Total energy generated
|
82
|
|
|
83
|
|
|
86
|
|
Energy purchased - short-term contracts and other
|
10
|
|
|
9
|
|
|
6
|
|
Energy purchased - long-term contracts (renewable)
(1)
|
8
|
|
|
5
|
|
|
5
|
|
Energy purchased - long-term contracts (non-renewable)
|
—
|
|
|
3
|
|
|
3
|
|
|
100
|
%
|
|
100
|
%
|
|
100
|
%
|
(1)
|
All or some of the renewable energy attributes associated with generation from these generating facilities and purchases may be: (a) used in future years to comply with RPS or other regulatory requirements, (b) sold to third parties in the form of RECs or other environmental commodities, or (c) excluded from energy purchased.
|
Coal Mine
|
|
Location
|
|
Generating Facility Served
|
|
Mining Method
|
|
Recoverable Tons
|
|||
|
|
|
|
|
|
|
|
|
|||
Bridger
|
|
Rock Springs, WY
|
|
Jim Bridger
|
|
Surface
|
|
31
|
|
(1
|
)
|
Bridger
|
|
Rock Springs, WY
|
|
Jim Bridger
|
|
Underground
|
|
8
|
|
(1
|
)
|
Trapper
|
|
Craig, CO
|
|
Craig
|
|
Surface
|
|
5
|
|
(2
|
)
|
|
|
|
|
|
|
|
|
44
|
|
|
(1)
|
These coal reserves are leased and mined by Bridger Coal Company, a joint venture between Pacific Minerals, Inc. and a subsidiary of Idaho Power Company. Pacific Minerals, Inc., a wholly owned subsidiary of PacifiCorp, has a two-thirds interest in the joint venture. The amounts included above represent only PacifiCorp's two-thirds interest in the coal reserves.
|
(2)
|
These coal reserves are leased and mined by Trapper Mining Inc., a cooperative in which PacifiCorp has an ownership interest of 21%. The amount included above represents only PacifiCorp's 21% interest in the coal reserves. PacifiCorp does not operate the Trapper mine.
|
•
|
On property owned or leased by PacifiCorp;
|
•
|
Under or over streets, alleys, highways and other public places, the public domain and national forests and state lands under franchises, easements or other rights that are generally subject to termination;
|
•
|
Under or over private property as a result of easements obtained primarily from the title holder of record; or
|
•
|
Under or over Native American reservations under grant of easement by the United States Secretary of Interior or lease by Native American tribes.
|
|
2016
|
|
2015
|
|
2014
|
|||
Operating revenue:
|
|
|
|
|
|
|||
Regulated electric
|
76
|
%
|
|
74
|
%
|
|
65
|
%
|
Regulated gas
|
24
|
|
|
26
|
|
|
35
|
|
|
100
|
%
|
|
100
|
%
|
|
100
|
%
|
|
|
|
|
|
|
|||
Operating income:
|
|
|
|
|
|
|||
Regulated electric
|
88
|
%
|
|
86
|
%
|
|
81
|
%
|
Regulated gas
|
12
|
|
|
14
|
|
|
19
|
|
|
100
|
%
|
|
100
|
%
|
|
100
|
%
|
|
2016
|
|
2015
|
|
2014
|
||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Iowa
|
21,766
|
|
|
91
|
%
|
|
20,922
|
|
|
90
|
%
|
|
20,585
|
|
|
90
|
%
|
Illinois
|
1,940
|
|
|
8
|
|
|
1,903
|
|
|
9
|
|
|
1,975
|
|
|
9
|
|
South Dakota
|
218
|
|
|
1
|
|
|
217
|
|
|
1
|
|
|
217
|
|
|
1
|
|
|
23,924
|
|
|
100
|
%
|
|
23,042
|
|
|
100
|
%
|
|
22,777
|
|
|
100
|
%
|
|
2016
|
|
2015
|
|
2014
|
||||||||||||
GWh sold:
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Residential
|
6,408
|
|
|
20
|
%
|
|
6,166
|
|
|
19
|
%
|
|
6,429
|
|
|
20
|
%
|
Commercial
|
3,812
|
|
|
12
|
|
|
3,806
|
|
|
12
|
|
|
4,084
|
|
|
12
|
|
Industrial
|
12,115
|
|
|
37
|
|
|
11,487
|
|
|
36
|
|
|
10,642
|
|
|
33
|
|
Other
|
1,589
|
|
|
5
|
|
|
1,583
|
|
|
5
|
|
|
1,622
|
|
|
5
|
|
Total retail
|
23,924
|
|
|
74
|
|
|
23,042
|
|
|
72
|
|
|
22,777
|
|
|
70
|
|
Wholesale
|
8,489
|
|
|
26
|
|
|
8,741
|
|
|
28
|
|
|
9,716
|
|
|
30
|
|
Total GWh sold
|
32,413
|
|
|
100
|
%
|
|
31,783
|
|
|
100
|
%
|
|
32,493
|
|
|
100
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Average number of retail customers (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Residential
|
653
|
|
|
86
|
%
|
|
646
|
|
|
86
|
%
|
|
643
|
|
|
86
|
%
|
Commercial
|
91
|
|
|
12
|
|
|
90
|
|
|
12
|
|
|
87
|
|
|
12
|
|
Industrial
|
2
|
|
|
—
|
|
|
2
|
|
|
—
|
|
|
2
|
|
|
—
|
|
Other
|
14
|
|
|
2
|
|
|
14
|
|
|
2
|
|
|
14
|
|
|
2
|
|
Total
|
760
|
|
|
100
|
%
|
|
752
|
|
|
100
|
%
|
|
746
|
|
|
100
|
%
|
|
|
|
|
|
|
Year
|
|
Facility Net
|
|
Net Owned
|
||
Generating Facility
|
|
Location
|
|
Energy Source
|
|
Installed
|
|
Capacity (MW)
(1)
|
|
Capacity (MW)
(1)
|
||
WIND:
|
|
|
|
|
|
|
|
|
|
|
||
Adair
|
|
Adair, IA
|
|
Wind
|
|
2008
|
|
175
|
|
|
175
|
|
Adams
|
|
Lennox, IA
|
|
Wind
|
|
2015
|
|
150
|
|
|
150
|
|
Carroll
|
|
Carroll, IA
|
|
Wind
|
|
2008
|
|
150
|
|
|
150
|
|
Century
|
|
Blairsburg, IA
|
|
Wind
|
|
2005-2008
|
|
200
|
|
|
200
|
|
Charles City
|
|
Charles City, IA
|
|
Wind
|
|
2008
|
|
75
|
|
|
75
|
|
Eclipse
|
|
Adair, IA
|
|
Wind
|
|
2012
|
|
200
|
|
|
200
|
|
Highland
|
|
Primghar, IA
|
|
Wind
|
|
2015
|
|
475
|
|
|
475
|
|
Ida Grove
|
|
Ida Grove, IA
|
|
Wind
|
|
2016
|
|
300
|
|
|
300
|
|
Intrepid
|
|
Schaller, IA
|
|
Wind
|
|
2004-2005
|
|
176
|
|
|
176
|
|
Laurel
|
|
Laurel, IA
|
|
Wind
|
|
2011
|
|
120
|
|
|
120
|
|
Lundgren
|
|
Otho, IA
|
|
Wind
|
|
2014
|
|
250
|
|
|
250
|
|
Macksburg
|
|
Macksburg, IA
|
|
Wind
|
|
2014
|
|
119
|
|
|
119
|
|
Morning Light
|
|
Adair, IA
|
|
Wind
|
|
2012
|
|
100
|
|
|
100
|
|
O'Brien
|
|
Primghar, IA
|
|
Wind
|
|
2016
|
|
250
|
|
|
250
|
|
Pomeroy
|
|
Pomeroy, IA
|
|
Wind
|
|
2007-2011
|
|
286
|
|
|
286
|
|
Rolling Hills
|
|
Massena, IA
|
|
Wind
|
|
2011
|
|
443
|
|
|
443
|
|
Victory
|
|
Westside, IA
|
|
Wind
|
|
2006
|
|
99
|
|
|
99
|
|
Vienna
|
|
Gladbrook, IA
|
|
Wind
|
|
2012-2013
|
|
150
|
|
|
150
|
|
Walnut
|
|
Walnut, IA
|
|
Wind
|
|
2008
|
|
150
|
|
|
150
|
|
Wellsburg
|
|
Wellsburg, IA
|
|
Wind
|
|
2014
|
|
139
|
|
|
139
|
|
|
|
|
|
|
|
|
|
4,007
|
|
|
4,007
|
|
COAL:
|
|
|
|
|
|
|
|
|
|
|
||
George Neal Unit No. 3
|
|
Sergeant Bluff, IA
|
|
Coal
|
|
1975
|
|
518
|
|
|
373
|
|
George Neal Unit No. 4
|
|
Salix, IA
|
|
Coal
|
|
1979
|
|
660
|
|
|
268
|
|
Louisa
|
|
Muscatine, IA
|
|
Coal
|
|
1983
|
|
740
|
|
|
651
|
|
Ottumwa
|
|
Ottumwa, IA
|
|
Coal
|
|
1981
|
|
730
|
|
|
380
|
|
Walter Scott, Jr. Unit No. 3
|
|
Council Bluffs, IA
|
|
Coal
|
|
1978
|
|
702
|
|
|
555
|
|
Walter Scott, Jr. Unit No. 4
|
|
Council Bluffs, IA
|
|
Coal
|
|
2007
|
|
806
|
|
|
481
|
|
|
|
|
|
|
|
|
|
4,156
|
|
|
2,708
|
|
NATURAL GAS AND OTHER:
|
|
|
|
|
|
|
|
|
|
|
||
Greater Des Moines
|
|
Pleasant Hill, IA
|
|
Gas
|
|
2003-2004
|
|
481
|
|
|
481
|
|
Coralville
|
|
Coralville, IA
|
|
Gas
|
|
1970
|
|
63
|
|
|
63
|
|
Electrifarm
|
|
Waterloo, IA
|
|
Gas or Oil
|
|
1975-1978
|
|
182
|
|
|
182
|
|
Moline
|
|
Moline, IL
|
|
Gas
|
|
1970
|
|
61
|
|
|
61
|
|
Parr
|
|
Charles City, IA
|
|
Gas
|
|
1969
|
|
33
|
|
|
33
|
|
Pleasant Hill
|
|
Pleasant Hill, IA
|
|
Gas or Oil
|
|
1990-1994
|
|
160
|
|
|
160
|
|
River Hills
|
|
Des Moines, IA
|
|
Gas
|
|
1966-1967
|
|
115
|
|
|
115
|
|
Riverside Unit No. 5
|
|
Bettendorf, IA
|
|
Gas
|
|
1961
|
|
123
|
|
|
123
|
|
Sycamore
|
|
Johnston, IA
|
|
Gas or Oil
|
|
1974
|
|
148
|
|
|
148
|
|
28 portable power modules
|
|
Various
|
|
Oil
|
|
2000
|
|
56
|
|
|
56
|
|
|
|
|
|
|
|
|
|
1,422
|
|
|
1,422
|
|
NUCLEAR:
|
|
|
|
|
|
|
|
|
|
|
||
Quad Cities Unit Nos. 1 and 2
|
|
Cordova, IL
|
|
Uranium
|
|
1972
|
|
1,824
|
|
|
456
|
|
|
|
|
|
|
|
|
|
|
|
|
||
HYDROELECTRIC:
|
|
|
|
|
|
|
|
|
|
|
||
Moline Unit Nos. 1-4
(2)
|
|
Moline, IL
|
|
Hydroelectric
|
|
1941
|
|
2
|
|
|
2
|
|
|
|
|
|
|
|
|
|
|
|
|
||
Total Available Generating Capacity
|
|
|
|
|
|
11,411
|
|
|
8,595
|
|
||
|
|
|
|
|
|
|
|
|
|
|
||
PROJECTS UNDER CONSTRUCTION
|
|
|
|
|
|
|
|
|
||||
Various wind projects
|
|
|
|
|
|
|
|
2,000
|
|
|
2,000
|
|
|
|
|
|
13,411
|
|
|
10,595
|
|
(1)
|
Facility Net Capacity represents the lesser of nominal ratings or any limitations under applicable interconnection, power purchase, or other agreements for intermittent resources and the total net dependable capability available during summer conditions for all other units. An intermittent resource's nominal rating is the manufacturer's contractually specified capability (in MW) under specified conditions. Net Owned Capacity indicates MidAmerican Energy's ownership of Facility Net Capacity.
|
(2)
|
Three of the Moline hydroelectric units were out of service and not accredited by the MISO in 2016.
|
|
2016
|
|
2015
|
|
2014
|
|||
|
|
|
|
|
|
|||
Coal
|
39
|
%
|
|
48
|
%
|
|
55
|
%
|
Nuclear
|
12
|
|
|
12
|
|
|
12
|
|
Natural gas
|
2
|
|
|
1
|
|
|
—
|
|
Wind and other
(1)
|
35
|
|
|
29
|
|
|
24
|
|
Total energy generated
|
88
|
|
|
90
|
|
|
91
|
|
Energy purchased - short-term contracts and other
|
10
|
|
|
8
|
|
|
7
|
|
Energy purchased - long-term contracts (renewable)
(1)
|
1
|
|
|
1
|
|
|
1
|
|
Energy purchased - long-term contracts (non-renewable)
|
1
|
|
|
1
|
|
|
1
|
|
|
100
|
%
|
|
100
|
%
|
|
100
|
%
|
(1)
|
All or some of the renewable energy attributes associated with generation from these generating facilities and purchases may be: (a) used in future years to comply with RPS or other regulatory requirements, (b) sold to third parties in the form of renewable energy credits or other environmental commodities, or (c) excluded from energy purchased.
|
|
2016
|
|
2015
|
|
2014
|
|||
|
|
|
|
|
|
|||
Iowa
|
76
|
%
|
|
76
|
%
|
|
77
|
%
|
South Dakota
|
13
|
|
|
13
|
|
|
12
|
|
Illinois
|
10
|
|
|
10
|
|
|
10
|
|
Nebraska
|
1
|
|
|
1
|
|
|
1
|
|
|
100
|
%
|
|
100
|
%
|
|
100
|
%
|
|
2016
|
|
2015
|
|
2014
|
|||
|
|
|
|
|
|
|||
Residential
|
41
|
%
|
|
42
|
%
|
|
49
|
%
|
Commercial
(1)
|
21
|
|
|
21
|
|
|
24
|
|
Industrial
(1)
|
4
|
|
|
5
|
|
|
5
|
|
Total retail
|
66
|
|
|
68
|
|
|
78
|
|
Wholesale
(2)
|
34
|
|
|
32
|
|
|
22
|
|
|
100
|
%
|
|
100
|
%
|
|
100
|
%
|
|
|
|
|
|
|
|||
Total Dth of natural gas sold (in thousands)
|
113,294
|
|
|
110,105
|
|
|
115,209
|
|
Total Dth of transportation service (in thousands)
|
83,610
|
|
|
80,001
|
|
|
82,314
|
|
Total average number of retail customers (in thousands)
|
742
|
|
|
733
|
|
|
726
|
|
(1)
|
Commercial and industrial customers are classified primarily based on the nature of their business and natural gas usage. Commercial customers are non-residential customers that use natural gas principally for heating. Industrial customers are non-residential customers that use natural gas principally for their manufacturing processes.
|
(2)
|
Wholesale sales are generally made to other utilities, municipalities and energy marketing companies for eventual resale to end-use customers.
|
|
2016
|
|
2015
|
|
2014
|
|||
|
|
|
|
|
|
|||
Operating revenue:
|
|
|
|
|
|
|||
Electric
|
86
|
%
|
|
86
|
%
|
|
86
|
%
|
Gas
|
14
|
|
|
14
|
|
|
14
|
|
|
100
|
%
|
|
100
|
%
|
|
100
|
%
|
|
|
|
|
|
|
|||
Operating income:
|
|
|
|
|
|
|||
Electric
|
89
|
%
|
|
91
|
%
|
|
93
|
%
|
Gas
|
11
|
|
|
9
|
|
|
7
|
|
|
100
|
%
|
|
100
|
%
|
|
100
|
%
|
|
2016
|
|
2015
|
|
2014
|
||||||||||||
Nevada Power:
|
|
|
|
|
|
|
|
|
|
|
|
||||||
GWh sold:
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Residential
|
9,394
|
|
|
43
|
%
|
|
9,246
|
|
|
42
|
%
|
|
8,923
|
|
|
42
|
%
|
Commercial
|
4,663
|
|
|
21
|
|
|
4,635
|
|
|
21
|
|
|
4,489
|
|
|
21
|
|
Industrial
|
7,313
|
|
|
34
|
|
|
7,571
|
|
|
34
|
|
|
7,486
|
|
|
36
|
|
Other
|
212
|
|
|
1
|
|
|
214
|
|
|
1
|
|
|
211
|
|
|
1
|
|
Total retail
|
21,582
|
|
|
99
|
|
|
21,666
|
|
|
98
|
|
|
21,109
|
|
|
100
|
|
Wholesale
|
258
|
|
|
1
|
|
|
353
|
|
|
2
|
|
|
20
|
|
|
—
|
|
Total GWh sold
|
21,840
|
|
|
100
|
%
|
|
22,019
|
|
|
100
|
%
|
|
21,129
|
|
|
100
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Average number of retail customers (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Residential
|
796
|
|
|
88
|
%
|
|
782
|
|
|
88
|
%
|
|
770
|
|
|
88
|
%
|
Commercial
|
105
|
|
|
12
|
|
|
104
|
|
|
12
|
|
|
102
|
|
|
12
|
|
Industrial
|
2
|
|
|
—
|
|
|
2
|
|
|
—
|
|
|
2
|
|
|
—
|
|
Total
|
903
|
|
|
100
|
%
|
|
888
|
|
|
100
|
%
|
|
874
|
|
|
100
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Sierra Pacific:
|
|
|
|
|
|
|
|
|
|
|
|
||||||
GWh sold:
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Residential
|
2,375
|
|
|
26
|
%
|
|
2,315
|
|
|
26
|
%
|
|
2,268
|
|
|
26
|
%
|
Commercial
|
2,933
|
|
|
33
|
|
|
2,942
|
|
|
33
|
|
|
2,944
|
|
|
34
|
|
Industrial
|
3,014
|
|
|
34
|
|
|
2,973
|
|
|
34
|
|
|
2,869
|
|
|
33
|
|
Other
|
16
|
|
|
—
|
|
|
16
|
|
|
—
|
|
|
16
|
|
|
—
|
|
Total retail
|
8,338
|
|
|
93
|
|
|
8,246
|
|
|
93
|
|
|
8,097
|
|
|
93
|
|
Wholesale
|
662
|
|
|
7
|
|
|
664
|
|
|
7
|
|
|
645
|
|
|
7
|
|
Total GWh sold
|
9,000
|
|
|
100
|
%
|
|
8,910
|
|
|
100
|
%
|
|
8,742
|
|
|
100
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Average number of retail customers (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Residential
|
291
|
|
|
86
|
%
|
|
288
|
|
|
86
|
%
|
|
285
|
|
|
86
|
%
|
Commercial
|
47
|
|
|
14
|
|
|
46
|
|
|
14
|
|
|
46
|
|
|
14
|
|
Total
|
338
|
|
|
100
|
%
|
|
334
|
|
|
100
|
%
|
|
331
|
|
|
100
|
%
|
|
|
|
|
|
|
|
|
Facility
|
|
Net Owned
|
||
|
|
|
|
|
|
|
|
Net Capacity
|
|
Capacity
|
||
Generating Facility
|
|
Location
|
|
Energy Source
|
|
Installed
|
|
(MW)
(1)
|
|
(MW)
(1)
|
||
Nevada Power:
|
|
|
|
|
|
|
|
|
|
|
||
NATURAL GAS:
|
|
|
|
|
|
|
|
|
|
|
||
Clark
|
|
Las Vegas, NV
|
|
Natural gas
|
|
1973-2008
|
|
1,102
|
|
|
1,102
|
|
Lenzie
|
|
Las Vegas, NV
|
|
Natural gas
|
|
2006
|
|
1,102
|
|
|
1,102
|
|
Harry Allen
|
|
Las Vegas, NV
|
|
Natural gas
|
|
1995-2011
|
|
628
|
|
|
628
|
|
Higgins
|
|
Primm, NV
|
|
Natural gas
|
|
2004
|
|
530
|
|
|
530
|
|
Silverhawk
(2)
|
|
Las Vegas, NV
|
|
Natural gas
|
|
2004
|
|
520
|
|
|
390
|
|
Las Vegas
|
|
Las Vegas, NV
|
|
Natural gas
|
|
1994-2003
|
|
272
|
|
|
272
|
|
Sun Peak
|
|
Las Vegas, NV
|
Natural gas/oil
|
|
1991
|
|
210
|
|
|
210
|
|
|
|
|
|
|
|
|
|
|
4,364
|
|
|
4,234
|
|
COAL:
|
|
|
|
|
|
|
|
|
|
|
||
Reid Gardner Unit No. 4
(3)
|
|
Moapa, NV
|
|
Coal
|
|
1983
|
|
257
|
|
|
257
|
|
Navajo Unit Nos. 1, 2 and 3
(3)
|
|
Page, AZ
|
|
Coal
|
|
1974-1976
|
|
2,250
|
|
|
255
|
|
|
|
|
|
|
|
|
|
2,507
|
|
|
512
|
|
RENEWABLES:
|
|
|
|
|
|
|
|
|
|
|
||
Goodsprings
|
|
Goodsprings, NV
|
|
Waste heat
|
|
2010
|
|
5
|
|
|
5
|
|
Nellis
|
|
Las Vegas, NV
|
|
Solar
|
|
2015
|
|
15
|
|
|
15
|
|
|
|
|
|
|
|
|
|
20
|
|
|
20
|
|
|
|
|
|
|
|
|
|
|
|
|
||
Total Nevada Power
|
|
|
|
|
|
|
|
6,891
|
|
|
4,766
|
|
|
|
|
|
|
|
|
|
|
|
|
||
Sierra Pacific:
|
|
|
|
|
|
|
|
|
|
|
||
NATURAL GAS:
|
|
|
|
|
|
|
|
|
|
|
||
Tracy
|
|
Sparks, NV
|
|
Natural gas
|
|
1974-2008
|
|
753
|
|
|
753
|
|
Ft. Churchill
|
|
Yerington, NV
|
Natural gas
|
|
1968-1971
|
|
226
|
|
|
226
|
|
|
Clark Mountain
|
|
Sparks, NV
|
|
Natural gas
|
|
1994
|
|
132
|
|
|
132
|
|
|
|
|
|
|
|
|
|
1,111
|
|
|
1,111
|
|
COAL:
|
|
|
|
|
|
|
|
|
|
|
||
Valmy Unit Nos. 1 and 2
|
|
Valmy, NV
|
|
Coal
|
|
1981-1985
|
|
522
|
|
|
261
|
|
|
|
|
|
|
|
|
|
|
|
|
||
Total Sierra Pacific
|
|
|
|
|
|
|
|
1,633
|
|
|
1,372
|
|
|
|
|
|
|
|
|
|
|
|
|
||
Total NV Energy
|
|
|
|
|
|
|
|
8,524
|
|
|
6,138
|
|
(1)
|
Facility Net Capacity represents the lesser of nominal ratings or any limitations under applicable interconnection, power purchase, or other agreements for intermittent resources and the total net dependable capability available during summer conditions for all other units. An intermittent resource's nominal rating is the manufacturer's contractually specified capability (in MW) under specified conditions. Net Owned Capacity indicates Nevada Power or Sierra Pacific's ownership of Facility Net Capacity.
|
(2)
|
Nevada Power plans to acquire the remaining 25% (130 MW) of Silverhawk in April 2017.
|
(3)
|
Nevada Power currently anticipates retiring Reid Gardner Unit No. 4 in the first quarter of 2017 and eliminating its interest in Navajo Unit Nos. 1, 2 and 3 in 2019. Refer to "Environmental Laws and Regulations" in Item 1 of this Form 10-K for further discussion.
|
|
2016
|
|
2015
|
|
2014
|
|||
|
|
|
|
|
|
|||
Nevada Power:
|
|
|
|
|
|
|||
Natural gas
|
64
|
%
|
|
65
|
%
|
|
56
|
%
|
Coal
|
7
|
|
|
7
|
|
|
20
|
|
Total energy generated
|
71
|
|
|
72
|
|
|
76
|
|
Energy purchased - long-term contracts (non-renewable)
|
14
|
|
|
15
|
|
|
13
|
|
Energy purchased - long-term contracts (renewable)
(1)
|
14
|
|
|
12
|
|
|
10
|
|
Energy purchased - short-term contracts and other
|
1
|
|
|
1
|
|
|
1
|
|
|
100
|
%
|
|
100
|
%
|
|
100
|
%
|
|
|
|
|
|
|
|||
Sierra Pacific:
|
|
|
|
|
|
|||
Natural gas
|
45
|
%
|
|
41
|
%
|
|
46
|
%
|
Coal
|
8
|
|
|
13
|
|
|
21
|
|
Total energy generated
|
53
|
|
|
54
|
|
|
67
|
|
Energy purchased - long-term contracts (non-renewable)
|
36
|
|
|
36
|
|
|
22
|
|
Energy purchased - long-term contracts (renewable)
(1)
|
10
|
|
|
9
|
|
|
10
|
|
Energy purchased - short-term contracts and other
|
1
|
|
|
1
|
|
|
1
|
|
|
100
|
%
|
|
100
|
%
|
|
100
|
%
|
(1)
|
All or some of the renewable energy attributes associated with renewable energy purchased may be: (a) used in future years to comply with RPS or other regulatory requirements or (b) sold to third parties in the form of renewable energy credits or other environmental commodities.
|
•
|
The PUCN-approved long-term IRP which is filed every three years and has a 20-year planning horizon;
|
•
|
The PUCN-approved energy supply plan which is an intermediate term resource procurement and risk management plan that establishes the supply portfolio strategies within which intermediate term resource requirements will be met and has a one to three year planning horizon; and
|
•
|
Tactical execution activities with a one-month to twelve-month focus.
|
|
2016
|
|
2015
|
|
2014
|
|||
|
|
|
|
|
|
|||
Residential
|
52
|
%
|
|
49
|
%
|
|
51
|
%
|
Commercial
(1)
|
26
|
|
|
24
|
|
|
25
|
|
Industrial
(1)
|
9
|
|
|
8
|
|
|
9
|
|
Total retail
|
87
|
|
|
81
|
|
|
85
|
|
Wholesale
|
13
|
|
|
19
|
|
|
15
|
|
|
100
|
%
|
|
100
|
%
|
|
100
|
%
|
|
|
|
|
|
|
|||
Total Dth of natural gas sold (in thousands)
|
17,677
|
|
|
17,600
|
|
|
15,519
|
|
Total Dth of transportation service (in thousands)
|
2,256
|
|
|
2,288
|
|
|
2,275
|
|
Total average number of retail customers (in thousands)
|
163
|
|
|
159
|
|
|
156
|
|
(1)
|
Commercial and industrial customers are classified primarily based on their natural gas usage. Commercial customers are non-residential customers with monthly gas usage less than 12,000 therms during five consecutive winter months. Industrial customers are non-residential customers that use natural gas in excess of 12,000 therms during one or more winter months.
|
|
2016
|
|
2015
|
|
2014
|
||||||||||||
Northern Powergrid (Northeast) Limited:
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Residential
|
5,227
|
|
|
36
|
%
|
|
5,144
|
|
|
34
|
%
|
|
5,161
|
|
|
34
|
%
|
Commercial
|
2,222
|
|
|
15
|
%
|
|
2,417
|
|
|
16
|
|
|
2,393
|
|
|
16
|
|
Industrial
|
6,963
|
|
|
48
|
%
|
|
7,160
|
|
|
48
|
|
|
7,181
|
|
|
48
|
|
Other
|
214
|
|
|
1
|
%
|
|
231
|
|
|
2
|
|
|
262
|
|
|
2
|
|
|
14,626
|
|
|
100
|
%
|
|
14,952
|
|
|
100
|
%
|
|
14,997
|
|
|
100
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Northern Powergrid (Yorkshire) plc:
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Residential
|
7,612
|
|
|
36
|
%
|
|
7,574
|
|
|
35
|
%
|
|
7,481
|
|
|
35
|
%
|
Commercial
|
3,116
|
|
|
15
|
%
|
|
3,352
|
|
|
16
|
|
|
3,347
|
|
|
16
|
|
Industrial
|
10,275
|
|
|
48
|
%
|
|
10,403
|
|
|
48
|
|
|
10,486
|
|
|
48
|
|
Other
|
290
|
|
|
1
|
%
|
|
299
|
|
|
1
|
|
|
322
|
|
|
1
|
|
|
21,293
|
|
|
100
|
%
|
|
21,628
|
|
|
100
|
%
|
|
21,636
|
|
|
100
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Total electricity distributed
|
35,919
|
|
|
|
|
36,580
|
|
|
|
|
36,633
|
|
|
|
|||
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Number of end-users (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Northern Powergrid (Northeast) Limited
|
1,602
|
|
|
|
|
1,597
|
|
|
|
|
1,593
|
|
|
|
|||
Northern Powergrid (Yorkshire) plc
|
2,301
|
|
|
|
|
2,294
|
|
|
|
|
2,286
|
|
|
|
|||
|
3,903
|
|
|
|
|
3,891
|
|
|
|
|
3,879
|
|
|
|
(1)
|
TransAlta Energy Marketing U.S. ("TEMUS"); EDF Energy Services, LLC ("EDF"); San Diego Gas & Electric Company ("SDG&E"); Exelon Generation Company, LLC ("EGC"); Pacific Gas and Electric Company ("PG&E"), Ameren Illinois Company ("Ameren"), Southern California Edison ("SCE"), the Philippine National Irrigation Administration ("NIA"); Hawaii Electric Light Company, Inc. ("HELCO"); Austin Energy ("AE"); Omaha Public Power District ("OPPD"); U.S. General Services Administration ("USGSA"); Missouri Joint Municipal Electric Commission ("MJMEC"); Kansas Power Pool ("KPP"); Kansas Municipal Energy Agency ("KMEA"); and City of Independence, MO ("COIMO").
|
(2)
|
Facility Net Capacity represents the lesser of nominal ratings or any limitations under applicable interconnection, power purchase, or other agreements for intermittent resources and the total net dependable capability available during summer conditions for all other units. An intermittent resource's nominal rating is the manufacturer's contractually specified capability (in MW) under specified conditions. Net Owned Capacity indicates
BHE Renewables
' ownership of Facility Net Capacity.
|
(3)
|
The majority of the Imperial Valley Projects' Contract Capacity is currently sold to Southern California Edison Company under long-term power purchase agreements expiring in 2017 through 2026. Certain long-term power purchase agreement renewals have been entered into with other parties that begin upon the existing contracts' expiration and expire in 2039.
|
(4)
|
Under the terms of the agreement with the NIA, CalEnergy Philippines will own and operate the Casecnan project for a 20-year cooperation period which ends December 11, 2021, after which ownership and operation of the project will be transferred to the NIA at no cost on an "as-is" basis. NIA also pays CalEnergy Philippines for delivery of water pursuant to the agreement.
|
(5)
|
The power purchasers are commercial, industrial and not-for-profit organizations.
|
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Solar
|
$
|
369
|
|
|
$
|
383
|
|
|
$
|
238
|
|
Wind
|
138
|
|
|
99
|
|
|
99
|
|
|||
Geothermal
|
148
|
|
|
165
|
|
|
125
|
|
|||
Hydro
|
30
|
|
|
23
|
|
|
107
|
|
|||
Natural gas
|
58
|
|
|
58
|
|
|
54
|
|
|||
Total operating revenue
|
$
|
743
|
|
|
$
|
728
|
|
|
$
|
623
|
|
|
2016
|
|
2015
|
|
2014
|
|||
|
|
|
|
|
|
|||
Illinois
|
48
|
%
|
|
51
|
%
|
|
58
|
%
|
Texas
|
13
|
|
|
15
|
|
|
17
|
|
Ohio
|
21
|
|
|
18
|
|
|
10
|
|
Maryland
|
7
|
|
|
7
|
|
|
8
|
|
Other
|
11
|
|
|
9
|
|
|
7
|
|
|
100
|
%
|
|
100
|
%
|
|
100
|
%
|
|
2016
|
|
2015
|
|
2014
|
|||
|
|
|
|
|
|
|||
Iowa
|
86
|
%
|
|
87
|
%
|
|
87
|
%
|
Illinois
|
9
|
|
|
8
|
|
|
8
|
|
Other
|
5
|
|
|
5
|
|
|
5
|
|
|
100
|
%
|
|
100
|
%
|
|
100
|
%
|
State Regulator
|
|
Base Rate Test Period
|
|
Adjustment Mechanism
|
UPSC
|
|
Forecasted or historical with known and measurable changes
(1)
|
|
EBA under which 100% (beginning in June 2016) of the difference between base net power costs set during a general rate case and actual net power costs is deferred and reflected in future rates. Wheeling revenue is also included in the mechanism. Prior to June 2016, the amount deferred was 70% of the difference as noted above.
|
|
|
|
|
|
|
|
|
|
Balancing account to provide for 100% recovery or refund of the difference between the level of REC revenues included in base rates and actual REC revenues after adjusting for a REC incentive authorized by the UPSC.
|
|
|
|
|
|
|
|
|
|
Recovery mechanism for single capital investments that in total exceed 1% of existing rate base when a general rate case has occurred within the preceding 18 months.
|
|
|
|
|
|
OPUC
|
|
Forecasted
|
|
PCAM under which 90% of the difference between forecasted net variable power costs and production tax credits established under the annual TAM and actual net variable power costs and production tax credits is deferred and reflected in future rates. The difference between the forecasted and actual net variable power costs and production tax credits must fall outside of an established asymmetrical deadband range and is also subject to an earnings test.
|
|
|
|
|
|
|
|
|
|
Annual TAM based on forecasted net variable power costs and production tax credits. Production tax credits were not included in forecasted net variable power costs prior to 2017.
|
|
|
|
|
|
|
|
|
|
Renewable Adjustment Clause to recover the revenue requirement of new renewable resources and associated transmission costs that are not reflected in general rates.
|
|
|
|
|
|
|
|
|
|
Balancing account for proceeds from the sale of RECs.
|
|
|
|
|
|
WPSC
|
|
Forecasted or historical with known and measurable changes
(1)
|
|
ECAM under which 70% of the difference between base net power costs set during a general rate case and actual net power costs is deferred and reflected in future rates. Chemical costs and start-up fuel costs are also included in the mechanism starting in 2016.
|
|
|
|
|
|
|
|
|
|
REC and sulfur dioxide revenue adjustment mechanism to provide for recovery or refund of 100% of any difference between actual REC and sulfur dioxide revenues and the level in rates.
|
|
|
|
|
|
WUTC
|
|
Historical with known and measurable changes
|
|
PCAM under which the difference between base net power costs set during a general rate case and actual net power costs is deferred and reflected in future rates after applying a $4 million deadband for positive or negative net power cost variances. For net power cost variances between $4 million and $10 million, amounts to be recovered from customers are allocated 50/50 and amounts to be credited to customers are allocated 75/25 (customers/PacifiCorp). Positive or negative net power cost variances in excess of $10 million are allocated 90/10 (customers/PacifiCorp).
|
|
|
|
|
|
|
|
|
|
Deferral mechanism of costs for up to 24 months of new base load generation resources and eligible renewable resources and related transmission that qualify under the state's emissions performance standard and are not reflected in base rates.
|
|
|
|
|
|
|
|
|
|
REC revenue tracking mechanism to provide credit of 100% of Washington-allocated REC revenues.
|
|
|
|
|
|
|
|
|
|
Decoupling mechanism under which the difference between actual annual revenues and authorized revenues per customer is deferred and reflected in future rates, subject to an earnings test. To trigger a rate adjustment, the deferral balance must exceed plus or minus 2.5% of the authorized revenue at the end of each deferral period by rate class. Rate adjustments must not exceed a surcharge of 5% of the actual normalized revenue by class.
|
|
|
|
|
|
IPUC
|
|
Historical with known and measurable changes
|
|
ECAM under which 90% of the difference between base net power costs set during a general rate case and actual net power costs is deferred and reflected in future rates. Also provides for recovery or refund of 100% of the difference between the level of REC revenues included in base rates and actual REC revenues and differences in actual production tax credits compared to the amount in base rates.
|
|
|
|
|
|
CPUC
|
|
Forecasted
|
|
PTAM for major capital additions that allows for rate adjustments outside of the context of a traditional general rate case for the revenue requirement associated with capital additions exceeding $50 million on a total-company basis. Filed as eligible capital additions are placed into service.
|
|
|
|
|
|
|
|
|
|
ECAC that allows for an annual update to actual and forecasted net power costs.
|
|
|
|
|
|
|
|
|
|
PTAM for attrition, a mechanism that allows for an annual adjustment to costs other than net power costs.
|
(1)
|
PacifiCorp has relied on both historical test periods with known and measurable adjustments, as well as forecasted test periods.
|
•
|
the actual operating and capital costs of each of the licensees;
|
•
|
the operating and capital costs that each of the licensees would incur if it were as efficient as, in Ofgem's judgment, the more efficient licensees;
|
•
|
the actual value of certain costs which are judged to be beyond the control of the licensees;
|
•
|
the taxes that each licensee is expected to pay;
|
•
|
the regulatory value ascribed to the expenditures that have been incurred in the past and the efficient expenditures that are to be incurred in the forthcoming regulatory period;
|
•
|
the rate of return to be allowed on expenditures that make up the regulatory asset value;
|
•
|
the financial ratios of each of the licensees and the license requirement for each licensee to maintain investment grade status;
|
•
|
an allowance in respect of the repair of the pension deficits in the defined benefit pension schemes sponsored by each of the licensees; and
|
•
|
any under- or over-recoveries of revenues, relative to allowed revenues, in the previous price control period.
|
•
|
the period over which new regulatory assets are depreciated is being gradually lengthened, from 20 years to 45 years, with the change being phased over eight years;
|
•
|
allowed revenues will be adjusted during the price control period, rather than at the next price control review, to partially reflect cost variances relative to cost allowances;
|
•
|
the allowed cost of debt will be updated within the price control period by reference to a long-run trailing average based on external benchmarks of utility debt costs;
|
•
|
allowed revenues will be adjusted in relation to some new service standard incentives, principally relating to speed and service standards for new connections to the network; and
|
•
|
there is scope for a mid-period review and adjustment to revenues in the latter half of the period for any changes in the outputs required of licensees for certain specified reasons.
|
•
|
regulating and adjudicating issues related to the operation of electric utilities within Alberta;
|
•
|
processing and approving general tariff applications relating to revenue requirements and rates of return including deemed capital structure for regulated utilities while ensuring that utility rates are just and reasonable and approval of the transmission tariff rates of regulated transmission providers paid by the
AESO
, which is the independent transmission system operator in Alberta, Canada that controls the operation of
ALP
's transmission system;
|
•
|
approving the need for new electricity transmission facilities and permits to build and licenses to operate electricity transmission facilities;
|
•
|
reviewing operations and accounts from electric utilities and conducting on-site inspections to ensure compliance with industry regulation and standards;
|
•
|
adjudicating enforcement issues including the imposition of administrative penalties that arise when market participants violate the rules of the
AESO
; and
|
•
|
collecting, storing, analyzing, appraising and disseminating information to effectively fulfill its duties as an industry regulator.
|
•
|
Proposed immediate tariff relief of C$415 million for customers for 2015 and 2016, through (i) the discontinuance of construction work-in-progress ("CWIP") in rate base and the return to AFUDC accounting effective January 1, 2015, resulting in a C$82 million reduction of revenue requirement and the refund of C$277 million previously collected as CWIP in rate base as part of ALP's transmission tariffs during 2011-2014 less related returns of C$12 million and (ii) a change to the flow through method for calculating income taxes for 2016, resulting in further tariff relief of C$68 million; and
|
•
|
Depreciation rates as filed, but reduced most of ALP's salvage rates to 2014 levels, which resulted in a reduction of revenue of about C$87 million over two years.
|
•
|
Pursue the construction of an additional 552 MW of new wind-powered generation in Iowa, increasing MidAmerican Energy's generating portfolio to more than 4,000 MW of wind, which is forecast to be equivalent to 63 percent of its Iowa retail sales in 2017. MidAmerican Energy surpassed its Climate Pledge commitments in 2016 and is currently proceeding with the construction of an additional 2,000 MW of new wind-powered generation in Iowa. When complete, MidAmerican Energy’s wind portfolio will include more than 6,000 MW, which is forecast to be equivalent to 89 percent of its Iowa retail sales in 2020. MidAmerican Energy owns the largest portfolio of wind-powered generating capacity in the United States among rate-regulated utilities.
|
•
|
Retire more than 75 percent of the Nevada Utilities' coal-fueled generating capacity in Nevada by 2019.
|
•
|
Add more than 1,000 MW of incremental solar and wind capacity through long-term power purchase agreements to PacifiCorp's owned 1,030 MW of wind-powered generating capacity. PacifiCorp owns the second largest portfolio of wind-powered generating capacity in the United States among rate-regulated utilities. PacifiCorp’s Climate Pledge commitments were met December 2016. The new capacity brings PacifiCorp’s non-carbon generating capacity to more than 4,500 MW, which is forecast to be equivalent to 22 percent of its retail sales in 2017.
|
•
|
Invest in transmission infrastructure in the West and Midwest to support the integration of renewable energy onto the grid.
|
•
|
Support and advance the development of markets in the West to optimize the electric grid, lower costs, enhance reliability and more effectively integrate renewable sources.
|
•
|
Additional costs may be incurred to purchase required emissions allowances under any market-based cap-and-trade system in excess of allocations that are received at no cost. These purchases would be necessary until new technologies could be developed and deployed to reduce emissions or lower carbon generation is available;
|
•
|
Acquiring and renewing construction and operating permits for new and existing generating facilities may be costly and difficult;
|
•
|
Additional costs may be incurred to purchase and deploy new generating technologies;
|
•
|
Costs may be incurred to retire existing coal-fueled generating facilities before the end of their otherwise useful lives or to convert them to burn fuels, such as natural gas or biomass, that result in lower emissions;
|
•
|
Operating costs may be higher and generating unit outputs may be lower;
|
•
|
Higher interest and financing costs and reduced access to capital markets may result to the extent that financial markets view climate change and GHG emissions as a greater business risk; and
|
•
|
The relevant Registrant's natural gas pipeline operations, electric transmission and retail sales may be impacted in response to changes in customer demand and requirements to reduce GHG emissions.
|
•
|
In June 2013, Nevada Senate Bill 123 ("SB 123") was signed into law. Among other things, SB 123 and regulations thereunder require Nevada Power to file with the PUCN an emission reduction and capacity replacement plan by May 1, 2014. In May 2014, Nevada Power filed its emissions reduction capacity replacement plan. The plan provided for the retirement or elimination of 300 MW of coal generating capacity by December 31, 2014, another 250 MW of coal generating capacity by December 31, 2017, and another 250 MW of coal generating capacity by December 31, 2019, along with replacement of such capacity with a mixture of constructed, acquired or contracted renewable and non-technology specific generating units. The plan also sets forth the expected timeline and costs associated with decommissioning coal-fired generating units that will be retired or eliminated pursuant to the plan. The PUCN has the authority to approve or modify the emission reduction and capacity replacement plan filed by Nevada Power. Given the PUCN may recommend and/or approve variations to Nevada Power's resource plans relative to requirements under SB 123, the specific impacts of SB 123 on Nevada Power cannot be determined.
|
•
|
Under the authority of California's Global Warming Solutions Act, which includes a series of policies aimed at returning California greenhouse gas emissions to 1990 levels by 2020, the California Air Resources Board adopted a GHG cap-and-trade program with an effective date of January 1, 2012; compliance obligations were imposed on entities beginning in 2013. PacifiCorp is subject to the cap-and-trade program as a retail service provider in California and an importer of wholesale energy into California. In 2015, Governor Jerry Brown issued an executive order to reduce emissions to 40% below 1990 levels by 2030 and 80% by 2050. In September 2016, California Senate Bill 32 was signed into law establishing greenhouse gas emissions reduction targets of 40% below 1990 levels by 2030.
|
•
|
The states of California, Washington and Oregon have adopted GHG emissions performance standards for base load electricity generating resources. Under the laws in California and Oregon, the emissions performance standards provide that emissions must not exceed 1,100 pounds of carbon dioxide per MWh. Effective April 2013, Washington's amended emissions performance standards provide that GHG emissions for base load electricity generating resources must not exceed 970 pounds of carbon dioxide per MWh. These GHG emissions performance standards generally prohibit electric utilities from entering into long-term financial commitments (e.g., new ownership investments, upgrades, or new or renewed contracts with a term of five or more years) unless any base load generation supplied under long-term financial commitments comply with the GHG emissions performance standards.
|
•
|
Washington and Oregon enacted legislation in May 2007 and August 2007, respectively, establishing goals for the reduction of GHG emissions in their respective states. Washington's goals seek to (a) reduce emissions to 1990 levels by 2020; (b) reduce emissions to 25% below 1990 levels by 2035; and (c) reduce emissions to 50% below 1990 levels by 2050, or 70% below Washington's forecasted emissions in 2050. Oregon's goals seek to (a) cease the growth of Oregon GHG emissions by 2010; (b) reduce GHG levels to 10% below 1990 levels by 2020; and (c) reduce GHG levels to at least 75% below 1990 levels by 2050. Each state's legislation also calls for state government to develop policy recommendations in the future to assist in the monitoring and achievement of these goals.
|
•
|
In September 2016, the Washington State Department of Ecology issued a final rule regulating GHG emissions from sources in Washington. The rule regulates greenhouse gases including carbon dioxide, methane, nitrous oxide, hydrofluorocarbons, perfluorocarbons and sulfur hexafluoride beginning in 2017 with three-year compliance periods thereafter (i.e., 2017-2019, 2020-2022, etc.). Under the rule, the Washington State Department of Ecology will establish a GHG emissions reduction pathway for all covered entities. Covered entities may use emission reduction units, which may be traded with other covered entities, to meet their compliance requirements. PacifiCorp's resources that are covered under the rule include the Chehalis generating facility, which is a natural gas combined-cycle plant located in Washington state.
|
•
|
The Regional Greenhouse Gas Initiative, a mandatory, market-based effort to reduce GHG emissions in ten Northeastern and Mid-Atlantic states, required, beginning in 2009, the reduction of carbon dioxide emissions from the power sector of 10% by 2018. In May 2011, New Jersey withdrew from participation in the Regional Greenhouse Gas Initiative. Following a program review in 2012, the nine Regional Greenhouse Gas Initiative states implemented a new 2014 cap which was approximately 45% lower than the 2012-2013 cap. The cap is reduced each year by 2.5% from 2015 to 2020. As called for in the 2012 program review, a program review was initiated for 2016 and continues through 2017 with the expectation that states will implement program changes in the fourth control period from 2018 to 2020.
|
•
|
The federal Comprehensive Environmental Response, Compensation and Liability Act and similar state laws may require any current or former owners or operators of a disposal site, as well as transporters or generators of hazardous substances sent to such disposal site, to share in environmental remediation costs.
|
•
|
The Nuclear Waste Policy Act of 1982, under which the United States Department of Energy is responsible for the selection and development of repositories for, and the permanent disposal of, spent nuclear fuel and high-level radioactive wastes. Refer to Note
13
of the Notes to Consolidated Financial Statements of Berkshire Hathaway Energy in Item 8 of this Form 10-K and Note 12 of the Notes to Financial Statements of MidAmerican Energy in Item 8 of this Form 10-K for additional information regarding MidAmerican Energy's nuclear decommissioning obligations.
|
•
|
The federal Surface Mining Control and Reclamation Act of 1977 and similar state statutes establish operational, reclamation and closure standards that must be met during and upon completion of PacifiCorp's mining activities.
|
•
|
The
FERC
evaluates hydroelectric systems to ensure environmental impacts are minimized, including the issuance of environmental impact statements for licensed projects both initially and upon relicensing. The
FERC
monitors the hydroelectric facilities for compliance with the license terms and conditions, which include environmental provisions. Refer to Note
16
of the Notes to Consolidated Financial Statements of Berkshire Hathaway Energy in Item 8 of this Form 10-K and Note 13 of the Notes to Consolidated Financial Statements of PacifiCorp in Item 8 of this Form 10-K for information regarding the relicensing of PacifiCorp's Klamath River hydroelectric system.
|
•
|
their respective earnings, capital requirements, and required debt and preferred stock payments;
|
•
|
the satisfaction of certain terms contained in financing, ring-fencing or organizational documents; and
|
•
|
regulatory restrictions that limit the ability of BHE's regulated utility subsidiaries to distribute profits.
|
•
|
senior unsecured debt of
$7.8 billion
;
|
•
|
junior subordinated debentures of
$944 million
;
|
•
|
borrowings under its commercial paper program of
$834 million
;
|
•
|
guarantees and letters of credit in respect of subsidiary and equity method investments aggregating
$460 million
; and
|
•
|
commitments, subject to satisfaction of certain specified conditions, to provide equity contributions in support of renewable tax equity investments totaling
$288 million
.
|
•
|
the failure to complete the transaction for various reasons, such as the inability to obtain the required regulatory approvals, materially adverse developments in the potential acquiree's business or financial condition or successful intervening offers by third parties;
|
•
|
the failure of the combined business to realize the expected benefits;
|
•
|
the risk that federal, state or foreign regulators or courts could require regulatory commitments or other actions in respect of acquired assets, potentially including programs, contributions, investments, divestitures and market mitigation measures;
|
•
|
the risk of unexpected or unidentified issues not discovered in the diligence process; and
|
•
|
the need for substantial additional capital and financial investments.
|
•
|
regulating and adjudicating issues related to the operation of electric utilities within Alberta;
|
•
|
processing and approving general tariff applications relating to revenue requirements and rates of return including deemed capital structure for regulated utilities while ensuring that utility rates are just and reasonable and approval of the transmission tariff rates of regulated transmission providers by the
AESO
, which is the independent transmission system operator in Alberta that controls the operation of AltaLink's transmission system;
|
•
|
approving the need for new electricity transmission facilities and permits to build and licenses to operate electricity transmission facilities;
|
•
|
reviewing operations and accounts from electric utilities and conducting on-site inspections to ensure compliance with industry regulation and standards;
|
•
|
adjudicating enforcement issues including the imposition of administrative penalties that arise when market participants violate the rules of the
AESO
; and
|
•
|
collecting, storing, analyzing, appraising and disseminating information to effectively fulfill its duties as an industry regulator.
|
•
|
a depression, recession or other adverse economic condition that results in a lower level of economic activity or reduced spending by consumers on electricity or natural gas;
|
•
|
an increase in the market price of electricity or natural gas or a decrease in the price of other competing forms of energy;
|
•
|
shifts in competitively priced natural gas supply sources away from the sources connected to the
Pipeline Companies
' systems, including shale gas sources;
|
•
|
efforts by customers, legislators and regulators to reduce the consumption of electricity generated or distributed by each Registrant through various existing laws and regulations, as well as, deregulation, conservation, energy efficiency and private generation measures and programs;
|
•
|
laws mandating or encouraging renewable energy sources, which may decrease the demand for electricity and natural gas or change the market prices of these commodities;
|
•
|
higher fuel taxes or other governmental or regulatory actions that increase, directly or indirectly, the cost of natural gas or other fuel sources for electricity generation or that limit the use of natural gas or the generation of electricity from fossil fuels;
|
•
|
a shift to more energy-efficient or alternative fuel machinery or an improvement in fuel economy, whether as a result of technological advances by manufacturers, legislation mandating higher fuel economy or lower emissions, price differentials, incentives or otherwise;
|
•
|
a reduction in the state or federal subsidies or tax incentives that are provided to agricultural, industrial or other customers, or a significant sustained change in prices for commodities such as ethanol or corn for ethanol manufacturers; and
|
•
|
sustained mild weather that reduces heating or cooling needs.
|
•
|
Operational Risk
- Operations at any nuclear power plant could degrade to the point where the plant would have to be shut down. If such degradations were to occur, the process of identifying and correcting the causes of the operational downgrade to return the plant to operation could require significant time and expense, resulting in both lost revenue and increased fuel and purchased electricity costs to meet supply commitments. Rather than incurring substantial costs to restart the plant, the plant could be shut down. Furthermore, a shut-down or failure at any other nuclear power plant could cause regulators to require a shut-down or reduced availability at Quad Cities Station.
|
•
|
Regulatory Risk
- The NRC may modify, suspend or revoke licenses and impose civil penalties for failure to comply with applicable Atomic Energy Act regulations or the terms of the licenses of nuclear facilities. Unless extended, the NRC operating licenses for Quad Cities Station will expire in 2032. Changes in regulations by the NRC could require a substantial increase in capital expenditures or result in increased operating or decommissioning costs.
|
•
|
Nuclear Accident and Catastrophic Risks
- Accidents and other unforeseen catastrophic events have occurred at nuclear facilities other than Quad Cities Station, both in the United States and elsewhere, such as at the Fukushima Daiichi nuclear power plant in Japan as a result of the earthquake and tsunami in March 2011. The consequences of an accident or catastrophic event can be severe and include loss of life and property damage. Any resulting liability from a nuclear accident or catastrophic event could exceed the relevant Registrant's resources, including insurance coverage.
|
•
|
rising interest rates or unemployment rates, including a sustained high unemployment rate in the United States;
|
•
|
periods of economic slowdown or recession in the markets served;
|
•
|
decreasing home affordability;
|
•
|
lack of available mortgage credit for potential homebuyers, such as the reduced availability of credit, which may continue into future periods;
|
•
|
inadequate home inventory levels;
|
•
|
nontraditional sources of new competition; and
|
•
|
changes in applicable tax law.
|
Item 1B.
|
Unresolved Staff Comments
|
|
|
|
|
|
|
Facility Net
|
|
Net Owned
|
Energy
|
|
|
|
|
|
Capacity
|
|
Capacity
|
Source
|
|
Entity
|
|
Location by Significance
|
|
(MW)
|
|
(MW)
|
|
|
|
|
|
|
|
|
|
Natural gas
|
|
PacifiCorp, MidAmerican Energy, NV Energy and BHE Renewables
|
|
Nevada, Utah, Iowa, Illinois, Washington, Oregon, Texas, New York and Arizona
|
|
10,917
|
|
10,508
|
|
|
|
|
|
|
|
|
|
Coal
|
|
PacifiCorp, MidAmerican Energy and NV Energy
|
|
Wyoming, Iowa, Utah, Arizona, Nevada, Colorado and Montana
|
|
16,485
|
|
9,412
|
|
|
|
|
|
|
|
|
|
Wind
|
|
PacifiCorp, MidAmerican Energy and BHE Renewables
|
|
Iowa, Wyoming, Nebraska, Washington, California, Texas, Oregon, Illinois and Kansas
|
|
6,199
|
|
6,190
|
|
|
|
|
|
|
|
|
|
Solar
|
|
BHE Renewables and NV Energy
|
|
California, Arizona, Minnesota and Nevada
|
|
1,464
|
|
1,316
|
|
|
|
|
|
|
|
|
|
Hydroelectric
|
|
PacifiCorp, MidAmerican Energy
and BHE Renewables
|
|
Washington, Oregon, The Philippines, Idaho, California, Utah, Hawaii, Montana, Illinois and Wyoming
|
|
1,297
|
|
1,275
|
|
|
|
|
|
|
|
|
|
Nuclear
|
|
MidAmerican Energy
|
|
Illinois
|
|
1,824
|
|
456
|
|
|
|
|
|
|
|
|
|
Geothermal
|
|
PacifiCorp and BHE Renewables
|
|
California and Utah
|
|
370
|
|
370
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
38,556
|
|
29,527
|
Item 4.
|
Mine Safety Disclosures
|
Item 5.
|
Market for Registrant's Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities
|
Item 6.
|
Selected Financial Data
|
Item 7.
|
Management's Discussion and Analysis of Financial Condition and Results of Operations
|
Item 7A.
|
Quantitative and Qualitative Disclosures About Market Risk
|
Item 8.
|
Financial Statements and Supplementary Data
|
Berkshire Hathaway Energy Company and its subsidiaries
|
|
|
Report of Independent Registered Public Accounting Firm
|
|
|
Consolidated Balance Sheets
|
|
|
Consolidated Statements of Operations
|
|
|
Consolidated Statements of Comprehensive Income
|
|
|
Consolidated Statements of Changes in Equity
|
|
|
Consolidated Statements of Cash Flows
|
|
|
Notes to Consolidated Financial Statements
|
|
|
PacifiCorp and its subsidiaries
|
|
|
Report of Independent Registered Public Accounting Firm
|
|
|
Consolidated Balance Sheets
|
|
|
Consolidated Statements of Operations
|
|
|
Consolidated Statements of Comprehensive Income
|
|
|
Consolidated Statements of Changes in Equity
|
|
|
Consolidated Statements of Cash Flows
|
|
|
Notes to Consolidated Financial Statements
|
|
|
MidAmerican Energy Company
|
|
|
Report of Independent Registered Public Accounting Firm
|
|
|
Balance Sheets
|
|
|
Statements of Operations
|
|
|
Statements of Comprehensive Income
|
|
|
Statements of Changes in Equity
|
|
|
Statements of Cash Flows
|
|
|
Notes to Financial Statements
|
|
|
MidAmerican Funding, LLC and its subsidiaries
|
|
|
Report of Independent Registered Public Accounting Firm
|
|
|
Consolidated Balance Sheets
|
|
|
Consolidated Statements of Operations
|
|
|
Consolidated Statements of Comprehensive Income
|
|
|
Consolidated Statements of Changes in Equity
|
|
|
Consolidated Statements of Cash Flows
|
|
|
Notes to Consolidated Financial Statements
|
|
|
Nevada Power Company and its subsidiaries
|
|
|
Report of Independent Registered Public Accounting Firm
|
|
|
Consolidated Balance Sheets
|
|
|
Consolidated Statements of Operations
|
|
|
Consolidated Statements of Changes in Shareholder's Equity
|
|
|
Consolidated Statements of Cash Flows
|
|
|
Notes to Consolidated Financial Statements
|
|
|
Sierra Pacific Power Company and its subsidiaries
|
|
|
Report of Independent Registered Public Accounting Firm
|
|
|
Consolidated Balance Sheets
|
|
|
Consolidated Statements of Operations
|
|
|
Consolidated Statements of Changes in Shareholder's Equity
|
|
|
Consolidated Statements of Cash Flows
|
|
|
Notes to Consolidated Financial Statements
|
|
Item 6.
|
Selected Financial Data
|
|
Years Ended December 31,
|
||||||||||||||||||
|
2016
(1)
|
|
2015
(1)
|
|
2014
(1)
|
|
2013
(1)
|
|
2012
|
||||||||||
Consolidated Statement of Operations Data:
|
|
|
|
|
|
|
|
|
|
||||||||||
Operating revenue
|
$
|
17,422
|
|
|
$
|
17,880
|
|
|
$
|
17,326
|
|
|
$
|
12,635
|
|
|
$
|
11,548
|
|
Net income
|
2,570
|
|
|
2,400
|
|
|
2,122
|
|
|
1,676
|
|
|
1,495
|
|
|||||
Net income attributable to BHE shareholders
|
2,542
|
|
|
2,370
|
|
|
2,095
|
|
|
1,636
|
|
|
1,472
|
|
|||||
|
|
|
|
|
|
|
|
|
|
||||||||||
|
As of December 31,
|
||||||||||||||||||
|
2016
(1)
|
|
2015
(1)
|
|
2014
(1)
|
|
2013
(1)
|
|
2012
|
||||||||||
Consolidated Balance Sheet Data:
|
|
|
|
|
|
|
|
|
|
||||||||||
Total assets
(2)(3)
|
$
|
85,440
|
|
|
$
|
83,618
|
|
|
$
|
81,816
|
|
|
$
|
69,591
|
|
|
$
|
52,212
|
|
Short-term debt
|
1,869
|
|
|
974
|
|
|
1,445
|
|
|
232
|
|
|
887
|
|
|||||
Long-term debt, including current maturities:
|
|
|
|
|
|
|
|
|
|
||||||||||
BHE senior debt
(3)
|
7,818
|
|
|
7,814
|
|
|
7,810
|
|
|
6,575
|
|
|
4,592
|
|
|||||
BHE subordinated debt
|
944
|
|
|
2,944
|
|
|
3,794
|
|
|
2,594
|
|
|
—
|
|
|||||
Subsidiary debt
(3)
|
27,354
|
|
|
27,214
|
|
|
26,848
|
|
|
22,645
|
|
|
16,007
|
|
|||||
Total BHE shareholders' equity
|
24,327
|
|
|
22,401
|
|
|
20,442
|
|
|
18,711
|
|
|
15,742
|
|
(1)
|
Reflects the completion of the AltaLink acquisition from December 1, 2014 and the NV Energy acquisition from December 19, 2013.
|
(2)
|
In December 2015, the Company retrospectively adopted Accounting Standards Update No. 2015-17, which resulted in the reclassification of certain deferred income tax balances previously recognized within other current assets in the amounts of $291 million, $211 million and $119 million, as of December 31, 2014, 2013 and 2012, respectively, as reductions in noncurrent deferred income tax liabilities.
|
(3)
|
In December 2015, the Company retrospectively adopted Accounting Standards Update 2015-03, which resulted in the reclassification of certain deferred debt issuance costs previously recognized within other assets in the amounts of $50 million, $41 million and $29 million, as of December 31, 2014, 2013 and 2012, respectively, as reductions in BHE senior debt, and certain deferred debt issuance costs previously recognized within other assets in the amounts of $147 million, $157 million and $107 million, as of December 31, 2014, 2013 and 2012, respectively, as reductions in subsidiary debt.
|
Item 7.
|
Management's Discussion and Analysis of Financial Condition and Results of Operations
|
|
2016
|
|
2015
|
|
Change
|
|
2015
|
|
2014
|
|
Change
|
||||||||||||||||||
Net income attributable to BHE shareholders:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
PacifiCorp
|
$
|
764
|
|
|
$
|
697
|
|
|
$
|
67
|
|
|
10
|
%
|
|
$
|
697
|
|
|
$
|
700
|
|
|
$
|
(3
|
)
|
|
—
|
%
|
MidAmerican Funding
|
532
|
|
|
442
|
|
|
90
|
|
|
20
|
|
|
442
|
|
|
393
|
|
|
49
|
|
|
12
|
|
||||||
NV Energy
|
359
|
|
|
379
|
|
|
(20
|
)
|
|
(5
|
)
|
|
379
|
|
|
354
|
|
|
25
|
|
|
7
|
|
||||||
Northern Powergrid
|
342
|
|
|
422
|
|
|
(80
|
)
|
|
(19
|
)
|
|
422
|
|
|
412
|
|
|
10
|
|
|
2
|
|
||||||
BHE Pipeline Group
|
249
|
|
|
243
|
|
|
6
|
|
|
2
|
|
|
243
|
|
|
230
|
|
|
13
|
|
|
6
|
|
||||||
BHE Transmission
|
214
|
|
|
186
|
|
|
28
|
|
|
15
|
|
|
186
|
|
|
56
|
|
|
130
|
|
|
*
|
|||||||
BHE Renewables
|
179
|
|
|
124
|
|
|
55
|
|
|
44
|
|
|
124
|
|
|
121
|
|
|
3
|
|
|
2
|
|
||||||
HomeServices
|
127
|
|
|
104
|
|
|
23
|
|
|
22
|
|
|
104
|
|
|
83
|
|
|
21
|
|
|
25
|
|
||||||
BHE and Other
|
(224
|
)
|
|
(227
|
)
|
|
3
|
|
|
1
|
|
|
(227
|
)
|
|
(254
|
)
|
|
27
|
|
|
11
|
|
||||||
Total net income attributable to BHE shareholders
|
$
|
2,542
|
|
|
$
|
2,370
|
|
|
$
|
172
|
|
|
7
|
|
|
$
|
2,370
|
|
|
$
|
2,095
|
|
|
$
|
275
|
|
|
13
|
|
•
|
PacifiCorp
's net income increased
$67 million
due to higher margins of $86 million, lower operations and maintenance expenses of $18 million, and higher production tax credits of $8 million, partially offset by higher depreciation and amortization of $13 million, lower
AFUDC
of $9 million and higher property taxes of $5 million. Margins increased primarily due to lower purchased electricity costs, higher retail rates, lower coal-fueled generation and lower natural gas costs, partially offset by lower wholesale electricity revenue from lower volumes and prices. Retail customer volumes decreased by 0.6% due to lower commercial customer usage in Utah and lower industrial customer usage primarily in Utah and Oregon, partially offset by an increase in the average number of residential customers in Utah and Oregon and commercial customers in Utah and the impacts of weather on residential customer volumes.
|
•
|
MidAmerican Funding
's net income increased
$90 million
due to higher electric margins of $172 million, higher production tax credits of $39 million and lower fossil-fueled generation operations and maintenance of $35 million, partially offset by higher depreciation and amortization of $72 million from wind-powered generation and other plant placed in-service and an accrual related to an Iowa regulatory revenue sharing arrangement, a pre-tax gain of $13 million in 2015 on the sale of a generating facility lease, higher interest expense of $12 million and higher income taxes from the effects of ratemaking and higher pre-tax income. Electric margins reflect higher retail sales volumes, higher retail rates in Iowa, lower energy costs, higher wholesale revenue and higher transmission revenue.
|
•
|
NV Energy
's net income decreased
$20 million
due to higher operating expense of $27 million, higher depreciation and amortization of $11 million due to higher plant in-service and lower electric margins of $2 million, partially offset by lower interest expense of $12 million. Operating expense increased due to benefits from changes in contingent liabilities in 2015 and regulatory disallowances in 2016. Electric margins decreased primarily due to lower transmission and wholesale revenue and lower customer usage offset by higher customer growth.
|
•
|
Northern Powergrid
's net income decreased
$80 million
due to the stronger United States dollar of $47 million, lower distribution revenues mainly due to the recovery in 2015 of the December 2013 customer rebate and unfavorable movements in regulatory provisions, higher depreciation of $25 million from additional assets placed in service, higher write-offs of hydrocarbon well exploration costs of $15 million and higher interest expense of $7 million. These adverse variances were partially offset by higher smart meter revenue, lower operating expenses and lower income tax expense primarily due to the resolution of income tax return claims from prior years partially offset by decreased deferred income tax benefits due to a 1% reduction in the United Kingdom corporate income tax rate in 2016 compared to a 2% reduction in 2015.
|
•
|
BHE Pipeline Group's net income increased
$6 million
due to higher storage revenues, lower operating expenses and lower interest expense due to the early redemption in December 2015 of the 6.667% Senior Notes at Kern River, partially offset by lower transportation revenues and higher depreciation expense.
|
•
|
BHE Transmission
's net income increased
$28 million
from higher earnings at AltaLink of $22 million and at BHE U.S. Transmission of $6 million. Earnings at AltaLink increased primarily due to additional assets placed in-service and favorable regulatory decisions, partially offset by a $26 million pre-tax impairment related to nonregulated natural gas-fueled generation assets and the stronger United States dollar of $5 million. BHE U.S. Transmission's earnings improved primarily from higher equity earnings at Electric Transmission Texas, LLC from continued investment and additional plant placed in-service.
|
•
|
BHE Renewables' net income increased
$55 million
due to three tax equity investments reaching commercial operations in 2016 and higher production at wind projects, including additional capacity placed in-service in 2016 at two projects, partially offset by lower solar revenues mainly due to forced outages and higher depreciation expense due to additional wind and solar capacity placed in-service.
|
•
|
HomeServices
' net income increased
$23 million
due to a 9% increase in closed brokerage units, primarily due to acquired brokerage businesses, a 2% increase in average home sales prices and higher earnings at existing mortgage and franchise businesses.
|
•
|
BHE and Other
net loss improved
$3 million
due to lower interest expense, an increase in consolidated deferred state income tax benefits and higher investment returns, partially offset by higher United States income taxes on foreign earnings.
|
•
|
PacifiCorp
's net income decreased
$3 million
due to the recognition of insurance recoveries for a fire claim in 2014, higher depreciation and amortization of $35 million, lower AFUDC of $25 million and higher property taxes, partially offset by higher margins of $109 million and lower production tax credits of $9 million. Margins increased primarily due to higher retail rates, lower purchased electricity prices, lower natural gas generation and costs, Utah mine disposition costs in 2014 and lower coal generation, partially offset by higher purchased electricity volumes, lower wholesale electricity revenue from lower volumes and prices and lower retail customer volumes. Customer volumes decreased 0.7% due to lower industrial customer usage in Utah and Wyoming and lower residential customer usage across the service territory, partially offset by an increase in the average number of residential customers in Utah and Oregon, an increase in the average number of commercial customers in Utah and the impacts of weather on residential, commercial and irrigation customer volumes.
|
•
|
MidAmerican Funding
's net income increased
$49 million
due to higher regulated electric margins of $119 million, higher production tax credits of $27 million and lower fossil-fueled generation maintenance of $10 million, partially offset by higher depreciation and amortization of $56 million due to wind-powered generation and other plant placed in-service, lower
AFUDC
of $27 million, lower regulated natural gas margins of $12 million due to warmer temperatures in 2015 and higher interest expense of $9 million due to the issuance of first mortgage bonds in April 2014 and October 2015. Regulated electric margins increased primarily due to higher retail rates in Iowa and changes in rate structure related to seasonal pricing, lower purchased power costs, a lower average cost of fuel for generation and higher transmission revenue, partially offset by lower wholesale revenue. Electric retail customer volumes increased 1.2% as a result of strong industrial growth, partially offset by warmer winter temperatures compared to 2014.
|
•
|
NV Energy
's net income increased
$25 million
due to higher electric margins of $76 million and lower interest expense of $21 million, partially offset by higher depreciation and amortization of $31 million due to higher regulatory amortizations and higher operating expense of $30 million, primarily related to energy efficiency costs. Electric margins increased primarily due to higher electric retail customer volumes of 2.4% from increased customer usage and growth and the impacts of weather.
|
•
|
Northern Powergrid
's net income increased
$10 million
due to income tax benefits of $41 million from a 2% reduction in the United Kingdom corporate income tax rate, higher distribution revenue from recovery of the December 2013 customer rebate and favorable movements in regulatory provisions, and lower write-offs of hydrocarbon well exploration costs of $22 million, partially offset by lower tariff rates and distributed units and the stronger United States dollar of $34 million.
|
•
|
BHE Pipeline Group's net income increased
$13 million
due to lower operating expenses of $28 million primarily at Northern Natural Gas as a result of lower in-line inspection, hydrostatic testing and other maintenance project costs and higher transportation revenues of $7 million, partially offset by higher depreciation expense of $8 million and lower other income of $6 million due to a contract restructuring at Northern Natural Gas that expired in 2015.
|
•
|
BHE Transmission
's net income increased
$130 million
from higher earnings at AltaLink of $120 million due to the acquisition of AltaLink on December 1, 2014, and at BHE U.S. Transmission of $10 million primarily related to lower acquisition and project development costs.
|
•
|
BHE Renewables
' net income increased
$3 million
due to higher earnings of $18 million from solar projects primarily due to additional solar capacity at the Solar Star and Topaz Projects being placed in-service, partially offset by lower earnings of $18 million at CE Generation due to lower revenue from lower short run avoided cost pricing.
|
•
|
HomeServices
' net income increased
$21 million
due to higher earnings at existing brokerage, mortgage and franchise businesses, due to higher closed units, and acquired brokerage businesses, partially offset by $12 million of gains in 2014 from the acquisition of interests in equity method investments.
|
•
|
BHE and Other
net loss improved
$27 million
due to lower income tax expense from favorable consolidated deferred state income tax benefits and United States income taxes on foreign earnings, partially offset by higher interest expense from debt issuances in the fourth quarter of 2014.
|
|
2016
|
|
2015
|
|
Change
|
|
2015
|
|
2014
|
|
Change
|
||||||||||||||||||
Operating revenue:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
PacifiCorp
|
$
|
5,201
|
|
|
$
|
5,232
|
|
|
$
|
(31
|
)
|
|
(1
|
)%
|
|
$
|
5,232
|
|
|
$
|
5,252
|
|
|
$
|
(20
|
)
|
|
—
|
%
|
MidAmerican Funding
|
2,631
|
|
|
2,515
|
|
|
116
|
|
|
5
|
|
|
2,515
|
|
|
2,844
|
|
|
(329
|
)
|
|
(12
|
)
|
||||||
NV Energy
|
2,895
|
|
|
3,351
|
|
|
(456
|
)
|
|
(14
|
)
|
|
3,351
|
|
|
3,241
|
|
|
110
|
|
|
3
|
|
||||||
Northern Powergrid
|
995
|
|
|
1,140
|
|
|
(145
|
)
|
|
(13
|
)
|
|
1,140
|
|
|
1,283
|
|
|
(143
|
)
|
|
(11
|
)
|
||||||
BHE Pipeline Group
|
978
|
|
|
1,016
|
|
|
(38
|
)
|
|
(4
|
)
|
|
1,016
|
|
|
1,078
|
|
|
(62
|
)
|
|
(6
|
)
|
||||||
BHE Transmission
|
502
|
|
|
592
|
|
|
(90
|
)
|
|
(15)
|
|
592
|
|
|
62
|
|
|
530
|
|
|
*
|
||||||||
BHE Renewables
|
743
|
|
|
728
|
|
|
15
|
|
|
2
|
|
|
728
|
|
|
623
|
|
|
105
|
|
|
17
|
|
||||||
HomeServices
|
2,801
|
|
|
2,526
|
|
|
275
|
|
|
11
|
|
|
2,526
|
|
|
2,144
|
|
|
382
|
|
|
18
|
|
||||||
BHE and Other
|
676
|
|
|
780
|
|
|
(104
|
)
|
|
(13
|
)
|
|
780
|
|
|
799
|
|
|
(19
|
)
|
|
(2
|
)
|
||||||
Total operating revenue
|
$
|
17,422
|
|
|
$
|
17,880
|
|
|
$
|
(458
|
)
|
|
(3
|
)
|
|
$
|
17,880
|
|
|
$
|
17,326
|
|
|
$
|
554
|
|
|
3
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Operating income:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
PacifiCorp
|
$
|
1,427
|
|
|
$
|
1,344
|
|
|
$
|
83
|
|
|
6
|
%
|
|
$
|
1,344
|
|
|
$
|
1,308
|
|
|
$
|
36
|
|
|
3
|
%
|
MidAmerican Funding
|
566
|
|
|
451
|
|
|
115
|
|
|
25
|
|
|
451
|
|
|
395
|
|
|
56
|
|
|
14
|
|
||||||
NV Energy
|
770
|
|
|
812
|
|
|
(42
|
)
|
|
(5
|
)
|
|
812
|
|
|
791
|
|
|
21
|
|
|
3
|
|
||||||
Northern Powergrid
|
494
|
|
|
593
|
|
|
(99
|
)
|
|
(17
|
)
|
|
593
|
|
|
674
|
|
|
(81
|
)
|
|
(12
|
)
|
||||||
BHE Pipeline Group
|
455
|
|
|
464
|
|
|
(9
|
)
|
|
(2
|
)
|
|
464
|
|
|
439
|
|
|
25
|
|
|
6
|
|
||||||
BHE Transmission
|
92
|
|
|
260
|
|
|
(168
|
)
|
|
(65)
|
|
260
|
|
|
16
|
|
|
244
|
|
|
*
|
||||||||
BHE Renewables
|
256
|
|
|
255
|
|
|
1
|
|
|
—
|
|
|
255
|
|
|
314
|
|
|
(59
|
)
|
|
(19
|
)
|
||||||
HomeServices
|
212
|
|
|
184
|
|
|
28
|
|
|
15
|
|
|
184
|
|
|
125
|
|
|
59
|
|
|
47
|
|
||||||
BHE and Other
|
(21
|
)
|
|
(35
|
)
|
|
14
|
|
|
40
|
|
|
(35
|
)
|
|
(16
|
)
|
|
(19
|
)
|
|
*
|
|||||||
Total operating income
|
$
|
4,251
|
|
|
$
|
4,328
|
|
|
$
|
(77
|
)
|
|
(2
|
)
|
|
$
|
4,328
|
|
|
$
|
4,046
|
|
|
$
|
282
|
|
|
7
|
|
|
2016
|
|
2015
|
|
Change
|
|
2015
|
|
2014
|
|
Change
|
||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||||||
Subsidiary debt
|
$
|
1,378
|
|
|
$
|
1,392
|
|
|
$
|
(14
|
)
|
|
(1
|
)%
|
|
$
|
1,392
|
|
|
$
|
1,280
|
|
|
$
|
112
|
|
|
9
|
%
|
BHE senior debt and other
|
411
|
|
|
408
|
|
|
3
|
|
|
1
|
|
|
408
|
|
|
353
|
|
|
55
|
|
|
16
|
|
||||||
BHE junior subordinated debentures
|
65
|
|
|
104
|
|
|
(39
|
)
|
|
(38
|
)
|
|
104
|
|
|
78
|
|
|
26
|
|
|
33
|
|
||||||
Total interest expense
|
$
|
1,854
|
|
|
$
|
1,904
|
|
|
$
|
(50
|
)
|
|
(3
|
)
|
|
$
|
1,904
|
|
|
$
|
1,711
|
|
|
$
|
193
|
|
|
11
|
|
|
2016
|
|
2015
|
|
Change
|
|
2015
|
|
2014
|
|
Change
|
||||||||||||||||||
Equity income:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
ETT
|
$
|
95
|
|
|
$
|
81
|
|
|
$
|
14
|
|
|
17
|
%
|
|
$
|
81
|
|
|
$
|
80
|
|
|
$
|
1
|
|
|
1
|
%
|
Agua Caliente
|
25
|
|
|
24
|
|
|
1
|
|
|
4
|
|
|
24
|
|
|
27
|
|
|
(3
|
)
|
|
(11
|
)
|
||||||
CE Generation
|
—
|
|
|
—
|
|
|
—
|
|
|
*
|
|
|
—
|
|
|
(8
|
)
|
|
8
|
|
|
*
|
|
||||||
HomeServices
|
6
|
|
|
6
|
|
|
—
|
|
|
*
|
|
|
6
|
|
|
2
|
|
|
4
|
|
|
*
|
|
||||||
Other
|
(3
|
)
|
|
4
|
|
|
(7
|
)
|
|
*
|
|
|
4
|
|
|
8
|
|
|
(4
|
)
|
|
(50
|
)
|
||||||
Total equity income (loss)
|
$
|
123
|
|
|
$
|
115
|
|
|
$
|
8
|
|
|
7
|
|
|
$
|
115
|
|
|
$
|
109
|
|
|
$
|
6
|
|
|
6
|
|
|
|
|
|
|
MidAmerican
|
|
NV
|
|
Northern
|
|
|
|
|
|
|
||||||||||||||||
|
BHE
|
|
PacifiCorp
|
|
Funding
|
|
Energy
|
|
Powergrid
|
|
AltaLink
|
|
Other
|
|
Total
|
||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||||
Cash and cash equivalents
|
$
|
33
|
|
|
$
|
17
|
|
|
$
|
15
|
|
|
$
|
330
|
|
|
$
|
65
|
|
|
$
|
10
|
|
|
$
|
251
|
|
|
$
|
721
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Credit facilities
|
2,000
|
|
|
1,000
|
|
|
609
|
|
|
650
|
|
|
185
|
|
|
986
|
|
|
915
|
|
|
6,345
|
|
||||||||
Less:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||
Short-term debt
|
(834
|
)
|
|
(270
|
)
|
|
(99
|
)
|
|
—
|
|
|
—
|
|
|
(289
|
)
|
|
(377
|
)
|
|
(1,869
|
)
|
||||||||
Tax-exempt bond support and letters of credit
|
(7
|
)
|
|
(142
|
)
|
|
(220
|
)
|
|
(80
|
)
|
|
—
|
|
|
(8
|
)
|
|
—
|
|
|
(457
|
)
|
||||||||
Net credit facilities
|
1,159
|
|
|
588
|
|
|
290
|
|
|
570
|
|
|
185
|
|
|
689
|
|
|
538
|
|
|
4,019
|
|
||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||||
Total net liquidity
|
$
|
1,192
|
|
|
$
|
605
|
|
|
$
|
305
|
|
|
$
|
900
|
|
|
$
|
250
|
|
|
$
|
699
|
|
|
$
|
789
|
|
|
$
|
4,740
|
|
Credit facilities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Maturity dates
|
2019
|
|
|
2018, 2019
|
|
|
2017, 2018
|
|
|
2018
|
|
|
2020
|
|
|
2017, 2018, 2021
|
|
|
2017, 2018
|
|
|
|
|
|
Historical
|
|
Forecast
|
||||||||||||||||||||
|
2014
|
|
2015
|
|
2016
|
|
2017
|
|
2018
|
|
2019
|
||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
PacifiCorp
|
$
|
1,066
|
|
|
$
|
916
|
|
|
$
|
903
|
|
|
$
|
850
|
|
|
$
|
985
|
|
|
$
|
1,620
|
|
MidAmerican Funding
|
1,527
|
|
|
1,448
|
|
|
1,637
|
|
|
1,852
|
|
|
1,525
|
|
|
1,780
|
|
||||||
NV Energy
|
558
|
|
|
571
|
|
|
529
|
|
|
457
|
|
|
385
|
|
|
376
|
|
||||||
Northern Powergrid
|
675
|
|
|
674
|
|
|
579
|
|
|
626
|
|
|
520
|
|
|
420
|
|
||||||
BHE Pipeline Group
|
257
|
|
|
240
|
|
|
226
|
|
|
305
|
|
|
217
|
|
|
309
|
|
||||||
BHE Transmission
|
222
|
|
|
966
|
|
|
466
|
|
|
369
|
|
|
290
|
|
|
234
|
|
||||||
BHE Renewables
|
2,221
|
|
|
1,034
|
|
|
719
|
|
|
741
|
|
|
76
|
|
|
86
|
|
||||||
HomeServices
|
17
|
|
|
16
|
|
|
20
|
|
|
30
|
|
|
20
|
|
|
18
|
|
||||||
BHE and Other
|
12
|
|
|
10
|
|
|
11
|
|
|
21
|
|
|
19
|
|
|
16
|
|
||||||
Total
|
$
|
6,555
|
|
|
$
|
5,875
|
|
|
$
|
5,090
|
|
|
$
|
5,251
|
|
|
$
|
4,037
|
|
|
$
|
4,859
|
|
|
Historical
|
|
Forecast
|
||||||||||||||||||||
|
2014
|
|
2015
|
|
2016
|
|
2017
|
|
2018
|
|
2019
|
||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Wind generation
|
$
|
1,052
|
|
|
$
|
1,177
|
|
|
$
|
1,712
|
|
|
$
|
1,166
|
|
|
$
|
1,197
|
|
|
$
|
2,178
|
|
Solar generation
|
1,896
|
|
|
786
|
|
|
69
|
|
|
654
|
|
|
18
|
|
|
2
|
|
||||||
Electric transmission
|
547
|
|
|
936
|
|
|
448
|
|
|
393
|
|
|
247
|
|
|
160
|
|
||||||
Environmental
|
258
|
|
|
134
|
|
|
70
|
|
|
139
|
|
|
102
|
|
|
23
|
|
||||||
Other developmental projects
|
178
|
|
|
63
|
|
|
48
|
|
|
197
|
|
|
42
|
|
|
174
|
|
||||||
Other operating
|
2,624
|
|
|
2,779
|
|
|
2,743
|
|
|
2,702
|
|
|
2,431
|
|
|
2,322
|
|
||||||
Total
|
$
|
6,555
|
|
|
$
|
5,875
|
|
|
$
|
5,090
|
|
|
$
|
5,251
|
|
|
$
|
4,037
|
|
|
$
|
4,859
|
|
•
|
Wind generation includes the following:
|
◦
|
Construction of wind-powered generating facilities at MidAmerican Energy totaling
$943 million
for
2016
,
$931 million
for
2015
and
$767 million
for
2014
. MidAmerican Energy placed in-service 600 MW (nominal ratings) during
2016
, 608 MW (nominal ratings) during
2015
and 511 MW (nominal ratings) during
2014
. In August 2016, the IUB issued an order approving ratemaking principles related to MidAmerican Energy's construction of up to 2,000 MW (nominal ratings) of additional wind-powered generating facilities expected to be placed in-service in 2017 through 2019. MidAmerican Energy expects to spend $826 million in 2017, $853 million in 2018 and $1.4 billion in 2019 for these additional wind-powered generating facilities. The ratemaking principles establish a cost cap of $3.6 billion, including AFUDC, and a fixed rate of return on equity of 11.0% over the proposed 40-year useful lives of those facilities in any future Iowa rate proceeding. The cost cap ensures that as long as total costs are below the cap, the investment will be deemed prudent in any future Iowa rate proceeding. Additionally, the ratemaking principles modify the revenue sharing mechanism currently in effect. The revised sharing mechanism will be effective in 2018 and will be triggered each year by actual equity returns if they are above the weighted average return on equity for MidAmerican Energy calculated annually. Pursuant to the change in revenue sharing, MidAmerican Energy will share 100% of the revenue in excess of this trigger with customers. Such revenue sharing will reduce coal and nuclear generation rate base, which is intended to mitigate future base rate increases. MidAmerican Energy expects all of these wind-powered generating facilities to qualify for 100% of federal production tax credits available.
|
◦
|
Construction of wind-powered generating facilities at BHE Renewables totaling $456 million for 2016, $246 million for 2015, and $286 million for 2014. The Marshall Wind Project with a total capacity of 72 MW achieved commercial operation in April 2016 and the Grande Prairie Wind Project with a total capacity of 400 MW achieved commercial operation in November 2016. The Jumbo Road Project with a total capacity of 300 MW achieved commercial operation in April 2015.
|
◦
|
Equipment purchases totaling $324 million in 2016 for the purposes of repowering certain existing wind-powered generating facilities at PacifiCorp and MidAmerican Energy and the construction of new wind-powered generating facilities at PacifiCorp and BHE Renewables. The repowering projects entail the replacement of significant components of older turbines. Planned spending for the repowered and new wind-powered generating facilities totals $323 million in 2017, $313 million in 2018 and $740 million in 2019. The energy production from the repowered and the new facilities is expected to qualify for 100% of the federal renewable electricity production tax credits available for ten years once the equipment is placed in-service.
|
•
|
Solar generation includes the following:
|
◦
|
BHE Solar acquired the 110-MW Alamo 6 project located in Texas in January 2017 for approximately $385 million.
|
◦
|
BHE Solar spent $56 million in 2016 and $3 million in 2015 for construction of the community solar gardens in Minnesota and expects to spend an additional $153 million in 2017 and $6 million in 2018. The completed project will be comprised of 28 locations with a nominal facilities capacity of 96 MW.
|
◦
|
Construction of the Solar Star Projects totaling
$10 million
for
2016
,
$689 million
for
2015
and
$1.1 billion
for
2014
. Both projects declared July 1, 2015 as the commercial operation date in accordance with the power purchase agreements. Final completion under the engineering, procurement and construction agreements occurred November 30, 2015 and project completion was achieved under the financing documents on December 15, 2015.
|
◦
|
Construction of the Topaz Project totaling
$49 million
for
2015
and
$814 million
for
2014
. Final completion under the engineering, procurement and construction agreement occurred February 28, 2015, and project completion was achieved under the financing documents on March 30, 2015.
|
•
|
Electric transmission includes investments for ALP's transmission system including directly assigned projects from the
AESO
, PacifiCorp's costs primarily associated with main grid reinforcement and the Energy Gateway Transmission Expansion Program and MidAmerican Energy's MVPs approved by the MISO for the construction of approximately 250 miles of 345 kV transmission line located in Iowa and Illinois.
|
•
|
Environmental includes the installation of new or the replacement of existing emissions control equipment at certain generating facilities at the Utilities, including installation or upgrade of selective catalytic reduction control systems and low nitrogen oxide burners to reduce nitrogen oxides, particulate matter control systems, sulfur dioxide emissions control systems and mercury emissions control systems, as well as expenditures for the management of coal combustion residuals.
|
•
|
Other operating includes ongoing distribution systems infrastructure needed at the Utilities and Northern Powergrid and investments in routine expenditures for generation, transmission, distribution and other infrastructure needed to serve existing and expected demand.
|
|
|
Payments Due By Periods
|
||||||||||||||||||
|
|
|
|
2018-
|
|
2020-
|
|
2022 and
|
|
|
||||||||||
|
|
2017
|
|
2019
|
|
2021
|
|
After
|
|
Total
|
||||||||||
|
|
|
|
|
|
|
|
|
|
|
||||||||||
BHE senior debt
|
|
$
|
400
|
|
|
$
|
1,000
|
|
|
$
|
350
|
|
|
$
|
6,125
|
|
|
$
|
7,875
|
|
BHE junior subordinated debentures
|
|
—
|
|
|
—
|
|
|
—
|
|
|
944
|
|
|
944
|
|
|||||
Subsidiary debt
|
|
606
|
|
|
4,643
|
|
|
2,025
|
|
|
20,202
|
|
|
27,476
|
|
|||||
Interest payments on long-term debt
(1)
|
|
1,789
|
|
|
3,257
|
|
|
2,853
|
|
|
18,269
|
|
|
26,168
|
|
|||||
Short-term debt
|
|
1,869
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
1,869
|
|
|||||
Fuel, capacity and transmission contract commitments
(1)
|
|
2,370
|
|
|
2,995
|
|
|
2,218
|
|
|
10,053
|
|
|
17,636
|
|
|||||
Construction commitments
(1)
|
|
852
|
|
|
115
|
|
|
2
|
|
|
4
|
|
|
973
|
|
|||||
Operating leases and easements
(1)
|
|
141
|
|
|
223
|
|
|
160
|
|
|
1,085
|
|
|
1,609
|
|
|||||
Other
(1)
|
|
339
|
|
|
496
|
|
|
435
|
|
|
871
|
|
|
2,141
|
|
|||||
Total contractual cash obligations
|
|
$
|
8,366
|
|
|
$
|
12,729
|
|
|
$
|
8,043
|
|
|
$
|
57,553
|
|
|
$
|
86,691
|
|
(1)
|
Not reflected on the Consolidated Balance Sheets.
|
|
Domestic Plans
|
|
|
||||||||||||||||||||
|
|
|
|
|
Other Postretirement
|
|
United Kingdom
|
||||||||||||||||
|
Pension Plans
|
|
Benefit Plans
|
|
Pension Plan
|
||||||||||||||||||
|
+0.5%
|
|
-0.5%
|
|
+0.5%
|
|
-0.5%
|
|
+0.5%
|
|
-0.5%
|
||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Effect on December 31, 2016
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Benefit Obligations:
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Discount rate
|
$
|
(147
|
)
|
|
$
|
163
|
|
|
$
|
(31
|
)
|
|
$
|
34
|
|
|
$
|
(189
|
)
|
|
$
|
216
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Effect on 2016 Periodic Cost:
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Discount rate
|
$
|
(6
|
)
|
|
$
|
6
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
(16
|
)
|
|
$
|
16
|
|
Expected rate of return on plan assets
|
(12
|
)
|
|
12
|
|
|
(3
|
)
|
|
3
|
|
|
(9
|
)
|
|
9
|
|
Item 7A.
|
Quantitative and Qualitative Disclosures About Market Risk
|
|
Fair Value -
|
|
Estimated Fair Value after
|
||||||||
|
Net Asset
|
|
Hypothetical Change in Price
|
||||||||
|
(Liability)
|
|
10% increase
|
|
10% decrease
|
||||||
As of December 31, 2016:
|
|
|
|
|
|
||||||
Not designated as hedging contracts
|
$
|
(71
|
)
|
|
$
|
(37
|
)
|
|
$
|
(105
|
)
|
Designated as hedging contracts
|
(16
|
)
|
|
19
|
|
|
(51
|
)
|
|||
Total commodity derivative contracts
|
$
|
(87
|
)
|
|
$
|
(18
|
)
|
|
$
|
(156
|
)
|
|
|
|
|
|
|
||||||
As of December 31, 2015
|
|
|
|
|
|
||||||
Not designated as hedging contracts
|
$
|
(186
|
)
|
|
$
|
(148
|
)
|
|
$
|
(224
|
)
|
Designated as hedging contracts
|
(47
|
)
|
|
(4
|
)
|
|
(89
|
)
|
|||
Total commodity derivative contracts
|
$
|
(233
|
)
|
|
$
|
(152
|
)
|
|
$
|
(313
|
)
|
|
|
|
|
|
Estimated
|
|
Hypothetical
|
|||||
|
|
|
Hypothetical
|
|
Fair Value after
|
|
Percentage Increase
|
|||||
|
Fair
|
|
Price
|
|
Hypothetical
|
|
(Decrease) in BHE
|
|||||
|
Value
|
|
Change
|
|
Change in Prices
|
|
Shareholders' Equity
|
|||||
|
|
|
|
|
|
|
|
|||||
As of December 31, 2016
|
$
|
1,185
|
|
|
30% increase
|
|
$
|
1,541
|
|
|
1
|
%
|
|
|
|
30% decrease
|
|
830
|
|
|
(1
|
)
|
|||
|
|
|
|
|
|
|
|
|||||
As of December 31, 2015
|
$
|
1,238
|
|
|
30% increase
|
|
$
|
1,609
|
|
|
1
|
%
|
|
|
|
30% decrease
|
|
867
|
|
|
(1
|
)
|
Item 8.
|
Financial Statements and Supplementary Data
|
|
||
|
|
|
|
||
|
|
|
|
||
|
|
|
|
||
|
|
|
|
||
|
|
|
|
||
|
|
|
|
/s/
|
Deloitte & Touche LLP
|
|
As of December 31,
|
||||||
|
2016
|
|
2015
|
||||
LIABILITIES AND EQUITY
|
|||||||
Current liabilities:
|
|
|
|
||||
Accounts payable
|
$
|
1,317
|
|
|
$
|
1,564
|
|
Accrued interest
|
454
|
|
|
469
|
|
||
Accrued property, income and other taxes
|
389
|
|
|
372
|
|
||
Accrued employee expenses
|
261
|
|
|
264
|
|
||
Regulatory liabilities
|
187
|
|
|
402
|
|
||
Short-term debt
|
1,869
|
|
|
974
|
|
||
Current portion of long-term debt
|
1,006
|
|
|
1,148
|
|
||
Other current liabilities
|
830
|
|
|
896
|
|
||
Total current liabilities
|
6,313
|
|
|
6,089
|
|
||
|
|
|
|
||||
Regulatory liabilities
|
2,933
|
|
|
2,631
|
|
||
BHE senior debt
|
7,418
|
|
|
7,814
|
|
||
BHE junior subordinated debentures
|
944
|
|
|
2,944
|
|
||
Subsidiary debt
|
26,748
|
|
|
26,066
|
|
||
Deferred income taxes
|
13,879
|
|
|
12,685
|
|
||
Other long-term liabilities
|
2,742
|
|
|
2,854
|
|
||
Total liabilities
|
60,977
|
|
|
61,083
|
|
||
|
|
|
|
||||
Commitments and contingencies (Note 16)
|
|
|
|
||||
|
|
|
|
||||
Equity:
|
|
|
|
||||
BHE shareholders' equity:
|
|
|
|
||||
Common stock - 115 shares authorized, no par value, 77 shares issued and outstanding
|
—
|
|
|
—
|
|
||
Additional paid-in capital
|
6,390
|
|
|
6,403
|
|
||
Retained earnings
|
19,448
|
|
|
16,906
|
|
||
Accumulated other comprehensive loss, net
|
(1,511
|
)
|
|
(908
|
)
|
||
Total BHE shareholders' equity
|
24,327
|
|
|
22,401
|
|
||
Noncontrolling interests
|
136
|
|
|
134
|
|
||
Total equity
|
24,463
|
|
|
22,535
|
|
||
|
|
|
|
|
|||
Total liabilities and equity
|
$
|
85,440
|
|
|
$
|
83,618
|
|
|
Years Ended December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
Operating revenue:
|
|
|
|
|
|
||||||
Energy
|
$
|
14,621
|
|
|
$
|
15,354
|
|
|
$
|
15,182
|
|
Real estate
|
2,801
|
|
|
2,526
|
|
|
2,144
|
|
|||
Total operating revenue
|
17,422
|
|
|
17,880
|
|
|
17,326
|
|
|||
|
|
|
|
|
|
||||||
Operating costs and expenses:
|
|
|
|
|
|
||||||
Energy:
|
|
|
|
|
|
||||||
Cost of sales
|
4,315
|
|
|
5,079
|
|
|
5,732
|
|
|||
Operating expense
|
3,707
|
|
|
3,732
|
|
|
3,501
|
|
|||
Depreciation and amortization
|
2,560
|
|
|
2,399
|
|
|
2,028
|
|
|||
Real estate
|
2,589
|
|
|
2,342
|
|
|
2,019
|
|
|||
Total operating costs and expenses
|
13,171
|
|
|
13,552
|
|
|
13,280
|
|
|||
|
|
|
|
|
|
|
|||||
Operating income
|
4,251
|
|
|
4,328
|
|
|
4,046
|
|
|||
|
|
|
|
|
|
||||||
Other income (expense):
|
|
|
|
|
|
||||||
Interest expense
|
(1,854
|
)
|
|
(1,904
|
)
|
|
(1,711
|
)
|
|||
Capitalized interest
|
139
|
|
|
74
|
|
|
89
|
|
|||
Allowance for equity funds
|
158
|
|
|
91
|
|
|
98
|
|
|||
Interest and dividend income
|
120
|
|
|
107
|
|
|
38
|
|
|||
Other, net
|
36
|
|
|
39
|
|
|
42
|
|
|||
Total other income (expense)
|
(1,401
|
)
|
|
(1,593
|
)
|
|
(1,444
|
)
|
|||
|
|
|
|
|
|
||||||
Income before income tax expense and equity income
|
2,850
|
|
|
2,735
|
|
|
2,602
|
|
|||
Income tax expense
|
403
|
|
|
450
|
|
|
589
|
|
|||
Equity income
|
123
|
|
|
115
|
|
|
109
|
|
|||
Net income
|
2,570
|
|
|
2,400
|
|
|
2,122
|
|
|||
Net income attributable to noncontrolling interests
|
28
|
|
|
30
|
|
|
27
|
|
|||
Net income attributable to BHE shareholders
|
$
|
2,542
|
|
|
$
|
2,370
|
|
|
$
|
2,095
|
|
|
Years Ended December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Net income
|
$
|
2,570
|
|
|
$
|
2,400
|
|
|
$
|
2,122
|
|
|
|
|
|
|
|
||||||
Other comprehensive loss, net of tax:
|
|
|
|
|
|
||||||
Unrecognized amounts on retirement benefits, net of tax of
$11, $17 and $19
|
(9
|
)
|
|
52
|
|
|
69
|
|
|||
Foreign currency translation adjustment
|
(583
|
)
|
|
(680
|
)
|
|
(314
|
)
|
|||
Unrealized (losses) gains on available-for-sale securities, net of tax of
$(19), $129 and $(84)
|
(30
|
)
|
|
225
|
|
|
(134
|
)
|
|||
Unrealized gains (losses) on cash flow hedges, net of tax of
$13, $(7) and $(13)
|
19
|
|
|
(11
|
)
|
|
(18
|
)
|
|||
Total other comprehensive loss, net of tax
|
(603
|
)
|
|
(414
|
)
|
|
(397
|
)
|
|||
|
|
|
|
|
|
|
|||||
Comprehensive income
|
1,967
|
|
|
1,986
|
|
|
1,725
|
|
|||
Comprehensive income attributable to noncontrolling interests
|
28
|
|
|
30
|
|
|
27
|
|
|||
Comprehensive income attributable to BHE shareholders
|
$
|
1,939
|
|
|
$
|
1,956
|
|
|
$
|
1,698
|
|
|
BHE Shareholders' Equity
|
|
|
|
|
|||||||||||||||||||||
|
|
|
|
|
|
|
|
|
Accumulated
|
|
|
|
|
|||||||||||||
|
|
|
|
|
Additional
|
|
|
|
Other
|
|
|
|
|
|||||||||||||
|
Common
|
|
Paid-in
|
|
Retained
|
|
Comprehensive
|
|
Noncontrolling
|
|
Total
|
|||||||||||||||
|
Shares
|
|
Stock
|
|
Capital
|
|
Earnings
|
|
Loss, Net
|
|
Interests
|
|
Equity
|
|||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||
Balance, December 31, 2013
|
77
|
|
|
$
|
—
|
|
|
$
|
6,390
|
|
|
$
|
12,418
|
|
|
$
|
(97
|
)
|
|
$
|
105
|
|
|
$
|
18,816
|
|
Net income
|
—
|
|
|
—
|
|
|
—
|
|
|
2,095
|
|
|
—
|
|
|
17
|
|
|
2,112
|
|
||||||
Other comprehensive loss
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(397
|
)
|
|
—
|
|
|
(397
|
)
|
||||||
Distributions
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(22
|
)
|
|
(22
|
)
|
||||||
Other equity transactions
|
—
|
|
|
—
|
|
|
33
|
|
|
—
|
|
|
—
|
|
|
31
|
|
|
64
|
|
||||||
Balance, December 31, 2014
|
77
|
|
|
—
|
|
|
6,423
|
|
|
14,513
|
|
|
(494
|
)
|
|
131
|
|
|
20,573
|
|
||||||
Adoption of ASC 853
|
—
|
|
|
—
|
|
|
—
|
|
|
56
|
|
|
—
|
|
|
11
|
|
|
67
|
|
||||||
Net income
|
—
|
|
|
—
|
|
|
—
|
|
|
2,370
|
|
|
—
|
|
|
18
|
|
|
2,388
|
|
||||||
Other comprehensive loss
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(414
|
)
|
|
—
|
|
|
(414
|
)
|
||||||
Distributions
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(21
|
)
|
|
(21
|
)
|
||||||
Common stock purchases
|
—
|
|
|
—
|
|
|
(3
|
)
|
|
(33
|
)
|
|
—
|
|
|
—
|
|
|
(36
|
)
|
||||||
Other equity transactions
|
—
|
|
|
—
|
|
|
(17
|
)
|
|
—
|
|
|
—
|
|
|
(5
|
)
|
|
(22
|
)
|
||||||
Balance, December 31, 2015
|
77
|
|
|
—
|
|
|
6,403
|
|
|
16,906
|
|
|
(908
|
)
|
|
134
|
|
|
22,535
|
|
||||||
Net income
|
—
|
|
|
—
|
|
|
—
|
|
|
2,542
|
|
|
—
|
|
|
14
|
|
|
2,556
|
|
||||||
Other comprehensive loss
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(603
|
)
|
|
—
|
|
|
(603
|
)
|
||||||
Distributions
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(20
|
)
|
|
(20
|
)
|
||||||
Other equity transactions
|
—
|
|
|
—
|
|
|
(13
|
)
|
|
—
|
|
|
—
|
|
|
8
|
|
|
(5
|
)
|
||||||
Balance, December 31, 2016
|
77
|
|
|
$
|
—
|
|
|
$
|
6,390
|
|
|
$
|
19,448
|
|
|
$
|
(1,511
|
)
|
|
$
|
136
|
|
|
$
|
24,463
|
|
|
Years Ended December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
Cash flows from operating activities:
|
|
|
|
|
|
||||||
Net income
|
$
|
2,570
|
|
|
$
|
2,400
|
|
|
$
|
2,122
|
|
Adjustments to reconcile net income to net cash flows from operating activities:
|
|
|
|
|
|
||||||
Depreciation and amortization
|
2,591
|
|
|
2,428
|
|
|
2,057
|
|
|||
Allowance for equity funds
|
(158
|
)
|
|
(91
|
)
|
|
(98
|
)
|
|||
Equity income, net of distributions
|
(67
|
)
|
|
(38
|
)
|
|
(79
|
)
|
|||
Changes in regulatory assets and liabilities
|
(34
|
)
|
|
356
|
|
|
(168
|
)
|
|||
Deferred income taxes and amortization of investment tax credits
|
1,090
|
|
|
1,265
|
|
|
2,335
|
|
|||
Other, net
|
(80
|
)
|
|
11
|
|
|
147
|
|
|||
Changes in other operating assets and liabilities, net of effects from acquisitions:
|
|
|
|
|
|
||||||
Trade receivables and other assets
|
(158
|
)
|
|
(9
|
)
|
|
(44
|
)
|
|||
Derivative collateral, net
|
32
|
|
|
(14
|
)
|
|
(70
|
)
|
|||
Pension and other postretirement benefit plans
|
(79
|
)
|
|
(11
|
)
|
|
86
|
|
|||
Accrued property, income and other taxes
|
377
|
|
|
877
|
|
|
(1,117
|
)
|
|||
Accounts payable and other liabilities
|
(28
|
)
|
|
(194
|
)
|
|
(25
|
)
|
|||
Net cash flows from operating activities
|
6,056
|
|
|
6,980
|
|
|
5,146
|
|
|||
|
|
|
|
|
|
||||||
Cash flows from investing activities:
|
|
|
|
|
|
||||||
Capital expenditures
|
(5,090
|
)
|
|
(5,875
|
)
|
|
(6,555
|
)
|
|||
Acquisitions, net of cash acquired
|
(66
|
)
|
|
(164
|
)
|
|
(2,956
|
)
|
|||
(Increase) decrease in restricted cash and investments
|
(36
|
)
|
|
(28
|
)
|
|
173
|
|
|||
Purchases of available-for-sale securities
|
(141
|
)
|
|
(144
|
)
|
|
(150
|
)
|
|||
Proceeds from sales of available-for-sale securities
|
191
|
|
|
142
|
|
|
118
|
|
|||
Equity method investments
|
(570
|
)
|
|
(202
|
)
|
|
(37
|
)
|
|||
Other, net
|
(34
|
)
|
|
41
|
|
|
(11
|
)
|
|||
Net cash flows from investing activities
|
(5,746
|
)
|
|
(6,230
|
)
|
|
(9,418
|
)
|
|||
|
|
|
|
|
|
||||||
Cash flows from financing activities:
|
|
|
|
|
|
||||||
Proceeds from BHE senior debt
|
—
|
|
|
—
|
|
|
1,478
|
|
|||
Proceeds from BHE junior subordinated debentures
|
—
|
|
|
—
|
|
|
1,500
|
|
|||
Repayments of BHE senior debt and junior subordinated debentures
|
(2,000
|
)
|
|
(850
|
)
|
|
(550
|
)
|
|||
Common stock purchases
|
—
|
|
|
(36
|
)
|
|
—
|
|
|||
Proceeds from subsidiary debt
|
2,327
|
|
|
2,479
|
|
|
1,257
|
|
|||
Repayments of subsidiary debt
|
(1,831
|
)
|
|
(1,354
|
)
|
|
(971
|
)
|
|||
Net proceeds from (repayments of) short-term debt
|
879
|
|
|
(421
|
)
|
|
1,055
|
|
|||
Other, net
|
(65
|
)
|
|
(73
|
)
|
|
(44
|
)
|
|||
Net cash flows from financing activities
|
(690
|
)
|
|
(255
|
)
|
|
3,725
|
|
|||
|
|
|
|
|
|
||||||
Effect of exchange rate changes
|
(7
|
)
|
|
(4
|
)
|
|
(11
|
)
|
|||
|
|
|
|
|
|
||||||
Net change in cash and cash equivalents
|
(387
|
)
|
|
491
|
|
|
(558
|
)
|
|||
Cash and cash equivalents at beginning of period
|
1,108
|
|
|
617
|
|
|
1,175
|
|
|||
Cash and cash equivalents at end of period
|
$
|
721
|
|
|
$
|
1,108
|
|
|
$
|
617
|
|
(
1
)
|
Organization and Operations
|
|
|
|
2014
|
|
|
|
|
|
|
Operating revenue
|
|
|
17,888
|
|
|
|
|
|
|
Net income attributable to BHE shareholders
|
|
|
2,155
|
|
|
Depreciable
|
|
|
|
|
||||
|
Life
|
|
2016
|
|
2015
|
||||
Regulated assets:
|
|
|
|
|
|
||||
Utility generation, transmission and distribution systems
|
5-80 years
|
|
$
|
71,536
|
|
|
$
|
69,248
|
|
Interstate natural gas pipeline assets
|
3-80 years
|
|
6,942
|
|
|
6,755
|
|
||
|
|
|
78,478
|
|
|
76,003
|
|
||
Accumulated depreciation and amortization
|
|
|
(23,603
|
)
|
|
(22,682
|
)
|
||
Regulated assets, net
|
|
|
54,875
|
|
|
53,321
|
|
||
|
|
|
|
|
|
||||
Nonregulated assets:
|
|
|
|
|
|
||||
Independent power plants
|
5-30 years
|
|
5,594
|
|
|
4,751
|
|
||
Other assets
|
3-30 years
|
|
1,002
|
|
|
875
|
|
||
|
|
|
6,596
|
|
|
5,626
|
|
||
Accumulated depreciation and amortization
|
|
|
(1,060
|
)
|
|
(805
|
)
|
||
Nonregulated assets, net
|
|
|
5,536
|
|
|
4,821
|
|
||
|
|
|
|
|
|
|
|||
Net operating assets
|
|
|
60,411
|
|
|
58,142
|
|
||
Construction work-in-progress
|
|
|
2,098
|
|
|
2,627
|
|
||
Property, plant and equipment, net
|
|
|
$
|
62,509
|
|
|
$
|
60,769
|
|
(
5
)
|
Jointly Owned Utility Facilities
|
|
|
|
|
|
Accumulated
|
|
Construction
|
|||||||
|
Company
|
|
Facility In
|
|
Depreciation and
|
|
Work-in-
|
|||||||
|
Share
|
|
Service
|
|
Amortization
|
|
Progress
|
|||||||
PacifiCorp:
|
|
|
|
|
|
|
|
|||||||
Jim Bridger Nos. 1-4
|
67
|
%
|
|
$
|
1,420
|
|
|
$
|
583
|
|
|
$
|
10
|
|
Hunter No. 1
|
94
|
|
|
473
|
|
|
161
|
|
|
1
|
|
|||
Hunter No. 2
|
60
|
|
|
296
|
|
|
98
|
|
|
—
|
|
|||
Wyodak
|
80
|
|
|
467
|
|
|
203
|
|
|
1
|
|
|||
Colstrip Nos. 3 and 4
|
10
|
|
|
244
|
|
|
130
|
|
|
5
|
|
|||
Hermiston
|
50
|
|
|
178
|
|
|
76
|
|
|
2
|
|
|||
Craig Nos. 1 and 2
|
19
|
|
|
325
|
|
|
223
|
|
|
32
|
|
|||
Hayden No. 1
|
25
|
|
|
74
|
|
|
32
|
|
|
—
|
|
|||
Hayden No. 2
|
13
|
|
|
43
|
|
|
20
|
|
|
—
|
|
|||
Foote Creek
|
79
|
|
|
39
|
|
|
25
|
|
|
—
|
|
|||
Transmission and distribution facilities
|
Various
|
|
777
|
|
|
228
|
|
|
61
|
|
||||
Total PacifiCorp
|
|
|
4,336
|
|
|
1,779
|
|
|
112
|
|
||||
MidAmerican Energy:
|
|
|
|
|
|
|
|
|||||||
Louisa No. 1
|
88
|
%
|
|
766
|
|
|
418
|
|
|
9
|
|
|||
Quad Cities Nos. 1 and 2
(1)
|
25
|
|
|
689
|
|
|
367
|
|
|
7
|
|
|||
Walter Scott, Jr. No. 3
|
79
|
|
|
614
|
|
|
303
|
|
|
1
|
|
|||
Walter Scott, Jr. No. 4
(2)
|
60
|
|
|
448
|
|
|
101
|
|
|
2
|
|
|||
George Neal No. 4
|
41
|
|
|
307
|
|
|
154
|
|
|
1
|
|
|||
Ottumwa No. 1
|
52
|
|
|
548
|
|
|
191
|
|
|
13
|
|
|||
George Neal No. 3
|
72
|
|
|
426
|
|
|
174
|
|
|
1
|
|
|||
Transmission facilities
|
Various
|
|
247
|
|
|
86
|
|
|
1
|
|
||||
Total MidAmerican Energy
|
|
|
4,045
|
|
|
1,794
|
|
|
35
|
|
||||
NV Energy:
|
|
|
|
|
|
|
|
|||||||
Navajo
|
11
|
%
|
|
213
|
|
|
145
|
|
|
2
|
|
|||
Silverhawk
|
75
|
|
|
248
|
|
|
66
|
|
|
3
|
|
|||
Valmy
|
50
|
|
|
389
|
|
|
216
|
|
|
1
|
|
|||
Transmission facilities
|
Various
|
|
213
|
|
|
41
|
|
|
—
|
|
||||
Total NV Energy
|
|
|
1,063
|
|
|
468
|
|
|
6
|
|
||||
BHE Pipeline Group
- common facilities
|
Various
|
|
286
|
|
|
164
|
|
|
—
|
|
||||
Total
|
|
|
$
|
9,730
|
|
|
$
|
4,205
|
|
|
$
|
153
|
|
(1)
|
Includes amounts related to nuclear fuel.
|
(2)
|
Facility in-service and accumulated depreciation and amortization amounts are net of credits applied under Iowa revenue sharing arrangements totaling
$319 million
and
$75 million
, respectively.
|
|
Weighted
|
|
|
|
|
||||
|
Average
|
|
|
|
|
||||
|
Remaining Life
|
|
2016
|
|
2015
|
||||
|
|
|
|
|
|
||||
Deferred income taxes
(1)
|
27 years
|
|
$
|
1,754
|
|
|
$
|
1,577
|
|
Employee benefit plans
(2)
|
17 years
|
|
816
|
|
|
778
|
|
||
Asset disposition costs
|
Various
|
|
281
|
|
|
307
|
|
||
Deferred net power costs
|
1 year
|
|
38
|
|
|
140
|
|
||
Asset retirement obligations
|
12 years
|
|
301
|
|
|
281
|
|
||
Unrealized loss on regulated derivative contracts
|
5 years
|
|
154
|
|
|
250
|
|
||
Abandoned projects
|
3 years
|
|
159
|
|
|
136
|
|
||
Unamortized contract values
|
7 years
|
|
98
|
|
|
110
|
|
||
Other
|
Various
|
|
856
|
|
|
706
|
|
||
Total regulatory assets
|
|
|
$
|
4,457
|
|
|
$
|
4,285
|
|
|
|
|
|
|
|
||||
Reflected as:
|
|
|
|
|
|
||||
Current assets
|
|
|
$
|
150
|
|
|
$
|
130
|
|
Noncurrent assets
|
|
|
4,307
|
|
|
4,155
|
|
||
Total regulatory assets
|
|
|
$
|
4,457
|
|
|
$
|
4,285
|
|
(1)
|
Amounts primarily represent income tax benefits related to state accelerated tax depreciation and certain property-related basis differences that were previously flowed through to customers and will be included in regulated rates when the temporary differences reverse.
|
(2)
|
Represents amounts not yet recognized as a component of net periodic benefit cost that are expected to be included in regulated rates when recognized.
|
|
Weighted
|
|
|
|
|
||||
|
Average
|
|
|
|
|
||||
|
Remaining Life
|
|
2016
|
|
2015
|
||||
|
|
|
|
|
|
||||
Cost of removal
(1)
|
27 years
|
|
$
|
2,242
|
|
|
$
|
2,167
|
|
Deferred net power costs
|
1 years
|
|
64
|
|
|
206
|
|
||
Asset retirement obligations
|
35 years
|
|
122
|
|
|
147
|
|
||
Levelized depreciation
|
23 years
|
|
244
|
|
|
199
|
|
||
Impact fees
|
6 years
|
|
90
|
|
|
—
|
|
||
Employee benefit plans
(2)
|
12 years
|
|
25
|
|
|
13
|
|
||
Unrealized gain on regulated derivative contracts
|
1 year
|
|
6
|
|
|
—
|
|
||
Other
|
Various
|
|
327
|
|
|
301
|
|
||
Total regulatory liabilities
|
|
|
$
|
3,120
|
|
|
$
|
3,033
|
|
|
|
|
|
|
|
||||
Reflected as:
|
|
|
|
|
|
||||
Current liabilities
|
|
|
$
|
187
|
|
|
$
|
402
|
|
Noncurrent liabilities
|
|
|
2,933
|
|
|
2,631
|
|
||
Total regulatory liabilities
|
|
|
$
|
3,120
|
|
|
$
|
3,033
|
|
(1)
|
Amounts represent estimated costs, as accrued through depreciation rates and exclusive of ARO liabilities, of removing regulated property, plant and equipment in accordance with accepted regulatory practices. Amounts are deducted from rate base or otherwise accrue a carrying cost.
|
(2)
|
Represents amounts not yet recognized as a component of net periodic benefit cost that are to be returned to customers in future periods when recognized.
|
|
2016
|
|
2015
|
||||
Investments:
|
|
|
|
||||
BYD Company Limited common stock
|
$
|
1,185
|
|
|
$
|
1,238
|
|
Rabbi trusts
|
403
|
|
|
380
|
|
||
Other
|
106
|
|
|
130
|
|
||
Total investments
|
1,694
|
|
|
1,748
|
|
||
|
|
|
|
||||
Equity method investments:
|
|
|
|
||||
Electric Transmission Texas, LLC
|
672
|
|
|
585
|
|
||
Bridger Coal Company
|
165
|
|
|
190
|
|
||
BHE Renewables tax equity investments
|
741
|
|
|
168
|
|
||
Other
|
142
|
|
|
160
|
|
||
Total equity method investments
|
1,720
|
|
|
1,103
|
|
||
|
|
|
|
||||
Restricted cash and investments:
|
|
|
|
||||
Quad Cities Station nuclear decommissioning trust funds
|
460
|
|
|
429
|
|
||
Solar Star and Topaz Projects
|
64
|
|
|
95
|
|
||
Other
|
218
|
|
|
129
|
|
||
Total restricted cash and investments
|
742
|
|
|
653
|
|
||
|
|
|
|
||||
Total investments and restricted cash and investments
|
$
|
4,156
|
|
|
$
|
3,504
|
|
|
|
|
|
||||
Reflected as:
|
|
|
|
||||
Current assets
|
$
|
211
|
|
|
$
|
137
|
|
Noncurrent assets
|
3,945
|
|
|
3,367
|
|
||
Total investments and restricted cash and investments
|
$
|
4,156
|
|
|
$
|
3,504
|
|
|
|
|
|
|
MidAmerican
|
|
NV
|
|
Northern
|
|
|
|
|
|
|
||||||||||||||||
|
BHE
|
|
PacifiCorp
|
|
Funding
|
|
Energy
|
|
Powergrid
|
|
AltaLink
|
|
Other
|
|
Total
(1)
|
||||||||||||||||
2016:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||||
Credit facilities
|
$
|
2,000
|
|
|
$
|
1,000
|
|
|
$
|
609
|
|
|
$
|
650
|
|
|
$
|
185
|
|
|
$
|
986
|
|
|
$
|
915
|
|
|
$
|
6,345
|
|
Less:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||||
Short-term debt
|
(834
|
)
|
|
(270
|
)
|
|
(99
|
)
|
|
—
|
|
|
—
|
|
|
(289
|
)
|
|
(377
|
)
|
|
(1,869
|
)
|
||||||||
Tax-exempt bond support and letters of credit
|
(7
|
)
|
|
(142
|
)
|
|
(220
|
)
|
|
(80
|
)
|
|
—
|
|
|
(8
|
)
|
|
—
|
|
|
(457
|
)
|
||||||||
Net credit facilities
|
$
|
1,159
|
|
|
$
|
588
|
|
|
$
|
290
|
|
|
$
|
570
|
|
|
$
|
185
|
|
|
$
|
689
|
|
|
$
|
538
|
|
|
$
|
4,019
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||||
2015:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||||
Credit facilities
|
$
|
2,000
|
|
|
$
|
1,200
|
|
|
$
|
609
|
|
|
$
|
650
|
|
|
$
|
221
|
|
|
$
|
813
|
|
|
$
|
928
|
|
|
$
|
6,421
|
|
Less:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||||
Short-term debt
|
(253
|
)
|
|
(20
|
)
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(401
|
)
|
|
(300
|
)
|
|
(974
|
)
|
||||||||
Tax-exempt bond support and letters of credit
|
(51
|
)
|
|
(160
|
)
|
|
(195
|
)
|
|
—
|
|
|
—
|
|
|
(9
|
)
|
|
—
|
|
|
(415
|
)
|
||||||||
Net credit facilities
|
$
|
1,696
|
|
|
$
|
1,020
|
|
|
$
|
414
|
|
|
$
|
650
|
|
|
$
|
221
|
|
|
$
|
403
|
|
|
$
|
628
|
|
|
$
|
5,032
|
|
(1)
|
The above table does not include unused credit facilities and letters of credit for investments that are accounted for under the equity method.
|
(
9
)
|
BHE Debt
|
|
Par Value
|
|
2016
|
|
2015
|
||||||
|
|
|
|
|
|
||||||
1.10% Senior Notes, due 2017
|
$
|
400
|
|
|
$
|
400
|
|
|
$
|
399
|
|
5.75% Senior Notes, due 2018
|
650
|
|
|
649
|
|
|
648
|
|
|||
2.00% Senior Notes, due 2018
|
350
|
|
|
349
|
|
|
348
|
|
|||
2.40% Senior Notes, due 2020
|
350
|
|
|
349
|
|
|
348
|
|
|||
3.75% Senior Notes, due 2023
|
500
|
|
|
497
|
|
|
497
|
|
|||
3.50% Senior Notes, due 2025
|
400
|
|
|
397
|
|
|
397
|
|
|||
8.48% Senior Notes, due 2028
|
475
|
|
|
477
|
|
|
477
|
|
|||
6.125% Senior Bonds, due 2036
|
1,700
|
|
|
1,690
|
|
|
1,690
|
|
|||
5.95% Senior Bonds, due 2037
|
550
|
|
|
547
|
|
|
547
|
|
|||
6.50% Senior Bonds, due 2037
|
1,000
|
|
|
987
|
|
|
987
|
|
|||
5.15% Senior Notes, due 2043
|
750
|
|
|
739
|
|
|
739
|
|
|||
4.50% Senior Notes, due 2045
|
750
|
|
|
737
|
|
|
737
|
|
|||
Total BHE Senior Debt
|
$
|
7,875
|
|
|
$
|
7,818
|
|
|
$
|
7,814
|
|
|
|
|
|
|
|
||||||
Reflected as:
|
|
|
|
|
|
||||||
Current liabilities
|
|
|
$
|
400
|
|
|
$
|
—
|
|
||
Noncurrent liabilities
|
|
|
7,418
|
|
|
7,814
|
|
||||
Total BHE Senior Debt
|
|
|
$
|
7,818
|
|
|
$
|
7,814
|
|
|
Par Value
|
|
2016
|
|
2015
|
||||||
|
|
|
|
|
|
||||||
Junior subordinated debentures, due 2043
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
1,444
|
|
Junior subordinated debentures, due 2044
|
944
|
|
|
944
|
|
|
1,500
|
|
|||
Total BHE junior subordinated debentures
- noncurrent
|
$
|
944
|
|
|
$
|
944
|
|
|
$
|
2,944
|
|
|
Par Value
|
|
2016
|
|
2015
|
||||||
|
|
|
|
|
|
||||||
PacifiCorp
|
$
|
7,120
|
|
|
$
|
7,079
|
|
|
$
|
7,159
|
|
MidAmerican Funding
|
4,657
|
|
|
4,592
|
|
|
4,560
|
|
|||
NV Energy
|
4,569
|
|
|
4,582
|
|
|
4,860
|
|
|||
Northern Powergrid
|
2,351
|
|
|
2,379
|
|
|
2,772
|
|
|||
BHE Pipeline Group
|
995
|
|
|
990
|
|
|
1,040
|
|
|||
BHE Transmission
|
4,068
|
|
|
4,058
|
|
|
3,467
|
|
|||
BHE Renewables
|
3,716
|
|
|
3,674
|
|
|
3,356
|
|
|||
Total subsidiary debt
|
$
|
27,476
|
|
|
$
|
27,354
|
|
|
$
|
27,214
|
|
|
|
|
|
|
|
||||||
Reflected as:
|
|
|
|
|
|
||||||
Current liabilities
|
|
|
$
|
606
|
|
|
$
|
1,148
|
|
||
Noncurrent liabilities
|
|
|
26,748
|
|
|
26,066
|
|
||||
Total subsidiary debt
|
|
|
$
|
27,354
|
|
|
$
|
27,214
|
|
|
Par Value
|
|
2016
|
|
2015
|
||||||
First mortgage bonds:
|
|
|
|
|
|
||||||
3.85% to 8.53%, due through 2021
|
$
|
1,272
|
|
|
$
|
1,269
|
|
|
$
|
1,271
|
|
2.95% to 8.27%, due 2022 to 2026
|
1,829
|
|
|
1,820
|
|
|
1,819
|
|
|||
7.70% due 2031
|
300
|
|
|
298
|
|
|
298
|
|
|||
5.25% to 6.10%, due 2034 to 2036
|
850
|
|
|
843
|
|
|
843
|
|
|||
5.75% to 6.35%, due 2037 to 2039
|
2,150
|
|
|
2,134
|
|
|
2,133
|
|
|||
4.10% due 2042
|
300
|
|
|
297
|
|
|
297
|
|
|||
Variable-rate series, tax-exempt bond obligations (2016-0.69% to 0.86%; 2015-0.01% to 0.22%):
|
|
|
|
|
|
||||||
Due 2017 to 2018
|
91
|
|
|
91
|
|
|
91
|
|
|||
Due 2018 to 2025
(1)
|
108
|
|
|
108
|
|
|
107
|
|
|||
Due 2024
(1)(2)
|
143
|
|
|
142
|
|
|
196
|
|
|||
Due 2024 to 2025
(2)
|
50
|
|
|
50
|
|
|
59
|
|
|||
Capital lease obligations - 8.75% to 14.61%, due through 2035
|
27
|
|
|
27
|
|
|
45
|
|
|||
Total PacifiCorp
|
$
|
7,120
|
|
|
$
|
7,079
|
|
|
$
|
7,159
|
|
(1)
|
Supported by
$255 million
and
$310 million
of fully available letters of credit issued under committed bank arrangements as of December 31,
2016
and
2015
, respectively.
|
(2)
|
Secured by pledged first mortgage bonds registered to and held by the tax-exempt bond trustee generally with the same interest rates, maturity dates and redemption provisions as the tax-exempt bond obligations.
|
|
Par Value
|
|
2016
|
|
2015
|
||||||
MidAmerican Funding:
|
|
|
|
|
|
||||||
6.927% Senior Bonds, due 2029
|
$
|
325
|
|
|
$
|
291
|
|
|
$
|
289
|
|
|
|
|
|
|
|
||||||
MidAmerican Energy:
|
|
|
|
|
|
||||||
Tax-exempt bond obligations -
|
|
|
|
|
|
||||||
Variable-rate tax-exempt bond obligation series: (2016-0.76%, 2015-0.03%), due 2023-2046
|
220
|
|
|
219
|
|
|
194
|
|
|||
First Mortgage Bonds:
|
|
|
|
|
|
||||||
2.40%, due 2019
|
500
|
|
|
499
|
|
|
499
|
|
|||
3.70%, due 2023
|
250
|
|
|
248
|
|
|
248
|
|
|||
3.50%, due 2024
|
500
|
|
|
501
|
|
|
502
|
|
|||
4.80%, due 2043
|
350
|
|
|
345
|
|
|
345
|
|
|||
4.40%, due 2044
|
400
|
|
|
394
|
|
|
394
|
|
|||
4.25%, due 2046
|
450
|
|
|
445
|
|
|
444
|
|
|||
Notes:
|
|
|
|
|
|
||||||
5.95% Series, due 2017
|
250
|
|
|
250
|
|
|
250
|
|
|||
5.3% Series, due 2018
|
350
|
|
|
350
|
|
|
349
|
|
|||
6.75% Series, due 2031
|
400
|
|
|
396
|
|
|
395
|
|
|||
5.75% Series, due 2035
|
300
|
|
|
298
|
|
|
298
|
|
|||
5.8% Series, due 2036
|
350
|
|
|
347
|
|
|
347
|
|
|||
Transmission upgrade obligation, 4.45% and 3.42% due through 2035 and 2036, respectively
|
10
|
|
|
7
|
|
|
4
|
|
|||
Capital lease obligations - 4.16%, due through 2020
|
2
|
|
|
2
|
|
|
2
|
|
|||
Total MidAmerican Energy
|
4,332
|
|
|
4,301
|
|
|
4,271
|
|
|||
Total MidAmerican Funding
|
$
|
4,657
|
|
|
$
|
4,592
|
|
|
$
|
4,560
|
|
|
Par Value
|
|
2016
|
|
2015
|
||||||
NV Energy -
|
|
|
|
|
|
||||||
6.250% Senior Notes, due 2020
|
$
|
315
|
|
|
$
|
363
|
|
|
$
|
373
|
|
|
|
|
|
|
|
||||||
Nevada Power:
|
|
|
|
|
|
||||||
General and refunding mortgage securities:
|
|
|
|
|
|
||||||
5.950% Series M, due 2016
|
—
|
|
|
—
|
|
|
210
|
|
|||
6.500% Series O, due 2018
|
324
|
|
|
324
|
|
|
323
|
|
|||
6.500% Series S, due 2018
|
499
|
|
|
498
|
|
|
498
|
|
|||
7.125% Series V, due 2019
|
500
|
|
|
499
|
|
|
499
|
|
|||
6.650% Series N, due 2036
|
367
|
|
|
357
|
|
|
356
|
|
|||
6.750% Series R, due 2037
|
349
|
|
|
345
|
|
|
345
|
|
|||
5.375% Series X, due 2040
|
250
|
|
|
247
|
|
|
247
|
|
|||
5.450% Series Y, due 2041
|
250
|
|
|
236
|
|
|
235
|
|
|||
Variable-rate series (2016-1.890% to 1.928%, 2015-0.672% to 1.055%):
|
|
|
|
|
|
||||||
Pollution Control Revenue Bonds Series 2006A, due 2032
|
38
|
|
|
38
|
|
|
38
|
|
|||
Pollution Control Revenue Bonds Series 2006, due 2036
|
38
|
|
|
37
|
|
|
37
|
|
|||
Capital and financial lease obligations - 2.750% to 11.600%, due through 2054
|
485
|
|
|
485
|
|
|
497
|
|
|||
Total Nevada Power
|
3,100
|
|
|
3,066
|
|
|
3,285
|
|
|||
|
|
|
|
|
|
||||||
Sierra Pacific:
|
|
|
|
|
|
||||||
General and refunding mortgage securities:
|
|
|
|
|
|
||||||
6.000% Series M, due 2016
|
—
|
|
|
—
|
|
|
450
|
|
|||
3.375% Series T, due 2023
|
250
|
|
|
248
|
|
|
248
|
|
|||
2.600% Series U, due 2026
|
400
|
|
|
395
|
|
|
—
|
|
|||
6.750% Series P, due 2037
|
252
|
|
|
255
|
|
|
255
|
|
|||
Tax-exempt refunding revenue bond obligations:
|
|
|
|
|
|
||||||
Fixed-rate series:
|
|
|
|
|
|
||||||
1.250% Pollution Control Series 2016A, due 2029
|
20
|
|
|
20
|
|
|
—
|
|
|||
1.500% Gas Facilities Series 2016A, due 2031
|
58
|
|
|
58
|
|
|
—
|
|
|||
3.000% Gas and Water Series 2016B, due 2036
|
60
|
|
|
64
|
|
|
—
|
|
|||
Variable-rate series (2016-0.788% to 0.800%, 2015-0.733% to 1.054%):
|
|
|
|
|
|
||||||
Pollution Control Series 2006A, due 2031
|
—
|
|
|
—
|
|
|
58
|
|
|||
Pollution Control Series 2006B, due 2036
|
—
|
|
|
—
|
|
|
74
|
|
|||
Pollution Control Series 2006C, due 2036
|
—
|
|
|
—
|
|
|
80
|
|
|||
Water Facilities Series 2016C, due 2036
|
30
|
|
|
29
|
|
|
—
|
|
|||
Water Facilities Series 2016D, due 2036
|
25
|
|
|
25
|
|
|
—
|
|
|||
Water Facilities Series 2016E, due 2036
|
25
|
|
|
25
|
|
|
—
|
|
|||
Capital and financial lease obligations - 2.700% to 10.130%, due through 2054
|
34
|
|
|
34
|
|
|
37
|
|
|||
Total Sierra Pacific
|
1,154
|
|
|
1,153
|
|
|
1,202
|
|
|||
Total NV Energy
|
$
|
4,569
|
|
|
$
|
4,582
|
|
|
$
|
4,860
|
|
|
Par Value
(1)
|
|
2016
|
|
2015
|
||||||
|
|
|
|
|
|
||||||
8.875% Bonds, due 2020
|
$
|
123
|
|
|
$
|
136
|
|
|
$
|
162
|
|
9.25% Bonds, due 2020
|
247
|
|
|
259
|
|
|
315
|
|
|||
3.901% to 4.586% European Investment Bank loans, due 2018 to 2022
|
333
|
|
|
333
|
|
|
398
|
|
|||
7.25% Bonds, due 2022
|
247
|
|
|
257
|
|
|
306
|
|
|||
2.50% Bonds due 2025
|
185
|
|
|
182
|
|
|
217
|
|
|||
2.073% European Investment Bank loan, due 2025
|
62
|
|
|
62
|
|
|
—
|
|
|||
2.564% European Investment Bank loans, due 2027
|
308
|
|
|
308
|
|
|
368
|
|
|||
7.25% Bonds, due 2028
|
229
|
|
|
234
|
|
|
280
|
|
|||
4.375% Bonds, due 2032
|
185
|
|
|
182
|
|
|
217
|
|
|||
5.125% Bonds, due 2035
|
247
|
|
|
243
|
|
|
291
|
|
|||
5.125% Bonds, due 2035
|
185
|
|
|
183
|
|
|
218
|
|
|||
Total Northern Powergrid
|
$
|
2,351
|
|
|
$
|
2,379
|
|
|
$
|
2,772
|
|
(1)
|
The par values for these debt instruments are denominated in sterling.
|
|
Par Value
|
|
2016
|
|
2015
|
||||||
Northern Natural Gas:
|
|
|
|
|
|
||||||
5.75% Senior Notes, due 2018
|
$
|
200
|
|
|
$
|
199
|
|
|
$
|
199
|
|
4.25% Senior Notes, due 2021
|
200
|
|
|
199
|
|
|
199
|
|
|||
5.8% Senior Bonds, due 2037
|
150
|
|
|
149
|
|
|
149
|
|
|||
4.1% Senior Bonds, due 2042
|
250
|
|
|
248
|
|
|
248
|
|
|||
Total Northern Natural Gas
|
800
|
|
|
795
|
|
|
795
|
|
|||
|
|
|
|
|
|
||||||
Kern River:
|
|
|
|
|
|
||||||
4.893% Senior Notes, due 2018
|
195
|
|
|
195
|
|
|
245
|
|
|||
|
|
|
|
|
|
||||||
Total BHE Pipeline Group
|
$
|
995
|
|
|
$
|
990
|
|
|
$
|
1,040
|
|
|
Par Value
(1)
|
|
2016
|
|
2015
|
||||||
AltaLink Investments, L.P.:
|
|
|
|
|
|
||||||
Series 09-1 Senior Bonds, 5.207%, due 2016
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
112
|
|
Series 12-1 Senior Bonds, 3.674%, due 2019
|
149
|
|
|
153
|
|
|
151
|
|
|||
Series 13-1 Senior Bonds, 3.265%, due 2020
|
149
|
|
|
152
|
|
|
149
|
|
|||
Series 15-1 Senior Bonds, 2.244%, due 2022
|
149
|
|
|
148
|
|
|
144
|
|
|||
Total AltaLink Investments, L.P.
|
447
|
|
|
453
|
|
|
556
|
|
|||
|
|
|
|
|
|
||||||
AltaLink, L.P.:
|
|
|
|
|
|
||||||
Series 2008-1 Notes, 5.243%, due 2018
|
149
|
|
|
148
|
|
|
145
|
|
|||
Series 2013-2 Notes, 3.621%, due 2020
|
93
|
|
|
93
|
|
|
90
|
|
|||
Series 2012-2 Notes, 2.978%, due 2022
|
204
|
|
|
204
|
|
|
198
|
|
|||
Series 2013-4 Notes, 3.668%, due 2023
|
372
|
|
|
371
|
|
|
360
|
|
|||
Series 2014-1 Notes, 3.399%, due 2024
|
260
|
|
|
260
|
|
|
252
|
|
|||
Series 2016-1 Notes, 2.747%, due 2026
|
260
|
|
|
259
|
|
|
—
|
|
|||
Series 2006-1 Notes, 5.249%, due 2036
|
112
|
|
|
111
|
|
|
108
|
|
|||
Series 2010-1 Notes, 5.381%, due 2040
|
93
|
|
|
93
|
|
|
90
|
|
|||
Series 2010-2 Notes, 4.872%, due 2040
|
112
|
|
|
111
|
|
|
108
|
|
|||
Series 2011-1 Notes, 4.462%, due 2041
|
205
|
|
|
204
|
|
|
198
|
|
|||
Series 2012-1 Notes, 3.99%, due 2042
|
391
|
|
|
385
|
|
|
374
|
|
|||
Series 2013-3 Notes, 4.922%, due 2043
|
260
|
|
|
260
|
|
|
252
|
|
|||
Series 2014-3 Notes, 4.054%, due 2044
|
219
|
|
|
218
|
|
|
212
|
|
|||
Series 2015-1 Notes, 4.090%, due 2045
|
260
|
|
|
259
|
|
|
251
|
|
|||
Series 2016-2 Notes, 3.717%, due 2046
|
335
|
|
|
333
|
|
|
—
|
|
|||
Series 2013-1 Notes, 4.446%, due 2053
|
186
|
|
|
186
|
|
|
180
|
|
|||
Series 2014-2 Notes, 4.274%, due 2064
|
97
|
|
|
97
|
|
|
93
|
|
|||
Total AltaLink, L.P.
|
3,608
|
|
|
3,592
|
|
|
2,911
|
|
|||
|
|
|
|
|
|
||||||
Other:
|
|
|
|
|
|
||||||
Construction Loan, 4.950%, due 2021
|
13
|
|
|
13
|
|
|
—
|
|
|||
|
|
|
|
|
|
||||||
Total BHE Transmission
|
$
|
4,068
|
|
|
$
|
4,058
|
|
|
$
|
3,467
|
|
(1)
|
The par values for these debt instruments are denominated in Canadian dollars.
|
|
Par Value
|
|
2016
|
|
2015
|
||||||
Fixed-rate
(1)
:
|
|
|
|
|
|
||||||
CE Generation Bonds, 7.416%, due 2018
|
$
|
67
|
|
|
$
|
67
|
|
|
$
|
97
|
|
Salton Sea Funding Corporation Bonds, 7.475%, due 2018
|
30
|
|
|
31
|
|
|
51
|
|
|||
Cordova Funding Corporation Bonds, 8.48% to 9.07%, due 2019
|
96
|
|
|
97
|
|
|
113
|
|
|||
Bishop Hill Holdings Senior Notes, 5.125%, due 2032
|
100
|
|
|
99
|
|
|
102
|
|
|||
Solar Star Funding Senior Notes, 3.950%, due 2035
|
316
|
|
|
311
|
|
|
321
|
|
|||
Solar Star Funding Senior Notes, 5.375%, due 2035
|
977
|
|
|
966
|
|
|
988
|
|
|||
Grande Prairie Wind Senior Notes, 3.860%, due 2037
|
419
|
|
|
414
|
|
|
—
|
|
|||
Topaz Solar Farms Senior Notes, 5.750%, due 2039
|
791
|
|
|
780
|
|
|
815
|
|
|||
Topaz Solar Farms Senior Notes, 4.875%, due 2039
|
230
|
|
|
229
|
|
|
239
|
|
|||
Other
|
22
|
|
|
22
|
|
|
25
|
|
|||
Variable-rate
(1)
:
|
|
|
|
|
|
||||||
Pinyon Pines I and II Term Loans, due 2019
(2)
|
356
|
|
|
355
|
|
|
378
|
|
|||
Wailuku Special Purpose Revenue Bonds, 0.90%, due 2021
|
7
|
|
|
7
|
|
|
8
|
|
|||
TX Jumbo Road Term Loan, due 2025
(2)
|
212
|
|
|
206
|
|
|
219
|
|
|||
Marshall Wind Term Loan, due 2026
(2)
|
93
|
|
|
90
|
|
|
—
|
|
|||
Total BHE Renewables
|
$
|
3,716
|
|
|
$
|
3,674
|
|
|
$
|
3,356
|
|
(1)
|
Amortizes quarterly or semiannually.
|
(2)
|
The term loans have variable interest rates based on LIBOR plus a margin that varies during the terms of the agreements. The Company has entered into interest rate swaps that fix the interest rate on 75% of the Pinyon Pines outstanding debt and 100% of the TX Jumbo Road and Marshall Wind outstanding debt. The variable interest rate as of December 31,
2016
and
2015
was
2.62%
and
2.23%
, respectively, while the fixed interest rates ranged from
3.21%
to
3.63%
as of December 31,
2016
, and
3.55%
to
3.63%
as of December 31,
2015
.
|
|
|
|
|
|
|
|
|
|
|
|
2022 and
|
|
|
||||||||||||||
|
2017
|
|
2018
|
|
2019
|
|
2020
|
|
2021
|
|
Thereafter
|
|
Total
|
||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
BHE senior notes
|
$
|
400
|
|
|
$
|
1,000
|
|
|
$
|
—
|
|
|
$
|
350
|
|
|
$
|
—
|
|
|
$
|
6,125
|
|
|
$
|
7,875
|
|
BHE junior subordinated debentures
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
944
|
|
|
944
|
|
|||||||
PacifiCorp
|
58
|
|
|
588
|
|
|
352
|
|
|
40
|
|
|
425
|
|
|
5,657
|
|
|
7,120
|
|
|||||||
MidAmerican Funding
|
251
|
|
|
351
|
|
|
500
|
|
|
2
|
|
|
1
|
|
|
3,552
|
|
|
4,657
|
|
|||||||
NV Energy
|
18
|
|
|
840
|
|
|
519
|
|
|
336
|
|
|
27
|
|
|
2,829
|
|
|
4,569
|
|
|||||||
Northern Powergrid
|
—
|
|
|
49
|
|
|
49
|
|
|
418
|
|
|
—
|
|
|
1,835
|
|
|
2,351
|
|
|||||||
BHE Pipeline Group
|
66
|
|
|
329
|
|
|
—
|
|
|
—
|
|
|
200
|
|
|
400
|
|
|
995
|
|
|||||||
BHE Transmission
|
—
|
|
|
151
|
|
|
151
|
|
|
245
|
|
|
3
|
|
|
3,518
|
|
|
4,068
|
|
|||||||
BHE Renewables
|
213
|
|
|
236
|
|
|
528
|
|
|
161
|
|
|
167
|
|
|
2,411
|
|
|
3,716
|
|
|||||||
Totals
|
$
|
1,006
|
|
|
$
|
3,544
|
|
|
$
|
2,099
|
|
|
$
|
1,552
|
|
|
$
|
823
|
|
|
$
|
27,271
|
|
|
$
|
36,295
|
|
|
2016
|
|
2015
|
|
2014
|
||||||
Current:
|
|
|
|
|
|
||||||
Federal
|
$
|
(743
|
)
|
|
$
|
(929
|
)
|
|
$
|
(1,872
|
)
|
State
|
1
|
|
|
29
|
|
|
(3
|
)
|
|||
Foreign
|
55
|
|
|
84
|
|
|
129
|
|
|||
|
(687
|
)
|
|
(816
|
)
|
|
(1,746
|
)
|
|||
Deferred:
|
|
|
|
|
|
||||||
Federal
|
1,164
|
|
|
1,310
|
|
|
2,296
|
|
|||
State
|
(59
|
)
|
|
(53
|
)
|
|
37
|
|
|||
Foreign
|
(7
|
)
|
|
17
|
|
|
11
|
|
|||
|
1,098
|
|
|
1,274
|
|
|
2,344
|
|
|||
|
|
|
|
|
|
||||||
Investment tax credits
|
(8
|
)
|
|
(8
|
)
|
|
(9
|
)
|
|||
Total
|
$
|
403
|
|
|
$
|
450
|
|
|
$
|
589
|
|
|
2016
|
|
2015
|
|
2014
|
|||
|
|
|
|
|
|
|||
Federal statutory income tax rate
|
35
|
%
|
|
35
|
%
|
|
35
|
%
|
Income tax credits
|
(14
|
)
|
|
(11
|
)
|
|
(10
|
)
|
State income tax, net of federal income tax benefit
|
(1
|
)
|
|
(1
|
)
|
|
1
|
|
Income tax effect of foreign income
|
(6
|
)
|
|
(7
|
)
|
|
(3
|
)
|
Equity income
|
2
|
|
|
2
|
|
|
2
|
|
Other, net
|
(2
|
)
|
|
(2
|
)
|
|
(2
|
)
|
Effective income tax rate
|
14
|
%
|
|
16
|
%
|
|
23
|
%
|
|
2016
|
|
2015
|
||||
Deferred income tax assets:
|
|
|
|
||||
Federal, state and foreign carryforwards
|
$
|
987
|
|
|
$
|
865
|
|
Regulatory liabilities
|
909
|
|
|
834
|
|
||
AROs
|
326
|
|
|
317
|
|
||
Employee benefits
|
209
|
|
|
190
|
|
||
Derivative contracts
|
29
|
|
|
83
|
|
||
Other
|
707
|
|
|
815
|
|
||
Total deferred income tax assets
|
3,167
|
|
|
3,104
|
|
||
Valuation allowances
|
(64
|
)
|
|
(35
|
)
|
||
Total deferred income tax assets, net
|
3,103
|
|
|
3,069
|
|
||
|
|
|
|
||||
Deferred income tax liabilities:
|
|
|
|
||||
Property-related items
|
(14,237
|
)
|
|
(13,157
|
)
|
||
Regulatory assets
|
(1,449
|
)
|
|
(1,446
|
)
|
||
Investments
|
(962
|
)
|
|
(852
|
)
|
||
Other
|
(334
|
)
|
|
(299
|
)
|
||
Total deferred income tax liabilities
|
(16,982
|
)
|
|
(15,754
|
)
|
||
Net deferred income tax liability
|
$
|
(13,879
|
)
|
|
$
|
(12,685
|
)
|
|
Federal
|
|
State
|
|
Foreign
|
|
Total
|
||||||||
Net operating loss carryforwards
(1)
|
$
|
179
|
|
|
$
|
11,549
|
|
|
$
|
352
|
|
|
$
|
12,080
|
|
Deferred income taxes on net operating loss carryforwards
|
$
|
65
|
|
|
$
|
674
|
|
|
$
|
95
|
|
|
$
|
834
|
|
Expiration dates
|
2023-2025
|
|
2017-2036
|
|
2035-2036
|
|
|
|
|||||||
|
|
|
|
|
|
|
|
||||||||
Tax credits
(2)
|
$
|
128
|
|
|
$
|
25
|
|
|
$
|
—
|
|
|
$
|
153
|
|
Expiration dates
|
2023- indefinite
|
|
2017- indefinite
|
|
|
|
|
(1)
|
The federal net operating loss carry forwards relate principally to net operating loss carry forwards of subsidiaries that are tax residents in both the United States and the United Kingdom. The federal net operating loss carry forwards were generated prior to Berkshire Hathaway Inc.'s ownership and will begin to expire in 2023.
|
(2)
|
Includes
$97 million
of deferred foreign tax credits associated with the federal income tax on unremitted tax earnings and profit pools that will begin to be creditable and expire
10 years
after the date the foreign earnings are repatriated through actual or deemed dividends. As of December 31,
2016
the statute of limitation had not begun on the foreign tax credit carryforwards.
|
|
2016
|
|
2015
|
||||
|
|
|
|
||||
Beginning balance
|
$
|
198
|
|
|
$
|
220
|
|
Additions based on tax positions related to the current year
|
7
|
|
|
3
|
|
||
Additions for tax positions of prior years
|
6
|
|
|
46
|
|
||
Reductions for tax positions of prior years
|
(11
|
)
|
|
(58
|
)
|
||
Statute of limitations
|
(1
|
)
|
|
(6
|
)
|
||
Settlements
|
(67
|
)
|
|
(6
|
)
|
||
Interest and penalties
|
(4
|
)
|
|
(1
|
)
|
||
Ending balance
|
$
|
128
|
|
|
$
|
198
|
|
|
Pension
|
|
Other Postretirement
|
||||||||||||||||||||
|
2016
|
|
2015
|
|
2014
|
|
2016
|
|
2015
|
|
2014
|
||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Service cost
|
$
|
29
|
|
|
$
|
33
|
|
|
$
|
36
|
|
|
$
|
9
|
|
|
$
|
11
|
|
|
$
|
14
|
|
Interest cost
|
126
|
|
|
121
|
|
|
131
|
|
|
31
|
|
|
31
|
|
|
46
|
|
||||||
Expected return on plan assets
|
(160
|
)
|
|
(169
|
)
|
|
(164
|
)
|
|
(41
|
)
|
|
(45
|
)
|
|
(53
|
)
|
||||||
Net amortization
|
46
|
|
|
53
|
|
|
44
|
|
|
(12
|
)
|
|
(11
|
)
|
|
(3
|
)
|
||||||
Net periodic benefit cost (credit)
|
$
|
41
|
|
|
$
|
38
|
|
|
$
|
47
|
|
|
$
|
(13
|
)
|
|
$
|
(14
|
)
|
|
$
|
4
|
|
|
Pension
|
|
Other Postretirement
|
||||||||||||
|
2016
|
|
2015
|
|
2016
|
|
2015
|
||||||||
|
|
|
|
|
|
|
|
||||||||
Plan assets at fair value, beginning of year
|
$
|
2,489
|
|
|
$
|
2,718
|
|
|
$
|
662
|
|
|
$
|
858
|
|
Employer contributions
|
78
|
|
|
13
|
|
|
2
|
|
|
2
|
|
||||
Participant contributions
|
—
|
|
|
—
|
|
|
10
|
|
|
9
|
|
||||
Actual return on plan assets
|
163
|
|
|
(17
|
)
|
|
41
|
|
|
—
|
|
||||
Settlement
|
(11
|
)
|
|
(23
|
)
|
|
—
|
|
|
(150
|
)
|
||||
Benefits paid
|
(194
|
)
|
|
(202
|
)
|
|
(49
|
)
|
|
(57
|
)
|
||||
Plan assets at fair value, end of year
|
$
|
2,525
|
|
|
$
|
2,489
|
|
|
$
|
666
|
|
|
$
|
662
|
|
|
Pension
|
|
Other Postretirement
|
||||||||||||
|
2016
|
|
2015
|
|
2016
|
|
2015
|
||||||||
|
|
|
|
|
|
|
|
||||||||
Benefit obligation, beginning of year
|
$
|
2,934
|
|
|
$
|
3,119
|
|
|
$
|
740
|
|
|
$
|
936
|
|
Service cost
|
29
|
|
|
33
|
|
|
9
|
|
|
11
|
|
||||
Interest cost
|
126
|
|
|
121
|
|
|
31
|
|
|
31
|
|
||||
Participant contributions
|
—
|
|
|
—
|
|
|
10
|
|
|
9
|
|
||||
Actuarial loss (gain)
|
67
|
|
|
(110
|
)
|
|
(7
|
)
|
|
(43
|
)
|
||||
Amendment
|
1
|
|
|
(4
|
)
|
|
—
|
|
|
3
|
|
||||
Settlement
|
(11
|
)
|
|
(23
|
)
|
|
—
|
|
|
(150
|
)
|
||||
Benefits paid
|
(194
|
)
|
|
(202
|
)
|
|
(49
|
)
|
|
(57
|
)
|
||||
Benefit obligation, end of year
|
$
|
2,952
|
|
|
$
|
2,934
|
|
|
$
|
734
|
|
|
$
|
740
|
|
Accumulated benefit obligation, end of year
|
$
|
2,929
|
|
|
$
|
2,906
|
|
|
|
|
|
|
Pension
|
|
Other Postretirement
|
||||||||||||
|
2016
|
|
2015
|
|
2016
|
|
2015
|
||||||||
|
|
|
|
|
|
|
|
||||||||
Plan assets at fair value, end of year
|
$
|
2,525
|
|
|
$
|
2,489
|
|
|
$
|
666
|
|
|
$
|
662
|
|
Benefit obligation, end of year
|
2,952
|
|
|
2,934
|
|
|
734
|
|
|
740
|
|
||||
Funded status
|
$
|
(427
|
)
|
|
$
|
(445
|
)
|
|
$
|
(68
|
)
|
|
$
|
(78
|
)
|
|
|
|
|
|
|
|
|
||||||||
Amounts recognized on the Consolidated Balance Sheets:
|
|
|
|
|
|
|
|
||||||||
Other assets
|
$
|
26
|
|
|
$
|
7
|
|
|
$
|
19
|
|
|
$
|
15
|
|
Other current liabilities
|
(15
|
)
|
|
(15
|
)
|
|
—
|
|
|
—
|
|
||||
Other long-term liabilities
|
(438
|
)
|
|
(437
|
)
|
|
(87
|
)
|
|
(93
|
)
|
||||
Amounts recognized
|
$
|
(427
|
)
|
|
$
|
(445
|
)
|
|
$
|
(68
|
)
|
|
$
|
(78
|
)
|
|
Pension
|
|
Other Postretirement
|
||||||||||||
|
2016
|
|
2015
|
|
2016
|
|
2015
|
||||||||
|
|
|
|
|
|
|
|
||||||||
Fair value of plan assets
|
$
|
1,841
|
|
|
$
|
1,811
|
|
|
$
|
413
|
|
|
$
|
413
|
|
|
|
|
|
|
|
|
|
||||||||
Projected benefit obligation
|
$
|
2,294
|
|
|
$
|
2,263
|
|
|
$
|
500
|
|
|
$
|
505
|
|
|
|
|
|
|
|
|
|
||||||||
Accumulated benefit obligation
|
$
|
2,278
|
|
|
$
|
2,244
|
|
|
|
|
|
|
Pension
|
|
Other Postretirement
|
||||||||||||
|
2016
|
|
2015
|
|
2016
|
|
2015
|
||||||||
|
|
|
|
|
|
|
|
||||||||
Net loss
|
$
|
775
|
|
|
$
|
768
|
|
|
$
|
88
|
|
|
$
|
97
|
|
Prior service credit
|
(7
|
)
|
|
(25
|
)
|
|
(52
|
)
|
|
(68
|
)
|
||||
Regulatory deferrals
|
(7
|
)
|
|
(2
|
)
|
|
7
|
|
|
8
|
|
||||
Total
|
$
|
761
|
|
|
$
|
741
|
|
|
$
|
43
|
|
|
$
|
37
|
|
|
|
|
|
|
Accumulated
|
|
|
||||||||
|
|
|
|
|
Other
|
|
|
||||||||
|
Regulatory
|
|
Regulatory
|
|
Comprehensive
|
|
|
||||||||
|
Asset
|
|
Liability
|
|
Loss
|
|
Total
|
||||||||
Pension
|
|
|
|
|
|
|
|
||||||||
Balance, December 31, 2014
|
$
|
710
|
|
|
$
|
(6
|
)
|
|
$
|
19
|
|
|
$
|
723
|
|
Net loss (gain) arising during the year
|
76
|
|
|
5
|
|
|
(6
|
)
|
|
75
|
|
||||
Net prior service credit arising during the year
|
(4
|
)
|
|
—
|
|
|
—
|
|
|
(4
|
)
|
||||
Net amortization
|
(53
|
)
|
|
—
|
|
|
—
|
|
|
(53
|
)
|
||||
Total
|
19
|
|
|
5
|
|
|
(6
|
)
|
|
18
|
|
||||
Balance, December 31, 2015
|
729
|
|
|
(1
|
)
|
|
13
|
|
|
741
|
|
||||
Net loss arising during the year
|
76
|
|
|
(11
|
)
|
|
—
|
|
|
65
|
|
||||
Net prior service cost arising during the year
|
1
|
|
|
—
|
|
|
—
|
|
|
1
|
|
||||
Net amortization
|
(45
|
)
|
|
(1
|
)
|
|
—
|
|
|
(46
|
)
|
||||
Total
|
32
|
|
|
(12
|
)
|
|
—
|
|
|
20
|
|
||||
Balance, December 31, 2016
|
$
|
761
|
|
|
$
|
(13
|
)
|
|
$
|
13
|
|
|
$
|
761
|
|
|
Regulatory
|
|
Regulatory
|
|
|
||||||
|
Asset
|
|
Liability
|
|
Total
|
||||||
Other Postretirement
|
|
|
|
|
|
||||||
Balance, December 31, 2014
|
$
|
37
|
|
|
$
|
(14
|
)
|
|
$
|
23
|
|
Net (gain) loss arising during the year
|
(1
|
)
|
|
1
|
|
|
—
|
|
|||
Net prior service cost arising during the year
|
3
|
|
|
—
|
|
|
3
|
|
|||
Net amortization
|
10
|
|
|
1
|
|
|
11
|
|
|||
Total
|
12
|
|
|
2
|
|
|
14
|
|
|||
Balance, December 31, 2015
|
49
|
|
|
(12
|
)
|
|
37
|
|
|||
Net gain arising during the year
|
(5
|
)
|
|
(1
|
)
|
|
(6
|
)
|
|||
Net amortization
|
11
|
|
|
1
|
|
|
12
|
|
|||
Total
|
6
|
|
|
—
|
|
|
6
|
|
|||
Balance, December 31, 2016
|
$
|
55
|
|
|
$
|
(12
|
)
|
|
$
|
43
|
|
|
Net
|
|
Prior Service
|
|
Regulatory
|
|
|
||||||||
|
Loss
|
|
Credit
|
|
Deferrals
|
|
Total
|
||||||||
|
|
|
|
|
|
|
|
||||||||
Pension
|
$
|
33
|
|
|
$
|
(3
|
)
|
|
$
|
(2
|
)
|
|
$
|
28
|
|
Other postretirement
|
2
|
|
|
(16
|
)
|
|
1
|
|
|
(13
|
)
|
||||
Total
|
$
|
35
|
|
|
$
|
(19
|
)
|
|
$
|
(1
|
)
|
|
$
|
15
|
|
|
Pension
|
|
Other Postretirement
|
||||||||||||||
|
2016
|
|
2015
|
|
2014
|
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Benefit obligations as of December 31:
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Discount rate
|
4.06
|
%
|
|
4.43
|
%
|
|
4.00
|
%
|
|
4.01
|
%
|
|
4.33
|
%
|
|
3.88
|
%
|
Rate of compensation increase
|
2.75
|
%
|
|
2.75
|
%
|
|
2.75
|
%
|
|
N/A
|
|
|
N/A
|
|
|
N/A
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Net periodic benefit cost for the years ended December 31:
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Discount rate
|
4.43
|
%
|
|
4.00
|
%
|
|
4.81
|
%
|
|
4.33
|
%
|
|
3.93
|
%
|
|
4.82
|
%
|
Expected return on plan assets
|
6.78
|
%
|
|
6.88
|
%
|
|
6.86
|
%
|
|
7.03
|
%
|
|
7.00
|
%
|
|
7.34
|
%
|
Rate of compensation increase
|
2.75
|
%
|
|
2.75
|
%
|
|
3.00
|
%
|
|
N/A
|
|
|
N/A
|
|
|
N/A
|
|
|
2016
|
|
2015
|
||
Assumed healthcare cost trend rates as of December 31:
|
|
|
|
||
Healthcare cost trend rate assumed for next year
|
7.40
|
%
|
|
7.70
|
%
|
Rate that the cost trend rate gradually declines to
|
5.00
|
%
|
|
5.00
|
%
|
Year that the rate reaches the rate it is assumed to remain at
|
2025
|
|
2025
|
|
One Percentage-Point
|
||||||
|
Increase
|
|
Decrease
|
||||
Increase (decrease) in:
|
|
|
|
||||
Total service and interest cost for the year ended December 31, 2016
|
$
|
1
|
|
|
$
|
—
|
|
Other postretirement benefit obligation as of December 31, 2016
|
4
|
|
|
(4
|
)
|
|
|
|
Other
|
|
Pension
|
|
Postretirement
|
|
%
|
|
%
|
PacifiCorp:
|
|
|
|
Debt securities
(1)
|
33-37
|
|
33-37
|
Equity securities
(1)
|
53-57
|
|
61-65
|
Limited partnership interests
|
8-12
|
|
1-3
|
Other
|
0-1
|
|
0-1
|
|
|
|
|
MidAmerican Energy:
|
|
|
|
Debt securities
(1)
|
20-40
|
|
25-45
|
Equity securities
(1)
|
60-80
|
|
50-80
|
Real estate funds
|
2-8
|
|
—
|
Other
|
0-5
|
|
0-5
|
|
|
|
|
NV Energy:
|
|
|
|
Debt securities
(1)
|
53-77
|
|
40
|
Equity securities
(1)
|
23-47
|
|
60
|
(1)
|
For purposes of target allocation percentages and consistent with the plans' investment policy, investment funds are allocated based on the underlying investments in debt and equity securities.
|
|
Input Levels for Fair Value Measurements
(1)
|
|
|
||||||||||||
|
Level 1
|
|
Level 2
|
|
Level 3
|
|
Total
|
||||||||
As of December 31, 2016:
|
|
|
|
|
|
|
|
||||||||
Cash equivalents
|
$
|
4
|
|
|
$
|
54
|
|
|
$
|
—
|
|
|
$
|
58
|
|
Debt securities:
|
|
|
|
|
|
|
|
||||||||
United States government obligations
|
161
|
|
|
—
|
|
|
—
|
|
|
161
|
|
||||
International government obligations
|
—
|
|
|
2
|
|
|
—
|
|
|
2
|
|
||||
Corporate obligations
|
—
|
|
|
295
|
|
|
—
|
|
|
295
|
|
||||
Municipal obligations
|
—
|
|
|
20
|
|
|
—
|
|
|
20
|
|
||||
Agency, asset and mortgage-backed obligations
|
—
|
|
|
112
|
|
|
—
|
|
|
112
|
|
||||
Equity securities:
|
|
|
|
|
|
|
|
||||||||
United States companies
|
583
|
|
|
—
|
|
|
—
|
|
|
583
|
|
||||
International companies
|
117
|
|
|
—
|
|
|
—
|
|
|
117
|
|
||||
Investment funds
(2)
|
146
|
|
|
—
|
|
|
—
|
|
|
146
|
|
||||
Total assets in the fair value hierarchy
|
$
|
1,011
|
|
|
$
|
483
|
|
|
$
|
—
|
|
|
1,494
|
|
|
Investment funds
(2)
measured at net asset value
|
|
|
|
|
|
|
920
|
|
|||||||
Limited partnership interests
(3)
measured at net asset value
|
|
|
|
|
|
|
61
|
|
|||||||
Real estate funds measured at net asset value
|
|
|
|
|
|
|
50
|
|
|||||||
Total assets measured at fair value
|
|
|
|
|
|
|
$
|
2,525
|
|
||||||
|
|
|
|
|
|
|
|
||||||||
As of December 31, 2015:
|
|
|
|
|
|
|
|
||||||||
Cash equivalents
|
$
|
—
|
|
|
$
|
26
|
|
|
$
|
—
|
|
|
$
|
26
|
|
Debt securities:
|
|
|
|
|
|
|
|
||||||||
United States government obligations
|
155
|
|
|
—
|
|
|
—
|
|
|
155
|
|
||||
International government obligations
|
—
|
|
|
4
|
|
|
—
|
|
|
4
|
|
||||
Corporate obligations
|
—
|
|
|
335
|
|
|
—
|
|
|
335
|
|
||||
Municipal obligations
|
—
|
|
|
25
|
|
|
—
|
|
|
25
|
|
||||
Agency, asset and mortgage-backed obligations
|
—
|
|
|
154
|
|
|
—
|
|
|
154
|
|
||||
Equity securities:
|
|
|
|
|
|
|
|
||||||||
United States companies
|
586
|
|
|
—
|
|
|
—
|
|
|
586
|
|
||||
International companies
|
122
|
|
|
—
|
|
|
—
|
|
|
122
|
|
||||
Investment funds
(2)
|
144
|
|
|
—
|
|
|
—
|
|
|
144
|
|
||||
Total assets in the fair value hierarchy
|
$
|
1,007
|
|
|
$
|
544
|
|
|
$
|
—
|
|
|
1,551
|
|
|
Investment funds
(2)
measured at net asset value
|
|
|
|
|
|
|
823
|
|
|||||||
Limited partnership interests
(3)
measured at net asset value
|
|
|
|
|
|
|
65
|
|
|||||||
Real estate funds measured at net asset value
|
|
|
|
|
|
|
50
|
|
|||||||
Total assets measured at fair value
|
|
|
|
|
|
|
$
|
2,489
|
|
(1)
|
Refer to Note
15
for additional discussion regarding the three levels of the fair value hierarchy.
|
(2)
|
Investment funds are comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately
62%
and
38%
, respectively, for
2016
and
66%
and
34%
, respectively, for
2015
. Additionally, these funds are invested in United States and international securities of approximately
60%
and
40%
, respectively, for
2016
and
58%
and
42%
, respectively, for
2015
.
|
(3)
|
Limited partnership interests include several funds that invest primarily in real estate, buyout, growth equity and venture capital.
|
|
Input Levels for Fair Value Measurements
(1)
|
|
|
||||||||||||
|
Level 1
|
|
Level 2
|
|
Level 3
|
|
Total
|
||||||||
As of December 31, 2016:
|
|
|
|
|
|
|
|
||||||||
Cash equivalents
|
$
|
18
|
|
|
$
|
2
|
|
|
$
|
—
|
|
|
$
|
20
|
|
Debt securities:
|
|
|
|
|
|
|
|
||||||||
United States government obligations
|
19
|
|
|
—
|
|
|
—
|
|
|
19
|
|
||||
Corporate obligations
|
—
|
|
|
29
|
|
|
—
|
|
|
29
|
|
||||
Municipal obligations
|
—
|
|
|
39
|
|
|
—
|
|
|
39
|
|
||||
Agency, asset and mortgage-backed obligations
|
—
|
|
|
25
|
|
|
—
|
|
|
25
|
|
||||
Equity securities:
|
|
|
|
|
|
|
|
||||||||
United States companies
|
217
|
|
|
—
|
|
|
—
|
|
|
217
|
|
||||
International companies
|
5
|
|
|
—
|
|
|
—
|
|
|
5
|
|
||||
Investment funds
(2)
|
152
|
|
|
—
|
|
|
—
|
|
|
152
|
|
||||
Total assets in the fair value hierarchy
|
$
|
411
|
|
|
$
|
95
|
|
|
$
|
—
|
|
|
506
|
|
|
Investment funds
(2)
measured at net asset value
|
|
|
|
|
|
|
156
|
|
|||||||
Limited partnership interests
(3)
measured at net asset value
|
|
|
|
|
|
|
4
|
|
|||||||
Total assets measured at fair value
|
|
|
|
|
|
|
$
|
666
|
|
||||||
|
|
|
|
|
|
|
|
||||||||
As of December 31, 2015:
|
|
|
|
|
|
|
|
||||||||
Cash equivalents
|
$
|
12
|
|
|
$
|
1
|
|
|
$
|
—
|
|
|
$
|
13
|
|
Debt securities:
|
|
|
|
|
|
|
|
||||||||
United States government obligations
|
18
|
|
|
—
|
|
|
—
|
|
|
18
|
|
||||
Corporate obligations
|
—
|
|
|
33
|
|
|
—
|
|
|
33
|
|
||||
Municipal obligations
|
—
|
|
|
41
|
|
|
—
|
|
|
41
|
|
||||
Agency, asset and mortgage-backed obligations
|
—
|
|
|
28
|
|
|
—
|
|
|
28
|
|
||||
Equity securities:
|
|
|
|
|
|
|
|
||||||||
United States companies
|
216
|
|
|
—
|
|
|
—
|
|
|
216
|
|
||||
International companies
|
6
|
|
|
—
|
|
|
—
|
|
|
6
|
|
||||
Investment funds
(2)
|
149
|
|
|
—
|
|
|
—
|
|
|
149
|
|
||||
Total assets in the fair value hierarchy
|
$
|
401
|
|
|
$
|
103
|
|
|
$
|
—
|
|
|
504
|
|
|
Investment funds
(2)
measured at net asset value
|
|
|
|
|
|
|
154
|
|
|||||||
Limited partnership interests
(3)
measured at net asset value
|
|
|
|
|
|
|
4
|
|
|||||||
Total assets measured at fair value
|
|
|
|
|
|
|
$
|
662
|
|
(1)
|
Refer to Note
15
for additional discussion regarding the three levels of the fair value hierarchy.
|
(2)
|
Investment funds are comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately
63%
and
37%
, respectively, for both
2016
and
2015
. Additionally, these funds are invested in United States and international securities of approximately
72%
and
28%
, respectively, for
2016
and
70%
and
30%
, respectively, for
2015
.
|
(3)
|
Limited partnership interests include several funds that invest primarily in real estate, buyout, growth equity and venture capital.
|
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Service cost
|
$
|
20
|
|
|
$
|
24
|
|
|
$
|
24
|
|
Interest cost
|
72
|
|
|
79
|
|
|
95
|
|
|||
Expected return on plan assets
|
(110
|
)
|
|
(116
|
)
|
|
(124
|
)
|
|||
Net amortization
|
44
|
|
|
62
|
|
|
51
|
|
|||
Net periodic benefit cost
|
$
|
26
|
|
|
$
|
49
|
|
|
$
|
46
|
|
|
2016
|
|
2015
|
||||
|
|
|
|
||||
Plan assets at fair value, beginning of year
|
$
|
2,276
|
|
|
$
|
2,368
|
|
Employer contributions
|
55
|
|
|
77
|
|
||
Participant contributions
|
1
|
|
|
2
|
|
||
Actual return on plan assets
|
349
|
|
|
48
|
|
||
Benefits paid
|
(115
|
)
|
|
(91
|
)
|
||
Foreign currency exchange rate changes
|
(397
|
)
|
|
(128
|
)
|
||
Plan assets at fair value, end of year
|
$
|
2,169
|
|
|
$
|
2,276
|
|
|
2016
|
|
2015
|
||||
|
|
|
|
||||
Benefit obligation, beginning of year
|
$
|
2,142
|
|
|
$
|
2,279
|
|
Service cost
|
20
|
|
|
24
|
|
||
Interest cost
|
72
|
|
|
79
|
|
||
Participant contributions
|
1
|
|
|
2
|
|
||
Actuarial loss (gain)
|
387
|
|
|
(30
|
)
|
||
Benefits paid
|
(115
|
)
|
|
(91
|
)
|
||
Foreign currency exchange rate changes
|
(382
|
)
|
|
(121
|
)
|
||
Benefit obligation, end of year
|
$
|
2,125
|
|
|
$
|
2,142
|
|
Accumulated benefit obligation, end of year
|
$
|
1,858
|
|
|
$
|
1,891
|
|
|
2016
|
|
2015
|
||||
|
|
|
|
||||
Plan assets at fair value, end of year
|
$
|
2,169
|
|
|
$
|
2,276
|
|
Benefit obligation, end of year
|
2,125
|
|
|
2,142
|
|
||
Funded status
|
$
|
44
|
|
|
$
|
134
|
|
|
|
|
|
||||
Amounts recognized on the Consolidated Balance Sheets:
|
|
|
|
||||
Other assets
|
$
|
44
|
|
|
$
|
134
|
|
|
2016
|
|
2015
|
||||
|
|
|
|
||||
Net loss
|
$
|
590
|
|
|
$
|
592
|
|
|
2016
|
|
2015
|
||||
|
|
|
|
||||
Balance, beginning of year
|
$
|
592
|
|
|
$
|
655
|
|
Net loss arising during the year
|
148
|
|
|
38
|
|
||
Net amortization
|
(44
|
)
|
|
(62
|
)
|
||
Foreign currency exchange rate changes
|
(106
|
)
|
|
(39
|
)
|
||
Total
|
(2
|
)
|
|
(63
|
)
|
||
Balance, end of year
|
$
|
590
|
|
|
$
|
592
|
|
|
2016
|
|
2015
|
|
2014
|
|||
|
|
|
|
|
|
|||
Benefit obligations as of December 31:
|
|
|
|
|
|
|||
Discount rate
|
2.70
|
%
|
|
3.70
|
%
|
|
3.60
|
%
|
Rate of compensation increase
|
3.00
|
%
|
|
2.90
|
%
|
|
2.80
|
%
|
Rate of future price inflation
|
3.00
|
%
|
|
2.90
|
%
|
|
2.80
|
%
|
|
|
|
|
|
|
|||
Net periodic benefit cost for the years ended December 31:
|
|
|
|
|
|
|||
Discount rate
|
3.70
|
%
|
|
3.60
|
%
|
|
4.40
|
%
|
Expected return on plan assets
|
5.60
|
%
|
|
5.60
|
%
|
|
6.10
|
%
|
Rate of compensation increase
|
2.90
|
%
|
|
2.80
|
%
|
|
3.15
|
%
|
Rate of future price inflation
|
2.90
|
%
|
|
2.80
|
%
|
|
3.15
|
%
|
2017
|
$
|
75
|
|
2018
|
77
|
|
|
2019
|
79
|
|
|
2020
|
81
|
|
|
2021
|
83
|
|
|
2022-2026
|
448
|
|
(1)
|
For purposes of target allocation percentages and consistent with the plans' investment policy, investment funds have been allocated based on the underlying investments in debt and equity securities.
|
|
Input Levels for Fair Value Measurements
(1)
|
|
|
||||||||||||
|
Level 1
|
|
Level 2
|
|
Level 3
|
|
Total
|
||||||||
As of December 31, 2016:
|
|
|
|
|
|
|
|
||||||||
Cash equivalents
|
$
|
4
|
|
|
$
|
83
|
|
|
$
|
—
|
|
|
$
|
87
|
|
Debt securities:
|
|
|
|
|
|
|
|
||||||||
United Kingdom government obligations
|
718
|
|
|
—
|
|
|
—
|
|
|
718
|
|
||||
Equity securities:
|
|
|
|
|
|
|
|
||||||||
Investment funds
(2)
|
—
|
|
|
1,095
|
|
|
—
|
|
|
1,095
|
|
||||
Real estate funds
|
—
|
|
|
—
|
|
|
105
|
|
|
105
|
|
||||
Total
|
$
|
722
|
|
|
$
|
1,178
|
|
|
$
|
105
|
|
|
2,005
|
|
|
Investment funds
(2)
measured at net asset value
|
|
|
|
|
|
|
164
|
|
|||||||
Total assets measured at fair value
|
|
|
|
|
|
|
$
|
2,169
|
|
||||||
|
|
|
|
|
|
|
|
||||||||
As of December 31, 2015:
|
|
|
|
|
|
|
|
||||||||
Cash equivalents
|
$
|
46
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
46
|
|
Debt securities:
|
|
|
|
|
|
|
|
||||||||
United Kingdom government obligations
|
424
|
|
|
—
|
|
|
—
|
|
|
424
|
|
||||
Other international government obligations
|
—
|
|
|
13
|
|
|
—
|
|
|
13
|
|
||||
Corporate obligations
|
—
|
|
|
186
|
|
|
—
|
|
|
186
|
|
||||
Equity securities:
|
|
|
|
|
|
|
|
||||||||
Investment funds
(2)
|
24
|
|
|
1,189
|
|
|
—
|
|
|
1,213
|
|
||||
Real estate funds
|
—
|
|
|
—
|
|
|
204
|
|
|
204
|
|
||||
Total
|
$
|
494
|
|
|
$
|
1,388
|
|
|
$
|
204
|
|
|
2,086
|
|
|
Investment funds
(2)
measured at net asset value
|
|
|
|
|
|
|
190
|
|
|||||||
Total assets measured at fair value
|
|
|
|
|
|
|
$
|
2,276
|
|
(1)
|
Refer to Note
15
for additional discussion regarding the three levels of the fair value hierarchy.
|
(2)
|
Investment funds are comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately
44%
and
56%
, respectively, for both
2016
and
2015
.
|
|
Real Estate Funds
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Beginning balance
|
$
|
204
|
|
|
$
|
199
|
|
|
$
|
179
|
|
Actual return on plan assets still held at period end
|
10
|
|
|
18
|
|
|
33
|
|
|||
Sales
|
(80
|
)
|
|
—
|
|
|
—
|
|
|||
Foreign currency exchange rate changes
|
(29
|
)
|
|
(13
|
)
|
|
(13
|
)
|
|||
Ending balance
|
$
|
105
|
|
|
$
|
204
|
|
|
$
|
199
|
|
(
13
)
|
Asset Retirement Obligations
|
|
2016
|
|
2015
|
||||
|
|
|
|
||||
Fossil fuel facilities
|
$
|
404
|
|
|
$
|
443
|
|
Quad Cities Station
|
343
|
|
|
289
|
|
||
Wind generating facilities
|
124
|
|
|
104
|
|
||
Offshore pipeline facilities
|
33
|
|
|
31
|
|
||
Solar generating facilities
|
12
|
|
|
12
|
|
||
Other
|
38
|
|
|
42
|
|
||
Total asset retirement obligations
|
$
|
954
|
|
|
$
|
921
|
|
|
|
|
|
||||
Quad Cities Station nuclear decommissioning trust funds
|
$
|
460
|
|
|
$
|
429
|
|
|
2016
|
|
2015
|
||||
|
|
|
|
||||
Beginning balance
|
$
|
921
|
|
|
$
|
753
|
|
Change in estimated costs
|
33
|
|
|
104
|
|
||
Additions
|
25
|
|
|
59
|
|
||
Retirements
|
(63
|
)
|
|
(32
|
)
|
||
Accretion
|
38
|
|
|
37
|
|
||
Ending balance
|
$
|
954
|
|
|
$
|
921
|
|
|
|
|
|
||||
Reflected as:
|
|
|
|
||||
Other current liabilities
|
$
|
98
|
|
|
$
|
92
|
|
Other long-term liabilities
|
856
|
|
|
829
|
|
||
Total ARO liability
|
$
|
954
|
|
|
$
|
921
|
|
|
Other
|
|
|
|
Other
|
|
Other
|
|
|
||||||||||
|
Current
|
|
Other
|
|
Current
|
|
Long-term
|
|
|
||||||||||
|
Assets
|
|
Assets
|
|
Liabilities
|
|
Liabilities
|
|
Total
|
||||||||||
As of December 31, 2016:
|
|
|
|
|
|
|
|
|
|
||||||||||
Not designated as hedging contracts:
|
|
|
|
|
|
|
|
|
|
||||||||||
Commodity assets
(1)
|
$
|
42
|
|
|
$
|
86
|
|
|
$
|
5
|
|
|
$
|
2
|
|
|
$
|
135
|
|
Commodity liabilities
(1)
|
(10
|
)
|
|
—
|
|
|
(46
|
)
|
|
(150
|
)
|
|
(206
|
)
|
|||||
Interest rate assets
|
15
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
15
|
|
|||||
Interest rate liabilities
|
—
|
|
|
—
|
|
|
(4
|
)
|
|
(6
|
)
|
|
(10
|
)
|
|||||
Total
|
47
|
|
|
86
|
|
|
(45
|
)
|
|
(154
|
)
|
|
(66
|
)
|
|||||
|
|
|
|
|
|
|
|
|
|
||||||||||
Designated as hedging contracts:
|
|
|
|
|
|
|
|
|
|
||||||||||
Commodity assets
|
1
|
|
|
—
|
|
|
2
|
|
|
3
|
|
|
6
|
|
|||||
Commodity liabilities
|
—
|
|
|
—
|
|
|
(14
|
)
|
|
(8
|
)
|
|
(22
|
)
|
|||||
Interest rate assets
|
—
|
|
|
8
|
|
|
—
|
|
|
—
|
|
|
8
|
|
|||||
Interest rate liabilities
|
—
|
|
|
—
|
|
|
(3
|
)
|
|
—
|
|
|
(3
|
)
|
|||||
Total
|
1
|
|
|
8
|
|
|
(15
|
)
|
|
(5
|
)
|
|
(11
|
)
|
|||||
|
|
|
|
|
|
|
|
|
|
||||||||||
Total derivatives
|
48
|
|
|
94
|
|
|
(60
|
)
|
|
(159
|
)
|
|
(77
|
)
|
|||||
Cash collateral receivable
|
—
|
|
|
—
|
|
|
13
|
|
|
61
|
|
|
74
|
|
|||||
Total derivatives - net basis
|
$
|
48
|
|
|
$
|
94
|
|
|
$
|
(47
|
)
|
|
$
|
(98
|
)
|
|
$
|
(3
|
)
|
(1)
|
The Company's commodity derivatives not designated as hedging contracts are generally included in regulated rates, and as of December 31,
2016
and
2015
, a net regulatory asset of
$148 million
and
$250 million
, respectively, was recorded related to the net derivative liability of
$71 million
and
$186 million
, respectively. The difference between the net regulatory asset and the net derivative liability relates primarily to a power purchase agreement derivative at BHE Renewables.
|
|
Commodity Derivatives
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Beginning balance
|
$
|
250
|
|
|
$
|
223
|
|
|
$
|
182
|
|
Changes in fair value recognized in net regulatory assets
|
(30
|
)
|
|
128
|
|
|
96
|
|
|||
Net (losses) gains reclassified to operating revenue
|
(5
|
)
|
|
1
|
|
|
(32
|
)
|
|||
Net losses reclassified to cost of sales
|
(67
|
)
|
|
(102
|
)
|
|
(23
|
)
|
|||
Ending balance
|
$
|
148
|
|
|
$
|
250
|
|
|
$
|
223
|
|
|
Commodity Derivatives
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Beginning balance
|
$
|
46
|
|
|
$
|
32
|
|
|
$
|
12
|
|
Changes in fair value recognized in OCI
|
26
|
|
|
52
|
|
|
(6
|
)
|
|||
Net gains reclassified to operating revenue
|
1
|
|
|
9
|
|
|
—
|
|
|||
Net (losses) gains reclassified to cost of sales
|
(57
|
)
|
|
(47
|
)
|
|
26
|
|
|||
Ending balance
|
$
|
16
|
|
|
$
|
46
|
|
|
$
|
32
|
|
|
Unit of
|
|
|
|
|
||
|
Measure
|
|
2016
|
|
2015
|
||
Electricity purchases
|
Megawatt hours
|
|
5
|
|
|
10
|
|
Natural gas purchases
|
Decatherms
|
|
271
|
|
|
317
|
|
Fuel purchases
|
Gallons
|
|
11
|
|
|
11
|
|
Interest rate swaps
|
US$
|
|
714
|
|
|
653
|
|
Mortgage commitments, net
|
US$
|
|
(309
|
)
|
|
(312
|
)
|
•
|
Level 1 - Inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the Company has the ability to access at the measurement date.
|
•
|
Level 2 - Inputs include quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, inputs other than quoted prices that are observable for the asset or liability and inputs that are derived principally from or corroborated by observable market data by correlation or other means (market corroborated inputs).
|
•
|
Level 3 - Unobservable inputs reflect the Company's judgments about the assumptions market participants would use in pricing the asset or liability since limited market data exists. The Company develops these inputs based on the best information available, including its own data.
|
|
Input Levels for Fair Value Measurements
|
|
|
|
|
||||||||||||||
|
Level 1
|
|
Level 2
|
|
Level 3
|
|
Other
(1)
|
|
Total
|
||||||||||
As of December 31, 2016:
|
|
|
|
|
|
|
|
|
|
||||||||||
Assets:
|
|
|
|
|
|
|
|
|
|
||||||||||
Commodity derivatives
|
$
|
5
|
|
|
$
|
49
|
|
|
$
|
87
|
|
|
$
|
(22
|
)
|
|
$
|
119
|
|
Interest rate derivatives
|
—
|
|
|
16
|
|
|
7
|
|
|
—
|
|
|
23
|
|
|||||
Mortgage loans held for sale
|
—
|
|
|
359
|
|
|
—
|
|
|
—
|
|
|
359
|
|
|||||
Money market mutual funds
(2)
|
586
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
586
|
|
|||||
Debt securities:
|
|
|
|
|
|
|
|
|
|
||||||||||
United States government obligations
|
161
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
161
|
|
|||||
International government obligations
|
—
|
|
|
3
|
|
|
—
|
|
|
—
|
|
|
3
|
|
|||||
Corporate obligations
|
—
|
|
|
36
|
|
|
—
|
|
|
—
|
|
|
36
|
|
|||||
Municipal obligations
|
—
|
|
|
2
|
|
|
—
|
|
|
—
|
|
|
2
|
|
|||||
Agency, asset and mortgage-backed obligations
|
—
|
|
|
2
|
|
|
—
|
|
|
—
|
|
|
2
|
|
|||||
Equity securities:
|
|
|
|
|
|
|
|
|
|
||||||||||
United States companies
|
250
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
250
|
|
|||||
International companies
|
1,190
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
1,190
|
|
|||||
Investment funds
|
147
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
147
|
|
|||||
|
$
|
2,339
|
|
|
$
|
467
|
|
|
$
|
94
|
|
|
$
|
(22
|
)
|
|
$
|
2,878
|
|
Liabilities:
|
|
|
|
|
|
|
|
|
|
||||||||||
Commodity derivatives
|
$
|
(2
|
)
|
|
$
|
(199
|
)
|
|
$
|
(27
|
)
|
|
$
|
96
|
|
|
$
|
(132
|
)
|
Interest rate derivatives
|
(1
|
)
|
|
(11
|
)
|
|
(1
|
)
|
|
—
|
|
|
(13
|
)
|
|||||
|
$
|
(3
|
)
|
|
$
|
(210
|
)
|
|
$
|
(28
|
)
|
|
$
|
96
|
|
|
$
|
(145
|
)
|
As of December 31, 2015:
|
|
|
|
|
|
|
|
|
|
||||||||||
Assets:
|
|
|
|
|
|
|
|
|
|
||||||||||
Commodity derivatives
|
$
|
—
|
|
|
$
|
16
|
|
|
$
|
93
|
|
|
$
|
(16
|
)
|
|
$
|
93
|
|
Interest rate derivatives
|
—
|
|
|
5
|
|
|
5
|
|
|
—
|
|
|
10
|
|
|||||
Mortgage loans held for sale
|
—
|
|
|
327
|
|
|
—
|
|
|
—
|
|
|
327
|
|
|||||
Money market mutual funds
(2)
|
421
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
421
|
|
|||||
Debt securities:
|
|
|
|
|
|
|
|
|
|
||||||||||
United States government obligations
|
133
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
133
|
|
|||||
International government obligations
|
—
|
|
|
2
|
|
|
—
|
|
|
—
|
|
|
2
|
|
|||||
Corporate obligations
|
—
|
|
|
39
|
|
|
—
|
|
|
—
|
|
|
39
|
|
|||||
Municipal obligations
|
—
|
|
|
1
|
|
|
—
|
|
|
—
|
|
|
1
|
|
|||||
Agency, asset and mortgage-backed obligations
|
—
|
|
|
3
|
|
|
—
|
|
|
—
|
|
|
3
|
|
|||||
Auction rate securities
|
—
|
|
|
—
|
|
|
44
|
|
|
—
|
|
|
44
|
|
|||||
Equity securities:
|
|
|
|
|
|
|
|
|
|
||||||||||
United States companies
|
239
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
239
|
|
|||||
International companies
|
1,244
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
1,244
|
|
|||||
Investment funds
|
136
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
136
|
|
|||||
|
$
|
2,173
|
|
|
$
|
393
|
|
|
$
|
142
|
|
|
$
|
(16
|
)
|
|
$
|
2,692
|
|
Liabilities:
|
|
|
|
|
|
|
|
|
|
||||||||||
Commodity derivatives
|
$
|
(13
|
)
|
|
$
|
(283
|
)
|
|
$
|
(46
|
)
|
|
$
|
119
|
|
|
$
|
(223
|
)
|
Interest rate derivatives
|
—
|
|
|
(13
|
)
|
|
(1
|
)
|
|
—
|
|
|
(14
|
)
|
|||||
|
$
|
(13
|
)
|
|
$
|
(296
|
)
|
|
$
|
(47
|
)
|
|
$
|
119
|
|
|
$
|
(237
|
)
|
(1)
|
Represents netting under master netting arrangements and a net cash collateral receivable of
$74 million
and
$103 million
as of December 31,
2016
and
2015
, respectively.
|
(2)
|
Amounts are included in cash and cash equivalents; other current assets; and noncurrent investments and restricted cash and investments on the Consolidated Balance Sheets. The fair value of these money market mutual funds approximates cost.
|
|
Commodity Derivatives
|
|
Interest Rate Derivatives
|
|
Auction Rate Securities
|
||||||||||||||||||||||||||||||
|
2016
|
|
2015
|
|
2014
|
|
2016
|
|
2015
|
|
2014
|
|
2016
|
|
2015
|
|
2014
|
||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||||||
Beginning balance
|
$
|
47
|
|
|
$
|
51
|
|
|
$
|
60
|
|
|
$
|
4
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
44
|
|
|
$
|
45
|
|
|
$
|
44
|
|
Changes included in earnings
|
8
|
|
|
19
|
|
|
19
|
|
|
121
|
|
|
87
|
|
|
—
|
|
|
5
|
|
|
—
|
|
|
—
|
|
|||||||||
Changes in fair value recognized in OCI
|
(2
|
)
|
|
(7
|
)
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
8
|
|
|
(1
|
)
|
|
1
|
|
|||||||||
Changes in fair value recognized in net regulatory assets
|
(11
|
)
|
|
(19
|
)
|
|
5
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|||||||||
Purchases
|
1
|
|
|
1
|
|
|
1
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|||||||||
Redemptions
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(57
|
)
|
|
—
|
|
|
—
|
|
|||||||||
Settlements
|
17
|
|
|
2
|
|
|
1
|
|
|
(119
|
)
|
|
(86
|
)
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|||||||||
Transfers from Level 2
|
—
|
|
|
—
|
|
|
(35
|
)
|
|
—
|
|
|
3
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|||||||||
Ending balance
|
$
|
60
|
|
|
$
|
47
|
|
|
$
|
51
|
|
|
$
|
6
|
|
|
$
|
4
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
44
|
|
|
$
|
45
|
|
|
2016
|
|
2015
|
||||||||||||
|
Carrying
|
|
Fair
|
|
Carrying
|
|
Fair
|
||||||||
|
Value
|
|
Value
|
|
Value
|
|
Value
|
||||||||
|
|
|
|
|
|
|
|
||||||||
Long-term debt
|
$
|
36,116
|
|
|
$
|
40,718
|
|
|
$
|
37,972
|
|
|
$
|
41,785
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2022 and
|
|
|
||||||||||||||
|
|
2017
|
|
2018
|
|
2019
|
|
2020
|
|
2021
|
|
Thereafter
|
|
Total
|
||||||||||||||
Contract type:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Fuel, capacity and transmission contract commitments
|
|
$
|
2,370
|
|
|
$
|
1,606
|
|
|
$
|
1,389
|
|
|
$
|
1,208
|
|
|
$
|
1,010
|
|
|
$
|
10,053
|
|
|
$
|
17,636
|
|
Construction commitments
|
|
852
|
|
|
49
|
|
|
66
|
|
|
1
|
|
|
1
|
|
|
4
|
|
|
973
|
|
|||||||
Operating leases and easements
|
|
141
|
|
|
122
|
|
|
101
|
|
|
87
|
|
|
73
|
|
|
1,085
|
|
|
1,609
|
|
|||||||
Maintenance, service and other contracts
|
|
303
|
|
|
220
|
|
|
212
|
|
|
186
|
|
|
180
|
|
|
723
|
|
|
1,824
|
|
|||||||
|
|
$
|
3,666
|
|
|
$
|
1,997
|
|
|
$
|
1,768
|
|
|
$
|
1,482
|
|
|
$
|
1,264
|
|
|
$
|
11,865
|
|
|
$
|
22,042
|
|
•
|
MidAmerican Energy's construction of wind-powered generating facilities in 2017 and
two
Multi-Value Projects approved by the Midcontinent Independent System Operator, Inc. for high voltage transmission lines in Iowa and Illinois in 2017.
|
•
|
ALP's investments in directly assigned transmission projects from the
AESO
.
|
•
|
PacifiCorp's costs associated with investments in emissions control equipment and certain transmission and distribution projects.
|
(
17
)
|
BHE Shareholders' Equity
|
|
|
|
|
|
|
|
|
|
|
Accumulated
|
||||||||||
|
|
|
|
|
|
Unrealized
|
|
|
|
Other
|
||||||||||
|
|
Unrecognized
|
|
Foreign
|
|
Gains on
|
|
Unrealized
|
|
Comprehensive
|
||||||||||
|
|
Amounts on
|
|
Currency
|
|
Available-
|
|
Gains on
|
|
Loss Attributable
|
||||||||||
|
|
Retirement
|
|
Translation
|
|
For-Sale
|
|
Cash Flow
|
|
To BHE
|
||||||||||
|
|
Benefits
|
|
Adjustment
|
|
Securities
|
|
Hedges
|
|
Shareholders, Net
|
||||||||||
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Balance, December 31, 2013
|
|
$
|
(559
|
)
|
|
$
|
(98
|
)
|
|
$
|
524
|
|
|
$
|
36
|
|
|
$
|
(97
|
)
|
Other comprehensive income
|
|
69
|
|
|
(314
|
)
|
|
(134
|
)
|
|
(18
|
)
|
|
(397
|
)
|
|||||
Balance, December 31, 2014
|
|
(490
|
)
|
|
(412
|
)
|
|
390
|
|
|
18
|
|
|
(494
|
)
|
|||||
Other comprehensive income (loss)
|
|
52
|
|
|
(680
|
)
|
|
225
|
|
|
(11
|
)
|
|
(414
|
)
|
|||||
Balance, December 31, 2015
|
|
(438
|
)
|
|
(1,092
|
)
|
|
615
|
|
|
7
|
|
|
(908
|
)
|
|||||
Other comprehensive income (loss)
|
|
(9
|
)
|
|
(583
|
)
|
|
(30
|
)
|
|
19
|
|
|
(603
|
)
|
|||||
Balance, December 31, 2016
|
|
$
|
(447
|
)
|
|
$
|
(1,675
|
)
|
|
$
|
585
|
|
|
$
|
26
|
|
|
$
|
(1,511
|
)
|
(
19
)
|
Noncontrolling Interests
|
|
2016
|
|
2015
|
|
2014
|
||||||
Supplemental disclosure of cash flow information:
|
|
|
|
|
|
||||||
Interest paid, net of amounts capitalized
|
$
|
1,673
|
|
|
$
|
1,764
|
|
|
$
|
1,585
|
|
Income taxes received, net
(1)
|
$
|
1,016
|
|
|
$
|
1,666
|
|
|
$
|
635
|
|
|
|
|
|
|
|
||||||
Supplemental disclosure of non-cash investing and financing transactions:
|
|
|
|
|
|
||||||
Accruals related to property, plant and equipment additions
|
$
|
547
|
|
|
$
|
718
|
|
|
$
|
1,143
|
|
(1)
|
Includes
$1.1 billion
,
$1.8 billion
and
$764 million
of income taxes received from Berkshire Hathaway in
2016
,
2015
and
2014
, respectively.
|
|
Years Ended December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
Operating revenue:
|
|
|
|
|
|
||||||
PacifiCorp
|
$
|
5,201
|
|
|
$
|
5,232
|
|
|
$
|
5,252
|
|
MidAmerican Funding
|
2,631
|
|
|
2,515
|
|
|
2,844
|
|
|||
NV Energy
|
2,895
|
|
|
3,351
|
|
|
3,241
|
|
|||
Northern Powergrid
|
995
|
|
|
1,140
|
|
|
1,283
|
|
|||
BHE Pipeline Group
|
978
|
|
|
1,016
|
|
|
1,078
|
|
|||
BHE Transmission
|
502
|
|
|
592
|
|
|
62
|
|
|||
BHE Renewables
|
743
|
|
|
728
|
|
|
623
|
|
|||
HomeServices
|
2,801
|
|
|
2,526
|
|
|
2,144
|
|
|||
BHE and Other
(1)
|
676
|
|
|
780
|
|
|
799
|
|
|||
Total operating revenue
|
$
|
17,422
|
|
|
$
|
17,880
|
|
|
$
|
17,326
|
|
|
|
|
|
|
|
||||||
Depreciation and amortization:
|
|
|
|
|
|
||||||
PacifiCorp
|
$
|
783
|
|
|
$
|
780
|
|
|
$
|
745
|
|
MidAmerican Funding
|
479
|
|
|
407
|
|
|
351
|
|
|||
NV Energy
|
421
|
|
|
410
|
|
|
379
|
|
|||
Northern Powergrid
|
200
|
|
|
202
|
|
|
198
|
|
|||
BHE Pipeline Group
|
206
|
|
|
204
|
|
|
196
|
|
|||
BHE Transmission
|
241
|
|
|
185
|
|
|
13
|
|
|||
BHE Renewables
|
230
|
|
|
216
|
|
|
152
|
|
|||
HomeServices
|
31
|
|
|
29
|
|
|
29
|
|
|||
BHE and Other
(1)
|
—
|
|
|
(5
|
)
|
|
(6
|
)
|
|||
Total depreciation and amortization
|
$
|
2,591
|
|
|
$
|
2,428
|
|
|
$
|
2,057
|
|
|
|
|
|
|
|
||||||
Operating income:
|
|
|
|
|
|
||||||
PacifiCorp
|
$
|
1,427
|
|
|
$
|
1,344
|
|
|
$
|
1,308
|
|
MidAmerican Funding
|
566
|
|
|
451
|
|
|
395
|
|
|||
NV Energy
|
770
|
|
|
812
|
|
|
791
|
|
|||
Northern Powergrid
|
494
|
|
|
593
|
|
|
674
|
|
|||
BHE Pipeline Group
|
455
|
|
|
464
|
|
|
439
|
|
|||
BHE Transmission
|
92
|
|
|
260
|
|
|
16
|
|
|||
BHE Renewables
|
256
|
|
|
255
|
|
|
314
|
|
|||
HomeServices
|
212
|
|
|
184
|
|
|
125
|
|
|||
BHE and Other
(1)
|
(21
|
)
|
|
(35
|
)
|
|
(16
|
)
|
|||
Total operating income
|
4,251
|
|
|
4,328
|
|
|
4,046
|
|
|||
Interest expense
|
(1,854
|
)
|
|
(1,904
|
)
|
|
(1,711
|
)
|
|||
Capitalized interest
|
139
|
|
|
74
|
|
|
89
|
|
|||
Allowance for equity funds
|
158
|
|
|
91
|
|
|
98
|
|
|||
Interest and dividend income
|
120
|
|
|
107
|
|
|
38
|
|
|||
Other, net
|
36
|
|
|
39
|
|
|
42
|
|
|||
Total income before income tax expense and equity income (loss)
|
$
|
2,850
|
|
|
$
|
2,735
|
|
|
$
|
2,602
|
|
|
Years Ended December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
Interest expense:
|
|
|
|
|
|
||||||
PacifiCorp
|
$
|
381
|
|
|
$
|
383
|
|
|
$
|
386
|
|
MidAmerican Funding
|
218
|
|
|
206
|
|
|
197
|
|
|||
NV Energy
|
250
|
|
|
262
|
|
|
283
|
|
|||
Northern Powergrid
|
136
|
|
|
145
|
|
|
151
|
|
|||
BHE Pipeline Group
|
50
|
|
|
66
|
|
|
76
|
|
|||
BHE Transmission
|
153
|
|
|
146
|
|
|
14
|
|
|||
BHE Renewables
|
198
|
|
|
193
|
|
|
175
|
|
|||
HomeServices
|
2
|
|
|
3
|
|
|
4
|
|
|||
BHE and Other
(1)
|
466
|
|
|
500
|
|
|
425
|
|
|||
Total interest expense
|
$
|
1,854
|
|
|
$
|
1,904
|
|
|
$
|
1,711
|
|
|
|
|
|
|
|
||||||
Income tax expense (benefit):
|
|
|
|
|
|
||||||
PacifiCorp
|
$
|
341
|
|
|
$
|
328
|
|
|
$
|
310
|
|
MidAmerican Funding
|
(139
|
)
|
|
(150
|
)
|
|
(122
|
)
|
|||
NV Energy
|
200
|
|
|
207
|
|
|
195
|
|
|||
Northern Powergrid
|
22
|
|
|
35
|
|
|
110
|
|
|||
BHE Pipeline Group
|
163
|
|
|
158
|
|
|
149
|
|
|||
BHE Transmission
|
26
|
|
|
63
|
|
|
28
|
|
|||
BHE Renewables
|
(32
|
)
|
|
41
|
|
|
65
|
|
|||
HomeServices
|
81
|
|
|
72
|
|
|
44
|
|
|||
BHE and Other
(1)
|
(259
|
)
|
|
(304
|
)
|
|
(190
|
)
|
|||
Total income tax expense (benefit)
|
$
|
403
|
|
|
$
|
450
|
|
|
$
|
589
|
|
|
|
|
|
|
|
||||||
Capital expenditures:
|
|
|
|
|
|
||||||
PacifiCorp
|
$
|
903
|
|
|
$
|
916
|
|
|
$
|
1,066
|
|
MidAmerican Funding
|
1,637
|
|
|
1,448
|
|
|
1,527
|
|
|||
NV Energy
|
529
|
|
|
571
|
|
|
558
|
|
|||
Northern Powergrid
|
579
|
|
|
674
|
|
|
675
|
|
|||
BHE Pipeline Group
|
226
|
|
|
240
|
|
|
257
|
|
|||
BHE Transmission
|
466
|
|
|
966
|
|
|
222
|
|
|||
BHE Renewables
|
719
|
|
|
1,034
|
|
|
2,221
|
|
|||
HomeServices
|
20
|
|
|
16
|
|
|
17
|
|
|||
BHE and Other
|
11
|
|
|
10
|
|
|
12
|
|
|||
Total capital expenditures
|
$
|
5,090
|
|
|
$
|
5,875
|
|
|
$
|
6,555
|
|
|
As of December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
Property, plant and equipment, net:
|
|
|
|
|
|
||||||
PacifiCorp
|
$
|
19,162
|
|
|
$
|
19,039
|
|
|
$
|
18,755
|
|
MidAmerican Funding
|
12,835
|
|
|
11,737
|
|
|
10,535
|
|
|||
NV Energy
|
9,825
|
|
|
9,767
|
|
|
9,648
|
|
|||
Northern Powergrid
|
5,148
|
|
|
5,790
|
|
|
5,599
|
|
|||
BHE Pipeline Group
|
4,423
|
|
|
4,345
|
|
|
4,286
|
|
|||
BHE Transmission
|
5,810
|
|
|
5,301
|
|
|
5,567
|
|
|||
BHE Renewables
|
5,302
|
|
|
4,805
|
|
|
4,897
|
|
|||
HomeServices
|
78
|
|
|
70
|
|
|
68
|
|
|||
BHE and Other
|
(74
|
)
|
|
(85
|
)
|
|
(107
|
)
|
|||
Total property, plant and equipment, net
|
$
|
62,509
|
|
|
$
|
60,769
|
|
|
$
|
59,248
|
|
|
|
|
|
|
|
||||||
Total assets:
|
|
|
|
|
|
||||||
PacifiCorp
|
$
|
23,563
|
|
|
$
|
23,550
|
|
|
$
|
23,404
|
|
MidAmerican Funding
|
17,571
|
|
|
16,315
|
|
|
15,164
|
|
|||
NV Energy
|
14,320
|
|
|
14,656
|
|
|
14,256
|
|
|||
Northern Powergrid
|
6,433
|
|
|
7,317
|
|
|
7,059
|
|
|||
BHE Pipeline Group
|
5,144
|
|
|
4,953
|
|
|
4,951
|
|
|||
BHE Transmission
|
8,378
|
|
|
7,553
|
|
|
7,979
|
|
|||
BHE Renewables
|
7,010
|
|
|
5,892
|
|
|
6,082
|
|
|||
HomeServices
|
1,776
|
|
|
1,705
|
|
|
1,622
|
|
|||
BHE and Other
|
1,245
|
|
|
1,677
|
|
|
1,299
|
|
|||
Total assets
|
$
|
85,440
|
|
|
$
|
83,618
|
|
|
$
|
81,816
|
|
|
|
|
|
|
|
||||||
|
Years Ended December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
Operating revenue by country:
|
|
|
|
|
|
||||||
United States
|
$
|
15,895
|
|
|
$
|
16,121
|
|
|
$
|
15,857
|
|
United Kingdom
|
995
|
|
|
1,140
|
|
|
1,281
|
|
|||
Canada
|
506
|
|
|
600
|
|
|
78
|
|
|||
Philippines and other
|
26
|
|
|
19
|
|
|
110
|
|
|||
Total operating revenue by country
|
$
|
17,422
|
|
|
$
|
17,880
|
|
|
$
|
17,326
|
|
|
|
|
|
|
|
||||||
Income before income tax expense and equity income by country:
|
|
|
|
|
|||||||
United States
|
$
|
2,264
|
|
|
$
|
2,034
|
|
|
$
|
2,001
|
|
United Kingdom
|
382
|
|
|
472
|
|
|
557
|
|
|||
Canada
|
135
|
|
|
165
|
|
|
4
|
|
|||
Philippines and other
|
69
|
|
|
64
|
|
|
40
|
|
|||
Total income before income tax expense and equity income by country:
|
$
|
2,850
|
|
|
$
|
2,735
|
|
|
$
|
2,602
|
|
|
As of December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
Property, plant and equipment, net by country:
|
|
|
|
|
|
||||||
United States
|
$
|
51,671
|
|
|
$
|
49,680
|
|
|
$
|
47,918
|
|
United Kingdom
|
5,020
|
|
|
5,757
|
|
|
5,563
|
|
|||
Canada
|
5,803
|
|
|
5,298
|
|
|
5,570
|
|
|||
Philippines and other
|
15
|
|
|
34
|
|
|
197
|
|
|||
Total property, plant and equipment, net by country
|
$
|
62,509
|
|
|
$
|
60,769
|
|
|
$
|
59,248
|
|
(1)
|
The differences between the reportable segment amounts and the consolidated amounts, described as
BHE and Other
, relate to other corporate entities, including MidAmerican Energy Services, LLC, corporate functions and intersegment eliminations.
|
|
|
|
|
|
|
|
|
|
BHE
|
|
|
|
|
|
|
|
BHE
|
|
|
||||||||||||||||||||
|
|
|
MidAmerican
|
|
NV
|
|
Northern
|
|
Pipeline
|
|
BHE
|
|
BHE
|
|
Home-
|
|
and
|
|
|
||||||||||||||||||||
|
PacifiCorp
|
|
Funding
|
|
Energy
|
|
Powergrid
|
|
Group
|
|
Transmission
|
|
Renewables
|
|
Services
|
|
Other
|
|
Total
|
||||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||||||||
December 31, 2014
|
$
|
1,129
|
|
|
$
|
2,102
|
|
|
$
|
2,369
|
|
|
$
|
1,100
|
|
|
$
|
127
|
|
|
$
|
1,657
|
|
|
$
|
95
|
|
|
$
|
761
|
|
|
$
|
3
|
|
|
$
|
9,343
|
|
Acquisitions
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
44
|
|
|
—
|
|
|
33
|
|
|
—
|
|
|
77
|
|
||||||||||
Foreign currency translation
|
—
|
|
|
—
|
|
|
—
|
|
|
(44
|
)
|
|
—
|
|
|
(273
|
)
|
|
—
|
|
|
—
|
|
|
(1
|
)
|
|
(318
|
)
|
||||||||||
Other
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(26
|
)
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(26
|
)
|
||||||||||
December 31, 2015
|
1,129
|
|
|
2,102
|
|
|
2,369
|
|
|
1,056
|
|
|
101
|
|
|
1,428
|
|
|
95
|
|
|
794
|
|
|
2
|
|
|
9,076
|
|
||||||||||
Acquisitions
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
4
|
|
|
—
|
|
|
46
|
|
|
—
|
|
|
50
|
|
||||||||||
Foreign currency translation
|
—
|
|
|
—
|
|
|
—
|
|
|
(126
|
)
|
|
—
|
|
|
42
|
|
|
—
|
|
|
—
|
|
|
(2
|
)
|
|
(86
|
)
|
||||||||||
Other
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(26
|
)
|
|
(4
|
)
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(30
|
)
|
||||||||||
December 31, 2016
|
$
|
1,129
|
|
|
$
|
2,102
|
|
|
$
|
2,369
|
|
|
$
|
930
|
|
|
$
|
75
|
|
|
$
|
1,470
|
|
|
$
|
95
|
|
|
$
|
840
|
|
|
$
|
—
|
|
|
$
|
9,010
|
|
Item 6.
|
Selected Financial Data
|
|
Years Ended December 31,
|
||||||||||||||||||
|
2016
|
|
2015
|
|
2014
|
|
2013
|
|
2012
|
||||||||||
|
|
|
|
|
|
|
|
|
|
||||||||||
Consolidated Statement of Operations Data:
|
|
|
|
|
|
|
|
|
|
||||||||||
Operating revenue
|
$
|
5,201
|
|
|
$
|
5,232
|
|
|
$
|
5,252
|
|
|
$
|
5,147
|
|
|
$
|
4,882
|
|
Operating income
|
1,426
|
|
|
1,340
|
|
|
1,300
|
|
|
1,264
|
|
|
1,021
|
|
|||||
Net income
|
763
|
|
|
695
|
|
|
698
|
|
|
682
|
|
|
537
|
|
|
As of December 31,
|
||||||||||||||||||
|
2016
|
|
2015
|
|
2014
|
|
2013
|
|
2012
|
||||||||||
|
|
|
|
|
|
|
|
|
|
||||||||||
Consolidated Balance Sheet Data:
|
|
|
|
|
|
|
|
|
|
||||||||||
Total assets
(1)(2)
|
$
|
22,394
|
|
|
$
|
22,367
|
|
|
$
|
22,205
|
|
|
$
|
21,559
|
|
|
$
|
21,581
|
|
Short-term debt
|
270
|
|
|
20
|
|
|
20
|
|
|
—
|
|
|
—
|
|
|||||
Current portion of long-term debt and
|
|
|
|
|
|
|
|
|
|
||||||||||
capital lease obligations
|
58
|
|
|
68
|
|
|
134
|
|
|
238
|
|
|
267
|
|
|||||
Long-term debt and capital lease obligations,
|
|
|
|
|
|
|
|
|
|
||||||||||
excluding current portion
(2)
|
7,021
|
|
|
7,078
|
|
|
6,885
|
|
|
6,605
|
|
|
6,559
|
|
|||||
Total shareholders' equity
|
7,390
|
|
|
7,503
|
|
|
7,756
|
|
|
7,787
|
|
|
7,644
|
|
(1)
|
In December 2015, PacifiCorp retrospectively adopted Accounting Standards Update No. 2015-17, which resulted in the reclassification of current deferred income tax assets in the amounts of $28 million, $66 million, and $112 million, as of December 31, 2014, 2013 and 2012, respectively, as reductions in noncurrent deferred income tax liabilities.
|
(2)
|
In December 2015, PacifiCorp retrospectively adopted Accounting Standards Update No. 2015-03, which resulted in the reclassification of certain deferred debt issuance costs previously recognized within other assets in the amounts of $34 million, $34 million, and $35 million, as of December 31, 2014, 2013, and 2012, respectively, as reductions in long-term debt.
|
Item 7.
|
Management's Discussion and Analysis of Financial Condition and Results of Operations
|
|
|
2016
|
|
2015
|
|
Change
|
|
2015
|
|
2014
|
|
Change
|
||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Gross margin (in millions):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Operating revenue
|
|
$
|
5,201
|
|
|
$
|
5,232
|
|
|
$
|
(31
|
)
|
|
(1
|
)%
|
|
$
|
5,232
|
|
|
$
|
5,252
|
|
|
$
|
(20
|
)
|
|
—
|
%
|
Energy costs
|
|
1,751
|
|
|
1,868
|
|
|
(117
|
)
|
|
(6
|
)
|
|
1,868
|
|
|
1,997
|
|
|
(129
|
)
|
|
(6
|
)
|
||||||
Gross margin
|
|
$
|
3,450
|
|
|
$
|
3,364
|
|
|
$
|
86
|
|
|
3
|
|
|
$
|
3,364
|
|
|
$
|
3,255
|
|
|
$
|
109
|
|
|
3
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Sales (GWh):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Residential
|
|
16,058
|
|
|
15,566
|
|
|
492
|
|
|
3
|
%
|
|
15,566
|
|
|
15,568
|
|
|
(2
|
)
|
|
—
|
%
|
||||||
Commercial
|
|
16,857
|
|
|
17,262
|
|
|
(405
|
)
|
|
(2
|
)
|
|
17,262
|
|
|
17,073
|
|
|
189
|
|
|
1
|
|
||||||
Industrial and irrigation
|
|
20,924
|
|
|
21,403
|
|
|
(479
|
)
|
|
(2
|
)
|
|
21,403
|
|
|
21,934
|
|
|
(531
|
)
|
|
(2
|
)
|
||||||
Other
|
|
479
|
|
|
410
|
|
|
69
|
|
|
17
|
|
|
410
|
|
|
424
|
|
|
(14
|
)
|
|
(3
|
)
|
||||||
Total retail
|
|
54,318
|
|
|
54,641
|
|
|
(323
|
)
|
|
(1
|
)
|
|
54,641
|
|
|
54,999
|
|
|
(358
|
)
|
|
(1
|
)
|
||||||
Wholesale
|
|
6,641
|
|
|
8,889
|
|
|
(2,248
|
)
|
|
(25
|
)
|
|
8,889
|
|
|
10,270
|
|
|
(1,381
|
)
|
|
(13
|
)
|
||||||
Total sales
|
|
60,959
|
|
|
63,530
|
|
|
(2,571
|
)
|
|
(4
|
)
|
|
63,530
|
|
|
65,269
|
|
|
(1,739
|
)
|
|
(3
|
)
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Average number of retail customers
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
(in thousands)
|
|
1,841
|
|
|
1,813
|
|
|
28
|
|
|
2
|
%
|
|
1,813
|
|
|
1,783
|
|
|
30
|
|
|
2
|
%
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Average revenue per MWh:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Retail
|
|
$
|
89.55
|
|
|
$
|
87.99
|
|
|
$
|
1.56
|
|
|
2
|
%
|
|
$
|
87.99
|
|
|
$
|
85.73
|
|
|
$
|
2.26
|
|
|
3
|
%
|
Wholesale
|
|
$
|
26.46
|
|
|
$
|
29.92
|
|
|
$
|
(3.46
|
)
|
|
(12
|
)%
|
|
$
|
29.92
|
|
|
$
|
33.94
|
|
|
$
|
(4.02
|
)
|
|
(12
|
)%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Sources of energy (GWh)
(1)
:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Coal
|
|
36,578
|
|
|
41,298
|
|
|
(4,720
|
)
|
|
(11
|
)%
|
|
41,298
|
|
|
42,218
|
|
|
(920
|
)
|
|
(2
|
)%
|
||||||
Natural gas
|
|
9,884
|
|
|
9,222
|
|
|
662
|
|
|
7
|
|
|
9,222
|
|
|
10,881
|
|
|
(1,659
|
)
|
|
(15
|
)
|
||||||
Hydroelectric
(2)
|
|
3,843
|
|
|
2,914
|
|
|
929
|
|
|
32
|
|
|
2,914
|
|
|
3,782
|
|
|
(868
|
)
|
|
(23
|
)
|
||||||
Wind and other
(2)
|
|
3,253
|
|
|
2,892
|
|
|
361
|
|
|
12
|
|
|
2,892
|
|
|
3,318
|
|
|
(426
|
)
|
|
(13
|
)
|
||||||
Total energy generated
|
|
53,558
|
|
|
56,326
|
|
|
(2,768
|
)
|
|
(5
|
)
|
|
56,326
|
|
|
60,199
|
|
|
(3,873
|
)
|
|
(6
|
)
|
||||||
Energy purchased
|
|
11,429
|
|
|
11,646
|
|
|
(217
|
)
|
|
(2
|
)
|
|
11,646
|
|
|
9,817
|
|
|
1,829
|
|
|
19
|
|
||||||
Total
|
|
64,987
|
|
|
67,972
|
|
|
(2,985
|
)
|
|
(4
|
)
|
|
67,972
|
|
|
70,016
|
|
|
(2,044
|
)
|
|
(3
|
)
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Average cost of energy per MWh:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Energy generated
(3)
|
|
$
|
19.27
|
|
|
$
|
19.38
|
|
|
$
|
(0.11
|
)
|
|
(1
|
)%
|
|
$
|
19.38
|
|
|
$
|
20.71
|
|
|
$
|
(1.33
|
)
|
|
(6
|
)%
|
Energy purchased
|
|
$
|
44.64
|
|
|
$
|
49.92
|
|
|
$
|
(5.28
|
)
|
|
(11
|
)%
|
|
$
|
49.92
|
|
|
$
|
58.56
|
|
|
$
|
(8.64
|
)
|
|
(15
|
)%
|
(1)
|
GWh amounts are net of energy used by the related generating facilities.
|
(2)
|
All or some of the renewable energy attributes associated with generation from these generating facilities may be: (a) used in future years to comply with RPS or other regulatory requirements or (b) sold to third parties in the form of RECs or other environmental commodities.
|
(3)
|
The average cost per MWh of energy generated includes only the cost of fuel associated with the generating facilities.
|
•
|
$71 million of lower purchased electricity costs primarily due to lower average market prices;
|
•
|
$57 million of higher retail revenues primarily due to higher retail rates;
|
•
|
$37 million of lower coal costs primarily due to decreased generation of $95 million, partially offset by higher average unit costs of $31 million and charges related to damaged longwall mining equipment of $20 million; and
|
•
|
$22 million of lower natural gas costs due to lower market prices, partially offset by increased generation.
|
•
|
$90 million of lower wholesale electricity revenue due to lower volumes and prices.
|
•
|
$131 million of lower natural gas costs due to decreased generation, primarily as a result of lower availability and dispatch, and lower average unit costs, partially offset by increased generation from the addition of Lake Side 2;
|
•
|
$109 million of increases mainly from higher retail rates; and
|
•
|
$25 million of lower coal costs primarily due to decreased generation, including the idling of the Carbon Facility in April 2015 and Utah Mine Disposition costs in 2014.
|
•
|
$83 million of lower wholesale electricity revenue due to lower volumes and prices;
|
•
|
$31 million of lower REC revenue primarily due to the effects of established adjustment mechanisms;
|
•
|
$21 million of lower net deferrals of incurred net power costs in accordance with established adjustment mechanisms;
|
•
|
$16 million of lower retail revenues from a 0.7% decrease in retail customer volumes due to 1.8% lower customer usage primarily by industrial customers in Utah and Wyoming and residential customers across the service territory, partially offset by a 0.8% increase in the average number of residential customers in Utah and Oregon and commercial customers in Utah and a 0.3% increase due to the impacts of weather on residential, commercial and irrigation customer volumes; and
|
•
|
$6 million of higher purchased electricity costs due to higher volumes substantially offset by lower average market prices.
|
Cash and cash equivalents
|
|
$
|
17
|
|
|
|
|
||
Credit facilities
(1)
|
|
1,000
|
|
|
Less:
|
|
|
||
Short-term debt
|
|
(270
|
)
|
|
Tax-exempt bond support
|
|
(142
|
)
|
|
Net credit facilities
|
|
588
|
|
|
|
|
|
||
Total net liquidity
|
|
$
|
605
|
|
|
|
|
||
Credit facilities:
|
|
|
||
Maturity dates
|
|
2018, 2019
|
|
(1)
|
Refer to Note
6
of Notes to Consolidated Financial Statements in Item 8 of this Form 10
-
K for further discussion regarding PacifiCorp's credit facilities.
|
|
Historical
|
|
Forecast
|
||||||||||||||||||||
|
2014
|
|
2015
|
|
2016
|
|
2017
|
|
2018
|
|
2019
|
||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Transmission system investment
|
$
|
262
|
|
|
$
|
137
|
|
|
$
|
94
|
|
|
$
|
119
|
|
|
$
|
108
|
|
|
$
|
85
|
|
Environmental
|
158
|
|
|
114
|
|
|
58
|
|
|
32
|
|
|
21
|
|
|
14
|
|
||||||
Wind investment
|
—
|
|
|
—
|
|
|
110
|
|
|
31
|
|
|
181
|
|
|
740
|
|
||||||
Operating and other
|
646
|
|
|
665
|
|
|
641
|
|
|
668
|
|
|
675
|
|
|
781
|
|
||||||
Total
|
$
|
1,066
|
|
|
$
|
916
|
|
|
$
|
903
|
|
|
$
|
850
|
|
|
$
|
985
|
|
|
$
|
1,620
|
|
•
|
Transmission system investment includes main grid reinforcement costs, construction costs for the 170-mile single-circuit 345-kV Sigurd-Red Butte transmission line that was placed in-service in May 2015 and initial development costs for several other long-term projects.
|
•
|
Environmental includes the installation of new or the replacement of existing emissions control equipment at certain generating facilities, including installation or upgrade of selective catalytic reduction control systems and low nitrogen oxide burners to reduce nitrogen oxides, particulate matter control systems, sulfur dioxide emissions controls systems and mercury emissions control systems, as well as expenditures for the management of coal combustion residuals.
|
•
|
Wind investment includes initial costs for new wind plant construction projects and repowering of existing wind plants.
|
•
|
Remaining investments relate to operating projects that consist of routine expenditures for generation, transmission, distribution and other infrastructure needed to serve existing and expected demand, including upgrades to customer meters in Oregon and Idaho.
|
|
Payments Due By Periods
|
||||||||||||||||||
|
2017
|
|
2018-2019
|
|
2020-2021
|
|
2022 and Thereafter
|
|
Total
|
||||||||||
|
|
|
|
|
|
|
|
|
|
||||||||||
Long-term debt, including interest:
|
|
|
|
|
|
|
|
|
|
||||||||||
Fixed-rate obligations
|
$
|
357
|
|
|
$
|
1,522
|
|
|
$
|
1,027
|
|
|
$
|
8,894
|
|
|
$
|
11,800
|
|
Variable-rate obligations
(1)
|
53
|
|
|
90
|
|
|
42
|
|
|
223
|
|
|
408
|
|
|||||
Capital leases, including interest
|
9
|
|
|
8
|
|
|
9
|
|
|
20
|
|
|
46
|
|
|||||
Operating leases and easements
|
5
|
|
|
10
|
|
|
9
|
|
|
39
|
|
|
63
|
|
|||||
Asset retirement obligations
|
21
|
|
|
23
|
|
|
38
|
|
|
351
|
|
|
433
|
|
|||||
Power purchase agreements - commercially operable
(2)
:
|
|
|
|
|
|
|
|
|
|
||||||||||
Electricity commodity contracts
|
207
|
|
|
231
|
|
|
225
|
|
|
903
|
|
|
1,566
|
|
|||||
Electricity capacity contracts
|
37
|
|
|
70
|
|
|
62
|
|
|
665
|
|
|
834
|
|
|||||
Electricity mixed contracts
|
9
|
|
|
16
|
|
|
15
|
|
|
62
|
|
|
102
|
|
|||||
Power purchase agreements - non-commercially operable
(2)
|
10
|
|
|
30
|
|
|
35
|
|
|
390
|
|
|
465
|
|
|||||
Transmission
|
109
|
|
|
196
|
|
|
108
|
|
|
467
|
|
|
880
|
|
|||||
Fuel purchase agreements
(2)
:
|
|
|
|
|
|
|
|
|
|
||||||||||
Natural gas supply and transportation
|
62
|
|
|
56
|
|
|
55
|
|
|
260
|
|
|
433
|
|
|||||
Coal supply and transportation
|
734
|
|
|
1,156
|
|
|
798
|
|
|
1,147
|
|
|
3,835
|
|
|||||
Other purchase obligations
|
115
|
|
|
132
|
|
|
42
|
|
|
72
|
|
|
361
|
|
|||||
Other long-term liabilities
(3)
|
14
|
|
|
9
|
|
|
13
|
|
|
52
|
|
|
88
|
|
|||||
Total contractual cash obligations
|
$
|
1,742
|
|
|
$
|
3,549
|
|
|
$
|
2,478
|
|
|
$
|
13,545
|
|
|
$
|
21,314
|
|
(1)
|
Consists of principal and interest for tax-exempt bond obligations with interest rates scheduled to reset periodically prior to maturity. Future variable interest rates are assumed to equal December 31,
2016
rates. Refer to "Interest Rate Risk" in Item 7A of this Form 10-K for additional discussion related to variable-rate liabilities.
|
(2)
|
Commodity contracts are agreements for the delivery of energy. Capacity contracts are agreements that provide rights to energy output, generally of a specified generating facility. Forecasted or other applicable estimated prices were used to determine total dollar value of the commitments. PacifiCorp has several contracts for purchases of electricity from facilities that have not yet achieved commercial operation. To the extent any of these facilities do not achieve commercial operation, PacifiCorp has no obligation to the counterparty.
|
(3)
|
Includes environmental and hydroelectric relicensing commitments recorded in the Consolidated Balance Sheets that are contractually or legally binding. Excludes regulatory liabilities and employee benefit plan obligations that are not legally or contractually fixed as to timing and amount. Deferred income taxes are excluded since cash payments are based primarily on taxable income for each year. Uncertain tax positions are also excluded because the amounts and timing of cash payments are not certain.
|
|
|
|
Other Postretirement
|
||||||||||||
|
Pension Plans
|
|
Benefit Plan
|
||||||||||||
|
+0.5%
|
|
-0.5%
|
|
+0.5%
|
|
-0.5%
|
||||||||
|
|
|
|
|
|
|
|
||||||||
Effect on December 31, 2016 Benefit Obligations:
|
|
|
|
|
|
|
|
||||||||
Discount rate
|
$
|
(64
|
)
|
|
$
|
71
|
|
|
$
|
(15
|
)
|
|
$
|
17
|
|
|
|
|
|
|
|
|
|
||||||||
Effect on 2016 Periodic Cost:
|
|
|
|
|
|
|
|
||||||||
Discount rate
|
$
|
(4
|
)
|
|
$
|
4
|
|
|
$
|
—
|
|
|
$
|
—
|
|
Expected rate of return on plan assets
|
(5
|
)
|
|
5
|
|
|
(1
|
)
|
|
1
|
|
Item 7A.
|
Quantitative and Qualitative Disclosures About Market Risk
|
|
2016
|
||
Minimum VaR (measured)
|
$
|
6
|
|
Average VaR (calculated)
|
8
|
|
|
Maximum VaR (measured)
|
12
|
|
|
Fair Value -
|
|
Estimated Fair Value after
|
||||||||
|
Net Asset
|
|
Hypothetical Change in Price
|
||||||||
|
(Liability)
|
|
10% increase
|
|
10% decrease
|
||||||
As of December 31, 2016:
|
|
|
|
|
|
||||||
Total commodity derivative contracts
|
$
|
(77
|
)
|
|
$
|
(59
|
)
|
|
$
|
(95
|
)
|
|
|
|
|
|
|
||||||
As of December 31, 2015
|
|
|
|
|
|
||||||
Total commodity derivative contracts
|
$
|
(136
|
)
|
|
$
|
(103
|
)
|
|
$
|
(169
|
)
|
Item 8.
|
Financial Statements and Supplementary Data
|
|
||
|
|
|
|
||
|
|
|
|
||
|
|
|
|
||
|
|
|
Consolidated Statements of Changes in
Shareholders' Equity
|
|
|
|
|
|
|
||
|
|
|
|
|
As of December 31,
|
||||||
|
2016
|
|
2015
|
||||
|
|
|
|
||||
ASSETS
|
|||||||
|
|
|
|
||||
Current assets:
|
|
|
|
||||
Cash and cash equivalents
|
$
|
17
|
|
|
$
|
12
|
|
Accounts receivable, net
|
728
|
|
|
740
|
|
||
Income taxes receivable
|
17
|
|
|
17
|
|
||
Inventories:
|
|
|
|
||||
Materials and supplies
|
228
|
|
|
233
|
|
||
Fuel
|
215
|
|
|
192
|
|
||
Regulatory assets
|
53
|
|
|
102
|
|
||
Other current assets
|
96
|
|
|
81
|
|
||
Total current assets
|
1,354
|
|
|
1,377
|
|
||
|
|
|
|
||||
Property, plant and equipment, net
|
19,162
|
|
|
19,026
|
|
||
Regulatory assets
|
1,490
|
|
|
1,583
|
|
||
Other assets
|
388
|
|
|
381
|
|
||
|
|
|
|
||||
Total assets
|
$
|
22,394
|
|
|
$
|
22,367
|
|
|
As of December 31,
|
||||||
|
2016
|
|
2015
|
||||
|
|
|
|
||||
LIABILITIES AND SHAREHOLDERS' EQUITY
|
|||||||
|
|
|
|
||||
Current liabilities:
|
|
|
|
||||
Accounts payable
|
$
|
408
|
|
|
$
|
473
|
|
Accrued employee expenses
|
67
|
|
|
70
|
|
||
Accrued interest
|
115
|
|
|
115
|
|
||
Accrued property and other taxes
|
63
|
|
|
62
|
|
||
Short-term debt
|
270
|
|
|
20
|
|
||
Current portion of long-term debt and capital lease obligations
|
58
|
|
|
68
|
|
||
Regulatory liabilities
|
54
|
|
|
34
|
|
||
Other current liabilities
|
164
|
|
|
229
|
|
||
Total current liabilities
|
1,199
|
|
|
1,071
|
|
||
|
|
|
|
||||
Regulatory liabilities
|
978
|
|
|
938
|
|
||
Long-term debt and capital lease obligations
|
7,021
|
|
|
7,078
|
|
||
Deferred income taxes
|
4,880
|
|
|
4,750
|
|
||
Other long-term liabilities
|
926
|
|
|
1,027
|
|
||
Total liabilities
|
15,004
|
|
|
14,864
|
|
||
|
|
|
|
||||
Commitments and contingencies (Note 13)
|
|
|
|
||||
|
|
|
|
||||
Shareholders' equity:
|
|
|
|
||||
Preferred stock
|
2
|
|
|
2
|
|
||
Common stock - 750 shares authorized, no par value, 357 shares issued and outstanding
|
—
|
|
|
—
|
|
||
Additional paid-in capital
|
4,479
|
|
|
4,479
|
|
||
Retained earnings
|
2,921
|
|
|
3,033
|
|
||
Accumulated other comprehensive loss, net
|
(12
|
)
|
|
(11
|
)
|
||
Total shareholders' equity
|
7,390
|
|
|
7,503
|
|
||
|
|
|
|
||||
Total liabilities and shareholders' equity
|
$
|
22,394
|
|
|
$
|
22,367
|
|
|
Years Ended December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Operating revenue
|
$
|
5,201
|
|
|
$
|
5,232
|
|
|
$
|
5,252
|
|
|
|
|
|
|
|
||||||
Operating costs and expenses:
|
|
|
|
|
|
||||||
Energy costs
|
1,751
|
|
|
1,868
|
|
|
1,997
|
|
|||
Operations and maintenance
|
1,064
|
|
|
1,082
|
|
|
1,057
|
|
|||
Depreciation and amortization
|
770
|
|
|
757
|
|
|
726
|
|
|||
Taxes, other than income taxes
|
190
|
|
|
185
|
|
|
172
|
|
|||
Total operating costs and expenses
|
3,775
|
|
|
3,892
|
|
|
3,952
|
|
|||
|
|
|
|
|
|
||||||
Operating income
|
1,426
|
|
|
1,340
|
|
|
1,300
|
|
|||
|
|
|
|
|
|
||||||
Other income (expense):
|
|
|
|
|
|
||||||
Interest expense
|
(380
|
)
|
|
(379
|
)
|
|
(379
|
)
|
|||
Allowance for borrowed funds
|
15
|
|
|
18
|
|
|
25
|
|
|||
Allowance for equity funds
|
27
|
|
|
33
|
|
|
51
|
|
|||
Other, net
|
15
|
|
|
11
|
|
|
10
|
|
|||
Total other income (expense)
|
(323
|
)
|
|
(317
|
)
|
|
(293
|
)
|
|||
|
|
|
|
|
|
||||||
Income before income tax expense
|
1,103
|
|
|
1,023
|
|
|
1,007
|
|
|||
Income tax expense
|
340
|
|
|
328
|
|
|
309
|
|
|||
Net income
|
$
|
763
|
|
|
$
|
695
|
|
|
$
|
698
|
|
|
Years Ended December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Net income
|
$
|
763
|
|
|
$
|
695
|
|
|
$
|
698
|
|
|
|
|
|
|
|
||||||
Other comprehensive (loss) income, net of tax —
|
|
|
|
|
|
||||||
Unrecognized amounts on retirement benefits, net of tax of $-, $1 and $(3)
|
(1
|
)
|
|
2
|
|
|
(4
|
)
|
|||
|
|
|
|
|
|
||||||
Comprehensive income
|
$
|
762
|
|
|
$
|
697
|
|
|
$
|
694
|
|
|
|
|
|
|
|
|
|
|
Accumulated
|
|
|
||||||||||||
|
|
|
|
|
Additional
|
|
|
|
Other
|
|
Total
|
||||||||||||
|
Preferred
|
|
Common
|
|
Paid-in
|
|
Retained
|
|
Comprehensive
|
|
Shareholders'
|
||||||||||||
|
Stock
|
|
Stock
|
|
Capital
|
|
Earnings
|
|
Loss, Net
|
|
Equity
|
||||||||||||
Balance, December 31, 2013
|
$
|
2
|
|
|
$
|
—
|
|
|
$
|
4,479
|
|
|
$
|
3,315
|
|
|
$
|
(9
|
)
|
|
$
|
7,787
|
|
Net income
|
—
|
|
|
—
|
|
|
—
|
|
|
698
|
|
|
—
|
|
|
698
|
|
||||||
Other comprehensive loss
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(4
|
)
|
|
(4
|
)
|
||||||
Common stock dividends declared
|
—
|
|
|
—
|
|
|
—
|
|
|
(725
|
)
|
|
—
|
|
|
(725
|
)
|
||||||
Balance, December 31, 2014
|
2
|
|
|
—
|
|
|
4,479
|
|
|
3,288
|
|
|
(13
|
)
|
|
7,756
|
|
||||||
Net income
|
—
|
|
|
—
|
|
|
—
|
|
|
695
|
|
|
—
|
|
|
695
|
|
||||||
Other comprehensive income
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
2
|
|
|
2
|
|
||||||
Common stock dividends declared
|
—
|
|
|
—
|
|
|
—
|
|
|
(950
|
)
|
|
—
|
|
|
(950
|
)
|
||||||
Balance, December 31, 2015
|
2
|
|
|
—
|
|
|
4,479
|
|
|
3,033
|
|
|
(11
|
)
|
|
7,503
|
|
||||||
Net income
|
—
|
|
|
—
|
|
|
—
|
|
|
763
|
|
|
—
|
|
|
763
|
|
||||||
Other comprehensive loss
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(1
|
)
|
|
(1
|
)
|
||||||
Common stock dividends declared
|
—
|
|
|
—
|
|
|
—
|
|
|
(875
|
)
|
|
—
|
|
|
(875
|
)
|
||||||
Balance, December 31, 2016
|
$
|
2
|
|
|
$
|
—
|
|
|
$
|
4,479
|
|
|
$
|
2,921
|
|
|
$
|
(12
|
)
|
|
$
|
7,390
|
|
|
Years Ended December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
Cash flows from operating activities:
|
|
|
|
|
|
||||||
Net income
|
$
|
763
|
|
|
$
|
695
|
|
|
$
|
698
|
|
Adjustments to reconcile net income to net cash flows from operating
|
|
|
|
|
|
||||||
activities:
|
|
|
|
|
|
||||||
Depreciation and amortization
|
770
|
|
|
757
|
|
|
726
|
|
|||
Allowance for equity funds
|
(27
|
)
|
|
(33
|
)
|
|
(51
|
)
|
|||
Deferred income taxes and amortization of investment tax credits
|
139
|
|
|
172
|
|
|
297
|
|
|||
Changes in regulatory assets and liabilities
|
122
|
|
|
63
|
|
|
(112
|
)
|
|||
Other, net
|
4
|
|
|
6
|
|
|
22
|
|
|||
Changes in other operating assets and liabilities:
|
|
|
|
|
|
||||||
Accounts receivable and other assets
|
(25
|
)
|
|
5
|
|
|
5
|
|
|||
Derivative collateral, net
|
6
|
|
|
(47
|
)
|
|
(16
|
)
|
|||
Inventories
|
(21
|
)
|
|
(7
|
)
|
|
37
|
|
|||
Income taxes
|
—
|
|
|
116
|
|
|
(155
|
)
|
|||
Accounts payable and other liabilities
|
(163
|
)
|
|
7
|
|
|
119
|
|
|||
Net cash flows from operating activities
|
1,568
|
|
|
1,734
|
|
|
1,570
|
|
|||
|
|
|
|
|
|
||||||
Cash flows from investing activities:
|
|
|
|
|
|
||||||
Capital expenditures
|
(903
|
)
|
|
(916
|
)
|
|
(1,066
|
)
|
|||
Other, net
|
34
|
|
|
(2
|
)
|
|
(13
|
)
|
|||
Net cash flows from investing activities
|
(869
|
)
|
|
(918
|
)
|
|
(1,079
|
)
|
|||
|
|
|
|
|
|
||||||
Cash flows from financing activities:
|
|
|
|
|
|
||||||
Proceeds from long-term debt
|
—
|
|
|
248
|
|
|
422
|
|
|||
Repayments of long-term debt and capital lease obligations
|
(68
|
)
|
|
(124
|
)
|
|
(238
|
)
|
|||
Net proceeds from short-term debt
|
250
|
|
|
—
|
|
|
20
|
|
|||
Common stock dividends
|
(875
|
)
|
|
(950
|
)
|
|
(725
|
)
|
|||
Other, net
|
(1
|
)
|
|
(1
|
)
|
|
—
|
|
|||
Net cash flows from financing activities
|
(694
|
)
|
|
(827
|
)
|
|
(521
|
)
|
|||
|
|
|
|
|
|
||||||
Net change in cash and cash equivalents
|
5
|
|
|
(11
|
)
|
|
(30
|
)
|
|||
Cash and cash equivalents at beginning of period
|
12
|
|
|
23
|
|
|
53
|
|
|||
Cash and cash equivalents at end of period
|
$
|
17
|
|
|
$
|
12
|
|
|
$
|
23
|
|
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Beginning balance
|
$
|
7
|
|
|
$
|
7
|
|
|
$
|
8
|
|
Charged to operating costs and expenses, net
|
12
|
|
|
10
|
|
|
11
|
|
|||
Write-offs, net
|
(12
|
)
|
|
(10
|
)
|
|
(12
|
)
|
|||
Ending balance
|
$
|
7
|
|
|
$
|
7
|
|
|
$
|
7
|
|
|
Depreciable Life
|
|
2016
|
|
2015
|
||||
Property, plant and equipment:
|
|
|
|
|
|
||||
Generation
|
14 - 67 years
|
|
$
|
12,371
|
|
|
$
|
12,164
|
|
Transmission
|
58 - 75 years
|
|
6,055
|
|
|
5,914
|
|
||
Distribution
|
20 - 70 years
|
|
6,590
|
|
|
6,408
|
|
||
Intangible plant
(1)
|
5 - 62 years
|
|
884
|
|
|
875
|
|
||
Other
|
5 - 60 years
|
|
1,398
|
|
|
1,396
|
|
||
Property, plant and equipment in-service
|
|
|
27,298
|
|
|
26,757
|
|
||
Accumulated depreciation and amortization
|
|
|
(8,793
|
)
|
|
(8,360
|
)
|
||
Net property, plant and equipment in-service
|
|
|
18,505
|
|
|
18,397
|
|
||
Construction work-in-progress
|
|
|
657
|
|
|
629
|
|
||
Total property, plant and equipment, net
|
|
|
$
|
19,162
|
|
|
$
|
19,026
|
|
(1)
|
Computer software costs included in intangible plant are initially assigned a depreciable life of
5
to
10
years.
|
|
|
|
Facility
|
|
Accumulated
|
|
Construction
|
|||||||
|
PacifiCorp
|
|
in
|
|
Depreciation and
|
|
Work-in-
|
|||||||
|
Share
|
|
Service
|
|
Amortization
|
|
Progress
|
|||||||
|
|
|
|
|
|
|
|
|||||||
Jim Bridger Nos. 1 - 4
|
67
|
%
|
|
$
|
1,420
|
|
|
$
|
583
|
|
|
$
|
10
|
|
Hunter No. 1
|
94
|
|
|
473
|
|
|
161
|
|
|
1
|
|
|||
Hunter No. 2
|
60
|
|
|
296
|
|
|
98
|
|
|
—
|
|
|||
Wyodak
|
80
|
|
|
467
|
|
|
203
|
|
|
1
|
|
|||
Colstrip Nos. 3 and 4
|
10
|
|
|
244
|
|
|
130
|
|
|
5
|
|
|||
Hermiston
|
50
|
|
|
178
|
|
|
76
|
|
|
2
|
|
|||
Craig Nos. 1 and 2
|
19
|
|
|
325
|
|
|
223
|
|
|
32
|
|
|||
Hayden No. 1
|
25
|
|
|
74
|
|
|
32
|
|
|
—
|
|
|||
Hayden No. 2
|
13
|
|
|
43
|
|
|
20
|
|
|
—
|
|
|||
Foote Creek
|
79
|
|
|
39
|
|
|
25
|
|
|
—
|
|
|||
Transmission and distribution facilities
|
Various
|
|
777
|
|
|
228
|
|
|
61
|
|
||||
Total
|
|
|
$
|
4,336
|
|
|
$
|
1,779
|
|
|
$
|
112
|
|
|
Weighted
|
|
|
|
|
||||
|
Average
|
|
|
|
|
||||
|
Remaining
|
|
|
|
|
||||
|
Life
|
|
2016
|
|
2015
|
||||
|
|
|
|
|
|
||||
Deferred income taxes
(1)
|
26 years
|
|
$
|
421
|
|
|
$
|
437
|
|
Employee benefit plans
(2)
|
21 years
|
|
525
|
|
|
499
|
|
||
Utah mine disposition
(3)
|
Various
|
|
166
|
|
|
186
|
|
||
Unamortized contract values
|
7 years
|
|
98
|
|
|
110
|
|
||
Deferred net power costs
|
1 year
|
|
33
|
|
|
86
|
|
||
Unrealized loss on derivative contracts
|
5 years
|
|
73
|
|
|
133
|
|
||
Asset retirement obligation
|
20 years
|
|
82
|
|
|
65
|
|
||
Other
|
Various
|
|
145
|
|
|
169
|
|
||
Total regulatory assets
|
|
|
$
|
1,543
|
|
|
$
|
1,685
|
|
|
|
|
|
|
|
||||
Reflected as:
|
|
|
|
|
|
||||
Current assets
|
|
|
$
|
53
|
|
|
$
|
102
|
|
Noncurrent assets
|
|
|
1,490
|
|
|
1,583
|
|
||
Total regulatory assets
|
|
|
$
|
1,543
|
|
|
$
|
1,685
|
|
(1)
|
Amounts primarily represent income tax benefits and expense related to certain property-related basis differences and other various items that PacifiCorp is required to pass on to its customers.
|
(2)
|
Represents amounts not yet recognized as a component of net periodic benefit cost that are expected to be included in rates when recognized.
|
(3)
|
Amounts represent regulatory assets established as a result of the Utah mine disposition discussed below for the net property, plant and equipment not considered probable of disallowance and for the portion of losses associated with the assets held for sale, UMWA 1974 Pension Plan withdrawal and closure costs incurred to date considered probable of recovery.
|
|
Weighted
|
|
|
|
|
||||
|
Average
|
|
|
|
|
||||
|
Remaining
|
|
|
|
|
||||
|
Life
|
|
2016
|
|
2015
|
||||
|
|
|
|
|
|
||||
Cost of removal
(1)
|
26 years
|
|
$
|
917
|
|
|
$
|
894
|
|
Deferred income taxes
|
Various
|
|
9
|
|
|
12
|
|
||
Other
|
Various
|
|
106
|
|
|
66
|
|
||
Total regulatory liabilities
|
|
|
$
|
1,032
|
|
|
$
|
972
|
|
|
|
|
|
|
|
||||
Reflected as:
|
|
|
|
|
|
||||
Current liabilities
|
|
|
$
|
54
|
|
|
$
|
34
|
|
Noncurrent liabilities
|
|
|
978
|
|
|
938
|
|
||
Total regulatory liabilities
|
|
|
$
|
1,032
|
|
|
$
|
972
|
|
(1)
|
Amounts represent estimated costs, as accrued through depreciation rates and exclusive of ARO liabilities, of removing property, plant and equipment in accordance with accepted regulatory practices. Amounts are deducted from rate base or otherwise accrue a carrying cost.
|
2016:
|
|
|
||
Credit facilities
|
|
$
|
1,000
|
|
Less:
|
|
|
||
Short-term debt
|
|
(270
|
)
|
|
Tax-exempt bond support
|
|
(142
|
)
|
|
Net credit facilities
|
|
$
|
588
|
|
|
|
|
||
2015:
|
|
|
||
Credit facilities
|
|
$
|
1,200
|
|
Less:
|
|
|
||
Short-term debt
|
|
(20
|
)
|
|
Tax-exempt bond support and letters of credit
|
|
(160
|
)
|
|
Net credit facilities
|
|
$
|
1,020
|
|
|
2016
|
|
2015
|
||||||||||||||
|
|
|
|
|
Average
|
|
|
|
Average
|
||||||||
|
Principal
|
|
Carrying
|
|
Interest
|
|
Carrying
|
|
Interest
|
||||||||
|
Amount
|
|
Value
|
|
Rate
|
|
Value
|
|
Rate
|
||||||||
|
|
|
|
|
|
|
|
|
|
||||||||
First mortgage bonds:
|
|
|
|
|
|
|
|
|
|
||||||||
3.85% to 8.53%, due through 2021
|
$
|
1,272
|
|
|
$
|
1,269
|
|
|
5.10
|
%
|
|
$
|
1,271
|
|
|
5.10
|
%
|
2.95% to 8.27%, due 2022 to 2026
|
1,829
|
|
|
1,820
|
|
|
4.10
|
|
|
1,819
|
|
|
4.10
|
|
|||
7.70% due 2031
|
300
|
|
|
298
|
|
|
7.70
|
|
|
298
|
|
|
7.70
|
|
|||
5.25% to 6.10%, due 2034 to 2036
|
850
|
|
|
843
|
|
|
5.80
|
|
|
843
|
|
|
5.80
|
|
|||
5.75% to 6.35%, due 2037 to 2039
|
2,150
|
|
|
2,134
|
|
|
6.00
|
|
|
2,133
|
|
|
6.00
|
|
|||
4.10% due 2042
|
300
|
|
|
297
|
|
|
4.10
|
|
|
297
|
|
|
4.10
|
|
|||
Variable-rate series, tax-exempt bond obligations (2016-0.69% to 0.86%; 2015-0.01% to 0.22%):
|
|
|
|
|
|
|
|
|
|
||||||||
Due 2017 to 2018
|
91
|
|
|
91
|
|
|
0.85
|
|
|
91
|
|
|
0.22
|
|
|||
Due 2018 to 2025
(1)
|
108
|
|
|
108
|
|
|
0.74
|
|
|
107
|
|
|
0.01
|
|
|||
Due 2024
(1)(2)
|
143
|
|
|
142
|
|
|
0.70
|
|
|
196
|
|
|
0.02
|
|
|||
Due 2024 to 2025
(2)
|
50
|
|
|
50
|
|
|
0.80
|
|
|
59
|
|
|
0.21
|
|
|||
Total long-term debt
|
7,093
|
|
|
7,052
|
|
|
|
|
7,114
|
|
|
|
|||||
Capital lease obligations:
|
|
|
|
|
|
|
|
|
|
||||||||
8.75% to 14.61%, due through 2035
|
27
|
|
|
27
|
|
|
11.09
|
|
|
32
|
|
|
11.25
|
|
|||
Total long-term debt and capital lease
|
|
|
|
|
|
|
|
|
|
||||||||
obligations
|
$
|
7,120
|
|
|
$
|
7,079
|
|
|
|
|
$
|
7,146
|
|
|
|
Reflected as:
|
|
|
|
||||
|
2016
|
|
2015
|
||||
|
|
|
|
||||
Current portion of long-term debt and capital lease obligations
|
$
|
58
|
|
|
$
|
68
|
|
Long-term debt and capital lease obligations
|
7,021
|
|
|
7,078
|
|
||
Total long-term debt and capital lease obligations
|
$
|
7,079
|
|
|
$
|
7,146
|
|
1)
|
Supported by
$255 million
and
$310 million
of fully available letters of credit issued under committed bank arrangements as of December 31,
2016
and
2015
, respectively.
|
2)
|
Secured by pledged first mortgage bonds registered to and held by the tax-exempt bond trustee generally with the same interest rates, maturity dates and redemption provisions as the tax-exempt bond obligations.
|
|
Long-term
|
|
Capital Lease
|
|
|
||||||
|
Debt
|
|
Obligations
|
|
Total
|
||||||
|
|
|
|
|
|
||||||
2017
|
$
|
52
|
|
|
$
|
9
|
|
|
$
|
61
|
|
2018
|
586
|
|
|
4
|
|
|
590
|
|
|||
2019
|
350
|
|
|
4
|
|
|
354
|
|
|||
2020
|
38
|
|
|
3
|
|
|
41
|
|
|||
2021
|
420
|
|
|
6
|
|
|
426
|
|
|||
Thereafter
|
5,647
|
|
|
20
|
|
|
5,667
|
|
|||
Total
|
7,093
|
|
|
46
|
|
|
7,139
|
|
|||
Unamortized discount and debt issuance costs
|
(41
|
)
|
|
—
|
|
|
(41
|
)
|
|||
Amounts representing interest
|
—
|
|
|
(19
|
)
|
|
(19
|
)
|
|||
Total
|
$
|
7,052
|
|
|
$
|
27
|
|
|
$
|
7,079
|
|
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Current:
|
|
|
|
|
|
||||||
Federal
|
$
|
169
|
|
|
$
|
130
|
|
|
$
|
2
|
|
State
|
32
|
|
|
26
|
|
|
10
|
|
|||
Total
|
201
|
|
|
156
|
|
|
12
|
|
|||
|
|
|
|
|
|
||||||
Deferred:
|
|
|
|
|
|
||||||
Federal
|
123
|
|
|
148
|
|
|
260
|
|
|||
State
|
21
|
|
|
29
|
|
|
43
|
|
|||
Total
|
144
|
|
|
177
|
|
|
303
|
|
|||
|
|
|
|
|
|
||||||
Investment tax credits
|
(5
|
)
|
|
(5
|
)
|
|
(6
|
)
|
|||
Total income tax expense
|
$
|
340
|
|
|
$
|
328
|
|
|
$
|
309
|
|
|
2016
|
|
2015
|
|
2014
|
|||
|
|
|
|
|
|
|||
Federal statutory income tax rate
|
35
|
%
|
|
35
|
%
|
|
35
|
%
|
State income taxes, net of federal income tax benefit
|
3
|
|
|
3
|
|
|
3
|
|
Federal income tax credits
|
(6
|
)
|
|
(6
|
)
|
|
(7
|
)
|
Other
|
(1
|
)
|
|
—
|
|
|
—
|
|
Effective income tax rate
|
31
|
%
|
|
32
|
%
|
|
31
|
%
|
|
2016
|
|
2015
|
||||
|
|
|
|
||||
Deferred income tax assets:
|
|
|
|
||||
Regulatory liabilities
|
$
|
393
|
|
|
$
|
374
|
|
Employee benefits
|
202
|
|
|
189
|
|
||
Derivative contracts and unamortized contract values
|
67
|
|
|
94
|
|
||
State carryforwards
|
69
|
|
|
68
|
|
||
Loss contingencies
|
12
|
|
|
67
|
|
||
Asset retirement obligations
|
78
|
|
|
81
|
|
||
Other
|
82
|
|
|
88
|
|
||
|
903
|
|
|
961
|
|
||
Deferred income tax liabilities:
|
|
|
|
||||
Property, plant and equipment
|
(5,161
|
)
|
|
(5,030
|
)
|
||
Regulatory assets
|
(586
|
)
|
|
(639
|
)
|
||
Other
|
(36
|
)
|
|
(42
|
)
|
||
|
(5,783
|
)
|
|
(5,711
|
)
|
||
Net deferred income tax liability
|
$
|
(4,880
|
)
|
|
$
|
(4,750
|
)
|
|
|
State
|
||
|
|
|
||
Net operating loss carryforwards
|
|
$
|
1,415
|
|
Deferred income taxes on net operating loss carryforwards
|
|
$
|
52
|
|
Expiration dates
|
|
2017 - 2032
|
|
|
|
|
|
||
Tax credit carryforwards
|
|
$
|
17
|
|
Expiration dates
|
|
2017 - indefinite
|
|
(
9
)
|
Employee Benefit Plans
|
|
Pension
|
|
Other Postretirement
|
||||||||||||||||||||
|
2016
|
|
2015
|
|
2014
|
|
2016
|
|
2015
|
|
2014
|
||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Service cost
|
$
|
4
|
|
|
$
|
4
|
|
|
$
|
5
|
|
|
$
|
2
|
|
|
$
|
3
|
|
|
$
|
6
|
|
Interest cost
|
54
|
|
|
53
|
|
|
57
|
|
|
15
|
|
|
16
|
|
|
28
|
|
||||||
Expected return on plan assets
|
(75
|
)
|
|
(77
|
)
|
|
(76
|
)
|
|
(21
|
)
|
|
(23
|
)
|
|
(31
|
)
|
||||||
Net amortization
|
34
|
|
|
42
|
|
|
29
|
|
|
(5
|
)
|
|
(4
|
)
|
|
2
|
|
||||||
Net periodic benefit cost (credit)
|
$
|
17
|
|
|
$
|
22
|
|
|
$
|
15
|
|
|
$
|
(9
|
)
|
|
$
|
(8
|
)
|
|
$
|
5
|
|
|
Pension
|
|
Other Postretirement
|
||||||||||||
|
2016
|
|
2015
|
|
2016
|
|
2015
|
||||||||
|
|
|
|
|
|
|
|
||||||||
Plan assets at fair value, beginning of year
|
$
|
1,043
|
|
|
$
|
1,146
|
|
|
$
|
305
|
|
|
$
|
482
|
|
Employer contributions
|
5
|
|
|
4
|
|
|
1
|
|
|
1
|
|
||||
Participant contributions
|
—
|
|
|
—
|
|
|
6
|
|
|
6
|
|
||||
Actual return on plan assets
|
51
|
|
|
—
|
|
|
17
|
|
|
1
|
|
||||
Settlement
|
—
|
|
|
—
|
|
|
—
|
|
|
(150
|
)
|
||||
Benefits paid
|
(100
|
)
|
|
(107
|
)
|
|
(27
|
)
|
|
(35
|
)
|
||||
Plan assets at fair value, end of year
|
$
|
999
|
|
|
$
|
1,043
|
|
|
$
|
302
|
|
|
$
|
305
|
|
|
Pension
|
|
Other Postretirement
|
||||||||||||
|
2016
|
|
2015
|
|
2016
|
|
2015
|
||||||||
|
|
|
|
|
|
|
|
||||||||
Benefit obligation, beginning of year
|
$
|
1,289
|
|
|
$
|
1,378
|
|
|
$
|
362
|
|
|
$
|
539
|
|
Service cost
|
4
|
|
|
4
|
|
|
2
|
|
|
3
|
|
||||
Interest cost
|
54
|
|
|
53
|
|
|
15
|
|
|
16
|
|
||||
Participant contributions
|
—
|
|
|
—
|
|
|
6
|
|
|
6
|
|
||||
Actuarial (gain) loss
|
29
|
|
|
(39
|
)
|
|
—
|
|
|
(17
|
)
|
||||
Settlement
|
—
|
|
|
—
|
|
|
—
|
|
|
(150
|
)
|
||||
Benefits paid
|
(100
|
)
|
|
(107
|
)
|
|
(27
|
)
|
|
(35
|
)
|
||||
Benefit obligation, end of year
|
$
|
1,276
|
|
|
$
|
1,289
|
|
|
$
|
358
|
|
|
$
|
362
|
|
Accumulated benefit obligation, end of year
|
$
|
1,276
|
|
|
$
|
1,289
|
|
|
|
|
|
|
Pension
|
|
Other Postretirement
|
||||||||||||
|
2016
|
|
2015
|
|
2016
|
|
2015
|
||||||||
|
|
|
|
|
|
|
|
||||||||
Plan assets at fair value, end of year
|
$
|
999
|
|
|
$
|
1,043
|
|
|
$
|
302
|
|
|
$
|
305
|
|
Less - Benefit obligation, end of year
|
1,276
|
|
|
1,289
|
|
|
358
|
|
|
362
|
|
||||
Funded status
|
$
|
(277
|
)
|
|
$
|
(246
|
)
|
|
$
|
(56
|
)
|
|
$
|
(57
|
)
|
|
|
|
|
|
|
|
|
||||||||
Amounts recognized on the Consolidated Balance Sheets:
|
|
|
|
|
|
|
|
||||||||
Other current liabilities
|
$
|
(5
|
)
|
|
$
|
(4
|
)
|
|
$
|
—
|
|
|
$
|
—
|
|
Other long-term liabilities
|
(272
|
)
|
|
(242
|
)
|
|
(56
|
)
|
|
(57
|
)
|
||||
Amounts recognized
|
$
|
(277
|
)
|
|
$
|
(246
|
)
|
|
$
|
(56
|
)
|
|
$
|
(57
|
)
|
|
Pension
|
|
Other Postretirement
|
||||||||||||
|
2016
|
|
2015
|
|
2016
|
|
2015
|
||||||||
|
|
|
|
|
|
|
|
||||||||
Net loss
|
$
|
518
|
|
|
$
|
508
|
|
|
$
|
39
|
|
|
$
|
36
|
|
Prior service credit
|
—
|
|
|
(13
|
)
|
|
(13
|
)
|
|
(19
|
)
|
||||
Regulatory deferrals
|
(7
|
)
|
|
(3
|
)
|
|
8
|
|
|
9
|
|
||||
Total
|
$
|
511
|
|
|
$
|
492
|
|
|
$
|
34
|
|
|
$
|
26
|
|
|
|
|
Accumulated
|
|
|
||||||
|
|
|
Other
|
|
|
||||||
|
Regulatory
|
|
Comprehensive
|
|
|
||||||
|
Asset
|
|
Loss
|
|
Total
|
||||||
Pension
|
|
|
|
|
|
||||||
Balance, December 31, 2014
|
$
|
474
|
|
|
$
|
22
|
|
|
$
|
496
|
|
Net loss (gain) arising during the year
|
40
|
|
|
(2
|
)
|
|
38
|
|
|||
Net amortization
|
(41
|
)
|
|
(1
|
)
|
|
(42
|
)
|
|||
Total
|
(1
|
)
|
|
(3
|
)
|
|
(4
|
)
|
|||
Balance, December 31, 2015
|
473
|
|
|
19
|
|
|
492
|
|
|||
Net loss arising during the year
|
51
|
|
|
2
|
|
|
53
|
|
|||
Net amortization
|
(33
|
)
|
|
(1
|
)
|
|
(34
|
)
|
|||
Total
|
18
|
|
|
1
|
|
|
19
|
|
|||
Balance, December 31, 2016
|
$
|
491
|
|
|
$
|
20
|
|
|
$
|
511
|
|
|
Regulatory
|
||
|
Asset
|
||
Other Postretirement
|
|
||
Balance, December 31, 2014
|
$
|
17
|
|
Net loss arising during the year
|
5
|
|
|
Net amortization
|
4
|
|
|
Total
|
9
|
|
|
Balance, December 31, 2015
|
26
|
|
|
Net loss arising during the year
|
3
|
|
|
Net amortization
|
5
|
|
|
Total
|
8
|
|
|
Balance, December 31, 2016
|
$
|
34
|
|
|
|
Net
|
|
Prior Service
|
|
Regulatory
|
|
|
||||||||
|
|
Loss
|
|
Credit
|
|
Deferrals
|
|
Total
|
||||||||
|
|
|
|
|
|
|
|
|
||||||||
Pension
|
|
$
|
16
|
|
|
$
|
—
|
|
|
$
|
(2
|
)
|
|
$
|
14
|
|
Other postretirement
|
|
—
|
|
|
(7
|
)
|
|
1
|
|
|
(6
|
)
|
||||
Total
|
|
$
|
16
|
|
|
$
|
(7
|
)
|
|
$
|
(1
|
)
|
|
$
|
8
|
|
|
Pension
|
|
Other Postretirement
|
||||||||||||||
|
2016
|
|
2015
|
|
2014
|
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Benefit obligations as of December 31:
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Discount rate
|
4.05
|
%
|
|
4.40
|
%
|
|
4.00
|
%
|
|
4.05
|
%
|
|
4.35
|
%
|
|
3.90
|
%
|
Rate of compensation increase
|
N/A
|
|
|
2.75
|
|
|
2.75
|
|
|
N/A
|
|
|
N/A
|
|
|
N/A
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Net periodic benefit cost for the years ended December 31:
|
|
|
|
|
|
|
|
|
|
|
|||||||
Discount rate
|
4.40
|
%
|
|
4.00
|
%
|
|
4.80
|
%
|
|
4.35
|
%
|
|
3.99
|
%
|
|
4.90
|
%
|
Expected return on plan assets
|
7.50
|
|
|
7.50
|
|
|
7.50
|
|
|
7.50
|
|
|
7.08
|
|
|
7.50
|
|
Rate of compensation increase
|
2.75
|
|
|
2.75
|
|
|
3.00
|
|
|
N/A
|
|
|
N/A
|
|
|
N/A
|
|
|
Projected Benefit Payments
|
||||||
|
Pension
|
|
Other Postretirement
|
||||
|
|
|
|
||||
2017
|
$
|
105
|
|
|
$
|
28
|
|
2018
|
109
|
|
|
28
|
|
||
2019
|
108
|
|
|
27
|
|
||
2020
|
104
|
|
|
30
|
|
||
2021
|
97
|
|
|
26
|
|
||
2022-2026
|
426
|
|
|
116
|
|
|
Pension
(1)
|
|
Other Postretirement
(1)
|
|
%
|
|
%
|
Debt securities
(2)
|
33 - 37
|
|
33 - 37
|
Equity securities
(2)
|
53 - 57
|
|
61 - 65
|
Limited partnership interests
|
8 - 12
|
|
1 - 3
|
Other
|
0 - 1
|
|
0 - 1
|
(1)
|
PacifiCorp's Retirement Plan trust includes a separate account that is used to fund benefits for the other postretirement benefit plan. In addition to this separate account, the assets for the other postretirement benefit plan are held in Voluntary Employees' Beneficiary Association ("VEBA") trusts, each of which has its own investment allocation strategies. Target allocations for the other postretirement benefit plan include the separate account of the Retirement Plan trust and the VEBA trusts.
|
(2)
|
For purposes of target allocation percentages and consistent with the plans' investment policy, investment funds are allocated based on the underlying investments in debt and equity securities.
|
|
|
Input Levels for Fair Value Measurements
|
|
|
||||||||||||
|
|
Level 1
(1)
|
|
Level 2
(1)
|
|
Level 3
(1)
|
|
Total
|
||||||||
As of December 31, 2016:
|
|
|
|
|
|
|
|
|
||||||||
Cash equivalents
|
|
$
|
—
|
|
|
$
|
10
|
|
|
$
|
—
|
|
|
$
|
10
|
|
Debt securities:
|
|
|
|
|
|
|
|
|
||||||||
United States government obligations
|
|
25
|
|
|
—
|
|
|
—
|
|
|
25
|
|
||||
Corporate obligations
|
|
—
|
|
|
36
|
|
|
—
|
|
|
36
|
|
||||
Municipal obligations
|
|
—
|
|
|
6
|
|
|
—
|
|
|
6
|
|
||||
Agency, asset and mortgage-backed obligations
|
|
—
|
|
|
37
|
|
|
—
|
|
|
37
|
|
||||
Equity securities:
|
|
|
|
|
|
|
|
|
||||||||
United States companies
|
|
389
|
|
|
—
|
|
|
—
|
|
|
389
|
|
||||
International companies
|
|
15
|
|
|
—
|
|
|
—
|
|
|
15
|
|
||||
Investment funds
(2)
|
|
83
|
|
|
—
|
|
|
—
|
|
|
83
|
|
||||
Total assets in the fair value hierarchy
|
|
$
|
512
|
|
|
$
|
89
|
|
|
$
|
—
|
|
|
601
|
|
|
Investment funds
(2)
measured at net asset value
|
|
|
|
|
|
|
|
337
|
|
|||||||
Limited partnership interests
(3)
measured at net asset value
|
|
|
|
|
|
|
|
61
|
|
|||||||
Investments at fair value
|
|
|
|
|
|
|
|
$
|
999
|
|
||||||
|
|
|
|
|
|
|
|
|
||||||||
As of December 31, 2015:
|
|
|
|
|
|
|
|
|
||||||||
Cash equivalents
|
|
$
|
—
|
|
|
$
|
10
|
|
|
$
|
—
|
|
|
$
|
10
|
|
Debt securities:
|
|
|
|
|
|
|
|
|
||||||||
United States government obligations
|
|
19
|
|
|
—
|
|
|
—
|
|
|
19
|
|
||||
Corporate obligations
|
|
—
|
|
|
42
|
|
|
—
|
|
|
42
|
|
||||
Municipal obligations
|
|
—
|
|
|
5
|
|
|
—
|
|
|
5
|
|
||||
Agency, asset and mortgage-backed obligations
|
|
—
|
|
|
43
|
|
|
—
|
|
|
43
|
|
||||
Equity securities:
|
|
|
|
|
|
|
|
|
||||||||
United States companies
|
|
408
|
|
|
—
|
|
|
—
|
|
|
408
|
|
||||
International companies
|
|
17
|
|
|
—
|
|
|
—
|
|
|
17
|
|
||||
Investment funds
(2)
|
|
83
|
|
|
—
|
|
|
—
|
|
|
83
|
|
||||
Total assets in the fair value hierarchy
|
|
$
|
527
|
|
|
$
|
100
|
|
|
$
|
—
|
|
|
627
|
|
|
Investment funds
(2)
measured at net asset value
|
|
|
|
|
|
|
|
351
|
|
|||||||
Limited partnership interests
(3)
measured at net asset value
|
|
|
|
|
|
|
|
65
|
|
|||||||
Investments at fair value
|
|
|
|
|
|
|
|
$
|
1,043
|
|
(1)
|
Refer to Note 12 for additional discussion regarding the three levels of the fair value hierarchy.
|
(2)
|
Investment funds are substantially comprised of mutual funds and collective trust funds.
These funds consist of equity and debt securities of approximately
54%
and
46%
respectively, for
2016
and
53%
and
47%
, respectively, for
2015
, and are invested in United States and international securities of approximately
39%
and
61%
, respectively, for
2016
and
40%
and
60%
, respectively, for
2015
.
|
(3)
|
Limited partnership interests include several funds that invest primarily in real estate, buyout, growth equity and venture capital.
|
|
|
Input Levels for Fair Value Measurements
|
|
|
||||||||||||
|
|
Level 1
(1)
|
|
Level 2
(1)
|
|
Level 3
(1)
|
|
Total
|
||||||||
As of December 31, 2016:
|
|
|
|
|
|
|
|
|
||||||||
Cash and cash equivalents
|
|
$
|
4
|
|
|
$
|
1
|
|
|
$
|
—
|
|
|
$
|
5
|
|
Debt securities:
|
|
|
|
|
|
|
|
|
||||||||
United States government obligations
|
|
11
|
|
|
—
|
|
|
—
|
|
|
11
|
|
||||
Corporate obligations
|
|
—
|
|
|
13
|
|
|
—
|
|
|
13
|
|
||||
Municipal obligations
|
|
—
|
|
|
2
|
|
|
—
|
|
|
2
|
|
||||
Agency, asset and mortgage-backed obligations
|
|
—
|
|
|
13
|
|
|
—
|
|
|
13
|
|
||||
Equity securities:
|
|
|
|
|
|
|
|
|
||||||||
United States companies
|
|
93
|
|
|
—
|
|
|
—
|
|
|
93
|
|
||||
International companies
|
|
4
|
|
|
—
|
|
|
—
|
|
|
4
|
|
||||
Investment funds
(2)
|
|
32
|
|
|
—
|
|
|
—
|
|
|
32
|
|
||||
Total assets in the fair value hierarchy
|
|
$
|
144
|
|
|
$
|
29
|
|
|
$
|
—
|
|
|
173
|
|
|
Investment funds
(2)
measured at net asset value
|
|
|
|
|
|
|
|
125
|
|
|||||||
Limited partnership interests
(3)
measured at net asset value
|
|
|
|
|
|
|
|
4
|
|
|||||||
Investments at fair value
|
|
|
|
|
|
|
|
$
|
302
|
|
||||||
|
|
|
|
|
|
|
|
|
||||||||
As of December 31, 2015:
|
|
|
|
|
|
|
|
|
||||||||
Cash and cash equivalents
|
|
$
|
4
|
|
|
$
|
1
|
|
|
$
|
—
|
|
|
$
|
5
|
|
Debt securities:
|
|
|
|
|
|
|
|
|
||||||||
United States government obligations
|
|
9
|
|
|
—
|
|
|
—
|
|
|
9
|
|
||||
Corporate obligations
|
|
—
|
|
|
15
|
|
|
—
|
|
|
15
|
|
||||
Municipal obligations
|
|
—
|
|
|
1
|
|
|
—
|
|
|
1
|
|
||||
Agency, asset and mortgage-backed obligations
|
|
—
|
|
|
14
|
|
|
—
|
|
|
14
|
|
||||
Equity securities:
|
|
|
|
|
|
|
|
|
||||||||
United States companies
|
|
95
|
|
|
—
|
|
|
—
|
|
|
95
|
|
||||
International companies
|
|
4
|
|
|
—
|
|
|
—
|
|
|
4
|
|
||||
Investment funds
(2)
|
|
32
|
|
|
—
|
|
|
—
|
|
|
32
|
|
||||
Total assets in the fair value hierarchy
|
|
$
|
144
|
|
|
$
|
31
|
|
|
$
|
—
|
|
|
175
|
|
|
Investment funds
(2)
measured at net asset value
|
|
|
|
|
|
|
|
126
|
|
|||||||
Limited partnership interests
(3)
measured at net asset value
|
|
|
|
|
|
|
|
4
|
|
|||||||
Investments at fair value
|
|
|
|
|
|
|
|
$
|
305
|
|
(1)
|
Refer to Note 12 for additional discussion regarding the three levels of the fair value hierarchy.
|
(2)
|
Investment funds are substantially comprised of mutual funds and collective trust funds.
These funds consist of equity and debt securities of approximately
62%
and
38%
, respectively, for
2016
and
61%
and
39%
, respectively, for
2015
,
and are invested in United States and international securities of approximately
71%
and
29%
, respectively, for
2016
and
67%
and
33%
, respectively, for
2015
.
|
(3)
|
Limited partnership interests include several funds that invest primarily in real estate, buyout, growth equity and venture capital.
|
|
|
|
|
PPA zone status or
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
|
|
|
|
plan funded status percentage for
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
|
|
|
|
plan years beginning July 1,
|
|
|
|
|
|
Contributions
(1)
|
|
|
||||||||||||||
Plan name
|
|
Employer Identification Number
|
|
2016
|
|
2015
|
|
2014
|
|
Funding improvement plan
|
|
Surcharge imposed under PPA
(1)
|
|
2016
|
|
2015
|
|
2014
|
|
Year contributions to plan exceeded more than 5% of total contributions
(2)
|
||||||
UMWA 1974 Pension Plan
|
|
52-1050282
|
|
Critical and Declining
|
|
Critical and Declining
|
|
Critical
|
|
Implemented
|
|
Yes
|
|
$
|
—
|
|
|
$
|
1
|
|
|
$
|
2
|
|
|
None
|
Local 57 Trust Fund
|
|
87-0640888
|
|
At least 80%
|
|
At least 80%
|
|
At least 80%
|
|
None
|
|
None
|
|
$
|
8
|
|
|
$
|
8
|
|
|
$
|
9
|
|
|
2015, 2014, 2013
|
(1)
|
PacifiCorp's and Energy West Mining Company's minimum contributions to the plans are based on the amount of wages paid to employees covered by the Local 57 Trust Fund collective bargaining agreements and the number of mining hours worked for the UMWA 1974 Pension Plan, respectively, subject to ERISA minimum funding requirements. As a result of the plan's critical status, Energy West Mining Company was required to begin paying a surcharge for hours worked on and after December 1, 2014.
|
(2)
|
For the UMWA 1974 Pension Plan, information is for plan years beginning July 1, 2014, 2013 and 2012. Information for the plan year beginning July 1, 2015 is not yet available. For the Local 57 Trust Fund, information is for plan years beginning July 1, 2014, 2013 and 2012. Information for the plan year beginning July 1, 2015 is not yet available.
|
|
2016
|
|
2015
|
||||
|
|
|
|
||||
Beginning balance
|
$
|
224
|
|
|
$
|
135
|
|
Change in estimated costs
|
2
|
|
|
62
|
|
||
Additions
|
—
|
|
|
30
|
|
||
Retirements
|
(19
|
)
|
|
(10
|
)
|
||
Accretion
|
8
|
|
|
7
|
|
||
Ending balance
|
$
|
215
|
|
|
$
|
224
|
|
|
|
|
|
||||
Reflected as:
|
|
|
|
||||
Other current liabilities
|
$
|
21
|
|
|
$
|
35
|
|
Other long-term liabilities
|
194
|
|
|
189
|
|
||
|
$
|
215
|
|
|
$
|
224
|
|
|
Other
|
|
|
|
Other
|
|
Other
|
|
|
||||||||||
|
Current
|
|
Other
|
|
Current
|
|
Long-term
|
|
|
||||||||||
|
Assets
|
|
Assets
|
|
Liabilities
|
|
Liabilities
|
|
Total
|
||||||||||
|
|
|
|
|
|
|
|
|
|
||||||||||
As of December 31, 2016:
|
|
|
|
|
|
|
|
|
|
||||||||||
Not designated as hedging contracts
(1)
:
|
|
|
|
|
|
|
|
|
|
||||||||||
Commodity assets
|
$
|
24
|
|
|
$
|
2
|
|
|
$
|
1
|
|
|
$
|
—
|
|
|
$
|
27
|
|
Commodity liabilities
|
(6
|
)
|
|
—
|
|
|
(14
|
)
|
|
(84
|
)
|
|
(104
|
)
|
|||||
Total
|
18
|
|
|
2
|
|
|
(13
|
)
|
|
(84
|
)
|
|
(77
|
)
|
|||||
|
|
|
|
|
|
|
|
|
|
||||||||||
Total derivatives
|
18
|
|
|
2
|
|
|
(13
|
)
|
|
(84
|
)
|
|
(77
|
)
|
|||||
Cash collateral receivable
|
—
|
|
|
—
|
|
|
10
|
|
|
59
|
|
|
69
|
|
|||||
Total derivatives - net basis
|
$
|
18
|
|
|
$
|
2
|
|
|
$
|
(3
|
)
|
|
$
|
(25
|
)
|
|
$
|
(8
|
)
|
|
|
|
|
|
|
|
|
|
|
||||||||||
As of December 31, 2015:
|
|
|
|
|
|
|
|
|
|
||||||||||
Not designated as hedging contracts
(1)
:
|
|
|
|
|
|
|
|
|
|
||||||||||
Commodity assets
|
$
|
10
|
|
|
$
|
—
|
|
|
$
|
2
|
|
|
$
|
—
|
|
|
$
|
12
|
|
Commodity liabilities
|
(1
|
)
|
|
—
|
|
|
(58
|
)
|
|
(89
|
)
|
|
(148
|
)
|
|||||
Total
|
9
|
|
|
—
|
|
|
(56
|
)
|
|
(89
|
)
|
|
(136
|
)
|
|||||
|
|
|
|
|
|
|
|
|
|
||||||||||
Total derivatives
|
9
|
|
|
—
|
|
|
(56
|
)
|
|
(89
|
)
|
|
(136
|
)
|
|||||
Cash collateral receivable
|
—
|
|
|
—
|
|
|
18
|
|
|
57
|
|
|
75
|
|
|||||
Total derivatives - net basis
|
$
|
9
|
|
|
$
|
—
|
|
|
$
|
(38
|
)
|
|
$
|
(32
|
)
|
|
$
|
(61
|
)
|
(1)
|
PacifiCorp's commodity derivatives are generally included in rates and as of December 31,
2016
and
2015
, a regulatory asset of
$73 million
and
$133 million
, respectively, was recorded related to the net derivative liability of
$77 million
and
$136 million
, respectively.
|
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Beginning balance
|
$
|
133
|
|
|
$
|
85
|
|
|
$
|
55
|
|
Changes in fair value recognized in regulatory assets
|
(27
|
)
|
|
82
|
|
|
45
|
|
|||
Net gains reclassified to operating revenue
|
10
|
|
|
40
|
|
|
(4
|
)
|
|||
Net losses reclassified to energy costs
|
(43
|
)
|
|
(74
|
)
|
|
(11
|
)
|
|||
Ending balance
|
$
|
73
|
|
|
$
|
133
|
|
|
$
|
85
|
|
|
Unit of
|
|
|
|
|
||
|
Measure
|
|
2016
|
|
2015
|
||
|
|
|
|
|
|
||
Electricity (sales) purchases
|
Megawatt hours
|
|
(3
|
)
|
|
1
|
|
Natural gas purchases
|
Decatherms
|
|
84
|
|
|
111
|
|
Fuel oil purchases
|
Gallons
|
|
11
|
|
|
11
|
|
(
12
)
|
Fair Value Measurements
|
•
|
Level 1 - Inputs are unadjusted quoted prices in active markets for identical assets or liabilities that PacifiCorp has the ability to access at the measurement date.
|
•
|
Level 2 - Inputs include quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, inputs other than quoted prices that are observable for the asset or liability and inputs that are derived principally from or corroborated by observable market data by correlation or other means (market corroborated inputs).
|
•
|
Level 3 - Unobservable inputs reflect PacifiCorp's judgments about the assumptions market participants would use in pricing the asset or liability since limited market data exists. PacifiCorp develops these inputs based on the best information available, including its own data.
|
|
Input Levels for Fair Value Measurements
|
|
|
|
|
||||||||||||||
|
Level 1
|
|
Level 2
|
|
Level 3
|
|
Other
(1)
|
|
Total
|
||||||||||
As of December 31, 2016:
|
|
|
|
|
|
|
|
|
|
||||||||||
Assets:
|
|
|
|
|
|
|
|
|
|
||||||||||
Commodity derivatives
|
$
|
—
|
|
|
$
|
27
|
|
|
$
|
—
|
|
|
$
|
(7
|
)
|
|
$
|
20
|
|
Money market mutual funds
(2)
|
13
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
13
|
|
|||||
Investment funds
|
17
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
17
|
|
|||||
|
$
|
30
|
|
|
$
|
27
|
|
|
$
|
—
|
|
|
$
|
(7
|
)
|
|
$
|
50
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Liabilities - Commodity derivatives
|
$
|
—
|
|
|
$
|
(104
|
)
|
|
$
|
—
|
|
|
$
|
76
|
|
|
$
|
(28
|
)
|
|
|
|
|
|
|
|
|
|
|
||||||||||
As of December 31, 2015:
|
|
|
|
|
|
|
|
|
|
||||||||||
Assets:
|
|
|
|
|
|
|
|
|
|
||||||||||
Commodity derivatives
|
$
|
—
|
|
|
$
|
9
|
|
|
$
|
3
|
|
|
$
|
(3
|
)
|
|
$
|
9
|
|
Money market mutual funds
(2)
|
13
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
13
|
|
|||||
Investment funds
|
15
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
15
|
|
|||||
|
$
|
28
|
|
|
$
|
9
|
|
|
$
|
3
|
|
|
$
|
(3
|
)
|
|
$
|
37
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Liabilities - Commodity derivatives
|
$
|
—
|
|
|
$
|
(148
|
)
|
|
$
|
—
|
|
|
$
|
78
|
|
|
$
|
(70
|
)
|
(1)
|
Represents netting under master netting arrangements and a net cash collateral receivable of
$69 million
and
$75 million
as of December 31,
2016
and
2015
, respectively.
|
(2)
|
Amounts are included in cash and cash equivalents, other current assets and other assets on the Consolidated Balance Sheets. The fair value of these money market mutual funds approximates cost.
|
|
2017
|
|
2018
|
|
2019
|
|
2020
|
|
2021
|
|
2022 and Thereafter
|
|
Total
|
||||||||||||||
Contract type:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Purchased electricity contracts -
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
commercially operable
|
$
|
253
|
|
|
$
|
160
|
|
|
$
|
157
|
|
|
$
|
157
|
|
|
$
|
145
|
|
|
$
|
1,630
|
|
|
$
|
2,502
|
|
Purchased electricity contracts -
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
non-commercially operable
|
10
|
|
|
13
|
|
|
17
|
|
|
17
|
|
|
18
|
|
|
390
|
|
|
465
|
|
|||||||
Fuel contracts
|
796
|
|
|
616
|
|
|
596
|
|
|
507
|
|
|
346
|
|
|
1,407
|
|
|
4,268
|
|
|||||||
Construction commitments
|
62
|
|
|
46
|
|
|
26
|
|
|
4
|
|
|
1
|
|
|
4
|
|
|
143
|
|
|||||||
Transmission
|
109
|
|
|
106
|
|
|
90
|
|
|
61
|
|
|
47
|
|
|
467
|
|
|
880
|
|
|||||||
Operating leases and easements
|
5
|
|
|
5
|
|
|
5
|
|
|
5
|
|
|
4
|
|
|
39
|
|
|
63
|
|
|||||||
Maintenance, service and
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
other contracts
|
53
|
|
|
29
|
|
|
31
|
|
|
17
|
|
|
20
|
|
|
68
|
|
|
218
|
|
|||||||
Total commitments
|
$
|
1,288
|
|
|
$
|
975
|
|
|
$
|
922
|
|
|
$
|
768
|
|
|
$
|
581
|
|
|
$
|
4,005
|
|
|
$
|
8,539
|
|
|
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
|
||||||
Interest paid, net of amounts capitalized
|
|
$
|
350
|
|
|
$
|
342
|
|
|
$
|
340
|
|
Income taxes paid, net
|
|
$
|
201
|
|
|
$
|
40
|
|
|
$
|
161
|
|
Item 6.
|
Selected Financial Data
|
Item 7.
|
Management's Discussion and Analysis of Financial Condition and Results of Operations
|
|
2016
|
|
2015
|
|
Change
|
|
2015
|
|
2014
|
|
Change
|
||||||||||||||||||
Gross margin (in millions):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Operating revenue
|
$
|
1,985
|
|
|
$
|
1,837
|
|
|
$
|
148
|
|
|
8
|
%
|
|
$
|
1,837
|
|
|
$
|
1,817
|
|
|
$
|
20
|
|
|
1
|
%
|
Cost of fuel, energy and capacity
(1)
|
409
|
|
|
433
|
|
|
(24
|
)
|
|
(6
|
)
|
|
433
|
|
|
532
|
|
|
(99
|
)
|
|
(19
|
)
|
||||||
Gross margin
|
$
|
1,576
|
|
|
$
|
1,404
|
|
|
$
|
172
|
|
|
12
|
|
|
$
|
1,404
|
|
|
$
|
1,285
|
|
|
$
|
119
|
|
|
9
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Sales (GWh):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Residential
|
6,408
|
|
|
6,166
|
|
|
242
|
|
|
4
|
%
|
|
6,166
|
|
|
6,429
|
|
|
(263
|
)
|
|
(4
|
)%
|
||||||
Commercial
|
3,812
|
|
|
3,806
|
|
|
6
|
|
|
—
|
|
|
3,806
|
|
|
4,084
|
|
|
(278
|
)
|
|
(7
|
)
|
||||||
Industrial
|
12,115
|
|
|
11,487
|
|
|
628
|
|
|
5
|
|
|
11,487
|
|
|
10,642
|
|
|
845
|
|
|
8
|
|
||||||
Other
|
1,589
|
|
|
1,583
|
|
|
6
|
|
|
—
|
|
|
1,583
|
|
|
1,622
|
|
|
(39
|
)
|
|
(2
|
)
|
||||||
Total retail
|
23,924
|
|
|
23,042
|
|
|
882
|
|
|
4
|
|
|
23,042
|
|
|
22,777
|
|
|
265
|
|
|
1
|
|
||||||
Wholesale
|
8,489
|
|
|
8,741
|
|
|
(252
|
)
|
|
(3
|
)
|
|
8,741
|
|
|
9,716
|
|
|
(975
|
)
|
|
(10
|
)
|
||||||
Total sales
|
32,413
|
|
|
31,783
|
|
|
630
|
|
|
2
|
|
|
31,783
|
|
|
32,493
|
|
|
(710
|
)
|
|
(2
|
)
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Average number of retail customers (in thousands)
|
760
|
|
|
752
|
|
|
8
|
|
|
1
|
%
|
|
752
|
|
|
746
|
|
|
6
|
|
|
1
|
%
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Average revenue per MWh:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Retail
|
$
|
71.86
|
|
|
$
|
69.68
|
|
|
$
|
2.18
|
|
|
3
|
%
|
|
$
|
69.68
|
|
|
$
|
66.92
|
|
|
$
|
2.76
|
|
|
4
|
%
|
Wholesale
|
$
|
22.95
|
|
|
$
|
20.09
|
|
|
$
|
2.86
|
|
|
14
|
%
|
|
$
|
20.09
|
|
|
$
|
26.48
|
|
|
$
|
(6.39
|
)
|
|
(24
|
)%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Heating degree days
|
5,321
|
|
|
5,654
|
|
|
(333
|
)
|
|
(6
|
)%
|
|
5,654
|
|
|
6,899
|
|
|
(1,245
|
)
|
|
(18
|
)%
|
||||||
Cooling degree days
|
1,314
|
|
|
1,067
|
|
|
247
|
|
|
23
|
%
|
|
1,067
|
|
|
933
|
|
|
134
|
|
|
14
|
%
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Sources of energy (GWh)
(2)
:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Coal
|
13,179
|
|
|
15,525
|
|
|
(2,346
|
)
|
|
(15
|
)%
|
|
15,525
|
|
|
18,234
|
|
|
(2,709
|
)
|
|
(15
|
)%
|
||||||
Nuclear
|
3,912
|
|
|
3,885
|
|
|
27
|
|
|
1
|
|
|
3,885
|
|
|
3,842
|
|
|
43
|
|
|
1
|
|
||||||
Natural gas
|
556
|
|
|
199
|
|
|
357
|
|
|
*
|
|
199
|
|
|
114
|
|
|
85
|
|
|
75
|
|
|||||||
Wind and other
(3)
|
11,684
|
|
|
9,606
|
|
|
2,078
|
|
|
22
|
|
|
9,606
|
|
|
7,965
|
|
|
1,641
|
|
|
21
|
|
||||||
Total energy generated
|
29,331
|
|
|
29,215
|
|
|
116
|
|
|
—
|
|
|
29,215
|
|
|
30,155
|
|
|
(940
|
)
|
|
(3
|
)
|
||||||
Energy purchased
|
3,882
|
|
|
3,194
|
|
|
688
|
|
|
22
|
|
|
3,194
|
|
|
3,029
|
|
|
165
|
|
|
5
|
|
||||||
Total
|
33,213
|
|
|
32,409
|
|
|
804
|
|
|
2
|
|
|
32,409
|
|
|
33,184
|
|
|
(775
|
)
|
|
(2
|
)
|
*
|
Not meaningful.
|
(1)
|
Effective in August 2014, MidAmerican Energy is allowed to recover fluctuations in electric energy costs for its Iowa retail electric generation through an energy adjustment mechanism.
|
(2)
|
GWh amounts are net of energy used by the related generating facilities.
|
(3)
|
All or some of the renewable energy attributes associated with generation from these generating facilities may be: (a) used in future years to comply with renewable portfolio standards or other regulatory requirements or (b) sold to third parties in the form of renewable energy credits or other environmental commodities.
|
(1)
|
Higher retail gross margin of $118 million due to -
|
•
|
an increase of $47 million from higher electric rates in Iowa effective January 1, 2016, for the third step of a 2014 Iowa rate increase;
|
•
|
an increase of $33 million primarily from non-weather-related usage factors, including higher industrial sales volumes;
|
•
|
an increase of $27 million from the impact of temperatures;
|
•
|
an increase of $13 million from lower retail energy costs due to a lower average cost of fuel for generation and lower coal-fueled generation; partially offset by
|
•
|
a decrease of $2 million from lower recoveries through bill riders;
|
(2)
|
Higher wholesale gross margin of $37 million due to higher margins per unit from greater availability of lower cost generation for wholesale purposes, partially offset by lower sales volumes attributable to lower coal-fueled generation; and
|
(3)
|
Higher MVP transmission revenue of $17 million, which is expected to increase as projects are constructed.
|
(1)
|
Higher retail gross margin of $109 million due to -
|
•
|
an increase of $70 million from higher electric rates, reflecting higher rates of $45 million annually, effective January 2015, for the second step of a 2014 Iowa rate increase, $16 million annually in Illinois, effective December 2014, and an increase from the full-year impact of changes in Iowa rate structure related to seasonal pricing, which were effective with the implementation of final Iowa base rates in August 2014 that resulted in a greater differential between summer rates from June to September and rates in the remaining months;
|
•
|
an increase of $32 million from lower retail energy costs primarily due to a lower average cost of fuel for generation and lower purchased power costs;
|
•
|
an increase of $11 million from non-weather-related usage factors;
|
•
|
an increase of $8 million principally from higher recoveries through bill riders; and
|
•
|
a decrease of $8 million from the impact of temperatures;
|
(2)
|
Higher MVP transmission revenue of $25 million, which is expected to increase as projects are constructed; partially offset by
|
(3)
|
Lower wholesale gross margin of $15 million due to decreases of -
|
•
|
$9 million from lower sales volumes; and
|
•
|
$6 million from lower average prices.
|
|
2016
|
|
2015
|
|
Change
|
|
2015
|
|
2014
|
|
Change
|
||||||||||||||||||
Gross margin (in millions):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Operating revenue
|
$
|
637
|
|
|
$
|
661
|
|
|
$
|
(24
|
)
|
|
(4
|
)%
|
|
$
|
661
|
|
|
$
|
996
|
|
|
$
|
(335
|
)
|
|
(34
|
)%
|
Cost of gas sold
|
367
|
|
|
397
|
|
|
(30
|
)
|
|
(8
|
)
|
|
397
|
|
|
720
|
|
|
(323
|
)
|
|
(45
|
)
|
||||||
Gross margin
|
$
|
270
|
|
|
$
|
264
|
|
|
$
|
6
|
|
|
2
|
|
|
$
|
264
|
|
|
$
|
276
|
|
|
$
|
(12
|
)
|
|
(4
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Natural gas throughput (000's Dths):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Residential
|
46,020
|
|
|
46,519
|
|
|
(499
|
)
|
|
(1
|
)%
|
|
46,519
|
|
|
56,224
|
|
|
(9,705
|
)
|
|
(17
|
)%
|
||||||
Commercial
|
23,345
|
|
|
23,466
|
|
|
(121
|
)
|
|
(1
|
)
|
|
23,466
|
|
|
28,256
|
|
|
(4,790
|
)
|
|
(17
|
)
|
||||||
Industrial
|
5,079
|
|
|
4,833
|
|
|
246
|
|
|
5
|
|
|
4,833
|
|
|
5,335
|
|
|
(502
|
)
|
|
(9
|
)
|
||||||
Other
|
37
|
|
|
37
|
|
|
—
|
|
|
—
|
|
|
37
|
|
|
48
|
|
|
(11
|
)
|
|
(23
|
)
|
||||||
Total retail sales
|
74,481
|
|
|
74,855
|
|
|
(374
|
)
|
|
—
|
|
|
74,855
|
|
|
89,863
|
|
|
(15,008
|
)
|
|
(17
|
)
|
||||||
Wholesale sales
|
38,813
|
|
|
35,250
|
|
|
3,563
|
|
|
10
|
|
|
35,250
|
|
|
25,346
|
|
|
9,904
|
|
|
39
|
|
||||||
Total sales
|
113,294
|
|
|
110,105
|
|
|
3,189
|
|
|
3
|
|
|
110,105
|
|
|
115,209
|
|
|
(5,104
|
)
|
|
(4
|
)
|
||||||
Gas transportation service
|
83,610
|
|
|
80,001
|
|
|
3,609
|
|
|
5
|
|
|
80,001
|
|
|
82,314
|
|
|
(2,313
|
)
|
|
(3
|
)
|
||||||
Total gas throughput
|
196,904
|
|
|
190,106
|
|
|
6,798
|
|
|
4
|
|
|
190,106
|
|
|
197,523
|
|
|
(7,417
|
)
|
|
(4
|
)
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Average number of retail customers (in thousands)
|
742
|
|
|
733
|
|
|
9
|
|
|
1
|
%
|
|
733
|
|
|
726
|
|
|
7
|
|
|
1
|
%
|
||||||
Average revenue per retail Dth sold
|
$
|
6.85
|
|
|
$
|
7.12
|
|
|
$
|
(0.27
|
)
|
|
(4
|
)%
|
|
$
|
7.12
|
|
|
$
|
9.24
|
|
|
$
|
(2.12
|
)
|
|
(23
|
)%
|
Average cost of natural gas per retail Dth sold
|
$
|
3.70
|
|
|
$
|
4.03
|
|
|
$
|
(0.33
|
)
|
|
(8
|
)%
|
|
$
|
4.03
|
|
|
$
|
6.54
|
|
|
$
|
(2.51
|
)
|
|
(38
|
)%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Combined retail and wholesale average cost of natural gas per Dth sold
|
$
|
3.24
|
|
|
$
|
3.61
|
|
|
$
|
(0.37
|
)
|
|
(10
|
)%
|
|
$
|
3.61
|
|
|
$
|
6.25
|
|
|
$
|
(2.64
|
)
|
|
(42
|
)%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Heating degree days
|
5,616
|
|
|
5,913
|
|
|
(297
|
)
|
|
(5
|
)%
|
|
5,913
|
|
|
7,209
|
|
|
(1,296
|
)
|
|
(18
|
)%
|
|
Historical
|
|
Forecast
|
||||||||||||||||||||
|
2014
|
|
2015
|
|
2016
|
|
2017
|
|
2018
|
|
2019
|
||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Wind-powered generation development
|
$
|
767
|
|
|
$
|
931
|
|
|
$
|
943
|
|
|
$
|
843
|
|
|
$
|
880
|
|
|
$
|
1,438
|
|
Wind-powered generation repowering
|
—
|
|
|
—
|
|
|
67
|
|
|
292
|
|
|
132
|
|
|
—
|
|
||||||
Transmission Multi-Value Projects
|
144
|
|
|
156
|
|
|
119
|
|
|
38
|
|
|
37
|
|
|
—
|
|
||||||
Other
|
615
|
|
|
359
|
|
|
507
|
|
|
678
|
|
|
475
|
|
|
341
|
|
||||||
Total
|
$
|
1,526
|
|
|
$
|
1,446
|
|
|
$
|
1,636
|
|
|
$
|
1,851
|
|
|
$
|
1,524
|
|
|
$
|
1,779
|
|
•
|
The construction of wind-powered generating facilities in Iowa. As of
December 31, 2016
, MidAmerican Energy had 4,048 MW (nominal ratings) placed in service. In August 2016, the IUB issued an order approving ratemaking principles related to MidAmerican Energy's construction of up to 2,000 MW (nominal ratings) of additional wind-powered generating facilities expected to be placed in service in 2017 through 2019. The ratemaking principles establish a cost cap of $3.6 billion, including AFUDC, and a fixed rate of return on equity of 11.0% over the proposed 40-year useful lives of those facilities in any future Iowa rate proceeding. The cost cap ensures that as long as total costs are below the cap, the investment will be deemed prudent in any future Iowa rate proceeding. Additionally, the ratemaking principles modify the revenue sharing mechanism currently in effect. The revised sharing mechanism will be effective in 2018 and will be triggered each year by actual equity returns exceeding the weighted average return on equity for MidAmerican Energy calculated annually. Pursuant to the change in revenue sharing, MidAmerican Energy will share 100% of the revenue in excess of this trigger with customers. Such revenue sharing will reduce coal and nuclear generation rate base, which is intended to mitigate future base rate increases. MidAmerican Energy expects all of these wind-powered generating facilities to qualify for 100% of federal production tax credits available.
|
•
|
The repowering of certain existing wind-powered generating facilities in Iowa. This project entails the replacement of significant components of the oldest turbines in MidAmerican Energy’s fleet. The energy production from such repowered facilities is expected to qualify for 100% of the federal production tax credits available for ten years following completion.
|
•
|
Transmission MVP investments. MidAmerican Energy has approval from the MISO for the construction of four MVPs located in Iowa and Illinois totaling approximately $520 million in capital expenditures, excluding non-cash equity AFUDC. When complete, the four MVPs will have added approximately 250 miles of 345 kV transmission line to MidAmerican Energy's transmission system and will be owned and operated by MidAmerican Energy. As of December 31, 2016, MidAmerican Energy has invested $445 million since 2012, excluding non-cash equity AFUDC.
|
•
|
Remaining expenditures primarily relate to
routine operating projects for distribution, generation, transmission and other infrastructure needed to serve existing and expected demand.
|
|
Payments Due By Periods
|
|
|
||||||||||||||||
|
|
|
2018-
|
|
2020-
|
|
2022 and
|
|
|
||||||||||
|
2017
|
|
2019
|
|
2021
|
|
After
|
|
Total
|
||||||||||
MidAmerican Energy:
|
|
|
|
|
|
|
|
|
|
||||||||||
Long-term debt
|
$
|
251
|
|
|
$
|
851
|
|
|
$
|
3
|
|
|
$
|
3,227
|
|
|
$
|
4,332
|
|
Interest payments on long-term debt
(1) (2)
|
192
|
|
|
321
|
|
|
293
|
|
|
2,150
|
|
|
2,956
|
|
|||||
Coal, electricity and natural gas contract commitments
(1)
|
315
|
|
|
218
|
|
|
75
|
|
|
82
|
|
|
690
|
|
|||||
Construction commitments
(1)
|
347
|
|
|
7
|
|
|
—
|
|
|
—
|
|
|
354
|
|
|||||
Easements and operating leases
(1)
|
20
|
|
|
40
|
|
|
38
|
|
|
624
|
|
|
722
|
|
|||||
Other commitments
(1)
|
72
|
|
|
181
|
|
|
178
|
|
|
210
|
|
|
641
|
|
|||||
|
1,197
|
|
|
1,618
|
|
|
587
|
|
|
6,293
|
|
|
9,695
|
|
|||||
|
|
|
|
|
|
|
|
|
|
||||||||||
MidAmerican Funding parent:
|
|
|
|
|
|
|
|
|
|
||||||||||
Long-term debt
|
—
|
|
|
—
|
|
|
—
|
|
|
325
|
|
|
325
|
|
|||||
Interest payments on long-term debt
(1)
|
22
|
|
|
45
|
|
|
45
|
|
|
169
|
|
|
281
|
|
|||||
|
22
|
|
|
45
|
|
|
45
|
|
|
494
|
|
|
606
|
|
|||||
Total contractual cash obligations
|
$
|
1,219
|
|
|
$
|
1,663
|
|
|
$
|
632
|
|
|
$
|
6,787
|
|
|
$
|
10,301
|
|
(1)
|
Not reflected on the Consolidated Balance Sheets.
|
(2)
|
Includes interest payments for tax-exempt bond obligations with interest rates scheduled to reset periodically prior to maturity. Future variable interest rates are assumed to equal December 31,
2016
rates.
|
|
|
|
Other Postretirement
|
||||||||||||
|
Pension Plans
|
|
Benefit Plans
|
||||||||||||
|
+0.5%
|
|
-0.5%
|
|
+0.5%
|
|
-0.5%
|
||||||||
Effect on December 31, 2016 Benefit Obligations:
|
|
|
|
|
|
|
|
||||||||
Discount rate
|
$
|
(36
|
)
|
|
$
|
40
|
|
|
$
|
(9
|
)
|
|
$
|
10
|
|
|
|
|
|
|
|
|
|
||||||||
Effect on 2016 Periodic Cost:
|
|
|
|
|
|
|
|
||||||||
Discount rate
|
1
|
|
|
(1
|
)
|
|
—
|
|
|
—
|
|
||||
Expected rate of return on plan assets
|
(3
|
)
|
|
3
|
|
|
(1
|
)
|
|
1
|
|
Item 8.
|
Financial Statements and Supplementary Data
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Years Ended December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
Operating revenue:
|
|
|
|
|
|
||||||
Regulated electric
|
$
|
1,985
|
|
|
$
|
1,837
|
|
|
$
|
1,817
|
|
Regulated gas and other
|
640
|
|
|
665
|
|
|
1,005
|
|
|||
Total operating revenue
|
2,625
|
|
|
2,502
|
|
|
2,822
|
|
|||
|
|
|
|
|
|
||||||
Operating costs and expenses:
|
|
|
|
|
|
||||||
Cost of fuel, energy and capacity
|
409
|
|
|
433
|
|
|
532
|
|
|||
Cost of gas sold and other
|
367
|
|
|
398
|
|
|
720
|
|
|||
Operations and maintenance
|
693
|
|
|
705
|
|
|
717
|
|
|||
Depreciation and amortization
|
479
|
|
|
407
|
|
|
351
|
|
|||
Property and other taxes
|
112
|
|
|
110
|
|
|
108
|
|
|||
Total operating costs and expenses
|
2,060
|
|
|
2,053
|
|
|
2,428
|
|
|||
|
|
|
|
|
|
||||||
Operating income
|
565
|
|
|
449
|
|
|
394
|
|
|||
|
|
|
|
|
|
||||||
Other income and (expense):
|
|
|
|
|
|
||||||
Interest expense
|
(196
|
)
|
|
(183
|
)
|
|
(174
|
)
|
|||
Allowance for borrowed funds
|
8
|
|
|
8
|
|
|
16
|
|
|||
Allowance for equity funds
|
19
|
|
|
20
|
|
|
39
|
|
|||
Other, net
|
14
|
|
|
5
|
|
|
10
|
|
|||
Total other income and (expense)
|
(155
|
)
|
|
(150
|
)
|
|
(109
|
)
|
|||
|
|
|
|
|
|
||||||
Income before income tax benefit
|
410
|
|
|
299
|
|
|
285
|
|
|||
Income tax benefit
|
(132
|
)
|
|
(147
|
)
|
|
(116
|
)
|
|||
|
|
|
|
|
|
||||||
Income from continuing operations
|
542
|
|
|
446
|
|
|
401
|
|
|||
|
|
|
|
|
|
||||||
Discontinued operations (Note 3):
|
|
|
|
|
|
||||||
Income from discontinued operations
|
—
|
|
|
22
|
|
|
28
|
|
|||
Income tax expense
|
—
|
|
|
6
|
|
|
12
|
|
|||
Income on discontinued operations
|
—
|
|
|
16
|
|
|
16
|
|
|||
|
|
|
|
|
|
||||||
Net income
|
$
|
542
|
|
|
$
|
462
|
|
|
$
|
417
|
|
|
Years Ended December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Net income
|
$
|
542
|
|
|
$
|
462
|
|
|
$
|
417
|
|
|
|
|
|
|
|
||||||
Other comprehensive income (loss), net of tax:
|
|
|
|
|
|
||||||
Unrealized gains on available-for-sale securities, net of tax of $1, $- and $1
|
3
|
|
|
—
|
|
|
1
|
|
|||
Unrealized losses on cash flow hedges, net of tax of $-, $(4) and $(10)
|
—
|
|
|
(7
|
)
|
|
(13
|
)
|
|||
Total other comprehensive income (loss), net of tax
|
3
|
|
|
(7
|
)
|
|
(12
|
)
|
|||
|
|
|
|
|
|
||||||
Comprehensive income
|
$
|
545
|
|
|
$
|
455
|
|
|
$
|
405
|
|
|
|
|
|
|
Accumulated
|
|
|
||||||||
|
|
|
|
|
Other
|
|
|
||||||||
|
Common
|
|
Retained
|
|
Comprehensive
|
|
Total
|
||||||||
|
Stock
|
|
Earnings
|
|
Loss, Net
|
|
Equity
|
||||||||
|
|
|
|
|
|
|
|
||||||||
Balance, December 31, 2013
|
$
|
561
|
|
|
$
|
3,295
|
|
|
$
|
(11
|
)
|
|
$
|
3,845
|
|
Net income
|
—
|
|
|
417
|
|
|
—
|
|
|
417
|
|
||||
Other comprehensive income
|
—
|
|
|
—
|
|
|
(12
|
)
|
|
(12
|
)
|
||||
Balance, December 31, 2014
|
561
|
|
|
3,712
|
|
|
(23
|
)
|
|
4,250
|
|
||||
Net income
|
—
|
|
|
462
|
|
|
—
|
|
|
462
|
|
||||
Other comprehensive loss
|
—
|
|
|
—
|
|
|
(7
|
)
|
|
(7
|
)
|
||||
Balance, December 31, 2015
|
561
|
|
|
4,174
|
|
|
(30
|
)
|
|
4,705
|
|
||||
Net income
|
—
|
|
|
542
|
|
|
—
|
|
|
542
|
|
||||
Other comprehensive loss
|
—
|
|
|
—
|
|
|
3
|
|
|
3
|
|
||||
Dividend (Note 3)
|
—
|
|
|
(117
|
)
|
|
27
|
|
|
(90
|
)
|
||||
Balance, December 31, 2016
|
$
|
561
|
|
|
$
|
4,599
|
|
|
$
|
—
|
|
|
$
|
5,160
|
|
|
Years Ended December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
Cash flows from operating activities:
|
|
|
|
|
|
||||||
Net income
|
$
|
542
|
|
|
$
|
462
|
|
|
$
|
417
|
|
Adjustments to reconcile net income to net cash flows from operating activities:
|
|
|
|
|
|
||||||
Depreciation and amortization
|
479
|
|
|
407
|
|
|
351
|
|
|||
Deferred income taxes and amortization of investment tax credits
|
361
|
|
|
275
|
|
|
300
|
|
|||
Changes in other assets and liabilities
|
47
|
|
|
49
|
|
|
47
|
|
|||
Other, net
|
(91
|
)
|
|
(58
|
)
|
|
(57
|
)
|
|||
Changes in other operating assets and liabilities:
|
|
|
|
|
|
||||||
Receivables, net
|
(61
|
)
|
|
91
|
|
|
(3
|
)
|
|||
Inventories
|
(27
|
)
|
|
(53
|
)
|
|
44
|
|
|||
Derivative collateral, net
|
5
|
|
|
33
|
|
|
(53
|
)
|
|||
Contributions to pension and other postretirement benefit plans, net
|
(6
|
)
|
|
(8
|
)
|
|
(2
|
)
|
|||
Accounts payable
|
39
|
|
|
(76
|
)
|
|
30
|
|
|||
Accrued property, income and other taxes, net
|
107
|
|
|
217
|
|
|
(252
|
)
|
|||
Other current assets and liabilities
|
8
|
|
|
12
|
|
|
1
|
|
|||
Net cash flows from operating activities
|
1,403
|
|
|
1,351
|
|
|
823
|
|
|||
|
|
|
|
|
|
||||||
Cash flows from investing activities:
|
|
|
|
|
|
||||||
Utility construction expenditures
|
(1,636
|
)
|
|
(1,446
|
)
|
|
(1,526
|
)
|
|||
Purchases of available-for-sale securities
|
(138
|
)
|
|
(142
|
)
|
|
(88
|
)
|
|||
Proceeds from sales of available-for-sale securities
|
158
|
|
|
135
|
|
|
80
|
|
|||
Proceeds from sales of other investments
|
—
|
|
|
—
|
|
|
8
|
|
|||
Other, net
|
1
|
|
|
3
|
|
|
5
|
|
|||
Net cash flows from investing activities
|
(1,615
|
)
|
|
(1,450
|
)
|
|
(1,521
|
)
|
|||
|
|
|
|
|
|
||||||
Cash flows from financing activities:
|
|
|
|
|
|
||||||
Proceeds from long-term debt
|
62
|
|
|
649
|
|
|
840
|
|
|||
Repayments of long-term debt
|
(38
|
)
|
|
(426
|
)
|
|
(356
|
)
|
|||
Net proceeds from (repayments of) short-term debt
|
99
|
|
|
(50
|
)
|
|
50
|
|
|||
Other, net
|
—
|
|
|
—
|
|
|
(1
|
)
|
|||
Net cash flows from financing activities
|
123
|
|
|
173
|
|
|
533
|
|
|||
|
|
|
|
|
|
||||||
Net change in cash and cash equivalents
|
(89
|
)
|
|
74
|
|
|
(165
|
)
|
|||
Cash and cash equivalents at beginning of year
|
103
|
|
|
29
|
|
|
194
|
|
|||
Cash and cash equivalents at end of year
|
$
|
14
|
|
|
$
|
103
|
|
|
$
|
29
|
|
(
1
)
|
Company Organization
|
(
2
)
|
Summary of Significant Accounting Policies
|
(
3
)
|
Discontinued Operations
|
|
|
2015
|
|
2014
|
||||
|
|
|
|
|
||||
Operating revenue
|
|
$
|
905
|
|
|
$
|
918
|
|
Cost of sales
|
|
$
|
854
|
|
|
$
|
863
|
|
|
|
|
|
|
||||
Cash flows from operating activities
|
|
$
|
30
|
|
|
$
|
(22
|
)
|
Receivables
|
|
$
|
115
|
|
Derivative assets
|
|
41
|
|
|
Deferred income taxes
|
|
21
|
|
|
Accounts payable
|
|
(49
|
)
|
|
Derivative liabilities
|
|
(42
|
)
|
|
Other assets and liabilities, net
|
|
4
|
|
|
Accumulated other comprehensive loss, net
|
|
27
|
|
|
Equity, excluding accumulated other comprehensive loss, net
|
|
(117
|
)
|
|
Depreciable Life
|
|
2016
|
|
2015
|
||||
|
|
|
|
|
|
||||
Utility plant in service:
|
|
|
|
|
|
||||
Generation
|
20-70 years
|
|
$
|
11,282
|
|
|
$
|
10,404
|
|
Transmission
|
52-75 years
|
|
1,726
|
|
|
1,305
|
|
||
Electric distribution
|
20-75 years
|
|
3,197
|
|
|
3,059
|
|
||
Gas distribution
|
28-70 years
|
|
1,565
|
|
|
1,507
|
|
||
Utility plant in service
|
|
|
17,770
|
|
|
16,275
|
|
||
Accumulated depreciation and amortization
|
|
|
(5,448
|
)
|
|
(5,229
|
)
|
||
Utility plant in service, net
|
|
|
12,322
|
|
|
11,046
|
|
||
Nonregulated property, net:
|
|
|
|
|
|
||||
Nonregulated property gross
|
20-50 years
|
|
7
|
|
|
15
|
|
||
Accumulated depreciation and amortization
|
|
|
(1
|
)
|
|
(5
|
)
|
||
Nonregulated property, net
|
|
|
6
|
|
|
10
|
|
||
|
|
|
12,328
|
|
|
11,056
|
|
||
Construction work-in-progress
|
|
|
493
|
|
|
667
|
|
||
Property, plant and equipment, net
|
|
|
$
|
12,821
|
|
|
$
|
11,723
|
|
|
2016
|
|
2015
|
|
2014
|
|||
|
|
|
|
|
|
|||
Electric
|
2.8
|
%
|
|
3.0
|
%
|
|
2.8
|
%
|
Gas
|
2.9
|
%
|
|
2.9
|
%
|
|
2.8
|
%
|
|
|
|
|
|
Accumulated
|
|
Construction
|
|||||||
|
Company
|
|
Plant in
|
|
Depreciation and
|
|
Work-in-
|
|||||||
|
Share
|
|
Service
|
|
Amortization
|
|
Progress
|
|||||||
|
|
|
|
|
|
|
|
|||||||
Louisa Unit No. 1
|
88.0
|
%
|
|
$
|
766
|
|
|
$
|
418
|
|
|
$
|
9
|
|
Quad Cities Unit Nos. 1 & 2
(1)
|
25.0
|
|
|
689
|
|
|
367
|
|
|
7
|
|
|||
Walter Scott, Jr. Unit No. 3
|
79.1
|
|
|
614
|
|
|
303
|
|
|
1
|
|
|||
Walter Scott, Jr. Unit No. 4
(2)
|
59.7
|
|
|
448
|
|
|
101
|
|
|
2
|
|
|||
George Neal Unit No. 4
|
40.6
|
|
|
307
|
|
|
154
|
|
|
1
|
|
|||
Ottumwa Unit No. 1
|
52.0
|
|
|
548
|
|
|
191
|
|
|
13
|
|
|||
George Neal Unit No. 3
|
72.0
|
|
|
426
|
|
|
174
|
|
|
1
|
|
|||
Transmission facilities
(3)
|
Various
|
|
|
247
|
|
|
86
|
|
|
1
|
|
|||
Total
|
|
|
$
|
4,045
|
|
|
$
|
1,794
|
|
|
$
|
35
|
|
(1)
|
Includes amounts related to nuclear fuel.
|
(2)
|
Plant in service and accumulated depreciation and amortization amounts are net of credits applied under Iowa revenue sharing arrangements totaling
$319 million
and
$75 million
, respectively.
|
(3)
|
Includes
345
and
161
kilovolt transmission lines and substations.
|
(
6
)
|
Regulatory Matters
|
|
Average
|
|
|
|
|
||||
|
Remaining Life
|
|
2016
|
|
2015
|
||||
|
|
|
|
|
|
||||
Deferred income taxes, net
(1)
|
29 years
|
|
$
|
985
|
|
|
$
|
858
|
|
Asset retirement obligations
(2)
|
9 years
|
|
105
|
|
|
94
|
|
||
Employee benefit plans
(3)
|
11 years
|
|
40
|
|
|
39
|
|
||
Unrealized loss on regulated derivative contracts
|
1 year
|
|
2
|
|
|
20
|
|
||
Other
|
Various
|
|
29
|
|
|
33
|
|
||
Total
|
|
|
$
|
1,161
|
|
|
$
|
1,044
|
|
(1)
|
Amounts primarily represent income tax benefits related to state accelerated tax depreciation and certain property-related basis differences that were previously flowed through to customers and will be included in regulated rates when the temporary differences reverse.
|
(2)
|
Amount predominantly relates to asset retirement obligations for fossil-fueled and wind-powered generating facilities. Refer to Note
12
for a discussion of asset retirement obligations.
|
(3)
|
Represents amounts not yet recognized as a component of net periodic benefit cost that are expected to be included in regulated rates when recognized.
|
|
Average
|
|
|
|
|
||||
|
Remaining Life
|
|
2016
|
|
2015
|
||||
|
|
|
|
|
|
||||
Cost of removal accrual
(1)
|
29 years
|
|
$
|
665
|
|
|
$
|
653
|
|
Asset retirement obligations
(2)
|
36 years
|
|
117
|
|
|
140
|
|
||
Pre-funded AFUDC on transmission MVPs
(3)
|
56 years
|
|
35
|
|
|
19
|
|
||
Iowa electric revenue sharing accrual
(4)
|
1 year
|
|
30
|
|
|
—
|
|
||
Employee benefit plans
(5)
|
11 years
|
|
12
|
|
|
—
|
|
||
Unrealized gain on regulated derivative contracts
|
1 year
|
|
6
|
|
|
—
|
|
||
Other
|
Various
|
|
18
|
|
|
19
|
|
||
Total
|
|
|
$
|
883
|
|
|
$
|
831
|
|
(1)
|
Amounts represent estimated costs, as accrued through depreciation rates and exclusive of ARO liabilities, of removing utility plant in accordance with accepted regulatory practices. Amounts are deducted from rate base or otherwise accrue a carrying cost.
|
(2)
|
Amount predominantly represents the excess of nuclear decommission trust assets over the related asset retirement obligation. Refer to Note
12
for a discussion of asset retirement obligations.
|
(3)
|
Represents AFUDC accrued on transmission MVPs that is deducted from rate base as a result of the inclusion of related construction work-in-progress in rate base.
|
(4)
|
Represents current-year accruals under a regulatory arrangement in Iowa in which equity returns exceeding specified thresholds reduce utility plant upon final determination.
|
(5)
|
Represents amounts not yet recognized as a component of net periodic benefit cost that are to be returned to customers in future periods when recognized.
|
(
7
)
|
Investments and Restricted Cash and Investments
|
|
2016
|
|
2015
|
||||
|
|
|
|
||||
Nuclear decommissioning trust
|
$
|
460
|
|
|
$
|
429
|
|
Rabbi trusts
|
184
|
|
|
175
|
|
||
Auction rate securities
|
—
|
|
|
26
|
|
||
Other
|
9
|
|
|
4
|
|
||
Total
|
$
|
653
|
|
|
$
|
634
|
|
|
2016
|
|
2015
|
||||
|
|
|
|
||||
Credit facilities
|
$
|
605
|
|
|
$
|
605
|
|
Less:
|
|
|
|
||||
Short-term debt outstanding
|
(99
|
)
|
|
—
|
|
||
Variable-rate tax-exempt bond support
|
(220
|
)
|
|
(195
|
)
|
||
Net credit facilities
|
$
|
286
|
|
|
$
|
410
|
|
(
9
)
|
Long-Term Debt
|
|
Par Value
|
|
2016
|
|
2015
|
||||||
|
|
|
|
|
|
||||||
First mortgage bonds:
|
|
|
|
|
|
||||||
2.40%, due 2019
|
$
|
500
|
|
|
$
|
499
|
|
|
$
|
499
|
|
3.70%, due 2023
|
250
|
|
|
248
|
|
|
248
|
|
|||
3.50%, due 2024
|
500
|
|
|
501
|
|
|
502
|
|
|||
4.80%, due 2043
|
350
|
|
|
345
|
|
|
345
|
|
|||
4.40%, due 2044
|
400
|
|
|
394
|
|
|
394
|
|
|||
4.25%, due 2046
|
450
|
|
|
445
|
|
|
444
|
|
|||
Notes:
|
|
|
|
|
|
||||||
5.95% Series, due 2017
|
250
|
|
|
250
|
|
|
250
|
|
|||
5.3% Series, due 2018
|
350
|
|
|
350
|
|
|
349
|
|
|||
6.75% Series, due 2031
|
400
|
|
|
396
|
|
|
395
|
|
|||
5.75% Series, due 2035
|
300
|
|
|
298
|
|
|
298
|
|
|||
5.8% Series, due 2036
|
350
|
|
|
347
|
|
|
347
|
|
|||
Transmission upgrade obligation, 4.45% and 3.42% due through 2035 and 2036, respectively
|
10
|
|
|
7
|
|
|
4
|
|
|||
Variable-rate tax-exempt bond obligation series: (weighted average interest rate- 2016-0.76%, 2015-0.03%):
|
|
|
|
|
|
||||||
Due 2016
|
—
|
|
|
—
|
|
|
33
|
|
|||
Due 2017
|
—
|
|
|
—
|
|
|
4
|
|
|||
Due 2023, issued in 1993
|
7
|
|
|
7
|
|
|
7
|
|
|||
Due 2023, issued in 2008
|
57
|
|
|
57
|
|
|
57
|
|
|||
Due 2024
|
35
|
|
|
35
|
|
|
35
|
|
|||
Due 2025
|
13
|
|
|
13
|
|
|
13
|
|
|||
Due 2036
|
33
|
|
|
33
|
|
|
—
|
|
|||
Due 2038
|
45
|
|
|
45
|
|
|
45
|
|
|||
Due 2046
|
30
|
|
|
29
|
|
|
—
|
|
|||
Capital lease obligations - 4.16%, due through 2020
|
2
|
|
|
2
|
|
|
2
|
|
|||
Total
|
$
|
4,332
|
|
|
$
|
4,301
|
|
|
$
|
4,271
|
|
2017
|
|
$
|
251
|
|
2018
|
|
351
|
|
|
2019
|
|
500
|
|
|
2020
|
|
2
|
|
|
2021
|
|
1
|
|
|
2022 and thereafter
|
|
3,227
|
|
(
10
)
|
Income Taxes
|
|
2016
|
|
2015
|
|
2014
|
||||||
Current:
|
|
|
|
|
|
||||||
Federal
|
$
|
(479
|
)
|
|
$
|
(415
|
)
|
|
$
|
(411
|
)
|
State
|
(14
|
)
|
|
(6
|
)
|
|
(4
|
)
|
|||
|
(493
|
)
|
|
(421
|
)
|
|
(415
|
)
|
|||
Deferred:
|
|
|
|
|
|
||||||
Federal
|
366
|
|
|
281
|
|
|
298
|
|
|||
State
|
(4
|
)
|
|
(6
|
)
|
|
2
|
|
|||
|
362
|
|
|
275
|
|
|
300
|
|
|||
|
|
|
|
|
|
||||||
Investment tax credits
|
(1
|
)
|
|
(1
|
)
|
|
(1
|
)
|
|||
Total
|
$
|
(132
|
)
|
|
$
|
(147
|
)
|
|
$
|
(116
|
)
|
|
2016
|
|
2015
|
||||
Deferred income tax assets:
|
|
|
|
||||
Regulatory liabilities
|
$
|
333
|
|
|
$
|
327
|
|
Asset retirement obligations
|
230
|
|
|
214
|
|
||
Employee benefits
|
66
|
|
|
66
|
|
||
Other
|
74
|
|
|
88
|
|
||
Total deferred income tax assets
|
703
|
|
|
695
|
|
||
|
|
|
|
||||
Deferred income tax liabilities:
|
|
|
|
||||
Depreciable property
|
(3,763
|
)
|
|
(3,321
|
)
|
||
Regulatory assets
|
(471
|
)
|
|
(418
|
)
|
||
Other
|
(41
|
)
|
|
(17
|
)
|
||
Total deferred income tax liabilities
|
(4,275
|
)
|
|
(3,756
|
)
|
||
|
|
|
|
||||
Net deferred income tax liability
|
$
|
(3,572
|
)
|
|
$
|
(3,061
|
)
|
|
2016
|
|
2015
|
||||
|
|
|
|
||||
Beginning balance
|
$
|
10
|
|
|
$
|
26
|
|
Additions based on tax positions related to the current year
|
—
|
|
|
3
|
|
||
Additions for tax positions of prior years
|
10
|
|
|
47
|
|
||
Reductions based on tax positions related to the current year
|
(2
|
)
|
|
(6
|
)
|
||
Reductions for tax positions of prior years
|
(8
|
)
|
|
(46
|
)
|
||
Statute of limitations
|
—
|
|
|
(5
|
)
|
||
Settlements
|
—
|
|
|
(6
|
)
|
||
Interest and penalties
|
—
|
|
|
(3
|
)
|
||
Ending balance
|
$
|
10
|
|
|
$
|
10
|
|
(
11
)
|
Employee Benefit Plans
|
|
Pension
|
|
Other Postretirement
|
||||||||||||||||||||
|
2016
|
|
2015
|
|
2014
|
|
2016
|
|
2015
|
|
2014
|
||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Service cost
|
$
|
10
|
|
|
$
|
12
|
|
|
$
|
14
|
|
|
$
|
5
|
|
|
$
|
7
|
|
|
$
|
6
|
|
Interest cost
|
34
|
|
|
32
|
|
|
35
|
|
|
10
|
|
|
9
|
|
|
10
|
|
||||||
Expected return on plan assets
|
(44
|
)
|
|
(46
|
)
|
|
(45
|
)
|
|
(13
|
)
|
|
(15
|
)
|
|
(15
|
)
|
||||||
Net amortization
|
2
|
|
|
2
|
|
|
1
|
|
|
(4
|
)
|
|
(3
|
)
|
|
(3
|
)
|
||||||
Net periodic benefit cost (credit)
|
$
|
2
|
|
|
$
|
—
|
|
|
$
|
5
|
|
|
$
|
(2
|
)
|
|
$
|
(2
|
)
|
|
$
|
(2
|
)
|
|
Pension
|
|
Other Postretirement
|
||||||||||||
|
2016
|
|
2015
|
|
2016
|
|
2015
|
||||||||
|
|
|
|
|
|
|
|
||||||||
Plan assets at fair value, beginning of year
|
$
|
678
|
|
|
$
|
730
|
|
|
$
|
249
|
|
|
$
|
259
|
|
Employer contributions
|
7
|
|
|
7
|
|
|
1
|
|
|
1
|
|
||||
Participant contributions
|
—
|
|
|
—
|
|
|
1
|
|
|
1
|
|
||||
Actual return on plan assets
|
57
|
|
|
4
|
|
|
14
|
|
|
—
|
|
||||
Benefits paid
|
(58
|
)
|
|
(63
|
)
|
|
(13
|
)
|
|
(12
|
)
|
||||
Plan assets at fair value, end of year
|
$
|
684
|
|
|
$
|
678
|
|
|
$
|
252
|
|
|
$
|
249
|
|
|
Pension
|
|
Other Postretirement
|
||||||||||||
|
2016
|
|
2015
|
|
2016
|
|
2015
|
||||||||
|
|
|
|
|
|
|
|
||||||||
Benefit obligation, beginning of year
|
$
|
785
|
|
|
$
|
840
|
|
|
$
|
234
|
|
|
$
|
249
|
|
Service cost
|
10
|
|
|
12
|
|
|
5
|
|
|
7
|
|
||||
Interest cost
|
34
|
|
|
32
|
|
|
10
|
|
|
9
|
|
||||
Participant contributions
|
—
|
|
|
—
|
|
|
1
|
|
|
1
|
|
||||
Actuarial loss (gain)
|
2
|
|
|
(36
|
)
|
|
(4
|
)
|
|
(20
|
)
|
||||
Benefits paid
|
(58
|
)
|
|
(63
|
)
|
|
(13
|
)
|
|
(12
|
)
|
||||
Benefit obligation, end of year
|
$
|
773
|
|
|
$
|
785
|
|
|
$
|
233
|
|
|
$
|
234
|
|
Accumulated benefit obligation, end of year
|
$
|
764
|
|
|
$
|
773
|
|
|
|
|
|
|
Pension
|
|
Other Postretirement
|
||||||||||||
|
2016
|
|
2015
|
|
2016
|
|
2015
|
||||||||
|
|
|
|
|
|
|
|
||||||||
Plan assets at fair value, end of year
|
$
|
684
|
|
|
$
|
678
|
|
|
$
|
252
|
|
|
$
|
249
|
|
Less - Benefit obligation, end of year
|
773
|
|
|
785
|
|
|
233
|
|
|
234
|
|
||||
Funded status
|
$
|
(89
|
)
|
|
$
|
(107
|
)
|
|
$
|
19
|
|
|
$
|
15
|
|
|
|
|
|
|
|
|
|
||||||||
Amounts recognized on the Balance Sheets:
|
|
|
|
|
|
|
|
||||||||
Other assets
|
$
|
26
|
|
|
$
|
7
|
|
|
$
|
19
|
|
|
$
|
15
|
|
Other current liabilities
|
(8
|
)
|
|
(8
|
)
|
|
—
|
|
|
—
|
|
||||
Other liabilities
|
(107
|
)
|
|
(106
|
)
|
|
—
|
|
|
—
|
|
||||
Amounts recognized
|
$
|
(89
|
)
|
|
$
|
(107
|
)
|
|
$
|
19
|
|
|
$
|
15
|
|
|
Pension
|
|
Other Postretirement
|
||||||||||||
|
2016
|
|
2015
|
|
2016
|
|
2015
|
||||||||
|
|
|
|
|
|
|
|
||||||||
Net loss
|
$
|
15
|
|
|
$
|
26
|
|
|
$
|
36
|
|
|
$
|
42
|
|
Prior service cost (credit)
|
1
|
|
|
2
|
|
|
(31
|
)
|
|
(36
|
)
|
||||
Total
|
$
|
16
|
|
|
$
|
28
|
|
|
$
|
5
|
|
|
$
|
6
|
|
|
Regulatory
Asset
|
|
Regulatory
Liability
|
|
Receivables
(Payables)
with Affiliates
|
|
Total
|
||||||||
Pension
|
|
|
|
|
|
|
|
||||||||
Balance, December 31, 2014
|
$
|
22
|
|
|
$
|
(5
|
)
|
|
$
|
7
|
|
|
$
|
24
|
|
Net loss (gain) arising during the year
|
2
|
|
|
5
|
|
|
(1
|
)
|
|
6
|
|
||||
Net amortization
|
(2
|
)
|
|
—
|
|
|
—
|
|
|
(2
|
)
|
||||
Total
|
—
|
|
|
5
|
|
|
(1
|
)
|
|
4
|
|
||||
Balance, December 31, 2015
|
22
|
|
|
—
|
|
|
6
|
|
|
28
|
|
||||
Net gain arising during the year
|
1
|
|
|
(11
|
)
|
|
—
|
|
|
(10
|
)
|
||||
Net amortization
|
(1
|
)
|
|
(1
|
)
|
|
—
|
|
|
(2
|
)
|
||||
Total
|
—
|
|
|
(12
|
)
|
|
—
|
|
|
(12
|
)
|
||||
Balance, December 31, 2016
|
$
|
22
|
|
|
$
|
(12
|
)
|
|
$
|
6
|
|
|
$
|
16
|
|
|
Regulatory
Asset
|
|
Regulatory
Liability
|
|
Receivables
(Payables)
with Affiliates
|
|
Total
|
||||||||
Other Postretirement
|
|
|
|
|
|
|
|
||||||||
Balance, December 31, 2014
|
$
|
20
|
|
|
$
|
—
|
|
|
$
|
(13
|
)
|
|
$
|
7
|
|
Net gain arising during the year
|
(5
|
)
|
|
—
|
|
|
—
|
|
|
(5
|
)
|
||||
Net amortization
|
2
|
|
|
—
|
|
|
2
|
|
|
4
|
|
||||
Total
|
(3
|
)
|
|
—
|
|
|
2
|
|
|
(1
|
)
|
||||
Balance, December 31, 2015
|
17
|
|
|
—
|
|
|
(11
|
)
|
|
6
|
|
||||
Net gain arising during the year
|
(2
|
)
|
|
—
|
|
|
(3
|
)
|
|
(5
|
)
|
||||
Net amortization
|
3
|
|
|
—
|
|
|
1
|
|
|
4
|
|
||||
Total
|
1
|
|
|
—
|
|
|
(2
|
)
|
|
(1
|
)
|
||||
Balance, December 31, 2016
|
$
|
18
|
|
|
$
|
—
|
|
|
$
|
(13
|
)
|
|
$
|
5
|
|
|
Net
Loss
|
|
Prior
Service
Cost (Credit)
|
|
Total
|
||||||
|
|
|
|
|
|
||||||
Pension
|
$
|
1
|
|
|
$
|
1
|
|
|
$
|
2
|
|
Other postretirement
|
2
|
|
|
(6
|
)
|
|
(4
|
)
|
|||
Total
|
$
|
3
|
|
|
$
|
(5
|
)
|
|
$
|
(2
|
)
|
|
Pension
|
|
Other Postretirement
|
||||||||||||||
|
2016
|
|
2015
|
|
2014
|
|
2016
|
|
2015
|
|
2014
|
||||||
Benefit obligations as of December 31:
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Discount rate
|
4.10
|
%
|
|
4.50
|
%
|
|
4.00
|
%
|
|
3.90
|
%
|
|
4.25
|
%
|
|
3.75
|
%
|
Rate of compensation increase
|
2.75
|
%
|
|
2.75
|
%
|
|
2.75
|
%
|
|
N/A
|
|
|
N/A
|
|
|
N/A
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Net periodic benefit cost for the years ended December 31:
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Discount rate
|
4.50
|
%
|
|
4.00
|
%
|
|
4.75
|
%
|
|
4.25
|
%
|
|
3.75
|
%
|
|
4.50
|
%
|
Expected return on plan assets
(1)
|
7.00
|
%
|
|
7.25
|
%
|
|
7.50
|
%
|
|
6.75
|
%
|
|
7.00
|
%
|
|
7.25
|
%
|
Rate of compensation increase
|
2.75
|
%
|
|
2.75
|
%
|
|
3.00
|
%
|
|
N/A
|
|
|
N/A
|
|
|
N/A
|
|
(1)
|
Amounts reflected are pre-tax values. Assumed after-tax returns for a taxable, non-union other postretirement plan were 5.00% for
2016
, and 5.18% for
2015
, and 5.37% for
2014
.
|
|
2016
|
|
2015
|
||
Assumed healthcare cost trend rates as of December 31:
|
|
|
|
||
Healthcare cost trend rate assumed for next year
|
7.40
|
%
|
|
7.70
|
%
|
Rate that the cost trend rate gradually declines to
|
5.00
|
%
|
|
5.00
|
%
|
Year that the rate reaches the rate it is assumed to remain at
|
2025
|
|
2025
|
|
One Percentage-Point
|
||||||
|
Increase
|
|
Decrease
|
||||
Increase (decrease) in:
|
|
||||||
Total service and interest cost for the year ended December 31, 2016
|
$
|
—
|
|
|
$
|
—
|
|
Other postretirement benefit obligation as of December 31, 2016
|
3
|
|
|
(2
|
)
|
|
Projected Benefit Payments
|
||||||
|
Pension
|
|
Other Postretirement
|
||||
|
|
|
|
||||
2017
|
$
|
60
|
|
|
$
|
18
|
|
2018
|
60
|
|
|
19
|
|
||
2019
|
62
|
|
|
20
|
|
||
2020
|
62
|
|
|
21
|
|
||
2021
|
60
|
|
|
21
|
|
||
2022-2026
|
278
|
|
|
97
|
|
|
Pension
|
|
Other
Postretirement
|
|
%
|
|
%
|
Debt securities
(1)
|
20-40
|
|
25-45
|
Equity securities
(1)
|
60-80
|
|
50-80
|
Real estate funds
|
2-8
|
|
—
|
Other
|
0-5
|
|
0-5
|
(1)
|
For purposes of target allocation percentages and consistent with the plans' investment policy, investment funds are allocated based on the underlying investments in debt and equity securities.
|
|
Input Levels for Fair Value Measurements
(1)
|
|
|
||||||||||||
|
Level 1
|
|
Level 2
|
|
Level 3
|
|
Total
|
||||||||
As of December 31, 2016:
|
|
|
|
|
|
|
|
||||||||
Cash equivalents
|
$
|
—
|
|
|
$
|
17
|
|
|
$
|
—
|
|
|
$
|
17
|
|
Debt securities:
|
|
|
|
|
|
|
|
||||||||
United States government obligations
|
9
|
|
|
—
|
|
|
—
|
|
|
9
|
|
||||
Corporate obligations
|
—
|
|
|
53
|
|
|
—
|
|
|
53
|
|
||||
Municipal obligations
|
—
|
|
|
6
|
|
|
—
|
|
|
6
|
|
||||
Agency, asset and mortgage-backed obligations
|
—
|
|
|
22
|
|
|
—
|
|
|
22
|
|
||||
Equity securities:
|
|
|
|
|
|
|
|
||||||||
United States companies
|
130
|
|
|
—
|
|
|
—
|
|
|
130
|
|
||||
International equity securities
|
39
|
|
|
—
|
|
|
—
|
|
|
39
|
|
||||
Investment funds
(2)
|
63
|
|
|
—
|
|
|
—
|
|
|
63
|
|
||||
Total assets in the hierarchy
|
$
|
241
|
|
|
$
|
98
|
|
|
$
|
—
|
|
|
339
|
|
|
Investment funds
(2)
measured at net asset value
|
|
|
|
|
|
|
295
|
|
|||||||
Real estate funds measured at net asset value
|
|
|
|
|
|
|
50
|
|
|||||||
Total assets measured at fair value
|
|
|
|
|
|
|
$
|
684
|
|
||||||
|
|
|
|
|
|
|
|
||||||||
As of December 31, 2015:
|
|
|
|
|
|
|
|
||||||||
Cash equivalents
|
$
|
—
|
|
|
$
|
16
|
|
|
$
|
—
|
|
|
$
|
16
|
|
Debt securities:
|
|
|
|
|
|
|
|
||||||||
United States government obligations
|
5
|
|
|
—
|
|
|
—
|
|
|
5
|
|
||||
Corporate obligations
|
—
|
|
|
57
|
|
|
—
|
|
|
57
|
|
||||
Municipal obligations
|
—
|
|
|
6
|
|
|
—
|
|
|
6
|
|
||||
Agency, asset and mortgage-backed obligations
|
—
|
|
|
27
|
|
|
—
|
|
|
27
|
|
||||
Equity securities:
|
|
|
|
|
|
|
|
||||||||
United States companies
|
130
|
|
|
—
|
|
|
—
|
|
|
130
|
|
||||
International equity securities
|
40
|
|
|
—
|
|
|
—
|
|
|
40
|
|
||||
Investment funds
(2)
|
61
|
|
|
—
|
|
|
—
|
|
|
61
|
|
||||
Total assets in the hierarchy
|
$
|
236
|
|
|
$
|
106
|
|
|
$
|
—
|
|
|
342
|
|
|
Investment funds
(2)
measured at net asset value
|
|
|
|
|
|
|
296
|
|
|||||||
Real estate funds measured at net asset value
|
|
|
|
|
|
|
40
|
|
|||||||
Total assets measured at fair value
|
|
|
|
|
|
|
$
|
678
|
|
(1)
|
Refer to Note
14
for additional discussion regarding the three levels of the fair value hierarchy.
|
(2)
|
Investment funds are comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately
74%
and
26%
, respectively, for
2016
and
72%
and
28%
, respectively, for
2015
.
Additionally, these funds are invested in United States and international securities of approximately
71%
and
29%
, respectively, for
2016
and
73%
and
27%
, respectively, for
2015
.
|
|
Input Levels for Fair Value Measurements
(1)
|
|
|
||||||||||||
|
Level 1
|
|
Level 2
|
|
Level 3
|
|
Total
|
||||||||
As of December 31, 2016:
|
|
|
|
|
|
|
|
||||||||
Cash equivalents
|
$
|
10
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
10
|
|
Debt securities:
|
|
|
|
|
|
|
|
||||||||
United States government obligations
|
5
|
|
|
—
|
|
|
—
|
|
|
5
|
|
||||
Corporate obligations
|
—
|
|
|
11
|
|
|
—
|
|
|
11
|
|
||||
Municipal obligations
|
—
|
|
|
37
|
|
|
—
|
|
|
37
|
|
||||
Agency, asset and mortgage-backed obligations
|
—
|
|
|
11
|
|
|
—
|
|
|
11
|
|
||||
Equity securities:
|
|
|
|
|
|
|
|
||||||||
United States companies
|
122
|
|
|
—
|
|
|
—
|
|
|
122
|
|
||||
Investment funds
(2)
|
56
|
|
|
—
|
|
|
—
|
|
|
56
|
|
||||
Total assets measured at fair value
|
$
|
193
|
|
|
$
|
59
|
|
|
$
|
—
|
|
|
$
|
252
|
|
|
|
|
|
|
|
|
|
||||||||
As of December 31, 2015:
|
|
|
|
|
|
|
|
||||||||
Cash equivalents
|
$
|
5
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
5
|
|
Debt securities:
|
|
|
|
|
|
|
|
||||||||
United States government obligations
|
5
|
|
|
—
|
|
|
—
|
|
|
5
|
|
||||
Corporate obligations
|
—
|
|
|
12
|
|
|
—
|
|
|
12
|
|
||||
Municipal obligations
|
—
|
|
|
39
|
|
|
—
|
|
|
39
|
|
||||
Agency, asset and mortgage-backed obligations
|
—
|
|
|
12
|
|
|
—
|
|
|
12
|
|
||||
Equity securities:
|
|
|
|
|
|
|
|
||||||||
United States companies
|
120
|
|
|
—
|
|
|
—
|
|
|
120
|
|
||||
Investment funds
(2)
|
56
|
|
|
—
|
|
|
—
|
|
|
56
|
|
||||
Total assets measured at fair value
|
$
|
186
|
|
|
$
|
63
|
|
|
$
|
—
|
|
|
$
|
249
|
|
(1)
|
Refer to Note
14
for additional discussion regarding the three levels of the fair value hierarchy.
|
(2)
|
Investment funds are comprised of mutual funds and collective trust funds. These funds consist of equity and debt securities of approximately
70%
and
30%
, respectively, for
2016
and
68%
and
32%
, respectively, for
2015
.
Additionally, these funds are invested in United States and international securities of approximately
30%
and
70%
, respectively, for
2016
and
32%
and
68%
, respectively, for
2015
.
|
(
12
)
|
Asset Retirement Obligations
|
|
2016
|
|
2015
|
||||
|
|
|
|
||||
Quad Cities Station
|
$
|
343
|
|
|
$
|
289
|
|
Fossil-fueled generating facilities
|
132
|
|
|
160
|
|
||
Wind-powered generating facilities
|
91
|
|
|
82
|
|
||
Other
|
1
|
|
|
1
|
|
||
Total asset retirement obligations
|
$
|
567
|
|
|
$
|
532
|
|
|
|
|
|
||||
Quad Cities Station nuclear decommissioning trust funds
(1)
|
$
|
460
|
|
|
$
|
429
|
|
(1)
|
Refer to Note
7
for a discussion of the Quad Cities Station nuclear decommissioning trust funds.
|
|
2016
|
|
2015
|
||||
|
|
|
|
||||
Beginning balance
|
$
|
532
|
|
|
$
|
460
|
|
Change in estimated costs
|
28
|
|
|
36
|
|
||
Additions
|
14
|
|
|
22
|
|
||
Retirements
|
(32
|
)
|
|
(9
|
)
|
||
Accretion
|
25
|
|
|
23
|
|
||
Ending balance
|
$
|
567
|
|
|
$
|
532
|
|
|
|
|
|
||||
Reflected as:
|
|
|
|
||||
Other current liabilities
|
$
|
57
|
|
|
$
|
44
|
|
Asset retirement obligations
|
510
|
|
|
488
|
|
||
|
$
|
567
|
|
|
$
|
532
|
|
|
Other
|
|
|
|
Other
|
|
Other
|
|
|
||||||||||
|
Current
|
|
Other
|
|
Current
|
|
Long-term
|
|
|
||||||||||
|
Assets
|
|
Assets
|
|
Liabilities
|
|
Liabilities
|
|
Total
|
||||||||||
As of December 31, 2016:
|
|
|
|
|
|
|
|
|
|
||||||||||
Not designated as hedging contracts
(1)(2)
:
|
|
|
|
|
|
|
|
|
|
||||||||||
Commodity assets
|
$
|
8
|
|
|
$
|
2
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
10
|
|
Commodity liabilities
|
(2
|
)
|
|
—
|
|
|
(3
|
)
|
|
(1
|
)
|
|
(6
|
)
|
|||||
Total
|
6
|
|
|
2
|
|
|
(3
|
)
|
|
(1
|
)
|
|
4
|
|
|||||
|
|
|
|
|
|
|
|
|
|
||||||||||
Designated as hedging contracts
(2)
:
|
|
|
|
|
|
|
|
|
|
||||||||||
Commodity assets
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|||||
Commodity liabilities
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|||||
Total
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|||||
|
|
|
|
|
|
|
|
|
|
||||||||||
Total derivatives
|
6
|
|
|
2
|
|
|
(3
|
)
|
|
(1
|
)
|
|
4
|
|
|||||
Cash collateral receivable
|
—
|
|
|
—
|
|
|
1
|
|
|
—
|
|
|
1
|
|
|||||
Total derivatives - net basis
|
$
|
6
|
|
|
$
|
2
|
|
|
$
|
(2
|
)
|
|
$
|
(1
|
)
|
|
$
|
5
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
As of December 31, 2015:
|
|
|
|
|
|
|
|
|
|
||||||||||
Not designated as hedging contracts
(1)
:
|
|
|
|
|
|
|
|
|
|
||||||||||
Commodity assets
|
$
|
12
|
|
|
$
|
4
|
|
|
$
|
5
|
|
|
$
|
2
|
|
|
$
|
23
|
|
Commodity liabilities
|
(3
|
)
|
|
—
|
|
|
(36
|
)
|
|
(10
|
)
|
|
(49
|
)
|
|||||
Total
|
9
|
|
|
4
|
|
|
(31
|
)
|
|
(8
|
)
|
|
(26
|
)
|
|||||
|
|
|
|
|
|
|
|
|
|
||||||||||
Designated as hedging contracts:
|
|
|
|
|
|
|
|
|
|
||||||||||
Commodity assets
|
—
|
|
|
—
|
|
|
1
|
|
|
2
|
|
|
3
|
|
|||||
Commodity liabilities
|
—
|
|
|
—
|
|
|
(32
|
)
|
|
(17
|
)
|
|
(49
|
)
|
|||||
Total
|
—
|
|
|
—
|
|
|
(31
|
)
|
|
(15
|
)
|
|
(46
|
)
|
|||||
|
|
|
|
|
|
|
|
|
|
||||||||||
Total derivatives
|
9
|
|
|
4
|
|
|
(62
|
)
|
|
(23
|
)
|
|
(72
|
)
|
|||||
Cash collateral receivable
|
—
|
|
|
—
|
|
|
22
|
|
|
6
|
|
|
28
|
|
|||||
Total derivatives - net basis
|
$
|
9
|
|
|
$
|
4
|
|
|
$
|
(40
|
)
|
|
$
|
(17
|
)
|
|
$
|
(44
|
)
|
(1)
|
MidAmerican Energy's commodity derivatives not designated as hedging contracts are generally included in regulated rates. Accordingly, as of December 31,
2016
, a net regulatory
liability
of
$4 million
was recorded related to the net derivative asset of
$4 million
, and as of December 31,
2015
, a net regulatory
asset
of
$20 million
was recorded related to the net derivative liability of
$26 million
.
|
(2)
|
The changes in derivative values from December 31, 2015, are substantially due to the transfer of MidAmerican Energy's unregulated retail services business to a subsidiary of BHE.
|
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Beginning balance
|
$
|
20
|
|
|
$
|
38
|
|
|
$
|
10
|
|
Changes in fair value recognized in net regulatory assets (liabilities)
|
3
|
|
|
40
|
|
|
61
|
|
|||
Net losses reclassified to operating revenue
|
(15
|
)
|
|
(42
|
)
|
|
(28
|
)
|
|||
Net losses reclassified to cost of fuel, energy and capacity
|
—
|
|
|
(1
|
)
|
|
(1
|
)
|
|||
Net losses reclassified to cost of gas sold
|
(12
|
)
|
|
(15
|
)
|
|
(4
|
)
|
|||
Ending balance
|
$
|
(4
|
)
|
|
$
|
20
|
|
|
$
|
38
|
|
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Nonregulated operating revenue
|
$
|
—
|
|
|
$
|
15
|
|
|
$
|
6
|
|
Regulated cost of fuel, energy and capacity
|
—
|
|
|
2
|
|
|
—
|
|
|||
Nonregulated cost of sales
|
—
|
|
|
(21
|
)
|
|
9
|
|
|||
Total
|
$
|
—
|
|
|
$
|
(4
|
)
|
|
$
|
15
|
|
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Beginning balance
|
$
|
45
|
|
|
$
|
34
|
|
|
$
|
11
|
|
Transfer to affiliate
|
(45
|
)
|
|
—
|
|
|
—
|
|
|||
Changes in fair value recognized in OCI
|
—
|
|
|
58
|
|
|
(3
|
)
|
|||
Net (losses) gains reclassified to nonregulated cost of sales
|
—
|
|
|
(47
|
)
|
|
26
|
|
|||
Ending balance
|
$
|
—
|
|
|
$
|
45
|
|
|
$
|
34
|
|
|
Unit of
|
|
|
|
|
||
|
Measure
|
|
2016
|
|
2015
|
||
|
|
|
|
|
|
||
Electricity purchases
|
Megawatt hours
|
|
—
|
|
|
15
|
|
Natural gas purchases
|
Decatherms
|
|
18
|
|
|
17
|
|
(
14
)
|
Fair Value Measurements
|
•
|
Level 1 - Inputs are unadjusted quoted prices in active markets for identical assets or liabilities that MidAmerican Energy has the ability to access at the measurement date.
|
•
|
Level 2 - Inputs include quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, inputs other than quoted prices that are observable for the asset or liability and inputs that are derived principally from or corroborated by observable market data by correlation or other means (market corroborated inputs).
|
•
|
Level 3 - Unobservable inputs reflect MidAmerican Energy's judgments about the assumptions market participants would use in pricing the asset or liability since limited market data exists. MidAmerican Energy develops these inputs based on the best information available, including its own data.
|
|
|
Input Levels for Fair Value Measurements
|
|
|
|
|
||||||||||||||
|
|
Level 1
|
|
Level 2
|
|
Level 3
|
|
Other
(1)
|
|
Total
|
||||||||||
As of December 31, 2016:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Assets:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Commodity derivatives
|
|
$
|
—
|
|
|
$
|
9
|
|
|
$
|
1
|
|
|
$
|
(2
|
)
|
|
$
|
8
|
|
Money market mutual funds
(2)
|
|
1
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
1
|
|
|||||
Debt securities:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
United States government obligations
|
|
161
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
161
|
|
|||||
International government obligations
|
|
—
|
|
|
3
|
|
|
—
|
|
|
—
|
|
|
3
|
|
|||||
Corporate obligations
|
|
—
|
|
|
36
|
|
|
—
|
|
|
—
|
|
|
36
|
|
|||||
Municipal obligations
|
|
—
|
|
|
2
|
|
|
—
|
|
|
—
|
|
|
2
|
|
|||||
Agency, asset and mortgage-backed obligations
|
|
—
|
|
|
2
|
|
|
—
|
|
|
—
|
|
|
2
|
|
|||||
Equity securities:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
United States companies
|
|
250
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
250
|
|
|||||
International companies
|
|
5
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
5
|
|
|||||
Investment funds
|
|
9
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
9
|
|
|||||
|
|
$
|
426
|
|
|
$
|
52
|
|
|
$
|
1
|
|
|
$
|
(2
|
)
|
|
$
|
477
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Liabilities - commodity derivatives
|
|
$
|
—
|
|
|
$
|
(3
|
)
|
|
$
|
(3
|
)
|
|
$
|
3
|
|
|
$
|
(3
|
)
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
As of December 31, 2015
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Assets:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Commodity derivatives
|
|
$
|
—
|
|
|
$
|
8
|
|
|
$
|
18
|
|
|
$
|
(13
|
)
|
|
$
|
13
|
|
Money market mutual funds
(2)
|
|
56
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
56
|
|
|||||
Debt securities:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
United States government obligations
|
|
133
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
133
|
|
|||||
International government obligations
|
|
—
|
|
|
2
|
|
|
—
|
|
|
—
|
|
|
2
|
|
|||||
Corporate obligations
|
|
—
|
|
|
39
|
|
|
—
|
|
|
—
|
|
|
39
|
|
|||||
Municipal obligations
|
|
—
|
|
|
1
|
|
|
—
|
|
|
—
|
|
|
1
|
|
|||||
Agency, asset and mortgage-backed obligations
|
|
—
|
|
|
3
|
|
|
—
|
|
|
—
|
|
|
3
|
|
|||||
Auction rate securities
|
|
—
|
|
|
—
|
|
|
26
|
|
|
—
|
|
|
26
|
|
|||||
Equity securities:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
United States companies
|
|
239
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
239
|
|
|||||
International companies
|
|
6
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
6
|
|
|||||
Investment funds
|
|
4
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
4
|
|
|||||
|
|
$
|
438
|
|
|
$
|
53
|
|
|
$
|
44
|
|
|
$
|
(13
|
)
|
|
$
|
522
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Liabilities - commodity derivatives
|
|
$
|
(13
|
)
|
|
$
|
(61
|
)
|
|
$
|
(24
|
)
|
|
$
|
41
|
|
|
$
|
(57
|
)
|
(1)
|
Represents netting under master netting arrangements and a net cash collateral receivable of
$1 million
and
$28 million
as of December 31,
2016
and
2015
, respectively.
|
(2)
|
Amounts are included in cash and cash equivalents and investments and restricted cash and investments on the Balance Sheets. The fair value of these money market mutual funds approximates cost.
|
|
|
Commodity Derivatives
|
|
Auction Rate Securities
|
||||||||||||||||||||
|
|
2016
|
|
2015
|
|
2014
|
|
2016
|
|
2015
|
|
2014
|
||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Beginning balance
|
|
$
|
(6
|
)
|
|
$
|
12
|
|
|
$
|
(3
|
)
|
|
$
|
26
|
|
|
$
|
26
|
|
|
$
|
23
|
|
Transfer to affiliate
|
|
(4
|
)
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
||||||
Changes included in earnings
(1)
|
|
—
|
|
|
11
|
|
|
12
|
|
|
5
|
|
|
—
|
|
|
—
|
|
||||||
Changes in fair value recognized in OCI
|
|
—
|
|
|
(7
|
)
|
|
—
|
|
|
4
|
|
|
—
|
|
|
3
|
|
||||||
Changes in fair value recognized in net regulatory assets
|
|
(6
|
)
|
|
(25
|
)
|
|
6
|
|
|
—
|
|
|
—
|
|
|
—
|
|
||||||
Purchases
|
|
—
|
|
|
1
|
|
|
1
|
|
|
—
|
|
|
—
|
|
|
—
|
|
||||||
Redemptions
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(35
|
)
|
|
—
|
|
|
—
|
|
||||||
Settlements
|
|
14
|
|
|
2
|
|
|
(4
|
)
|
|
—
|
|
|
—
|
|
|
—
|
|
||||||
Ending balance
|
|
$
|
(2
|
)
|
|
$
|
(6
|
)
|
|
$
|
12
|
|
|
$
|
—
|
|
|
$
|
26
|
|
|
$
|
26
|
|
(1)
|
Changes included in earnings related to MidAmerican Energy's unregulated retail services business that was transferred to an affiliate of BHE. Refer to Note 3 for a discussion of discontinued operations. Net unrealized (losses) gains included in earnings for the years ended December 31,
2015
and
2014
, related to commodity derivatives held at December 31,
2015
and
2014
, totaled
$8 million
and
$16 million
, respectively.
|
|
2016
|
|
2015
|
||||||||||||
|
Carrying
Value
|
|
Fair Value
|
|
Carrying
Value
|
|
Fair Value
|
||||||||
|
|
|
|
|
|
|
|
||||||||
Long-term debt
|
$
|
4,301
|
|
|
$
|
4,735
|
|
|
$
|
4,271
|
|
|
$
|
4,636
|
|
(
15
)
|
Commitments and Contingencies
|
|
|
|
|
|
|
|
|
|
|
|
|
2022 and
|
|
|
||||||||||||||
|
|
2017
|
|
2018
|
|
2019
|
|
2020
|
|
2021
|
|
Thereafter
|
|
Total
|
||||||||||||||
Contract type:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Coal and natural gas for generation
|
|
$
|
141
|
|
|
$
|
73
|
|
|
$
|
40
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
254
|
|
Electric capacity and transmission
|
|
37
|
|
|
29
|
|
|
29
|
|
|
28
|
|
|
25
|
|
|
59
|
|
|
207
|
|
|||||||
Natural gas contracts for gas operations
|
|
137
|
|
|
34
|
|
|
13
|
|
|
12
|
|
|
10
|
|
|
23
|
|
|
229
|
|
|||||||
Construction commitments
|
|
347
|
|
|
2
|
|
|
5
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
354
|
|
|||||||
Easements and operating leases
|
|
20
|
|
|
20
|
|
|
20
|
|
|
19
|
|
|
19
|
|
|
624
|
|
|
722
|
|
|||||||
Maintenance and services contracts
|
|
72
|
|
|
90
|
|
|
91
|
|
|
92
|
|
|
86
|
|
|
210
|
|
|
641
|
|
|||||||
|
|
$
|
754
|
|
|
$
|
248
|
|
|
$
|
198
|
|
|
$
|
151
|
|
|
$
|
140
|
|
|
$
|
916
|
|
|
$
|
2,407
|
|
(
16
)
|
Components of Accumulated Other Comprehensive Loss, Net
|
|
|
Unrealized
|
|
Unrealized
|
|
Accumulated
|
||||||
|
|
Losses on
|
|
Losses
|
|
Other
|
||||||
|
|
Available-For-Sale
|
|
on Cash Flow
|
|
Comprehensive
|
||||||
|
|
Securities
|
|
Hedges
|
|
Loss, Net
|
||||||
|
|
|
|
|
|
|
||||||
Balance, December 31, 2014
|
|
$
|
(3
|
)
|
|
$
|
(20
|
)
|
|
$
|
(23
|
)
|
Other comprehensive loss
|
|
—
|
|
|
(7
|
)
|
|
(7
|
)
|
|||
Balance, December 31, 2015
|
|
$
|
(3
|
)
|
|
$
|
(27
|
)
|
|
$
|
(30
|
)
|
Other comprehensive income
|
|
3
|
|
|
—
|
|
|
3
|
|
|||
Dividend (Note 3)
|
|
—
|
|
|
27
|
|
|
27
|
|
|||
Balance, December 31, 2016
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Corporate-owned life insurance income
|
$
|
8
|
|
|
$
|
4
|
|
|
$
|
8
|
|
Gain on redemption of auction rate securities
|
5
|
|
|
—
|
|
|
—
|
|
|||
Other, net
|
1
|
|
|
1
|
|
|
2
|
|
|||
Total
|
$
|
14
|
|
|
$
|
5
|
|
|
$
|
10
|
|
|
2016
|
|
2015
|
|
2014
|
||||||
Supplemental cash flow information:
|
|
|
|
|
|
||||||
Interest paid, net of amounts capitalized
|
$
|
181
|
|
|
$
|
154
|
|
|
$
|
144
|
|
Income taxes received, net
|
$
|
601
|
|
|
$
|
629
|
|
|
$
|
149
|
|
|
|
|
|
|
|
||||||
Supplemental disclosure of non-cash investing transactions:
|
|
|
|
|
|
||||||
Accounts payable related to utility plant additions
|
$
|
131
|
|
|
$
|
249
|
|
|
$
|
128
|
|
Dividend of unregulated retail services business (Note 3)
|
$
|
90
|
|
|
$
|
—
|
|
|
$
|
—
|
|
(
19
)
|
Related Party Transactions
|
(
20
)
|
Segment Information
|
|
Years Ended December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
Operating revenue:
|
|
|
|
|
|
||||||
Regulated electric
|
$
|
1,985
|
|
|
$
|
1,837
|
|
|
$
|
1,817
|
|
Regulated gas
|
637
|
|
|
661
|
|
|
996
|
|
|||
Other
|
3
|
|
|
4
|
|
|
9
|
|
|||
Total operating revenue
|
$
|
2,625
|
|
|
$
|
2,502
|
|
|
$
|
2,822
|
|
|
|
|
|
|
|
||||||
Depreciation and amortization:
|
|
|
|
|
|
||||||
Regulated electric
|
$
|
436
|
|
|
$
|
366
|
|
|
$
|
312
|
|
Regulated gas
|
43
|
|
|
41
|
|
|
39
|
|
|||
Total depreciation and amortization
|
$
|
479
|
|
|
$
|
407
|
|
|
$
|
351
|
|
|
|
|
|
|
|
||||||
Operating income:
|
|
|
|
|
|
||||||
Regulated electric
|
$
|
497
|
|
|
$
|
385
|
|
|
$
|
319
|
|
Regulated gas
|
68
|
|
|
64
|
|
|
75
|
|
|||
Total operating income
|
$
|
565
|
|
|
$
|
449
|
|
|
$
|
394
|
|
|
|
|
|
|
|
||||||
Interest expense:
|
|
|
|
|
|
||||||
Regulated electric
|
$
|
178
|
|
|
$
|
166
|
|
|
$
|
157
|
|
Regulated gas
|
18
|
|
|
17
|
|
|
17
|
|
|||
Total interest expense
|
$
|
196
|
|
|
$
|
183
|
|
|
$
|
174
|
|
|
|
|
|
|
|
||||||
Income tax (benefit) expense from continuing operations:
|
|
|
|
|
|
||||||
Regulated electric
|
$
|
(156
|
)
|
|
$
|
(163
|
)
|
|
$
|
(138
|
)
|
Regulated gas
|
22
|
|
|
16
|
|
|
22
|
|
|||
Other
|
2
|
|
|
—
|
|
|
—
|
|
|||
Total income tax (benefit) expense from continuing operations
|
$
|
(132
|
)
|
|
$
|
(147
|
)
|
|
$
|
(116
|
)
|
|
|
|
|
|
|
||||||
Net income:
|
|
|
|
|
|
||||||
Regulated electric
|
$
|
512
|
|
|
$
|
413
|
|
|
$
|
361
|
|
Regulated gas
|
32
|
|
|
33
|
|
|
40
|
|
|||
Other
|
(2
|
)
|
|
—
|
|
|
—
|
|
|||
Income from continuing operations
|
542
|
|
|
446
|
|
|
401
|
|
|||
Income on discontinued operations
|
—
|
|
|
16
|
|
|
16
|
|
|||
Net income
|
$
|
542
|
|
|
$
|
462
|
|
|
$
|
417
|
|
|
Years Ended December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
Utility construction expenditures:
|
|
|
|
|
|
||||||
Regulated electric
|
$
|
1,564
|
|
|
$
|
1,365
|
|
|
$
|
1,429
|
|
Regulated gas
|
72
|
|
|
81
|
|
|
97
|
|
|||
Total utility construction expenditures
|
$
|
1,636
|
|
|
$
|
1,446
|
|
|
$
|
1,526
|
|
|
|
|
|
|
|
||||||
|
As of December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
Total assets:
|
|
|
|
|
|
||||||
Regulated electric
|
$
|
14,113
|
|
|
$
|
12,970
|
|
|
$
|
11,850
|
|
Regulated gas
|
1,345
|
|
|
1,251
|
|
|
1,217
|
|
|||
Other
|
1
|
|
|
164
|
|
|
167
|
|
|||
Total assets
|
$
|
15,459
|
|
|
$
|
14,385
|
|
|
$
|
13,234
|
|
(
21
)
|
Subsequent Events
|
|
2016
|
||||||||||||||
|
1
st
Quarter
|
|
2
nd
Quarter
|
|
3
rd
Quarter
|
|
4
th
Quarter
|
||||||||
|
(In millions)
|
||||||||||||||
Operating revenue
|
$
|
625
|
|
|
$
|
584
|
|
|
$
|
795
|
|
|
$
|
621
|
|
Operating income
|
100
|
|
|
139
|
|
|
284
|
|
|
42
|
|
||||
Net income
|
76
|
|
|
131
|
|
|
320
|
|
|
15
|
|
||||
|
|
|
|
|
|
|
|
||||||||
|
2015
|
||||||||||||||
|
1
st
Quarter
|
|
2
nd
Quarter
|
|
3
rd
Quarter
|
|
4
th
Quarter
|
||||||||
|
(In millions)
|
||||||||||||||
Operating revenue
|
$
|
722
|
|
|
$
|
572
|
|
|
$
|
680
|
|
|
$
|
528
|
|
Operating income
|
100
|
|
|
112
|
|
|
208
|
|
|
29
|
|
||||
Income from continuing operations
|
90
|
|
|
126
|
|
|
233
|
|
|
(3
|
)
|
||||
Income on discontinued operations
|
4
|
|
|
5
|
|
|
1
|
|
|
6
|
|
||||
Net income
|
94
|
|
|
131
|
|
|
234
|
|
|
3
|
|
|
Years Ended December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
Operating revenue:
|
|
|
|
|
|
||||||
Regulated electric
|
$
|
1,985
|
|
|
$
|
1,837
|
|
|
$
|
1,817
|
|
Regulated gas and other
|
646
|
|
|
678
|
|
|
1,027
|
|
|||
Total operating revenue
|
2,631
|
|
|
2,515
|
|
|
2,844
|
|
|||
|
|
|
|
|
|
||||||
Operating costs and expenses:
|
|
|
|
|
|
||||||
Cost of fuel, energy and capacity
|
409
|
|
|
433
|
|
|
532
|
|
|||
Cost of gas sold and other
|
371
|
|
|
407
|
|
|
738
|
|
|||
Operations and maintenance
|
694
|
|
|
707
|
|
|
720
|
|
|||
Depreciation and amortization
|
479
|
|
|
407
|
|
|
351
|
|
|||
Property and other taxes
|
112
|
|
|
110
|
|
|
108
|
|
|||
Total operating costs and expenses
|
2,065
|
|
|
2,064
|
|
|
2,449
|
|
|||
|
|
|
|
|
|
||||||
Operating income
|
566
|
|
|
451
|
|
|
395
|
|
|||
|
|
|
|
|
|
||||||
Other income and (expense):
|
|
|
|
|
|
||||||
Interest expense
|
(219
|
)
|
|
(206
|
)
|
|
(197
|
)
|
|||
Allowance for borrowed funds
|
8
|
|
|
8
|
|
|
16
|
|
|||
Allowance for equity funds
|
19
|
|
|
20
|
|
|
39
|
|
|||
Other, net
|
19
|
|
|
19
|
|
|
18
|
|
|||
Total other income and (expense)
|
(173
|
)
|
|
(159
|
)
|
|
(124
|
)
|
|||
|
|
|
|
|
|
||||||
Income before income tax benefit
|
393
|
|
|
292
|
|
|
271
|
|
|||
Income tax benefit
|
(139
|
)
|
|
(150
|
)
|
|
(122
|
)
|
|||
|
|
|
|
|
|
||||||
Income from continuing operations
|
532
|
|
|
442
|
|
|
393
|
|
|||
|
|
|
|
|
|
||||||
Discontinued operations (Note 3):
|
|
|
|
|
|
||||||
Income from discontinued operations
|
—
|
|
|
22
|
|
|
28
|
|
|||
Income tax expense
|
—
|
|
|
6
|
|
|
12
|
|
|||
Income on discontinued operations
|
—
|
|
|
16
|
|
|
16
|
|
|||
|
|
|
|
|
|
||||||
Net income
|
$
|
532
|
|
|
$
|
458
|
|
|
$
|
409
|
|
|
Years Ended December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Net income
|
$
|
532
|
|
|
$
|
458
|
|
|
$
|
409
|
|
|
|
|
|
|
|
||||||
Other comprehensive income (loss), net of tax:
|
|
|
|
|
|
||||||
Unrealized gains on available-for-sale securities, net of tax of $1, $- and $1
|
3
|
|
|
—
|
|
|
1
|
|
|||
Unrealized losses on cash flow hedges, net of tax of $-, $(4) and $(10)
|
—
|
|
|
(7
|
)
|
|
(13
|
)
|
|||
Total other comprehensive income (loss), net of tax
|
3
|
|
|
(7
|
)
|
|
(12
|
)
|
|||
|
|
|
|
|
|
||||||
Comprehensive income
|
$
|
535
|
|
|
$
|
451
|
|
|
$
|
397
|
|
|
|
|
|
|
Accumulated
|
|
|
||||||||
|
|
|
|
|
Other
|
|
|
||||||||
|
Paid-in
Capital
|
|
Retained
Earnings
|
|
Comprehensive
Loss, Net
|
|
Total Equity
|
||||||||
|
|
|
|
|
|
|
|
||||||||
Balance, December 31, 2013
|
$
|
1,679
|
|
|
$
|
3,009
|
|
|
$
|
(11
|
)
|
|
$
|
4,677
|
|
Net income
|
—
|
|
|
409
|
|
|
—
|
|
|
409
|
|
||||
Other comprehensive loss
|
—
|
|
|
—
|
|
|
(12
|
)
|
|
(12
|
)
|
||||
Other equity transactions
|
—
|
|
|
(1
|
)
|
|
—
|
|
|
(1
|
)
|
||||
Balance, December 31, 2014
|
1,679
|
|
|
3,417
|
|
|
(23
|
)
|
|
5,073
|
|
||||
Net income
|
—
|
|
|
458
|
|
|
—
|
|
|
458
|
|
||||
Other comprehensive loss
|
—
|
|
|
—
|
|
|
(7
|
)
|
|
(7
|
)
|
||||
Other equity transactions
|
—
|
|
|
1
|
|
|
—
|
|
|
1
|
|
||||
Balance, December 31, 2015
|
1,679
|
|
|
3,876
|
|
|
(30
|
)
|
|
5,525
|
|
||||
Net income
|
—
|
|
|
532
|
|
|
—
|
|
|
532
|
|
||||
Other comprehensive income
|
—
|
|
|
—
|
|
|
3
|
|
|
3
|
|
||||
Transfer to affiliate (Note 3)
|
—
|
|
|
—
|
|
|
27
|
|
|
27
|
|
||||
Other equity transactions
|
—
|
|
|
(1
|
)
|
|
—
|
|
|
(1
|
)
|
||||
Balance, December 31, 2016
|
$
|
1,679
|
|
|
$
|
4,407
|
|
|
$
|
—
|
|
|
$
|
6,086
|
|
|
Years Ended December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
Cash flows from operating activities:
|
|
|
|
|
|
||||||
Net income
|
$
|
532
|
|
|
$
|
458
|
|
|
$
|
409
|
|
Adjustments to reconcile net income to net cash flows from operating activities:
|
|
|
|
|
|
||||||
Depreciation and amortization
|
479
|
|
|
407
|
|
|
351
|
|
|||
Deferred income taxes and amortization of investment tax credits
|
362
|
|
|
276
|
|
|
298
|
|
|||
Changes in other assets and liabilities
|
47
|
|
|
49
|
|
|
47
|
|
|||
Other, net
|
(92
|
)
|
|
(69
|
)
|
|
(49
|
)
|
|||
Changes in other operating assets and liabilities:
|
|
|
|
|
|
||||||
Receivables, net
|
(61
|
)
|
|
93
|
|
|
(2
|
)
|
|||
Inventories
|
(27
|
)
|
|
(53
|
)
|
|
44
|
|
|||
Derivative collateral, net
|
5
|
|
|
33
|
|
|
(53
|
)
|
|||
Contributions to pension and other postretirement benefit plans, net
|
(6
|
)
|
|
(8
|
)
|
|
(2
|
)
|
|||
Accounts payable
|
39
|
|
|
(76
|
)
|
|
30
|
|
|||
Accrued property, income and other taxes, net
|
107
|
|
|
213
|
|
|
(253
|
)
|
|||
Other current assets and liabilities
|
8
|
|
|
12
|
|
|
—
|
|
|||
Net cash flows from operating activities
|
1,393
|
|
|
1,335
|
|
|
820
|
|
|||
|
|
|
|
|
|
||||||
Cash flows from investing activities:
|
|
|
|
|
|
||||||
Utility construction expenditures
|
(1,636
|
)
|
|
(1,446
|
)
|
|
(1,526
|
)
|
|||
Purchases of available-for-sale securities
|
(138
|
)
|
|
(142
|
)
|
|
(88
|
)
|
|||
Proceeds from sales of available-for-sale securities
|
158
|
|
|
135
|
|
|
80
|
|
|||
Proceeds from sales of other investments
|
2
|
|
|
13
|
|
|
10
|
|
|||
Other, net
|
—
|
|
|
2
|
|
|
5
|
|
|||
Net cash flows from investing activities
|
(1,614
|
)
|
|
(1,438
|
)
|
|
(1,519
|
)
|
|||
|
|
|
|
|
|
||||||
Cash flows from financing activities:
|
|
|
|
|
|
||||||
Proceeds from long-term debt
|
62
|
|
|
649
|
|
|
840
|
|
|||
Repayments of long-term debt
|
(38
|
)
|
|
(426
|
)
|
|
(356
|
)
|
|||
Net change in note payable to affiliate
|
9
|
|
|
3
|
|
|
1
|
|
|||
Net proceeds from (repayments of) short-term debt
|
99
|
|
|
(50
|
)
|
|
50
|
|
|||
Other, net
|
1
|
|
|
—
|
|
|
—
|
|
|||
Net cash flows from financing activities
|
133
|
|
|
176
|
|
|
535
|
|
|||
|
|
|
|
|
|
||||||
Net change in cash and cash equivalents
|
(88
|
)
|
|
73
|
|
|
(164
|
)
|
|||
Cash and cash equivalents at beginning of year
|
103
|
|
|
30
|
|
|
194
|
|
|||
Cash and cash equivalents at end of year
|
$
|
15
|
|
|
$
|
103
|
|
|
$
|
30
|
|
(
1
)
|
Company Organization
|
(
2
)
|
Summary of Significant Accounting Policies
|
(
3
)
|
Discontinued Operations
|
(
5
)
|
Jointly Owned Utility Facilities
|
(
6
)
|
Regulatory Matters
|
(
7
)
|
Investments and Restricted Cash and Investments
|
(
8
)
|
Short-Term Debt and Credit Facilities
|
|
2016
|
|
2015
|
|
2014
|
||||||
Current:
|
|
|
|
|
|
||||||
Federal
|
$
|
(485
|
)
|
|
$
|
(418
|
)
|
|
$
|
(414
|
)
|
State
|
(16
|
)
|
|
(8
|
)
|
|
(5
|
)
|
|||
|
(501
|
)
|
|
(426
|
)
|
|
(419
|
)
|
|||
Deferred:
|
|
|
|
|
|
||||||
Federal
|
367
|
|
|
282
|
|
|
296
|
|
|||
State
|
(4
|
)
|
|
(5
|
)
|
|
2
|
|
|||
|
363
|
|
|
277
|
|
|
298
|
|
|||
|
|
|
|
|
|
||||||
Investment tax credits
|
(1
|
)
|
|
(1
|
)
|
|
(1
|
)
|
|||
Total
|
$
|
(139
|
)
|
|
$
|
(150
|
)
|
|
$
|
(122
|
)
|
|
2016
|
|
2015
|
||||
Deferred income tax assets:
|
|
|
|
||||
Regulatory liabilities
|
$
|
333
|
|
|
$
|
327
|
|
Employee benefits
|
66
|
|
|
66
|
|
||
Asset retirement obligations
|
230
|
|
|
214
|
|
||
Other
|
82
|
|
|
97
|
|
||
Total deferred income tax assets
|
711
|
|
|
704
|
|
||
|
|
|
|
||||
Deferred income tax liabilities:
|
|
|
|
||||
Depreciable property
|
(3,767
|
)
|
|
(3,326
|
)
|
||
Regulatory assets
|
(471
|
)
|
|
(418
|
)
|
||
Other
|
(41
|
)
|
|
(16
|
)
|
||
Total deferred income tax liabilities
|
(4,279
|
)
|
|
(3,760
|
)
|
||
|
|
|
|
||||
Net deferred income tax liability
|
$
|
(3,568
|
)
|
|
$
|
(3,056
|
)
|
|
2016
|
|
2015
|
||||
|
|
|
|
||||
Beginning balance
|
$
|
10
|
|
|
$
|
26
|
|
Additions based on tax positions related to the current year
|
—
|
|
|
4
|
|
||
Additions for tax positions of prior years
|
10
|
|
|
46
|
|
||
Reductions based on tax positions related to the current year
|
(2
|
)
|
|
(6
|
)
|
||
Reductions for tax positions of prior years
|
(8
|
)
|
|
(46
|
)
|
||
Statute of limitations
|
—
|
|
|
(5
|
)
|
||
Settlements
|
—
|
|
|
(6
|
)
|
||
Interest and penalties
|
—
|
|
|
(3
|
)
|
||
Ending balance
|
$
|
10
|
|
|
$
|
10
|
|
(
11
)
|
Employee Benefit Plans
|
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Pension costs
|
$
|
4
|
|
|
$
|
4
|
|
|
$
|
4
|
|
Other postretirement costs
|
(1
|
)
|
|
(2
|
)
|
|
(2
|
)
|
(
12
)
|
Asset Retirement Obligations
|
(
13
)
|
Risk Management and Hedging Activities
|
(
16
)
|
Components of Accumulated Other Comprehensive Loss, Net
|
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Corporate-owned life insurance income
|
$
|
8
|
|
|
$
|
4
|
|
|
$
|
8
|
|
Gain on redemption of auction rate securities
|
5
|
|
|
—
|
|
|
—
|
|
|||
Gains on sales of assets and other investments
|
3
|
|
|
13
|
|
|
—
|
|
|||
Leveraged leases
|
—
|
|
|
1
|
|
|
5
|
|
|||
Other, net
|
3
|
|
|
1
|
|
|
5
|
|
|||
Total
|
$
|
19
|
|
|
$
|
19
|
|
|
$
|
18
|
|
|
2016
|
|
2015
|
|
2014
|
||||||
Supplemental cash flow information:
|
|
|
|
|
|
||||||
Interest paid, net of amounts capitalized
|
$
|
204
|
|
|
$
|
177
|
|
|
$
|
167
|
|
Income taxes received, net
|
$
|
609
|
|
|
$
|
630
|
|
|
$
|
153
|
|
|
|
|
|
|
|
||||||
Supplemental disclosure of non-cash investing transactions:
|
|
|
|
|
|
||||||
Accounts payable related to utility plant additions
|
$
|
131
|
|
|
$
|
249
|
|
|
$
|
128
|
|
Transfer of assets and liabilities to affiliate (Note 3)
|
$
|
90
|
|
|
$
|
—
|
|
|
$
|
—
|
|
(
19
)
|
Related Party Transactions
|
(
20
)
|
Segment Information
|
|
Years Ended December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
Operating revenue:
|
|
|
|
|
|
||||||
Regulated electric
|
$
|
1,985
|
|
|
$
|
1,837
|
|
|
$
|
1,817
|
|
Regulated gas
|
637
|
|
|
661
|
|
|
996
|
|
|||
Other
|
9
|
|
|
17
|
|
|
31
|
|
|||
Total operating revenue
|
$
|
2,631
|
|
|
$
|
2,515
|
|
|
$
|
2,844
|
|
|
|
|
|
|
|
||||||
Depreciation and amortization:
|
|
|
|
|
|
||||||
Regulated electric
|
$
|
436
|
|
|
$
|
366
|
|
|
$
|
312
|
|
Regulated gas
|
43
|
|
|
41
|
|
|
39
|
|
|||
Total depreciation and amortization
|
$
|
479
|
|
|
$
|
407
|
|
|
$
|
351
|
|
|
|
|
|
|
|
||||||
Operating income:
|
|
|
|
|
|
||||||
Regulated electric
|
$
|
497
|
|
|
$
|
385
|
|
|
$
|
319
|
|
Regulated gas
|
68
|
|
|
64
|
|
|
75
|
|
|||
Other
|
1
|
|
|
2
|
|
|
1
|
|
|||
Total operating income
|
$
|
566
|
|
|
$
|
451
|
|
|
$
|
395
|
|
|
|
|
|
|
|
||||||
Interest expense:
|
|
|
|
|
|
||||||
Regulated electric
|
$
|
178
|
|
|
$
|
166
|
|
|
$
|
157
|
|
Regulated gas
|
18
|
|
|
17
|
|
|
17
|
|
|||
Other
|
23
|
|
|
23
|
|
|
23
|
|
|||
Total interest expense
|
$
|
219
|
|
|
$
|
206
|
|
|
$
|
197
|
|
|
|
|
|
|
|
||||||
Income tax (benefit) expense from continuing operations:
|
|
|
|
|
|
||||||
Regulated electric
|
$
|
(156
|
)
|
|
$
|
(163
|
)
|
|
$
|
(138
|
)
|
Regulated gas
|
22
|
|
|
16
|
|
|
22
|
|
|||
Other
|
(5
|
)
|
|
(3
|
)
|
|
(6
|
)
|
|||
Total income tax (benefit) expense from continuing operations
|
$
|
(139
|
)
|
|
$
|
(150
|
)
|
|
$
|
(122
|
)
|
|
|
|
|
|
|
||||||
Net income:
|
|
|
|
|
|
||||||
Regulated electric
|
$
|
512
|
|
|
$
|
413
|
|
|
$
|
361
|
|
Regulated gas
|
32
|
|
|
33
|
|
|
40
|
|
|||
Other
|
(12
|
)
|
|
(4
|
)
|
|
(8
|
)
|
|||
Income from continuing operations
|
532
|
|
|
442
|
|
|
393
|
|
|||
Income on discontinued operations
|
—
|
|
|
16
|
|
|
16
|
|
|||
Net income
|
$
|
532
|
|
|
$
|
458
|
|
|
$
|
409
|
|
|
|
|
|
|
|
||||||
Utility construction expenditures:
|
|
|
|
|
|
||||||
Regulated electric
|
$
|
1,564
|
|
|
$
|
1,365
|
|
|
$
|
1,429
|
|
Regulated gas
|
72
|
|
|
81
|
|
|
97
|
|
|||
Total utility construction expenditures
|
$
|
1,636
|
|
|
$
|
1,446
|
|
|
$
|
1,526
|
|
|
As of December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
Total assets:
|
|
|
|
|
|
||||||
Regulated electric
|
$
|
15,304
|
|
|
$
|
14,161
|
|
|
$
|
13,041
|
|
Regulated gas
|
1,424
|
|
|
1,330
|
|
|
1,296
|
|
|||
Other
|
19
|
|
|
183
|
|
|
185
|
|
|||
Total assets
|
$
|
16,747
|
|
|
$
|
15,674
|
|
|
$
|
14,522
|
|
Regulated electric
|
$
|
1,191
|
|
Regulated gas
|
79
|
|
|
Total
|
$
|
1,270
|
|
(
21
)
|
Subsequent Events
|
(
22
)
|
Unaudited Quarterly Operating Results
|
|
2016
|
||||||||||||||
|
1
st
Quarter
|
|
2
nd
Quarter
|
|
3
rd
Quarter
|
|
4
th
Quarter
|
||||||||
|
(In millions)
|
||||||||||||||
Operating revenue
|
$
|
626
|
|
|
$
|
585
|
|
|
$
|
797
|
|
|
$
|
623
|
|
Operating income
|
100
|
|
|
140
|
|
|
284
|
|
|
42
|
|
||||
Net income
|
73
|
|
|
127
|
|
|
318
|
|
|
14
|
|
|
2015
|
||||||||||||||
|
1
st
Quarter
|
|
2
nd
Quarter
|
|
3
rd
Quarter
|
|
4
th
Quarter
|
||||||||
|
(In millions)
|
||||||||||||||
Operating revenue
|
$
|
727
|
|
|
$
|
576
|
|
|
$
|
681
|
|
|
$
|
531
|
|
Operating income
|
101
|
|
|
112
|
|
|
209
|
|
|
29
|
|
||||
Income from continuing operations
|
95
|
|
|
124
|
|
|
230
|
|
|
(7
|
)
|
||||
Income on discontinued operations
|
4
|
|
|
5
|
|
|
1
|
|
|
6
|
|
||||
Net income
|
99
|
|
|
129
|
|
|
231
|
|
|
(1
|
)
|
|
|
2016
|
|
2015
|
|
Change
|
|
2015
|
|
2014
|
|
Change
|
||||||||||||||||
Gross margin (in millions):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Operating revenue
|
|
$
|
2,083
|
|
|
$
|
2,402
|
|
|
$
|
(319
|
)
|
(13
|
)%
|
|
$
|
2,402
|
|
|
$
|
2,337
|
|
|
$
|
65
|
|
3
|
%
|
Cost of fuel, energy and capacity
|
|
768
|
|
|
1,084
|
|
|
(316
|
)
|
(29
|
)
|
|
1,084
|
|
|
1,076
|
|
|
8
|
|
1
|
|
||||||
Gross margin
|
|
$
|
1,315
|
|
|
$
|
1,318
|
|
|
$
|
(3
|
)
|
—
|
|
|
$
|
1,318
|
|
|
$
|
1,261
|
|
|
$
|
57
|
|
5
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
GWh sold:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Residential
|
|
9,394
|
|
|
9,246
|
|
|
148
|
|
2
|
%
|
|
9,246
|
|
|
8,923
|
|
|
323
|
|
4
|
%
|
||||||
Commercial
|
|
4,663
|
|
|
4,635
|
|
|
28
|
|
1
|
|
|
4,635
|
|
|
4,489
|
|
|
146
|
|
3
|
|
||||||
Industrial
|
|
7,313
|
|
|
7,571
|
|
|
(258
|
)
|
(3
|
)
|
|
7,571
|
|
|
7,486
|
|
|
85
|
|
1
|
|
||||||
Other
|
|
212
|
|
|
214
|
|
|
(2
|
)
|
(1
|
)
|
|
214
|
|
|
211
|
|
|
3
|
|
—
|
|
||||||
Total retail
|
|
21,582
|
|
|
21,666
|
|
|
(84
|
)
|
—
|
|
|
21,666
|
|
|
21,109
|
|
|
557
|
|
3
|
|
||||||
Wholesale
|
|
258
|
|
|
353
|
|
|
(95
|
)
|
(27
|
)
|
|
353
|
|
|
20
|
|
|
333
|
|
*
|
|
||||||
Total GWh sold
|
|
21,840
|
|
|
22,019
|
|
|
(179
|
)
|
(1
|
)
|
|
22,019
|
|
|
21,129
|
|
|
890
|
|
4
|
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Average number of retail customers (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Residential
|
|
796
|
|
|
782
|
|
|
14
|
|
2
|
%
|
|
782
|
|
|
770
|
|
|
12
|
|
2
|
%
|
||||||
Commercial
|
|
105
|
|
|
104
|
|
|
1
|
|
1
|
|
|
104
|
|
|
102
|
|
|
2
|
|
2
|
|
||||||
Industrial
|
|
2
|
|
|
2
|
|
|
—
|
|
—
|
|
|
2
|
|
|
2
|
|
|
—
|
|
—
|
|
||||||
Total
|
|
903
|
|
|
888
|
|
|
15
|
|
2
|
|
|
888
|
|
|
874
|
|
|
14
|
|
2
|
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Average revenue per MWh -
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Retail
|
|
$
|
94.27
|
|
|
$
|
108.49
|
|
|
$
|
(14.22
|
)
|
(13
|
)%
|
|
$
|
108.49
|
|
|
$
|
108.90
|
|
|
$
|
(0.41
|
)
|
—
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Heating degree days
|
|
1,508
|
|
|
1,491
|
|
|
17
|
|
1
|
%
|
|
1,491
|
|
|
1,306
|
|
|
185
|
|
14
|
%
|
||||||
Cooling degree days
|
|
4,002
|
|
|
4,069
|
|
|
(67
|
)
|
(2
|
)%
|
|
4,069
|
|
|
3,970
|
|
|
99
|
|
2
|
%
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Sources of energy (GWh)
(1)
:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Coal
|
|
1,480
|
|
|
1,556
|
|
|
(76
|
)
|
(5
|
)%
|
|
1,556
|
|
|
4,422
|
|
|
(2,866
|
)
|
(65
|
)%
|
||||||
Natural gas
|
|
14,577
|
|
|
14,567
|
|
|
10
|
|
—
|
|
|
14,567
|
|
|
12,590
|
|
|
1,977
|
|
16
|
|
||||||
Other
|
|
61
|
|
|
4
|
|
|
57
|
|
*
|
|
|
4
|
|
|
15
|
|
|
(11
|
)
|
(73
|
)
|
||||||
Total energy generated
|
|
16,118
|
|
|
16,127
|
|
|
(9
|
)
|
—
|
|
|
16,127
|
|
|
17,027
|
|
|
(900
|
)
|
(5
|
)
|
||||||
Energy purchased
|
|
6,462
|
|
|
6,431
|
|
|
31
|
|
—
|
|
|
6,431
|
|
|
5,424
|
|
|
1,007
|
|
19
|
|
||||||
Total
|
|
22,580
|
|
|
22,558
|
|
|
22
|
|
—
|
|
|
22,558
|
|
|
22,451
|
|
|
107
|
|
—
|
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Average total cost of energy per MWh
(2)
|
|
$
|
34.00
|
|
|
$
|
48.04
|
|
|
$
|
(14.04
|
)
|
(29
|
)%
|
|
$
|
48.04
|
|
|
$
|
47.94
|
|
|
$
|
0.10
|
|
—
|
%
|
*
|
Not meaningful
|
(1)
|
GWh amounts are net of energy used by the related generating facilities.
|
(2)
|
The average total cost of energy per MWh includes the cost of fuel, purchased power and deferrals and does not include other costs.
|
•
|
$9 million in usage patterns for commercial and industrial customers;
|
•
|
$8 million due to lower customer usage, due to the impacts of weather; and
|
•
|
$2 million in transmission revenue.
|
•
|
$16 million due to higher customer growth.
|
•
|
$26 million in higher energy efficiency program rate revenue, which is offset in operating and maintenance expense;
|
•
|
$14 million due to higher customer growth;
|
•
|
$14 million due to higher customer usage, primarily due to the impacts of weather; and
|
•
|
$3 million in transmission revenue primarily due to increased ON Line usage.
|
Cash and cash equivalents
|
|
$
|
279
|
|
Credit facilities
(1)
|
|
400
|
|
|
Total net liquidity
|
|
$
|
679
|
|
Credit facilities:
|
|
|
||
Maturity dates
|
|
2018
|
|
(1)
|
Refer to Note
6
of Notes to Consolidated Financial Statements in Item 8 of this Form 10
-
K for further discussion regarding
Nevada Power
's credit facility.
|
|
Historical
|
|
Forecasted
|
||||||||||||||||||||
|
2014
|
|
2015
|
|
2016
|
|
2017
|
|
2018
|
|
2019
|
||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Generation development
|
$
|
201
|
|
|
$
|
45
|
|
|
$
|
1
|
|
|
$
|
79
|
|
|
$
|
—
|
|
|
$
|
2
|
|
Distribution
|
107
|
|
|
102
|
|
|
144
|
|
|
102
|
|
|
119
|
|
|
111
|
|
||||||
Transmission system investment
|
19
|
|
|
63
|
|
|
30
|
|
|
12
|
|
|
19
|
|
|
35
|
|
||||||
Other
|
44
|
|
|
110
|
|
|
160
|
|
|
105
|
|
|
90
|
|
|
84
|
|
||||||
Total
|
$
|
371
|
|
|
$
|
320
|
|
|
$
|
335
|
|
|
$
|
298
|
|
|
$
|
228
|
|
|
$
|
232
|
|
•
|
Generation development investment includes the purchase of the remaining 25% interest in the Silverhawk generating facility in 2017. Nevada Power’s cost for the remaining interest will total $77 million. In December 2015, the PUCN approved the purchase of the facility in Nevada Power’s triennial IRP filing.
|
•
|
Remaining investments relate to operating projects that consist of routine expenditures for transmission, distribution, generation and other infrastructure needed to serve existing and expected demand.
|
|
|
Payments Due by Periods
|
||||||||||||||||||
|
|
2017
|
|
2018 - 2019
|
|
2020 - 2021
|
|
2022 and Thereafter
|
|
Total
|
||||||||||
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Long-term debt
|
|
$
|
—
|
|
|
$
|
1,323
|
|
|
$
|
—
|
|
|
$
|
1,292
|
|
|
$
|
2,615
|
|
Interest payments on long-term debt
(1)
|
|
165
|
|
|
250
|
|
|
153
|
|
|
1,270
|
|
|
1,838
|
|
|||||
Capital leases, including interest
(2),(3)
|
|
12
|
|
|
25
|
|
|
30
|
|
|
44
|
|
|
111
|
|
|||||
ON Line financial lease, including interest
(2)
|
|
44
|
|
|
87
|
|
|
89
|
|
|
767
|
|
|
987
|
|
|||||
Fuel and capacity contract commitments
(1)
|
|
697
|
|
|
797
|
|
|
713
|
|
|
5,310
|
|
|
7,517
|
|
|||||
Fuel and capacity contract commitments (not commercially operable)
(1)
|
|
7
|
|
|
43
|
|
|
73
|
|
|
683
|
|
|
806
|
|
|||||
Operating leases and easements
(1)
|
|
9
|
|
|
17
|
|
|
14
|
|
|
51
|
|
|
91
|
|
|||||
Asset retirement obligations
|
|
20
|
|
|
18
|
|
|
15
|
|
|
43
|
|
|
96
|
|
|||||
Maintenance, service and other contracts
(1)
|
|
118
|
|
|
76
|
|
|
73
|
|
|
75
|
|
|
342
|
|
|||||
Total contractual cash obligations
|
|
$
|
1,072
|
|
|
$
|
2,636
|
|
|
$
|
1,160
|
|
|
$
|
9,535
|
|
|
$
|
14,403
|
|
(1)
|
Not reflected on the Consolidated Balance Sheets.
|
(2)
|
Interest is not reflected on the Consolidated Balance Sheets.
|
(3)
|
Includes fuel and capacity contracts designated as a capital lease.
|
|
Fair Value -
|
|
Estimated Fair Value after
|
||||||||
|
Net
|
|
Hypothetical Change in Price
|
||||||||
|
Liability
|
|
10% increase
|
|
10% decrease
|
||||||
As of December 31, 2016:
|
|
|
|
|
|
||||||
Commodity derivative contracts
|
$
|
(14
|
)
|
|
$
|
(15
|
)
|
|
$
|
(13
|
)
|
|
|
|
|
|
|
||||||
As of December 31, 2015:
|
|
|
|
|
|
||||||
Commodity derivative contracts
|
$
|
(18
|
)
|
|
$
|
(20
|
)
|
|
$
|
(16
|
)
|
/s/
|
Deloitte & Touche LLP
|
|
As of December 31,
|
||||||
|
2016
|
|
2015
|
||||
ASSETS
|
|||||||
|
|
|
|
||||
Current assets:
|
|
|
|
||||
Cash and cash equivalents
|
$
|
279
|
|
|
$
|
536
|
|
Accounts receivable, net
|
243
|
|
|
265
|
|
||
Inventories
|
73
|
|
|
80
|
|
||
Regulatory assets
|
20
|
|
|
—
|
|
||
Other current assets
|
38
|
|
|
46
|
|
||
Total current assets
|
653
|
|
|
927
|
|
||
|
|
|
|
||||
Property, plant and equipment, net
|
6,997
|
|
|
6,996
|
|
||
Regulatory assets
|
1,000
|
|
|
1,057
|
|
||
Other assets
|
39
|
|
|
37
|
|
||
|
|
|
|
||||
Total assets
|
$
|
8,689
|
|
|
$
|
9,017
|
|
|
|
|
|
||||
LIABILITIES AND SHAREHOLDER'S EQUITY
|
|||||||
Current liabilities:
|
|
|
|
||||
Accounts payable
|
$
|
187
|
|
|
$
|
214
|
|
Accrued interest
|
50
|
|
|
54
|
|
||
Accrued property, income and other taxes
|
93
|
|
|
30
|
|
||
Regulatory liabilities
|
37
|
|
|
173
|
|
||
Current portion of long-term debt and financial and capital lease obligations
|
17
|
|
|
225
|
|
||
Customer deposits
|
78
|
|
|
58
|
|
||
Other current liabilities
|
39
|
|
|
28
|
|
||
Total current liabilities
|
501
|
|
|
782
|
|
||
|
|
|
|
||||
Long-term debt and financial and capital lease obligations
|
3,049
|
|
|
3,060
|
|
||
Regulatory liabilities
|
416
|
|
|
304
|
|
||
Deferred income taxes
|
1,474
|
|
|
1,405
|
|
||
Other long-term liabilities
|
277
|
|
|
303
|
|
||
Total liabilities
|
5,717
|
|
|
5,854
|
|
||
|
|
|
|
||||
Commitments and contingencies (Note 14)
|
|
|
|
||||
|
|
|
|
||||
Shareholder's equity:
|
|
|
|
||||
Common stock - $1.00 stated value, 1,000 shares authorized, issued and outstanding
|
—
|
|
|
—
|
|
||
Other paid-in capital
|
2,308
|
|
|
2,308
|
|
||
Retained earnings
|
667
|
|
|
858
|
|
||
Accumulated other comprehensive loss, net
|
(3
|
)
|
|
(3
|
)
|
||
Total shareholder's equity
|
2,972
|
|
|
3,163
|
|
||
|
|
|
|
||||
Total liabilities and shareholder's equity
|
$
|
8,689
|
|
|
$
|
9,017
|
|
|
|
|
|
||||
The accompanying notes are an integral part of the consolidated financial statements.
|
|
Years Ended December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Operating revenue
|
$
|
2,083
|
|
|
$
|
2,402
|
|
|
$
|
2,337
|
|
|
|
|
|
|
|
||||||
Operating costs and expenses:
|
|
|
|
|
|
||||||
Cost of fuel, energy and capacity
|
768
|
|
|
1,084
|
|
|
1,076
|
|
|||
Operating and maintenance
|
394
|
|
|
372
|
|
|
413
|
|
|||
Depreciation and amortization
|
303
|
|
|
297
|
|
|
274
|
|
|||
Property and other taxes
|
38
|
|
|
36
|
|
|
33
|
|
|||
Total operating costs and expenses
|
1,503
|
|
|
1,789
|
|
|
1,796
|
|
|||
|
|
|
|
|
|
||||||
Operating income
|
580
|
|
|
613
|
|
|
541
|
|
|||
|
|
|
|
|
|
||||||
Other income (expense):
|
|
|
|
|
|
||||||
Interest expense
|
(185
|
)
|
|
(190
|
)
|
|
(208
|
)
|
|||
Allowance for borrowed funds
|
4
|
|
|
3
|
|
|
1
|
|
|||
Allowance for equity funds
|
2
|
|
|
4
|
|
|
1
|
|
|||
Other, net
|
24
|
|
|
20
|
|
|
22
|
|
|||
Total other income (expense)
|
(155
|
)
|
|
(163
|
)
|
|
(184
|
)
|
|||
|
|
|
|
|
|
||||||
Income before income tax expense
|
425
|
|
|
450
|
|
|
357
|
|
|||
Income tax expense
|
146
|
|
|
162
|
|
|
130
|
|
|||
Net income
|
$
|
279
|
|
|
$
|
288
|
|
|
$
|
227
|
|
|
|
|
|
|
|
||||||
The accompanying notes are an integral part of these consolidated financial statements.
|
|
|
|
|
|
|
|
|
|
|
Accumulated
|
|
|
|||||||||||
|
|
|
|
|
|
Other
|
|
|
|
Other
|
|
Total
|
|||||||||||
|
|
Common Stock
|
|
Paid-in
|
|
Retained
|
|
Comprehensive
|
|
Shareholder's
|
|||||||||||||
|
|
Shares
|
|
Amount
|
|
Capital
|
|
Earnings
|
|
Loss, Net
|
|
Equity
|
|||||||||||
Balance, December 31, 2013
|
|
1,000
|
|
|
$
|
—
|
|
|
$
|
2,308
|
|
|
$
|
586
|
|
|
$
|
(4
|
)
|
|
$
|
2,890
|
|
Net income
|
|
—
|
|
|
—
|
|
|
—
|
|
|
227
|
|
|
—
|
|
|
227
|
|
|||||
Dividends declared
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(230
|
)
|
|
—
|
|
|
(230
|
)
|
|||||
Other equity transactions
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
1
|
|
|
1
|
|
|||||
Balance, December 31, 2014
|
|
1,000
|
|
|
—
|
|
|
2,308
|
|
|
583
|
|
|
(3
|
)
|
|
2,888
|
|
|||||
Net income
|
|
—
|
|
|
—
|
|
|
—
|
|
|
288
|
|
|
—
|
|
|
288
|
|
|||||
Dividends declared
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(13
|
)
|
|
—
|
|
|
(13
|
)
|
|||||
Balance, December 31, 2015
|
|
1,000
|
|
|
—
|
|
|
2,308
|
|
|
858
|
|
|
(3
|
)
|
|
3,163
|
|
|||||
Net income
|
|
—
|
|
|
—
|
|
|
—
|
|
|
279
|
|
|
—
|
|
|
279
|
|
|||||
Dividends declared
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(469
|
)
|
|
—
|
|
|
(469
|
)
|
|||||
Other equity transactions
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(1
|
)
|
|
—
|
|
|
(1
|
)
|
|||||
Balance, December 31, 2016
|
|
1,000
|
|
|
$
|
—
|
|
|
$
|
2,308
|
|
|
$
|
667
|
|
|
$
|
(3
|
)
|
|
$
|
2,972
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
The accompanying notes are an integral part of these consolidated financial statements.
|
|
Years Ended December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Cash flows from operating activities:
|
|
|
|
|
|
||||||
Net income
|
$
|
279
|
|
|
$
|
288
|
|
|
$
|
227
|
|
Adjustments to reconcile net income to net cash flows from operating activities:
|
|
|
|
|
|
||||||
(Gain) loss on nonrecurring items
|
1
|
|
|
(3
|
)
|
|
15
|
|
|||
Depreciation and amortization
|
303
|
|
|
297
|
|
|
274
|
|
|||
Deferred income taxes and amortization of investment tax credits
|
78
|
|
|
162
|
|
|
130
|
|
|||
Allowance for equity funds
|
(2
|
)
|
|
(4
|
)
|
|
(1
|
)
|
|||
Changes in regulatory assets and liabilities
|
131
|
|
|
4
|
|
|
2
|
|
|||
Deferred energy
|
(21
|
)
|
|
176
|
|
|
(44
|
)
|
|||
Amortization of deferred energy
|
(107
|
)
|
|
36
|
|
|
79
|
|
|||
Other, net
|
—
|
|
|
13
|
|
|
68
|
|
|||
Changes in other operating assets and liabilities:
|
|
|
|
|
|
||||||
Accounts receivable and other assets
|
26
|
|
|
(40
|
)
|
|
(19
|
)
|
|||
Inventories
|
7
|
|
|
9
|
|
|
(15
|
)
|
|||
Accrued property, income and other taxes
|
63
|
|
|
—
|
|
|
1
|
|
|||
Accounts payable and other liabilities
|
13
|
|
|
(46
|
)
|
|
(13
|
)
|
|||
Net cash flows from operating activities
|
771
|
|
|
892
|
|
|
704
|
|
|||
|
|
|
|
|
|
||||||
Cash flows from investing activities:
|
|
|
|
|
|
||||||
Capital expenditures
|
(335
|
)
|
|
(320
|
)
|
|
(371
|
)
|
|||
Proceeds from sale of assets
|
—
|
|
|
9
|
|
|
—
|
|
|||
Other, net
|
—
|
|
|
10
|
|
|
—
|
|
|||
Net cash flows from investing activities
|
(335
|
)
|
|
(301
|
)
|
|
(371
|
)
|
|||
|
|
|
|
|
|
||||||
Cash flows from financing activities:
|
|
|
|
|
|
||||||
Repayments of long-term debt and financial and capital lease obligations
|
(224
|
)
|
|
(262
|
)
|
|
(9
|
)
|
|||
Dividends paid
|
(469
|
)
|
|
(13
|
)
|
|
(230
|
)
|
|||
Net cash flows from financing activities
|
(693
|
)
|
|
(275
|
)
|
|
(239
|
)
|
|||
|
|
|
|
|
|
||||||
Net change in cash and cash equivalents
|
(257
|
)
|
|
316
|
|
|
94
|
|
|||
Cash and cash equivalents at beginning of period
|
536
|
|
|
220
|
|
|
126
|
|
|||
Cash and cash equivalents at end of period
|
$
|
279
|
|
|
$
|
536
|
|
|
$
|
220
|
|
|
|
|
|
|
|
||||||
The accompanying notes are an integral part of these consolidated financial statements.
|
|
2016
|
|
2015
|
|
2014
|
||||||
Beginning balance
|
$
|
13
|
|
|
$
|
14
|
|
|
$
|
8
|
|
Charged to operating costs and expenses, net
|
16
|
|
|
16
|
|
|
14
|
|
|||
Write-offs, net
|
(17
|
)
|
|
(17
|
)
|
|
(8
|
)
|
|||
Ending balance
|
$
|
12
|
|
|
$
|
13
|
|
|
$
|
14
|
|
|
Depreciable Life
|
|
2016
|
|
2015
|
||||
Utility plant:
|
|
|
|
|
|
||||
Generation
|
30 - 55 years
|
|
$
|
4,271
|
|
|
$
|
4,212
|
|
Distribution
|
20 - 65 years
|
|
3,231
|
|
|
3,118
|
|
||
Transmission
|
45 - 65 years
|
|
1,846
|
|
|
1,788
|
|
||
General and intangible plant
|
5 - 65 years
|
|
738
|
|
|
694
|
|
||
Utility plant
|
|
|
10,086
|
|
|
9,812
|
|
||
Accumulated depreciation and amortization
|
|
|
(3,205
|
)
|
|
(2,971
|
)
|
||
Utility plant, net
|
|
|
6,881
|
|
|
6,841
|
|
||
Other non-regulated, net of accumulated depreciation and amortization
|
45 years
|
|
2
|
|
|
2
|
|
||
Plant, net
|
|
|
6,883
|
|
|
6,843
|
|
||
Construction work-in-progress
|
|
|
114
|
|
|
153
|
|
||
Property, plant and equipment, net
|
|
|
$
|
6,997
|
|
|
$
|
6,996
|
|
|
Weighted
|
|
|
|
|
||||
|
Average
|
|
|
|
|
||||
|
Remaining Life
|
|
2016
|
|
2015
|
||||
|
|
|
|
|
|
||||
Deferred income taxes
(1)
|
27 years
|
|
$
|
141
|
|
|
$
|
149
|
|
Merger costs from 1999 merger
|
28 years
|
|
136
|
|
|
143
|
|
||
Deferred operating costs
|
20 years
|
|
127
|
|
|
87
|
|
||
Decommissioning costs
|
7 years
|
|
114
|
|
|
121
|
|
||
Employee benefit plans
(2)
|
10 years
|
|
105
|
|
|
98
|
|
||
Abandoned projects
|
3 years
|
|
75
|
|
|
91
|
|
||
Asset retirement obligations
|
7 years
|
|
74
|
|
|
79
|
|
||
Legacy meters
|
16 years
|
|
60
|
|
|
64
|
|
||
Merrill Lynch deferred energy costs
|
3 years
|
|
40
|
|
|
56
|
|
||
Other
|
Various
|
|
148
|
|
|
169
|
|
||
Total regulatory assets
|
|
|
$
|
1,020
|
|
|
$
|
1,057
|
|
|
|
|
|
|
|
||||
Reflected as:
|
|
|
|
|
|
||||
Current assets
|
|
|
$
|
20
|
|
|
$
|
—
|
|
Other assets
|
|
|
1,000
|
|
|
1,057
|
|
||
Total regulatory assets
|
|
|
$
|
1,020
|
|
|
$
|
1,057
|
|
(1)
|
Amounts represent income tax benefits related to accelerated tax depreciation and certain property-related basis differences that were previously flowed through to customers and will be included in regulated rates when the temporary differences reverse.
|
(2)
|
Represents amounts not yet recognized as a component of net periodic benefit cost that are expected to be included in regulated rates when recognized.
|
|
Weighted
|
|
|
|
|
||||
|
Average
|
|
|
|
|
||||
|
Remaining Life
|
|
2016
|
|
2015
|
||||
|
|
|
|
|
|
||||
Cost of removal
(1)
|
33 years
|
|
$
|
294
|
|
|
$
|
273
|
|
Impact fees
|
6 years
|
|
90
|
|
|
—
|
|
||
Energy efficiency program
|
1 year
|
|
37
|
|
|
34
|
|
||
Deferred energy costs
|
1 year
|
|
—
|
|
|
139
|
|
||
Other
|
Various
|
|
32
|
|
|
31
|
|
||
Total regulatory liabilities
|
|
|
$
|
453
|
|
|
$
|
477
|
|
|
|
|
|
|
|
||||
Reflected as:
|
|
|
|
|
|
||||
Current liabilities
|
|
|
$
|
37
|
|
|
$
|
173
|
|
Other long-term liabilities
|
|
|
416
|
|
|
304
|
|
||
Total regulatory liabilities
|
|
|
$
|
453
|
|
|
$
|
477
|
|
(1)
|
Amounts represent estimated costs, as accrued through depreciation rates and exclusive of ARO liabilities, of removing regulated property, plant and equipment in accordance with accepted regulatory practices. Amounts are deducted from rate base or otherwise accrue a carrying cost.
|
|
Par Value
|
|
2016
|
|
2015
|
||||||
General and refunding mortgage securities:
|
|
|
|
|
|
||||||
5.950% Series M, due 2016
|
—
|
|
|
—
|
|
|
210
|
|
|||
6.500% Series O, due 2018
|
324
|
|
|
324
|
|
|
323
|
|
|||
6.500% Series S, due 2018
|
499
|
|
|
498
|
|
|
498
|
|
|||
7.125% Series V, due 2019
|
500
|
|
|
499
|
|
|
499
|
|
|||
6.650% Series N, due 2036
|
367
|
|
|
357
|
|
|
356
|
|
|||
6.750% Series R, due 2037
|
349
|
|
|
345
|
|
|
345
|
|
|||
5.375% Series X, due 2040
|
250
|
|
|
247
|
|
|
247
|
|
|||
5.450% Series Y, due 2041
|
250
|
|
|
236
|
|
|
235
|
|
|||
Variable-rate series (2016-1.890% to 1.928%, 2015-0.672% to 1.055%):
|
|
|
|
|
|
||||||
Pollution Control Revenue Bonds Series 2006A, due 2032
|
38
|
|
|
38
|
|
|
38
|
|
|||
Pollution Control Revenue Bonds Series 2006, due 2036
|
38
|
|
|
37
|
|
|
37
|
|
|||
Capital and financial lease obligations - 2.750% to 11.600%, due through 2054
|
485
|
|
|
485
|
|
|
497
|
|
|||
Total long-term debt and financial and capital leases
|
$
|
3,100
|
|
|
$
|
3,066
|
|
|
$
|
3,285
|
|
|
|
|
|
|
|
||||||
Reflected as:
|
|
|
|
|
|
||||||
Current portion of long-term debt and financial and capital lease obligations
|
|
|
$
|
17
|
|
|
$
|
225
|
|
||
Long-term debt and financial and capital lease obligations
|
|
|
3,049
|
|
|
3,060
|
|
||||
Total long-term debt and financial and capital leases
|
|
|
$
|
3,066
|
|
|
$
|
3,285
|
|
|
|
Long-term
|
|
Capital and Financial
|
|
|
||||||
|
|
Debt
|
|
Lease Obligations
|
|
Total
|
||||||
|
|
|
|
|
|
|
||||||
2017
|
|
$
|
—
|
|
|
$
|
75
|
|
|
$
|
75
|
|
2018
|
|
823
|
|
|
74
|
|
|
897
|
|
|||
2019
|
|
500
|
|
|
76
|
|
|
576
|
|
|||
2020
|
|
—
|
|
|
75
|
|
|
75
|
|
|||
2021
|
|
—
|
|
|
79
|
|
|
79
|
|
|||
Thereafter
|
|
1,292
|
|
|
831
|
|
|
2,123
|
|
|||
Total
|
|
2,615
|
|
|
1,210
|
|
|
3,825
|
|
|||
Unamortized premium, discount and debt issuance cost
|
|
(34
|
)
|
|
—
|
|
|
(34
|
)
|
|||
Executory costs
|
|
—
|
|
|
(111
|
)
|
|
(111
|
)
|
|||
Amounts representing interest
|
|
—
|
|
|
(614
|
)
|
|
(614
|
)
|
|||
Total
|
|
$
|
2,581
|
|
|
$
|
485
|
|
|
$
|
3,066
|
|
•
|
In 1984,
Nevada Power
entered into a
30
-year capital lease for the Pearson Building with
five
,
five
-year renewal options beginning in year 2015. In February 2010,
Nevada Power
amended this capital lease agreement to include the lease of the adjoining parking lot and to exercise
three
of the
five
-year renewal options beginning in year 2015. There remain
two
additional renewal options which could extend the lease an additional
ten
years. Capital assets of
$25 million
and
$27 million
were included in property, plant and equipment, net as of
December 31
,
2016
and
2015
, respectively.
|
•
|
In 2007,
Nevada Power
entered into a
20
-year lease, with
three
10
-year renewal options, to occupy land and building for its Beltway Complex operations center in southern Nevada.
Nevada Power
accounts for the building portion of the lease as a capital lease and the land portion of the lease as an operating lease.
Nevada Power
transferred operations to the facilities in June 2009. Capital assets of
$7 million
were included in property, plant and equipment, net as of
December 31
,
2016
and
2015
.
|
•
|
Nevada Power
has long-term energy purchase contracts which qualify as capital leases. The leases were entered into between the years 1989 and 1990 and became commercially operable through 1993. The terms of the leases are for
30
years and expire between the years 2022-2023. Capital assets of
$38 million
and
$40 million
were included in property, plant and equipment, net as of
December 31
,
2016
and
2015
, respectively.
|
•
|
Nevada Power
has master leasing agreements of which various pieces of equipment qualify as capital leases. The remaining equipment is treated as operating leases. Lease terms average
seven
years under the master lease agreement. Capital assets of
$1 million
were included in property, plant and equipment, net as of
December 31
,
2016
and
2015
.
|
•
|
ON Line was placed in-service on
December 31
, 2013. The
Nevada Utilities
entered into a long-term transmission use agreement, in which the
Nevada Utilities
have
25%
interest and Great Basin Transmission South, LLC has
75%
interest. Refer to Note
4
for additional information. The
Nevada Utilities
' share of the long-term transmission use agreement and ownership interest is split at
95%
for Nevada Power and
5%
for Sierra Pacific. The term is for
41
years with the agreement ending
December 31
, 2054. Payments began on January 31, 2014. ON Line assets of
$402 million
and
$410 million
were included in property, plant and equipment, net as of
December 31
,
2016
and
2015
, respectively.
|
|
|
Other
|
|
Other
|
|
|
||||||
|
|
Current
|
|
Long-term
|
|
|
||||||
|
|
Liabilities
|
|
Liabilities
|
|
Total
|
||||||
As of December 31, 2016:
|
|
|
|
|
|
|
||||||
Commodity derivative liabilities
(1)
|
|
$
|
(7
|
)
|
|
$
|
(7
|
)
|
|
$
|
(14
|
)
|
|
|
|
|
|
|
|
||||||
As of December 31, 2015:
|
|
|
|
|
|
|
||||||
Commodity derivative liabilities
(1)
|
|
$
|
(8
|
)
|
|
$
|
(14
|
)
|
|
$
|
(22
|
)
|
(1)
|
Nevada Power
's commodity derivatives not designated as hedging contracts are included in regulated rates and as of
December 31
,
2016
and
2015
, a regulatory asset of
$14 million
and
$22 million
, respectively, was recorded related to the derivative liability of
$14 million
and
$22 million
, respectively.
|
|
|
Unit of
|
|
|
|
|
||
|
|
Measure
|
|
2016
|
|
2015
|
||
Electricity sales
|
|
Megawatt hours
|
|
(2
|
)
|
|
(2
|
)
|
Natural gas purchases
|
|
Decatherms
|
|
114
|
|
|
126
|
|
(
9
)
|
Fair Value Measurements
|
•
|
Level 1 - Inputs are unadjusted quoted prices in active markets for identical assets or liabilities that
Nevada Power
has the ability to access at the measurement date.
|
•
|
Level 2 - Inputs include quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, inputs other than quoted prices that are observable for the asset or liability and inputs that are derived principally from or corroborated by observable market data by correlation or other means (market corroborated inputs).
|
•
|
Level 3 - Unobservable inputs reflect
Nevada Power
's judgments about the assumptions market participants would use in pricing the asset or liability since limited market data exists.
Nevada Power
develops these inputs based on the best information available, including its own data.
|
|
Input Levels for Fair Value Measurements
|
|
|
||||||||||||
|
Level 1
|
|
Level 2
|
|
Level 3
|
|
Total
|
||||||||
As of December 31, 2016:
|
|
|
|
|
|
|
|
||||||||
Assets:
|
|
|
|
|
|
|
|
||||||||
Money market mutual funds
(1)
|
$
|
220
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
220
|
|
Investment funds
|
6
|
|
|
—
|
|
|
—
|
|
|
6
|
|
||||
|
$
|
226
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
226
|
|
|
|
|
|
|
|
|
|
||||||||
Liabilities - commodity derivatives
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
(14
|
)
|
|
$
|
(14
|
)
|
|
|
|
|
|
|
|
|
||||||||
As of December 31, 2015:
|
|
|
|
|
|
|
|
||||||||
Assets - investment funds
|
$
|
5
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
5
|
|
|
|
|
|
|
|
|
|
||||||||
Liabilities - commodity derivatives
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
(22
|
)
|
|
$
|
(22
|
)
|
(1)
|
Amounts are included in cash and cash equivalents on the Consolidated Balance Sheets. The fair value of these money market mutual funds approximates cost.
|
|
|
2016
|
|
2015
|
|
2014
|
||||||
Beginning balance
|
|
$
|
(22
|
)
|
|
$
|
(30
|
)
|
|
$
|
(47
|
)
|
Changes in fair value recognized in regulatory assets
|
|
(4
|
)
|
|
—
|
|
|
9
|
|
|||
Settlements
|
|
12
|
|
|
8
|
|
|
8
|
|
|||
Ending balance
|
|
$
|
(14
|
)
|
|
$
|
(22
|
)
|
|
$
|
(30
|
)
|
(
10
)
|
Income Taxes
|
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Current – Federal
|
$
|
68
|
|
|
$
|
—
|
|
|
$
|
—
|
|
Deferred – Federal
|
79
|
|
|
163
|
|
|
131
|
|
|||
Investment tax credits
|
(1
|
)
|
|
(1
|
)
|
|
(1
|
)
|
|||
Total income tax expense
|
$
|
146
|
|
|
$
|
162
|
|
|
$
|
130
|
|
|
2016
|
|
2015
|
||||
Deferred income tax assets:
|
|
|
|
||||
Capital and financial leases
|
170
|
|
|
174
|
|
||
Regulatory liabilities
|
83
|
|
|
47
|
|
||
Employee benefits
|
29
|
|
|
30
|
|
||
Customer advances
|
23
|
|
|
22
|
|
||
Federal net operating loss and credit carryforwards
|
5
|
|
|
15
|
|
||
Other
|
16
|
|
|
17
|
|
||
Total deferred income tax assets
|
326
|
|
|
305
|
|
||
Valuation allowance
|
(5
|
)
|
|
(5
|
)
|
||
Total deferred income tax assets, net
|
321
|
|
|
300
|
|
||
|
|
|
|
||||
Deferred income tax liabilities:
|
|
|
|
||||
Property related items
|
(1,293
|
)
|
|
(1,242
|
)
|
||
Regulatory assets
|
(321
|
)
|
|
(275
|
)
|
||
Capital and financial leases
|
(165
|
)
|
|
(169
|
)
|
||
Other
|
(16
|
)
|
|
(19
|
)
|
||
Total deferred income tax liabilities
|
(1,795
|
)
|
|
(1,705
|
)
|
||
Net deferred income tax liability
|
$
|
(1,474
|
)
|
|
$
|
(1,405
|
)
|
Other tax credits
|
$
|
5
|
|
Expiration dates
|
2017 - 2028
|
(
11
)
|
Related Party Transactions
|
|
2016
|
|
2015
|
||||
Qualified Pension Plan -
|
|
|
|
||||
Other long-term liabilities
|
$
|
(24
|
)
|
|
$
|
(38
|
)
|
|
|
|
|
||||
Non-Qualified Pension Plans:
|
|
|
|
||||
Other current liabilities
|
(1
|
)
|
|
(1
|
)
|
||
Other long-term liabilities
|
(9
|
)
|
|
(9
|
)
|
||
|
|
|
|
||||
Other Postretirement Plans -
|
|
|
|
||||
Other long-term liabilities
|
(4
|
)
|
|
(5
|
)
|
|
2016
|
|
2015
|
||||
|
|
|
|
||||
Waste water remediation
|
$
|
38
|
|
|
$
|
42
|
|
Evaporative ponds and dry ash landfills
|
22
|
|
|
27
|
|
||
Asbestos
|
4
|
|
|
3
|
|
||
Solar
|
2
|
|
|
2
|
|
||
Other
|
17
|
|
|
11
|
|
||
Total asset retirement obligations
|
$
|
83
|
|
|
$
|
85
|
|
|
2016
|
|
2015
|
||||
|
|
|
|
||||
Beginning balance
|
$
|
85
|
|
|
$
|
86
|
|
Change in estimated costs
|
4
|
|
|
3
|
|
||
Additions
|
—
|
|
|
3
|
|
||
Retirements
|
(10
|
)
|
|
(11
|
)
|
||
Accretion
|
4
|
|
|
4
|
|
||
Ending balance
|
$
|
83
|
|
|
$
|
85
|
|
|
|
|
|
||||
Reflected as:
|
|
|
|
||||
Other current liabilities
|
$
|
20
|
|
|
$
|
13
|
|
Other long-term liabilities
|
63
|
|
|
72
|
|
||
|
$
|
83
|
|
|
$
|
85
|
|
(
14
)
|
Commitments and Contingencies
|
|
2017
|
|
2018
|
|
2019
|
|
2020
|
|
2021
|
|
2022 and Thereafter
|
|
Total
|
||||||||||||||
Contract type:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Fuel, capacity and transmission contract commitments
|
$
|
697
|
|
|
$
|
445
|
|
|
$
|
352
|
|
|
$
|
355
|
|
|
$
|
358
|
|
|
$
|
5,310
|
|
|
$
|
7,517
|
|
Fuel and capacity contract commitments (not commercially operable)
|
7
|
|
|
14
|
|
|
29
|
|
|
36
|
|
|
37
|
|
|
683
|
|
|
806
|
|
|||||||
Operating leases and easements
|
9
|
|
|
9
|
|
|
8
|
|
|
7
|
|
|
7
|
|
|
51
|
|
|
91
|
|
|||||||
Maintenance, service and other contracts
|
118
|
|
|
39
|
|
|
37
|
|
|
37
|
|
|
36
|
|
|
75
|
|
|
342
|
|
|||||||
Total commitments
|
$
|
831
|
|
|
$
|
507
|
|
|
$
|
426
|
|
|
$
|
435
|
|
|
$
|
438
|
|
|
$
|
6,119
|
|
|
$
|
8,756
|
|
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Supplemental disclosure of cash flow information -
|
|
|
|
|
|
||||||
Interest paid, net of amounts capitalized
|
$
|
173
|
|
|
$
|
186
|
|
|
$
|
194
|
|
|
|
|
|
|
|
||||||
Supplemental disclosure of non-cash investing and financing transactions:
|
|
|
|
|
|
||||||
Accruals related to property, plant and equipment additions
|
$
|
19
|
|
|
$
|
51
|
|
|
$
|
30
|
|
Capital and financial lease obligations incurred
|
$
|
(1
|
)
|
|
$
|
(5
|
)
|
|
$
|
7
|
|
|
Three-Month Periods Ended
|
||||||||||||||
|
March 31,
|
|
June 30,
|
|
September 30,
|
|
December 31,
|
||||||||
|
2016
|
|
2016
|
|
2016
|
|
2016
|
||||||||
|
|
|
|
|
|
|
|
||||||||
Operating revenues
|
$
|
399
|
|
|
$
|
525
|
|
|
$
|
766
|
|
|
$
|
393
|
|
Operating income
|
46
|
|
|
141
|
|
|
324
|
|
|
69
|
|
||||
Net income
|
3
|
|
|
66
|
|
|
188
|
|
|
22
|
|
||||
|
|
|
|
|
|
|
|
||||||||
|
Three-Month Periods Ended
|
||||||||||||||
|
March 31,
|
|
June 30,
|
|
September 30,
|
|
December 31,
|
||||||||
|
2015
|
|
2015
|
|
2015
|
|
2015
|
||||||||
|
|
|
|
|
|
|
|
||||||||
Operating revenues
|
$
|
459
|
|
|
$
|
607
|
|
|
$
|
878
|
|
|
$
|
458
|
|
Operating income
|
74
|
|
|
136
|
|
|
329
|
|
|
74
|
|
||||
Net income
|
24
|
|
|
60
|
|
|
187
|
|
|
17
|
|
|
|
2016
|
|
2015
|
|
Change
|
|
2015
|
|
2014
|
|
Change
|
||||||||||||||||
Gross margin (in millions):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Operating electric revenue
|
|
$
|
702
|
|
|
$
|
810
|
|
|
$
|
(108
|
)
|
(13
|
)%
|
|
$
|
810
|
|
|
$
|
779
|
|
|
$
|
31
|
|
4
|
%
|
Cost of fuel, energy and capacity
|
|
265
|
|
|
374
|
|
|
(109
|
)
|
(29
|
)
|
|
374
|
|
|
361
|
|
|
13
|
|
4
|
|
||||||
Gross margin
|
|
$
|
437
|
|
|
$
|
436
|
|
|
$
|
1
|
|
—
|
|
|
$
|
436
|
|
|
$
|
418
|
|
|
$
|
18
|
|
4
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
GWh sold:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Residential
|
|
2,375
|
|
|
2,315
|
|
|
60
|
|
3
|
%
|
|
2,315
|
|
|
2,268
|
|
|
47
|
|
2
|
%
|
||||||
Commercial
|
|
2,933
|
|
|
2,942
|
|
|
(9
|
)
|
—
|
|
|
2,942
|
|
|
2,944
|
|
|
(2
|
)
|
—
|
|
||||||
Industrial
|
|
3,014
|
|
|
2,973
|
|
|
41
|
|
1
|
|
|
2,973
|
|
|
2,869
|
|
|
104
|
|
4
|
|
||||||
Other
|
|
16
|
|
|
16
|
|
|
—
|
|
—
|
|
|
16
|
|
|
16
|
|
|
—
|
|
—
|
|
||||||
Total retail
|
|
8,338
|
|
|
8,246
|
|
|
92
|
|
1
|
|
|
8,246
|
|
|
8,097
|
|
|
149
|
|
2
|
|
||||||
Wholesale
|
|
662
|
|
|
664
|
|
|
(2
|
)
|
—
|
|
|
664
|
|
|
645
|
|
|
19
|
|
3
|
|
||||||
Total GWh sold
|
|
9,000
|
|
|
8,910
|
|
|
90
|
|
1
|
|
|
8,910
|
|
|
8,742
|
|
|
168
|
|
2
|
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Average number of retail customers (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Residential
|
|
291
|
|
|
288
|
|
|
3
|
|
1
|
%
|
|
288
|
|
|
285
|
|
|
3
|
|
1
|
%
|
||||||
Commercial
|
|
47
|
|
|
46
|
|
|
1
|
|
2
|
|
|
46
|
|
|
46
|
|
|
—
|
|
—
|
|
||||||
Total
|
|
338
|
|
|
334
|
|
|
4
|
|
1
|
|
|
334
|
|
|
331
|
|
|
3
|
|
1
|
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Average revenue per MWh:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Retail
|
|
$
|
78.08
|
|
|
$
|
90.85
|
|
|
$
|
(12.77
|
)
|
(14
|
)%
|
|
$
|
90.85
|
|
|
$
|
88.78
|
|
|
$
|
2.07
|
|
2
|
%
|
Wholesale
|
|
$
|
52.05
|
|
|
$
|
61.37
|
|
|
$
|
(9.32
|
)
|
(15
|
)%
|
|
$
|
61.37
|
|
|
$
|
68.34
|
|
|
$
|
(6.97
|
)
|
(10
|
)%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Heating degree days
|
|
4,185
|
|
|
4,122
|
|
|
63
|
|
2
|
%
|
|
4,122
|
|
|
3,910
|
|
|
212
|
|
5
|
%
|
||||||
Cooling degree days
|
|
1,088
|
|
|
1,194
|
|
|
(106
|
)
|
(9
|
)%
|
|
1,194
|
|
|
1,211
|
|
|
(17
|
)
|
(1
|
)%
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Sources of energy (GWh)
(1)
:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Coal
|
|
751
|
|
|
1,210
|
|
|
(459
|
)
|
(38
|
)%
|
|
1,210
|
|
|
1,870
|
|
|
(660
|
)
|
(35
|
)%
|
||||||
Natural gas
|
|
4,290
|
|
|
3,981
|
|
|
309
|
|
8
|
|
|
3,981
|
|
|
4,169
|
|
|
(188
|
)
|
(5
|
)
|
||||||
Total energy generated
|
|
5,041
|
|
|
5,191
|
|
|
(150
|
)
|
(3
|
)
|
|
5,191
|
|
|
6,039
|
|
|
(848
|
)
|
(14
|
)
|
||||||
Energy purchased
|
|
4,383
|
|
|
4,441
|
|
|
(58
|
)
|
(1
|
)
|
|
4,441
|
|
|
2,943
|
|
|
1,498
|
|
51
|
|
||||||
Total
|
|
9,424
|
|
|
9,632
|
|
|
(208
|
)
|
(2
|
)
|
|
9,632
|
|
|
8,982
|
|
|
650
|
|
7
|
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Average total cost of energy per MWh
(2)
|
|
$
|
28.16
|
|
|
$
|
38.80
|
|
|
$
|
(10.64
|
)
|
(27
|
)%
|
|
$
|
38.80
|
|
|
$
|
40.19
|
|
|
$
|
(1.39
|
)
|
(3
|
)%
|
|
|
2016
|
|
2015
|
|
Change
|
|
2015
|
|
2014
|
|
Change
|
||||||||||||||||
Gross margin (in millions):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Operating natural gas revenue
|
|
$
|
110
|
|
|
$
|
137
|
|
|
$
|
(27
|
)
|
(20
|
)%
|
|
$
|
137
|
|
|
$
|
125
|
|
|
$
|
12
|
|
10
|
%
|
Natural gas purchased for resale
|
|
55
|
|
|
84
|
|
|
(29
|
)
|
(35
|
)
|
|
84
|
|
|
76
|
|
|
8
|
|
11
|
|
||||||
Gross margin
|
|
$
|
55
|
|
|
$
|
53
|
|
|
$
|
2
|
|
4
|
|
|
$
|
53
|
|
|
$
|
49
|
|
|
$
|
4
|
|
8
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Dth sold:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Residential
|
|
9,207
|
|
|
8,649
|
|
|
558
|
|
6
|
%
|
|
8,649
|
|
|
7,921
|
|
|
728
|
|
9
|
%
|
||||||
Commercial
|
|
4,679
|
|
|
4,198
|
|
|
481
|
|
11
|
|
|
4,198
|
|
|
3,921
|
|
|
277
|
|
7
|
|
||||||
Industrial
|
|
1,548
|
|
|
1,470
|
|
|
78
|
|
5
|
|
|
1,470
|
|
|
1,416
|
|
|
54
|
|
4
|
|
||||||
Total retail
|
|
15,434
|
|
|
14,317
|
|
|
1,117
|
|
8
|
|
|
14,317
|
|
|
13,258
|
|
|
1,059
|
|
8
|
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Average number of retail customers (in thousands)
|
|
162
|
|
|
159
|
|
|
3
|
|
2
|
%
|
|
159
|
|
|
156
|
|
|
3
|
|
2
|
%
|
||||||
Average revenue per retail Dth sold:
|
|
$
|
7.13
|
|
|
$
|
9.57
|
|
|
$
|
(2.44
|
)
|
(25
|
)%
|
|
$
|
9.57
|
|
|
$
|
9.43
|
|
|
$
|
0.14
|
|
1
|
%
|
Average cost of natural gas per retail Dth sold
|
|
$
|
3.56
|
|
|
$
|
5.87
|
|
|
$
|
(2.31
|
)
|
(39
|
)%
|
|
$
|
5.87
|
|
|
$
|
5.73
|
|
|
$
|
0.14
|
|
2
|
%
|
Heating degree days
|
|
4,185
|
|
|
4,122
|
|
|
63
|
|
2
|
%
|
|
4,122
|
|
|
3,910
|
|
|
212
|
|
5
|
%
|
•
|
$4 million in higher energy efficiency program rate revenue, which is offset in operating and maintenance expense;
|
•
|
$3 million in higher customer growth; and
|
•
|
$2 million in higher customer usage primarily due to the impacts of weather.
|
•
|
$4 million related to a settlement payment associated with terminated transmission service in 2015;
|
•
|
$2 million decrease in wholesale demand charges; and
|
•
|
$2 million in usage patterns for commercial and industrial customers.
|
•
|
$9 million from recovery of costs associated with advanced service delivery;
|
•
|
$5 million in higher energy efficiency program rate revenue, which is offset in operating and maintenance expense; and
|
•
|
$4 million related to a settlement payment associated with terminated transmission service.
|
Cash and cash equivalents
|
|
$
|
55
|
|
|
|
|
||
Credit facilities
(1)
|
|
250
|
|
|
Less -
|
|
|
||
Letters of credit and tax-exempt bond support
|
|
(80
|
)
|
|
Net credit facilities
|
|
170
|
|
|
|
|
|
||
Total net liquidity
|
|
$
|
225
|
|
Credit facilities:
|
|
|
||
Maturity dates
|
|
2018
|
|
(1)
|
Refer to Note
6
of Notes to Consolidated Financial Statements in Item 8 of this Form 10
-
K for further discussion regarding
Sierra Pacific
's credit facility.
|
|
Historical
|
|
Forecasted
|
||||||||||||||||||||
|
2014
|
|
2015
|
|
2016
|
|
2017
|
|
2018
|
|
2019
|
||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Generation development
|
$
|
51
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
Distribution
|
89
|
|
|
86
|
|
|
115
|
|
|
101
|
|
|
74
|
|
|
73
|
|
||||||
Transmission system investment
|
19
|
|
|
38
|
|
|
12
|
|
|
20
|
|
|
44
|
|
|
24
|
|
||||||
Other
|
27
|
|
|
128
|
|
|
67
|
|
|
43
|
|
|
46
|
|
|
53
|
|
||||||
Total
|
$
|
186
|
|
|
$
|
252
|
|
|
$
|
194
|
|
|
$
|
164
|
|
|
$
|
164
|
|
|
$
|
150
|
|
|
Payments Due by Periods
|
||||||||||||||||||
|
2017
|
|
2018 - 2019
|
|
2020 - 2021
|
|
2022 and Thereafter
|
|
Total
|
||||||||||
Long-term debt
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
1,121
|
|
|
$
|
1,121
|
|
Interest payments on long-term debt
(1)
|
40
|
|
|
79
|
|
|
79
|
|
|
379
|
|
|
577
|
|
|||||
Capital leases, including interest
(2)
|
2
|
|
|
4
|
|
|
2
|
|
|
10
|
|
|
18
|
|
|||||
ON Line financial lease, including interest
(2)
|
2
|
|
|
4
|
|
|
5
|
|
|
40
|
|
|
51
|
|
|||||
Fuel and capacity contract commitments
(1)
|
238
|
|
|
259
|
|
|
133
|
|
|
375
|
|
|
1,005
|
|
|||||
Fuel and capacity contract commitments (not commercially operable)
(1)
|
5
|
|
|
20
|
|
|
22
|
|
|
215
|
|
|
262
|
|
|||||
Operating leases and easements
(1)
|
4
|
|
|
7
|
|
|
6
|
|
|
46
|
|
|
63
|
|
|||||
Asset retirement obligations
|
—
|
|
|
—
|
|
|
—
|
|
|
14
|
|
|
14
|
|
|||||
Maintenance, service and other contracts
(1)
|
4
|
|
|
9
|
|
|
12
|
|
|
17
|
|
|
42
|
|
|||||
Total contractual cash obligations
|
$
|
295
|
|
|
$
|
382
|
|
|
$
|
259
|
|
|
$
|
2,217
|
|
|
$
|
3,153
|
|
(1)
|
Not reflected on the Consolidated Balance Sheets.
|
(2)
|
Interest is not reflected on the Consolidated Balance Sheets.
|
/s/
|
Deloitte & Touche LLP
|
|
As of December 31,
|
||||||
|
2016
|
|
2015
|
||||
ASSETS
|
|||||||
|
|
|
|
||||
Current assets:
|
|
|
|
||||
Cash and cash equivalents
|
$
|
55
|
|
|
$
|
106
|
|
Accounts receivable, net
|
117
|
|
|
124
|
|
||
Inventories
|
45
|
|
|
39
|
|
||
Regulatory assets
|
25
|
|
|
—
|
|
||
Other current assets
|
13
|
|
|
13
|
|
||
Total current assets
|
255
|
|
|
282
|
|
||
|
|
|
|
||||
Property, plant and equipment, net
|
2,822
|
|
|
2,766
|
|
||
Regulatory assets
|
410
|
|
|
432
|
|
||
Other assets
|
6
|
|
|
7
|
|
||
|
|
|
|
||||
Total assets
|
$
|
3,493
|
|
|
$
|
3,487
|
|
|
|
|
|
||||
LIABILITIES AND SHAREHOLDER'S EQUITY
|
|||||||
Current liabilities:
|
|
|
|
||||
Accounts payable
|
$
|
146
|
|
|
$
|
127
|
|
Accrued interest
|
14
|
|
|
15
|
|
||
Accrued property, income and other taxes
|
10
|
|
|
13
|
|
||
Regulatory liabilities
|
69
|
|
|
78
|
|
||
Current portion of long-term debt and financial and capital lease obligations
|
1
|
|
|
453
|
|
||
Customer deposits
|
16
|
|
|
17
|
|
||
Other current liabilities
|
12
|
|
|
11
|
|
||
Total current liabilities
|
268
|
|
|
714
|
|
||
|
|
|
|
||||
Long-term debt and financial and capital lease obligations
|
1,152
|
|
|
749
|
|
||
Regulatory liabilities
|
221
|
|
|
230
|
|
||
Deferred income taxes
|
617
|
|
|
570
|
|
||
Other long-term liabilities
|
127
|
|
|
148
|
|
||
Total liabilities
|
2,385
|
|
|
2,411
|
|
||
|
|
|
|
||||
Commitments and contingencies (Note 13)
|
|
|
|
||||
|
|
|
|
||||
Shareholder's equity:
|
|
|
|
||||
Common stock - $3.75 stated value, 20,000,000 shares authorized and 1,000 issued and outstanding
|
—
|
|
|
—
|
|
||
Other paid-in capital
|
1,111
|
|
|
1,111
|
|
||
Accumulated deficit
|
(2
|
)
|
|
(35
|
)
|
||
Accumulated other comprehensive loss, net
|
(1
|
)
|
|
—
|
|
||
Total shareholder's equity
|
1,108
|
|
|
1,076
|
|
||
|
|
|
|
||||
Total liabilities and shareholder's equity
|
$
|
3,493
|
|
|
$
|
3,487
|
|
|
|
|
|
||||
The accompanying notes are an integral part of the consolidated financial statements.
|
|
Years Ended December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Operating revenue:
|
|
|
|
|
|
||||||
Electric
|
$
|
702
|
|
|
$
|
810
|
|
|
$
|
779
|
|
Natural gas
|
110
|
|
|
137
|
|
|
125
|
|
|||
Total operating revenue
|
812
|
|
|
947
|
|
|
904
|
|
|||
|
|
|
|
|
|
||||||
Operating costs and expenses:
|
|
|
|
|
|
||||||
Cost of fuel, energy and capacity
|
265
|
|
|
374
|
|
|
361
|
|
|||
Natural gas purchased for resale
|
55
|
|
|
84
|
|
|
76
|
|
|||
Operating and maintenance
|
170
|
|
|
167
|
|
|
162
|
|
|||
Depreciation and amortization
|
118
|
|
|
113
|
|
|
105
|
|
|||
Property and other taxes
|
24
|
|
|
25
|
|
|
22
|
|
|||
Total operating costs and expenses
|
632
|
|
|
763
|
|
|
726
|
|
|||
|
|
|
|
|
|
||||||
Operating income
|
180
|
|
|
184
|
|
|
178
|
|
|||
|
|
|
|
|
|
||||||
Other income (expense):
|
|
|
|
|
|
||||||
Interest expense
|
(54
|
)
|
|
(61
|
)
|
|
(61
|
)
|
|||
Allowance for borrowed funds
|
4
|
|
|
2
|
|
|
2
|
|
|||
Allowance for equity funds
|
(1
|
)
|
|
2
|
|
|
3
|
|
|||
Other, net
|
4
|
|
|
3
|
|
|
12
|
|
|||
Total other income (expense)
|
(47
|
)
|
|
(54
|
)
|
|
(44
|
)
|
|||
|
|
|
|
|
|
||||||
Income before income tax expense
|
133
|
|
|
130
|
|
|
134
|
|
|||
Income tax expense
|
49
|
|
|
47
|
|
|
47
|
|
|||
Net income
|
$
|
84
|
|
|
$
|
83
|
|
|
$
|
87
|
|
|
|
|
|
|
|
||||||
The accompanying notes are an integral part of these consolidated financial statements.
|
|
|
|
|
|
|
|
|
|
|
Accumulated
|
|
|
|||||||||||
|
|
|
|
|
|
Other
|
|
|
|
Other
|
|
Total
|
|||||||||||
|
|
Common Stock
|
|
Paid-in
|
|
Accumulated
|
|
Comprehensive
|
|
Shareholder's
|
|||||||||||||
|
|
Shares
|
|
Amount
|
|
Capital
|
|
Deficit
|
|
Loss, Net
|
|
Equity
|
|||||||||||
Balance, December 31, 2013
|
|
1,000
|
|
|
$
|
—
|
|
|
$
|
1,111
|
|
|
$
|
(93
|
)
|
|
$
|
(2
|
)
|
|
$
|
1,016
|
|
Net income
|
|
—
|
|
|
—
|
|
|
—
|
|
|
87
|
|
|
—
|
|
|
87
|
|
|||||
Dividends declared
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(105
|
)
|
|
—
|
|
|
(105
|
)
|
|||||
Other equity transactions
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|||||
Balance, December 31, 2014
|
|
1,000
|
|
|
—
|
|
|
1,111
|
|
|
(111
|
)
|
|
(2
|
)
|
|
998
|
|
|||||
Net income
|
|
—
|
|
|
—
|
|
|
—
|
|
|
83
|
|
|
—
|
|
|
83
|
|
|||||
Dividends declared
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(7
|
)
|
|
—
|
|
|
(7
|
)
|
|||||
Other equity transactions
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
2
|
|
|
2
|
|
|||||
Balance, December 31, 2015
|
|
1,000
|
|
|
—
|
|
|
1,111
|
|
|
(35
|
)
|
|
—
|
|
|
1,076
|
|
|||||
Net income
|
|
—
|
|
|
—
|
|
|
—
|
|
|
84
|
|
|
—
|
|
|
84
|
|
|||||
Dividends declared
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(51
|
)
|
|
—
|
|
|
(51
|
)
|
|||||
Other equity transactions
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(1
|
)
|
|
(1
|
)
|
|||||
Balance, December 31, 2016
|
|
1,000
|
|
|
$
|
—
|
|
|
$
|
1,111
|
|
|
$
|
(2
|
)
|
|
$
|
(1
|
)
|
|
$
|
1,108
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
The accompanying notes are an integral part of these consolidated financial statements.
|
|
Years Ended December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Cash flows from operating activities:
|
|
|
|
|
|
||||||
Net income
|
$
|
84
|
|
|
$
|
83
|
|
|
$
|
87
|
|
Adjustments to reconcile net income to net cash flows from operating activities:
|
|
|
|
|
|
||||||
Loss on nonrecurring items
|
5
|
|
|
—
|
|
|
14
|
|
|||
Depreciation and amortization
|
118
|
|
|
113
|
|
|
105
|
|
|||
Allowance for equity funds
|
1
|
|
|
(2
|
)
|
|
(3
|
)
|
|||
Deferred income taxes and amortization of investment tax credits
|
49
|
|
|
47
|
|
|
47
|
|
|||
Changes in regulatory assets and liabilities
|
(17
|
)
|
|
(21
|
)
|
|
(23
|
)
|
|||
Deferred energy
|
53
|
|
|
81
|
|
|
(30
|
)
|
|||
Amortization of deferred energy
|
(54
|
)
|
|
17
|
|
|
19
|
|
|||
Other, net
|
—
|
|
|
(9
|
)
|
|
20
|
|
|||
Changes in other operating assets and liabilities:
|
|
|
|
|
|
||||||
Accounts receivable and other assets
|
7
|
|
|
15
|
|
|
28
|
|
|||
Inventories
|
(6
|
)
|
|
1
|
|
|
3
|
|
|||
Accrued property, income and other taxes
|
(3
|
)
|
|
—
|
|
|
—
|
|
|||
Accounts payable and other liabilities
|
6
|
|
|
17
|
|
|
(21
|
)
|
|||
Net cash flows from operating activities
|
243
|
|
|
342
|
|
|
246
|
|
|||
|
|
|
|
|
|
||||||
Cash flows from investing activities:
|
|
|
|
|
|
||||||
Capital expenditures
|
(194
|
)
|
|
(252
|
)
|
|
(186
|
)
|
|||
Other, net
|
—
|
|
|
2
|
|
|
—
|
|
|||
Net cash flows from investing activities
|
(194
|
)
|
|
(250
|
)
|
|
(186
|
)
|
|||
|
|
|
|
|
|
||||||
Cash flows from financing activities:
|
|
|
|
|
|
||||||
Proceeds from issuance of long-term debt
|
1,089
|
|
|
—
|
|
|
—
|
|
|||
Repayments of long-term debt and financial and capital lease obligations
|
(1,138
|
)
|
|
(1
|
)
|
|
1
|
|
|||
Dividends paid
|
(51
|
)
|
|
(7
|
)
|
|
(105
|
)
|
|||
Other, net
|
—
|
|
|
—
|
|
|
(1
|
)
|
|||
Net cash flows from financing activities
|
(100
|
)
|
|
(8
|
)
|
|
(105
|
)
|
|||
|
|
|
|
|
|
||||||
Net change in cash and cash equivalents
|
(51
|
)
|
|
84
|
|
|
(45
|
)
|
|||
Cash and cash equivalents at beginning of period
|
106
|
|
|
22
|
|
|
67
|
|
|||
Cash and cash equivalents at end of period
|
$
|
55
|
|
|
$
|
106
|
|
|
$
|
22
|
|
|
|
|
|
|
|
||||||
The accompanying notes are an integral part of these consolidated financial statements.
|
|
2016
|
|
2015
|
|
2014
|
||||||
Beginning balance
|
$
|
1
|
|
|
$
|
2
|
|
|
$
|
1
|
|
Charged to operating costs and expenses, net
|
2
|
|
|
1
|
|
|
2
|
|
|||
Write-offs, net
|
(1
|
)
|
|
(2
|
)
|
|
(1
|
)
|
|||
Ending balance
|
$
|
2
|
|
|
$
|
1
|
|
|
$
|
2
|
|
|
Depreciable Life
|
|
2016
|
|
2015
|
||||
Utility plant:
|
|
|
|
|
|
||||
Electric generation
|
30 - 60 years
|
|
$
|
1,137
|
|
|
$
|
1,134
|
|
Electric distribution
|
20 - 70 years
|
|
1,417
|
|
|
1,382
|
|
||
Electric transmission
|
50 - 70 years
|
|
771
|
|
|
739
|
|
||
Electric general and intangible plant
|
5 - 65 years
|
|
164
|
|
|
139
|
|
||
Natural gas distribution
|
40 - 70 years
|
|
381
|
|
|
374
|
|
||
Natural gas general and intangible plant
|
5 - 60 years
|
|
15
|
|
|
13
|
|
||
Common general
|
5 - 65 years
|
|
267
|
|
|
265
|
|
||
Utility plant
|
|
|
4,152
|
|
|
4,046
|
|
||
Accumulated depreciation and amortization
|
|
|
(1,442
|
)
|
|
(1,368
|
)
|
||
Utility plant, net
|
|
|
2,710
|
|
|
2,678
|
|
||
Other non-regulated, net of accumulated depreciation and amortization
|
60 years
|
|
5
|
|
|
—
|
|
||
Plant, net
|
|
|
2,715
|
|
|
2,678
|
|
||
Construction work-in-progress
|
|
|
107
|
|
|
88
|
|
||
Property, plant and equipment, net
|
|
|
$
|
2,822
|
|
|
$
|
2,766
|
|
|
Sierra
|
|
|
|
|
|
Construction
|
|||||||
|
Pacific's
|
|
Utility
|
|
Accumulated
|
|
Work-in-
|
|||||||
|
Share
|
|
Plant
|
|
Depreciation
|
|
Progress
|
|||||||
|
|
|
|
|
|
|
|
|||||||
Valmy Generating Station
|
50
|
%
|
|
$
|
389
|
|
|
$
|
216
|
|
|
$
|
1
|
|
ON Line Transmission Line
|
1
|
|
|
8
|
|
|
1
|
|
|
—
|
|
|||
Valmy Transmission
|
50
|
|
|
4
|
|
|
2
|
|
|
—
|
|
|||
Total
|
|
|
$
|
401
|
|
|
$
|
219
|
|
|
$
|
1
|
|
|
Weighted
|
|
|
|
|
||||
|
Average
|
|
|
|
|
||||
|
Remaining Life
|
|
2016
|
|
2015
|
||||
|
|
|
|
|
|
||||
Employee benefit plans
(1)
|
10 years
|
|
$
|
128
|
|
|
$
|
126
|
|
Deferred income taxes
(2)
|
27 years
|
|
85
|
|
|
90
|
|
||
Merger costs from 1999 merger
|
30 years
|
|
80
|
|
|
83
|
|
||
Abandoned projects
|
9 years
|
|
39
|
|
|
44
|
|
||
Renewable energy programs
|
1 year
|
|
25
|
|
|
—
|
|
||
Losses on reacquired debt
|
17 years
|
|
22
|
|
|
22
|
|
||
Other
|
Various
|
|
56
|
|
|
67
|
|
||
Total regulatory assets
|
|
|
$
|
435
|
|
|
$
|
432
|
|
|
|
|
|
|
|
||||
Reflected as:
|
|
|
|
|
|
||||
Current assets
|
|
|
$
|
25
|
|
|
$
|
—
|
|
Other assets
|
|
|
410
|
|
|
432
|
|
||
Total regulatory assets
|
|
|
$
|
435
|
|
|
$
|
432
|
|
(1)
|
Represents amounts not yet recognized as a component of net periodic benefit cost that are expected to be included in regulated rates when recognized.
|
(2)
|
Amounts represent income tax benefits related to accelerated tax depreciation and certain property-related basis differences that were previously flowed through to customers and will be included in regulated rates when the temporary differences reverse.
|
|
Weighted
|
|
|
|
|
||||
|
Average
|
|
|
|
|
||||
|
Remaining Life
|
|
2016
|
|
2015
|
||||
|
|
|
|
|
|
||||
Cost of removal
(1)
|
39 years
|
|
$
|
205
|
|
|
$
|
208
|
|
Deferred energy costs
|
1 year
|
|
64
|
|
|
66
|
|
||
Renewable energy program
|
1 year
|
|
—
|
|
|
8
|
|
||
Other
|
Various
|
|
21
|
|
|
26
|
|
||
Total regulatory liabilities
|
|
|
$
|
290
|
|
|
$
|
308
|
|
|
|
|
|
|
|
||||
Reflected as:
|
|
|
|
|
|
||||
Current liabilities
|
|
|
$
|
69
|
|
|
$
|
78
|
|
Other long-term liabilities
|
|
|
221
|
|
|
230
|
|
||
Total regulatory liabilities
|
|
|
$
|
290
|
|
|
$
|
308
|
|
(1)
|
Amounts represent estimated costs, as accrued through depreciation rates and exclusive of ARO liabilities, of removing regulated property, plant and equipment in accordance with accepted regulatory practices. Amounts are deducted from rate base or otherwise accrue a carrying cost.
|
|
|
2016
|
|
2015
|
||||
Credit facilities
|
|
$
|
250
|
|
|
$
|
250
|
|
Less - Water Facilities Refunding Revenue Bond support
|
|
(80
|
)
|
|
—
|
|
||
Net credit facilities
|
|
$
|
170
|
|
|
$
|
250
|
|
|
Par Value
|
|
2016
|
|
2015
|
||||||
General and refunding mortgage securities:
|
|
|
|
|
|
||||||
6.000% Series M, due 2016
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
450
|
|
3.375% Series T, due 2023
|
250
|
|
|
248
|
|
|
248
|
|
|||
2.600% Series U, due 2026
|
400
|
|
|
395
|
|
|
—
|
|
|||
6.750% Series P, due 2037
|
252
|
|
|
255
|
|
|
255
|
|
|||
Tax-exempt refunding revenue bond obligations:
|
|
|
|
|
|
||||||
Fixed-rate series:
|
|
|
|
|
|
||||||
1.250% Pollution Control Series 2016A, due 2029
(1)
|
20
|
|
|
20
|
|
|
—
|
|
|||
1.500% Gas Facilities Series 2016A, due 2031
(1)
|
58
|
|
|
58
|
|
|
—
|
|
|||
3.000% Gas and Water Series 2016B, due 2036
(2)
|
60
|
|
|
64
|
|
|
—
|
|
|||
Variable-rate series (2016-0.788% to 0.800%, 2015-0.733% to 1.054%):
|
|
|
|
|
|
||||||
Pollution Control Series 2006A, due 2031
|
—
|
|
|
—
|
|
|
58
|
|
|||
Pollution Control Series 2006B, due 2036
|
—
|
|
|
—
|
|
|
74
|
|
|||
Pollution Control Series 2006C, due 2036
|
—
|
|
|
—
|
|
|
80
|
|
|||
Water Facilities Series 2016C, due 2036
|
30
|
|
|
29
|
|
|
—
|
|
|||
Water Facilities Series 2016D, due 2036
|
25
|
|
|
25
|
|
|
—
|
|
|||
Water Facilities Series 2016E, due 2036
|
25
|
|
|
25
|
|
|
—
|
|
|||
Capital and financial lease obligations - 2.700% to 10.130%, due through 2054
|
34
|
|
|
34
|
|
|
37
|
|
|||
Total long-term debt and financial and capital leases
|
$
|
1,154
|
|
|
$
|
1,153
|
|
|
$
|
1,202
|
|
|
|
|
|
|
|
||||||
Reflected as:
|
|
|
|
|
|
||||||
Current portion of long-term debt and financial and capital lease obligations
|
|
|
$
|
1
|
|
|
$
|
453
|
|
||
Long-term debt and financial and capital lease obligations
|
|
|
1,152
|
|
|
749
|
|
||||
Total long-term debt and financial and capital leases
|
|
|
$
|
1,153
|
|
|
$
|
1,202
|
|
(1)
|
Subject to mandatory purchase by Sierra Pacific in June 2019 at which date the interest rate may be adjusted from time to time.
|
(2)
|
Subject to mandatory purchase by Sierra Pacific in June 2022 at which date the interest rate may be adjusted from time to time.
|
|
|
Long-term
|
|
Capital and Financial
|
|
|
||||||
|
|
Debt
|
|
Lease Obligations
|
|
Total
|
||||||
|
|
|
|
|
|
|
||||||
2017
|
|
$
|
—
|
|
|
$
|
4
|
|
|
$
|
4
|
|
2018
|
|
—
|
|
|
4
|
|
|
4
|
|
|||
2019
|
|
—
|
|
|
4
|
|
|
4
|
|
|||
2020
|
|
—
|
|
|
4
|
|
|
4
|
|
|||
2021
|
|
—
|
|
|
3
|
|
|
3
|
|
|||
Thereafter
|
|
1,120
|
|
|
50
|
|
|
1,170
|
|
|||
Total
|
|
1,120
|
|
|
69
|
|
|
1,189
|
|
|||
Unamortized premium, discount and debt issuance cost
|
|
(1
|
)
|
|
—
|
|
|
(1
|
)
|
|||
Amounts representing interest
|
|
—
|
|
|
(35
|
)
|
|
(35
|
)
|
|||
Total
|
|
$
|
1,119
|
|
|
$
|
34
|
|
|
$
|
1,153
|
|
•
|
Sierra Pacific
has master leasing agreements of which various pieces of equipment qualify as capital leases. The remaining equipment is treated as operating leases. Lease terms average
seven
years under the master lease agreement. Capital assets of
$3 million
were included in property, plant and equipment, net as of
December 31
,
2016
and
2015
.
|
•
|
ON Line was placed in-service on December 31, 2013. The Nevada Utilities entered into a long-term transmission use agreement, in which the Nevada Utilities have
25%
interest and Great Basin Transmission South, LLC has
75%
interest. Refer to Note
4
for additional information. The Nevada Utilities share of the long-term transmission use agreement and ownership interest is split at
5%
for
Sierra Pacific
and
95%
for Nevada Power. The term is for
41
years with the agreement ending December 31, 2054. Payments began on January 31, 2014. ON Line assets of
$21 million
and
$22 million
were included in property, plant and equipment, net as of
December 31
,
2016
and
2015
, respectively.
|
•
|
In 2015,
Sierra Pacific
entered into a
20
-year capital lease for the Fort Churchill Solar Array. Capital assets of
$10 million
and
$12 million
were included in property, plant and equipment, net as of
December 31
,
2016
and
2015
, respectively.
|
(
8
)
|
Fair Value Measurements
|
•
|
Level 1 - Inputs are unadjusted quoted prices in active markets for identical assets or liabilities that
Sierra Pacific
has the ability to access at the measurement date.
|
•
|
Level 2 - Inputs include quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, inputs other than quoted prices that are observable for the asset or liability and inputs that are derived principally from or corroborated by observable market data by correlation or other means (market corroborated inputs).
|
•
|
Level 3 - Unobservable inputs reflect
Sierra Pacific
's judgments about the assumptions market participants would use in pricing the asset or liability since limited market data exists.
Sierra Pacific
develops these inputs based on the best information available, including its own data.
|
|
Input Levels for Fair Value Measurements
|
|
|
||||||||||||
|
Level 1
|
|
Level 2
|
|
Level 3
|
|
Total
|
||||||||
As of December 31, 2016:
|
|
|
|
|
|
|
|
||||||||
Assets:
|
|
|
|
|
|
|
|
||||||||
Money market mutual funds
(1)
|
$
|
35
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
35
|
|
Investment funds
|
1
|
|
|
—
|
|
|
—
|
|
|
1
|
|
||||
|
$
|
36
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
36
|
|
|
|
|
|
|
|
|
|
||||||||
As of December 31, 2015:
|
|
|
|
|
|
|
|
||||||||
Assets - investment funds
|
$
|
1
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
1
|
|
|
|
|
|
|
|
|
|
||||||||
Liabilities - commodity derivatives
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
(1
|
)
|
|
$
|
(1
|
)
|
(1)
|
Amounts are included in cash and cash equivalents on the Consolidated Balance Sheets. The fair value of these money market mutual funds approximates cost.
|
(
9
)
|
Income Taxes
|
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Deferred - Federal
|
$
|
50
|
|
|
$
|
48
|
|
|
$
|
48
|
|
Investment tax credits
|
(1
|
)
|
|
(1
|
)
|
|
(1
|
)
|
|||
Total income tax expense
|
$
|
49
|
|
|
$
|
47
|
|
|
$
|
47
|
|
|
2016
|
|
2015
|
|
2014
|
|||
|
|
|
|
|
|
|||
Federal statutory income tax rate
|
35
|
%
|
|
35
|
%
|
|
35
|
%
|
Effects of ratemaking
|
1
|
|
|
1
|
|
|
1
|
|
Other
|
1
|
|
|
—
|
|
|
(1
|
)
|
Effective income tax rate
|
37
|
%
|
|
36
|
%
|
|
35
|
%
|
|
2016
|
|
2015
|
||||
Deferred income tax assets:
|
|
|
|
||||
Federal net operating loss and credit carryforwards
|
$
|
25
|
|
|
$
|
39
|
|
Employee benefit plans
|
22
|
|
|
25
|
|
||
Regulatory liabilities
|
16
|
|
|
19
|
|
||
Capital and financial lease liabilities
|
12
|
|
|
13
|
|
||
Customer Advances
|
9
|
|
|
8
|
|
||
Commodity derivative contract
|
5
|
|
|
5
|
|
||
Other
|
6
|
|
|
7
|
|
||
Total deferred income tax assets
|
$
|
95
|
|
|
$
|
116
|
|
|
|
|
|
||||
Deferred income tax liabilities:
|
|
|
|
||||
Property related items
|
$
|
(562
|
)
|
|
$
|
(538
|
)
|
Regulatory assets
|
(124
|
)
|
|
(121
|
)
|
||
Capital and financial leases
|
(12
|
)
|
|
(13
|
)
|
||
Other
|
(14
|
)
|
|
(14
|
)
|
||
Total deferred income tax liabilities
|
$
|
(712
|
)
|
|
$
|
(686
|
)
|
Net deferred income tax liability
|
$
|
(617
|
)
|
|
$
|
(570
|
)
|
Net operating loss carryforwards
|
$
|
55
|
|
Deferred income taxes on federal net operating loss carryforwards
|
$
|
19
|
|
Expiration dates
|
2031 - 2033
|
||
|
|
||
Other tax credits
|
$
|
6
|
|
Expiration dates
|
2021 - 2032
|
|
2016
|
|
2015
|
||||
Qualified Pension Plan -
|
|
|
|
||||
Other long-term liabilities
|
$
|
(12
|
)
|
|
$
|
(29
|
)
|
|
|
|
|
||||
Non-Qualified Pension Plans:
|
|
|
|
||||
Other current liabilities
|
(1
|
)
|
|
(1
|
)
|
||
Other long-term liabilities
|
(9
|
)
|
|
(9
|
)
|
||
|
|
|
|
||||
Other Postretirement Plans -
|
|
|
|
||||
Other long-term liabilities
|
(28
|
)
|
|
(32
|
)
|
|
2016
|
|
2015
|
||||
|
|
|
|
||||
Asbestos
|
$
|
4
|
|
|
$
|
4
|
|
Evaporative ponds and dry ash landfills
|
3
|
|
|
3
|
|
||
Other
|
3
|
|
|
3
|
|
||
Total asset retirement obligations
|
$
|
10
|
|
|
$
|
10
|
|
|
2016
|
|
2015
|
||||
|
|
|
|
||||
Beginning balance
|
$
|
10
|
|
|
$
|
11
|
|
Retirements
|
—
|
|
|
(1
|
)
|
||
Ending balance
|
$
|
10
|
|
|
$
|
10
|
|
|
|
|
|
||||
Reflected as:
|
|
|
|
||||
Other current liabilities
|
$
|
—
|
|
|
$
|
—
|
|
Other long-term liabilities
|
10
|
|
|
10
|
|
||
|
$
|
10
|
|
|
$
|
10
|
|
(
13
)
|
Commitments and Contingencies
|
|
|
|
|
|
|
|
|
|
|
|
2022 and
|
|
|
||||||||||||||
|
2017
|
|
2018
|
|
2019
|
|
2020
|
|
2021
|
|
Thereafter
|
|
Total
|
||||||||||||||
Contract type:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||
Fuel, capacity and transmission contract commitments
|
$
|
238
|
|
|
$
|
156
|
|
|
$
|
103
|
|
|
$
|
71
|
|
|
$
|
62
|
|
|
$
|
375
|
|
|
$
|
1,005
|
|
Fuel and capacity contract commitments (not commercially operable)
|
5
|
|
|
10
|
|
|
10
|
|
|
11
|
|
|
11
|
|
|
215
|
|
|
262
|
|
|||||||
Operating leases and easements
|
4
|
|
|
4
|
|
|
3
|
|
|
3
|
|
|
3
|
|
|
46
|
|
|
63
|
|
|||||||
Maintenance, service and other contracts
|
4
|
|
|
5
|
|
|
4
|
|
|
6
|
|
|
6
|
|
|
17
|
|
|
42
|
|
|||||||
Total commitments
|
$
|
251
|
|
|
$
|
175
|
|
|
$
|
120
|
|
|
$
|
91
|
|
|
$
|
82
|
|
|
$
|
653
|
|
|
$
|
1,372
|
|
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Supplemental disclosure of cash flow information -
|
|
|
|
|
|
||||||
Interest paid, net of amounts capitalized
|
$
|
47
|
|
|
$
|
54
|
|
|
$
|
54
|
|
|
|
|
|
|
|
||||||
Supplemental disclosure of non-cash investing and financing transactions:
|
|
|
|
|
|
||||||
Accruals related to property, plant and equipment additions
|
$
|
15
|
|
|
$
|
24
|
|
|
$
|
31
|
|
Capital and financial lease obligations incurred
|
$
|
—
|
|
|
$
|
13
|
|
|
$
|
1
|
|
|
|
Years Ended December 31,
|
||||||||||
|
|
2016
|
|
2015
|
|
2014
|
||||||
Operating revenue:
|
|
|
|
|
|
|
||||||
Regulated electric
|
|
$
|
702
|
|
|
$
|
810
|
|
|
$
|
779
|
|
Regulated gas
|
|
110
|
|
|
137
|
|
|
125
|
|
|||
Total operating revenue
|
|
$
|
812
|
|
|
$
|
947
|
|
|
$
|
904
|
|
|
|
|
|
|
|
|
||||||
Cost of sales:
|
|
|
|
|
|
|
||||||
Regulated electric
|
|
$
|
265
|
|
|
$
|
374
|
|
|
$
|
361
|
|
Regulated gas
|
|
55
|
|
|
84
|
|
|
76
|
|
|||
Total cost of sales
|
|
$
|
320
|
|
|
$
|
458
|
|
|
$
|
437
|
|
|
|
|
|
|
|
|
||||||
Gross margin:
|
|
|
|
|
|
|
||||||
Regulated electric
|
|
$
|
437
|
|
|
$
|
436
|
|
|
$
|
418
|
|
Regulated gas
|
|
55
|
|
|
53
|
|
|
49
|
|
|||
Total gross margin
|
|
$
|
492
|
|
|
$
|
489
|
|
|
$
|
467
|
|
|
|
|
|
|
|
|
||||||
Operating and maintenance:
|
|
|
|
|
|
|
||||||
Regulated electric
|
|
$
|
153
|
|
|
$
|
149
|
|
|
$
|
143
|
|
Regulated gas
|
|
17
|
|
|
18
|
|
|
19
|
|
|||
Total operating and maintenance
|
|
$
|
170
|
|
|
$
|
167
|
|
|
$
|
162
|
|
|
|
|
|
|
|
|
||||||
Depreciation and amortization:
|
|
|
|
|
|
|
||||||
Regulated electric
|
|
$
|
101
|
|
|
$
|
96
|
|
|
$
|
90
|
|
Regulated gas
|
|
17
|
|
|
17
|
|
|
15
|
|
|||
Total depreciation and amortization
|
|
$
|
118
|
|
|
$
|
113
|
|
|
$
|
105
|
|
|
|
|
|
|
|
|
||||||
Operating income:
|
|
|
|
|
|
|
||||||
Regulated electric
|
|
$
|
161
|
|
|
$
|
168
|
|
|
$
|
165
|
|
Regulated gas
|
|
19
|
|
|
16
|
|
|
13
|
|
|||
Total operating income
|
|
$
|
180
|
|
|
$
|
184
|
|
|
$
|
178
|
|
|
|
|
|
|
|
|
||||||
Interest expense:
|
|
|
|
|
|
|
||||||
Regulated electric
|
|
$
|
49
|
|
|
$
|
56
|
|
|
$
|
57
|
|
Regulated gas
|
|
5
|
|
|
5
|
|
|
4
|
|
|||
Total interest expense
|
|
$
|
54
|
|
|
$
|
61
|
|
|
$
|
61
|
|
|
|
|
|
|
|
|
||||||
Income tax expense:
|
|
|
|
|
|
|
||||||
Regulated electric
|
|
$
|
44
|
|
|
$
|
43
|
|
|
$
|
43
|
|
Regulated gas
|
|
5
|
|
|
4
|
|
|
4
|
|
|||
Total income tax expense
|
|
$
|
49
|
|
|
$
|
47
|
|
|
$
|
47
|
|
|
|
Years Ended December 31,
|
||||||||||
|
|
2016
|
|
2015
|
|
2014
|
||||||
Capital expenditures:
|
|
|
|
|
|
|
||||||
Regulated electric
|
|
$
|
176
|
|
|
$
|
229
|
|
|
$
|
168
|
|
Regulated gas
|
|
18
|
|
|
23
|
|
|
18
|
|
|||
Total capital expenditures
|
|
$
|
194
|
|
|
$
|
252
|
|
|
$
|
186
|
|
|
|
|
|
|
|
|
||||||
|
|
As of December 31,
|
||||||||||
Total assets:
|
|
2016
|
|
2015
|
|
2014
|
||||||
Regulated electric
|
|
$
|
3,119
|
|
|
$
|
3,060
|
|
|
$
|
2,984
|
|
Regulated gas
|
|
314
|
|
|
316
|
|
|
322
|
|
|||
Regulated common assets
(1)
|
|
60
|
|
|
111
|
|
|
30
|
|
|||
Total assets
|
|
$
|
3,493
|
|
|
$
|
3,487
|
|
|
$
|
3,336
|
|
(1)
|
Consists principally of cash and cash equivalents not included in either the regulated electric or regulated natural gas segments.
|
|
Three-Month Periods Ended
|
||||||||||||||
|
March 31,
|
|
June 30,
|
|
September 30,
|
|
December 31,
|
||||||||
|
2016
|
|
2016
|
|
2016
|
|
2016
|
||||||||
Regulated electric operating revenue
|
$
|
170
|
|
|
$
|
162
|
|
|
$
|
207
|
|
|
$
|
163
|
|
Regulated natural gas operating revenue
|
47
|
|
|
19
|
|
|
15
|
|
|
29
|
|
||||
Operating income
|
41
|
|
|
28
|
|
|
69
|
|
|
42
|
|
||||
Net income
|
17
|
|
|
10
|
|
|
38
|
|
|
19
|
|
||||
|
|
|
|
|
|
|
|
||||||||
|
Three-Month Periods Ended
|
||||||||||||||
|
March 31,
|
|
June 30,
|
|
September 30,
|
|
December 31,
|
||||||||
|
2015
|
|
2015
|
|
2015
|
|
2015
|
||||||||
Regulated electric operating revenue
|
$
|
196
|
|
|
$
|
201
|
|
|
$
|
228
|
|
|
$
|
185
|
|
Regulated natural gas operating revenue
|
50
|
|
|
26
|
|
|
18
|
|
|
43
|
|
||||
Operating income
|
43
|
|
|
37
|
|
|
66
|
|
|
38
|
|
||||
Net income
|
19
|
|
|
16
|
|
|
33
|
|
|
15
|
|
Item 9A.
|
Controls and Procedures
|
Berkshire Hathaway Energy Company
|
|
PacifiCorp
|
|
MidAmerican Funding, LLC
|
February 24, 2017
|
|
February 24, 2017
|
|
February 24, 2017
|
|
|
|
|
|
MidAmerican Energy Company
|
|
Nevada Power Company
|
|
Sierra Pacific Power Company
|
February 24, 2017
|
|
February 24, 2017
|
|
February 24, 2017
|
Item 9B.
|
Other Information
|
Item 10.
|
Directors, Executive Officers and Corporate Governance
|
Item 11.
|
Executive Compensation
|
|
|
|
|
|
|
|
|
|
|
Change in
|
|
|
|
|
|||||||||||
|
|
|
|
|
|
|
|
|
|
Pension
|
|
|
|
|
|||||||||||
|
|
|
|
|
|
|
|
|
|
Value and
|
|
|
|
|
|||||||||||
|
|
|
|
|
|
|
|
Non-Equity
|
|
Nonqualified
|
|
|
|
|
|||||||||||
Name and
|
|
|
|
|
|
|
|
Incentive
|
|
Deferred
|
|
All
|
|
|
|||||||||||
Principal
|
|
|
|
Base
|
|
|
|
Plan
|
|
Compensation
|
|
Other
|
|
|
|||||||||||
Position
|
|
Year
|
|
Salary
|
|
Bonus
(1)
|
|
Compensation
|
|
Earnings
(2)
|
|
Compensation
(3)
|
|
Total
(4)
|
|||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
Gregory E. Abel, Chairman, President
|
|
2016
|
|
$
|
1,000,000
|
|
|
$
|
15,000,000
|
|
|
$
|
—
|
|
|
$
|
1,377,000
|
|
|
$
|
141,227
|
|
|
17,518,227
|
|
and Chief Executive Officer
|
|
2015
|
|
1,000,000
|
|
|
11,500,000
|
|
|
28,000,000
|
|
|
—
|
|
|
267,944
|
|
|
40,767,944
|
|
|||||
|
|
2014
|
|
1,000,000
|
|
|
11,500,000
|
|
|
12,000,000
|
|
|
2,625,000
|
|
|
450,612
|
|
|
27,575,612
|
|
|||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
Patrick J. Goodman, Executive Vice
|
|
2016
|
|
470,000
|
|
|
2,076,308
|
|
|
—
|
|
|
756,000
|
|
|
47,035
|
|
|
3,349,343
|
|
|||||
President and Chief Financial
|
|
2015
|
|
460,000
|
|
|
1,672,101
|
|
|
—
|
|
|
—
|
|
|
57,451
|
|
|
2,189,552
|
|
|||||
Officer
|
|
2014
|
|
450,000
|
|
|
1,717,600
|
|
|
—
|
|
|
1,146,000
|
|
|
46,413
|
|
|
3,360,013
|
|
|||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
Natalie L. Hocken, Senior Vice
|
|
2016
|
|
410,000
|
|
|
1,286,748
|
|
|
—
|
|
|
7,000
|
|
|
30,498
|
|
|
1,734,246
|
|
|||||
President and General Counsel
(5)
|
|
2015
|
|
313,636
|
|
|
810,090
|
|
|
—
|
|
|
—
|
|
|
30,339
|
|
|
1,154,065
|
|
(1)
|
Consists of annual cash incentive awards earned pursuant to the PIP for
BHE
's NEOs, performance awards earned related to non-routine projects, and the vesting of LTIP awards and associated vested earnings. The breakout for
2016
is as follows:
|
|
|
|
|
|
|
LTIP
|
||||||||||||||
|
|
|
|
Performance
|
|
Vested
|
|
Vested
|
|
|
||||||||||
|
|
PIP
|
|
Award
|
|
Awards
|
|
Earnings
|
|
Total
|
||||||||||
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Gregory E. Abel
|
|
$
|
15,000,000
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
Patrick J. Goodman
|
|
500,000
|
|
|
430,000
|
|
|
945,000
|
|
|
201,308
|
|
|
1,146,308
|
|
|||||
Natalie L. Hocken
|
|
375,000
|
|
|
215,000
|
|
|
450,747
|
|
|
246,001
|
|
|
696,748
|
|
Net Income
|
|
Award
|
|
|
|
Less than or equal to net income target goal
|
|
None
|
Exceeds net income target goal
|
|
33.33% of excess
|
(2)
|
Amounts are based upon the aggregate increase in the actuarial present value of all qualified and nonqualified defined benefit plans, which include
BHE
's cash balance and SERP, as applicable. Amounts are computed using assumptions consistent with those used in preparing the related pension disclosures in the Notes to Consolidated Financial Statements of Berkshire Hathaway Energy in Item 8 of this Form 10-K and are as of December 31,
2016
. No participant in
BHE
's DCP earned "above-market" or "preferential" earnings on amounts deferred.
|
(3)
|
Amounts consist of 401(k) contributions
BHE
paid on behalf of the NEOs, as well as perquisites and other personal benefits related to life insurance premiums, the personal use of corporate aircraft and financial planning and tax preparation that
BHE
paid on behalf of Messrs. Abel and Goodman. The personal use of corporate aircraft represents
BHE
's incremental cost of providing this personal benefit determined by applying the percentage of flight hours used for personal use to
BHE
's incremental expenses incurred from operating its corporate aircraft, partially offset by reimbursed costs by the NEO. All other compensation is based upon amounts paid by
BHE
.
|
(4)
|
Any amounts voluntarily deferred by the NEO, if applicable, are included in the appropriate column in the summary compensation table.
|
(5)
|
Ms. Hocken was named Senior Vice President and General Counsel effective July 10, 2015. Ms. Hocken was previously the Senior Vice President, Transmission and System Operations at PacifiCorp, an indirect, wholly owned subsidiary of
BHE
's.
|
|
|
|
|
Number of
|
|
|
|
|
||||
|
|
|
|
years
|
|
Present value
|
|
Payments
|
||||
|
|
|
|
credited
|
|
of accumulated
|
|
during last
|
||||
Name
|
|
Plan name
|
|
service
(1)
|
|
benefit
(2)
|
|
fiscal year
|
||||
|
|
|
|
|
|
|
|
|
||||
Gregory E. Abel
|
|
SERP
|
|
n/a
|
|
$
|
11,648,000
|
|
|
$
|
—
|
|
|
|
MidAmerican Energy Company Retirement Plan
|
|
18 years
|
|
326,000
|
|
|
—
|
|
||
|
|
|
|
|
|
|
|
|
||||
Patrick J. Goodman
|
|
SERP
|
|
22 years
|
|
4,055,000
|
|
|
—
|
|
||
|
|
MidAmerican Energy Company Retirement Plan
|
|
10 years
|
|
195,000
|
|
|
—
|
|
||
|
|
|
|
|
|
|
|
|
||||
Natalie L. Hocken
|
|
PacifiCorp Retirement Plan
|
|
7 years
|
|
102,000
|
|
|
—
|
|
(1)
|
Mr. Goodman's credited years of service, for purposes of the SERP only, includes 18 years of service with
BHE
and four additional years of imputed service from a predecessor company.
|
(2)
|
Amounts are computed using assumptions consistent with those used in preparing the related pension disclosures in Notes to Consolidated Financial Statements of Berkshire Hathaway Energy in Item 8 of this Form 10-K and are as of December 31,
2016
, which is the measurement date for the plans. The present value of accumulated benefits for the SERP was calculated using the following form of payment assumptions: (1) Mr. Abel - a 100% joint and survivor annuity and (2) Mr. Goodman - a 66 2/3% joint and survivor annuity. The present value of accumulated benefits for the MidAmerican Energy Company Retirement Plan was calculated using a 90% lump sum payment and a 10% single life annuity. The present value assumptions used in calculating the present value of accumulated benefits for both the SERP and the MidAmerican Energy Company Retirement Plan were as follows: a cash balance interest crediting rate of 1.44% in
2017
and
2018
and 2.10% thereafter; a cash balance conversion rate of 4.10% in
2016
and thereafter; a discount rate of 4.10%; an expected retirement age of 65; and postretirement mortality and cash balance conversion mortality based on the RP-2014 mortality tables, translated to 2011 using scale MP-2014 and loaded 3% for credibility-weighted experience, with custom RPEC-2016 generational improvements.
|
|
|
|
|
|
|
|
|
|
|
Aggregate
|
||||||||||
|
|
Executive
|
|
Registrant
|
|
Aggregate
|
|
Aggregate
|
|
balance as of
|
||||||||||
|
|
contributions
|
|
contributions
|
|
earnings
|
|
withdrawals/
|
|
December 31,
|
||||||||||
Name
|
|
in 2016
(1)
|
|
in 2016
|
|
in 2016
|
|
distributions
|
|
2016
|
||||||||||
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Gregory E. Abel
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
197,944
|
|
|
$
|
(374,059
|
)
|
|
$
|
2,061,061
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Patrick J. Goodman
|
|
—
|
|
|
—
|
|
|
142,535
|
|
|
—
|
|
|
1,624,365
|
|
|||||
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Natalie L. Hocken
|
|
—
|
|
|
—
|
|
|
115,240
|
|
|
(71,828
|
)
|
|
1,379,287
|
|
(1)
|
Excludes the value of 10,041 shares of
BHE
common stock reserved for issuance to Mr. Abel. Mr. Abel deferred the right to receive the value of these shares pursuant to a legacy nonqualified deferred compensation plan.
|
|
|
Cash
|
|
|
|
Life
|
|
|
|
Benefits
|
|
Excise and
|
||||||||||||
Termination Scenario
|
|
Severance
(1)
|
|
Incentive
|
|
Insurance
(2)
|
|
Pension
(3)
|
|
Continuation
(4)
|
|
Other Taxes
(5)
|
||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Retirement, Voluntary and Involuntary
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
8,452,000
|
|
|
$
|
—
|
|
|
$
|
—
|
|
With Cause
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Involuntary Without Cause, Disability and
|
|
28,500,000
|
|
|
—
|
|
|
—
|
|
|
8,452,000
|
|
|
85,491
|
|
|
—
|
|
||||||
Voluntary With Good Reason
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Death
|
|
28,500,000
|
|
|
—
|
|
|
1,825,824
|
|
|
7,733,000
|
|
|
85,491
|
|
|
—
|
|
(1)
|
The cash severance payments are determined in accordance with Mr. Abel's employment agreement.
|
(2)
|
Life insurance benefits are equal to two times base salary, as of the preceding June 1, less the benefits otherwise payable in all other termination scenarios, which are equal to the total cash value of the policies less cumulative premiums paid by
BHE
.
|
(3)
|
Pension values represent the excess of the present value of benefits payable under each termination scenario over the amount already reflected in the Pension Benefits Table. Mr. Abel's death scenario is based on a 100% joint and survivor with 15-year certain annuity commencing immediately. Mr. Abel's other termination scenarios are based on a 100% joint and survivor annuity commencing immediately.
|
(4)
|
Includes health and welfare, life insurance and financial planning and tax preparation benefits for two years. The health and welfare benefit amounts are estimated using the rates
BHE
currently charges employees terminating employment but electing to continue their medical, dental and vision insurance after termination. These amounts are grossed-up for taxes and then reduced by the amount Mr. Abel would have paid if he had continued his employment. The life insurance benefit amounts are based on the cost of individual policies offering benefits equivalent to
BHE
's group coverage and are grossed-up for taxes. These amounts also assume benefit continuation for the entire two year period, with no offset by another employer.
BHE
will also continue to provide financial planning and tax preparation reimbursement, or the economic equivalent thereof, for two years or pay a lump sum cash amount to keep Mr. Abel in the same economic position on an after-tax basis. The amount included is based on an annual estimated cost using the most recent three-year average annual reimbursement. If it is determined that benefits paid with respect to the extension of medical and dental benefits to Mr. Abel would not be exempt from taxation under the Internal Revenue Code,
BHE
shall pay to Mr. Abel a lump sum cash payment following separation from service to allow him to obtain equivalent medical and dental benefits and which would put him in the same after-tax economic position.
|
(5)
|
As provided in Mr. Abel's employment agreement, should it be deemed under Section 280G of the Internal Revenue Code that termination payments constitute excess parachute payments subject to an excise tax,
BHE
will gross up such payments to cover the excise tax and any additional taxes associated with such gross-up. Based on computations prescribed under Section 280G and related regulations,
BHE
does not believe that any of the termination scenarios are subject to any excise tax.
|
|
|
Cash
|
|
|
|
Life
|
|
|
|
Benefits
|
|
Excise and
|
||||||||||||
Termination Scenario
|
|
Severance
(1)
|
|
Incentive
(2)
|
|
Insurance
(3)
|
|
Pension
(4)
|
|
Continuation
(5)
|
|
Other Taxes
(6)
|
||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Retirement and Voluntary
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
2,077,000
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Involuntary With Cause
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Involuntary Without Cause and Voluntary
|
|
4,360,000
|
|
|
—
|
|
|
—
|
|
|
2,077,000
|
|
|
24,239
|
|
|
—
|
|
||||||
With Good Reason
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Death
|
|
4,360,000
|
|
|
1,747,885
|
|
|
892,388
|
|
|
2,892,000
|
|
|
24,239
|
|
|
—
|
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Disability
|
|
4,360,000
|
|
|
1,747,885
|
|
|
—
|
|
|
3,534,000
|
|
|
24,239
|
|
|
—
|
|
(1)
|
The cash severance payments are determined in accordance with Mr. Goodman's employment agreement.
|
(2)
|
Amounts represent the unvested portion of Mr. Goodman's LTIP account, which becomes 100% vested upon his death or disability.
|
(3)
|
Life insurance benefits are equal to two times base salary, as of the preceding June 1, less the benefits otherwise payable in all other termination scenarios, which are equal to the total cash value of the policies less cumulative premiums paid by
BHE
.
|
(4)
|
Pension values represent the excess of the present value of benefits payable under each termination scenario over the amount already reflected in the Pension Benefits Table. Mr. Goodman's voluntary termination, retirement, involuntary without cause, and change in control termination scenarios are based on a 66 2/3% joint and survivor annuity commencing at age 55 (reductions for termination prior to age 55 and commencement prior to age 65). Mr. Goodman's disability scenario is based on a 66 2/3% joint and survivor annuity commencing at age 55 (no reduction for termination prior to age 55, reduced for commencement prior to age 65). Mr. Goodman's death scenario is based on a 15-year certain only annuity commencing immediately (no reduction for termination prior to age 55 and commencement prior to age 65).
|
(5)
|
Includes health and welfare, life insurance and financial planning and tax preparation benefits for one year. The health and welfare benefit amounts are estimated using the rates
BHE
currently charges employees terminating employment but electing to continue their medical, dental and vision insurance after termination. These amounts are grossed-up for taxes and then reduced by the amount Mr. Goodman would have paid if he had continued his employment. The life insurance benefit amounts are based on the cost of individual policies offering benefits equivalent to
BHE
's group coverage and are grossed-up for taxes. These amounts also assume benefit continuation for the entire one year period, with no offset by another employer.
BHE
will also continue to provide financial planning and tax preparation reimbursement, or the economic equivalent thereof, for one year or pay a lump sum cash amount to keep Mr. Goodman in the same economic position on an after-tax basis. The amount included is based on an annual estimated cost using the most recent three-year average annual reimbursement.
|
(6)
|
As provided in Mr. Goodman's employment agreement, should it be deemed under Section 280G of the Internal Revenue Code that termination payments constitute excess parachute payments subject to an excise tax,
BHE
will gross up such payments to cover the excise tax and any additional taxes associated with such gross-up. Based on computations prescribed under Section 280G and related regulations,
BHE
does not believe that any of the termination scenarios are subject to any excise tax.
|
|
|
Cash
|
|
|
|
Life
|
|
|
|
Benefits
|
|
Excise and
|
||||||||||||
Termination Scenario
|
|
Severance
|
|
Incentive
(1)
|
|
Insurance
|
|
Pension
(2)
|
|
Continuation
|
|
Other Taxes
|
||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Retirement, Voluntary and Involuntary With or
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
6,000
|
|
|
$
|
—
|
|
|
$
|
—
|
|
Without Cause
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Death and Disability
|
|
—
|
|
|
1,055,675
|
|
|
—
|
|
|
6,000
|
|
|
—
|
|
|
—
|
|
(1)
|
Amounts represent the unvested portion of Ms. Hocken's LTIP account, which becomes 100% vested upon her death or disability.
|
(2)
|
Pension values represent the excess of the present value of benefits payable under each termination scenario over the amount already reflected in the Pension Benefits Table.
|
|
|
|
|
|
|
|
|
Change in
|
|
|
|
|
||||||||||
|
|
|
|
|
|
|
|
Pension
|
|
|
|
|
||||||||||
|
|
|
|
|
|
|
|
Value and
|
|
|
|
|
||||||||||
|
|
|
|
|
|
|
|
Nonqualified
|
|
|
|
|
||||||||||
|
|
|
|
|
|
|
|
Deferred
|
|
|
|
|
||||||||||
|
|
|
|
|
|
|
|
Compensation
|
|
All Other
|
|
|
||||||||||
Name and Principal Position
|
|
Year
|
|
Base Salary
|
|
Bonus
(1)
|
|
Earnings
(2)
|
|
Compensation
(3)
|
|
Total
(4)
|
||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Gregory E. Abel
(5)
|
|
2016
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
Chairman and
|
|
2015
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|||||
Chief Executive Officer
|
|
2014
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|||||
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Stefan A. Bird
|
|
2016
|
|
338,000
|
|
|
738,784
|
|
|
629
|
|
|
13,958
|
|
|
1,091,371
|
|
|||||
President and Chief Executive
|
|
2015
|
|
313,275
|
|
|
844,634
|
|
|
13,201
|
|
|
12,614
|
|
|
1,183,724
|
|
|||||
Officer, Pacific Power
|
|
2014
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|||||
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Cindy A. Crane
|
|
2016
|
|
338,000
|
|
|
758,248
|
|
|
35,752
|
|
|
15,841
|
|
|
1,147,841
|
|
|||||
President and Chief Executive
|
|
2015
|
|
324,028
|
|
|
758,656
|
|
|
8,589
|
|
|
13,429
|
|
|
1,104,702
|
|
|||||
Officer, Rocky Mountain Power
|
|
2014
|
|
224,538
|
|
|
580,950
|
|
|
79,542
|
|
|
73,838
|
|
|
958,868
|
|
|||||
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
R. Patrick Reiten
|
|
2016
|
|
344,007
|
|
|
1,058,240
|
|
|
—
|
|
|
26,809
|
|
|
1,429,056
|
|
|||||
President and Chief Executive
|
|
2015
|
|
330,000
|
|
|
898,935
|
|
|
—
|
|
|
25,864
|
|
|
1,254,799
|
|
|||||
Officer, PacifiCorp Transmission
|
|
2014
|
|
320,000
|
|
|
1,167,125
|
|
|
822
|
|
|
25,980
|
|
|
1,513,927
|
|
|||||
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Nikki L. Kobliha
|
|
2016
|
|
203,900
|
|
|
143,004
|
|
|
9,728
|
|
|
29,585
|
|
|
386,217
|
|
|||||
Vice President, Chief Financial Officer, and Treasurer
|
|
2015
|
|
177,384
|
|
|
91,758
|
|
|
—
|
|
|
27,253
|
|
|
296,395
|
|
|||||
|
|
2014
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
(1)
|
Consists of annual cash incentive awards earned pursuant to the AIP for
PacifiCorp
's NEOs, performance awards for Messrs. Bird, Reiten and Crane in recognition of efforts to support
PacifiCorp
's objectives and the vesting of LTIP awards and associated vested earnings. The breakout for
2016
is as follows:
|
|
|
|
|
|
|
LTIP
|
||||||||||||||
|
|
|
|
Performance
|
|
Vested
|
|
Vested
|
|
|
||||||||||
|
|
AIP
|
|
Award
|
|
Awards
|
|
Earnings
|
|
Total
|
||||||||||
Stefan A. Bird
|
|
$
|
304,000
|
|
|
$
|
34,000
|
|
|
$
|
378,722
|
|
|
$
|
22,062
|
|
|
$
|
400,784
|
|
Cindy A. Crane
|
|
304,000
|
|
|
34,000
|
|
|
318,484
|
|
|
101,764
|
|
|
420,248
|
|
|||||
R. Patrick Reiten
|
|
304,000
|
|
|
16,000
|
|
|
477,500
|
|
|
260,739
|
|
|
738,239
|
|
|||||
Nikki L. Kobliha
|
|
121,100
|
|
|
—
|
|
|
21,750
|
|
|
154
|
|
|
21,904
|
|
(2)
|
Amounts are based upon the aggregate increase in the actuarial present value of all qualified and nonqualified defined benefit plans, which includes the Retirement Plan. Refer to the Pension Benefits table below for a discussion of the assumptions used in calculating these amounts. No participant in
PacifiCorp
's nonqualified deferred compensation plans earned "above market" or "preferential" earnings on amounts deferred. Negative amounts for the change in pension value not reported in the Summary Compensation Table are as follows: Mr. Reiten $(651).
|
(3)
|
Amounts consist of PacifiCorp K Plus Employee Savings Plan, or 401(k) Plan, contributions
PacifiCorp
paid on behalf of the NEOs, except for Mr. Bird and Ms. Crane for whom
PacifiCorp
also includes an amount paid to her as a tax gross-up with respect to a personal benefit with a value less than $10,000.
|
(4)
|
Any amounts voluntarily deferred by the NEO, if applicable, are included in the appropriate column in the Summary Compensation Table.
|
(5)
|
Mr. Abel receives no direct compensation from
PacifiCorp
.
PacifiCorp
reimburses BHE for the cost of Mr. Abel's time spent on matters supporting
PacifiCorp
, including compensation paid to him by BHE, pursuant to an intercompany administrative services agreement among BHE and its subsidiaries. Please refer to Berkshire Hathaway Energy's Item 11 in this Annual Report on Form 10‑K for executive compensation information for Mr. Abel.
|
(6)
|
Mr. Reiten resigned as a director and officer of PacifiCorp effective December 31, 2016.
|
|
|
|
|
Number of years of
|
|
Present value of
|
||
Name
|
|
Plan name
|
|
credited service
|
|
accumulated benefits
(1)
|
||
|
|
|
|
|
|
|
||
Gregory E. Abel
|
|
n/a
|
|
n/a
|
|
n/a
|
|
|
Stefan A. Bird
|
|
Retirement
|
|
10 years
|
|
$
|
167,745
|
|
Cindy A. Crane
|
|
Retirement
|
|
21 years
|
|
433,558
|
|
|
R. Patrick Reiten
|
|
Retirement
|
|
2 years
|
|
16,124
|
|
|
Nikki L. Kobliha
|
|
Retirement
|
|
12 years
|
|
105,491
|
|
(1)
|
Amounts are computed using assumptions, other than the expected retirement age, consistent with those used in preparing the related pension disclosures in the Notes to Consolidated Financial Statements of PacifiCorp in Item 8 of this Form 10-K and are as of December 31,
2016
, which is the measurement date for the plans. The expected retirement age assumption has been determined in accordance with Instruction 2 to Item 402(h)(2) of Regulation S-K. For the Retirement Plan calculations of the present value of accumulated benefits, the following assumptions were used: 50% lump sum payment; 35% joint and 100% survivor annuity; and 15% single life annuity. The present value assumptions used in calculating the present value of accumulated benefits for the Retirement Plan were as follows: a discount rate of 4.05%; an expected retirement age of 65; postretirement mortality using the RP-2014 gender specific tables, adjusted for BHE credibility weighted experience, translated to 2011 using MP-2014. 2012 rates were used for MP-2016 and generational mortality improvements from 2012 forward were based on the custom RPEC 2016 model; a lump sum interest rate of 4.05%; and lump sum mortality same as postretirement mortality; blended 50% male and 50% female.
|
|
|
Executive
|
|
Registrant
|
|
Aggregate
|
|
Aggregate
|
|
Aggregate
|
||||||||||
|
|
contributions
|
|
contributions
|
|
earnings
|
|
withdrawals/
|
|
balance as of
|
||||||||||
Name
|
|
in 2016
(1)
|
|
in 2016
|
|
in 2016
|
|
distributions
|
|
December 31, 2016
(2)
|
||||||||||
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Gregory E. Abel
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
Stefan A. Bird
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|||||
Cindy A. Crane
|
|
579,864
|
|
|
—
|
|
|
212,289
|
|
|
—
|
|
|
2,584,801
|
|
|||||
R. Patrick Reiten
|
|
|
|
—
|
|
|
125,416
|
|
|
(493,537
|
)
|
|
836,789
|
|
||||||
Nikki L. Kobliha
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
(1)
|
The executive contribution amount shown for Ms. Crane represents a deferral of $338,000 of her 2016 compensation and her 2012 LTIP award which was deferred in 2016. The $338,000 deferred compensation and $67,107 of the deferred LTIP award are included in the 2016 total compensation reported for her in the Summary Compensation Table and are not additional compensation. The remaining 2012 LTIP award was earned prior to 2016.
|
(2)
|
The aggregate balance as of December 31,
2016
shown for Ms. Crane includes $35,397 of compensation previously reported in 2014 in the Summary Compensation Table.
|
Termination Scenario
|
|
Incentive
(1)
|
|
Pension
(2)
|
||||
|
|
|
|
|
||||
Gregory E. Abel:
|
|
|
|
|
||||
Retirement, Voluntary and Involuntary With or Without Cause
|
|
$
|
—
|
|
|
$
|
—
|
|
Death and Disability
|
|
—
|
|
|
—
|
|
||
Stefan A. Bird:
|
|
|
|
|
||||
Retirement, Voluntary and Involuntary With or Without Cause
|
|
—
|
|
|
54,565
|
|
||
Death and Disability
|
|
673,062
|
|
|
54,565
|
|
||
Cindy A. Crane:
|
|
|
|
|
||||
Retirement, Voluntary and Involuntary With or Without Cause
|
|
—
|
|
|
24,904
|
|
||
Death and Disability
|
|
698,395
|
|
|
24,904
|
|
||
R. Patrick Reiten:
|
|
|
|
|
||||
Retirement, Voluntary and Involuntary With or Without Cause
|
|
—
|
|
|
3,782
|
|
||
Death and Disability
|
|
775,891
|
|
|
3,782
|
|
||
Nikki L. Kobliha:
|
|
|
|
|
||||
Retirement, Voluntary and Involuntary With or Without Cause
|
|
—
|
|
|
3,359
|
|
||
Death and Disability
|
|
43,480
|
|
|
3,359
|
|
(1)
|
Amounts represent the unvested portion of each NEO's LTIP account, which becomes 100% vested upon death or disability.
|
(2)
|
Pension values represent the excess of the present value of benefits payable under each termination scenario over the amount already reflected in the Pension Benefits table.
|
Name and Address of Beneficial Owner
(1)
|
|
Number of Shares Beneficially Owned
(2)
|
|
Percentage Of Class
(2)
|
||
|
|
|
|
|
||
Berkshire Hathaway
(3)
|
|
69,602,161
|
|
|
90.0
|
%
|
Walter Scott, Jr.
(4)
|
|
4,100,000
|
|
|
5.3
|
%
|
Gregory E. Abel
|
|
740,961
|
|
|
1.0
|
%
|
Natalie L. Hocken
|
|
—
|
|
|
—
|
|
Warren E. Buffett
(3)(5)
|
|
—
|
|
|
—
|
|
Patrick J. Goodman
|
|
—
|
|
|
—
|
|
Marc D. Hamburg
(3)(5)
|
|
—
|
|
|
—
|
|
All directors and executive officers as a group (6 persons)
|
|
4,840,961
|
|
|
6.3
|
%
|
(1)
|
Unless otherwise indicated, each address is c/o
Berkshire Hathaway Energy Company
at 666 Grand Avenue, 29th Floor, Des Moines, Iowa 50309.
|
(2)
|
Includes shares of which the listed beneficial owner is deemed to have the right to acquire beneficial ownership under Rule 13d-3(d) under the Securities Exchange Act, including, among other things, shares which the listed beneficial owner has the right to acquire within 60 days.
|
(3)
|
Such beneficial owner's address is 1440 Kiewit Plaza, Omaha, Nebraska 68131.
|
(4)
|
Excludes 2,913,022 shares held by family members and family trusts and corporations, or Scott Family Interests, as to which Mr. Scott disclaims beneficial ownership. Mr. Scott's address is 1000 Kiewit Plaza, Omaha, Nebraska 68131.
|
(5)
|
Excludes 69,602,161 shares of common stock held by Berkshire Hathaway as to which Messrs. Buffett and Hamburg disclaim beneficial ownership.
|
Name and Address of Beneficial Owner
(1)
|
|
Number of Shares Beneficially Owned
(2)
|
|
Percentage Of Class
(2)
|
||
|
|
|
|
|
||
Walter Scott, Jr.
(3)(4)
|
|
|
|
|
||
Class A
|
|
100
|
|
|
*
|
|
Class B
|
|
—
|
|
|
—
|
|
Gregory E. Abel
(4)
|
|
|
|
|
||
Class A
|
|
5
|
|
|
*
|
|
Class B
|
|
2,363
|
|
|
*
|
|
Natalie L. Hocken
|
|
|
|
|
||
Class A
|
|
—
|
|
|
—
|
|
Class B
|
|
—
|
|
|
—
|
|
Warren E. Buffett
(5)
|
|
|
|
|
||
Class A
|
|
295,161
|
|
|
38.1
|
%
|
Class B
|
|
79,345
|
|
|
*
|
|
Patrick J. Goodman
|
|
|
|
|
||
Class A
|
|
5
|
|
|
*
|
|
Class B
|
|
786
|
|
|
*
|
|
Marc D. Hamburg
(5)
|
|
|
|
|
||
Class A
|
|
—
|
|
|
—
|
|
Class B
|
|
—
|
|
|
—
|
|
All directors and executive officers as a group (6 persons)
|
|
|
|
|
||
Class A
|
|
295,271
|
|
|
38.1
|
%
|
Class B
|
|
82,494
|
|
|
*
|
|
(1)
|
Unless otherwise indicated, each address is c/o
Berkshire Hathaway Energy Company
at 666 Grand Avenue, 29th Floor, Des Moines, Iowa 50309.
|
(2)
|
Includes shares of which the listed beneficial owner is deemed to have the right to acquire beneficial ownership under Rule 13d-3(d) under the Securities Exchange Act, including, among other things, shares which the listed beneficial owner has the right to acquire within 60 days.
|
(3)
|
Does not include 10 Class A shares owned by Mr. Scott's wife. Mr. Scott's address is 1000 Kiewit Plaza, Omaha, Nebraska 68131.
|
(4)
|
In accordance with a shareholders' agreement, as amended on December 7, 2005, based on an assumed value for
BHE
's
common stock and the closing price of Berkshire Hathaway common stock on
February 17, 2017
, Mr. Scott and the Scott Family Interests and Mr. Abel would be entitled to exchange their shares of
BHE
common stock for either 15,255 and 1,612, respectively, shares of Berkshire Hathaway Class A stock or 22,881,664 and 2,417,563, respectively, shares of Berkshire Hathaway Class B stock. Assuming an exchange of all available
BHE
shares into either Berkshire Hathaway Class A shares or Berkshire Hathaway Class B shares, Mr. Scott and the Scott Family Interests would beneficially own 1.9% of the outstanding shares of Berkshire Hathaway Class A stock or 1.7% of the outstanding shares of Berkshire Hathaway Class B stock, and Mr. Abel would beneficially own less than 1% of the outstanding shares of either class of stock.
|
(5)
|
Such beneficial owner's address is 1440 Kiewit Plaza, Omaha, Nebraska 68131.
|
|
|
BHE
|
|
Berkshire Hathaway
|
||||||||||||||
|
|
Common Stock
|
|
Class A Common Stock
|
|
Class B Common Stock
|
||||||||||||
Beneficial Owner
|
|
Number of Shares Beneficially Owned
(1)
|
|
Percentage of Class
(1)
|
|
Number of Shares Beneficially Owned
(1)
|
|
Percentage of Class
(1)
|
|
Number of Shares Beneficially Owned
(1)
|
|
Percentage of Class
(1)
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Gregory E. Abel
(2)
|
|
740,961
|
|
|
1.0
|
%
|
|
5
|
|
|
*
|
|
|
2,363
|
|
|
*
|
|
Stefan A. Bird
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
Cindy A. Crane
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
Patrick J. Goodman
|
|
—
|
|
|
—
|
|
|
5
|
|
|
*
|
|
|
786
|
|
|
*
|
|
Natalie L. Hocken
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
Nikki L. Kobliha
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
All executive officers and directors as a group (6 persons)
|
|
740,961
|
|
|
1.0
|
%
|
|
10
|
|
|
*
|
|
|
3,149
|
|
|
*
|
|
(1)
|
Includes shares of which the listed beneficial owner is deemed to have the right to acquire beneficial ownership under Rule 13d-3(d) under the Securities Exchange Act, including, among other things, shares which the listed beneficial owner has the right to acquire within 60 days.
|
(2)
|
In accordance with a shareholders' agreement, as amended on December 7, 2005, based on an assumed value for BHE's common stock and the closing price of Berkshire Hathaway common stock on
February 17, 2017
, Mr. Abel would be entitled to exchange his shares of BHE common stock for either 1,612 shares of Berkshire Hathaway Class A stock or 2,417,563 shares of Berkshire Hathaway Class B stock. Assuming an exchange of all available BHE shares into either Berkshire Hathaway Class A shares or Berkshire Hathaway Class B shares, Mr. Abel would beneficially own less than 1% of the outstanding shares of either class of stock.
|
Item 13.
|
Certain Relationships and Related Transactions, and Director Independence
|
Item 14.
|
Principal Accountant Fees and Services
|
|
Berkshire
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
|
Hathaway
|
|
|
|
MidAmerican
|
|
MidAmerican
|
|
Nevada
|
|
Sierra
|
||||||||||||
|
Energy
|
|
PacifiCorp
|
|
Funding
|
|
Energy
|
|
Power
|
|
Pacific
|
||||||||||||
2016
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Audit fees
(1)
|
$
|
9.1
|
|
|
$
|
1.5
|
|
|
$
|
1.2
|
|
|
$
|
1.1
|
|
|
$
|
0.9
|
|
|
$
|
1.1
|
|
Audit-related fees
(2)
|
0.8
|
|
|
0.2
|
|
|
0.2
|
|
|
0.2
|
|
|
—
|
|
|
—
|
|
||||||
Tax fees
(3)
|
0.1
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
||||||
Total
|
$
|
10.0
|
|
|
$
|
1.7
|
|
|
$
|
1.4
|
|
|
$
|
1.3
|
|
|
$
|
0.9
|
|
|
$
|
1.1
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
2015
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Audit fees
(1)
|
$
|
9.3
|
|
|
$
|
1.7
|
|
|
$
|
1.2
|
|
|
$
|
1.1
|
|
|
$
|
0.9
|
|
|
$
|
0.9
|
|
Audit-related fees
(2)
|
0.9
|
|
|
0.3
|
|
|
0.2
|
|
|
0.1
|
|
|
—
|
|
|
—
|
|
||||||
Tax fees
(3)
|
0.1
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
||||||
Total
|
$
|
10.3
|
|
|
$
|
2.0
|
|
|
$
|
1.4
|
|
|
$
|
1.2
|
|
|
$
|
0.9
|
|
|
$
|
0.9
|
|
(1)
|
Audit fees include fees for the audit of the consolidated financial statements and interim reviews of the quarterly financial statements for each Registrant, audit services provided in connection with required statutory audits of certain of
BHE
's subsidiaries and comfort letters, consents and other services related to SEC matters for each Registrant.
|
(2)
|
Audit-related fees primarily include fees for assurance and related services for any other statutory or regulatory requirements, audits of certain employee benefit plans and consultations on various accounting and reporting matters.
|
(3)
|
Tax fees include fees for services relating to tax compliance, tax planning and tax advice. These services include assistance regarding federal, state and international tax compliance, tax return preparation and tax audits.
|
Item 15.
|
Exhibits and Financial Statement Schedules
|
|
2016
|
|
2015
|
||||
ASSETS
|
|||||||
Current assets:
|
|
|
|
||||
Cash and cash equivalents
|
$
|
33
|
|
|
$
|
23
|
|
Accounts receivable
|
21
|
|
|
16
|
|
||
Notes receivable - affiliate
|
105
|
|
|
—
|
|
||
Income tax receivable
|
—
|
|
|
167
|
|
||
Other current assets
|
2
|
|
|
2
|
|
||
Total current assets
|
161
|
|
|
208
|
|
||
|
|
|
|
||||
Investments in subsidiaries
|
33,400
|
|
|
32,505
|
|
||
Other investments
|
1,338
|
|
|
1,389
|
|
||
Goodwill
|
1,221
|
|
|
1,221
|
|
||
Other assets
|
1,171
|
|
|
1,340
|
|
||
|
|
|
|
||||
Total assets
|
$
|
37,291
|
|
|
$
|
36,663
|
|
LIABILITIES AND EQUITY
|
|||||||
Current liabilities:
|
|
|
|
||||
Accounts payable and other current liabilities
|
$
|
357
|
|
|
$
|
306
|
|
Notes payable - affiliate
|
194
|
|
|
—
|
|
||
Short-term debt
|
834
|
|
|
253
|
|
||
Current portion of BHE senior debt
|
400
|
|
|
—
|
|
||
Total current liabilities
|
1,785
|
|
|
559
|
|
||
|
|
|
|
||||
BHE senior debt
|
7,418
|
|
|
7,814
|
|
||
BHE junior subordinated debentures
|
944
|
|
|
2,944
|
|
||
Notes payable - affiliate
|
1,859
|
|
|
1,985
|
|
||
Other long-term liabilities
|
942
|
|
|
946
|
|
||
Total liabilities
|
12,948
|
|
|
14,248
|
|
||
|
|
|
|
||||
Equity:
|
|
|
|
||||
BHE shareholders' equity:
|
|
|
|
||||
Common stock - 115 shares authorized, no par value, 77 shares issued and outstanding
|
—
|
|
|
—
|
|
||
Additional paid-in capital
|
6,390
|
|
|
6,403
|
|
||
Retained earnings
|
19,448
|
|
|
16,906
|
|
||
Accumulated other comprehensive loss, net
|
(1,511
|
)
|
|
(908
|
)
|
||
Total BHE shareholders' equity
|
24,327
|
|
|
22,401
|
|
||
Noncontrolling interest
|
16
|
|
|
14
|
|
||
Total equity
|
24,343
|
|
|
22,415
|
|
||
|
|
|
|
||||
Total liabilities and equity
|
$
|
37,291
|
|
|
$
|
36,663
|
|
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Operating costs and expenses:
|
|
|
|
|
|
||||||
General and administration
|
$
|
51
|
|
|
$
|
58
|
|
|
$
|
51
|
|
Depreciation and amortization
|
4
|
|
|
3
|
|
|
3
|
|
|||
Total operating costs and expenses
|
55
|
|
|
61
|
|
|
54
|
|
|||
|
|
|
|
|
|
||||||
Operating loss
|
(55
|
)
|
|
(61
|
)
|
|
(54
|
)
|
|||
|
|
|
|
|
|
||||||
Other income (expense):
|
|
|
|
|
|
||||||
Interest expense
|
(527
|
)
|
|
(556
|
)
|
|
(476
|
)
|
|||
Other, net
|
37
|
|
|
14
|
|
|
4
|
|
|||
Total other income (expense)
|
(490
|
)
|
|
(542
|
)
|
|
(472
|
)
|
|||
|
|
|
|
|
|
||||||
Loss before income tax benefit and equity income
|
(545
|
)
|
|
(603
|
)
|
|
(526
|
)
|
|||
Income tax benefit
|
(285
|
)
|
|
(330
|
)
|
|
(221
|
)
|
|||
Equity income
|
2,805
|
|
|
2,646
|
|
|
2,402
|
|
|||
Net income
|
2,545
|
|
|
2,373
|
|
|
2,097
|
|
|||
Net income attributable to noncontrolling interest
|
3
|
|
|
3
|
|
|
2
|
|
|||
Net income attributable to BHE shareholders
|
$
|
2,542
|
|
|
$
|
2,370
|
|
|
$
|
2,095
|
|
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Net income
|
$
|
2,545
|
|
|
$
|
2,373
|
|
|
$
|
2,097
|
|
Other comprehensive loss, net of tax
|
(603
|
)
|
|
(414
|
)
|
|
(397
|
)
|
|||
Comprehensive income
|
1,942
|
|
|
1,959
|
|
|
1,700
|
|
|||
Comprehensive income attributable to noncontrolling interests
|
3
|
|
|
3
|
|
|
2
|
|
|||
Comprehensive income attributable to BHE shareholders
|
$
|
1,939
|
|
|
$
|
1,956
|
|
|
$
|
1,698
|
|
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Cash flows from operating activities
|
$
|
2,760
|
|
|
$
|
2,528
|
|
|
$
|
1,937
|
|
|
|
|
|
|
|
||||||
Cash flows from investing activities:
|
|
|
|
|
|
||||||
Investments in subsidiaries
|
(1,080
|
)
|
|
(1,506
|
)
|
|
(4,937
|
)
|
|||
Purchases of investments
|
(24
|
)
|
|
(36
|
)
|
|
(56
|
)
|
|||
Proceeds from sale of investments
|
20
|
|
|
47
|
|
|
35
|
|
|||
Notes receivable from affiliate, net
|
(307
|
)
|
|
19
|
|
|
(55
|
)
|
|||
Other, net
|
(5
|
)
|
|
(7
|
)
|
|
(7
|
)
|
|||
Net cash flows from investing activities
|
(1,396
|
)
|
|
(1,483
|
)
|
|
(5,020
|
)
|
|||
|
|
|
|
|
|
||||||
Cash flows from financing activities:
|
|
|
|
|
|
||||||
Proceeds from BHE senior debt
|
—
|
|
|
—
|
|
|
1,478
|
|
|||
Proceeds from BHE junior subordinated debentures
|
—
|
|
|
—
|
|
|
1,500
|
|
|||
Proceeds from issuance of BHE common stock
|
—
|
|
|
—
|
|
|
—
|
|
|||
Repayments of BHE senior debt
|
—
|
|
|
—
|
|
|
(250
|
)
|
|||
Repayments of BHE subordinated debt
|
(2,000
|
)
|
|
(850
|
)
|
|
(300
|
)
|
|||
Common stock purchases
|
—
|
|
|
(36
|
)
|
|
—
|
|
|||
Net proceeds from (repayments of) short-term debt
|
581
|
|
|
(142
|
)
|
|
395
|
|
|||
Notes payable to affiliate, net
|
69
|
|
|
4
|
|
|
(30
|
)
|
|||
Other, net
|
(4
|
)
|
|
(1
|
)
|
|
1
|
|
|||
Net cash flows from financing activities
|
(1,354
|
)
|
|
(1,025
|
)
|
|
2,794
|
|
|||
|
|
|
|
|
|
||||||
Net change in cash and cash equivalents
|
10
|
|
|
20
|
|
|
(289
|
)
|
|||
Cash and cash equivalents at beginning of year
|
23
|
|
|
3
|
|
|
292
|
|
|||
Cash and cash equivalents at end of year
|
$
|
33
|
|
|
$
|
23
|
|
|
$
|
3
|
|
|
|
Column B
|
|
Column C
|
|
|
Column E
|
|||||||||||||
|
|
Balance at
|
|
Charged
|
|
|
|
|
|
Balance
|
||||||||||
Column A
|
|
Beginning
|
|
to
|
|
Acquisition
|
|
Column D
|
|
at End
|
||||||||||
Description
|
|
of Year
|
|
Income
|
|
Reserves
|
|
Deductions
|
|
of Year
|
||||||||||
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Reserves Deducted From Assets To Which They Apply:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Reserve for uncollectible accounts receivable:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Year ended 2016
|
|
$
|
31
|
|
|
$
|
39
|
|
|
$
|
—
|
|
|
$
|
(37
|
)
|
|
$
|
33
|
|
Year ended 2015
|
|
37
|
|
|
33
|
|
|
—
|
|
|
(39
|
)
|
|
31
|
|
|||||
Year ended 2014
|
|
33
|
|
|
37
|
|
|
—
|
|
|
(33
|
)
|
|
37
|
|
|||||
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Reserves Not Deducted From Assets
(1)
:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Year ended 2016
|
|
$
|
13
|
|
|
$
|
5
|
|
|
$
|
—
|
|
|
$
|
(5
|
)
|
|
$
|
13
|
|
Year ended 2015
|
|
11
|
|
|
7
|
|
|
—
|
|
|
(5
|
)
|
|
13
|
|
|||||
Year ended 2014
|
|
9
|
|
|
12
|
|
|
—
|
|
|
(10
|
)
|
|
11
|
|
(1)
|
Reserves not deducted from assets relate primarily to estimated liabilities for losses retained by
BHE
for workers compensation, public liability and property damage claims.
|
|
Years Ended December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Interest expense
|
$
|
22
|
|
|
$
|
22
|
|
|
$
|
22
|
|
Loss before income taxes
|
(22
|
)
|
|
(22
|
)
|
|
(22
|
)
|
|||
Income tax benefit
|
(9
|
)
|
|
(8
|
)
|
|
(9
|
)
|
|||
Equity in undistributed earnings of subsidiaries
|
545
|
|
|
472
|
|
|
422
|
|
|||
Net income
|
$
|
532
|
|
|
$
|
458
|
|
|
$
|
409
|
|
|
Years Ended December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Net income
|
$
|
532
|
|
|
$
|
458
|
|
|
$
|
409
|
|
Total other comprehensive income (loss), net of tax
|
3
|
|
|
(7
|
)
|
|
(12
|
)
|
|||
|
|
|
|
|
|
||||||
Comprehensive income
|
$
|
535
|
|
|
$
|
451
|
|
|
$
|
397
|
|
|
Years Ended December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Net cash flows from operating activities
|
$
|
(13
|
)
|
|
$
|
(13
|
)
|
|
$
|
(13
|
)
|
|
|
|
|
|
|
||||||
Net cash flows from investing activities
|
—
|
|
|
—
|
|
|
—
|
|
|||
|
|
|
|
|
|
||||||
Net cash flows from financing activities:
|
|
|
|
|
|
||||||
Net change in amounts payable to subsidiary
|
13
|
|
|
13
|
|
|
13
|
|
|||
Net cash flows from financing activities
|
13
|
|
|
13
|
|
|
13
|
|
|||
|
|
|
|
|
|
||||||
Net change in cash and cash equivalents
|
—
|
|
|
—
|
|
|
—
|
|
|||
Cash and cash equivalents at beginning of year
|
—
|
|
|
—
|
|
|
—
|
|
|||
Cash and cash equivalents at end of year
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
Years Ended December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Other income
|
$
|
1
|
|
|
$
|
1
|
|
|
$
|
2
|
|
Income before income taxes
|
1
|
|
|
1
|
|
|
2
|
|
|||
Income tax expense
|
—
|
|
|
—
|
|
|
1
|
|
|||
Equity in undistributed earnings of subsidiaries
|
544
|
|
|
471
|
|
|
421
|
|
|||
Net income
|
$
|
545
|
|
|
$
|
472
|
|
|
$
|
422
|
|
|
Years Ended December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Net income
|
$
|
545
|
|
|
$
|
472
|
|
|
$
|
422
|
|
Total other comprehensive income (loss), net of tax
|
3
|
|
|
(7
|
)
|
|
(12
|
)
|
|||
|
|
|
|
|
|
||||||
Comprehensive income
|
$
|
548
|
|
|
$
|
465
|
|
|
$
|
410
|
|
|
Years Ended December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Net cash flows from operating activities
|
$
|
1
|
|
|
$
|
1
|
|
|
$
|
—
|
|
|
|
|
|
|
|
||||||
Net cash flows from investing activities:
|
|
|
|
|
|
||||||
Dividend from subsidiary
|
—
|
|
|
16
|
|
|
—
|
|
|||
Net change in amounts receivable from parent
|
(13
|
)
|
|
(13
|
)
|
|
(13
|
)
|
|||
Other
|
—
|
|
|
(1
|
)
|
|
3
|
|
|||
Net cash flows from investing activities
|
(13
|
)
|
|
2
|
|
|
(10
|
)
|
|||
|
|
|
|
|
|
||||||
Net cash flows from financing activities:
|
|
|
|
|
|
||||||
Capital expenditures
|
(1
|
)
|
|
—
|
|
|
—
|
|
|||
Net change in amounts payable to subsidiaries
|
5
|
|
|
(7
|
)
|
|
10
|
|
|||
Net change in note payable to Berkshire Hathaway Energy Company
|
9
|
|
|
3
|
|
|
1
|
|
|||
Net cash flows from financing activities
|
13
|
|
|
(4
|
)
|
|
11
|
|
|||
|
|
|
|
|
|
||||||
Net change in cash and cash equivalents
|
1
|
|
|
(1
|
)
|
|
1
|
|
|||
Cash and cash equivalents at beginning of year
|
—
|
|
|
1
|
|
|
—
|
|
|||
Cash and cash equivalents at end of year
|
$
|
1
|
|
|
$
|
—
|
|
|
$
|
1
|
|
|
|
Column B
|
|
Column C
|
|
|
|
Column E
|
||||||||
|
|
Balance at
|
|
Additions
|
|
|
|
Balance
|
||||||||
Column A
|
|
Beginning
|
|
Charged
|
|
Column D
|
|
at End
|
||||||||
Description
|
|
of Year
|
|
to Income
|
|
Deductions
|
|
of Year
|
||||||||
|
|
|
|
|
|
|
|
|
||||||||
Reserves Deducted From Assets To Which They Apply:
|
|
|
|
|
|
|
|
|
||||||||
Reserve for uncollectible accounts receivable:
|
|
|
|
|
|
|
|
|
||||||||
|
|
|
|
|
|
|
|
|
||||||||
Year ended 2016
|
|
$
|
6
|
|
|
$
|
7
|
|
|
$
|
(6
|
)
|
|
$
|
7
|
|
|
|
|
|
|
|
|
|
|
||||||||
Year ended 2015
|
|
$
|
7
|
|
|
$
|
7
|
|
|
$
|
(8
|
)
|
|
$
|
6
|
|
|
|
|
|
|
|
|
|
|
||||||||
Year ended 2014
|
|
$
|
10
|
|
|
$
|
7
|
|
|
$
|
(10
|
)
|
|
$
|
7
|
|
|
|
|
|
|
|
|
|
|
||||||||
|
|
|
|
|
|
|
|
|
||||||||
Reserves Not Deducted From Assets
(1)
:
|
|
|
|
|
|
|
|
|
||||||||
|
|
|
|
|
|
|
|
|
||||||||
Year ended 2016
|
|
$
|
13
|
|
|
$
|
5
|
|
|
$
|
(5
|
)
|
|
$
|
13
|
|
|
|
|
|
|
|
|
|
|
||||||||
Year ended 2015
|
|
$
|
11
|
|
|
$
|
7
|
|
|
$
|
(5
|
)
|
|
$
|
13
|
|
|
|
|
|
|
|
|
|
|
||||||||
Year ended 2014
|
|
$
|
9
|
|
|
$
|
12
|
|
|
$
|
(10
|
)
|
|
$
|
11
|
|
(1)
|
Reserves not deducted from assets include estimated liabilities for losses retained by MidAmerican Energy for workers compensation, public liability and property damage claims.
|
|
|
Column B
|
|
Column C
|
|
|
|
Column E
|
||||||||
|
|
Balance at
|
|
Additions
|
|
|
|
Balance
|
||||||||
Column A
|
|
Beginning
|
|
Charged
|
|
Column D
|
|
at End
|
||||||||
Description
|
|
of Year
|
|
to Income
|
|
Deductions
|
|
of Year
|
||||||||
|
|
|
|
|
|
|
|
|
||||||||
Reserves Deducted From Assets To Which They Apply:
|
|
|
|
|
|
|
|
|
||||||||
Reserve for uncollectible accounts receivable:
|
|
|
|
|
|
|
|
|
||||||||
|
|
|
|
|
|
|
|
|
||||||||
Year ended 2016
|
|
$
|
6
|
|
|
$
|
7
|
|
|
$
|
(6
|
)
|
|
$
|
7
|
|
|
|
|
|
|
|
|
|
|
||||||||
Year ended 2015
|
|
$
|
7
|
|
|
$
|
7
|
|
|
$
|
(8
|
)
|
|
$
|
6
|
|
|
|
|
|
|
|
|
|
|
||||||||
Year ended 2014
|
|
$
|
10
|
|
|
$
|
7
|
|
|
$
|
(10
|
)
|
|
$
|
7
|
|
|
|
|
|
|
|
|
|
|
||||||||
|
|
|
|
|
|
|
|
|
||||||||
Reserves Not Deducted From Assets
(1)
:
|
|
|
|
|
|
|
|
|
||||||||
|
|
|
|
|
|
|
|
|
||||||||
Year ended 2016
|
|
$
|
13
|
|
|
$
|
5
|
|
|
$
|
(5
|
)
|
|
$
|
13
|
|
|
|
|
|
|
|
|
|
|
||||||||
Year ended 2015
|
|
$
|
11
|
|
|
$
|
7
|
|
|
$
|
(5
|
)
|
|
$
|
13
|
|
|
|
|
|
|
|
|
|
|
||||||||
Year ended 2014
|
|
$
|
9
|
|
|
$
|
12
|
|
|
$
|
(10
|
)
|
|
$
|
11
|
|
(1)
|
Reserves not deducted from assets include primarily estimated liabilities for losses retained by MidAmerican Funding and MHC for workers compensation, public liability and property damage claims.
|
Item 15(c)
|
MHC Inc. Consolidated Financial Statements
|
|
Years Ended December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
Operating revenue:
|
|
|
|
|
|
||||||
Regulated electric
|
$
|
1,985
|
|
|
$
|
1,837
|
|
|
$
|
1,817
|
|
Regulated gas and other
|
646
|
|
|
678
|
|
|
1,027
|
|
|||
Total operating revenue
|
2,631
|
|
|
2,515
|
|
|
2,844
|
|
|||
|
|
|
|
|
|
||||||
Operating costs and expenses:
|
|
|
|
|
|
||||||
Cost of fuel, energy and capacity
|
410
|
|
|
433
|
|
|
532
|
|
|||
Cost of gas sold and other
|
371
|
|
|
407
|
|
|
738
|
|
|||
Operations and maintenance
|
693
|
|
|
707
|
|
|
720
|
|
|||
Depreciation and amortization
|
479
|
|
|
407
|
|
|
351
|
|
|||
Property and other taxes
|
112
|
|
|
110
|
|
|
108
|
|
|||
Total operating costs and expenses
|
2,065
|
|
|
2,064
|
|
|
2,449
|
|
|||
|
|
|
|
|
|
||||||
Operating income
|
566
|
|
|
451
|
|
|
395
|
|
|||
|
|
|
|
|
|
||||||
Other income and (expense):
|
|
|
|
|
|
||||||
Interest expense
|
(196
|
)
|
|
(184
|
)
|
|
(175
|
)
|
|||
Allowance for borrowed funds
|
8
|
|
|
8
|
|
|
16
|
|
|||
Allowance for equity funds
|
19
|
|
|
20
|
|
|
39
|
|
|||
Other, net
|
18
|
|
|
20
|
|
|
18
|
|
|||
Total other income and (expense)
|
(151
|
)
|
|
(136
|
)
|
|
(102
|
)
|
|||
|
|
|
|
|
|
||||||
Income before income tax benefit
|
415
|
|
|
315
|
|
|
293
|
|
|||
Income tax benefit
|
(130
|
)
|
|
(141
|
)
|
|
(113
|
)
|
|||
|
|
|
|
|
|
||||||
Income from continuing operations
|
545
|
|
|
456
|
|
|
406
|
|
|||
|
|
|
|
|
|
||||||
Discontinued operations (Note 3):
|
|
|
|
|
|
||||||
Income from discontinued operations
|
—
|
|
|
22
|
|
|
28
|
|
|||
Income tax expense
|
—
|
|
|
6
|
|
|
12
|
|
|||
Income on discontinued operations
|
—
|
|
|
16
|
|
|
16
|
|
|||
|
|
|
|
|
|
||||||
Net income
|
$
|
545
|
|
|
$
|
472
|
|
|
$
|
422
|
|
|
Years Ended December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Net income
|
$
|
545
|
|
|
$
|
472
|
|
|
$
|
422
|
|
|
|
|
|
|
|
||||||
Other comprehensive income (loss), net of tax:
|
|
|
|
|
|
||||||
Unrealized gains on available-for-sale securities, net of tax of $1, $- and $1
|
3
|
|
|
—
|
|
|
1
|
|
|||
Unrealized losses on cash flow hedges, net of tax of $-, $(4) and $(10)
|
—
|
|
|
(7
|
)
|
|
(13
|
)
|
|||
Total other comprehensive income (loss), net of tax
|
3
|
|
|
(7
|
)
|
|
(12
|
)
|
|||
|
|
|
|
|
|
||||||
Comprehensive income
|
$
|
548
|
|
|
$
|
465
|
|
|
$
|
410
|
|
|
|
|
|
|
Accumulated
|
|
|
||||||||
|
|
|
|
|
Other
|
|
|
||||||||
|
Paid-in
|
|
Retained
|
|
Comprehensive
|
|
Total
|
||||||||
|
Capital
|
|
Earnings
|
|
Loss, Net
|
|
Equity
|
||||||||
|
|
|
|
|
|
|
|
||||||||
Balance, December 31, 2013
|
$
|
2,430
|
|
|
$
|
2,850
|
|
|
$
|
(11
|
)
|
|
$
|
5,269
|
|
Net income
|
—
|
|
|
422
|
|
|
—
|
|
|
422
|
|
||||
Other comprehensive loss
|
—
|
|
|
—
|
|
|
(12
|
)
|
|
(12
|
)
|
||||
Balance, December 31, 2014
|
2,430
|
|
|
3,272
|
|
|
(23
|
)
|
|
5,679
|
|
||||
Net income
|
—
|
|
|
472
|
|
|
—
|
|
|
472
|
|
||||
Other comprehensive loss
|
—
|
|
|
—
|
|
|
(7
|
)
|
|
(7
|
)
|
||||
Balance, December 31, 2015
|
2,430
|
|
|
3,744
|
|
|
(30
|
)
|
|
6,144
|
|
||||
Net income
|
—
|
|
|
545
|
|
|
—
|
|
|
545
|
|
||||
Other comprehensive income
|
—
|
|
|
—
|
|
|
3
|
|
|
3
|
|
||||
Transfer to affiliate (Note 3)
|
—
|
|
|
—
|
|
|
27
|
|
|
27
|
|
||||
Other equity transactions
|
—
|
|
|
(1
|
)
|
|
—
|
|
|
(1
|
)
|
||||
Balance, December 31, 2016
|
$
|
2,430
|
|
|
$
|
4,288
|
|
|
$
|
—
|
|
|
$
|
6,718
|
|
|
Years Ended December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
Cash flows from operating activities:
|
|
|
|
|
|
||||||
Net income
|
$
|
545
|
|
|
$
|
472
|
|
|
$
|
422
|
|
Adjustments to reconcile net income to net cash flows from operating activities:
|
|
|
|
|
|
||||||
Depreciation and amortization
|
479
|
|
|
407
|
|
|
351
|
|
|||
Deferred income taxes and amortization of investment tax credits
|
362
|
|
|
276
|
|
|
298
|
|
|||
Changes in other assets and liabilities
|
47
|
|
|
49
|
|
|
47
|
|
|||
Other, net
|
(92
|
)
|
|
(70
|
)
|
|
(49
|
)
|
|||
Changes in other operating assets and liabilities:
|
|
|
|
|
|
||||||
Receivables, net
|
(61
|
)
|
|
93
|
|
|
(2
|
)
|
|||
Inventories
|
(27
|
)
|
|
(53
|
)
|
|
44
|
|
|||
Derivative collateral, net
|
5
|
|
|
33
|
|
|
(53
|
)
|
|||
Contributions to pension and other postretirement benefit plans, net
|
(6
|
)
|
|
(8
|
)
|
|
(2
|
)
|
|||
Accounts payable
|
39
|
|
|
(76
|
)
|
|
30
|
|
|||
Accrued property, income and other taxes, net
|
107
|
|
|
213
|
|
|
(253
|
)
|
|||
Other current assets and liabilities
|
8
|
|
|
12
|
|
|
—
|
|
|||
Net cash flows from operating activities
|
1,406
|
|
|
1,348
|
|
|
833
|
|
|||
|
|
|
|
|
|
||||||
Net cash flows from investing activities:
|
|
|
|
|
|
||||||
Utility construction expenditures
|
(1,636
|
)
|
|
(1,446
|
)
|
|
(1,526
|
)
|
|||
Purchases of available-for-sale securities
|
(138
|
)
|
|
(142
|
)
|
|
(88
|
)
|
|||
Proceeds from sales of available-for-sale securities
|
158
|
|
|
135
|
|
|
80
|
|
|||
Proceeds from sales of other investments
|
2
|
|
|
13
|
|
|
10
|
|
|||
Other, net
|
(13
|
)
|
|
(11
|
)
|
|
(8
|
)
|
|||
Net cash flows from investing activities
|
(1,627
|
)
|
|
(1,451
|
)
|
|
(1,532
|
)
|
|||
|
|
|
|
|
|
||||||
Net cash flows from financing activities:
|
|
|
|
|
|
||||||
Proceeds from long-term debt
|
62
|
|
|
649
|
|
|
840
|
|
|||
Repayments of long-term debt
|
(38
|
)
|
|
(426
|
)
|
|
(356
|
)
|
|||
Net change in amounts receivable from/payable to affiliates
|
9
|
|
|
3
|
|
|
1
|
|
|||
Net proceeds from (repayments of) short-term debt
|
99
|
|
|
(50
|
)
|
|
50
|
|
|||
Other, net
|
1
|
|
|
—
|
|
|
—
|
|
|||
Net cash flows from financing activities
|
133
|
|
|
176
|
|
|
535
|
|
|||
|
|
|
|
|
|
||||||
Net change in cash and cash equivalents
|
(88
|
)
|
|
73
|
|
|
(164
|
)
|
|||
Cash and cash equivalents at beginning of year
|
103
|
|
|
30
|
|
|
194
|
|
|||
Cash and cash equivalents at end of year
|
$
|
15
|
|
|
$
|
103
|
|
|
$
|
30
|
|
(
1
)
|
Company Organization
|
(
2
)
|
Summary of Significant Accounting Policies
|
(
7
)
|
Investments and Restricted Cash and Investments
|
(
9
)
|
Long-Term Debt
|
(
10
)
|
Income Taxes
|
|
2016
|
|
2015
|
|
2014
|
||||||
Current:
|
|
|
|
|
|
||||||
Federal
|
$
|
(478
|
)
|
|
$
|
(411
|
)
|
|
$
|
(407
|
)
|
State
|
(14
|
)
|
|
(6
|
)
|
|
(3
|
)
|
|||
|
(492
|
)
|
|
(417
|
)
|
|
(410
|
)
|
|||
Deferred:
|
|
|
|
|
|
||||||
Federal
|
367
|
|
|
282
|
|
|
296
|
|
|||
State
|
(4
|
)
|
|
(5
|
)
|
|
2
|
|
|||
|
363
|
|
|
277
|
|
|
298
|
|
|||
|
|
|
|
|
|
||||||
Investment tax credits
|
(1
|
)
|
|
(1
|
)
|
|
(1
|
)
|
|||
Total
|
$
|
(130
|
)
|
|
$
|
(141
|
)
|
|
$
|
(113
|
)
|
|
2016
|
|
2015
|
||||
Deferred income tax assets:
|
|
|
|
||||
Regulatory liabilities
|
$
|
333
|
|
|
$
|
327
|
|
Derivative contracts
|
—
|
|
|
—
|
|
||
Asset retirement obligations
|
230
|
|
|
214
|
|
||
Employee benefits
|
66
|
|
|
66
|
|
||
Other
|
82
|
|
|
97
|
|
||
Total deferred income tax assets
|
711
|
|
|
704
|
|
||
|
|
|
|
||||
Deferred income tax liabilities:
|
|
|
|
||||
Depreciable property
|
(3,767
|
)
|
|
(3,326
|
)
|
||
Regulatory assets
|
(471
|
)
|
|
(418
|
)
|
||
Other
|
(41
|
)
|
|
(16
|
)
|
||
Total deferred income tax liabilities
|
(4,279
|
)
|
|
(3,760
|
)
|
||
|
|
|
|
||||
Net deferred income tax liability
|
$
|
(3,568
|
)
|
|
$
|
(3,056
|
)
|
|
2016
|
|
2015
|
||||
|
|
|
|
||||
Beginning balance
|
$
|
10
|
|
|
$
|
26
|
|
Additions based on tax positions related to the current year
|
—
|
|
|
4
|
|
||
Additions for tax positions of prior years
|
10
|
|
|
46
|
|
||
Reductions based on tax positions related to the current year
|
(2
|
)
|
|
(6
|
)
|
||
Reductions for tax positions of prior years
|
(8
|
)
|
|
(46
|
)
|
||
Statute of limitations
|
—
|
|
|
(5
|
)
|
||
Settlements
|
—
|
|
|
(6
|
)
|
||
Interest and penalties
|
—
|
|
|
(3
|
)
|
||
Ending balance
|
$
|
10
|
|
|
$
|
10
|
|
(
11
)
|
Employee Benefit Plans
|
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Pension costs
|
$
|
4
|
|
|
$
|
4
|
|
|
$
|
4
|
|
Other postretirement costs
|
(1
|
)
|
|
(2
|
)
|
|
(2
|
)
|
(
12
)
|
Asset Retirement Obligations
|
(
13
)
|
Risk Management and Hedging Activities
|
(
14
)
|
Fair Value Measurements
|
(
15
)
|
Commitments and Contingencies
|
(
16
)
|
Components of Accumulated Other Comprehensive Loss, Net
|
|
2016
|
|
2015
|
|
2014
|
||||||
|
|
|
|
|
|
||||||
Corporate-owned life insurance income
|
$
|
8
|
|
|
$
|
4
|
|
|
$
|
8
|
|
Gain on redemption of auction rate securities
|
5
|
|
|
—
|
|
|
—
|
|
|||
Gains on sales of assets and other investments
|
3
|
|
|
13
|
|
|
—
|
|
|||
Leveraged leases
|
—
|
|
|
1
|
|
|
5
|
|
|||
Other, net
|
2
|
|
|
2
|
|
|
5
|
|
|||
Total
|
$
|
18
|
|
|
$
|
20
|
|
|
$
|
18
|
|
|
2016
|
|
2015
|
|
2014
|
||||||
Supplemental cash flow information:
|
|
|
|
|
|
||||||
Interest paid, net of amounts capitalized
|
$
|
181
|
|
|
$
|
154
|
|
|
$
|
144
|
|
Income taxes received, net
|
$
|
600
|
|
|
$
|
621
|
|
|
$
|
143
|
|
|
|
|
|
|
|
||||||
Supplemental disclosure of non-cash investing and financing transactions:
|
|
|
|
|
|
||||||
Accounts payable related to utility plant additions
|
$
|
131
|
|
|
$
|
249
|
|
|
$
|
128
|
|
Transfer of assets and liabilities to affiliate (note 3)
|
$
|
90
|
|
|
$
|
—
|
|
|
$
|
—
|
|
(
19
)
|
Related Party Transactions
|
(
20
)
|
Segment Information
|
|
Years Ended December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
Operating revenue:
|
|
|
|
|
|
||||||
Regulated electric
|
$
|
1,985
|
|
|
$
|
1,837
|
|
|
$
|
1,817
|
|
Regulated gas
|
637
|
|
|
661
|
|
|
996
|
|
|||
Other
|
9
|
|
|
17
|
|
|
31
|
|
|||
Total operating revenue
|
$
|
2,631
|
|
|
$
|
2,515
|
|
|
$
|
2,844
|
|
|
|
|
|
|
|
||||||
Depreciation and amortization:
|
|
|
|
|
|
||||||
Regulated electric
|
$
|
436
|
|
|
$
|
366
|
|
|
$
|
312
|
|
Regulated gas
|
43
|
|
|
41
|
|
|
39
|
|
|||
Total depreciation and amortization
|
$
|
479
|
|
|
$
|
407
|
|
|
$
|
351
|
|
|
|
|
|
|
|
||||||
Operating income:
|
|
|
|
|
|
||||||
Regulated electric
|
$
|
497
|
|
|
$
|
385
|
|
|
$
|
319
|
|
Regulated gas
|
68
|
|
|
64
|
|
|
75
|
|
|||
Other
|
1
|
|
|
2
|
|
|
1
|
|
|||
Total operating income
|
$
|
566
|
|
|
$
|
451
|
|
|
$
|
395
|
|
|
|
|
|
|
|
||||||
Interest expense:
|
|
|
|
|
|
||||||
Regulated electric
|
$
|
178
|
|
|
$
|
166
|
|
|
$
|
157
|
|
Regulated gas
|
18
|
|
|
17
|
|
|
17
|
|
|||
Other
|
—
|
|
|
1
|
|
|
1
|
|
|||
Total interest expense
|
$
|
196
|
|
|
$
|
184
|
|
|
$
|
175
|
|
|
|
|
|
|
|
||||||
Income tax (benefit) expense from continuing operations:
|
|
|
|
|
|
||||||
Regulated electric
|
$
|
(156
|
)
|
|
$
|
(163
|
)
|
|
$
|
(138
|
)
|
Regulated gas
|
22
|
|
|
16
|
|
|
22
|
|
|||
Other
|
4
|
|
|
6
|
|
|
3
|
|
|||
Total income tax (benefit) expense from continuing operations
|
$
|
(130
|
)
|
|
$
|
(141
|
)
|
|
$
|
(113
|
)
|
|
|
|
|
|
|
||||||
Net income:
|
|
|
|
|
|
||||||
Regulated electric
|
$
|
512
|
|
|
$
|
413
|
|
|
$
|
361
|
|
Regulated gas
|
32
|
|
|
33
|
|
|
40
|
|
|||
Other
|
1
|
|
|
10
|
|
|
5
|
|
|||
Income from continuing operations
|
545
|
|
|
456
|
|
|
406
|
|
|||
Income on discontinued operations
|
—
|
|
|
16
|
|
|
16
|
|
|||
Net income
|
$
|
545
|
|
|
$
|
472
|
|
|
$
|
422
|
|
|
|
|
|
|
|
||||||
Utility construction expenditures:
|
|
|
|
|
|
||||||
Regulated electric
|
$
|
1,564
|
|
|
$
|
1,365
|
|
|
$
|
1,429
|
|
Regulated gas
|
72
|
|
|
81
|
|
|
97
|
|
|||
Total utility construction expenditures
|
$
|
1,636
|
|
|
$
|
1,446
|
|
|
$
|
1,526
|
|
|
As of December 31,
|
||||||||||
|
2016
|
|
2015
|
|
2014
|
||||||
Total assets:
|
|
|
|
|
|
||||||
Regulated electric
|
$
|
15,304
|
|
|
$
|
14,161
|
|
|
$
|
13,041
|
|
Regulated gas
|
1,424
|
|
|
1,330
|
|
|
1,296
|
|
|||
Other
|
317
|
|
|
468
|
|
|
457
|
|
|||
Total assets
|
$
|
17,045
|
|
|
$
|
15,959
|
|
|
$
|
14,794
|
|
Regulated electric
|
$
|
1,191
|
|
Regulated gas
|
79
|
|
|
Total
|
$
|
1,270
|
|
(
21
)
|
Subsequent Events
|
|
BERKSHIRE HATHAWAY ENERGY COMPANY
|
|
|
|
/s/ Gregory E. Abel*
|
|
Gregory E. Abel
|
|
Chairman, President and Chief Executive Officer
|
|
(principal executive officer)
|
Signature
|
|
Title
|
|
Date
|
|
|
|
|
|
/s/ Gregory E. Abel*
|
|
Chairman, President and Chief
|
|
February 24, 2017
|
Gregory E. Abel
|
|
Executive Officer
|
|
|
|
|
(principal executive officer)
|
|
|
|
|
|
|
|
/s/ Patrick J. Goodman*
|
|
Executive Vice President and
|
|
February 24, 2017
|
Patrick J. Goodman
|
|
Chief Financial Officer
|
|
|
|
|
(principal financial and accounting
|
|
|
|
|
officer)
|
|
|
|
|
|
|
|
/s/ Walter Scott, Jr.*
|
|
Director
|
|
February 24, 2017
|
Walter Scott, Jr.
|
|
|
|
|
|
|
|
|
|
/s/ Marc D. Hamburg*
|
|
Director
|
|
February 24, 2017
|
Marc D. Hamburg
|
|
|
|
|
|
|
|
|
|
/s/ Warren E. Buffett*
|
|
Director
|
|
February 24, 2017
|
Warren E. Buffett
|
|
|
|
|
|
|
|
|
|
*By:
/s/ Natalie L. Hocken
|
|
Attorney-in-Fact
|
|
February 24, 2017
|
Natalie L. Hocken
|
|
|
|
|
|
PACIFICORP
|
|
|
|
/s/ Nikki L. Kobliha
|
|
Nikki L. Kobliha
|
|
Director, Vice President, Chief Financial Officer, and Treasurer
|
|
(principal financial and accounting officer)
|
Signature
|
|
Title
|
|
Date
|
|
|
|
|
|
/s/ Gregory E. Abel
|
|
Chairman of the Board of Directors
|
|
February 24, 2017
|
Gregory E. Abel
|
|
and Chief Executive Officer
|
|
|
|
|
(principal executive officer)
|
|
|
|
|
|
|
|
/s/ Nikki L. Kobliha
|
|
Director, Vice President,
|
|
February 24, 2017
|
Nikki L. Kobliha
|
|
Chief Financial Officer, and Treasurer
|
|
|
|
|
(principal financial and accounting officer)
|
|
|
|
|
|
|
|
/s/ Stefan A. Bird
|
|
Director
|
|
February 24, 2017
|
Stefan A. Bird
|
|
|
|
|
|
|
|
|
|
/s/ Cindy A. Crane
|
|
Director
|
|
February 24, 2017
|
Cindy A. Crane
|
|
|
|
|
|
|
|
|
|
/s/ Patrick J. Goodman
|
|
Director
|
|
February 24, 2017
|
Patrick J. Goodman
|
|
|
|
|
|
|
|
|
|
/s/ Natalie L. Hocken
|
|
Director
|
|
February 24, 2017
|
Natalie L. Hocken
|
|
|
|
|
|
MIDAMERICAN ENERGY COMPANY
|
|
|
|
/s/ William J. Fehrman
|
|
William J. Fehrman
|
|
President and Chief Executive Officer
|
|
(principal executive officer)
|
Signatures
|
|
Title
|
|
Date
|
|
|
|
|
|
/s/William J. Fehrman
|
|
President, Chief Executive Officer and Director
|
|
February 24, 2017
|
William J. Fehrman
|
|
(principal executive officer)
|
|
|
|
|
|
|
|
/s/Thomas B. Specketer
|
|
Vice President, Chief Financial Officer and Director
|
|
February 24, 2017
|
Thomas B. Specketer
|
|
(principal financial and accounting officer)
|
|
|
|
|
|
|
|
/s/Robert B. Berntsen
|
|
Director
|
|
February 24, 2017
|
Robert B. Berntsen
|
|
|
|
|
|
MIDAMERICAN FUNDING, LLC
|
|
|
|
/s/ William J. Fehrman
|
|
William J Fehrman
|
|
President
|
|
(principal executive officer)
|
Signatures
|
|
Title
|
|
Date
|
|
|
|
|
|
/s/William J. Fehrman
|
|
President and Manager
|
|
February 24, 2017
|
William J. Fehrman
|
|
(principal executive officer)
|
|
|
|
|
|
|
|
/s/Thomas B. Specketer
|
|
Vice President and Controller
|
|
February 24, 2017
|
Thomas B. Specketer
|
|
(principal financial and accounting officer)
|
|
|
|
|
|
|
|
/s/Patrick J. Goodman
|
|
Manager
|
|
February 24, 2017
|
Patrick J. Goodman
|
|
|
|
|
|
|
|
|
|
/s/Sandra Hatfield Clubb
|
|
Manager
|
|
February 24, 2017
|
Sandra Hatfield Clubb
|
|
|
|
|
|
|
|
|
|
/s/Natalie L. Hocken
|
|
Manager
|
|
February 24, 2017
|
Natalie L. Hocken
|
|
|
|
|
|
NEVADA POWER COMPANY
|
|
|
|
/s/ Paul J. Caudill
|
|
Paul J. Caudill
|
|
President and Chief Executive Officer
|
|
(principal executive officer)
|
Signature
|
|
Title
|
|
Date
|
|
|
|
|
|
/s/ Paul J. Caudill
|
|
President and Chief Executive Officer
|
|
February 24, 2017
|
Paul J. Caudill
|
|
(principal executive officer)
|
|
|
|
|
|
|
|
/s/ E. Kevin Bethel
|
|
Senior Vice President, Chief Financial
|
|
February 24, 2017
|
E. Kevin Bethel
|
|
Officer and Director
|
|
|
|
|
(principal financial and accounting officer)
|
|
|
|
|
|
|
|
/s/ Douglas A. Cannon
|
|
Director
|
|
February 24, 2017
|
Douglas A. Cannon
|
|
|
|
|
|
|
|
|
|
/s/ Patrick S. Egan
|
|
Director
|
|
February 24, 2017
|
Patrick S. Egan
|
|
|
|
|
|
|
|
|
|
/s/ Kevin C. Geraghty
|
|
Director
|
|
February 24, 2017
|
Kevin C. Geraghty
|
|
|
|
|
|
|
|
|
|
/s/ Francis P. Gonzales
|
|
Director
|
|
February 24, 2017
|
Francis P. Gonzales
|
|
|
|
|
|
|
|
|
|
/s/ John C. Owens
|
|
Director
|
|
February 24, 2017
|
John C. Owens
|
|
|
|
|
|
|
|
|
|
/s/ Shawn M. Elicegui
|
|
Director
|
|
February 24, 2017
|
Shawn M. Elicegui
|
|
|
|
|
|
SIERRA PACIFIC POWER COMPANY
|
|
|
|
/s/ Paul J. Caudill
|
|
Paul J. Caudill
|
|
President and Chief Executive Officer
|
|
(principal executive officer)
|
Signature
|
|
Title
|
|
Date
|
|
|
|
|
|
/s/ Paul J. Caudill
|
|
President and Chief Executive Officer
|
|
February 24, 2017
|
Paul J. Caudill
|
|
(principal executive officer)
|
|
|
|
|
|
|
|
/s/ E. Kevin Bethel
|
|
Senior Vice President, Chief Financial
|
|
February 24, 2017
|
E. Kevin Bethel
|
|
Officer and Director
|
|
|
|
|
(principal financial and accounting officer)
|
|
|
|
|
|
|
|
/s/ Douglas A. Cannon
|
|
Director
|
|
February 24, 2017
|
Douglas A. Cannon
|
|
|
|
|
|
|
|
|
|
/s/ Patrick S. Egan
|
|
Director
|
|
February 24, 2017
|
Patrick S. Egan
|
|
|
|
|
|
|
|
|
|
/s/ Kevin C. Geraghty
|
|
Director
|
|
February 24, 2017
|
Kevin C. Geraghty
|
|
|
|
|
|
|
|
|
|
/s/ Francis P. Gonzales
|
|
Director
|
|
February 24, 2017
|
Francis P. Gonzales
|
|
|
|
|
|
|
|
|
|
/s/ John C. Owens
|
|
Director
|
|
February 24, 2017
|
John C. Owens
|
|
|
|
|
|
|
|
|
|
/s/ Shawn M. Elicegui
|
|
Director
|
|
February 24, 2017
|
Shawn M. Elicegui
|
|
|
|
|
3.1
|
Second Amended and Restated Articles of Incorporation of MidAmerican Energy Holdings Company effective March 2, 2006 (incorporated by reference to Exhibit 3.1 to the
Berkshire Hathaway Energy Company
Annual Report on Form 10-K for the year ended December 31, 2005).
|
3.2
|
Articles of Amendment to the Second Amended and Restated Articles of Incorporation of MidAmerican Energy Holdings Company effective April 30, 2014 (incorporated by reference to Exhibit 3.1 to the
Berkshire Hathaway Energy Company
Quarterly Report on Form 10-Q for the quarter ended March 31, 2014).
|
3.3
|
Amended and Restated Bylaws of Berkshire Hathaway Energy Company (incorporated by reference to Exhibit 3.2 to the
Berkshire Hathaway Energy Company
Annual Report on Form 10-K for the year ended December 31, 2005).
|
4.1
|
Shareholders Agreement, dated as of March 14, 2000 (incorporated by reference to Exhibit 4.19 to the
Berkshire Hathaway Energy Company
Registration Statement No. 333-101699 dated December 6, 2002).
|
4.2
|
Amendment No. 1 to Shareholders Agreement, dated December 7, 2005 (incorporated by reference to Exhibit 4.17 to the
Berkshire Hathaway Energy Company
Annual Report on Form 10-K for the year ended December 31, 2005).
|
4.3
|
Indenture, dated as of November 12, 2014, by and between Berkshire Hathaway Energy Company and The Bank of New York Mellon Trust Company, N.A., as Trustee, relating to the Junior Subordinated Debentures due 2044 (including form of junior subordinated debenture) (incorporated by reference to Exhibit 4.1 to the Berkshire Hathaway Energy Company Current Report on Form 8-K dated December 1, 2014).
|
4.4
|
Indenture, dated as of October 4, 2002, by and between MidAmerican Energy Holdings Company and The Bank of New York, Trustee (incorporated by reference to Exhibit 4.1 to the
Berkshire Hathaway Energy Company
Registration Statement No. 333-101699 dated December 6, 2002).
|
4.5
|
Fourth Supplemental Indenture, dated as of March 24, 2006, by and between MidAmerican Energy Holdings Company and The Bank of New York Trust Company, N.A., Trustee, relating to the 6.125% Senior Bonds due 2036 (incorporated by reference to Exhibit 4.1 to the
Berkshire Hathaway Energy Company
Current Report on Form 8-K dated March 28, 2006).
|
4.6
|
Fifth Supplemental Indenture, dated as of May 11, 2007, by and between MidAmerican Energy Holdings Company and The Bank of New York Trust Company, N.A., Trustee, relating to the 5.95% Senior Bonds due 2037 (incorporated by reference to Exhibit 4.1 to the
Berkshire Hathaway Energy Company
Current Report on Form 8-K dated May 11, 2007).
|
4.7
|
Sixth Supplemental Indenture, dated as of August 28, 2007, by and between MidAmerican Energy Holdings Company and The Bank of New York Trust Company, N.A., Trustee, relating to the 6.50% Senior Bonds due 2037 (incorporated by reference to Exhibit 4.1 to the
Berkshire Hathaway Energy Company
Current Report on Form 8-K dated August 28, 2007).
|
4.8
|
Seventh Supplemental Indenture, dated as of March 28, 2008, by and between MidAmerican Energy Holdings Company and The Bank of New York Trust Company, N.A., as Trustee, relating to the 5.75% Senior Notes due 2018 (incorporated by reference to Exhibit 4.1 to the
Berkshire Hathaway Energy Company
Current Report on Form 8-K dated March 28, 2008).
|
4.9
|
Ninth Supplemental Indenture, dated as of November 8, 2013, by and between MidAmerican Energy Holdings Company and The Bank of New York Mellon Trust Company, N.A., as Trustee, relating to the 1.100% Senior Notes due 2017, the 2.000% Senior Notes due 2018, the 3.750% Senior Notes due 2023 and the 5.150% Senior Notes due 2043 (incorporated by reference to Exhibit 4.1 to the
Berkshire Hathaway Energy Company
Current Report on Form 8-K dated November 8, 2013).
|
4.10
|
Tenth Supplemental Indenture, dated as December 4, 2014, by and between Berkshire Hathaway Energy Company and The Bank of New York Mellon Trust Company, N.A., as Trustee, relating to the 2.40% Senior Notes due 2020, the 3.50% Senior Notes due 2025 and the 4.50% Senior Notes due 2045 (incorporated by reference to Exhibit 4.8 to the Berkshire Hathaway Energy Company Registration Statement No. 333-200928 dated December 12, 2014).
|
Exhibit No.
|
Description
|
4.11
|
Indenture, dated as of October 15, 1997, by and between MidAmerican Energy Holdings Company and IBJ Schroder Bank & Trust Company, Trustee (incorporated by reference to Exhibit 4.1 to the
Berkshire Hathaway Energy Company
Current Report on Form 8-K dated October 23, 1997).
|
4.12
|
Form of Second Supplemental Indenture, dated as of September 22, 1998 by and between MidAmerican Energy Holdings Company and IBJ Schroder Bank & Trust Company, Trustee, relating to the 8.48% Senior Notes in the principal amount of $475,000,000 due 2028 (incorporated by reference to Exhibit 4.1 to the
Berkshire Hathaway Energy Company
Current Report on Form 8-K dated September 17, 1998).
|
4.13
|
Indenture, dated May 1, 2000, between NV Energy, Inc. (under its former name, Sierra Pacific Resources) and The Bank of New York, relating to the issuance of debt securities (incorporated by reference to Exhibit 4.1 to the NV Energy, Inc. Current Report on Form 8-K dated May 22, 2000).
|
4.14
|
Form of Officers' Certificate establishing the terms of NV Energy, Inc.'s 6.25% Senior Notes due 2020 (incorporated by reference to Exhibit 4.1 to the NV Energy, Inc. Current Report on Form 8-K dated November 19, 2010).
|
4.15
|
Trust Deed, dated December 15, 1997 among CE Electric UK Funding Company, AMBAC Insurance UK Limited and The Law Debenture Trust Corporation, p.l.c., Trustee (incorporated by reference to Exhibit 99.1 to the
Berkshire Hathaway Energy Company
Current Report on Form 8-K dated March 30, 2004).
|
4.16
|
Insurance and Indemnity Agreement, dated December 15, 1997 by and between CE Electric UK Funding Company and AMBAC Insurance UK Limited (incorporated by reference to Exhibit 99.2 to the
Berkshire Hathaway Energy Company
Current Report on Form 8-K dated March 30, 2004).
|
4.17
|
Supplemental Agreement to Insurance and Indemnity Agreement, dated September 19, 2001, by and between CE Electric UK Funding Company and AMBAC Insurance UK Limited (incorporated by reference to Exhibit 99.3 to the
Berkshire Hathaway Energy Company
Current Report on Form 8-K dated March 30, 2004).
|
4.18
|
Trust Indenture, dated as of September 10, 1999, by and between Cordova Funding Corporation and Chase Manhattan Bank and Trust Company, National Association, Trustee, relating to the $225,000,000 in principal amount of the 8.75% Senior Secured Bonds due 2019 (incorporated by reference to Exhibit 10.71 to the
Berkshire Hathaway Energy Company
Quarterly Report on Form 10-Q for the quarter ended March 31, 2004).
|
4.19
|
Trust Deed, dated as of February 4, 1998 among Yorkshire Power Finance Limited, Yorkshire Power Group Limited and Bankers Trustee Company Limited, Trustee, relating to the £200,000,000 in principal amount of the 7.25% Guaranteed Bonds due 2028 (incorporated by reference to Exhibit 10.74 to the
Berkshire Hathaway Energy Company
Quarterly Report on Form 10-Q for the quarter ended March 31, 2004).
|
4.20
|
First Supplemental Trust Deed, dated as of October 1, 2001, among Yorkshire Power Finance Limited, Yorkshire Power Group Limited and Bankers Trustee Company Limited, Trustee, relating to the £200,000,000 in principal amount of the 7.25% Guaranteed Bonds due 2028 (incorporated by reference to Exhibit 10.75 to the
Berkshire Hathaway Energy Company
Quarterly Report on Form 10-Q for the quarter ended March 31, 2004).
|
4.21
|
Third Supplemental Trust Deed, dated as of October 1, 2001, among Yorkshire Electricity Distribution plc, Yorkshire Electricity Group plc and Bankers Trustee Company Limited, Trustee, relating to the £200,000,000 in principal amount of the 9.25% Bonds due 2020 (incorporated by reference to Exhibit 10.76 to the
Berkshire Hathaway Energy Company
Quarterly Report on Form 10-Q for the quarter ended March 31, 2004).
|
4.22
|
First Supplemental Trust Deed, dated as of September 27, 2001, among Northern Electric Finance plc, Northern Electric plc, Northern Electric Distribution Limited and The Law Debenture Trust Corporation p.l.c., Trustee, relating to the £100,000,000 in principal amount of the 8.875% Guaranteed Bonds due 2020 (incorporated by reference to Exhibit 10.81 to the
Berkshire Hathaway Energy Company
Quarterly Report on Form 10-Q for the quarter ended March 31, 2004).
|
4.23
|
Trust Deed, dated as of January 17, 1995, by and between Yorkshire Electricity Group plc and Bankers Trustee Company Limited, Trustee, relating to the £200,000,000 in principal amount of the 9 1/4% Bonds due 2020 (incorporated by reference to Exhibit 10.83 to the
Berkshire Hathaway Energy Company
Quarterly Report on Form 10-Q for the quarter ended March 31, 2004).
|
Exhibit No.
|
Description
|
4.24
|
Master Trust Deed, dated as of October 16, 1995, by and between Northern Electric Finance plc, Northern Electric plc and The Law Debenture Trust Corporation p.l.c., Trustee, relating to the £100,000,000 in principal amount of the 8.875% Guaranteed Bonds due 2020 (incorporated by reference to Exhibit 10.70 to the
Berkshire Hathaway Energy Company
Annual Report on Form 10-K for the year ended December 31, 2004).
|
4.25
|
Trust Deed dated May 5, 2005 among Northern Electric Finance plc, Northern Electric Distribution Limited, Ambac Assurance UK Limited and HSBC Trustee (C.I.) Limited (incorporated by reference to Exhibit 99.1 to the
Berkshire Hathaway Energy Company
Quarterly Report on Form 10-Q for the quarter ended March 31, 2005).
|
4.26
|
Reimbursement and Indemnity Agreement, dated May 5, 2005 among Northern Electric Finance plc, Northern Electric Distribution Limited and Ambac Assurance UK Limited (incorporated by reference to Exhibit 99.2 to the
Berkshire Hathaway Energy Company
Quarterly Report on Form 10-Q for the quarter ended March 31, 2005).
|
4.27
|
Trust Deed, dated May 5, 2005 among Yorkshire Electricity Distribution plc, Ambac Assurance UK Limited and HSBC Trustee (C.I.) Limited (incorporated by reference to Exhibit 99.3 to the
Berkshire Hathaway Energy Company
Quarterly Report on Form 10-Q for the quarter ended March 31, 2005).
|
4.28
|
Reimbursement and Indemnity Agreement, dated May 5, 2005 between Yorkshire Electricity Distribution plc and Ambac Assurance UK Limited (incorporated by reference to Exhibit 99.4 to the
Berkshire Hathaway Energy Company
Quarterly Report on Form 10-Q for the quarter ended March 31, 2005).
|
4.29
|
Supplemental Trust Deed, dated May 5, 2005 among CE Electric UK Funding Company, Ambac Assurance UK Limited and The Law Debenture Trust Corporation plc (incorporated by reference to Exhibit 99.5 to the
Berkshire Hathaway Energy Company
Quarterly Report on Form 10-Q for the quarter ended March 31, 2005).
|
4.30
|
Second Supplemental Agreement to Insurance and Indemnity Agreement, dated May 5, 2005 by and between CE Electric UK Funding Company and Ambac Assurance UK Limited (incorporated by reference to Exhibit 99.6 to the
Berkshire Hathaway Energy Company
Quarterly Report on Form 10-Q for the quarter ended March 31, 2005).
|
4.31
|
£119,000,000 Finance Contract, dated July 2, 2010, by and between Northern Electric Distribution Limited and the European Investment Bank (incorporated by reference to Exhibit 4.1 to the
Berkshire Hathaway Energy Company
Quarterly Report on Form 10-Q for the quarter ended June 30, 2010).
|
4.32
|
Guarantee and Indemnity Agreement, dated July 2, 2010, by and between CE Electric UK Funding Company and the European Investment Bank (incorporated by reference to Exhibit 4.2 to the
Berkshire Hathaway Energy Company
Quarterly Report on Form 10-Q for the quarter ended June 30, 2010).
|
4.33
|
£151,000,000 Finance Contract, dated July 2, 2010, by and between Yorkshire Electricity Distribution plc and the European Investment Bank (incorporated by reference to Exhibit 4.3 to the
Berkshire Hathaway Energy Company
Quarterly Report on Form 10-Q for the quarter ended June 30, 2010).
|
4.34
|
Guarantee and Indemnity Agreement, dated July 2, 2010, by and between CE Electric UK Funding Company and the European Investment Bank (incorporated by reference to Exhibit 4.4 to the
Berkshire Hathaway Energy Company
Quarterly Report on Form 10-Q for the quarter ended June 30, 2010).
|
4.35
|
Trust Deed, dated as of July 5, 2012, among Northern Powergrid (Yorkshire) plc and HSBC Corporate Trustee Company (UK) Limited, relating to the £150,000,000 in principal amount of the 4.375% Bonds due 2032 (incorporated by reference to Exhibit 4.1 to the
Berkshire Hathaway Energy Company
Quarterly Report on Form 10-Q for the quarter ended June 30, 2012).
|
4.36
|
Trust Deed, dated as of April 1, 2015, among Northern Powergrid (Yorkshire) plc and HSBC Corporate Trustee Company (UK) Limited, relating to the £150,000,000 in principal amount of the 2.50% Bonds due 2025 (incorporated by reference to Exhibit 4.3 to the Berkshire Hathaway Energy Company Quarterly Report on Form 10-Q for the quarter ended March 31, 2015).
|
4.37
|
£120,000,000 Finance Contract, dated December 2, 2015, by and between Northern Powergrid (Northeast) Ltd and the European Investment Bank (incorporated by reference to Exhibit 4.1 to the Berkshire Hathaway Energy Company Quarterly Report on Form 10-Q for the quarter ended June 30, 2016).
|
Exhibit No.
|
Description
|
4.38
|
Guarantee and Indemnity Agreement, dated December 8, 2015, by and between Northern Powergrid Holdings Company and the European Investment Bank (incorporated by reference to Exhibit 4.2 to the Berkshire Hathaway Energy Company Quarterly Report on Form 10-Q for the quarter ended June 30, 2016).
|
4.39
|
£130,000,000 Finance Contract, dated December 2, 2015, by and between Northern Powergrid (Yorkshire) plc and the European Investment Bank (incorporated by reference to Exhibit 4.3 to the Berkshire Hathaway Energy Company Quarterly Report on Form 10-Q for the quarter ended June 30, 2016).
|
4.40
|
Guarantee and Indemnity Agreement, dated December 8, 2015, by and between Northern Powergrid Holdings Company and the European Investment Bank (incorporated by reference to Exhibit 4.4 to the Berkshire Hathaway Energy Company Quarterly Report on Form 10-Q for the quarter ended June 30, 2016).
|
4.41
|
Deed of Amendment and Consent, dated March 1, 2016, by and between Northern Powergrid Holdings Company, Northern Powergrid (Yorkshire) plc and the European Investment Bank (incorporated by reference to Exhibit 4.5 to the Berkshire Hathaway Energy Company Quarterly Report on Form 10-Q for the quarter ended June 30, 2016).
|
4.42
|
Fiscal Agency Agreement, dated as of July 15, 2008, by and between Northern Natural Gas Company and The Bank New York Mellon Trust Company, National Association, Fiscal Agent, relating to the $200,000,000 in principal amount of the 5.75% Senior Notes due 2018 (incorporated by reference to Exhibit 4.32 to the
Berkshire Hathaway Energy Company
Annual Report on Form 10-K for the year ended December 31, 2008).
|
4.43
|
Fiscal Agency Agreement, dated as of April 20, 2011, by and between Northern Natural Gas Company and The Bank of New York Mellon Trust Company, N.A., Fiscal Agent, relating to the $200,000,000 in principal amount of the 4.25% Senior Notes due 2021 (incorporated by reference to Exhibit 4.27 to the
Berkshire Hathaway Energy Company
Annual Report on Form 10-K for the year ended December 31, 2011).
|
4.44
|
Fiscal Agency Agreement, dated February 12, 2007, by and between Northern Natural Gas Company and The Bank of New York Trust Company, N.A., Fiscal Agent, relating to the $150,000,000 in principal amount of the 5.80% Senior Bonds due 2037 (incorporated by reference to Exhibit 99.1 to the
Berkshire Hathaway Energy Company
Current Report on Form 8-K dated February 12, 2007).
|
4.45
|
Fiscal Agency Agreement, dated August 27, 2012, by and between Northern Natural Gas Company and The Bank of New York Mellon Trust Company, N.A., Fiscal Agent, relating to the $250,000,000 in principal amount of the 4.10% Senior Bonds due 2042 (incorporated by reference to Exhibit 4.1 to the
Berkshire Hathaway Energy Company
Quarterly Report on Form 10-Q for the quarter ended September 30, 2012).
|
4.46
|
Trust Indenture, dated as of August 13, 2001, among Kern River Funding Corporation, Kern River Gas Transmission Company and JP Morgan Chase Bank, Trustee (incorporated by reference to Exhibit 10.48 to the
Berkshire Hathaway Energy Company
Annual Report on Form 10-K for the year ended December 31, 2003).
|
4.47
|
Third Supplemental Indenture, dated as of May 1, 2003, among Kern River Funding Corporation, Kern River Gas Transmission Company and JPMorgan Chase Bank, Trustee, relating to the $836,000,000 in principal amount of the 4.893% Senior Notes due 2018 (incorporated by reference to Exhibit 10.49 to the
Berkshire Hathaway Energy Company
Annual Report on Form 10-K for the year ended December 31, 2003).
|
4.48
|
Master Trust Indenture, dated November 21, 2005, by and between AltaLink Investments, L.P., AltaLink Investment Management Ltd. and BNY Trust Company of Canada (incorporated by reference to Exhibit 4.94 to the
Berkshire Hathaway Energy Company
Annual Report on Form 10-K for the year ended December 31, 2014).
|
4.49
|
Third Supplemental Indenture, dated December 15, 2010, by and between AltaLink Investments, L.P., AltaLink Investment Management Ltd. and BNY Trust Company of Canada (incorporated by reference to Exhibit 4.96 to the
Berkshire Hathaway Energy Company
Annual Report on Form 10-K for the year ended December 31, 2014).
|
Exhibit No.
|
Description
|
4.50
|
Series 12-1 Supplemental Indenture, dated June 5, 2012, by and between AltaLink Investments, L.P., AltaLink Investment Management Ltd. and BNY Trust Company of Canada (incorporated by reference to Exhibit 4.97 to the
Berkshire Hathaway Energy Company
Annual Report on Form 10-K for the year ended December 31, 2014).
|
4.51
|
Series 13-1 Supplemental Indenture, dated April 9, 2013, by and between AltaLink Investments, L.P., AltaLink Investment Management Ltd. and BNY Trust Company of Canada (incorporated by reference to Exhibit 4.98 to the
Berkshire Hathaway Energy Company
Annual Report on Form 10-K for the year ended December 31, 2014).
|
4.52
|
Series 15-1 Supplemental Indenture, dated March 6, 2015, by and between AltaLink Investments, L.P., AltaLink Investment Management Ltd. and BNY Trust Company of Canada, relating to C$200,000,000 in principal amount of the 2.244% Series 15-1 Senior Bonds due 2022 (incorporated by reference to Exhibit 4.2 to the Berkshire Hathaway Energy Company Quarterly Report on Form 10-Q for the quarter ended March 31, 2015).
|
4.53
|
2016 Supplemental Indenture, dated December 9, 2016, by and between AltaLink Investments, L.P., AltaLink Investment Management Ltd. and BNY Trust Company of Canada.
|
4.54
|
Amended and Restated Master Trust Indenture, dated April 28, 2003, by and between AltaLink, L.P., AltaLink Management Ltd. and BMO Trust Company (incorporated by reference to Exhibit 4.99 to the
Berkshire Hathaway Energy Company
Annual Report on Form 10-K for the year ended December 31, 2014).
|
4.55
|
Seventh Supplemental Indenture, dated April 28, 2003, by and between AltaLink, L.P., AltaLink Management Ltd. and BMO Trust Company (incorporated by reference to Exhibit 4.100 to the
Berkshire Hathaway Energy Company
Annual Report on Form 10-K for the year ended December 31, 2014).
|
4.56
|
Ninth Supplemental Indenture, dated May 9, 2006, by and between AltaLink, L.P., AltaLink Management Ltd. and BNY Trust Company of Canada (incorporated by reference to Exhibit 4.101 to the
Berkshire Hathaway Energy Company
Annual Report on Form 10-K for the year ended December 31, 2014).
|
4.57
|
Tenth Supplemental Indenture, dated May 21, 2008, by and between AltaLink, L.P., AltaLink Management Ltd. and BNY Trust Company of Canada (incorporated by reference to Exhibit 4.102 to the
Berkshire Hathaway Energy Company
Annual Report on Form 10-K for the year ended December 31, 2014).
|
4.58
|
Twelfth Supplemental Indenture, dated August 18, 2010, by and between AltaLink, L.P., AltaLink Management Ltd. and BNY Trust Company of Canada (incorporated by reference to Exhibit 4.103 to the
Berkshire Hathaway Energy Company
Annual Report on Form 10-K for the year ended December 31, 2014).
|
4.59
|
Sixteenth Supplemental Indenture, dated November 15, 2012, by and between AltaLink, L.P., AltaLink Management Ltd. and BNY Trust Company of Canada (incorporated by reference to Exhibit 4.104 to the
Berkshire Hathaway Energy Company
Annual Report on Form 10-K for the year ended December 31, 2014).
|
4.60
|
Seventeenth Supplemental Indenture, dated May 22, 2013, by and between AltaLink, L.P., AltaLink Management Ltd. and BNY Trust Company of Canada (incorporated by reference to Exhibit 4.105 to the
Berkshire Hathaway Energy Company
Annual Report on Form 10-K for the year ended December 31, 2014).
|
4.61
|
Eighteenth Supplemental Indenture, dated October 24, 2014, by and between AltaLink, L.P., AltaLink Management Ltd. and BNY Trust Company of Canada (incorporated by reference to Exhibit 4.106 to the
Berkshire Hathaway Energy Company
Annual Report on Form 10-K for the year ended December 31, 2014).
|
4.62
|
Nineteenth Supplemental Indenture, dated October 24, 2014, by and between AltaLink, L.P., AltaLink Management Ltd. and BNY Trust Company of Canada (incorporated by reference to Exhibit 4.107 to the
Berkshire Hathaway Energy Company
Annual Report on Form 10-K for the year ended December 31, 2014).
|
Exhibit No.
|
Description
|
4.63
|
Twentieth Supplemental Indenture, dated June 30, 2015, by and between AltaLink, L.P., AltaLink Management Ltd. and BNY Trust Company of Canada, relating to C$350,000,000 in principal amount of the 4.09% Series 2015-1 Medium-Term Notes due 2045 (incorporated by reference to Exhibit 4.5 to the Berkshire Hathaway Energy Company Quarterly Report on Form 10-Q for the quarter ended June 30, 2015).
|
4.64
|
Indenture, dated as of February 24, 2012, by and between Topaz Solar Farms LLC and The Bank of New York Mellon Trust Company, N.A., as Trustee, relating to the $850,000,000 in principal amount of the 5.75% Series A Senior Secured Notes due 2039 (incorporated by reference to Exhibit 4.56 to the
Berkshire Hathaway Energy Company
Annual Report on Form 10-K for the year ended December 31, 2011).
|
4.65
|
First Supplemental Indenture, dated as of April 15, 2013, between Topaz Solar Farms LLC, as Issuer, and The Bank of New York Mellon Trust Company, N.A., as Trustee, relating to the $250,000,000 in principal amount of the 4.875% Series B Senior Secured Notes due 2039 (incorporated by reference to Exhibit 4.1 to the
Berkshire Hathaway Energy Company
Quarterly Report on Form 10-Q for the quarter ended June 30, 2013).
|
4.66
|
Indenture, dated as of June 27, 2013, between Solar Star Funding, LLC, as Issuer, and Wells Fargo Bank, National Association, as Trustee, relating to the $1,000,000,000 in principal amount of the 5.375% Series A Senior Secured Notes due 2035 (incorporated by reference to Exhibit 4.2 to the
Berkshire Hathaway Energy Company
Quarterly Report on Form 10-Q for the quarter ended June 30, 2013).
|
4.67
|
First Supplemental Indenture, dated as of March 12, 2015, between Solar Star Funding, LLC, as Issuer, and Wells Fargo Bank, National Association, as Trustee, relating to the $325,000,000 in principal amount of the 3.95% Series B Senior Secured Notes due 2035 (incorporated by reference to Exhibit 4.1 to the Berkshire Hathaway Energy Company Quarterly Report on Form 10-Q for the quarter ended March 31, 2015).
|
4.68
|
Indenture, dated as of March 2, 1999, by and between CE Generation, LLC and Chase Manhattan Bank and Trust Company, National Association (incorporated by reference to Exhibit 4.1 to the CE Generation, LLC Registration Statement No. 333-89521 dated October 22, 1999).
|
4.69
|
First Supplemental Indenture, dated as of February 4, 2000, by and between CE Generation, LLC and Chase Manhattan Bank and Trust Company, National Association (incorporated by reference to Exhibit 4.2 to the CE Generation, LLC Registration Statement No. 333-89521 dated October 22, 1999).
|
4.70
|
Second Supplemental Indenture, dated as of March 6, 2000, by and between CE Generation, LLC and Chase Manhattan Bank and Trust Company, National Association (incorporated by reference to Exhibit 4.89 to the
Berkshire Hathaway Energy Company
Annual Report on Form 10-K for the year ended December 31, 2014).
|
4.71
|
Indenture, dated July 21, 1995, by and between Salton Sea Funding Corporation and Chase Manhattan Bank and Trust Company, National Association (incorporated by reference to Exhibit 4.1(a) to the Salton Sea Funding Corporation Registration Statement No. 333-95538 dated January 10, 1996).
|
4.72
|
Fourth Supplemental Indenture, dated October 13, 1998, by and between Salton Sea Funding Corporation and Chase Manhattan Bank and Trust Company, National Association (incorporated by reference to Exhibit 4.1(e) to the Salton Sea Funding Corporation Annual Report on Form 10-K/A for the year ended December 31, 1998).
|
4.73
|
Fifth Supplemental Indenture, dated February 16, 1999, by and between Salton Sea Funding Corporation and Chase Manhattan Bank and Trust Company, National Association (incorporated by reference to Exhibit 4.1(f) to the Salton Sea Funding Corporation Registration Statement No. 333-79581 dated June 29, 1999).
|
4.74
|
Sixth Supplemental Indenture, dated June 29, 1999, by and between Salton Sea Funding Corporation and Chase Manhattan Bank and Trust Company, National Association (incorporated by reference to Exhibit 4.1(g) to the Salton Sea Funding Corporation Registration Statement No. 333-79581 dated June 29, 1999).
|
Exhibit No.
|
Description
|
10.1
|
$2,000,000,000 Credit Agreement, dated as of June 30, 2016, among Berkshire Hathaway Energy Company, as Borrower, the Banks, Financial Institutions and Other Institutional Lenders, as Initial Lenders, MUFG Union Bank, N.A., as Administrative Agent, and the LC Issuing Banks (incorporated by reference to Exhibit 10.1 to the Berkshire Hathaway Energy Company Quarterly Report on Form 10-Q for the quarter ended June 30, 2016).
|
10.2
|
Amended and Restated £150,000,000 Facility Agreement, dated April 30, 2015, among Northern Powergrid Holdings Company, as Guarantor and Borrower, Northern Powergrid (Yorkshire) plc and Northern Powergrid (Northeast) Limited as Borrowers, and Abbey National Treasury Services plc, Lloyds Bank plc and The Royal Bank of Scotland plc, as Original Lenders (incorporated by reference to Exhibit 10.2 to the Berkshire Hathaway Energy Company Quarterly Report on Form 10-Q for the quarter ended June 30, 2016).
|
10.3
|
Amended and Restated Credit Agreement, dated as of July 30, 2015, among AltaLink Investments, L.P., as borrower, AltaLink Investment Management Ltd., as general partner, The Royal Bank of Canada, as administrative agent, and Lenders (incorporated by reference to Exhibit 10.3 to the Berkshire Hathaway Energy Company Quarterly Report on Form 10-Q for the quarter ended June 30, 2016).
|
10.4
|
First Amending Agreement to Amended and Restated Credit Agreement, dated as of November 20, 2015, among AltaLink Investments, L.P., as borrower, AltaLink Investment Management Ltd., as general partner, The Royal Bank of Canada, as administrative agent, and Lenders (incorporated by reference to Exhibit 10.4 to the Berkshire Hathaway Energy Company Quarterly Report on Form 10-Q for the quarter ended June 30, 2016).
|
10.5
|
Second Amending Agreement to Amended and Restated Credit Agreement, dated as of December 14, 2015, among AltaLink Investments, L.P., as borrower, AltaLink Investment Management Ltd., as general partner, The Royal Bank of Canada, as administrative agent, and Lenders (incorporated by reference to Exhibit 10.5 to the Berkshire Hathaway Energy Company Quarterly Report on Form 10-Q for the quarter ended June 30, 2016).
|
10.6
|
Third Amending Agreement to Amended and Restated Credit Agreement, dated as of July 8, 2016, among AltaLink Investments, L.P., as borrower, AltaLink Investment Management Ltd., as general partner, The Royal Bank of Canada, as administrative agent, and Lenders (incorporated by reference to Exhibit 10.6 to the Berkshire Hathaway Energy Company Quarterly Report on Form 10-Q for the quarter ended June 30, 2016).
|
10.7
|
Fourth Amending Agreement to Amended and Restated Credit Agreement, dated as of December 15, 2016, among AltaLink Investments, L.P., as borrower, AltaLink Investment Management Ltd., as general partner, The Royal Bank of Canada, as administrative agent, and Lenders.
|
10.8
|
Credit Agreement, dated as of December 9, 2016, among AltaLink Investments, L.P., as borrower, AltaLink Investment Management Ltd., as general partner, The Royal Bank of Canada, as administrative agent, and Lenders.
|
10.9
|
Fourth Amended and Restated Credit Agreement, dated as of December 17, 2015, among AltaLink, L.P., as borrower, AltaLink Management Ltd., as general partner, The Bank of Nova Scotia, as administrative agent, and Lenders (incorporated by reference to Exhibit 10.8 to the Berkshire Hathaway Energy Company Quarterly Report on Form 10-Q for the quarter ended June 30, 2016).
|
10.10
|
First Amending Agreement to Fourth Amended and Restated Credit Agreement, dated as of December 15, 2016, among AltaLink, L.P., as borrower, AltaLink Management Ltd., as general partner, The Bank of Nova Scotia, as administrative agent, and Lenders.
|
10.11
|
Third Amended and Restated Credit Agreement, dated as of December 17, 2015, among AltaLink, L.P., as borrower, AltaLink Management Ltd., as general partner, The Bank of Nova Scotia, as administrative agent, and Lenders (incorporated by reference to Exhibit 10.7 to the Berkshire Hathaway Energy Company Quarterly Report on Form 10-Q for the quarter ended June 30, 2016).
|
10.12
|
First Amending Agreement to Third Amended and Restated Credit Agreement, dated as of December 15, 2016, among AltaLink, L.P., as borrower, AltaLink Management Ltd., as general partner, The Bank of Nova Scotia, as administrative agent, and Lenders.
|
10.13*
|
Summary of Key Terms of Compensation Arrangements with
Berkshire Hathaway Energy Company
Named Executive Officers and Directors.
|
Exhibit No.
|
Description
|
10.14*
|
Amended and Restated Employment Agreement, dated February 25, 2008, by and between MidAmerican Energy Holdings Company and Gregory E. Abel (incorporated by reference to Exhibit 10.3 to the
Berkshire Hathaway Energy Company
Annual Report on Form 10-K for the year ended December 31, 2007).
|
10.15*
|
Amended and Restated Employment Agreement, dated February 25, 2008, by and between MidAmerican Energy Holdings Company and Patrick J. Goodman (incorporated by reference to Exhibit 10.5 to the
Berkshire Hathaway Energy Company
Annual Report on Form 10-K for the year ended December 31, 2007).
|
10.16*
|
CalEnergy Company, Inc. Voluntary Deferred Compensation Plan, effective December 1, 1997, First Amendment, dated as of August 17, 1999, and Second Amendment effective March 14, 2000 (incorporated by reference to Exhibit 10.50 to the MidAmerican Energy Holdings Company Registration Statement No. 333-101699 dated December 6, 2002).
|
10.17*
|
Berkshire Hathaway Energy Company Executive Voluntary Deferred Compensation Plan restated effective as of January 1, 2007 (incorporated by reference to Exhibit 10.9 to the
Berkshire Hathaway Energy Company
Annual Report on Form 10-K for the year ended December 31, 2007).
|
10.18*
|
MidAmerican Energy Company First Amended and Restated Supplemental Retirement Plan for Designated Officers dated as of May 10, 1999 amended on February 25, 2008 to be effective as of January 1, 2005 (incorporated by reference to Exhibit 10.10 to the
Berkshire Hathaway Energy Company
Annual Report on Form 10-K for the year ended December 31, 2007).
|
10.19*
|
Berkshire Hathaway Energy Company
Long-Term Incentive Partnership Plan as Amended and Restated January 1, 2014 (incorporated by reference to Exhibit 10.9 to the Berkshire Hathaway Energy Company Annual Report on Form 10-K for the year ended December 31, 2014).
|
14.1
|
Berkshire Hathaway Energy Company Code of Ethics For Chief Executive Officer, Chief Financial Officer and Other Covered Officers (incorporated by reference to Exhibit 14.1 to the Berkshire Hathaway Energy Company Annual Report on Form 10-K for the year ended December 31, 2015).
|
21.1
|
Subsidiaries of the Registrant.
|
23.1
|
Consent of Deloitte & Touche LLP.
|
24.1
|
Power of Attorney.
|
31.1
|
Principal Executive Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
|
31.2
|
Principal Financial Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
|
32.1
|
Principal Executive Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
|
32.2
|
Principal Financial Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
|
3.4
|
Third Restated Articles of Incorporation of PacifiCorp (incorporated by reference to Exhibit (3)a to the PacifiCorp Annual Report on Form 10-K for the year ended December 31, 1996).
|
3.5
|
Bylaws of PacifiCorp, as amended May 23, 2005 (incorporated by reference to Exhibit 3.2 to the PacifiCorp Annual Report on Form 10-K for the year ended March 31, 2005).
|
10.20*
|
Summary of Key Terms of Compensation Arrangements with PacifiCorp's Named Executive Officers and Directors.
|
10.21*
|
PacifiCorp Executive Voluntary Deferred Compensation Plan (incorporated by reference to Exhibit 10.3 to the PacifiCorp Annual Report on Form 10-K for the year ended December 31, 2007).
|
10.22*
|
Supplemental Executive Retirement Plan (incorporated by reference to Exhibit 10.7 to the PacifiCorp Annual Report on Form 10-K for the year ended March 31, 2005).
|
10.23*
|
Amendment No. 10 to PacifiCorp Supplemental Executive Retirement Plan dated June 2, 2006 (incorporated by reference to Exhibit 10.5 to the PacifiCorp Quarterly Report on Form 10-Q for the quarter ended June 30, 2006).
|
Exhibit No.
|
Description
|
10.24*
|
Amendment No. 11 to PacifiCorp Supplemental Executive Retirement Plan dated June 2, 2006 (incorporated by reference to Exhibit 10.6 to the PacifiCorp Quarterly Report on Form 10-Q for the quarter ended June 30, 2006).
|
10.25*
|
Amendment No. 1 to the PacifiCorp Executive Voluntary Deferred Compensation Plan dated October 28, 2008 (incorporated by reference to Exhibit 10.10 to the PacifiCorp Annual Report on Form 10-K for the year ended December 31, 2009).
|
10.26*
|
Amendment No. 2 to the PacifiCorp Executive Voluntary Deferred Compensation Plan dated October 16, 2012 (incorporated by reference to Exhibit 10.11 to the PacifiCorp Annual Report on Form 10-K for the year ended December 31, 2012).
|
10.27*
|
PacifiCorp Long-Term Incentive Partnership Plan effective January 1, 2014 (incorporated by reference to Exhibit 10.10 to the PacifiCorp Annual Report on Form 10-K for the year ended December 31, 2014).
|
12.1
|
Statements of Computation of Ratio of Earnings to Fixed Charges.
|
12.2
|
Statements of Computation of Ratio of Earnings to Combined Fixed Charges and Preferred Stock Dividends.
|
14.2
|
Code of Ethics (incorporated by reference to Exhibit 14.1 to the PacifiCorp Transition Report on Form 10-K for the nine-month period ended December 31, 2006).
|
23.2
|
Consent of Deloitte & Touche LLP.
|
31.3
|
Principal Executive Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
|
31.4
|
Principal Financial Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
|
32.3
|
Principal Executive Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
|
32.4
|
Principal Financial Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
|
Exhibit No.
|
Description
|
4.75
|
Mortgage and Deed of Trust dated as of January 9, 1989, between PacifiCorp and The Bank of New York Mellon Trust Company, N.A., as successor Trustee, incorporated by reference to Exhibit 4-E to the PacifiCorp Form 8-B, as supplemented and modified by 28 Supplemental Indentures, each incorporated by reference, as follows:
|
Exhibit
|
|
PacifiCorp
|
|
|
Number
|
|
File Type
|
|
File Date
|
(4)(b)
|
|
SE
|
|
November 2, 1989
|
(4)(a)
|
|
8-K
|
|
January 9, 1990
|
4(a)
|
|
8-K
|
|
September 11, 1991
|
4(a)
|
|
8-K
|
|
January 7, 1992
|
4(a)
|
|
10-Q
|
|
Quarter ended March 31, 1992
|
4(a)
|
|
10-Q
|
|
Quarter ended September 30, 1992
|
4(a)
|
|
8-K
|
|
April 1, 1993
|
4(a)
|
|
10-Q
|
|
Quarter ended September 30, 1993
|
(4)b
|
|
10-Q
|
|
Quarter ended June 30, 1994
|
(4)b
|
|
10-K
|
|
Year ended December 31, 1994
|
(4)b
|
|
10-K
|
|
Year ended December 31, 1995
|
(4)b
|
|
10-K
|
|
Year ended December 31, 1996
|
(4)b
|
|
10-K
|
|
Year ended December 31, 1998
|
99(a)
|
|
8-K
|
|
November 21, 2001
|
4.1
|
|
10-Q
|
|
Quarter ended June 30, 2003
|
99
|
|
8-K
|
|
September 8, 2003
|
4
|
|
8-K
|
|
August 24, 2004
|
4
|
|
8-K
|
|
June 13, 2005
|
4.2
|
|
8-K
|
|
August 14, 2006
|
4
|
|
8-K
|
|
March 14, 2007
|
4.1
|
|
8-K
|
|
October 3, 2007
|
4.1
|
|
8-K
|
|
July 17, 2008
|
4.1
|
|
8-K
|
|
January 8, 2009
|
4.1
|
|
8-K
|
|
May 12, 2011
|
4.1
|
|
8-K
|
|
January 6, 2012
|
4.1
|
|
8-K
|
|
June 6, 2013
|
4.1
|
|
8-K
|
|
March 13, 2014
|
4.1
|
|
8-K
|
|
June 19, 2015
|
10.28
|
$400,000,000 Credit Agreement, dated as of June 30, 2016, among PacifiCorp, as Borrower, the Banks, Financial Institutions and Other Institutional Lenders, as Initial Lenders, JPMorgan Chase Bank, N.A., as Administrative Agent, and the LC Issuing Banks (incorporated by reference to Exhibit 10.9 to the PacifiCorp Quarterly Report on Form 10-Q for the quarter ended June 30, 2016).
|
10.29
|
$600,000,000 Credit Agreement, dated as of March 27, 2013, among PacifiCorp, as Borrower, the Banks, Financial Institutions and Other Institutional Lenders, as Initial Lenders, JPMorgan Chase Bank, N.A., as Administrative Agent and Swingline Lender, and the LC Issuing Banks (incorporated by reference to Exhibit 10.1 to the PacifiCorp Quarterly Report on Form 10-Q for the quarter ended March 31, 2013).
|
95
|
Mine Safety Disclosures Required by the Dodd-Frank Wall Street Reform and Consumer Protection Act.
|
Exhibit No.
|
Description
|
3.6
|
Restated Articles of Incorporation of MidAmerican Energy Company, as amended October 27, 1998. (incorporated by reference to Exhibit 3.3 to the MidAmerican Energy Company Quarterly Report on Form 10-Q for the quarter ended September 30, 1998).
|
3.7
|
Restated Bylaws of MidAmerican Energy Company, as amended July 24, 1996. (incorporated by reference to Exhibit 3.1 to the MidAmerican Energy Company Quarterly Report on Form 10-Q for the quarter ended June 30, 1996).
|
14.3
|
Code of Ethics for Chief Executive Officer, Chief Financial Officer and Chief Accounting Officer. (incorporated by reference to Exhibit 14.1 to the MidAmerican Energy Company Annual Report on Form 10-K for the year ended December 31, 2003).
|
23.3
|
Consent of Deloitte & Touche LLP.
|
31.5
|
Principal Executive Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
|
31.6
|
Principal Financial Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
|
32.5
|
Principal Executive Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
|
32.6
|
Principal Financial Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
|
3.8
|
Articles of Organization of MidAmerican Funding, LLC (incorporated by reference to Exhibit 3.1 to the MidAmerican Funding, LLC Registration Statement No. 333-90553 dated November 8, 1999).
|
3.9
|
Operating Agreement of MidAmerican Funding, LLC (incorporated by reference to Exhibit 3.2 to the MidAmerican Funding, LLC Registration Statement No. 333-90553 dated November 8, 1999).
|
3.10
|
Amendment No. 1 to the Operating Agreement of MidAmerican Funding, LLC dated as of February 9, 2010 (incorporated by reference to Exhibit 3.3 to the MidAmerican Funding, LLC Annual Report on Form 10-K for the year ended December 31, 2010).
|
14.4
|
Code of Ethics for Chief Executive Officer, Chief Financial Officer and Chief Accounting Officer (incorporated by reference to Exhibit 14.2 to the MidAmerican Funding, LLC Annual Report on Form 10-K for the year ended December 31, 2003).
|
31.7
|
Principal Executive Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
|
31.8
|
Principal Financial Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
|
32.7
|
Principal Executive Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
|
32.8
|
Principal Financial Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
|
4.76
|
Form of Indenture, by and between MidAmerican Energy Company and The Bank of New York, Trustee (incorporated by reference to Exhibit 4.1 to the MidAmerican Energy Company Registration Statement No. 333-59760 dated January 31, 2002).
|
4.77
|
First Supplemental Indenture, dated as of February 8, 2002, by and between MidAmerican Energy Company and The Bank of New York, Trustee (incorporated by reference to Exhibit 4.3 to the MidAmerican Energy Company Annual Report on Form 10-K for the year ended December 31, 2004).
|
4.78
|
Fourth Supplemental Indenture, dated November 1, 2005, by and between MidAmerican Energy Company and The Bank of New York Trust Company, NA, Trustee (incorporated by reference to Exhibit 4.1 to the MidAmerican Energy Company Annual Report on Form 10-K for the year ended December 31, 2005).
|
4.79
|
Indenture, dated as of October 1, 2006, by and between MidAmerican Energy Company and The Bank of New York Trust Company, N.A., Trustee (incorporated by reference to Exhibit 4.1 to the MidAmerican Energy Company Quarterly Report on Form 10-Q for the quarter ended September 30, 2006).
|
Exhibit No.
|
Description
|
4.80
|
First Supplemental Indenture, dated as of October 6, 2006, by and between MidAmerican Energy Company and The Bank of New York Trust Company, N.A., Trustee relating to the 5.80% Notes due 2036 (incorporated by reference to Exhibit 4.2 to the MidAmerican Energy Company Quarterly Report on Form 10-Q for the quarter ended September 30, 2006).
|
4.81
|
Second Supplemental Indenture, dated June 29, 2007, by and between MidAmerican Energy Company and The Bank of New York Trust Company, N.A., Trustee relating to the 5.95% Notes due 2017 (incorporated by reference to Exhibit 4.1 to the MidAmerican Energy Company Current Report on Form 8-K dated June 29, 2007).
|
4.82
|
Third Supplemental Indenture, dated March 25, 2008, by and between MidAmerican Energy Company and The Bank of New York Trust Company, Trustee, relating to the 5.30% Notes due 2018 (incorporated by reference to Exhibit 4.1 to the MidAmerican Energy Company Current Report on Form 8-K dated March 25, 2008).
|
4.83
|
Indenture, dated as of September 9, 2013, between MidAmerican Energy Company and The Bank of New York Mellon Trust Company, N.A., as trustee (incorporated by reference to Exhibit 4.1 to the MidAmerican Energy Company Current Report on Form 8-K dated September 13, 2013).
|
4.84
|
First Supplemental Indenture, dated as of September 19, 2013, between MidAmerican Energy Company and The Bank of New York Mellon Trust Company, N.A., as trustee (incorporated by reference to Exhibit 4.1 to the MidAmerican Energy Company Current Report on Form 8-K dated September 19, 2013).
|
4.85
|
Specimen of 2.40% First Mortgage Bonds due 2019 (incorporated by reference to Exhibit 4.2 to the MidAmerican Energy Company Current Report on Form 8-K dated September 19, 2013).
|
4.86
|
Specimen of 3.70% First Mortgage Bonds due 2023 (incorporated by reference to Exhibit 4.3 to the MidAmerican Energy Company Current Report on Form 8-K dated September 19, 2013).
|
4.87
|
Specimen of 4.80% First Mortgage Bonds due 2043 (incorporated by reference to Exhibit 4.4 to the MidAmerican Energy Company Current Report on Form 8-K dated September 19, 2013).
|
4.88
|
Amendment No. 1 to the First Supplemental Indenture, dated as of April 3, 2014, by and between MidAmerican Energy Company and The Bank of New York Mellon Trust Company, N.A., to the Indenture dated as of September 9, 2013 (incorporated by reference to Exhibit 4.1 to the MidAmerican Energy Company Current Report on Form 8-K dated April 3, 2014).
|
4.89
|
Second Supplemental Indenture, dated as of April 3, 2014, by and between MidAmerican Energy Company and The Bank of New York Mellon Trust Company, N.A., to the Indenture dated as of September 9, 2013 (incorporated by reference to Exhibit 4.2 to the MidAmerican Energy Company Current Report on Form 8-K dated April 3, 2014).
|
4.90
|
Specimen of 3.50% First Mortgage Bonds due 2024 (incorporated by reference to Exhibit 4.4 to the MidAmerican Energy Company Current Report on Form 8-K dated April 3, 2014).
|
4.91
|
Specimen of 4.40% First Mortgage Bonds due 2044 (incorporated by reference to Exhibit 4.5 to the MidAmerican Energy Company Current Report on Form 8-K dated April 3, 2014).
|
4.92
|
Amendment No. 1 to the Second Supplemental Indenture, dated as of October 15, 2015, by and between MidAmerican Energy Company and The Bank of New York Mellon Trust Company, N.A., to the Indenture dated as of September 9, 2013 (incorporated by reference to Exhibit 4.1 to the MidAmerican Energy Company Current Report on Form 8-K dated October 15, 2015).
|
4.93
|
Third Supplemental Indenture, dated as of October 15, 2015, by and between MidAmerican Energy Company and The Bank of New York Mellon Trust Company, N.A., to the Indenture dated as of September 9, 2013 (incorporated by reference to Exhibit 4.2 to the MidAmerican Energy Company Current Report on Form 8-K dated October 15, 2015).
|
4.94
|
Specimen of 3.50% First Mortgage Bonds due 2024 (incorporated by reference to Exhibit 4.3 to the MidAmerican Energy Company Current Report on Form 8-K dated October 15, 2015).
|
4.95
|
Specimen of 4.25% First Mortgage Bonds due 2046 (incorporated by reference to Exhibit 4.5 to the MidAmerican Energy Company Current Report on Form 8-K dated October 15, 2015).
|
Exhibit No.
|
Description
|
4.96
|
Fourth Supplemental Indenture, dated as of December 8, 2016, by and between MidAmerican Energy Company and The Bank of New York Mellon Trust Company, N.A., to the Indenture dated as of September 9, 2013.
|
4.97
|
Fifth Supplemental Indenture, dated as of February 1, 2017, by and between MidAmerican Energy Company and The Bank of New York Mellon Trust Company, N.A., to the Indenture dated as of September 9, 2013 (incorporated by reference to Exhibit 4.1 to the MidAmerican Energy Company Current Report on Form 8-K dated February 1, 2017).
|
4.98
|
Specimen of 3.10% First Mortgage Bonds due 2027 (incorporated by reference to Exhibit 4.2 to the MidAmerican Energy Company Current Report on Form 8-K dated February 1, 2017).
|
4.99
|
Specimen of 3.95% First Mortgage Bonds due 2047 (incorporated by reference to Exhibit 4.3 to the MidAmerican Energy Company Current Report on Form 8-K dated February 1, 2017).
|
4.100
|
Mortgage, Security Agreement, Fixture Filing and Financing Statement, dated as of September 9, 2013, from MidAmerican Energy Company to The Bank of New York Mellon Trust Company, N.A., as collateral trustee (incorporated by reference to Exhibit 4.2 to the MidAmerican Energy Company Current Report on Form 8-K dated September 13, 2013).
|
4.101
|
Intercreditor and Collateral Trust Agreement, dated as of September 9, 2013, among MidAmerican Energy Company, The Bank of New York Mellon Trust Company, N.A., as trustee, and The Bank of New York Mellon Trust Company, N.A., as collateral trustee (incorporated by reference to Exhibit 4.3 to the MidAmerican Energy Company Current Report on Form 8-K dated September 13, 2013).
|
4.102
|
Form of Indenture, between MidAmerican Energy Company and the Trustee, (Senior Unsecured Debt Securities) (incorporated by reference to Exhibit 4.1 to the MidAmerican Energy Company Registration Statement No. 333-192077 dated November 4, 2013).
|
4.103
|
Form of Indenture, between MidAmerican Energy Company and the Trustee, (Subordinated Unsecured Debt Securities) (incorporated by reference to Exhibit 4.2 to the MidAmerican Energy Company Registration Statement No. 333-192077 dated November 4, 2013).
|
10.30
|
$600,000,000 Credit Agreement, dated as of March 27, 2013, among MidAmerican Energy Company, as Borrower, the Banks, Financial Institutions and Other Institutional Lenders, as Initial Lenders, JPMorgan Chase Bank, N.A., as Administrative Agent and Swingline Lender, and the LC Issuing Banks (incorporated by reference to Exhibit 10.1 to the MidAmerican Energy Company Quarterly Report on Form 10-Q for the quarter ended March 31, 2013).
|
4.104
|
Indenture and First Supplemental Indenture, dated March 11, 1999, by and between MidAmerican Funding, LLC and IBJ Whitehall Bank & Trust Company, Trustee, relating to the $325 million Senior Bonds (incorporated by reference to Exhibits 4.1 and 4.2 to the MidAmerican Funding, LLC Registration Statement No. 333-905333 dated November 8, 1999).
|
3.11
|
Restated Articles of Incorporation of Nevada Power Company, dated July 28, 1999 (incorporated by reference to Exhibit 3(B) to the Nevada Power Company Annual Report on Form 10-K for the year ended December 31, 1999).
|
3.12
|
Amended and Restated By-Laws of Nevada Power Company dated July 28, 1999 (incorporated by reference to Exhibit 3(C) to the Nevada Power Company Annual Report on Form 10-K for the year ended December 31, 1999).
|
10.31
|
Transmission Use and Capacity Exchange Agreement between Nevada Power Company, Sierra Pacific Power Company and Great Basin Transmission, LLC dated August 20, 2010 (incorporated by reference to Exhibit 10.1 to the Nevada Power Company Quarterly Report on Form 10-Q for the quarter ended September 30, 2010).
|
Exhibit No.
|
Description
|
10.32
|
Financing Agreement between Clark County, Nevada and Nevada Power Company, dated August 1, 2006 (relating to Clark County, Nevada $39,500,000 Pollution Control Refund Revenue Bonds Series 2006) (incorporated by reference to Exhibit 10.1 to the Nevada Power Company Quarterly Report on Form 10-Q for the quarter ended September 30, 2006).
|
10.33
|
Financing Agreement between Coconino County, Arizona Pollution Control Corporation and Nevada Power Company, dated August 1, 2006 (relating to Coconino County, Arizona $13,000,000 Pollution Control Corporation Refunding Revenue Bonds Series 2006B) (incorporated by reference to Exhibit 10.3 to the Nevada Power Company Quarterly Report on Form 10-Q for the quarter ended September 30, 2006).
|
10.34
|
Financing Agreement between Coconino County, Arizona Pollution Control Corporation and Nevada Power Company, dated August 1, 2006 (relating to Coconino County, Arizona $40,000,000 Pollution Control Corporation Refunding Revenue Bonds Series 2006A) (incorporated by reference to Exhibit 10.2 to the Nevada Power Company Quarterly Report on Form 10-Q for the quarter ended September 30, 2006).
|
12.3
|
Computation of Ratios of Earnings to Fixed Charges.
|
14.5
|
Code of Ethics for Chief Executive Officer, Chief Financial Officer and Other Covered Officers (incorporated by reference to Exhibit 14.1 to the Nevada Power Company Annual Report on Form 10-K for the year ended December 31, 2013).
|
23.4
|
Consent of Deloitte & Touche LLP.
|
31.9
|
Principal Executive Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
|
31.10
|
Principal Financial Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
|
32.9
|
Principal Executive Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
|
32.10
|
Principal Financial Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
|
4.105
|
General and Refunding Mortgage Indenture, dated May 1, 2001, between Nevada Power Company and The Bank of New York, as Trustee (incorporated by reference to Exhibit 4.1(a) to the Nevada Power Company Quarterly Report on Form 10-Q for the quarter ended June 30, 2001).
|
4.106
|
First Supplemental Indenture, dated as of May 1, 2001 (incorporated by reference to Exhibit 4.1(b) to the Nevada Power Company Quarterly Report on Form 10-Q for the quarter ended June 30, 2001).
|
4.107
|
Second Supplemental Indenture, dated as of October 1, 2001 (incorporated by reference to Exhibit 4(A) to the Nevada Power Company Annual Report on Form 10-K for the year ended December 31, 2001).
|
4.108
|
Officer's Certificate establishing the terms of Nevada Power Company's 6.650% General and Refunding Mortgage Notes, Series N, due 2036 (incorporated by reference to Exhibit 4.1 to the Nevada Power Company Form 10-Q for the quarter ended March 31, 2006).
|
4.109
|
Officer's Certificate establishing the terms of Nevada Power Company's 6.50% General and Refunding Mortgage Notes, Series O, due 2018 (incorporated by reference to Exhibit 4.7 to the Nevada Power Company Registration Statement No. 333-134801 dated June 7, 2006).
|
4.110
|
Officer's Certificate establishing the terms of Nevada Power Company's 6.750% General and Refunding Mortgage Notes, Series R, due 2037 (incorporated by reference to Exhibit 4.1 to the Nevada Power Company Current Report on Form 8-K dated June 27, 2007).
|
4.111
|
Officer's Certificate establishing the terms of Nevada Power Company's 6.50% General and Refunding Mortgage Notes, Series S, due 2018 (incorporated by reference to Exhibit 4.1 to the Nevada Power Company Current Report on Form 8-K dated July 28, 2008).
|
4.112
|
Officer's Certificate establishing the terms of Nevada Power Company d/b/a NV Energy's 7.125% General and Refunding Mortgage Notes, Series V, due 2019 (incorporated by reference to Exhibit 4.1 to the Nevada Power Company Current Report on Form 8-K dated February 26, 2009).
|
Exhibit No.
|
Description
|
4.113
|
Officer's Certificate establishing the terms of Nevada Power Company d/b/a NV Energy's 5.375% General and Refunding Mortgage Notes, Series X, due 2040 (incorporated by reference to Exhibit 4.1 to Nevada Power Company Current Report on Form 8-K dated September 10, 2010).
|
4.114
|
Officer's Certificate establishing the terms of Nevada Power Company d/b/a NV Energy's 5.45% General and Refunding Mortgage Notes, Series Y, due 2041 (incorporated by reference to Exhibit 4.1 to the Nevada Power Company Current Report on Form 8-K dated May 10, 2011).
|
10.35
|
$400,000,000 Amended and Restated Credit Agreement, dated as of June 27, 2014, among Nevada Power Company, as Borrower, the Initial Lenders, Wells Fargo Bank, National Association, as Administrative Agent and Swingline Lender, and the LC Issuing Banks (incorporated by reference to Exhibit 10.1 to the Nevada Power Company Current Report on Form 8-K dated June 27, 2014).
|
3.13
|
Restated Articles of Incorporation of Sierra Pacific Power Company, dated October 25, 2006 (incorporated by reference to Exhibit 3.1 to the Sierra Pacific Power Company Quarterly Report on Form 10-Q for quarter ended September 30, 2006).
|
3.14
|
By-Laws of Sierra Pacific Power Company, as amended through November 13, 1996 (incorporated by reference to Exhibit (3)(A) to the Sierra Pacific Power Company Annual Report on Form 10-K for the year ended December 31, 1996).
|
10.36
|
Transmission Use and Capacity Exchange Agreement between Nevada Power Company, Sierra Pacific Power Company and Great Basin Transmission, LLC dated August 20, 2010 (incorporated by reference to Exhibit 10.1 to the Sierra Pacific Power Company Quarterly Report on Form 10-Q for the quarter ended September 30, 2010).
|
10.37
|
Financing Agreement dated May 1, 2016 between Washoe County, Nevada and Sierra Pacific Power Company (relating to Washoe County, Nevada's $80,000,000 Water Facilities Refunding Revenue Bonds (Sierra Pacific Power Company Project) Series 2016C, 2016D and 2016E (incorporated by reference to Exhibit 4.1 to the Sierra Pacific Power Company Current Report on Form 8-K dated May 24, 2016).
|
10.38
|
Financing Agreement dated May 1, 2016 between Washoe County, Nevada and Sierra Pacific Power Company (relating to Washoe County, Nevada's $213,930,000 Gas Facilities Refunding Revenue Bonds, Gas and Water Facilities Refunding Revenue Bonds and Water Facilities Refunding Revenue Bonds (Sierra Pacific Power Company Projects) Series 2016A, 2016B, 2016F and 2016G (incorporated by reference to Exhibit 4.2 to the Sierra Pacific Power Company Current Report on Form 8-K dated May 24, 2016).
|
10.39
|
Financing Agreement dated May 1, 2016 between Humboldt County, Nevada and Sierra Pacific Power Company (relating to Humboldt County, Nevada's $49,750,000 Pollution Control Refunding Revenue Bonds (Sierra Pacific Power Company Project) Series 2016A and 2016B (incorporated by reference to Exhibit 4.3 to the Sierra Pacific Power Company Current Report on Form 8-K dated May 24, 2016).
|
12.4
|
Computation of Ratios of Earnings to Fixed Charges.
|
14.6
|
Code of Ethics for Chief Executive Officer, Chief Financial Officer and Other Covered Officers (incorporated by reference to Exhibit 14.1 to the Sierra Pacific Power Company Annual Report on Form 10-K for the year ended December 31, 2013).
|
31.11
|
Principal Executive Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
|
31.12
|
Principal Financial Officer Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
|
32.11
|
Principal Executive Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
|
32.12
|
Principal Financial Officer Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
|
Exhibit No.
|
Description
|
4.115
|
General and Refunding Mortgage Indenture, dated as of May 1, 2001, between Sierra Pacific Power Company and The Bank of New York, as Trustee (incorporated by reference to Exhibit 4.2(a) to the Sierra Pacific Power Company Quarterly Report on Form 10-Q for the quarter ended June 30, 2001).
|
4.116
|
Second Supplemental Indenture, dated as of October 30, 2006, to subject additional properties of Sierra Pacific Power Company located in the State of California to the lien of the General and Refunding Mortgage Indenture and to correct defects in the original Indenture (incorporated by reference to Exhibit 4(A) to the Sierra Pacific Power Company Annual Report on Form 10-K for the year ended December 31, 2006).
|
4.117
|
Officer's Certificate establishing the terms of Sierra Pacific Power Company's 6.750% General and Refunding Mortgage Notes, Series P, due 2037 (incorporated by reference to Exhibit 4.2 to the Sierra Pacific Power Company Current Report on Form 8-K dated June 27, 2007).
|
4.118
|
Officer’s Certificate establishing the terms of Sierra Pacific Power Company's 3.375% General and Refunding Mortgage Notes, Series T, due 2023 (incorporated by reference to Exhibit 4.1 to the Sierra Pacific Power Company Current Report on Form 8-K dated August 14, 2013).
|
4.119
|
Officer's Certificate establishing the terms of Sierra Pacific Power Company's 2.60% General and Refunding Mortgage Notes, Series U, due 2026 (incorporated by reference to Exhibit 4.1 to the Sierra Pacific Power Company Current Report on Form 8-K dated April 15, 2016).
|
4.120
|
Officer’s Certificate establishing the terms of Sierra Pacific Power Company’s General and Refunding Mortgage Notes, Series V (Nos. V-1, V-2 and V-3) (incorporated by reference to Exhibit 4.4 to the Sierra Pacific Power Company Current Report on Form 8-K dated May 24, 2016).
|
10.40
|
$250,000,000 Amended and Restated Credit Agreement, dated as of June 27, 2014, among Sierra Pacific Power Company, as Borrower, the Initial Lenders, Wells Fargo Bank, National Association, as Administrative Agent and Swingline Lender, and the LC Issuing Banks (incorporated by reference to Exhibit 10.1 to the Sierra Pacific Power Company Current Report on Form 8-K dated June 27, 2014).
|
101
|
The following financial information from each respective Registrant's Annual Report on Form 10-K for the year ended December 31,
2016
is formatted in XBRL (eXtensible Business Reporting Language) and included herein: (i) the Consolidated Balance Sheets, (ii) the Consolidated Statements of Operations, (iii) the Consolidated Statements of Comprehensive Income, (iv) the Consolidated Statements of Changes in Equity, (v) the Consolidated Statements of Cash Flows and (vi) the Notes to Consolidated Financial Statements, tagged in summary and detail.
|
1.1
|
Interpretation
|
1.2
|
Definitions
|
2.1
|
Terms of Senior Pledged Bond, Series 3
|
2.2
|
Delivery
|
2.3
|
Payable on Demand
|
2.4
|
Interest
|
2.5
|
Fully Registered Bond
|
2.6
|
Certification
|
2.7
|
Senior Bond and Pledged Bond; Loan Documents
|
3.1
|
Issuance of Senior Pledged Bond, Series 3
|
4.1
|
Confirmation of Master Indenture
|
5.1
|
Benefit of Indenture
|
6.1
|
Acceptance by Trustee
|
6.2
|
Paying Agent
|
7.1
|
Counterparts
|
7.2
|
Formal Date
|
7.3
|
Acknowledgement
|
7.4
|
Governing Law
|
|
|
ALTALINK INVESTMENT MANAGEMENT LTD., as general partner of ALTALINK INVESTMENTS, L.P.
|
|
By:
|
/s/ Jeffrey A. Austin
|
||
|
Name: Jeffrey A. Austin
|
||
|
Title: Director
|
||
By:
|
/s/ Calvin D. Haack
|
||
|
Name: Calvin D. Haack
|
||
|
Title: Director
|
|
|
ALTALINK INVESTMENT MANAGEMENT LTD.
|
|
By:
|
/s/ Jeffrey A. Austin
|
||
|
Name: Jeffrey A. Austin
|
||
|
Title: Director
|
||
By:
|
/s/ Calvin D. Haack
|
||
|
Name: Calvin D. Haack
|
||
|
Title: Director
|
|
|
BNY TRUST COMPANY OF CANADA
|
|
By:
|
/s/ J. Steven Broude
|
||
|
Name: J. Steven Broude
|
||
|
Title: Authorized Signatory
|
||
By:
|
|
||
|
Name:
|
||
|
Title:
|
|
|
BNY TRUST COMPANY OF CANADA, as Trustee
|
|
By:
|
|
||
|
Authorized Signing Officer
|
||
|
|
||
|
|
||
|
|
||
|
|
1.1
|
Definitions
|
1.2
|
Headings
|
1.3
|
References to Articles and Sections
|
2.1
|
Delivery of Senior Pledged Bond, Series 3
|
2.2
|
Realization
|
2.3
|
Application of Proceeds
|
2.4
|
Cancellation
|
2.5
|
Transfer
|
3.1
|
Satisfaction of Obligations
|
3.2
|
Voting
|
3.3
|
No Merger
|
3.4
|
Amendments
|
3.5
|
Legend
|
3.6
|
Enurement
|
3.7
|
Further Assurances
|
3.8
|
Currency
|
3.9
|
Gender and Number
|
3.10
|
Invalidity of Provisions
|
3.11
|
No Waiver
|
3.12
|
Governing Law, Attornment
|
3.13
|
Acknowledgment
|
|
|
ALTALINK INVESTMENT MANAGEMENT LTD., as general partner of ALTALINK INVESTMENTS, L.P.
|
|
By:
|
|
||
|
Name:
|
||
|
Title:
|
||
By:
|
|
||
|
Name:
|
||
|
Title:
|
|
|
ALTALINK INVESTMENT MANAGEMENT LTD.
|
|
By:
|
|
||
|
Name:
|
||
|
Title:
|
||
By:
|
|
||
|
Name:
|
||
|
Title:
|
|
|
ROYAL BANK OF CANADA, as Agent
|
|
By:
|
|
||
|
Name:
|
||
|
Title:
|
||
By:
|
|
||
|
Name:
|
||
|
Title:
|
|
Form of First Mortgage Bonds due 2046
|
|
||
REGISTERED
|
|
|
|
No. 1
|
ILL.C.C. No. 6654 ($30,000,000 issued pursuant to Illinois Commerce Commission Docket No.
|
||||
13-0634)
|
|
|
|
|
MORTGAGE BOND TRUSTEE’S CERTIFICATE OF AUTHENTICATION
|
||||
This is one of the Bonds of the series designated therein referred to in the within-mentioned
|
||||
Base Indenture.
|
|
|
THE BANK OF NEW YORK MELLON TRUST
|
|
|
COMPANY, N.A., as Mortgage Bond Trustee
|
|
|
|
|
|
By:________________________________________
|
|
|
Name:
|
|
|
Authorized Signatory
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
____________________________________________________________________________________________
|
||||
Please print or typewrite name and address
|
||||
including postal zip code of assignee
|
||||
____________________________________________________________________________________________
|
|
|
|
|
|
_________________________________________________
|
|
|
|
|
NOTICE: The signature to this assignment must correspond with the name as written upon the face of the within instrument in every particular, without alteration or enlargement or any change whatever. The signature must be guaranteed by a commercial bank, a trust company or a member of the New York Stock Exchange.
|
1.1
|
Definitions
|
2.1
|
Amendments to Section 1.1.
|
(a)
|
Section 1.1 of the Original Credit Agreement entitled “Definitions” is hereby amended by adding the following definitions in the applicable alphabetical order:
|
(b)
|
The definition of “Distribution” in Section 1.1 of the Original Credit Agreement is hereby amended by deleting the reference therein to “Debt” and replacing such reference with “Indebtedness”.
|
(c)
|
The definition of “Equivalent Amount” in Section 1.1 of the Original Credit Agreement is hereby amended by deleting the definition in its entirety and replacing such definition with the following:
|
(d)
|
The definition of “Eligible Assignees” in Section 1.1 of the Original Credit Agreement is hereby amended by deleting the references therein to “Loan Party” and replacing such references with “Credit Party”.
|
(e)
|
The definition of “Face Amount” in Section 1.1 of the Original Credit Agreement is hereby amended by deleting the reference therein to “BA Instrument” and replacing such reference with “Bankers’ Acceptance”.
|
(f)
|
The definition of “LIBOR Rate” in Section 1.1 of the Original Credit Agreement is hereby amended by deleting the reference in subparagraph (b) to “such Interest Period” and replacing such reference with “such LIBOR Interest Period”.
|
(g)
|
The definition of “Loan Documents” in Section 1.1 of the Original Credit Agreement is hereby amended by adding “, the Senior Pledged Bond, Series 2, the Bond Delivery Agreement” after the reference to “Third Supplemental Indenture” therein.
|
(h)
|
The definition of “Maturity Date” in Section 1.1 of the Original Credit Agreement is hereby amended by replacing the date “December 14, 2020” with the date “December 14, 2021” in such definition..
|
(i)
|
The definition of “Permitted Lien” in Section 1.1 of the Original Credit Agreement is hereby amended by deleting the reference in subparagraph (g) to “Issuer’s” and replacing such reference with “Borrower’s”.
|
(j)
|
The definition of “Prime Rate” in Section 1.1 of the Original Credit Agreement is hereby amended by deleting the reference therein to “Service” and replacing such reference with “Screen”.
|
2.2
|
Amendment to Section 2.9.
|
2.3
|
Amendment to Section 3.7.
|
2.4
|
Amendment to Section 10.19.
|
2.5
|
Amendment to Section 12.1.
|
2.6
|
Amendment to Section 13.2
|
(g)
|
FATCA.
If a payment made to a Lender under any Loan Document would be subject to U.S. federal withholding Taxes imposed by FATCA, if such Lender were to fail to comply with the applicable reporting requirements of FATCA (including those contained in Section 1471(b) or 1472(b) of the Internal Revenue Code, as applicable), such Lender shall deliver to the Borrower and the Agent at the time or times prescribed by law and at such time or times reasonably requested by the Borrower or the Agent such documentation prescribed by applicable law (including as prescribed by Section 1471(b)(3)(C)(i) of the Internal Revenue Code) and such additional documentation reasonably requested by the Borrower or the Agent as may be necessary for the Borrower and the Agent to comply with their obligations under FATCA and to determine that such Lender has complied with such Lender’s obligations under FATCA or to determine the amount to deduct and withhold from such payment. Solely for purposes of this clause (g), “FATCA” shall include any amendments made to FATCA after the date of this Agreement.
|
2.7
|
Amendment to Section 13.3.
|
2.8
|
Amendment to Section 14.1.
|
2.9
|
Amendment to Schedule 9.1(A).
|
3.1
|
Conditions Precedent
|
(a)
|
the Agent shall have received an executed copy of this Fourth Amending Agreement from each of the Agent, the Lenders, the Borrower and the General Partner;
|
(b)
|
the Agent has received an extension fee from the Borrower, which fee shall be in the amount of 4 bps calculated on the Commitment of each Lender party to this Fourth Amending Agreement, and payable to each such Lender; and
|
(c)
|
no Event of Default shall have occurred and be continuing.
|
4.1
|
Representations and Warranties True and Correct; No Default or Event of Default
|
5.1
|
No Other Amendments, Waivers or Consents
|
5.2
|
Time
|
5.3
|
Governing Law
|
5.4
|
Successors and Assigns
|
5.5
|
Counterparts
|
|
|
ALTALINK INVESTMENT MANAGEMENT LTD.,
in its capacity as General Partner of ALTALINK INVESTMENTS, L.P.
|
|
By:
|
/s/ Jeffrey A. Austin
|
||
|
Name: Jeffrey A. Austin
|
||
|
Title: Director
|
||
|
|
||
By:
|
/s/ Calvin D. Haack
|
||
|
Name: Calvin D. Haack
|
||
|
Title: Director
|
|
|
ALTALINK INVESTMENT MANAGEMENT LTD.
|
|
By:
|
/s/ Jeffrey A. Austin
|
||
|
Name: Jeffrey A. Austin
|
||
|
Title: Director
|
||
|
|
||
By:
|
/s/ Calvin D. Haack
|
||
|
Name: Calvin D. Haack
|
||
|
Title: Director
|
|
|
ROYAL BANK OF CANADA,
as Agent |
|
By:
|
/s/ Yvonne Brazier
|
||
|
Name: Yvonne Brazier
|
||
|
Title: Manager, Agency Services
|
||
|
|
|
|
|
|
By:
|
|
|
|
|
Name:
|
|
|
|
Title:
|
|
|
ROYAL BANK OF CANADA,
as Lender |
|
By:
|
/s/ Timothy P. Murray
|
||
|
Name: TIMOTHY P. MURRAY
|
||
|
Title: AUTHORIZED SIGNATORY
|
||
|
|
|
|
|
|
By:
|
|
|
|
|
Name:
|
|
|
|
Title:
|
|
|
BANK OF MONTREAL,
as Lender |
|
By:
|
/s/ Carol McDonald
|
||
|
Name: Carol McDonald
|
||
|
Title: Director
|
||
|
|
|
|
|
|
By:
|
|
|
|
|
Name:
|
|
|
|
Title:
|
|
|
ALBERTA TREASURY BRANCHES,
as Lender
|
|
By:
|
/s/ Trevor Guinard
|
||
|
Name: Trevor Guinard
|
||
|
Title: Director
|
||
|
|
|
|
|
|
By:
|
/s/ Evan Hahn
|
|
|
|
Name: Evan Hahn
|
|
|
|
Title: Associate Director
|
|
|
THE BANK OF NOVA SCOTIA,
as Lender |
|
By:
|
/s/ Bradley Walker
|
||
|
Name: Bradley Walker
|
||
|
Title: Director
|
||
|
|
|
|
|
|
By:
|
/s/ Mathieu Leroux
|
|
|
|
Name: Mathieu Leroux
|
|
|
|
Associate Director
|
|
|
NATIONAL BANK OF CANADA,
as Lender |
|
By:
|
/s/ Mark Williamson
|
||
|
Name: Mark Williamson
|
||
|
Title: Authorized Signatory
|
||
|
|
|
|
|
|
By:
|
/s/ John Niedermier
|
|
|
|
Name: John Niedermier
|
|
|
|
Title: Authorized Signatory
|
Article 1 INTERPRETATION
|
2
|
|
|
||
|
1.1
|
Definitions
|
2
|
|
|
|
1.2
|
References.
|
25
|
|
|
|
1.3
|
Headings.
|
25
|
|
|
|
1.4
|
Included Words.
|
25
|
|
|
|
1.5
|
Accounting Terms.
|
25
|
|
|
|
1.6
|
Time.
|
26
|
|
|
|
1.7
|
Currency.
|
26
|
|
|
|
1.8
|
Certificates and Opinions.
|
26
|
|
|
|
1.9
|
Schedules.
|
26
|
|
|
Article 2 AMOUNT AND TERMS OF THE CREDIT FACILITY
|
27
|
|
|
||
|
2.1
|
Credit Facility.
|
27
|
|
|
|
2.2
|
Cancellation.
|
27
|
|
|
|
2.3
|
Use of Proceeds.
|
27
|
|
|
|
2.4
|
Particulars of Borrowings.
|
28
|
|
|
|
2.5
|
Borrowing Notice.
|
28
|
|
|
|
2.6
|
Books of Account.
|
29
|
|
|
|
2.7
|
Co-ordination of Prime Rate and U.S. Base Rate Loans.
|
29
|
|
|
|
2.8
|
Bankers’ Acceptances.
|
30
|
|
|
|
2.9
|
LIBOR Loans.
|
34
|
|
|
|
2.10
|
Safekeeping of Drafts.
|
35
|
|
|
|
2.11
|
Certification to Third Parties.
|
35
|
|
|
Article 3 DOCUMENTARY CREDITS
|
35
|
|
|
||
|
3.1
|
Documentary Credits.
|
35
|
|
|
|
3.2
|
Procedure for Issue.
|
36
|
|
|
|
3.3
|
Form of Documentary Credits.
|
36
|
|
|
|
3.4
|
Reimbursements of Amounts Drawn.
|
36
|
|
|
|
3.5
|
Documentary Credit Participation.
|
37
|
|
|
|
3.6
|
Risk of Documentary Credits.
|
37
|
|
|
|
3.7
|
Fees.
|
38
|
|
|
|
3.8
|
Repayments.
|
39
|
|
|
|
3.9
|
Documentary Credits Outstanding Upon Default.
|
39
|
|
|
Article 4 INTEREST
|
39
|
|
|
||
|
4.1
|
Interest on Loans.
|
39
|
|
|
|
4.2
|
LIBOR Interest Period Determination.
|
40
|
|
|
|
4.3
|
Interest on Overdue Amounts.
|
41
|
|
|
|
4.4
|
Other Interest.
|
41
|
|
|
|
4.5
|
Interest Act (Canada).
|
41
|
|
|
|
4.6
|
Deemed Reinvestment Principle.
|
41
|
|
|
|
4.7
|
Maximum Return.
|
41
|
|
|
Article 5 FEES
|
42
|
|
|
||
|
5.1
|
Acceptance Fees.
|
42
|
|
|
|
5.2
|
Commitment Fee.
|
42
|
|
|
|
5.3
|
Basis of Calculation of Fees.
|
42
|
|
|
|
|
|
|
|
Article 6 PAYMENT
|
42
|
|
|
||
|
6.1
|
Voluntary Repayment of Outstanding Accommodation.
|
42
|
|
|
|
6.2
|
Repayment on Maturity Date and Extension.
|
44
|
|
|
|
6.3
|
Excess Accommodation.
|
44
|
|
|
|
6.4
|
Illegality.
|
45
|
|
|
Article 7 PAYMENTS AND INDEMNITIES
|
45
|
|
|
||
|
7.1
|
Payments on Non-Business Days.
|
45
|
|
|
|
7.2
|
Method and Place of Payment.
|
45
|
|
|
|
7.3
|
Net Payments.
|
45
|
|
|
|
7.4
|
Agent May Debit Account.
|
46
|
|
|
|
7.5
|
Currency of Payment.
|
46
|
|
|
|
7.6
|
General Indemnity.
|
46
|
|
|
|
7.7
|
Early Termination of LIBOR Interest Period.
|
47
|
|
|
|
7.8
|
Outstanding Bankers’ Acceptances.
|
47
|
|
|
Article 8 SECURITY
|
48
|
|
|
||
|
8.1
|
Security.
|
48
|
|
|
Article 9 REPRESENTATIONS AND WARRANTIES
|
48
|
|
|
||
|
9.1
|
Representations and Warranties.
|
48
|
|
|
|
9.2
|
Survival of Representations and Warranties.
|
53
|
|
|
Article 10 COVENANTS
|
53
|
|
|
||
|
10.1
|
Reporting Covenants.
|
53
|
|
|
|
10.2
|
Payments Under This Agreement and Loan Documents.
|
54
|
|
|
|
10.3
|
Proceeds.
|
54
|
|
|
|
10.4
|
Inspection of Property, Books and Records, Discussions.
|
54
|
|
|
|
10.5
|
Notices. The Borrower shall promptly give notice to the Agent of:
|
54
|
|
|
|
10.6
|
Disbursements under Master Trust Indenture.
|
55
|
|
|
|
10.7
|
Cure Defects.
|
55
|
|
|
|
10.8
|
Carrying on Business.
|
55
|
|
|
|
10.9
|
Insurance and Insurance Proceeds.
|
55
|
|
|
|
10.10
|
Compliance with Laws and Agreements.
|
56
|
|
|
|
10.11
|
Taxes.
|
56
|
|
|
|
10.12
|
Further Assurances.
|
56
|
|
|
|
10.13
|
Limitation on Indebtedness.
|
56
|
|
|
|
10.14
|
Negative Pledge.
|
57
|
|
|
|
10.15
|
Investments.
|
57
|
|
|
|
10.16
|
Change in Business and Ownership of AltaLink and Subsidiaries.
|
57
|
|
|
|
10.17
|
Mergers, Etc.
|
57
|
|
|
|
10.18
|
Acquisitions.
|
57
|
|
|
|
10.19
|
Transactions with Non-Arm’s Length Persons.
|
58
|
|
|
|
10.20
|
Environmental Covenants.
|
58
|
|
|
|
10.21
|
Hedging Agreements.
|
59
|
|
|
|
10.22
|
Distributions.
|
59
|
|
|
|
10.23
|
Fiscal Year.
|
59
|
|
|
|
10.24
|
Financial Covenants.
|
59
|
|
|
|
10.25
|
Master Trust Indenture.
|
59
|
|
|
Article 23 WAIVER OF JURY TRIAL
|
85
|
|
||
|
23.1
|
Waiver of Jury Trial.
|
85
|
|
Article 24 COUNTERPARTS; INTEGRATION; EFFECTIVENESS; ELECTRONIC EXECUTION
|
85
|
|
||
|
24.1
|
Counterparts; Integration; Effectiveness; Electronic Execution.
|
85
|
|
Article 25 TREATMENT OF CERTAIN INFORMATION: CONFIDENTIALITY
|
86
|
|
||
|
25.1
|
Treatment of Certain Information: Confidentiality.
|
86
|
|
Article 26 MISCELLANEOUS
|
87
|
|
||
|
26.1
|
Further Assurances
|
87
|
|
|
26.2
|
Acknowledgement
|
87
|
|
SCHEDULE 1
|
-
|
BORROWER’S CERTIFICATE OF COMPLIANCE
|
|
SCHEDULE 2(A)
|
-
|
BORROWING NOTICE
|
|
SCHEDULE 2(B)
|
-
|
NOTICE OF ROLL OVER
|
|
SCHEDULE 2(C)
|
-
|
CONVERSION OPTION NOTICE
|
|
SCHEDULE 3
|
-
|
NOTICE OF EXTENSION
|
|
SCHEDULE 4
|
-
|
FORM OF ISSUE NOTICE
|
|
SCHEDULE 5
|
-
|
ASSIGNMENT AND ASSUMPTION
|
|
SCHEDULE 6
|
-
|
COMMITMENTS OF THE LENDERS
|
|
SCHEDULE 6.1(a)
|
-
|
FORM OF NOTICE OF REPAYMENT
|
|
SCHEDULE 7
|
-
|
SENIOR PLEDGED BOND, SERIES 3
|
|
SCHEDULE 8
|
-
|
2016 SUPPLEMENTAL INDENTURE
|
|
SCHEDULE 9.1(a)
|
-
|
CREDIT PARTY AND SUBSIDIARY INFORMATION
|
|
SCHEDULE 10
|
-
|
MATERIAL AGREEMENTS
|
|
1.1
|
Definitions
|
Ratings
|
Category I
|
Category II
|
Category III
|
Category IV
|
Category V
|
Category VI
|
Category VII
|
S & P and DBRS
|
>A / A
|
A / A
|
A- / A (low)
|
BBB+ / BBB (high)
|
BBB / BBB
|
BBB- /
BBB(low)
|
< BBB- / BBB(low) / unrated
|
Applicable Margin for Bankers’ Acceptances, LIBOR Loans & Documentary Credits
|
70 bps
|
80 bps
|
100 bps
|
120 bps
|
145 bps
|
170 bps
|
200 bps
|
Applicable Margin for Prime Rate Loans and US Base Rate Loans
|
0 bps
|
0 bps
|
0 bps
|
20 bps
|
45 bps
|
70 bps
|
100 bps
|
Commitment Fee
|
14.0 bps
|
16.0 bps
|
20.0 bps
|
24.0 bps
|
29 bps
|
34 bps
|
40 bps
|
(a)
|
with respect to an issue of Bankers' Acceptances accepted by a Lender that is a Schedule I Bank, the CDOR Rate;
|
(b)
|
with respect to an issue of Bankers' Acceptances accepted by a Lender that is a Schedule II Bank or a Schedule III Bank, the lesser of: (i) the rate set out in clause (a) above plus 0.10%; and (ii) the annual rate, expressed as a percentage, as being the average discount rate for bankers' acceptances having a comparable face value and a comparable issue and maturity date to the face value and issue and maturity date of such issue of Bankers' Acceptances, expressed on the basis of a year of 365 days, quoted by such Lenders for the purchase by such Lenders of Bankers' Acceptances accepted by them, at or about 10:00 a.m. (Toronto time) on the date of issue of such Bankers' Acceptances; and
|
(c)
|
with respect to a BA Equivalent Loan:
|
(i)
|
made by a Lender that is a Schedule I Bank, the CDOR Rate; and
|
(ii)
|
made by any other Lender, the rate set out in clause (a) above plus 0.10%.
|
(a)
|
ownership of limited partnership units in AltaLink;
|
(b)
|
direct or indirect participation in the transmission of electricity in Canada or the United States;
|
(c)
|
the ownership or operation of electrical transmission lines and infrastructure in Canada or the United States, including the use of such infrastructure for telecommunication or other communication purposes, subject to such telecommunication or other communication purposes not exceeding 10% of Consolidated Assets;
|
(d)
|
engineering or administrative services related to the activities described in paragraphs (a) through (c) above;
|
(e)
|
the Acquisition of any Person related to the activities described in paragraphs (a) through (d) above, in compliance with Section 10.18;
|
(f)
|
such other services as determined to be ancillary to the activities described in paragraphs (a) through (d) above (whether or not such services are regulated by the AUC), with such other services not exceeding 10% of Consolidated Assets; and
|
(g)
|
provided that such activities are not prohibited by the Master Trust Indenture, business development activities related to the pursuit of potential opportunities regarding the transmission of electricity in countries other than Canada and the United States (including, without limitation, Brazil and India), provided however that (A) any costs or expenses incurred by the Borrower and its Subsidiaries in respect of such business development activities shall
|
(a)
|
Loan denominated in Canadian Dollars, the principal amount thereof;
|
(b)
|
Bankers’ Acceptance, the Face Amount thereof;
|
(c)
|
Loan denominated in U.S. Dollars, the Equivalent Amount expressed in Canadian Dollars of the principal amount thereof; and
|
(d)
|
Documentary Credit, (i) where the Documentary Credit is denominated in Canadian Dollars, the amount of the maximum aggregate liability (contingent or actual) of the Documentary Credit Lender pursuant to such Documentary Credit expressed in Canadian Dollars and (ii) where the Documentary Credit is denominated in US Dollars, the Equivalent Amount of the maximum aggregate liability (contingent or actual) of the Documentary Credit Lender pursuant to such Documentary Credit.
|
(a)
|
AltaLink Holdings, L.P. ceases to be the sole limited partner and owner of 99.99% of the Equity Securities of the Borrower or AltaLink Investment Management Ltd. ceases to be the sole general partner and owner of .01% of the Equity Securities in the Borrower;
|
(b)
|
the Borrower ceases to be the sole limited partner and owner of 99.99% of the Equity Securities in AltaLink and/or AltaLink Management Ltd. ceases to be the sole general partner and the owner of .01% of the Equity Securities of AltaLink;
|
(c)
|
the aggregate revenues and the total Assets of non-wholly owned Subsidiaries of the Borrower exceed 10% of the revenue and net tangible total Assets of the Borrower and its Subsidiaries. The parties agree that for the purposes of this paragraph (c) (and paragraph 5 of the Certificate of Compliance and Section 10.16(a)), AltaLink shall be deemed to be a wholly owned Subsidiary of the Borrower so long as (i) the representations and warranties in Section 9.1(t)(i) and (ii) remain true and correct, and (ii) Berkshire Hathaway Energy Company continues to own (directly or indirectly) 100% of the Equity Securities of AltaLink Management Ltd;
|
(d)
|
Berkshire Hathaway Energy Company ceases to collectively own (directly or indirectly) at least 51% of voting and economic interest in the Borrower, unless at the closing of a transaction wherein Berkshire Hathaway Energy Company will own (directly or indirectly) less than 51% of the voting and economic interest in of the Borrower, the Borrower has delivered to the Lenders confirmations taking such transaction into account from S&P and DBRS that the senior unsecured debt ratings of the Borrower shall not be lower than BBB- or BBB(low).
|
(a)
|
the aggregate principal amount of all obligations of the Borrower and its Subsidiaries for borrowed money (other than obligations arising out of the issuance of any Refunding Bonds (as such term is defined in the Master Trust Indenture) during such period of time as the Indebtedness to be repaid by the Refunding Bonds continues to be outstanding), including obligations with respect to bankers’ acceptances and contingent reimbursement obligations in respect of Documentary Credits and other instruments, and including all capitalized interest and other similar amounts required to be paid at maturity on obligations for borrowed money, but excluding Preferred Securities issued by the Borrower and its Subsidiaries;
|
(b)
|
the aggregate principal amount of all obligations issued or assumed by the Borrower and its Subsidiaries in connection with their acquisition of property in respect of the deferred purchase price of that property;
|
(c)
|
all Capital Lease Obligations and Purchase Money Obligations;
|
(d)
|
all Indebtedness outstanding under any Commercial Paper Program; and
|
(e)
|
all Guarantees of any of the foregoing.
|
(a)
|
impairment or adverse alteration of the quality of the Natural Environment for any use that can be made of it by humans, or by any animal, fish or plant that is useful to humans;
|
(b)
|
injury or damage to property or to plant or animal life;
|
(c)
|
harm or material discomfort to any Person;
|
(d)
|
an adverse effect on the health of any Person;
|
(e)
|
impairment of the safety of any Person;
|
(f)
|
rendering any property or plant or animal life unfit for human use;
|
(g)
|
loss of enjoyment of normal use of property; and
|
(h)
|
interference with the normal conduct of business.
|
(a)
|
to purchase such Indebtedness or obligation or any property or assets constituting security therefor;
|
(b)
|
to advance or supply funds (i) for the purchase or payment of such Indebtedness or obligation, (ii) to maintain working capital, net worth or other balance sheet condition of the primary obligor, or (iii) otherwise to advance or make available funds for the purchase or payment of such Indebtedness or obligation;
|
(c)
|
to lease property or to purchase securities or other property or services primarily for the purpose of assuring the owner of such Indebtedness or obligation of the ability of the primary obligor to make payment of the Indebtedness or obligation; or
|
(d)
|
otherwise to assure or indemnify the owner of the Indebtedness or obligation of the primary obligor against loss in respect thereof.
|
(a)
|
the aggregate principal amount of all obligations of that Person for borrowed money (other than Obligations arising out of the issuance of any Refunding Bonds (as such term is defined in the Master Trust Indenture) during such period of time as the Indebtedness to be repaid by the Refunding Bonds continues to be outstanding), including obligations with respect to bankers’ acceptances and contingent reimbursement obligations in respect of letters of credit and other instruments, and including all capitalized interest and other similar amounts required to be paid at maturity on obligations for borrowed money, but excluding Preferred Securities issued by that Person;
|
(b)
|
the aggregate principal amount of all obligations issued or assumed by that Person in connection with its acquisition of property in respect of the deferred purchase price of that property;
|
(c)
|
all Capital Lease Obligations and the aggregate principal amount of all Purchase Money Obligations of that Person;
|
(d)
|
the amount of any Mark-to-Market Exposure with respect to any Financial Instrument Obligations of that Person;
|
(e)
|
the principal amount of all borrowed money outstanding from time to time under any Commercial Paper Program;
|
(f)
|
the principal amount of all borrowed money outstanding from time to time which constitutes Subordinated Debt (as such term is defined in the Master Trust Indenture); and
|
(g)
|
all Guarantees of that Person in respect of any of the foregoing;
|
(a)
|
the rate of interest per annum, expressed on the basis of a year of 360 days, determined by the Agent, which is equal to the offered rate that appears on the page of the Reuters LIBOR01 screen (or any successor thereto as may be selected by the Agent) that displays an average British Bankers Association Interest Settlement Rate for deposits in U.S. Dollars with a term equivalent to such LIBOR Interest Period, determined as of approximately 11:00 a.m. (London time) two (2) Business Days prior to the first day of such LIBOR Interest Period, or
|
(b)
|
if the rates referenced in the preceding
subsection (a)
are not available, the rate per annum determined by the Agent as the rate of interest, expressed on a basis of 360 days at which deposits in U.S. Dollars for delivery on the first day of such LIBOR Interest Period in same day funds in the approximate amount of the LIBOR Loan being made, continued or converted
|
(a)
|
any Purchase Money Mortgage or Lien granted with respect to a Capital Lease Obligation, provided that the total Indebtedness secured by such Purchase Money Mortgages and Liens shall not exceed ten million dollars ($10,000,000) at any time;
|
(b)
|
any Lien for taxes, assessments, government charges or claims not yet due or that are being contested in good faith and in respect of which appropriate provision is made in the Borrower’s consolidated financial statements in accordance with GAAP;
|
(c)
|
any Lien securing appeal bonds or other similar liens arising in connection with court proceedings or contracts, bids or tenders entered into in the ordinary course of business, including, without limitation, surety bonds, security for costs of litigation where required by law, Documentary Credits, or any other instruments serving a similar purpose;
|
(d)
|
any Lien or deposit under workers’ compensation, social security or similar legislation or good faith deposits in connection with bids, tenders, leases and contracts entered into in the ordinary course of business or expropriation proceedings, or deposits to secure public or statutory obligations or deposits of cash or obligations to secure surety and appeal bonds;
|
(e)
|
any Lien or privilege imposed by law, such as builders’, carriers’, warehousemen’s, landlords’, mechanics’ and materialmen’s liens and privileges arising in the ordinary course of business which relate to Indebtedness not yet due or delinquent or the validity or amount of which are being contested in good faith and in respect of which adequate provision for payment has been made; any lien or privilege arising out of judgments or awards with respect to which the Borrower is prosecuting an appeal or proceedings for review and with respect to which it has secured a stay of execution pending that appeal or proceedings for review (provided no Event of Default has resulted therefrom); or undetermined or inchoate Liens and privileges incidental to current operations which have not at such time been filed pursuant to law against the Borrower or the applicable Non-AltaLink Subsidiary or which relate to obligations not due or delinquent; or the deposit of cash or securities in connection with any Lien or privilege referred to in this paragraph (e);
|
(f)
|
a Lien in cash or marketable debt securities in a sinking fund account established by the Borrower in support of a particular series of bonds under the Master Trust Indenture;
|
(g)
|
any encumbrance, such as easements, rights-of-way, servitudes or other similar rights in land granted to or reserved by other Persons, rights-of-way for access, sewers, electric lines, telegraph and telephone lines, oil and natural gas pipe lines and other similar purposes, or zoning or other restrictions as to the Borrower’s use of real property or interests therein, which do not in the aggregate materially impair its use in the operation of the Business;
|
(h)
|
any right reserved to or vested in any municipality or governmental or other public authority (whether by statutory provision or otherwise) to terminate, purchase assets used in connection with, or require annual or other periodic payments as a condition to the continuance of, any lease, licence, franchise, grant or permit;
|
(i)
|
any lien or right of distress reserved in or exercisable under any lease for rent and for compliance with the terms of that lease;
|
(j)
|
any Lien granted by the Borrower or the applicable Non-AltaLink Subsidiary to a public utility or any municipality or governmental or other public authority when required by that utility, municipality or other authority in connection with the operations of the Borrower;
|
(k)
|
any reservation, limitation, proviso or condition, if any, expressed in any original grants to the Borrower or the applicable Non-AltaLink Subsidiary from the Crown; and
|
(l)
|
any extension, renewal, alteration, substitution or replacement, in whole or in part, of any Lien referred to in any of the foregoing paragraphs, provided that the Lien is limited to all or part of the same property that secured the Lien and the principal amount of the secured Indebtedness is not increased by that action
.
|
1.2
|
References.
|
1.3
|
Headings.
|
1.4
|
Included Words.
|
1.5
|
Accounting Terms.
|
1.6
|
Time.
|
1.7
|
Currency.
|
1.8
|
Certificates and Opinions.
|
(a)
|
Unless otherwise provided in a particular Schedule to this Agreement, each certificate and each opinion furnished pursuant to any provision of this Agreement shall specify the Section or Sections under which such certificate or opinion is furnished, shall include a statement that the Person making such certificate or giving such opinion has read the provisions of this Agreement relevant thereto and shall include a statement that, in the opinion of such Person, such Person has made such examination and investigation as is necessary to enable such Person to express an informed opinion on the matters set out in the certificate or opinion.
|
(b)
|
Whenever the delivery of a certificate or opinion is a condition precedent to the taking of any action by the Agent or a Lender or Lenders under this Agreement, the truth and accuracy of the facts and opinions stated in such certificate or opinion shall in each case be conditions precedent to the right of the Borrower to have such action taken, and each statement of fact contained therein shall be deemed to be a representation and warranty of the Borrower for the purposes of this Agreement.
|
1.9
|
Schedules.
|
2.1
|
Credit Facility.
|
(a)
|
Subject to and upon the terms and conditions set forth in this Agreement, effective upon the Effective Date, the Lenders hereby establish a revolving term credit facility in the maximum aggregate principal amount equal to two hundred million ($200,000,000.00) and the Lenders hereby agree to establish in favour of the Borrower such revolving term credit facility by way
|
2.2
|
Cancellation.
|
2.3
|
Use of Proceeds.
|
2.4
|
Particulars of Borrowings.
|
(a)
|
Notwithstanding any contrary provision contained in the Loan Documents, in the event of any conflict or inconsistency between any of the provisions in this Agreement and any of the provisions in the Loan Documents, as against the parties hereto, the provisions of this Agreement shall prevail.
|
(b)
|
No Borrowing from any Lender shall be obtained at any time for any period which would extend beyond the earlier of (i) the date which is 364 days following the Borrowing Date in respect of such Borrowing, and (ii) the Maturity Date of such Lender.
|
(c)
|
Subject to the provisions hereof, any Accommodation which is repaid at any time prior to the expiry of the Maturity Date may be subsequently re-drawn.
|
2.5
|
Borrowing Notice.
|
(i)
|
the amount, currency and type or types of Accommodation desired;
|
(ii)
|
the details of the account of the Borrower to which payment of the Borrowing is to be wired or otherwise made, if applicable;
|
(iii)
|
the requested Borrowing Date;
|
(iv)
|
the term thereof;
|
(v)
|
if applicable, the Accommodation to be renewed or converted and, where such Accommodation includes any Loan, the currency thereof and the interest rate applicable thereto;
|
(vi)
|
if such Borrowing includes a Loan, whether it is to be a Prime Rate Loan, U.S. Base Rate Loan or a LIBOR Loan; and
|
(vii)
|
if such Borrowing includes a LIBOR Loan, the LIBOR Interest Period to be applicable to such Loan.
|
(viii)
|
on the Business Day preceding the applicable Borrowing Date, if the new Accommodation or any Accommodation to be renewed or converted is by way of Prime Rate Loans or U.S. Base Rate Loans;
|
(ix)
|
on the Business Day preceding the applicable Borrowing Date, if the new Accommodation or any Accommodation to be renewed or converted is by way of Bankers’ Acceptances; and
|
(x)
|
on the third Business Day preceding the applicable Borrowing Date, if any new Accommodation or any Accommodation to be renewed or converted is a LIBOR Loan.
|
2.6
|
Books of Account.
|
2.7
|
Co-ordination of Prime Rate and U.S. Base Rate Loans.
|
(a)
|
the Agent shall advise each Lender of its receipt of a notice from the Borrower pursuant to Section 2.5, on the day such notice is received and shall, as soon as possible, advise each Lender of such Lender’s Applicable Percentage of any Prime Rate or U.S. Base Rate Loan requested by the notice;
|
(b)
|
each Lender shall deliver its Applicable Percentage of such Loan to the Agent’s Account at the Branch not later than 11:00 a.m. on the Borrowing Date; and
|
(c)
|
when the Agent determines that all the conditions precedent to a Borrowing specified in this Agreement have been met or waived, it shall advance to the Borrower the amount delivered by each Lender by wiring such amount to relevant account of the Borrower before 12:00 noon on the Borrowing Date, but if the conditions precedent to the Borrowing are not met or waived by such time, the Agent shall return the funds to the Lenders or invest them in an overnight investment as orally instructed by each Lender until such time as the Loan is advanced.
|
2.8
|
Bankers’ Acceptances.
|
(a)
|
Power of Attorney for the Execution of Bankers’ Acceptances
. To facilitate acceptance of the Borrowings by way of Bankers’ Acceptances, the Borrower hereby appoints each Lender as its attorney to sign and endorse on its behalf, in handwriting or by facsimile or mechanical signature as and when deemed necessary by such Lender, blank forms of Drafts. In this respect, it is each Lender’s responsibility to maintain an adequate supply of blank forms of Drafts for acceptance under this Agreement. The Borrower recognizes and agrees that all Drafts signed and/or endorsed on its behalf by a Lender shall bind the Borrower fully and effectively as if signed in the handwriting of and duly issued by the proper signing officers of the Borrower. Each Lender is hereby authorized to issue such Drafts endorsed in blank in such face amounts as may be determined by such Lenders; provided that the aggregate amount thereof is equal to the aggregate amount of Bankers’ Acceptances required to be accepted and purchased by such Lender. No Lender shall be liable for any damage, loss or other claim arising by reason of any loss or improper use of any such instrument, except the gross negligence or wilful misconduct of the Lender or its officers, employees, agents or representatives. Each Lender shall maintain a record with respect to Bankers’ Acceptances held by it in blank hereunder, voided by it for any reason, accepted and purchased by it hereunder, and cancelled at the respective maturities. Each Lender agrees to provide such records to the Borrower at the Borrower’s expense upon request.
|
(b)
|
Sale of Bankers’ Acceptances.
It shall be the responsibility of each Lender unless otherwise requested by the Borrower, to purchase its Bankers’ Acceptances at a discount rate equal to the BA Discount Rate.
|
(c)
|
Coordination of BA Borrowings
. Each Lender shall advance its Applicable Percentage of each Borrowing by way of Bankers’ Acceptances in accordance with the following:
|
(i)
|
the Agent, promptly following receipt of a notice from the Borrower pursuant to Section 2.5 requesting a Borrowing by way of Bankers’ Acceptances, shall advise each Lender of the aggregate Face Amount and term(s) of the Bankers’ Acceptances to be accepted by it, which term(s) shall be identical for all Lenders. The aggregate Face Amount of Bankers’ Acceptances to be accepted by a Lender shall be determined by the Agent by reference to the respective Commitments of the Lenders, except that, if the Face Amount of a Bankers’ Acceptance would not be One Hundred Thousand Canadian Dollars (Cdn.$100,000) or a whole multiple thereof, the Face Amount shall be increased or reduced by the Agent in its sole discretion to the nearest whole multiple of One Hundred Thousand Canadian Dollars (Cdn.$100,000);
|
(ii)
|
unless requested by the Borrower not to purchase the subject Bankers’ Acceptances, each Lender shall transfer to the Agent at the Branch for value on each Borrowing Date immediately available Canadian Dollars in an aggregate amount equal to the BA Discount Proceeds of all Bankers’ Acceptances accepted and sold or purchased by the Lender on such Borrowing Date, net of the applicable Bankers’ Acceptance Fees in respect of such Bankers’ Acceptances. Each Lender shall also advise the Agent (which shall promptly give the relevant particulars to the Borrower) as soon as possible of the discount rate at which it has sold or purchased its Bankers’ Acceptances;
|
(iii)
|
if the Borrower requests the Lenders not to purchase the subject Bankers’ Acceptances, each Lender will forward the subject Bankers’ Acceptances to the Agent for delivery against payment of the applicable Bankers’ Acceptance Fees; and
|
(iv)
|
if the Agent determines that all the conditions precedent to a Borrowing specified in this Agreement have been met or waived, it shall advance to the Borrower the amount delivered by each Lender by wiring such amount to the account of the Borrower prior to 12:00 noon on the Borrowing Date, or, if applicable shall deliver the Bankers’ Acceptances as directed by the Borrower, but if the conditions precedent to the Borrowing are not met or waived by 2:30 p.m. on the Borrowing Date, the Agent shall return the funds to the Lenders or invest them in an overnight investment as orally instructed by each Lender until such time as the Advance is made.
|
(d)
|
Payment
. The Borrower shall provide for the payment to the Agent for the account of the Lenders of the Face Amount of each Bankers’ Acceptance at its maturity, either by payment of the amount thereof or through utilization of the Credit Facility in accordance with this Agreement (by rolling over the Bankers’ Acceptance or converting it into other Accommodation or a combination thereof). The Borrower will continue to be required to provide as aforesaid for each Bankers’ Acceptance at maturity notwithstanding the fact that a Lender may be the holder of the Bankers’ Acceptance which has been accepted by such Lender.
|
(e)
|
Collateralization.
|
(i)
|
If any Bankers’ Acceptance is outstanding on the Demand Date or the Maturity Date, the Borrower shall on such date pay to the Agent for the account of the Lenders at the Branch in Canadian Dollars an amount equal to the Face Amount of such Bankers’ Acceptance.
|
(ii)
|
All funds received by the Agent pursuant to Section 2.8(e)(i) shall be held by the Agent for set-off on the maturity date of the Bankers’ Acceptance against the liability of the Borrower to the Lender in respect of such Bankers’ Acceptance and, until then, shall be invested from time to time in such form of investment at the Branch designated by the Borrower and approved by the Agent, for a term corresponding to the maturity date of the applicable Bankers’ Acceptance and shall bear interest at the rate payable by the Agent on deposits of similar currency, amount and maturity. The balance of all such funds (together with interest thereon) held by the Agent will be applied to repayment of all debts and liabilities of the Borrower to the Lender under this Agreement and the Loan Documents and following repayment of all such debts and liabilities any amount remaining shall be paid to the Borrower or as otherwise required by law.
|
(f)
|
Notice of Rollover or Conversion.
The Borrower shall give the Agent notice in the form attached as Schedule 2(B) or Schedule 2(C) hereto, as applicable, not later than 11:00 a.m. on the Business Day prior to the maturity date of Bankers’ Acceptances, specifying the Accommodation into which the Bankers’ Acceptances will be renewed or converted on maturity.
|
(g)
|
Obligations Absolute.
The obligations of the Borrower with respect to Bankers’ Acceptances under this Agreement shall be unconditional and irrevocable, and shall be paid strictly in accordance with the terms of this Agreement under all circumstances, including, without limitation, the following circumstances:
|
(i)
|
any lack of validity or enforceability of any Draft accepted by a Lender as a Bankers’ Acceptance; or
|
(ii)
|
the existence of any claim, set-off, defence or other right which the Borrower may have at any time against the holder of a Bankers’ Acceptance, a Lender or any other person or entity, whether in connection with this Agreement or otherwise.
|
(h)
|
Shortfall on Drawdowns, Rollovers and Conversions.
The Borrower agrees that the difference between the:
|
(i)
|
amount of a Borrowing requested by the Borrower by way of Bankers’ Acceptances and the actual proceeds of the Bankers’ Acceptances;
|
(ii)
|
actual proceeds of a Bankers’ Acceptance and the amount required to pay a maturing Bankers’ Acceptance if a Bankers’ Acceptance is being rolled over; and
|
(iii)
|
actual proceeds of a Bankers’ Acceptance and the amount required to repay any Borrowing which is being converted to a Bankers’ Acceptance,
|
(i)
|
Depository Bills and Notes Act
.
At the option of any Lender (and notwithstanding Section 2.8 (a), Bankers’ Acceptances under this Agreement to be accepted by that Lender may be issued in the form of Depository Bills for a deposit with the Canadian Depository for Securities Limited pursuant to the
Depository Bills and Notes Act
(Canada). All Depository Bills so issued shall be governed by the provisions of this Section 2.8, as applicable.
|
(j)
|
BA Equivalent Loans
. Whenever the Borrower requests an Advance that includes Banker's Acceptances, each Lender that is not permitted by Applicable Law or by customary market practice to accept a Banker's Acceptance (a
"Non BA Lender"
) shall, in lieu of accepting its
pro rata
amount of such Banker's Acceptances, make available to the Borrower on the Borrowing Date a non‑interest bearing loan (a
"BA Equivalent Loan"
) in Canadian Dollars in an amount equal to the BA Discount Proceeds of its
pro rata
amount of the Banker's Acceptances, based on the BA Discount Rate applicable to such Lender. Each Non BA Lender shall also be entitled to deduct from the BA Equivalent Loan an amount equal to the Banker's Acceptance Fee that would have been applicable had it been able to accept Banker's Acceptances. The BA Equivalent Loan shall have a term equal to the term of the Banker's Acceptances that the Non BA Lender would otherwise have accepted and the Borrower shall, at the end of that term, be obligated to pay the Non BA Lender an amount equal to the aggregate face amount of the Banker's Acceptances that it would otherwise have accepted. All provisions of this Agreement applicable to Banker's Acceptances and Lenders that accept Banker's Acceptances shall apply
mutatis mutandis
to BA Equivalent Loans and Non BA Lenders and, without limiting the foregoing, Accommodations shall include BA Equivalent Loans.
|
2.9
|
LIBOR Loans.
|
(a)
|
If the Agent determines in (which determination shall be made in good faith and shall be conclusive and binding) in connection with any request for a LIBOR Loan or a conversion or continuation thereof that (a) U.S. Dollar deposits are not being offered to banks in the applicable offshore U.S. Dollar market for the applicable amount and LIBOR Interest Period of such LIBOR Loan, or adequate and reasonable means do not exist for determining the LIBOR Rate for such LIBOR Loan, or (b) if the Majority Lenders determine and notify the Agent that the LIBOR Rate for such LIBOR Loan does not adequately and fairly reflect the cost to such Lenders of funding such LIBOR Loan, then the Agent shall promptly notify the Borrower and all Lenders. Thereafter, the obligation of the Lenders to make or maintain
|
(b)
|
The Borrower shall give the Agent notice in writing not later than 10:00 a.m. on the third Business Day prior to the expiry of the LIBOR Interest Period in respect of a LIBOR Loan specifying the new LIBOR Interest Period (if the LIBOR Loan is to be renewed) or the Accommodation into which the LIBOR Loan will be converted on such expiry.
|
(c)
|
If no notice is given by the Borrower as provided in clause (a) or (b) above, the LIBOR Loan will be automatically converted on the expiration of the then applicable LIBOR Interest Period to a U.S. Base Rate Loan, without prejudice to the Lenders’ rights in respect of the failure to give the notice and whether or not a Default or Event of Default has occurred, in the principal amount of the funds required to be provided to the Agent for the account of the Lenders pursuant to this Section.
|
(d)
|
If any LIBOR Loan is outstanding on the Demand Date or the Maturity Date, the Borrower shall on such date pay to the Agent for the account of the Lenders at the Branch in U.S. Dollars an amount equal to the principal amount of such LIBOR Loan.
|
(e)
|
All funds received by the Agent pursuant to clause (d) shall be held by the Agent for set-off on the maturity date of the LIBOR Loan against the liability of the Borrower to the Lenders in respect of such LIBOR Loan and, until then, shall be invested from time to time in such form of investment at the Branch designated by the Borrower and approved by the Agent, for a term corresponding to the maturity date of the applicable LIBOR Loan and shall bear interest at the rate payable by the Agent on deposits of similar currency, amount and maturity. The balance of all such funds (together with interest thereon) held by the Agent will be applied to repayment of all debts and liabilities of the Borrower to the Lenders under this Agreement and the Loan Documents and following repayment of all such debts and liabilities any amount remaining shall be paid to the Borrower or as otherwise required by law.
|
(f)
|
Each Lender shall advance its Applicable Percentage of each LIBOR Loan in accordance with the following provisions:
|
(i)
|
the Agent shall advise each Lender of its receipt of a notice from a Borrower pursuant to Section 2.5 on the day such notice is received and shall, as soon as possible, advise each Lender of the amount of its Applicable Percentage of any Borrowing by way of LIBOR Loan requested by the notice;
|
(ii)
|
each Lender shall deliver its share of the Borrowing to the Agent’s Account at the Branch not later than 11:00 a.m. on the Borrowing Date; and
|
(iii)
|
when the Agent determines that all the conditions precedent to a Borrowing specified in this Agreement have been met, it shall advance to the Borrower the amount delivered by each Lender by wiring such amount to the account of the Borrower, but if the conditions precedent to the Borrowing are not met by 2:30 p.m. on the Borrowing Date, the Agent shall return the funds to the Lenders or invest them in an overnight investment as orally instructed by each Lender until such time as the LIBOR Loan is advanced.
|
2.10
|
Safekeeping of Drafts.
|
2.11
|
Certification to Third Parties.
|
3.1
|
Documentary Credits.
|
3.2
|
Procedure for Issue.
|
3.3
|
Form of Documentary Credits.
|
3.4
|
Reimbursements of Amounts Drawn.
|
3.5
|
Documentary Credit Participation.
|
3.6
|
Risk of Documentary Credits.
|
3.7
|
Fees.
|
3.8
|
Repayments.
|
(i)
|
the date on which any final and non-appealable order, judgment or other such determination has been rendered or issued either terminating the applicable Judicial Order or permanently enjoining the Lender from paying under such Documentary Credit; and
|
(ii)
|
the earlier of (i) the date on which either (x) the original counterpart of the Documentary Credit is returned to the Documentary Credit Lender for cancellation, or (y) the Documentary Credit Lender is released by the Beneficiary from any further obligations, and (ii) the expiry (to the extent permitted by any applicable law) of the Documentary Credit,
|
3.9
|
Documentary Credits Outstanding Upon Default.
|
4.1
|
Interest on Loans.
|
(a)
|
Prime Rate Loan
. Each Prime Rate Loan shall bear interest (both before and after demand, maturity, default and, to the extent permitted by law, judgment, with interest on overdue interest at the same rate) from and including the Borrowing Date for such Loan to, but not including, the date of repayment of such Loan on the unpaid principal amount of such Loan
|
(b)
|
U.S. Base Rate Loan
. Each U.S. Base Rate Loan shall bear interest (both before and after demand, maturity, default and, to the extent permitted by law, judgment, with interest on overdue interest at the same rate) from and including the Borrowing Date for such Loan to, but not including, the date of repayment of such Loan on the unpaid principal amount of such Loan at a nominal rate per annum equal to the U.S. Base Rate, plus the Applicable Margin then in effect, which shall, in each case, change automatically without notice to the Borrower as and when the U.S. Base Rate shall change so that at all times the rates set forth above shall be the U.S. Base Rate then in effect. Interest on each U.S. Base Rate Loan shall be computed on the basis of the actual number of days elapsed divided by 365 or 366, as applicable. Interest in respect of outstanding U.S. Base Rate Loans shall be payable monthly in arrears on the first Business Day of each month; provided, however, that interest on overdue interest shall be payable on demand.
|
(c)
|
LIBOR Loans
. Each LIBOR Loan shall bear interest (both before and after demand, maturity, default and, to the extent permitted by law, judgment, with interest on overdue interest at the same rate) from and including the Borrowing Date for such LIBOR Loan to, but not including, the date of repayment thereof on the unpaid principal amount thereof at a nominal rate per annum equal to the LIBOR Rate determined by the Agent for each LIBOR Interest Period applicable to such LIBOR Loan plus the Applicable Margin in effect on the first day of such LIBOR Interest Period. Interest on each LIBOR Loan shall be computed on the basis of the actual number of days elapsed divided by three hundred and sixty (360). Interest in respect of each LIBOR Loan shall be payable on the last day of each LIBOR Interest Period applicable thereto and also, with respect to each LIBOR Interest Period which is longer than ninety (90) days, the last day of such LIBOR Interest Period and each date within such LIBOR Interest Period which is the first Business Day following the expiration of each ninety (90) day interval after the first day of such LIBOR Interest Period; provided, however, that interest on overdue interest shall be payable on demand.
|
4.2
|
LIBOR Interest Period Determination.
|
4.3
|
Interest on Overdue Amounts.
|
4.4
|
Other Interest.
|
4.5
|
Interest Act (Canada).
|
4.6
|
Deemed Reinvestment Principle.
|
4.7
|
Maximum Return.
|
5.1
|
Acceptance Fees.
|
5.2
|
Commitment Fee.
|
5.3
|
Basis of Calculation of Fees.
|
6.1
|
Voluntary Repayment of Outstanding Accommodation.
|
(a)
|
Repayments
. The Borrower shall have the right to voluntarily repay outstanding Accommodations from time to time on any Business Day without premium on the terms and conditions set forth in this Section:
|
(i)
|
With respect to any voluntary repayment of an Accommodation, unless the Agent with the consent of the Lenders otherwise approves, the Canadian Dollar Amount of Accommodation included in such repayment shall be Two Million Five Hundred Thousand Canadian Dollars (Cdn.$2,500,000) or whole multiples of One Hundred Thousand Canadian Dollars (Cdn.$100,000) or the entire amount of that type of Accommodation outstanding, the U.S. Dollar amount of Accommodation included in such repayment shall be Two Million Five Hundred Thousand U.S. Dollars (U.S.$2,500,000)
or whole multiples of One Hundred Thousand U.S. Dollars (U.S.$100,000) or the entire amount of that type of Accommodation outstanding, and the Borrower shall give the Agent a written notice of repayment substantially in the form of Schedule 6.1(a) (a “
Notice of Repayment
”), specifying the amount, the type or types of Accommodation to be included in the repayment (and where such Accommodation includes any Loan, the currency thereof and the interest rate applicable thereto) and the applicable voluntary repayment date, which notice shall be irrevocable by the Borrower. The Notice of Repayment shall be given to the Agent not later than 10:00 a.m.:
|
(A)
|
on the second Business Day preceding the applicable repayment date in the case of Loans with a Canadian Dollar Amount in the aggregate equal to or greater than Two Million Five Hundred Thousand Canadian Dollars (Cdn.$2,500,000);
|
(B)
|
on the second Business Day preceding the applicable repayment date in the case of Bankers’ Acceptances in an aggregate Face Amount equal to or greater than Two Million Five Hundred Thousand Canadian Dollars (Cdn.$2,500,000); and
|
(C)
|
on the third Business Day preceding the applicable repayment date in the case of LIBOR Loans.
|
(ii)
|
In all other cases, Notice of Repayment shall be given on the applicable repayment date.
|
(iii)
|
Any Notice of Repayment received by the Agent on any Business Day after 11:00 a.m. shall be deemed to have been given to the Agent on the next succeeding Business Day.
|
(iv)
|
On the applicable voluntary repayment date, the Borrower shall pay to the Agent for the account of the Lenders, the amount of any Accommodation that is subject to the repayment, together with all interest and other fees and amounts accrued, unpaid and due in respect of such repayment; provided, however, that accrued interest will not be repayable prior to the applicable interest payment date in Section 4.1 in respect of Prime Rate Loans or U.S. Base Rate Loans unless the full balance outstanding thereunder is voluntarily repaid.
|
(b)
|
Repayment of Certain Types of Accommodation
. The following provisions shall also apply to the voluntary repayment by the Borrower of the following types of Accommodation:
|
(i)
|
Subject to Section 6.1(c), no repayment of any LIBOR Loan shall be made otherwise than upon the expiration of any applicable LIBOR Interest Period; and
|
(ii)
|
No repayment of outstanding Accommodation in the form of Bankers’ Acceptance shall be made otherwise than upon the expiration or maturity date or, in the case of a Documentary Credit, on the date of surrender thereof to the Documentary Credit Lender.
|
(c)
|
Repayment of LIBOR Loans
. Notwithstanding Sections 6.1(a) and 6.1(b), a LIBOR Loan may be repaid at any time within the thirty (30) day period after the Borrower receives notice that it is required to pay any amount under Section 7.6 in respect of such Accommodation, provided that in addition to the other amounts required to be paid pursuant to this Section at the time of such repayment, the Borrower pays to the Agent for the account of the Lenders at such time all reasonable breakage costs incurred by the Lenders with respect to, and all other amounts payable by the Borrower under Sections 7.6 and 7.7 in connection with, such repayment. A certificate of a Lender or Lenders as to such costs, providing details of the calculation of such costs, shall be prima facia evidence.
|
6.2
|
Repayment on Maturity Date and Extension.
|
(a)
|
Subject to the provisions of this Agreement and to this Section, the Borrower shall repay in full all outstanding Accommodations to each Lender on the Maturity Date of such Lender, together with all interest, fees and other amounts payable hereunder on the Maturity Date of such Lender, in each case, to the Agent for the account of the applicable Lender(s), and the Commitment of such Lender shall be permanently cancelled and the aggregate Committed Amount shall be permanently cancelled by a corresponding amount.
|
(b)
|
By notice in writing to the Agent in the form of Schedule 3 (a “
Notice of Extension
”) given not more than 90 and not less than 45 days prior to each anniversary date of the date of this Agreement, the Borrower may request each Lender to extend the Maturity Date of such Lender for an additional period of 365 days. The Lenders agree that they shall give or withhold their consent in a timely manner so that the Agent may provide a response to the Borrower to the Notice of Extension within thirty (30) days from the date of such receipt, provided that the decision of any Lender to extend the Maturity Date in respect of such Lender shall be at the sole discretion of such Lender. The Borrower shall be entitled to replace any Lender which
|
6.3
|
Excess Accommodation.
|
(a)
|
to the extent any of the Accommodations are Prime Rate Loans, U.S. Base Rate Loans, repay such excess; and
|
(b)
|
in the case of Banker’s Acceptances or LIBOR Loans, pay to the Agent for the account of the Lenders an amount in Canadian Dollars or U.S. Dollars, as applicable, equivalent to the amount by which the Committed Amount is exceeded.
|
6.4
|
Illegality.
|
7.1
|
Payments on Non-Business Days.
|
7.2
|
Method and Place of Payment.
|
7.3
|
Net Payments.
|
7.4
|
Agent May Debit Account.
|
7.5
|
Currency of Payment.
|
7.6
|
General Indemnity.
|
(a)
|
any Environmental Matter, Environmental Liability or Environmental Proceeding; and
|
(b)
|
any loss or expense incurred in liquidating or re-employing deposits from which such funds were obtained, which the Agent or Lender may sustain or incur as a consequence of:
|
(i)
|
failure by the Borrower to make payment when due of the principal amount of or interest on any LIBOR Loan;
|
(ii)
|
failure by the Borrower in proceeding with a Borrowing after the Borrower has given a Borrowing Notice;
|
(iii)
|
failure by the Borrower in repaying a Borrowing after the Borrower has given a notice of repayment;
|
(iv)
|
any breach, non-observance or non-performance by the Borrower of any of its obligations, covenants, agreements, representations or warranties contained in this Agreement; and
|
(v)
|
except as otherwise provided in Section 6.1(c)the repayment of any LIBOR Loan otherwise than on the expiration of any applicable LIBOR Interest Period or the repayment of any Bankers’ Acceptance otherwise than on the maturity date thereof.
|
7.7
|
Early Termination of LIBOR Interest Period.
|
7.8
|
Outstanding Bankers’ Acceptances.
|
8.1
|
Security.
|
9.1
|
Representations and Warranties.
|
(a)
|
Existence
– the Borrower and each of its Subsidiaries is a partnership, corporation or other entity, as the case may be, incorporated or organized and subsisting under the laws of its jurisdiction of incorporation or organization, specified on Schedule 9.1(a) (as such Schedule may be amended from time to time by Borrower and provided to the Lenders, provided that such amendments shall not otherwise be contrary to this Agreement) with and has all requisite partnership, corporate or other power and authority to own, hold under license or lease its property, undertaking and Assets and to carry on (i) its Business as now conducted (and as now proposed to be conducted); and (ii) the transactions contemplated by this Agreement and each other Loan Document to which it is a party. The General Partner is a corporation, duly and validly incorporated, organized and existing as a corporation under the laws of the Province of Alberta and has the legal capacity to act as the General Partner of the Borrower;
|
(b)
|
Capacity
– each of the Borrower and the General Partner has the legal capacity and right to enter into the Loan Documents and do all acts and things and execute and deliver all agreements, documents and instruments as are required thereunder to be done, observed or performed by it in accordance with the terms and conditions thereof;
|
(c)
|
Authority
- the execution and delivery by the Borrower and General Partner of this Agreement and each of the Loan Documents to which it is a party, and the performance by it of its obligations thereunder have been duly authorized by all necessary corporate, partnership or other action including, without limitation, the obtaining of all necessary shareholder, partnership or other relevant consents. No authorization, consent, approval, registration, qualification, designation, declaration or filing with any Governmental Authority or other Person, is or was necessary in connection with the execution, delivery and performance of
|
(d)
|
Execution and Delivery
,
Enforceability
- each of the Loan Documents has been duly executed and delivered by each of the Borrower and the General Partner and constitutes a valid and legally binding obligation of the Borrower enforceable against it in accordance with its terms, subject only to bankruptcy, insolvency, reorganization, arrangement or other statutes or judicial decisions affecting the enforcement of creditors’ rights in general and to general principles of equity under which specific performance and injunctive relief may be refused by a court in its discretion;
|
(e)
|
No Litigation
- there is no existing, pending or, to the knowledge of the Borrower or the General Partner, threatened litigation by or against the Borrower, its Subsidiaries or the General Partner which could reasonably be expected to be adversely determined to the rights of the Borrower, its Subsidiaries or the General Partner and which could reasonably be expected to cause a Material Adverse Effect; no event has occurred and, to the knowledge of the Borrower or the General Partner, no state or condition exists, which could give rise to any such litigation;
|
(f)
|
No Conflict
- the execution and delivery by the Borrower and the General Partner and the performance by them of their obligations under, and compliance with the terms, conditions and provisions of, this Agreement and each other Loan Document will not conflict with or result in a breach of any of the terms, conditions or provisions of (i) its articles, by-laws, partnership agreement or other organizational documents, as the case may be; (ii) any Applicable Law; (iii) any Material Agreement or any material contractual restriction binding on or affecting it or its Assets; or (iv) any material judgment, injunction, determination or award which is binding on it in each such case except to the extent that such breach could not reasonably be expected to result in a Material Adverse Change;
|
(g)
|
Financial Statements
- the financial statements and forecasts of the Borrower and its Subsidiaries which have been provided to the Agent are accurate and complete in all material respects, and fairly present the consolidated financial condition and business operations of the Borrower and its Subsidiaries, as at the date thereof and are prepared in a form and manner consistent with existing financial reporting practices of the Borrower in accordance with GAAP;
|
(h)
|
Books and Records
- all books and records of the Borrower and its Subsidiaries have been fully and accurately kept and completed and there are no material inaccuracies or discrepancies of any kind contained or reflected therein. The Borrower’s and its Subsidiaries’ records, systems, controls, data or information are not recorded, stored, maintained, operated or otherwise wholly or partly dependent upon or held by any means (including any electric, mechanical or photographic process, whether computerized or not) which (including all means of access thereto and therefrom) are not under the direct control of Borrower or its Subsidiaries, as applicable;
|
(i)
|
No Material Adverse Change
- there has been no Material Adverse Change since September 30, 2016;
|
(j)
|
Compliance with Laws and Agreements
– the Borrower, its Subsidiaries and the General Partner are in compliance with all Applicable Laws and all agreements or contracts where any non-compliance could reasonably be expected to cause a Material Adverse Effect;
|
(k)
|
Approvals
- all Governmental Approvals and other consents or authorizations necessary to permit the Borrower and its Subsidiaries and the General Partner (i) to execute, deliver and perform each Loan Document to which it is a party (if any), and to consummate the transactions contemplated thereby; and (ii) to own and operate the Business, have been obtained or effected and are in full force and effect. The Borrower and its Subsidiaries are in compliance with the requirements of all such Governmental Approvals and consents and there is no Claim existing, pending or, to the knowledge of the Borrower or the General Partner, threatened which could result in the revocation, cancellation, suspension or any adverse modification of any of such Governmental Approvals or consent;
|
(l)
|
No Default
- no Default or Event of Default under this Agreement or the Master Trust Indenture has occurred or is continuing which has not (i) been expressly waived in writing by the Agent, the Trustee under the Master Trust Indenture and the holders of the Senior Bonds, Series 09-1, the holders of the Senior Bonds, Series 12-1, the holders of the Senior Bonds, Series 13-1, and the holders of the Senior Bonds, Series 15-1; or (ii) been remedied (or otherwise ceased to be continuing);
|
(m)
|
Ownership of Assets, Principal Property
- the Borrower and its Subsidiaries each has good and marketable title to (and in the case of the Borrower) free and clear of all Liens, other than Permitted Liens, all of its respective Assets used in the Business. The Principal Property in the name of the General Partner is and will be held by the General Partner in trust for the Borrower;
|
(n)
|
Taxes
-
|
(i)
|
the Borrower and its Subsidiaries are currently exempt from (i) income tax under the
Income Tax Act
(Canada), and (ii) realty taxes under the
Assessment Act
(Alberta); the Borrower is not in default of any of the filings, payments or other requirements necessary to maintain such exempt status, nor does the Borrower have any knowledge of any event which could result in the Borrower or AltaLink ceasing to be exempt from taxation under such statutes; and
|
(ii)
|
the Borrower and its Subsidiaries have filed or caused to be filed all tax returns which, to its knowledge, are required to have been filed, and have paid all taxes shown to be due and payable on said returns or on any assessments made against it or any of its property and all other taxes, fees or other charges imposed on it or any of its property by any Governmental Authority (other than those the amount or validity of which is currently being contested in good faith by appropriate proceedings and with respect to which reserves in conformity with GAAP have been provided in its books); and no tax liens have been filed and, to the knowledge of the Borrower no claims are being asserted with respect to any such taxes, fees or other charges;
|
(o)
|
No Proceedings
- no essential portion of the Borrower’s or any of its Subsidiaries’ real or leased property has been taken or expropriated by any Governmental Authority nor has written notice or proceedings in respect thereof been given or commenced nor is the Borrower aware of any intent or proposal to give any such notice or commence any such proceedings;
|
(p)
|
Environmental
- except as disclosed to the Agent, neither the Borrower nor any of its Subsidiaries has:
|
(i)
|
any knowledge of any Environmental Adverse Effect or any condition existing at, on or under the Principal Property which, in any case or in the aggregate, with the passage of time or the giving of notice or both, could reasonably be expected to give rise to liability of the Borrower or any of its Subsidiaries resulting in a Material Adverse Effect;
|
(ii)
|
any knowledge of any present or prior leaks or spills with respect to underground storage tanks and piping system or any other underground structures existing at, on or under Principal Property or of any past violations by any Applicable Laws, policies or codes of practice involving the Principal Property, which violations, in any case or in the aggregate, could reasonably be expected to have a Material Adverse Effect;
|
(iii)
|
any knowledge that it has any obligation under any Environmental Laws to pay any compensation or damages resulting from the operation of the Principal Property, or that it will have any such obligation resulting from the maintenance and operation of the Principal Property, which, in any case or in the aggregate, could reasonably be expected to have a Material Adverse Effect; and
|
(iv)
|
any Environmental Liability which, in any case or in the aggregate, could reasonably be expected to have a Material Adverse Effect except as disclosed by the Borrower to the Agent in writing prior to the Effective Date;
|
(q)
|
No Proceedings or Investigations
- none of the Borrower or its Subsidiaries is, as at the date that this representation is made or deemed to be made, the subject of any civil, criminal or regulatory proceeding or governmental or regulatory investigation with respect to Environmental Laws nor are any of them aware of any threatened proceedings or investigations which, in any case or in the aggregate, could reasonably be expected to have a Material Adverse Effect except as disclosed in accordance with the notice requirements set out in Section 10.5. The Borrower and its Subsidiaries are actively and diligently proceeding to use all reasonable efforts to comply with all Environmental Laws and all such activities are being carried on in a prudent and responsible manner and with all due care and due diligence;
|
(r)
|
Insurance
- the Borrower and its Subsidiaries maintain insurance or self insure (including business interruption insurance, property insurance and general liability insurance) with responsible insurance carriers and in such amounts and covering such risks as are usually carried by companies engaged in similar businesses and owning similar properties;
|
(s)
|
Pension Plans
– Neither the Borrower nor any of its Subsidiaries (except AltaLink Management Ltd.) has established or is party to or obligated under any pension plans. All pension plans established by AltaLink Management Ltd. are being operated, administered and maintained in compliance with all laws, regulations and orders applicable thereto, except for such instances of non-compliance as have not resulted in and could not reasonably be expected to result in a Material Adverse Effect. All premiums, contributions and any other amounts required by applicable pension plan documents or applicable Laws to be paid or accrued by AltaLink Management Ltd., to the extent failure to do so could reasonably be expected to result in a Material Adverse Effect, are being paid or accrued as required;
|
(t)
|
Subsidiaries
- (i) the Borrower is the sole limited partner and is the owner of 99.99% of the Equity Securities in AltaLink and AltaLink Management Ltd. is the sole general partner and is the owner of .01% of the Equity Securities of AltaLink, (ii) no Person has any right or option to purchase or otherwise acquire any of the Equity Securities of AltaLink; and (iii) the Borrower does not own or hold any Equity Securities in, directly or indirectly, any other Person, other than as disclosed in Schedule 9.1(a), as amended from time to time and provided to the Lenders (provided such amendments shall not otherwise be contrary to this Agreement); and
|
(u)
|
Complete Disclosure
- all written information and data concerning the Borrower, the General Partner and the Borrower’s Subsidiaries that have been prepared by it or any of its representatives or advisors and that have been made available to the Agent or the Lenders are and, at the time such information and data were made available, were true and correct in all material respects and do not, and, at the time such information and data were made available, did not, contain any untrue statement of a material fact, or omit to state a material fact necessary in order to make the statements contained in such information and data not misleading in light of the circumstances under which such statements were made.
|
9.2
|
Survival of Representations and Warranties.
|
10.1
|
Reporting Covenants.
|
(a)
|
Information and Certificates
. The Borrower shall furnish to the Agent (in “pdf” format where practicable, or in such other form as may be agreed between the Borrower and the Agent):
|
(i)
|
not later than one hundred and forty (140) days (or such earlier date as may be prescribed from time to time under applicable securities legislation for the delivery of annual financial statements to security holders) after the end of each Fiscal Year, the annual financial statements (consolidated and unconsolidated) of the Borrower consisting of a balance sheet and statements of income, retained earnings and changes in financial position for the year then ended and for the immediately preceding Fiscal Year together with the report on such consolidated statements of the Borrower’s auditors and the discussion and analysis of such consolidated statements prepared by the management of the Borrower;
|
(ii)
|
not later than sixty (60) days (or such earlier date as may be prescribed from time to time under applicable securities legislation for the delivery of interim financial
|
(iii)
|
at the time the same are sent, copies of all financial statements and other information or material that are delivered to the Trustee under the Master Trust Indenture including, without limitation, notice of any “Event of Default” under the Master Trust Indenture;
|
(iv)
|
on or before thirty (30) days prior to the beginning of the next Fiscal Year of the Borrower, an annual consolidated and unconsolidated financial forecast of the Borrower;
|
(v)
|
a certified copy of any supplemental indenture which amends in any way the Master Trust Indenture; and
|
(vi)
|
upon delivery of each of the items set out in Sections 10.1(a)(i) and (ii) of this Agreement, the Borrower’s Certificate of Compliance, which Certificate of Compliance shall be accompanied by,
inter alia
, details of the calculation of EBITDA in accordance with GAAP for the purposes of the Interest Coverage Ratio in Section 10.24(a), in form and substance satisfactory to the Lenders.
|
10.2
|
Payments Under This Agreement and Loan Documents.
|
10.3
|
Proceeds.
|
10.4
|
Inspection of Property, Books and Records, Discussions.
|
10.5
|
Notices.
The Borrower shall promptly give notice to the Agent of:
|
(a)
|
the occurrence of any Default or Event of Default;
|
(b)
|
the commencement of, or receipt by the Borrower of a written threat of, any action, suit or proceeding against or affecting the Borrower before any Governmental Authority which,
|
(c)
|
any notice of any violation or administrative or judicial complaint or order having been filed or, to the Borrower’s knowledge, about to be filed against the Borrower which has, or has any reasonable likelihood of having, a Material Adverse Effect;
|
(d)
|
any notice from any Governmental Authority or any other Person alleging that the Borrower is or may be subject to any Environmental Liability which has, or has any reasonable likelihood of having, a Material Adverse Effect;
|
(e)
|
any notice of any material violation of Applicable Utilities Legislation;
|
(f)
|
the occurrence or non-occurrence of any other event which has, or has a reasonable likelihood of having, a Material Adverse Effect;
|
(g)
|
any changes in the ownership structure to the Borrower; and
|
(h)
|
any notice of a change in rating to the Senior Bonds (as such term is defined in the Master Trust Indenture) by any of the Rating Agencies.
|
10.6
|
Disbursements under Master Trust Indenture.
|
10.7
|
Cure Defects.
|
10.8
|
Carrying on Business.
|
10.9
|
Insurance and Insurance Proceeds.
|
(a)
|
The Borrower and each of its Subsidiaries shall maintain insurance with respect to its properties and business and against such casualties and contingencies and in such types and such amounts as shall be in accordance with sound business practices which are standard in the industry and in accordance with any express requirements of Governmental Authorities, where applicable, including the right to self-insure and/or co-insure with respect to any of the insurance required to be maintained by the Borrower pursuant to this paragraph.
|
(b)
|
Immediately upon receipt by the Borrower of any Insurance Proceeds, Borrower shall apply such Insurance Proceeds in accordance with Section 4.1 of the Master Trust Indenture. Notwithstanding the foregoing, to the extent that any Insurance Proceeds are used by the Borrower, within 12 months after receipt of same, to replace or repair the Assets in respect of which the Insurance Proceeds were received, then such Insurance Proceeds need not be so applied. Borrower shall provide Agent with a copy of any officer’s certificate provided pursuant to Section 6.10 of the Master Trust Indenture.
|
10.10
|
Compliance with Laws and Agreements.
|
10.11
|
Taxes.
|
10.12
|
Further Assurances.
|
10.13
|
Limitation on Indebtedness.
|
10.14
|
Negative Pledge.
|
10.15
|
Investments.
|
10.16
|
Change in Business and Ownership of AltaLink and Subsidiaries.
|
10.17
|
Mergers, Etc.
|
10.18
|
Acquisitions.
|
10.19
|
Transactions with Non-Arm’s Length Persons.
|
10.20
|
Environmental Covenants.
|
(a)
|
The Borrower and its Subsidiaries shall, at all times conduct and maintain the Business in compliance in all material respects with all Environmental Laws and Environmental Approvals.
|
(b)
|
If the Borrower or any of its Subsidiaries shall:
|
(i)
|
receive notice from any Governmental Authority that any material violation of any Environmental Law or Environmental Approval has been, may have been, or is about to be committed by the Borrower or its Subsidiaries;
|
(ii)
|
receive notice that any Remedial Order or other proceeding has been filed or is about to be filed against the Borrower or any of its Subsidiaries alleging material violations of any Environmental Law or requiring the Borrower or any of its Subsidiaries to take any material action in connection with the Release or threatened Release of a Hazardous Substance into the environment or requiring the cessation of a nuisance; or
|
(iii)
|
receive any notice from a Governmental Authority alleging that the Borrower or any of its Subsidiaries may be liable or responsible for material costs associated with a nuisance or a response to, or clean up of, a Release or threatened Release of a Hazardous Substance into the environment or any damages caused thereby;
|
10.21
|
Hedging Agreements.
|
10.22
|
Distributions.
|
10.23
|
Fiscal Year.
|
10.24
|
Financial Covenants.
|
(a)
|
Interest Coverage Ratio
. The Borrower shall maintain, measured each Fiscal Quarter in each Fiscal Year, commencing with the Fiscal Quarter ending December 31, 2016, a ratio of EBITDA for the four Fiscal Quarters then ended to Interest Expense for the four Fiscal Quarters then ended, of not less than 2.25:1. The parties agree that for the purposes of this Section 10.24(a), and provided that the reporting requirements in Section 10.1(a)(vi) are complied with in respect of such calculation, EBITDA shall be calculated on the basis of GAAP (as in effect immediately prior to the adoption by the Borrower of IFRS), notwithstanding the fact that the Borrower may have adopted IFRS; and
|
(b)
|
Consolidated Total Debt to Consolidated Total Capitalization
. The Borrower and its Subsidiaries shall maintain, during each Fiscal Quarter in each Fiscal Year, commencing with the Fiscal Quarter ending December 31, 2016, a maximum ratio of Consolidated Total Debt to Consolidated Total Capitalization of 80%.
|
10.25
|
Master Trust Indenture.
|
11.1
|
Conditions Precedent to the Closing.
|
(a)
|
this Agreement shall have been duly executed and delivered by the Borrower and the General Partner;
|
(b)
|
completion of and satisfactory results with respect to, such financial, business and legal due diligence as reasonably requested by the Lenders;
|
(c)
|
receipt of a duly executed 2016 Supplemental Indenture, Senior Pledged Bond, Series 3 and Bond Delivery Agreement and any other documents, certificates or other deliveries required under Section 2.4 of the Master Trust Indenture;
|
(d)
|
the Agent or the Lenders shall have received any other Loan Documents required by the Agent or the Lenders duly executed by the Borrower and the General Partner, as the case may be;
|
(e)
|
the following documents in form, substance and execution acceptable to the Agent shall have been delivered to the Agent:
|
(i)
|
duly certified copies of the constating documents of the Borrower and the General Partner, all necessary resolutions of the board of directors or similar necessary proceedings taken and required to be taken by the Borrower to authorize the execution and delivery of this Agreement and the Loan Documents to which it is a party and the entering into and performance of the transactions contemplated herein and therein;
|
(ii)
|
certificates of incumbency of the General Partner setting forth specimen signatures of the persons authorized to execute this Agreement, on behalf of the Borrower and the Loan Documents to which it is a party;
|
(iii)
|
certificate of status or the equivalent relative to the Borrower and the General Partner under its jurisdiction of creation; and
|
(iv)
|
the opinion of counsel for the Borrower in form and substance satisfactory to the Lenders;
|
(f)
|
there not having occurred a Material Adverse Change since September 30, 2016;
|
(g)
|
all fees payable on or before the date hereof in connection with the Credit Facility under this Agreement and any fee letter shall have been paid to the Agent; and
|
(h)
|
there shall exist no Default or Event of Default.
|
11.2
|
Conditions Precedent to All Borrowings, Conversions.
|
(a)
|
the Agent shall have received any required Borrowing Notice;
|
(b)
|
the Agent shall have received any required Documentary Credit agreement, or other Loan Document;
|
(c)
|
there shall exist no Default or Event of Default on the applicable Borrowing Date, nor shall any arise as a result of giving effect to the requested Borrowing;
|
(d)
|
all representations and warranties contained in ARTICLE 9 shall be true on and as of the Borrowing Date with the same effect as if such representations and warranties had been made on and as of such Borrowing Date; and
|
(e)
|
all fees payable on or before the subsequent Borrowing in connection with the Credit Facility under this Agreement or any other Loan Document shall have been paid to the Agent and the Lenders, as applicable.
|
11.3
|
Waiver.
|
12.1
|
Events of Default.
|
(a)
|
Default in Payment of any Amount Hereunder
. If the Borrower fails to pay (i) any principal amount of the Accommodations when such amount becomes due and payable, (ii) any interest or fees owing to the Lenders and/or Agent or any of them hereunder, or under any Loan Document when due and payable hereunder or thereunder and such failure shall remain unremedied for five (5) Business Days or (iii) any other amount owing to the Lenders and/or Agent or any of them hereunder, or under any Loan Document when due and payable hereunder or thereunder and such failure shall remain unremedied for five (5) Business Days;
|
(b)
|
Representation or Warranty.
If any representation and warranty made by the Borrower in or in connection with this Agreement or any of the other Loan Documents shall be untrue in any material respect on the date upon which it was given;
|
(c)
|
Default in Certain Covenants
.
|
(i)
|
If the Borrower or any of its Subsidiaries (as applicable and as if each Subsidiary of the Borrower were party hereto) shall fail, refuse or default in any material respect with the performance or observance of any of the covenants contained in Sections 10.13, 10.15, 10.16(b), and 10.18 to 10.23 inclusive, and such failure shall continue unremedied for 15 days; or
|
(ii)
|
If the Borrower or any of its Subsidiaries (as applicable and as if each Subsidiary of the Borrower were party hereto) shall fail, refuse or default in any material respect with the performance or observance of any of the covenants contained in Sections 10.14, 10.16(a), 10.17, 10.24 or 10.25, (provided that, in the case of Section 10.25, there shall be no Event of Default until the expiry of the applicable cure period, if any, under the Master Trust Indenture);
|
(d)
|
Default in Other Provisions.
If the Borrower or any of its Subsidiaries (as applicable and as if each Subsidiary of the Borrower were party hereto) shall fail, refuse or default in any material respect with the performance or observance of any of the other covenants, agreements or conditions contained herein and such failure, refusal or default adversely affects the Lenders
|
(e)
|
Indebtedness
.
If (i) the Borrower or any of its Subsidiaries fails to pay the principal of any of its Indebtedness (which shall, for greater certainty, exclude the Indebtedness under this Agreement but shall include (without limitation) the Indebtedness under the Master Trust Indenture, the 2015 Credit Agreement and the Senior Bonds, Series 09-1, the Senior Bonds, Series 12-1, the Senior Bonds, Series 13-1, and the Senior Bonds, Series 15-1) which is outstanding in an aggregate principal amount exceeding (x) Cdn. $15,000,000 in the case of the Borrower and (y) Cdn. $10,000,000 in the case of AltaLink or any other Subsidiary of the Borrower (or the Equivalent Amount in any other currency) when such amount becomes due and payable (whether by scheduled maturity, required prepayment, acceleration, demand or otherwise) and such failure continues after the applicable grace period, if any, specified in the agreement or instrument relating to such Indebtedness described in paragraphs (x) and (y) above, without waiver of such failure by the holder of such Indebtedness on or before the expiration of such period; or (ii) any other event occurs or condition exists (including a failure to pay the premium or interest on such Indebtedness) and continues after the applicable grace period, if any, specified in any agreement or instrument relating to any such Indebtedness without waiver of such failure by the holder of such Indebtedness on or before the expiration of such period, if the effect of such event is to accelerate, or permit the acceleration of, such Indebtedness; or (iii) any such Indebtedness shall be declared to be, or otherwise becomes, due and payable prior to its stated maturity by reason of default;
|
(f)
|
Judgment
. The rendering of a judgment or judgments against the Borrower or any of its Subsidiaries, in an aggregate amount in excess of Cdn. $20,000,000 (or the Equivalent Amount in any other currency), by a court or courts of competent jurisdiction, which judgment or judgments remain undischarged and unstayed for a period of sixty (60) days;
|
(g)
|
Change in Legislation.
If there occurs any change in the Applicable Utilities Legislation or any other Applicable Laws resulting in a Material Adverse Effect on the Business of the Borrower or any of its Subsidiaries;
|
(h)
|
Termination of Material Agreements, licences etc.
|
(i)
|
If any Material Agreement is terminated for any reason prior to the expiry of its term (except as contemplated thereunder) unless: (A) such Material Agreement is replaced by the Borrower with a contract on commercially reasonable terms or (B) such termination does not result in a Material Adverse Effect;
|
(ii)
|
if a default occurs under, or if the Borrower fails to observe or perform any term, covenant or agreement contained in, any Material Agreement unless such default or failure does not result in a Material Adverse Effect; or
|
(iii)
|
if any permit, licence, consent or other authorization required to be kept in full force and effect hereunder with respect to the Business is revoked or suspended for any reason whatsoever and such revocation or suspension results in a Material Adverse Effect and such revocation and suspension continues for a period of 45 days, unless the Borrower does not contest such revocation or suspension in good faith, diligently and by appropriate means;
|
(i)
|
Winding Up
.
If an order shall be made or an effective resolution be passed for the winding-up or liquidation of the Borrower or any of its Subsidiaries or any such proceedings are initiated unless such proceedings are being actively and diligently contested by the Borrower in good faith;
|
(j)
|
Bankruptcy or Insolvency.
If the Borrower or any of its Subsidiaries shall make a general assignment for the benefit of its creditors or a notice of intention to make a proposal or a proposal under the
Bankruptcy and
Insolvency Act
(Canada), or shall become insolvent or be declared or adjudged bankrupt, or a receiving order be made against the Borrower or any of its Subsidiaries or if a liquidator, trustee in bankruptcy, receiver, receiver and manager or any other officer with similar powers shall be appointed to the Borrower or any of its Subsidiaries, or if the Borrower or any of its Subsidiaries shall propose a compromise, arrangement or reorganization under the
Companies’ Creditors
Arrangement Act
(Canada) or any other legislation of any jurisdiction (including corporate statutes, as applicable) providing for the reorganization or winding-up of Borrower or any of its Subsidiaries or business entities or providing for an arrangement, composition, extension or adjustment with its creditors or shall voluntarily suspend transaction of its usual business, or shall take corporate or other action in furtherance of any of the foregoing purposes;
|
(k)
|
Receiver.
If any proceeding for the appointment of a receiver or trustee for the Borrower or any of its Subsidiaries or for any substantial part of the property of the Borrower or any of its Subsidiaries which is material to the conduct of the Business, and any such receivership or trusteeship remains undischarged for a period of sixty (60) days, or if the Borrower or any of its Subsidiaries becomes bankrupt or unable to pay its obligations as they become due or is declared to be bankrupt or unable to pay its obligations as they become due;
|
(l)
|
Full Force and Effect
. If this Agreement or any material portion hereof shall, at any time after its respective execution and delivery and for any reason, cease in any way to be in full force and effect or if the validity or enforceability of this Agreement is disputed in any manner by such Borrower and the Credit Facility has not been repaid within 30 days of demand therefor by the Agent; and
|
(m)
|
Change of Control
. If there shall occur any Change of Control.
|
12.2
|
Remedies.
|
(a)
|
demand payment of any principal, accrued interest, fees and other amounts which are then due and owing in respect of the Accommodation under the Credit Facility without presentment, protest or other notice of any kind, all of which are hereby expressly waived by the Borrower;
|
(b)
|
declare by notice to the Borrower the Credit Facility terminated, whereupon the same shall terminate immediately without any further notice of any kind;
|
(c)
|
commence such legal action or proceedings as it, in its sole discretion, may deem expedient, including the commencement of enforcement proceedings under the Loan Documents, all without any additional notice, presentation, demand, protest, notice of dishonour, entering into of possession of any of the assets, or any other action or notice, all of which the Borrower and General Partner hereby expressly waive; and
|
(d)
|
demand payment of the Senior Pledged Bond, Series 3 in accordance with the provisions of the Bond Delivery Agreement.
|
12.3
|
Remedies Cumulative.
|
12.4
|
Appropriation of Moneys Received.
|
12.5
|
Non-Merger.
|
12.6
|
Waiver.
|
12.7
|
Set-off.
|
13.1
|
Increased Costs.
|
(a)
|
Increased Costs Generally. If any Change in Law shall:
|
(i)
|
impose, modify or deem applicable any reserve, special deposit, compulsory loan, insurance charge or similar requirement against assets of, deposits with or for the account of, or credit extended or participated in by, any Lender;
|
(ii)
|
subject any Lender to any Tax of any kind whatsoever with respect to this Agreement or any Accommodations made by it, or change the basis of taxation of payments to such Lender in respect thereof, except for Indemnified Taxes or Other Taxes covered by Section 13.2 and the imposition, or any change in the rate, of any Excluded Tax payable by such Lender; or
|
(iii)
|
impose on any Lender or any applicable interbank market any other condition, cost or expense affecting this Agreement or Accommodations made by such Lender,
|
(b)
|
Capital Requirements.
If any Lender determines that any Change in Law affecting such Lender, or any lending office of such Lender or such Lender’s holding company, if any, regarding capital requirements has or would have the effect of reducing the rate of return on such Lender’s capital or on the capital of such Lender’s holding company, if any, as a consequence of this Agreement, the Commitments of such Lender or the Accommodations made by such Lender, to a level below that which such Lender or its holding company could have achieved but for such Change in Law (taking into consideration such Lender’s policies and the policies of its holding company with respect to capital adequacy), then from time to time the Borrower will pay to such Lender such additional amount or amounts as will compensate such Lender or its holding company for any such reduction suffered.
|
(c)
|
Certificates for Reimbursement.
A certificate of a Lender setting forth the amount or amounts necessary to compensate such Lender or its holding company, as the case may be, as specified in paragraph (a) or (b) of this Section (“
Additional Compensation
”), including a description of the event by reason of which it believes it is entitled to such compensation, and supplying reasonable supporting evidence (including, in the event of a Change in Law, a photocopy of the applicable Law evidencing such change) and reasonable detail of the basis of calculation of the amount or amounts, and delivered to the Borrower shall be conclusive absent manifest error. The Borrower shall pay such Lender the amount shown as due on any such certificate
|
(d)
|
Delay in Requests.
Failure or delay on the part of any Lender to demand compensation pursuant to this Section shall not constitute a waiver of such Lender’s right to demand such compensation, except that the Borrower shall not be required to compensate a Lender pursuant to this Section for any increased costs incurred or reductions suffered more than nine months prior to the date that such Lender notifies the Borrower of the Change in Law giving rise to such increased costs or reductions and of such Lender’s intention to claim compensation therefore, unless the Change in Law giving rise to such increased costs or reductions is retroactive, in which case the nine-month period referred to above shall be extended to include the period of retroactive effect thereof.
|
13.2
|
Taxes.
|
(a)
|
Payments Subject to Taxes.
If any Credit Party, the Agent or any Lender is required by Applicable Law to deduct or pay any Indemnified Taxes (including any Other Taxes) in respect of any payment by or on account of any obligation of a Credit Party hereunder or under any other Loan Document, then (i) the sum payable shall be increased by that Credit Party when payable as necessary so that after making or allowing for all required deductions and payments (including deductions and payments applicable to additional sums payable under this Section) the Agent or Lender, as the case may be, receives an amount equal to the sum it would have received had no such deductions or payments been required, (ii) the Credit Party shall make any such deductions required to be made by it under Applicable Law and (iii) the Credit Party shall timely pay the full amount required to be deducted to the relevant Governmental Authority in accordance with Applicable Law.
|
(b)
|
Payment of Other Taxes by the Borrower.
Without limiting the provisions of paragraph (1) above, the Borrower shall timely pay any Other Taxes to the relevant Governmental Authority in accordance with Applicable Law.
|
(c)
|
Indemnification by the Borrower.
The Borrower shall indemnify the Agent and each Lender, within 15 days after written demand therefor, for the full amount of any Indemnified Taxes or Other Taxes (including Indemnified Taxes or Other Taxes imposed or asserted on or attributable to amounts payable under this Section) paid by the Agent or such Lender and any penalties, interest and reasonable expenses arising therefrom or with respect thereto, whether or not such Indemnified Taxes or Other Taxes were correctly or legally imposed or asserted by the relevant Governmental Authority. A certificate as to the amount of such payment or
|
(d)
|
Evidence of Payments.
As soon as practicable after any payment of Indemnified Taxes or Other Taxes by a Credit Party to a Governmental Authority, the Credit Parties shall deliver to the Agent the original or a certified copy of a receipt issued by such Governmental Authority evidencing such payment, a copy of the return reporting such payment or other evidence of such payment reasonably satisfactory to the Agent.
|
(e)
|
Status of Lenders.
Any Foreign Lender that is entitled to an exemption from or reduction of withholding tax under the law of the jurisdiction in which the Borrower is resident for tax purposes, or any treaty to which such jurisdiction is a party, with respect to payments hereunder or under any other Loan Document shall, at the request of the Borrower, deliver to the Borrower (with a copy to the Agent), at the time or times prescribed by applicable Law or reasonably requested by the Borrower or the Agent, such properly completed and executed documentation prescribed by applicable Law as will permit such payments to be made without withholding or at a reduced rate of withholding. In addition any Lender, if requested by the Borrower or the Agent, shall deliver such other documentation prescribed by applicable Law or reasonably requested by the Borrower or the Agent as will enable the Borrower or the Agent to determine whether or not such Lender is subject to withholding or information reporting requirements.
|
(f)
|
Treatment of Certain Refunds and Tax Reductions
. If the Agent or a Lender determines, in its sole discretion, that it has received a refund of any Taxes or Other Taxes as to which it has been indemnified by the Borrower or with respect to which a Credit Party has paid additional amounts pursuant to this Section 13.2 or that, because of the payment of such Taxes or Other Taxes, it has benefited from a reduction in Excluded Taxes otherwise payable by it, it shall pay to the Borrower or other Credit Party, as applicable, an amount equal to such refund or reduction (but only to the extent of indemnity payments made, or additional amounts paid, by the Borrower or other Credit Party under this Section with respect to the Taxes or Other Taxes giving rise to such refund or reduction), net of all out-of-pocket expenses of the Agent or such Lender, as the case may be, and without interest (other than any net after-Tax interest paid by the relevant Governmental Authority with respect to such refund). The Borrower or other Credit Party as applicable, upon the request of the Agent or such Lender, agrees to repay the amount paid over to the Borrower or other Credit Party (plus any penalties, interest or other charges imposed by the relevant Governmental Authority) to the Agent or such Lender if the Agent or such Lender is required to repay such refund or reduction to such Governmental Authority. This paragraph shall not be construed to require the Agent or any Lender to make available its tax returns (or any other information relating to its taxes that it deems confidential) to the Borrower or any other Person, to arrange its affairs in any particular manner or to claim any available refund or reduction.
|
(g)
|
FATCA
. If a payment made to a Lender under any Loan Document would be subject to U.S. federal withholding Taxes imposed by FATCA, if such Lender were to fail to comply with the applicable reporting requirements of FATCA (including those contained in Section 1471
|
13.3
|
Mitigation Obligations: Replacement of Lenders.
|
(a)
|
Designation of a Different Lending Office.
If any Lender requests compensation under Section 13.1, or requires the Borrower to pay any additional amount to any Lender or any Governmental Authority for the account of any Lender pursuant to Section 13.2, then such Lender shall use reasonable efforts to designate a different lending office for funding or booking its Accommodations hereunder or to assign its rights and obligations hereunder to another of its offices, branches or affiliates, if, in the judgment of such Lender (with the prior consent of the Borrower), such designation or assignment (i) would eliminate or reduce amounts payable pursuant to Section 13.1 or Section 13.2, as the case may be, in the future and (ii) would not subject such Lender to any unreimbursed cost or expense and would not otherwise be disadvantageous to such Lender. The Borrower hereby agrees to pay all reasonable out-of-pocket costs and expenses incurred by any Lender in connection with any such designation or assignment.
|
(b)
|
Replacement of Lenders.
If any Lender requests compensation under Section 13.1, if the Borrower is required to pay any additional amount to any Lender or any Governmental Authority for the account of any Lender pursuant to Section 13.2, if any Lender’s obligations are suspended pursuant to Section 13.4 or if any Lender defaults in its obligation to fund Accommodations hereunder, then the Borrower may either, at its sole expense and effort, upon 10 days’ notice to such Lender and the Agent: (i) repay all outstanding amounts due to such affected Lender (or such portion which has not been acquired pursuant to clause (ii) below) and thereupon such Commitment of the affected Lender shall be permanently cancelled and the aggregate Commitment shall be permanently reduced by the same amount and the Commitment of each of the other Lenders shall remain the same; or (ii) require such Lender to assign, without recourse (in accordance with and subject to the restrictions contained in, and consents required by, Article 20), all of its interests, rights and obligations under this Agreement and the related Loan Documents to an assignee that shall assume such obligations (which assignee may be another Lender, if a Lender accepts such assignment), provided that:
|
(i)
|
the Borrower pays the Agent the assignment fee specified in Section 20.1(b)(vi);
|
(ii)
|
the assigning Lender receives payment of an amount equal to the outstanding principal of its Accommodations outstanding and participations in disbursements under Documentary Credits, accrued interest thereon, accrued fees and all other amounts payable to it hereunder and under the other Loan Documents (including any breakage costs and amounts required to be paid under this Agreement as a result of prepayment to a Lender) from the assignee (to the extent of such outstanding principal and accrued interest and fees) or the Borrower (in the case of all other amounts);
|
(c)
|
in the case of any such assignment resulting from a claim for compensation under Section 13.1 or payments required to be made pursuant to Section 13.2, such assignment will result in a reduction in such compensation or payments thereafter; and
|
(d)
|
such assignment does not conflict with Applicable Law.
|
13.4
|
Illegality.
|
14.1
|
Right of Setoff.
|
15.1
|
Sharing of Payments by Lenders.
|
(a)
|
if any such participations are purchased and all or any portion of the payment giving rise thereto is recovered, such participations shall be rescinded and the purchase price restored to the extent of such recovery, without interest;
|
(b)
|
the provisions of this Section shall not be construed to apply to (x) any payment made by any Credit Party pursuant to and in accordance with the express terms of this Agreement or (y) any payment obtained by a Lender as consideration for the assignment of or sale of a participation in any of its Accommodations or participations in disbursements under Documentary Credits to any assignee or participant, other than to any Credit Party or any Affiliate of a Credit Party (as to which the provisions of this Section shall apply); and
|
(c)
|
the provisions of this Section shall not be construed to apply to (w) any payment made while no Event of Default has occurred and is continuing in respect of obligations of the Borrower to such Lender that do not arise under or in connection with the Loan Documents, (x) any payment made in respect of an obligation that is secured by a Permitted Lien or that is otherwise entitled to priority over the Borrower’s obligations under or in connection with the Loan Documents, (y) any reduction arising from an amount owing to a Credit Party upon the termination of derivatives entered into between the Credit Party and such Lender, or (z) any payment to which such Lender is entitled as a result of any form of credit protection obtained by such Lender.
|
16.1
|
Agent’s Clawback.
|
(a)
|
Funding by Lenders; Presumption by Agent.
Unless the Agent shall have received notice from a Lender prior to the proposed date of any advance of funds that such Lender will not make available to the Agent such Lender’s share of such advance, the Agent may assume that
|
(b)
|
Payments by Borrower; Presumptions by Agent.
Unless the Agent shall have received notice from the Borrower prior to the date on which any payment is due to the Agent for the account of any Lender hereunder that the Borrower will not make such payment, the Agent may assume that the Borrower has made such payment on such date in accordance herewith and may, in reliance upon such assumption, distribute the amount due to the Lenders. In such event, if the Borrower has not in fact made such payment, then each of the Lenders severally agrees to repay to the Agent forthwith on demand the amount so distributed to such Lender with interest thereon, for each day from and including the date such amount is distributed to it to but excluding the date of payment to the Agent, at a rate determined by the Agent in accordance with prevailing banking industry practice on interbank compensation.
|
17.1
|
Appointment and Authority.
|
17.2
|
Rights as a Lender.
|
17.3
|
Exculpatory Provisions.
|
(a)
|
The Agent shall not have any duties or obligations except those expressly set forth herein and in the other Loan Documents. Without limiting the generality of the foregoing, the Agent:
|
(i)
|
shall not be subject to any fiduciary or other implied duties, regardless of whether a Default has occurred and is continuing;
|
(ii)
|
shall not have any duty to take any discretionary action or exercise any discretionary powers, except discretionary rights and powers expressly contemplated hereby or by the other Loan Documents that the Agent is required to exercise as directed in writing by the Majority Lenders (or such other number or percentage of the Lenders as shall be expressly provided for in the Loan Documents), but the Agent shall not be required to take any action that, in its opinion or the opinion of its counsel, may expose the Agent to liability or that is contrary to any Loan Document or applicable Law; and
|
(iii)
|
shall not, except as expressly set forth herein and in the other Loan Documents, have any duty to disclose, and shall not be liable for the failure to disclose, any information relating to the Borrower or any of their Affiliates that is communicated to or obtained by the person serving as the Agent or any of its Affiliates in any capacity.
|
(b)
|
The Agent shall not be liable for any action taken or not taken by it (i) with the consent or at the request of the Majority Lenders (or such other number or percentage of the Lenders as is necessary, or as the Agent believes in good faith is necessary, under the provisions of the Loan Documents) or (ii) in the absence of its own gross negligence or wilful misconduct. The Agent shall be deemed not to have knowledge of any Default unless and until notice describing the Default is given to the Agent by the Borrower or a Lender.
|
(c)
|
Except as otherwise expressly specified in this Agreement, the Agent shall not be responsible for or have any duty to ascertain or inquire into (i) any statement, warranty or representation made in or in connection with this Agreement or any other Loan Document, (ii) the contents of any certificate, report or other document delivered hereunder or thereunder or in connection herewith or therewith, (iii) the performance or observance of any of the covenants, agreements or other terms or conditions set forth herein or therein or the occurrence of any Default, (iv) the validity, enforceability, effectiveness or genuineness of this Agreement, any other Loan Document or any other agreement, instrument or document or (v) the satisfaction of any condition specified in this Agreement, other than to confirm receipt of items expressly required to be delivered to the Agent.
|
17.4
|
Reliance by Agent.
|
17.5
|
Indemnification of Agent.
|
17.6
|
Delegation of Duties.
|
17.7
|
Replacement of Agent.
|
(a)
|
The Agent may at any time give notice of its resignation to the Lenders and the Borrower. Upon receipt of any such notice of resignation, the Majority Lenders shall have the right, with the prior consent of the Borrower, to appoint a successor, which shall be a Lender having an office in Toronto, Ontario or Calgary Alberta or an Affiliate of any such Lender with an office in Toronto or Calgary. The Agent may also be removed at any time by the Majority Lenders upon 30 days’ notice to the Agent and the Borrower as long as the Majority Lenders, with the prior consent of the Borrower, appoint and obtain the acceptance of a successor within such 30 days, which shall have an office in Toronto/Calgary, or an Affiliate of any such Lender with an office in Toronto/Calgary.
|
(b)
|
If no such successor shall have been so appointed by the Majority Lenders and shall have accepted such appointment within 30 days after the retiring Agent gives notice of its resignation, then the retiring Agent may on behalf of the Lenders, appoint a successor Agent meeting the qualifications specified in Section 17.7(a), provided that if the Agent shall notify the Borrower and the Lenders that no qualifying Person has accepted such appointment, then such resignation shall nonetheless become effective in accordance with such notice and (a) the retiring Agent shall be discharged from its duties and obligations hereunder and under the other Loan Documents (except that in the case of any collateral security held by the Agent on behalf of the Lenders under any of the Loan Documents, the retiring Agent shall continue to hold such collateral security until such time as a successor Agent is appointed); and (b) all payments, communications and determinations provided to be made by, to or through the Agent shall instead be made by or to each Lender directly, until such time as the Majority Lenders appoint a successor Agent as provided for above in the preceding paragraph.
|
(c)
|
Upon a successor’s appointment as Agent hereunder, such successor shall succeed to and become vested with all of the rights, powers, privileges and duties of the former Agent, and the former Agent shall be discharged from all of its duties and obligations hereunder or under the other Loan Documents (if not already discharged therefrom as provided in the preceding paragraph). The fees payable by the Borrower to a successor Agent shall be the same as those payable to its predecessor unless otherwise agreed between the Borrower and such successor. After the termination of the service of the former Agent, the provisions of this ARTICLE 17 and of ARTICLE 19 shall continue in effect for the benefit of such former Agent, its sub-agents and their respective Related Parties in respect of any actions taken or omitted to be taken by any of them while the former Agent was acting as Agent.
|
17.8
|
Non-Reliance on Agent and Other Lenders.
|
17.9
|
Collective Action of the Lenders.
|
17.10
|
No Other Duties, etc.
|
18.1
|
Notices, etc.
|
(a)
|
Notices Generally.
Except in the case of notices and other communications expressly permitted to be given by telephone (and except as-provided in paragraph (b) below), all notices and other communications provided for herein shall be in writing and shall be delivered by hand or overnight courier service, mailed by certified or registered mail or sent by facsimile or telecopier to the addresses or facsimile or telecopier numbers specified elsewhere in this Agreement or, if to a Lender, to it at its address or telecopier number specified in the Register or, if to a Credit Party other than the Borrower , in care of the Borrower.
|
(b)
|
Electronic Communications.
Notices and other communications to the Lenders hereunder may be delivered or furnished by electronic communication (including e-mail and Internet or intranet websites) pursuant to procedures approved by the Agent, provided that the foregoing shall not apply to notices to any Lender if such Lender has notified the Agent that it is incapable of receiving notices under such Article by electronic communication. The Agent or the Borrower may, in its discretion, agree to accept notices and other communications to it hereunder by electronic communications pursuant to procedures approved by it, provided that approval of such procedures may be limited to particular notices or communications.
|
(c)
|
Change of Address, Etc. Any party hereto may change its address or telecopier number for notices and other communications hereunder by notice to the other parties hereto.
|
19.1
|
Expenses; Indemnity: Damage Waiver.
|
(a)
|
Costs and Expenses.
The Borrower shall pay (i) all reasonable out-of-pocket expenses incurred by the Agent and its Affiliates, including the reasonable fees, charges and disbursements of counsel for the Agent, in connection with the preparation, negotiation,
|
(b)
|
Indemnification by the Borrower.
The Borrower shall indemnify the Agent (and any sub-agent thereof), each Lender, and each Related Party of any of the foregoing Persons (each such Person being called an “
Indemnitee
”) against, and hold each Indemnitee harmless from, any and all losses, claims, damages, liabilities and related expenses, including the fees, charges and disbursements of any counsel for any Indemnitee, incurred by any Indemnitee or asserted against any Indemnitee by any third party or by any Credit Party arising out of, in connection with, or as a result of (i) the execution or delivery of this Agreement, any other Loan Document or any agreement or instrument contemplated hereby or thereby, the performance or non-performance by the parties hereto of their respective obligations hereunder or thereunder or the consummation or non-consummation of the transactions contemplated hereby or thereby, (ii) any Accommodation or the use or proposed use of the proceeds therefrom (including any refusal by the Documentary Credit Lender to honour a demand for payment under a Documentary Credit if the documents presented in connection with such demand do not strictly comply with the terms of such Documentary Credit), (iii) any actual or alleged presence or Release of Hazardous Substance on or from any property owned or operated by any Credit Party, or any Environmental Liabilities related in any way to any Credit Party, or (iv) any actual or prospective claim, litigation, investigation or proceeding relating to any of the foregoing, whether based on contract, tort or any other theory, whether brought by a third party or by a Credit Party and regardless of whether any Indemnitee is a party thereto, provided that such indemnity shall not, as to any Indemnitee, be available to the extent that such losses, claims, damages, liabilities or related expenses (x) are determined by a court of competent jurisdiction by final and nonappealable judgment to have resulted from the gross negligence or wilful misconduct of such Indemnitee or (y) result from a claim brought by the Borrower or any other Credit Party against an Indemnitee for breach of such Indemnitee’s obligations hereunder or under any other Loan Document, if the Credit Party has obtained a final and nonappealable judgment in its favour on such claim as determined by a court of competent jurisdiction, nor shall it be available in respect of matters specifically addressed in Section 13.1, Section 13.2 and Section 19.1(a)
|
(c)
|
Reimbursement by Lenders.
To the extent that a Borrower for any reason fails to indefeasibly pay any amount required under paragraph (a) or (b) of this Section to be paid by it to the Agent (or any sub-agent thereof) or any Related Party of any of the foregoing, each Lender severally agrees to pay to the Agent (or any such sub-agent) or such Related Party, as the case may be, such Lender’s Applicable Percentage (determined as of the time that the applicable unreimbursed expense or indemnity payment is sought) of such unpaid amount, provided that the unreimbursed expense or indemnified loss, claim, damage, liability or related expense, as the case may be, was incurred by or asserted against the Agent (or any such sub-agent) in its capacity as such, or against any Related Party of any of the foregoing acting for the Agent (or any such sub-agent) in connection with such capacity. The obligations of the Lenders under
|
(d)
|
Waiver of Consequential Damages, Etc.
To the fullest extent permitted by Applicable Law, the Credit Parties shall not assert, and hereby waive, any claim against any Indemnitee, on any theory of liability, for indirect, consequential, punitive, aggravated or exemplary damages (as opposed to direct damages) arising out of, in connection with, or as a result of, this Agreement, any other Loan Document or any agreement or instrument contemplated hereby (or any breach thereof), the transactions contemplated hereby or thereby, any Accommodation or the use of the proceeds thereof. No Indemnitee shall be liable for any damages arising from the use by unintended recipients of any information or other materials distributed by it through telecommunications, electronic or other information transmission systems in connection with this Agreement or the other Loan Documents or the transactions contemplated hereby or thereby.
|
(e)
|
Payments.
All amounts due under this Section shall be payable promptly after demand therefor with documented particulars thereof. A certificate of the Agent or a Lender setting forth the amount or amounts owing to the Agent, Lender or a sub-agent or Related Party, as the case may be, as specified in this Section, including reasonable detail of the basis of calculation of the amount or amounts, and delivered to the Borrower shall be conclusive absent manifest error.
|
20.1
|
Successors and Assigns.
|
(a)
|
Successors and Assigns Generally.
The provisions of this Agreement shall be binding upon and inure to the benefit of the parties hereto and their respective successors and assigns permitted hereby, except that no Credit Party may assign or otherwise transfer any of its rights or obligations hereunder without the prior written consent of the Agent and each Lender and no Lender may assign or otherwise transfer any of its rights or obligations hereunder except (i) to an Eligible Assignee in accordance with the provisions of paragraph (b) of this Section, (ii) by way of participation in accordance with the provisions of paragraph (d) of this Section, or (iii) by way of pledge or assignment of a security interest subject to the restrictions of paragraph (f) of this Section (and any other attempted assignment or transfer by any party hereto shall be null and void). Nothing in this Agreement, expressed or implied, shall be construed to confer upon any Person (other than the parties hereto, their respective successors and assigns permitted hereby, Participants to the extent provided in paragraph (d) of this Section and, to the extent expressly contemplated hereby, the Related Parties of each of the Agent and the Lenders) any legal or equitable right, remedy or claim under or by reason of this Agreement.
|
(b)
|
Assignments by Lenders.
Any Lender may at any time assign to one or more Eligible Assignees all or a portion of its rights and obligations under this Agreement (including all or a portion of its Commitment and the Accommodations outstanding at the time owing to it); provided that:
|
(i)
|
except if an Event of Default has occurred and is continuing or in the case of an assignment of the entire remaining amount of the assigning Lender’s Commitment
|
(ii)
|
each partial assignment shall be made as an assignment of a proportionate part of all the assigning Lender’s rights and obligations under this Agreement with respect to the Accommodations outstanding or the Commitment assigned, except that this clause (ii) shall not prohibit any Lender from assigning all or a portion of its rights and obligations among separate credits on a non-pro rata basis;
|
(iii)
|
any assignment must be approved by the Documentary Credit Lender (such approval not to be unreasonably withheld or delayed) unless the Person that is the proposed assignee is itself already a Lender;
|
(iv)
|
any assignment must be approved by the Agent (such approval not to be unreasonably withheld or delayed) unless the proposed assignee is a bank whose senior, unsecured, non-credit enhanced, long term debt is rated at least A3, A- or A low by at least two of Moodys, S&P and DBRS, respectively;
|
(v)
|
any assignment must be approved by the Borrower (such approval not to be unreasonably withheld or delayed) unless the proposed assignee is itself already a Lender or if an Event of Default has occurred and is continuing;
and no assignment will be made to a Foreign Lender unless an Event of Default has occurred and is continuing; and
|
(vi)
|
the parties to each assignment shall execute and deliver to the Agent an Assignment and Assumption, together with a processing and recordation fee of Cdn $3,500 and the Eligible Assignee, if it shall not be a Lender, shall deliver to the Agent an Administrative Questionnaire.
|
(c)
|
Register.
The Agent shall maintain at one of its offices in Toronto, Ontario a copy of each Assignment and Assumption delivered to it and a register for the recordation of the names and addresses of the Lenders, and the Commitments of, and principal amounts of the Accommodations outstanding owing to, each Lender pursuant to the terms hereof from time to time (the “
Register
”). The entries in the Register shall be conclusive, absent manifest error, and the Borrower, the Agent and the Lenders may treat each Person whose name is recorded in the Register pursuant to the terms hereof as a Lender hereunder for all purposes of this Agreement, notwithstanding notice to the contrary. The Register shall be available for inspection by the Borrower and any Lender, at any reasonable time and from time to time upon reasonable prior notice.
|
(d)
|
Participations.
Any Lender may at any time, without the consent of, or notice to, any Borrower or the Agent, sell participations to any Person (other than a natural person, a Credit Party or any Affiliate of a Credit Party ) (each, a “
Participant
”) in all or a portion of such Lender’s rights and/or obligations under this Agreement (including all or a portion of its Commitment and/or the Accommodations outstanding owing to it); provided that (i) such Lender’s obligations under this Agreement shall remain unchanged, (ii) such Lender shall remain solely responsible to the other parties hereto for the performance of such obligations and (iii) the Borrower, the Agent and the other Lenders shall continue to deal solely and directly with such Lender in connection with such Lender’s rights and obligations under this Agreement. Any payment by a Participant to a Lender in connection with a sale of a participation shall not be or be deemed to be a repayment by the Borrower or a new Loan to the Borrower.
|
(e)
|
Limitation on Participants Rights.
A Participant shall not be entitled to receive any greater payment under Section 13.1 and Section 13.2 than the applicable Lender would have been entitled to receive with respect to the participation sold to such Participant, unless the sale of the participation to such Participant is made with the Borrower’s prior written consent. A Participant that would be a Foreign Lender if it were a Lender shall not be entitled to the benefits of Section 13.2.
|
(f)
|
Certain Pledges.
Any Lender may at any time pledge or assign a security interest in all or any portion of its rights under this Agreement to secure obligations of such Lender, but no such pledge or assignment shall release such Lender from any of its obligations hereunder or substitute any such pledgee or assignee for such Lender as a party hereto.
|
21.1
|
Amendments and Waivers.
|
(a)
|
Subject to subsections (b) and (c), no acceptance, amendment or waiver of any provision of any of the Loan Documents, nor consent to any departure by the Borrower or any other Person from such provisions, shall be effective unless in writing and approved by the Majority Lenders. Any acceptance, amendment, waiver or consent shall be effective only in the specific instance and for the specific purpose for which it was given.
|
(b)
|
Only written acceptances, amendments, waivers or consents signed by all the Lenders shall (i) increase a Lender’s Commitment; (ii) reduce the principal or amount of, or interest on, directly or indirectly, any Accommodation outstanding or any fees; (iii) postpone any date fixed for any payment of principal of, or interest on, any Accommodation outstanding or any fees; (iv) change the percentage of the Commitments or the number or percentage of Lenders required for the Lenders, or any of them, or the Agent to take any action; (v) change the definition of Majority Lenders; (vi) release or cancel any security for any obligation of a Credit Party hereunder; or (vii) amend this Section 21.1(b).
|
(c)
|
Only written acceptances, amendments, waivers or consents signed by the Agent, in addition to the Majority Lenders, shall affect the rights or duties of the Agent under the Loan Documents.
|
21.2
|
Judgment Currency.
|
(a)
|
If, for the purposes of obtaining judgment in any court, it is necessary to convert a sum due to a Lender in any currency (the “
Original Currency
”) into another currency (the “
Other Currency
”), the parties agree, to the fullest extent that they may effectively do so, that the rate of exchange used shall be that at which, in accordance with normal banking procedures, such Lender could purchase the Original Currency with the Other Currency on the Business Day preceding the day on which final judgment is given or, if permitted by Applicable Law, on the day on which the judgment is paid or satisfied.
|
(b)
|
The obligations of the Borrower in respect of any sum due in the Original Currency from it to any Lender under any of the Loan Documents shall, notwithstanding any judgment in any Other Currency, be discharged only to the extent that on the Business Day following receipt by the Lender of any sum adjudged to be so due in the Other Currency, the Lender may, in accordance with normal banking procedures, purchase the Original Currency with such Other Currency. If the amount of the Original Currency so purchased is less than the sum originally due to the Lender in the Original Currency, the Borrower agrees, as a separate obligation and notwithstanding the judgment, to indemnify the Lender, against any loss, and, if the amount of the Original Currency so purchased exceeds the sum originally due to the Lender in the Original Currency, the Lender shall remit such excess to the Borrower.
|
22.1
|
Governing Law; Jurisdiction; Etc.
|
(a)
|
Governing Law.
This Agreement shall be governed by, and construed in accordance with, the laws of the Province of Alberta and the laws of Canada applicable in that Province.
|
(b)
|
Submission to Jurisdiction.
Each Credit Party irrevocably and unconditionally submits, for itself and its property, to the nonexclusive jurisdiction of the courts of the Province of Alberta , and any appellate court from any thereof, in any action or proceeding arising out of or relating to this Agreement or any other Loan Document, or for recognition or enforcement of any judgment, and each of the parties hereto irrevocably and unconditionally agrees that all claims in respect of any such action or proceeding may be heard and determined in such court. Each of the parties hereto agrees that a final judgment in any such action or proceeding shall be conclusive and may be enforced in other jurisdictions by suit on the judgment or in any other manner provided by law. Nothing in this Agreement or in any other Loan Document shall affect any right that the Agent or any Lender may otherwise have to bring any action or proceeding relating to this Agreement or any other Loan Document against any Credit Party or its properties in the courts of any jurisdiction.
|
(c)
|
Waiver of Venue.
Each Credit Party irrevocably and unconditionally waives, to the fullest extent permitted by applicable Law, any objection that it may now or hereafter have to the laying of venue of any action or proceeding arising out of or relating to this Agreement or any other Loan Document in any court referred to in paragraph (b) of this Section. Each of the parties hereto hereby irrevocably waives, to the fullest extent permitted by Applicable Law, the defence of an inconvenient forum to the maintenance of such action or proceeding in any such court.
|
23.1
|
Waiver of Jury Trial.
|
24.1
|
Counterparts; Integration; Effectiveness; Electronic Execution.
|
(a)
|
Counterparts; Integration; Effectiveness.
This Agreement may be executed in counterparts (and by different parties hereto in different counterparts), each of which shall constitute an original, but all of which when taken together shall constitute a single contract. This Agreement shall become effective when it has been executed by the Agent and when the Agent has received counterparts hereof that, when taken together, bear the signatures of each of the other parties hereto. Delivery of an executed counterpart of a signature page of this Agreement by telecopy
|
(b)
|
Electronic Execution of Assignments.
The words “execution,” “signed,” “signature,” and words of like import in any Assignment and Assumption shall be deemed to include electronic signatures or the keeping of records in electronic form, each of which shall be of the same legal effect, validity or enforceability as a manually executed signature or the use of a paper-based recordkeeping system, as the case may be, to the extent and as provided for in any Applicable Law, including Parts 2 and 3 of the
Personal Information Protection and Electronic Documents Act
(Canada), the
Electronic Commerce Act
, 2000 (Ontario), the
Personal Information Protection Act
(Alberta) and other similar federal or provincial laws based on the
Uniform Electronic Commerce Act
of the Uniform Law Conference of Canada or its
Uniform Electronic Evidence Act
, as the case may be.
|
25.1
|
Treatment of Certain Information: Confidentiality.
|
(a)
|
Each of the Agent and the Lenders agrees to maintain the confidentiality of the Information (as defined below), except that Information may be disclosed (a) to it, its Affiliates and its and its Affiliates’ respective partners, directors, officers, employees, agents, advisors and representatives (to the extent necessary to administer or enforce this Agreement and the other Loan Documents) (it being understood that the Persons to whom such disclosure is made will be informed of the confidential nature of such Information and instructed to keep such Information confidential), (b) to the extent requested by any regulatory authority having jurisdiction over it (including any self-regulatory authority), (c) to the extent required by applicable Laws or similar legal process, (d) to any other party hereto, (e) in connection with the exercise of any remedies hereunder or under any other Loan Document or any action or proceeding relating to this Agreement or any other Loan Document or the enforcement of rights hereunder or thereunder, (f) subject to an agreement containing provisions substantially the same as those of this Section, to (i) any assignee of or Participant in, or any prospective assignee of or Participant in, any of its rights or obligations under this Agreement or (ii) any actual or prospective counterparty (or its advisors) to any swap, derivative, credit-linked note or similar transaction relating to the Borrower and its obligations, (g) with the consent of the Borrower or (h) to the extent such Information (x) becomes publicly available other than as a result of a breach of this Section by such Person or actually known to such Person or (y) becomes available to the Agent or any Lender on a non-confidential basis from a source other than a Credit Party. If the Agent or any Lender is requested or required to disclose any Information (other than by any bank examiner) pursuant to or as required by applicable Laws or by a subpoena or similar legal process, the Agent or such Lender, as applicable, shall use its reasonable commercial efforts to provide the Borrower with notice of such requests or obligation in sufficient time so that the Borrower may seek an appropriate protective order or waive the Agent’s, or such Lender’s, as applicable, compliance with the provisions of this Section, and the Agent and such Lender, as applicable, shall, to the extent reasonable, co-operate with the Borrower in the Borrower obtaining any such protective order.
|
(b)
|
For purposes of this Section, “
Information
” means all information received from any Credit Party relating to any Credit Party or any of its Subsidiaries or any of their respective businesses, other than any such information that is available to the Agent or any Lender on a non-
|
(c)
|
In addition, and notwithstanding anything herein to the contrary, the Agent may provide basic information concerning the Borrower and the credit facilities established herein to Loan Pricing Corporation and/or other recognized trade publishers of information for general circulation in the loan market.
|
26.1
|
Further Assurances
|
26.2
|
Acknowledgment
|
|
|
ALTALINK INVESTMENT MANAGEMENT LTD., as general partner of ALTALINK INVESTMENTS, L.P.
|
|
By:
|
/s/ Jeffrey A. Austin
|
||
|
Name: Jeffrey A. Austin
|
||
|
Title: Director
|
||
By:
|
/s/ Calvin D. Haack
|
||
|
Name: Calvin D. Haack
|
||
|
Title: Director
|
|
|
ALTALINK INVESTMENT MANAGEMENT LTD.
|
|
By:
|
/s/ Jeffrey A. Austin
|
||
|
Name: Jeffrey A. Austin
|
||
|
Title: Director
|
||
By:
|
/s/ Calvin D. Haack
|
||
|
Name: Calvin D. Haack
|
||
|
Title: Director
|
|
|
ROYAL BANK OF CANADA, as Agent
|
|
By:
|
/s/ Rodica Dutka
|
||
|
Name: Rodica Dutka
|
||
|
Title: Manager, Agency
|
||
|
|
By:
|
|
|
|
|
Name:
|
|
|
|
Title:
|
|
|
ROYAL BANK OF CANADA, as Lender
|
|
By:
|
/s/ Timothy P. Murray
|
||
|
Name: TIMOTHY P. MURRAY
|
||
|
Title: AUTHORIZED SIGNATORY
|
||
|
|
By:
|
|
|
|
|
Name:
|
|
|
|
Title:
|
|
|
THE BANK OF NOVA SCOTIA, as Lender
|
|
By:
|
/s/ Bradley Walker
|
||
|
Name: Bradley Walker
|
||
|
Title: Director
|
||
|
|
By:
|
/s/ Mathieu Leroux
|
|
|
|
Name: Mathieu Leroux
|
|
|
|
Title: Associate Director
|
|
|
BANK OF MONTREAL, as Lender
|
|
By:
|
/s/ Carol McDonald
|
||
|
Name: Carol McDonald
|
||
|
Title: Director
|
||
By:
|
|
||
|
Name:
|
||
|
Title:
|
|
|
THE TORONTO-DOMINION BANK, as Lender
|
|
By:
|
/s/ Hassan Abbas
|
||
|
Name: Hassan Abbas
|
||
|
Title: Vice President
|
||
|
|
By:
|
/s/ Matthew Hendel
|
|
|
|
Name: Matthew Hendel
|
|
|
|
Title: Managing Director
|
|
|
NATIONAL BANK OF CANADA, as Lender
|
|
By:
|
/s/ Mark Williamson
|
||
|
Name: Mark Williamson
|
||
|
Title: Authorized Signatory
|
||
|
|
By:
|
/s/ Rahul Rahul
|
|
|
|
Name: Rahul Rahul
|
|
|
|
Title: Authorized Signatory
|
|
|
ALBERTA TREASURY BRANCHES, as Lender
|
|
By:
|
/s/ Trevor Guinard
|
||
|
Name: Trevor Guinard
|
||
|
Title: Director
|
||
|
|
By:
|
/s/ Evan Hahn
|
|
|
|
Name: Evan Hahn
|
|
|
|
Title: Associate Director
|
1.
|
Representations and Warranties
. All representations and warranties of the Borrower and the General Partner contained in the Credit Agreement are true and correct in all material respects as if made on and as of the date hereof, except as set out in Appendix I hereto or otherwise notified to the Agent under the Credit Agreement.
|
2.
|
Default/Event of Default
. No Default or Event of Default under the Credit Agreement has occurred and is continuing.
|
3.
|
Financial Covenants
. The Borrower is in compliance with the financial covenants set forth in Section 10.24 of the Credit Agreement and the detailed calculations evidencing such compliance are attached hereto.
|
4.
|
Ratings. [The ratings assigned by each of the Rating Agencies to the Senior Bonds, Series 09-1 is:
l
, the Senior Bonds, Series 12-1 is:
l
, the Senior Bonds, Series 13-1 is:
l
, and the Senior Bonds, Series 15-1 is
l
.]
|
5.
|
Change of Control Compliance
. Pursuant to Section 10.16 of the Credit Agreement, the total revenues and total Assets of all non-wholly-owned Subsidiaries of the Borrower does not exceed 10% of the Borrower’s consolidated revenues or Consolidated Assets, as disclosed in the most recent audited financial statements delivered to the Agent and the Lenders.
|
|
|
ALTALINK INVESTMENT
MANAGEMENT LTD., as general partner of ALTALINK INVESTMENTS, L.P. |
|
By:
|
|
||
|
Name:
|
||
|
Title:
|
||
By:
|
|
||
|
Name:
|
||
|
Title:
|
|
|
ALTALINK INVESTMENT
MANAGEMENT LTD. |
|
By:
|
|
||
|
Name:
|
||
|
Title:
|
||
By:
|
|
||
|
Name:
|
||
|
Title:
|
(a)
|
Prime Rate Loan in the amount of Cdn.$
l
, having a term of
l
[add same provision for any other amount and term requested]
;
|
(b)
|
U.S. Base Rate Loan in the amount of U.S.$
l
, having a term of
l
[add same provision for any other amount and term requested]
;
|
(c)
|
LIBOR Loan in the amount of U.S.$
l
, having a term and LIBOR Interest Period of
l
[add same provision for any other amount and term requested]
; and
|
(d)
|
Bankers’ Acceptance in the aggregate amount of Cdn.$
l
having a term of
l
[add same provision for any other amount and term requested]
.
|
|
|
ALTALINK INVESTMENT MANAGEMENT LTD., as general partner of ALTALINK INVESTMENTS, L.P.
|
|
|
|
||
By:
|
|
||
|
Name:
|
||
|
Title:
|
||
|
|
||
By:
|
|
||
|
Name:
|
||
|
Title:
|
(a)
|
it intends to repay the following Bankers’ Acceptances on the current maturity date:
|
(i)
|
aggregate Face Amount - $; and
|
(ii)
|
current maturity date _____________; and
|
(b)
|
the following Bankers’ Acceptances are to be rolled over in accordance with the Credit Agreement by the issuance of new Bankers’ Acceptances on the current maturity date specified below:
|
(i)
|
aggregate Face Amount of maturing Bankers’ Acceptances - $;
|
(ii)
|
current maturity date - ______________;
|
(iii)
|
new aggregate Face Amount - $
;
|
(iv)
|
new contract period - _______________; and
|
(v)
|
new maturity date - ________________.
|
|
|
ALTALINK INVESTMENT MANAGEMENT LTD., as general partner of ALTALINK INVESTMENTS, L.P.
|
|
By:
|
|
||
|
Name:
|
||
|
Title:
|
||
By:
|
|
||
|
Name:
|
||
|
Title:
|
|
|
ALTALINK INVESTMENT MANAGEMENT LTD., as general partner of ALTALINK INVESTMENTS, L.P.
|
|
|
|
||
By:
|
|
||
|
Name:
|
||
|
Title:
|
||
|
|
||
By:
|
|
||
|
Name:
|
||
|
Title:
|
|
|
ALTALINK INVESTMENT MANAGEMENT LTD., as general partner of ALTALINK INVESTMENTS, L.P.
|
|
|
|
||
By:
|
|
||
|
Name:
|
||
|
Title:
|
||
|
|
||
By:
|
|
||
|
Name:
|
||
|
Title:
|
(a)
|
The date of Issue, being a Business Day, is
l
.
|
(b)
|
The face amount of such Documentary Credit is Cdn $
l
/US$
l
.
|
(c)
|
The expiration date of such Documentary Credit, being a Business Day is
l
.
|
(d)
|
The proposed type of Documentary Credit is
[letter of credit][letter of guarantee]
.
|
(e)
|
The name and address of the Beneficiary is
l
.
|
(f)
|
[Insert any special terms or conditions for the Documentary Credit.]
|
|
|
ALTALINK INVESTMENT MANAGEMENT LTD., as general partner of ALTALINK INVESTMENTS, L.P.
|
|
|
|
||
By:
|
|
||
|
Name:
|
||
|
Title:
|
||
|
|
||
By:
|
|
||
|
Name:
|
||
|
Title:
|
1.
|
Assignor:
|
2.
|
Assignee:
|
|
[and is an Affiliate/Approved Fund of [
identify Lender
]
1
]
|
3.
|
Borrower(s):
|
4.
|
Administrative Agent: Royal Bank of Canada, as the administrative agent under the Credit Agreement
|
5.
|
Credit Agreement: The Credit Agreement dated as of December 9, 2016, among AltaLink Investments L.P., the Lenders parties thereto, Royal Bank of Canada as Administrative Agent, and the other agents parties thereto, as amended, restated or replaced from time to time.
|
6.
|
Assigned Interest:
|
Aggregate Amount of Commitment/Loans for all Lenders
2
|
Amount of Commitment/Loans Assigned
|
Percentage Assigned of Commitment/Loans
3
|
CUSIP Number
|
$
|
$
|
%
|
|
$
|
$
|
%
|
|
$
|
$
|
%
|
|
7.
|
Trade Date:
4
|
|
ASSIGNOR
[NAME OF ASSIGNOR]
|
||
|
|
|
|
|
By:
|
|
|
|
|
Title:
|
|
|
|
|
|
|
|
|
|
|
ASSIGNEE
[NAME OF ASSIGNEE]
|
||
|
|
|
|
|
By:
|
|
|
|
|
Title:
|
|
|
|
|
|
Consented to and Accepted:
|
|
|
|
|
|
|
|
Royal Bank of Canada, as
Administrative Agent
|
|
|
|
|
|
|
|
By
|
|
|
|
|
Title:
|
|
|
|
|
|
|
[Consented to:]
5
|
|
|
|
|
|
|
|
[NAME OF RELEVANT PARTY]
|
|
|
|
|
|
|
|
By
|
|
|
|
|
Title:
|
|
|
1.
|
Representations and Warranties
.
|
2.
|
Payments.
From and after the Effective Date, the Administrative Agent shall make all payments in respect of the Assigned Interest (including payments of principal, interest, fees and other amounts) to the Assignee whether such amounts have accrued prior to, on or after the Effective Date. The Assignor and the Assignee shall make all appropriate adjustments in payments by the Administrative Agent for periods prior to the Effective Date or with respect to the making of this assignment directly between themselves.
|
3.
|
General Provisions
. This Assignment and Assumption shall be binding upon, and inure to the benefit of, the parties hereto and their respective successors and permitted assigns. This Assignment and Assumption may be executed in any number of counterparts, which together shall constitute one instrument. Delivery of an executed counterpart of a signature page of this Assignment and Assumption by telecopy or by sending a scanned copy by electronic mail shall be effective as delivery of a manually executed counterpart of this Assignment and Assumption. This Assignment and Assumption shall be governed by, and construed in accordance with, the law governing the Credit Agreement.
|
Lenders
|
Lender’s Commitment (Cdn.$)
|
Applicable Percentage
|
Royal Bank of Canada
|
$50,000,000
|
25.0%
|
The Bank of Nova Scotia
|
$50,000,000
|
25.0%
|
Bank of Montreal
|
$39,000,000
|
19.5%
|
The Toronto-Dominion Bank
|
$28,000,000
|
14.0%
|
National Bank of Canada
|
$21,000,000
|
10.5%
|
Alberta Treasury Branches
|
$12,000,000
|
6.0%
|
|
|
ALTALINK INVESTMENT MANAGEMENT LTD., as general partner of ALTALINK INVESTMENTS, L.P.
|
|
|
|
||
By:
|
|
||
|
Name:
|
||
|
Title:
|
||
|
|
||
By:
|
|
||
|
Name:
|
||
|
Title:
|
(a)
|
Section 1.1 of the Credit Agreement is hereby amended by adding the following definition therein in the applicable alphabetical order;
|
(b)
|
The definition of “BA Discount Rate” in Section 1.1 of the Credit Agreement is hereby amended by deleting the reference to “Non-Acceptance Bank” in clause (b) therein and replacing it with “Non-Acceptance Lender”;
|
(c)
|
Each of (i) the definition of “CDOR” in Section 1.1 of the Credit Agreement, (ii) Section 4.1 of the Credit Agreement and (iii) Section 12.5 of the Credit Agreement, is hereby amended by deleting the reference to “the Agent” in such definition or Section and replacing it with “the Administrative Agent”;
|
(d)
|
The definition of “Maturity Date” contained in Section 1.1 of the Credit Agreement is hereby amended by deleting the reference to “December 15, 2017” and replacing it with “December 14, 2018;
|
(e)
|
The definition of “Revolving Period” contained in Section 1.1 of the Credit Agreement is hereby amended by deleting the reference to “December 15, 2016” and replacing it with “December 14, 2017;
|
(f)
|
The definition of “Fee Letter” contained in Section 1.1 of the Credit Agreement is deleted in its entirety and replaced with the following:
|
(g)
|
Each of Section 5.1(iii) and Schedule 2(A) of the Credit Agreement is hereby amended by deleting the reference therein to “Notice of Borrowing” and replacing such reference with “Borrowing Notice”; and
|
(h)
|
Subsection (ii) of Section 9.2(g) is hereby deleted in its entirety and replaced with the following:
|
(a)
|
the Administrative Agent shall have received this Amending Agreement duly executed and delivered by the Administrative Agent, the Lenders, the Borrower and the General Partner;
|
(b)
|
no Event of Default shall have occurred and be continuing; and
|
(c)
|
the Borrower shall have paid all fees and expenses in connection with this Amending Agreement including those set out in the Fee Letter.
|
|
|
ALTALINK MANAGEMENT LTD
.,
in its capacity as General Partner of
ALTALINK, L.P.
|
|
By:
|
/s/ David Koch
|
||
|
Name: David Koch
|
||
|
Title: Executive Vice President
and CFO |
||
|
|
||
By:
|
/s/ Christopher J. Lomore
|
||
|
Name: Christopher J. Lomore
|
||
|
Title: Vice President, Treasurer
|
|
|
ALTALINK MANAGEMENT LTD.
|
|
By:
|
/s/ David Koch
|
||
|
Name: David Koch
|
||
|
Title: Executive Vice President
and CFO |
||
|
|
||
By:
|
/s/ Christopher J. Lomore
|
||
|
Name: Christopher J. Lomore
|
||
|
Title: Vice President, Treasurer
|
|
|
THE BANK OF NOVA SCOTIA
, as Administrative Agent, Co-Lead Arranger and Co-Bookrunner
|
|
By:
|
/s/ Clement Yu
|
||
|
Name: Clement Yu
|
||
|
Title: Director
|
||
|
|
||
By:
|
/s/ Ryan Moonilal
|
||
|
Name: Ryan Moonilal
|
||
|
Title: Analyst
|
|
|
THE BANK OF NOVA SCOTIA
, as Lender
|
|
By:
|
/s/ Bradley Walker
|
||
|
Name: Bradley Walker
|
||
|
Title: Director
|
||
|
|
||
By:
|
/s/ Mathieu Leroux
|
||
|
Name: Mathieu Leroux
|
||
|
Title: Associate Director
|
|
|
ROYAL BANK OF CANADA
, as Syndication Agent, Co-Lead Arranger, and Co-Bookrunner
|
|
By:
|
/s/ Timothy P. Murray
|
||
|
Name: TIMOTHY P. MURRAY
|
||
|
Title: AUTHORIZED SIGNATORY
|
|
|
ROYAL BANK OF CANADA
, as Lender
|
|
By:
|
/s/ Timothy P. Murray
|
||
|
Name: TIMOTHY P. MURRAY
|
||
|
Title: AUTHORIZED SIGNATORY
|
|
|
THE BANK OF MONTREAL
, as Co-Documentation Agent
|
|
By:
|
/s/ Carol McDonald
|
||
|
Name: Carol McDonald
|
||
|
Director
|
||
|
|
||
By:
|
|
||
|
Name:
|
||
|
Title:
|
|
|
THE BANK OF MONTREAL
,
as Lender |
|
By:
|
/s/ Carol McDonald
|
||
|
Name: Carol McDonald
|
||
|
Title: Director
|
||
|
|
||
By:
|
|
||
|
Name:
|
||
|
Title:
|
|
|
NATIONAL BANK OF CANADA
, as Co-Documentation Agent
|
|
By:
|
/s/ Mark Williamson
|
||
|
Name: Mark Williamson
|
||
|
Title: Authorized Signatory
|
||
|
|
||
By:
|
/s/ Rahul Rahul
|
||
|
Name: Rahul Rahul
|
||
|
Title: Authorized Signatory
|
|
|
NATIONAL BANK OF CANADA
,
as Lender |
|
By:
|
/s/ Mark Williamson
|
||
|
Name: Mark Williamson
|
||
|
Title: Authorized Signatory
|
||
|
|
||
By:
|
/s/ Rahul Rahul
|
||
|
Name: Rahul Rahul
|
||
|
Title: Authorized Signatory
|
|
|
THE TORONTO-DOMINION BANK
, as Lender
|
|
By:
|
/s/ Matthew Hendel
|
||
|
Name: Matthew Hendel
|
||
|
Title: Managing Director
|
||
|
|
||
By:
|
/s/ Hassan Abbas
|
||
|
Name: Hassan Abbas
|
||
|
Title: Vice President
|
|
|
ALBERTA TREASURY BRANCHES
, as Lender
|
|
By:
|
/s/ Trevor Guinard
|
||
|
Name: Trevor Guinard
|
||
|
Title: Director
|
||
|
|
||
By:
|
/s/ Evan Hahn
|
||
|
Name: Evan Hahn
|
||
|
Title: Associate Director
|
(a)
|
Section 1.1 of the Credit Agreement is hereby amended by adding the following definition therein in the applicable alphabetical order:
|
(b)
|
The definition of “Applicable Margin” contained in Section 1.1 of the Credit Agreement is hereby amended by (i) deleting the reference to “applicable LIBOR Margin” in the second last paragraph of such definition and replacing it with “Applicable Margin for LIBOR Loans” and (ii) deleting the reference to “LIBOR Advance” in the second last paragraph of such definition and replacing it with “LIBOR Loan”;
|
(c)
|
The definition of “Maturity Date” contained in Section 1.1 of the Credit Agreement is hereby amended by deleting the reference to “December 15, 2017” and replacing it with “December 14, 2018”;
|
(d)
|
The definition of “Revolving Period” contained in Section 1.1 of the Credit Agreement is hereby amended by deleting the reference to “December 15, 2016” and replacing it with “December 14, 2017”;
|
(e)
|
Each of Section 5.1(iii) and Schedule 2(A) of the Credit Agreement is hereby amended by deleting the reference therein to “Notice of Borrowing” and replacing such reference with “Borrowing Notice”;
|
(f)
|
Subsection (ii) of Section 9.2(g) is hereby deleted in its entirety and replaced with the following:
|
(g)
|
Section 11.1 of the Credit Agreement is hereby amended by deleting the reference to “Administrative Agent” and replacing such reference with “Agent”.
|
(a)
|
the Agent shall have received this Amending Agreement duly executed and delivered by the Agent, the Lenders, the Borrower and the General Partner;
|
(b)
|
no Event of Default shall have occurred and be continuing; and
|
(c)
|
the Borrower shall have paid all fees and expenses in connection with this Amending Agreement including an extension fee of Cdn.$30,000 payable to the Agent.
|
|
|
ALTALINK MANAGEMENT LTD
.,
in its capacity as General Partner of
ALTALINK, L.P.
|
|
By:
|
/s/ David Koch
|
||
|
Name: David Koch
|
||
|
Title: Executive Vice President
and CFO |
||
|
|
||
By:
|
/s/ Christopher J. Lomore
|
||
|
Name: Christopher J. Lomore
|
||
|
Title: Vice President, Treasurer
|
|
|
ALTALINK MANAGEMENT LTD.
|
|
By:
|
/s/ David Koch
|
||
|
Name: David Koch
|
||
|
Title: Executive Vice President
and CFO |
||
|
|
||
By:
|
/s/ Christopher J. Lomore
|
||
|
Name: Christopher J. Lomore
|
||
|
Title: Vice President, Treasurer
|
|
|
THE BANK OF NOVA SCOTIA
, as Agent
|
|
By:
|
/s/ Clement Yu
|
||
|
Name: Clement Yu
|
||
|
Title: Director
|
||
|
|
||
By:
|
/s/ Ryan Moonilal
|
||
|
Name: Ryan Moonilal
|
||
|
Title: Analyst
|
|
|
THE BANK OF NOVA SCOTIA
, as Lender
|
|
By:
|
/s/ Bradley Walker
|
||
|
Name: Bradley Walker
|
||
|
Title: Director
|
||
|
|
||
By:
|
/s/ Mathieu Leroux
|
||
|
Name: Mathieu Leroux
|
||
|
Title: Associate Director
|
Name and Title
|
Base Salary
|
||
Gregory E. Abel
Chairman, President and Chief Executive Officer
|
$
|
1,000,000
|
|
Patrick J. Goodman
Executive Vice President and Chief Financial Officer
|
$
|
482,000
|
|
Natalie L. Hocken
Senior Vice President and General Counsel
|
$
|
420,000
|
|
Name and Title
|
|
Base Salary
|
||
|
|
|
||
Nikki L. Kobliha
|
|
$
|
209,854
|
|
Director, Vice President, Chief Financial Officer and Treasurer
|
|
|
||
|
|
|
||
Stefan A. Bird
|
|
346,000
|
|
|
President and Chief Executive Officer, Pacific Power
|
|
|
||
|
|
|
||
Cindy A. Crane
|
|
346,000
|
|
|
President and Chief Executive Officer, Rocky Mountain Power
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
|
|
Years Ended December 31,
|
||||||||||||||||||
|
|
2016
|
|
2015
|
|
2014
|
|
2013
|
|
2012
|
||||||||||
Earnings Available for Fixed Charges:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Income from continuing operations
|
|
|
|
|
|
|
|
|
|
|
||||||||||
before income tax expense
|
|
$
|
1,103
|
|
|
$
|
1,023
|
|
|
$
|
1,007
|
|
|
$
|
979
|
|
|
$
|
734
|
|
Fixed charges
|
|
385
|
|
|
384
|
|
|
384
|
|
|
385
|
|
|
385
|
|
|||||
Total earnings available for fixed charges
|
|
$
|
1,488
|
|
|
$
|
1,407
|
|
|
$
|
1,391
|
|
|
$
|
1,364
|
|
|
$
|
1,119
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Fixed Charges:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Interest expense
|
|
$
|
380
|
|
|
$
|
379
|
|
|
$
|
379
|
|
|
$
|
379
|
|
|
$
|
380
|
|
Estimated interest portion of rentals
|
|
|
|
|
|
|
|
|
|
|
||||||||||
charged to expense
|
|
5
|
|
|
5
|
|
|
5
|
|
|
6
|
|
|
5
|
|
|||||
Total fixed charges
|
|
$
|
385
|
|
|
$
|
384
|
|
|
$
|
384
|
|
|
$
|
385
|
|
|
$
|
385
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Ratio of Earnings to Fixed Charges
|
|
3.9x
|
|
|
3.7x
|
|
|
3.6x
|
|
|
3.5x
|
|
|
2.9x
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
|
|
Years Ended December 31,
|
||||||||||||||||||
|
|
2016
|
|
2015
|
|
2014
|
|
2013
|
|
2012
|
||||||||||
Earnings Available for Fixed Charges:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Income from continuing operations
|
|
|
|
|
|
|
|
|
|
|
||||||||||
before income tax expense
|
|
$
|
1,103
|
|
|
$
|
1,023
|
|
|
$
|
1,007
|
|
|
$
|
979
|
|
|
$
|
734
|
|
Fixed charges
|
|
385
|
|
|
384
|
|
|
384
|
|
|
385
|
|
|
385
|
|
|||||
Total earnings available for fixed charges
|
|
$
|
1,488
|
|
|
$
|
1,407
|
|
|
$
|
1,391
|
|
|
$
|
1,364
|
|
|
$
|
1,119
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Fixed Charges and Preferred Stock Dividends:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Interest expense
|
|
$
|
380
|
|
|
$
|
379
|
|
|
$
|
379
|
|
|
$
|
379
|
|
|
$
|
380
|
|
Estimated interest portion of rentals
|
|
|
|
|
|
|
|
|
|
|
||||||||||
charged to expense
|
|
5
|
|
|
5
|
|
|
5
|
|
|
6
|
|
|
5
|
|
|||||
Total fixed charges
|
|
385
|
|
|
384
|
|
|
384
|
|
|
385
|
|
|
385
|
|
|||||
Preferred stock dividends
(1)
|
|
—
|
|
|
—
|
|
|
—
|
|
|
2
|
|
|
3
|
|
|||||
Total fixed charges and preferred stock dividends
|
|
$
|
385
|
|
|
$
|
384
|
|
|
$
|
384
|
|
|
$
|
387
|
|
|
$
|
388
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Ratio of Earnings to Combined Fixed
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Charges and Preferred Stock Dividends
|
|
3.9x
|
|
|
3.7x
|
|
|
3.6x
|
|
|
3.5x
|
|
|
2.9x
|
|
|
|
Years Ended December 31,
|
||||||||||||||||||
|
|
2016
|
|
2015
|
|
2014
|
|
2013
|
|
2012
|
||||||||||
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Earnings available for fixed charges:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Net income
|
|
$
|
279
|
|
|
$
|
288
|
|
|
$
|
227
|
|
|
$
|
145
|
|
|
$
|
258
|
|
Add (deduct):
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Income tax expense
|
|
146
|
|
|
162
|
|
|
130
|
|
|
94
|
|
|
138
|
|
|||||
Fixed charges
|
|
185
|
|
|
190
|
|
|
211
|
|
|
220
|
|
|
220
|
|
|||||
Capitalized interest (allowance for borrowed funds used during construction)
|
|
(4
|
)
|
|
(3
|
)
|
|
(1
|
)
|
|
(6
|
)
|
|
(5
|
)
|
|||||
|
|
327
|
|
|
349
|
|
|
340
|
|
|
308
|
|
|
353
|
|
|||||
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Total earnings available for fixed charges
|
|
$
|
606
|
|
|
$
|
637
|
|
|
$
|
567
|
|
|
$
|
453
|
|
|
$
|
611
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Fixed charges -
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Interest expense
|
|
185
|
|
|
190
|
|
|
211
|
|
|
220
|
|
|
220
|
|
|||||
Total fixed charges
|
|
$
|
185
|
|
|
$
|
190
|
|
|
$
|
211
|
|
|
$
|
220
|
|
|
$
|
220
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Ratio of earnings to fixed charges
|
|
3.3x
|
|
|
3.4x
|
|
|
2.7x
|
|
|
2.1x
|
|
|
2.8x
|
|
|
|
Years Ended December 31,
|
||||||||||||||||||
|
|
2016
|
|
2015
|
|
2014
|
|
2013
|
|
2012
|
||||||||||
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Earnings available for fixed charges:
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Net income
|
|
$
|
84
|
|
|
$
|
83
|
|
|
$
|
87
|
|
|
$
|
55
|
|
|
$
|
84
|
|
Add (deduct):
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Income tax expense
|
|
49
|
|
|
47
|
|
|
47
|
|
|
33
|
|
|
40
|
|
|||||
Fixed charges
|
|
56
|
|
|
61
|
|
|
63
|
|
|
62
|
|
|
66
|
|
|||||
Capitalized interest (allowance for borrowed funds used during construction)
|
|
(4
|
)
|
|
(2
|
)
|
|
(2
|
)
|
|
(2
|
)
|
|
(2
|
)
|
|||||
|
|
101
|
|
|
106
|
|
|
108
|
|
|
93
|
|
|
104
|
|
|||||
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Total earnings available for fixed charges
|
|
$
|
185
|
|
|
$
|
189
|
|
|
$
|
195
|
|
|
$
|
148
|
|
|
$
|
188
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Fixed charges -
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Interest expense
|
|
56
|
|
|
61
|
|
|
63
|
|
|
62
|
|
|
66
|
|
|||||
Total fixed charges
|
|
$
|
56
|
|
|
$
|
61
|
|
|
$
|
63
|
|
|
$
|
62
|
|
|
$
|
66
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Ratio of earnings to fixed charges
|
|
3.3x
|
|
|
3.1x
|
|
|
3.1x
|
|
|
2.4x
|
|
|
2.8x
|
|
PPW Holdings LLC
|
Delaware
|
PacifiCorp
|
Oregon
|
MidAmerican Funding, LLC
|
Iowa
|
MHC Inc.
|
Iowa
|
MidAmerican Energy Company
|
Iowa
|
NVE Holdings, LLC
|
Delaware
|
NV Energy, Inc.
|
Nevada
|
Nevada Power Company d/b/a NV Energy
|
Nevada
|
Sierra Pacific Power Company d/b/a NV Energy
|
Nevada
|
Northern Powergrid Holdings Company
|
England
|
Northern Powergrid U.K. Holdings
|
England
|
Northern Powergrid Limited
|
England
|
Northern Electric plc.
|
England
|
Northern Powergrid (Northeast) Limited
|
England
|
Yorkshire Power Group Limited
|
England
|
Yorkshire Electricity Group plc.
|
England
|
Northern Powergrid (Yorkshire) plc.
|
England
|
NNGC Acquisition, LLC
|
Delaware
|
Northern Natural Gas Company
|
Delaware
|
KR Holding, LLC
|
Delaware
|
Kern River Gas Transmission Company
|
Texas
|
BHE Canada, LLC
|
Delaware
|
BHE Canada Holdings Corporation
|
Alberta
|
BHE AltaLink Ltd.
|
Canada
|
AltaLink Holdings, L.P.
|
Canada
|
AltaLink Investments, L.P.
|
Canada
|
AltaLink, L.P.
|
Canada
|
BHE U.S. Transmission, LLC
|
Delaware
|
BHE Renewables, LLC
|
Delaware
|
HomeServices of America, Inc.
|
Delaware
|
/s/ Gregory E. Abel
|
|
/s/ Patrick J. Goodman
|
GREGORY E. ABEL
|
|
PATRICK J. GOODMAN
|
|
|
|
/s/ Warren E. Buffett
|
|
/s/ Marc D. Hamburg
|
WARREN E. BUFFETT
|
|
MARC D. HAMBURG
|
|
|
|
/s/ Walter Scott, Jr.
|
|
|
WALTER SCOTT, JR.
|
|
|
1.
|
|
I have reviewed this Annual Report on Form 10-K of Berkshire Hathaway Energy Company;
|
|
|
|
|
|
2.
|
|
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
|
|
|
|
|
|
3.
|
|
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
|
|
|
|
|
|
4.
|
|
The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
|
|
|
|
|
|
|
|
a)
|
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
|
|
|
|
|
|
|
b)
|
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
|
|
|
|
|
|
|
c)
|
Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
|
|
|
|
|
|
|
d)
|
Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
|
|
|
||
5.
|
|
The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):
|
|
|
|
||
|
|
a)
|
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
|
|
|
||
|
|
b)
|
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.
|
Date: February 24, 2017
|
/s/ Gregory E. Abel
|
|
|
Gregory E. Abel
|
|
|
Chairman, President and Chief Executive Officer
|
|
|
(principal executive officer)
|
|
1.
|
|
I have reviewed this Annual Report on Form 10-K of Berkshire Hathaway Energy Company;
|
|
|
|
|
|
2.
|
|
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
|
|
|
|
|
|
3.
|
|
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
|
|
|
|
|
|
4.
|
|
The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
|
|
|
|
|
|
|
|
a)
|
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
|
|
|
|
|
|
|
b)
|
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
|
|
|
|
|
|
|
c)
|
Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
|
|
|
|
|
|
|
d)
|
Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
|
|
|
||
5.
|
|
The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):
|
|
|
|
||
|
|
a)
|
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
|
|
|
||
|
|
b)
|
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.
|
Date: February 24, 2017
|
/s/ Patrick J. Goodman
|
|
|
Patrick J. Goodman
|
|
|
Executive Vice President and Chief Financial Officer
|
|
|
(principal financial officer)
|
|
1.
|
I have reviewed this Annual Report on Form 10-K of
PacifiCorp
;
|
2.
|
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
|
3.
|
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
|
4.
|
The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
|
(a)
|
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
|
(b)
|
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
|
(c)
|
Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
|
(d)
|
Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and
|
5.
|
The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):
|
(a)
|
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and
|
(b)
|
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.
|
Date: February 24, 2017
|
|
/s/ Gregory E. Abel
|
|
|
|
|
Gregory E. Abel
|
|
|
|
|
Chairman of the Board of Directors and Chief Executive Officer
|
|
|
|
|
(principal executive officer)
|
|
|
1.
|
I have reviewed this Annual Report on Form 10-K of
PacifiCorp
;
|
2.
|
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
|
3.
|
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
|
4.
|
The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
|
(a)
|
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
|
(b)
|
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
|
(c)
|
Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
|
(d)
|
Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and
|
5.
|
The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):
|
(a)
|
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and
|
(b)
|
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.
|
Date: February 24, 2017
|
|
/s/ Nikki L. Kobliha
|
|
|
|
|
Nikki L. Kobliha
|
|
|
|
|
Director, Vice President, Chief Financial Officer, and Treasurer
|
|
|
|
|
(principal financial officer)
|
|
|
1.
|
I have reviewed this annual report on Form 10-K of MidAmerican Energy Company;
|
|
|
|
|
2.
|
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
|
|
|
|
|
3.
|
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
|
|
|
|
|
4.
|
The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal controls over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
|
|
|
|
|
|
a)
|
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
|
|
|
|
|
b)
|
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
|
|
|
|
|
c)
|
Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
|
|
|
|
|
d)
|
Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
|
|
|
|
5.
|
The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):
|
|
|
|
|
|
a)
|
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
|
|
|
|
|
b)
|
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.
|
Date: February 24, 2017
|
/s/ William J. Fehrman
|
|
|
William J. Fehrman
|
|
|
President and Chief Executive Officer
|
|
|
(principal executive officer)
|
|
1.
|
I have reviewed this annual report on Form 10-K of MidAmerican Energy Company;
|
|
|
|
|
2.
|
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
|
|
|
|
|
3.
|
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
|
|
|
|
|
4.
|
The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal controls over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
|
|
|
|
|
|
a)
|
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
|
|
|
|
|
b)
|
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
|
|
|
|
|
c)
|
Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
|
|
|
|
|
d)
|
Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
|
|
|
|
5.
|
The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):
|
|
|
|
|
|
a)
|
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
|
|
|
|
|
b)
|
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.
|
Date: February 24, 2017
|
/s/ Thomas B. Specketer
|
|
|
Thomas B. Specketer
|
|
|
Vice President and Chief Financial Officer
|
|
|
(principal financial officer)
|
|
1.
|
I have reviewed this annual report on Form 10-K of MidAmerican Funding, LLC;
|
|
|
|
|
2.
|
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
|
|
|
|
|
3.
|
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
|
|
|
|
|
4.
|
The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal controls over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
|
|
|
|
|
|
a)
|
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
|
|
|
|
|
b)
|
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
|
|
|
|
|
c)
|
Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
|
|
|
|
|
d)
|
Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
|
|
|
|
5.
|
The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):
|
|
|
|
|
|
a)
|
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
|
|
|
|
|
b)
|
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.
|
Date: February 24, 2017
|
/s/ William J. Fehrman
|
|
|
William J. Fehrman
|
|
|
President
|
|
|
(principal executive officer)
|
|
1.
|
I have reviewed this annual report on Form 10-K of MidAmerican Funding, LLC;
|
|
|
|
|
2.
|
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
|
|
|
|
|
3.
|
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
|
|
|
|
|
4.
|
The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal controls over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
|
|
|
|
|
|
a)
|
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
|
|
|
|
|
b)
|
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
|
|
|
|
|
c)
|
Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
|
|
|
|
|
d)
|
Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
|
|
|
|
5.
|
The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):
|
|
|
|
|
|
a)
|
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
|
|
|
|
|
b)
|
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.
|
Date: February 24, 2017
|
/s/ Thomas B. Specketer
|
|
|
Thomas B. Specketer
|
|
|
Vice President and Controller
|
|
|
(principal financial officer)
|
|
1.
|
I have reviewed this Annual Report on Form 10-K of
Nevada Power Company
(dba NV Energy);
|
2.
|
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
|
3.
|
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
|
4.
|
The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)), for the registrant and have:
|
(a)
|
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
|
(b)
|
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
|
(c)
|
Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
|
(d)
|
Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and
|
5.
|
The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):
|
(a)
|
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and
|
(b)
|
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.
|
Date: February 24, 2017
|
/s/ Paul J. Caudill
|
|
|
Paul J. Caudill
|
|
|
President and Chief Executive Officer
|
|
|
(principal executive officer)
|
|
1.
|
I have reviewed this Annual Report on Form 10-K of
Nevada Power Company
(dba NV Energy);
|
2.
|
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
|
3.
|
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
|
4.
|
The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)), for the registrant and have:
|
(a)
|
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
|
(b)
|
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
|
(c)
|
Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
|
(d)
|
Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and
|
5.
|
The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):
|
(a)
|
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and
|
(b)
|
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.
|
Date: February 24, 2017
|
/s/ E. Kevin Bethel
|
|
|
E. Kevin Bethel
|
|
|
Senior Vice President, Chief Financial Officer and Director
|
|
|
(principal financial officer)
|
|
1.
|
I have reviewed this Annual Report on Form 10-K of
Sierra Pacific Power Company
(dba NV Energy);
|
2.
|
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
|
3.
|
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
|
4.
|
The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)), for the registrant and have:
|
(a)
|
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
|
(b)
|
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
|
(c)
|
Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
|
(d)
|
Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and
|
5.
|
The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):
|
(a)
|
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and
|
(b)
|
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.
|
Date: February 24, 2017
|
/s/ Paul J. Caudill
|
|
|
Paul J. Caudill
|
|
|
President and Chief Executive Officer
|
|
|
(principal executive officer)
|
|
1.
|
I have reviewed this Annual Report on Form 10-K of
Sierra Pacific Power Company
(dba NV Energy);
|
2.
|
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
|
3.
|
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
|
4.
|
The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)), for the registrant and have:
|
(a)
|
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
|
(b)
|
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
|
(c)
|
Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
|
(d)
|
Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and
|
5.
|
The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):
|
(a)
|
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and
|
(b)
|
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.
|
Date: February 24, 2017
|
/s/ E. Kevin Bethel
|
|
|
E. Kevin Bethel
|
|
|
Senior Vice President, Chief Financial Officer and Director
|
|
|
(principal financial officer)
|
|
(1
|
)
|
|
the Annual Report on Form 10-K of the Company for the annual period ended December 31, 2016 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and
|
|
|
|
|
(2
|
)
|
|
the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.
|
Date: February 24, 2017
|
/s/ Gregory E. Abel
|
|
|
Gregory E. Abel
|
|
|
Chairman, President and Chief Executive Officer
|
|
|
(principal executive officer)
|
|
(1
|
)
|
|
the Annual Report on Form 10-K of the Company for the annual period ended December 31, 2016 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and
|
|
|
|
|
(2
|
)
|
|
the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.
|
Date: February 24, 2017
|
/s/ Patrick J. Goodman
|
|
|
Patrick J. Goodman
|
|
|
Executive Vice President and Chief Financial Officer
|
|
|
(principal financial officer)
|
|
(1)
|
the Annual Report on Form 10-K of the Company for the annual period ended
December 31, 2016
(the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and
|
(2)
|
the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.
|
Date: February 24, 2017
|
|
/s/ Gregory E. Abel
|
|
|
|
|
Gregory E. Abel
|
|
|
|
|
Chairman of the Board of Directors and Chief Executive Officer
|
|
|
|
|
(principal executive officer)
|
|
|
(1)
|
the Annual Report on Form 10-K of the Company for the annual period ended
December 31, 2016
(the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and
|
(2)
|
the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.
|
Date: February 24, 2017
|
|
/s/ Nikki L. Kobliha
|
|
|
|
|
Nikki L. Kobliha
|
|
|
|
|
Director, Vice President, Chief Financial Officer, and Treasurer
|
|
|
|
|
(principal financial officer)
|
|
|
(1)
|
the Annual Report on Form 10-K of the Company for the annual period ended December 31,
2016
(the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and
|
(2)
|
the information contained in the Report fairly presents, in all material respects, the financial condition and result of operations of the Company.
|
Date: February 24, 2017
|
/s/ William J. Fehrman
|
|
|
William J. Fehrman
|
|
|
President and Chief Executive Officer
|
|
|
(principal executive officer)
|
|
(1)
|
the Annual Report on Form 10-K of the Company for the annual period ended
December 31, 2016
(the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and
|
(2)
|
the information contained in the Report fairly presents, in all material respects, the financial condition and result of operations of the Company.
|
Date: February 24, 2017
|
/s/ Thomas B. Specketer
|
|
|
Thomas B. Specketer
|
|
|
Vice President and Chief Financial Officer
|
|
|
(principal financial officer)
|
|
(1)
|
the Annual Report on Form 10-K of the Company for the annual period ended
December 31, 2016
(the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and
|
(2)
|
the information contained in the Report fairly presents, in all material respects, the financial condition and result of operations of the Company.
|
Date: February 24, 2017
|
/s/ William J. Fehrman
|
|
|
William J. Fehrman
|
|
|
President
|
|
|
(principal executive officer)
|
|
(1)
|
the Annual Report on Form 10-K of the Company for the annual period ended
December 31, 2016
(the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and
|
(2)
|
the information contained in the Report fairly presents, in all material respects, the financial condition and result of operations of the Company.
|
Date: February 24, 2017
|
/s/ Thomas B. Specketer
|
|
|
Thomas B. Specketer
|
|
|
Vice President and Controller
|
|
|
(principal financial officer)
|
|
(1)
|
the Annual Report on Form 10-K of
Nevada Power Company
for the annual period ended
December 31, 2016
(the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and
|
(2)
|
the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of
Nevada Power Company
.
|
Date: February 24, 2017
|
/s/ Paul J. Caudill
|
|
|
Paul J. Caudill
|
|
|
President and Chief Executive Officer
|
|
|
(principal executive officer)
|
|
(1)
|
the Annual Report on Form 10-K of
Nevada Power Company
for the annual period ended
December 31, 2016
(the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and
|
(2)
|
the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of
Nevada Power Company
.
|
Date: February 24, 2017
|
/s/ E. Kevin Bethel
|
|
|
E. Kevin Bethel
|
|
|
Senior Vice President, Chief Financial Officer and Director
|
|
|
(principal financial officer)
|
|
(1)
|
the Annual Report on Form 10-K of
Sierra Pacific Power Company
for the annual period ended
December 31, 2016
(the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and
|
(2)
|
the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of
Sierra Pacific Power Company
.
|
Date: February 24, 2017
|
/s/ Paul J. Caudill
|
|
|
Paul J. Caudill
|
|
|
President and Chief Executive Officer
|
|
|
(principal executive officer)
|
|
(1)
|
the Annual Report on Form 10-K of
Sierra Pacific Power Company
for the annual period ended
December 31, 2016
(the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and
|
(2)
|
the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of
Sierra Pacific Power Company
.
|
Date: February 24, 2017
|
/s/ E. Kevin Bethel
|
|
|
E. Kevin Bethel
|
|
|
Senior Vice President, Chief Financial Officer and Director
|
|
|
(principal financial officer)
|
|
|
|
Mine Safety Act
|
|
|
|
Legal Actions
|
|||||||||||||||||||||||
|
|
|
|
|
|
|
|
Total
|
|
|
|
|
|||||||||||||||||
|
|
Section 104
|
|
|
|
Section
|
|
Value of
|
|
|
|
|
|||||||||||||||||
|
|
Significant
|
|
Section
|
|
107(a)
|
|
Proposed
|
|
Pending
|
|
|
|||||||||||||||||
|
|
and
|
Section
|
104(d)
|
Section
|
Imminent
|
|
MSHA
|
|
as of Last
|
Instituted
|
Resolved
|
|||||||||||||||||
|
|
Substantial
|
104(b)
|
Citations/
|
110(b)(2)
|
Danger
|
|
Assessments
|
|
Day of
|
During
|
During
|
|||||||||||||||||
Mining Facilities
|
|
Citations
(1)
|
Orders
(2)
|
Orders
(3)
|
Violations
(4)
|
Orders
(5)
|
|
(in thousands)
|
|
Period
(6)
|
Period
|
Period
|
|||||||||||||||||
Bridger (surface)
|
|
5
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
$
|
12
|
|
|
5
|
|
|
3
|
|
|
4
|
|
|
Bridger (underground)
|
|
37
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
74
|
|
|
4
|
|
|
9
|
|
|
10
|
|
||
Wyodak Coal Crushing Facility
|
|
1
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
(1)
|
Citations for alleged violations of mandatory health and safety standards that could significantly or substantially contribute to the cause and effect of a safety or health hazard under Section 104 of the Mine Safety Act.
|
(2)
|
For alleged failure to totally abate the subject matter of a Mine Safety Act Section 104(a) citation within the period specified in the citation.
|
(3)
|
For alleged unwarrantable failure (i.e., aggravated conduct constituting more than ordinary negligence) to comply with a mandatory health or safety standard.
|
(4)
|
For alleged flagrant violations (i.e., reckless or repeated failure to make reasonable efforts to eliminate a known violation of a mandatory health or safety standard that substantially and proximately caused, or reasonably could have been expected to cause, death or serious bodily injury).
|
(5)
|
For the existence of any condition or practice in a coal or other mine which could reasonably be expected to cause death or serious physical harm before such condition or practice can be abated.
|
(6)
|
Amounts include six contests of proposed penalties under Subpart C, two contests of citations or orders under Subpart B and one labor-related complaint under Subpart E of the Federal Mine Safety and Health Review Commission's procedural rules. The pending legal actions are not exclusive to citations, notices, orders and penalties assessed by MSHA during the reporting period.
|